CN110714755A - Method for rapidly predicting secondary enrichment speed of residual oil in water-drive reservoir - Google Patents
Method for rapidly predicting secondary enrichment speed of residual oil in water-drive reservoir Download PDFInfo
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- 238000012216 screening Methods 0.000 claims abstract description 4
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- 239000003921 oil Substances 0.000 claims description 99
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- 239000010779 crude oil Substances 0.000 claims description 28
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- E—FIXED CONSTRUCTIONS
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- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
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Abstract
The invention provides a method for quickly predicting the secondary enrichment speed of residual oil in a water-drive reservoir, which comprises the following steps of: step 1, performing secondary enrichment technology application well area screening of residual oil according to oil reservoir development characteristics; step 2, comprehensively determining key parameter values of the selected well area influencing the secondary enrichment speed of the residual oil by synthesizing seismic data, core test data, logging data, well testing data and development dynamic data; and 3, predicting the secondary enrichment speed of the residual oil. The method for rapidly predicting the secondary enrichment speed of the residual oil in the water-drive reservoir provides technical support for residual oil submergence and recovery efficiency improvement in the later development stage of the water-drive reservoir, particularly for development strategies, periodic oil recovery strategies, interlayer alternate mining period determination, secondary development of near-waste reservoirs and the like in the low-efficiency development reservoir in the ultra-high water-cut period, and has wide popularization and application prospect and remarkable economic and social benefits.
Description
Technical Field
The invention relates to the field of potential excavation and recovery efficiency improvement in the later stage of water-drive reservoir development, in particular to a method for quickly predicting the secondary enrichment speed of residual oil in a water-drive reservoir.
Background
After the water-drive oil reservoir enters an ultrahigh water content development stage, the residual oil is distributed and dispersed along with the deepening of the exploitation degree and is difficult to effectively use. In the development process, in an oil layer or a well area which is stopped to be produced due to strong flooding or extra-strong flooding of original forced production and forced injection, residual oil can be gathered again at the high position of the oil layer or the well area after a certain period of time due to the change of underground dynamic conditions, water content of the oil well is obviously reduced after the oil well is newly produced, the yield is increased, the oil layer or the well area is newly developed, and the condition can be called as secondary enrichment of the residual oil. The mode of utilizing the secondary enrichment mechanism of the residual oil for development can change the original low-efficiency development state of the oil reservoir and further improve the recovery ratio of the oil reservoir. At present, the method for predicting the secondary enrichment speed of the residual oil and determining the secondary enrichment effect of the residual oil in the oil well can only determine the change amplitude of the water content of an oil layer or a well region after redevelopment by establishing a geological model, performing numerical simulation history fitting and predicting, namely predicting the secondary enrichment speed of the residual oil, but the method needs to prepare a large amount of data, has long history fitting period of the model and is inconvenient to apply, and is difficult to meet the requirement of quick decision-making of yield increasing measures in the mine.
In the application No.: 201710080315.5, provides a quick identification method for secondary enrichment of residual oil in the later period of high water content of a complex fault block oil reservoir. It includes: measuring the target oil reservoir to obtain geological parameters and well pattern parameters of the target oil reservoir; establishing a primary physical model of the target oil reservoir according to the geological parameters and the well pattern parameters of the target oil reservoir; based on the preliminary physical model of the target oil reservoir, performing fitting calculation according to a streamline flow pipe method to obtain dynamic fitting characteristics of an oil production well and a saturation field before secondary enrichment of residual oil, and correcting the preliminary physical model of the target oil reservoir to obtain a corrected physical model; and on the basis of the corrected physical model, calculating vertical enrichment and horizontal enrichment of each node in the residual oil enrichment process respectively to obtain the reservoir saturation and water content of each node, and completing the identification of the secondary enrichment of the residual oil in the later period of high water content of the target oil reservoir. This patent utilizes the flowage pipe method to calculate the aqueous saturation field after the surplus oil secondary enrichment, then calculates the well-opening moisture content after the enrichment, and this method calculation process, mode are all comparatively loaded down with trivial details, are unfavorable for the mine site technical staff to judge surplus oil secondary enrichment effect fast, and the implementation is used the degree of difficulty great.
In the application No.: 201310718147.X, which is a Chinese patent application, relates to a prediction method for a residual oil re-enrichment period of a water-drive oil reservoir, and the prediction method for the residual oil re-enrichment period of the water-drive oil reservoir comprises the following steps of 1, calculating a water saturation value of the oil reservoir to be researched; step 2, selecting a corresponding water-drive reservoir oil-water migration velocity formula according to the water saturation value; and step 3, calculating the longest time required by the residual oil re-enrichment reservoir by using the selected water-drive reservoir oil-water migration velocity formula, namely the residual oil re-enrichment reservoir formation period. The method only can calculate the migration speed of the residual oil at a certain moment, and calculate the secondary enrichment and accumulation period of the residual oil at the speed.
Therefore, a novel method for quickly predicting the secondary enrichment speed of the residual oil in the water-drive reservoir is invented, and the technical problems are solved.
Disclosure of Invention
The invention aims to provide a rapid prediction method for the secondary enrichment speed of residual oil in a water-drive reservoir, which is used for establishing a characteristic model and regularly researching the sensitive factors influencing the secondary enrichment speed of the residual oil by the characteristic model.
The object of the invention can be achieved by the following technical measures: the method for quickly predicting the secondary enrichment speed of the residual oil of the water-drive reservoir comprises the following steps of: step 1, performing secondary enrichment technology application well area screening of residual oil according to oil reservoir development characteristics; step 2, comprehensively determining key parameter values of the selected well area influencing the secondary enrichment speed of the residual oil by synthesizing seismic data, core test data, logging data, well testing data and development dynamic data; and 3, predicting the secondary enrichment speed of the residual oil.
The object of the invention can also be achieved by the following technical measures:
in step 1, the reservoir conditions of the selected well region meet the following conditions:
(1) the well section at the target layer has good well conditions, meets the production well opening requirement, and is positioned at a relatively higher part of the structure;
(2) the permeability of the reservoir is high, and the seepage of the reservoir is more than 200 mD;
(3) the stratum inclination angle is higher and is more than 5 degrees;
(4) the viscosity of the underground crude oil is smaller and is less than 20mPa & s.
In step 2, comprehensively determining key parameter values of the selected well zone influencing the secondary enrichment speed of the residual oil by integrating the seismic data, the rock core test data, the logging data, the well test data and the development dynamic data, wherein the key parameter values comprise well shut-in time, the water content before well shut-in, the viscosity of the underground crude oil, the density of the underground crude oil, the fault/shielding distance between the oil well and a high part, the stratum permeability and the stratum inclination angle.
In step 2, the relevant parameters should satisfy the following ranges:
(1) closing the well: 0.5-15 a;
(2) water content before shut-in: 95 to 99 percent;
(3) viscosity of underground crude oil: 1-50 mPa.s;
(4) density of underground crude oil: 0.7-0.95g/cm3；
(5) Fault/shielding distance of oil well from high part: 10-100 m;
(6) formation permeability: 50-2000 mD;
(7) formation dip angle: 5-25 degrees.
And 3, calculating the secondary enrichment speed of the residual oil to obtain the water content reduction value of the oil well after the well is opened.
In step 3, the formula for calculating the secondary enrichment speed of the residual oil is as follows:
wherein t is shut-in time, unit a, and range is 0.5-15;
the water content before shut-in is in the unit f and the range is 0.95-0.99; mu.soThe viscosity of underground crude oil is unit mPa.s and ranges from 1 to 50; rhooIs the density of underground crude oil in g/cm3In the range of 0.7-0.95; d is the fault distance between the oil well and the high part, and the unit m ranges from 10 to 100; k is the formation permeability, unit mD, in the range of 50-2000; alpha is the formation dip, unit deg., in the range of 5-25.
According to the method for rapidly predicting the secondary enrichment speed of the residual oil in the water-drive reservoir, a characteristic model is used for simulating the relation between a main control factor influencing the secondary enrichment speed of the residual oil and the water content reduction range, and after multiple regression analysis, a calculation formula of the water content reduction range of an oil well and the main control factor of the secondary enrichment of the residual oil is established. The method for quickly predicting the secondary enrichment speed of the residual oil in the water-drive reservoir solves the problems of large data quantity, long calculation time and difficulty in quick application of modeling and digital-analog simulation methods in the prior art, can quickly predict the change amplitude of the water content of the oil well after different reservoirs, different stages and oil well shut-in any time, and has the characteristics of quick application and simple and convenient calculation. The method provides technical support for the residual oil potential excavation and the recovery efficiency improvement in the later development stage of the water-drive oil reservoir, particularly for the development strategy, the periodic oil recovery strategy, the interlayer alternate mining period determination, the secondary development of the near-waste oil reservoir and the like of the oil reservoir in the ultra-high water-cut period, and has wide popularization and application prospect and remarkable economic and social benefits.
Drawings
FIG. 1 is a flowchart illustrating a method for rapidly predicting a secondary enrichment rate of remaining oil in a water-flooding reservoir according to an embodiment of the present invention;
FIG. 2 is a constructed well pattern in an embodiment of the present invention;
FIG. 3 is a graph of well production after application of the secondary enrichment technique for resid in an embodiment of the present invention.
Detailed Description
In order to make the aforementioned and other objects, features and advantages of the present invention comprehensible, preferred embodiments accompanied with figures are described in detail below.
As shown in fig. 1, fig. 1 is a flowchart of an embodiment of a method for rapidly predicting a secondary enrichment rate of remaining oil in a water-drive reservoir according to the present invention.
In step 101, according to the oil reservoir development characteristics, performing secondary enrichment technology of the remaining oil and applying well region screening, wherein the oil reservoir conditions of the selected well region should meet the following conditions:
(1) the well section at the target layer has good well conditions, meets the production well opening requirement, and is positioned at a relatively higher part of the structure;
(2) the permeability of the reservoir is high, and the seepage of the reservoir is more than 200 mD;
(3) the dip angle of the stratum is higher, and the dip angle of the stratum is more than 5 degrees and is better;
(4) the viscosity of the underground crude oil is smaller, and the viscosity of the underground crude oil is less than 20mPa & s.
In step 102, key parameter values of the selected well zone influencing the secondary enrichment speed of the residual oil are comprehensively determined by integrating seismic data, core test data, logging data, well testing data, development dynamic data and the like, wherein the key parameter values comprise well shut-in time, water content before well shut-in, viscosity of underground crude oil, density of underground crude oil, fault/shielding distance between an oil well and a high part, stratum permeability, stratum inclination angle and the like, and related parameters meet the following ranges:
(1) closing the well: 0.5-15 a;
(2) water content before shut-in: 95 to 99 percent;
(3) viscosity of underground crude oil: 1-50 mPa.s;
(4) density of underground crude oil: 0.7-0.95g/cm3；
(5) Fault/shielding distance of oil well from high part: 10-100 m;
(6) formation permeability: 50-2000 mD;
(7) formation dip angle: 5-25 degrees.
In step 103, calculating the secondary enrichment speed of the residual oil by using the formula (1) to obtain the water content reduction value after the oil well is opened,
wherein t is shut-in time, unit a, and range is 0.5-15;the water content before shut-in is in the unit f and the range is 0.95-0.99; mu.soThe viscosity of underground crude oil is unit mPa.s and ranges from 1 to 50; rhooIs the density of underground crude oil in g/cm3In the range of 0.7-0.95; d is the fault distance between the oil well and the high part, and the unit m ranges from 10 to 100; k is the formation permeability, unit mD, in the range of 50-2000; alpha is the formation dip, unit deg., in the range of 5-25.
Aiming at the difficulties of residual oil dispersion and low-efficiency development of the oil reservoir in the later period of ultra-high water content of the water-drive oil reservoir, a numerical simulation method is utilized to establish a quantitative prediction method for the secondary enrichment speed of the residual oil of the water-drive oil reservoir. The method establishes a quantitative calculation method for key factors influencing the secondary enrichment speed of the residual oil and the water content reduction value of the oil well, realizes the prediction of the secondary enrichment speed of the residual oil of the water-drive oil reservoir in different well-closing time, different well-closing water content, different underground crude oil viscosity, different underground crude oil density, different oil well positions, different stratum permeability, different stratum inclination angles and different extraction degrees, has the characteristics of rapidness, simplicity and high prediction precision, provides technical support for the aspects of low-efficiency water-drive oil reservoir development strategy in an ultrahigh water-containing stage, periodic oil extraction countermeasures, interlayer alternate extraction period, secondary development of near-waste oil reservoirs and the like, and has wide popularization and application prospects and remarkable economic and social benefits.
The following is a specific embodiment to which the present invention is applied.
Oil field 1 is a typical water-drive reservoir with an oil-bearing area of 0.96km2Geological reserve of 5.9X 104t, the dip angle of the stratum is 11 degrees, the average permeability is 1021mD, the viscosity of underground crude oil is 17.7mPa & s, and the density of the stratum crude oil is 0.85g/cm3. The once-producing oil well of the oil layer is shut down or changed into layer production, and the accumulative production degree of the small layer is 30%.
Fig. 2 is a well diagram of the formation of the target strata, for which a screening analysis was performed, wherein the 47-40 wells were in the higher formation and the well conditions were good. The well produces the target interval from 4 months to 6 months in 1992 and the final-stage daily fluid is 15m3(d), daily oil 0.5t/d, comprehensive water content 97%, oil 1.4X 104t。
The well related parameters are substituted into formula (1), wherein the production stop time is 12a, the comprehensive water content before the stop is 97%, the viscosity of underground crude oil is 17.7mPa & s, and the density of the underground crude oil is 0.85/cm3The distance between the oil well and the fault is 50m, the formation permeability is 1021mD, and the dip angle of the formation is 11 degrees.
Through calculation, the water content reduction range of the well after the well is opened is predicted to be 21.7% by a residual oil secondary enrichment speed formula, and the well can obtain obvious effects of water reduction and oil increase. After the target interval is recovered by the above-well measure, the initial daily oil is 5.7t/d, the comprehensive water content is 76%, and the effect is obvious. FIG. 3 is a development curve after the oil well is opened, the water containing degradation value of the oil well is 21% after the oil well is actually opened, the prediction result is compared with the actual result, the absolute error is 0.7%, the relative error is 3%, the precision is high, and the method can be used as a method for rapidly predicting the secondary enrichment speed of the residual oil and meets the precision requirement.
Claims (6)
1. The method for quickly predicting the secondary enrichment speed of the residual oil in the water-drive reservoir is characterized by comprising the following steps of:
step 1, performing secondary enrichment technology application well area screening of residual oil according to oil reservoir development characteristics;
step 2, comprehensively determining key parameter values of the selected well area influencing the secondary enrichment speed of the residual oil by synthesizing seismic data, core test data, logging data, well testing data and development dynamic data;
and 3, predicting the secondary enrichment speed of the residual oil.
2. The method for rapidly predicting the secondary enrichment speed of the remaining oil in the water-drive reservoir according to claim 1, wherein in the step 1, the reservoir conditions of the selected well region meet the following conditions:
(1) the well section at the target layer has good well conditions, meets the production well opening requirement, and is positioned at a relatively higher part of the structure;
(2) the permeability of the reservoir is high, and the seepage of the reservoir is more than 200 mD;
(3) the stratum inclination angle is higher and is more than 5 degrees;
(4) the viscosity of the underground crude oil is smaller and is less than 20mPa & s.
3. The method for rapidly predicting the secondary enrichment speed of the remaining oil in the water-drive reservoir according to claim 1, wherein in the step 2, key parameter values of the selected well region influencing the secondary enrichment speed of the remaining oil are comprehensively determined by integrating seismic data, core test data, logging data, well test data and development dynamic data, and the key parameter values comprise well shut-in time, water content before well shut-in, viscosity of underground crude oil, density of the underground crude oil, fault/shielding distance between an oil well and a high part, stratum permeability and stratum inclination angle.
4. The method for rapidly predicting the secondary enrichment speed of the residual oil of the water-drive reservoir according to claim 3, wherein in the step 2, the relevant parameters meet the following ranges:
(1) closing the well: 0.5-15 a;
(2) water content before shut-in: 95 to 99 percent;
(3) viscosity of underground crude oil: 1-50 mPa.s;
(4) density of underground crude oil: 0.7-0.95g/cm3；
(5) Fault/shielding distance of oil well from high part: 10-100 m;
(6) formation permeability: 50-2000 mD;
(7) formation dip angle: 5-25 degrees.
5. The method for rapidly predicting the secondary enrichment speed of the residual oil of the water-drive reservoir according to claim 1, wherein in the step 3, the secondary enrichment speed of the residual oil is calculated to obtain the water content reduction value of the oil well after the well is opened.
6. The method for rapidly predicting the secondary enrichment speed of the residual oil in the water-drive reservoir according to claim 5, wherein in the step 3, the formula for calculating the secondary enrichment speed of the residual oil is as follows:
wherein t is shut-in time, unit a, and range is 0.5-15;
the water content before shut-in is in the unit f and the range is 0.95-0.99; mu.soThe viscosity of underground crude oil is unit mPa.s and ranges from 1 to 50; rhooIs the density of underground crude oil in g/cm3In the range of 0.7-0.95; d is the fault distance between the oil well and the high part, and the unit m ranges from 10 to 100; k is the formation permeability, unit mD, in the range of 50-2000; alpha is the formation dip, unit deg., in the range of 5-25.
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Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN111287739A (en) * | 2020-03-12 | 2020-06-16 | 中国石油天然气集团有限公司 | Residual oil distribution prediction method based on formation crude oil viscosity |
| CN114086930A (en) * | 2020-08-07 | 2022-02-25 | 中国石油化工股份有限公司 | Method for accelerating reuse of residual oil in abandoned layer after accumulation by reinforced water injection |
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Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN111287739A (en) * | 2020-03-12 | 2020-06-16 | 中国石油天然气集团有限公司 | Residual oil distribution prediction method based on formation crude oil viscosity |
| CN111287739B (en) * | 2020-03-12 | 2023-05-26 | 中国石油天然气集团有限公司 | Residual oil distribution prediction method based on stratum crude oil viscosity |
| CN114086930A (en) * | 2020-08-07 | 2022-02-25 | 中国石油化工股份有限公司 | Method for accelerating reuse of residual oil in abandoned layer after accumulation by reinforced water injection |
| CN114086930B (en) * | 2020-08-07 | 2024-04-16 | 中国石油化工股份有限公司 | Method for accelerating reuse of waste layer residual oil after aggregation by reinforced water injection |
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