CN108756857B - Method for predicting top gas distribution in oil sand reservoir formation period - Google Patents
Method for predicting top gas distribution in oil sand reservoir formation period Download PDFInfo
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- CN108756857B CN108756857B CN201810478514.6A CN201810478514A CN108756857B CN 108756857 B CN108756857 B CN 108756857B CN 201810478514 A CN201810478514 A CN 201810478514A CN 108756857 B CN108756857 B CN 108756857B
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- 239000003027 oil sand Substances 0.000 title claims abstract description 22
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 20
- 238000000034 method Methods 0.000 title claims abstract description 19
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 87
- 238000012937 correction Methods 0.000 claims abstract description 12
- 238000010586 diagram Methods 0.000 claims abstract description 8
- 238000010276 construction Methods 0.000 claims abstract description 3
- 238000009825 accumulation Methods 0.000 claims description 10
- 239000012530 fluid Substances 0.000 claims description 5
- 238000013517 stratification Methods 0.000 claims description 3
- 239000007789 gas Substances 0.000 description 32
- 239000003921 oil Substances 0.000 description 12
- 238000011161 development Methods 0.000 description 5
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 230000008569 process Effects 0.000 description 3
- 239000003345 natural gas Substances 0.000 description 2
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 239000010426 asphalt Substances 0.000 description 1
- 238000006065 biodegradation reaction Methods 0.000 description 1
- 239000004927 clay Substances 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- 230000009466 transformation Effects 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/04—Measuring depth or liquid level
- E21B47/047—Liquid level
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics (AREA)
- Geophysics And Detection Of Objects (AREA)
Abstract
The invention relates to a method for predicting the top gas distribution in an oil sand reservoir formation period, which comprises the following steps: 1) identifying and recording the oil-water interface depth value of each single well; 2) reading and recording the bottom surface depth values of single well top gas and top water; 3) selecting a well with the shallowest depth of an oil-water interface as a reference well; 4) subtracting the oil-water interface depth values of the other wells and the reference well to obtain the oil-water interface correction value of each well; 5) reading and recording the top surface depth value of each single well target layer from the single well; 6) subtracting the results obtained in the steps 5) and 4), and approximately recovering the top surface depth of the single well target layer to the depth of the reservoir forming period; 7) subtracting the results obtained in the steps 2) and 4) to obtain the corrected bottom surface depth values of single well top gas and top water; 8) performing plane interpolation by using the result obtained in the step 6), and drawing a recovered top surface construction diagram; 9) and 7) determining a gas-oil interface of the reservoir formation period by utilizing the results obtained in the steps 7) and 8), and obtaining the distribution range of the top gas in the reservoir formation period.
Description
Technical Field
The invention relates to a prediction method, in particular to a method for predicting the top gas distribution of an oil sand reservoir during the reservoir formation period.
Background
Oil sand is a sticky mixture consisting of sand, water, asphalt and clay, has the characteristics of high viscosity, high density and high carbon-hydrogen ratio, and is one of important unconventional resources. Aiming at the characteristics of oil sand, a steam assisted gravity drainage method is often adopted for mining, and the existence of gas and water in a reservoir stratum can absorb steam, so that the reservoir stratum cannot be efficiently heated by the steam.
The headspace and the headspace water in the oil sand reservoir formation period refer to: in the light oil accumulation period, natural gas is generated due to the biodegradation of the light oil, and the natural gas is enriched at the top of a reservoir under the action of buoyancy. The headspace gas is partially retained in the later-stage reservoir formation transformation process and partially lost to form a high water-bearing layer (headspace water) at the top of the reservoir, namely the distribution range of the headspace gas in the reservoir formation period is the same as that of the headspace gas plus the headspace water in the current structural form. At the present stage, geologists can only predict the top gas distribution range under the current structural state by means of well logging, 3-dimensional earthquake and the like, and cannot realize the spatial distribution prediction of top water, so that the high-efficiency development of oil sand is influenced.
Disclosure of Invention
In view of the above problems, the present invention provides a method for predicting the top gas distribution during the oil sand deposit period, which is operable and standardized.
In order to achieve the purpose, the invention adopts the following technical scheme: a method for predicting the top gas distribution in the oil sand accumulation period is characterized by comprising the following steps: 1) identifying and recording the oil-water interface depth value of each single well; 2) reading and recording the bottom surface depth values of single well top gas and top water; 3) selecting a well with the shallowest oil-water interface depth as a reference well, and approximately considering the oil-water interface depth of the reference well as the oil-water interface depth of the oil-water interface depth in the oil-water interface period; 4) subtracting the oil-water interface depth values of the other wells from the oil-water interface depth value of the reference well, so that each well obtains an oil-water interface correction value; 5) reading and recording the top surface depth value of each single well target layer from the single well; 6) subtracting the oil-water interface correction value obtained in the step 4) from the single-well target layer top surface depth value obtained in the step 5), so that the single-well target layer top surface depth is approximately recovered to the depth of the accumulation period; 7) subtracting the bottom depth values of the single well top gas and the top water recorded in the step 2) from the oil-water interface correction value obtained in the step 4) respectively to obtain the corrected bottom depth values of the single well top gas and the top water; 8) performing plane interpolation by using the recovered single well target layer top surface depth value obtained in the step 6), and drawing a recovered top surface construction drawing; 9) determining a gas-oil interface of the reservoir formation period by using the corrected bottom surface depth values of the single well top gas and the top water obtained in the step 7) and the top surface structural diagram obtained in the step 8), thereby obtaining the distribution range of the top gas in the reservoir formation period.
In the step 1), the core well determines the oil-water interface depth value through the core picture, the non-core well determines the oil-water interface depth value through well logging fluid interpretation, and the oil-water saturation is adopted as the recognition boundary of oil and water.
In the step 2), if the single well only develops the top gas, reading and recording the depth value of the bottom surface of the top gas of the single well; if the single well is developing the head gas and the head water, or only developing the head water, only the depth value of the bottom surface of the head water needs to be recorded.
In the step 5), the top surface depth value of the target layer of each single well is read and recorded based on geological knowledge and geological stratification results.
Due to the adoption of the technical scheme, the invention has the following advantages: 1. the invention utilizes the existing well drilling, rock core and fluid explanation results to recover the ancient structural characteristics of the oil sand light oil during the light oil accumulation period on the basis of the theory that the oil sand light oil should have a uniform oil-water interface during the accumulation period. 2. The method can quickly and accurately determine the distribution range of the top gas in the reservoir formation period by utilizing the fluid interpretation and the ancient structural characteristics, the range is consistent with the distribution range of the top gas and the top water in the oil reservoir at present, the result is reliable, the implementation process is quick, and the method has important guiding significance for the high-efficiency development of the oil sand. 3. The method can be widely used for top gas and top water prediction of the heavy oil reservoir with similar reservoir formation process and well pattern characteristics.
Drawings
FIG. 1 is an oil-water interface recognition diagram of an oil sand reservoir core according to the invention;
FIG. 2 is a diagram of a reservoir model for an oil sand reservoir of the present invention;
FIG. 3 is a chart of oil-water interface statistics and reference well depth selection in accordance with the present invention;
FIG. 4 is a plot of the correction for all wells of the present invention versus the oil-water interface of the reference well;
FIG. 5 is a top view of the restored ancient structure of the invention.
Detailed Description
The present invention will be described in detail with reference to examples.
The invention provides a method for predicting the top gas distribution in an oil sand reservoir formation period, which comprises the following steps:
1) and identifying and recording the oil-water interface depth value of each single well.
As shown in fig. 1, the oil-water interface characteristics in the oil sand reservoir are clear, the oil-water interface characteristics can be easily identified through core observation, the oil-containing sandstone core is black, and the oil-free sandstone core is grey white. In this embodiment, the core well may determine the depth value of the oil-water interface through the core photograph, the non-core well may determine the depth value of the oil-water interface through interpretation by logging fluid, and the recognition limit of oil and water is 50% of oil saturation.
2) And reading and recording the bottom surface depth values of single well head gas and head water.
As shown in fig. 2, there are 3 cases of the development states of the head water and the head gas in the oil sand reservoir, namely the development of only the head gas or the head water, and the simultaneous development of the head gas and the head water in a single well. In this embodiment, if a single well is developing only the top gas, the single well top gas bottom depth value is read and recorded; if the single well is developing the head gas and the head water, or only developing the head water, only the depth value of the bottom surface of the head water needs to be recorded.
3) As shown in fig. 3, one well with the shallowest oil-water interface depth is selected as a reference well, and the oil-water interface depth of the reference well is considered to be the oil-water interface depth of the reservoir formation period approximately.
4) Subtracting the oil-water interface depth values of the other wells from the oil-water interface depth values of the reference well, so that each well can obtain an oil-water interface correction value, and the oil-water interface correction value plane distribution diagram of each well is shown in fig. 4.
5) And reading and recording the top surface depth value of each single-well destination layer from the single well.
In this embodiment, the depth value of the top surface of the destination layer of each individual well is read and recorded based on geological knowledge and geological stratification results.
6) And (4) subtracting the oil-water interface correction value obtained in the step (4) from the single-well target layer top surface depth value obtained in the step (5), so that the single-well target layer top surface depth can be approximately restored to the depth of the accumulation period.
7) Subtracting the bottom depth values of the single well top gas and the top water recorded in the step 2) from the oil-water interface correction value obtained in the step 4) respectively to obtain the corrected bottom depth values of the single well top gas and the top water.
8) And (4) performing plane interpolation by using the recovered top surface depth value of the single well target layer obtained in the step 6), and drawing a recovered top surface structural diagram (as shown in fig. 5).
9) Determining a gas-oil interface of the reservoir formation period by using the corrected bottom surface depth values of the single well top gas and the top water obtained in the step 7) and the top surface structural diagram obtained in the step 8), thereby obtaining the distribution range of the top gas in the reservoir formation period.
The above embodiments are only for illustrative purposes and are not limited to the above embodiments, and any modifications, equivalent substitutions, improvements and the like within the spirit and principle of the present invention should be included in the protection scope of the present invention.
Claims (4)
1. A method for predicting the top gas distribution in the oil sand accumulation period is characterized by comprising the following steps:
1) identifying and recording the oil-water interface depth value of each single well;
2) reading and recording the bottom surface depth values of single well top gas and top water;
3) selecting a well with the shallowest oil-water interface depth as a reference well, and approximately considering the oil-water interface depth of the reference well as the oil-water interface depth of the oil-water interface depth in the oil-water interface period;
4) subtracting the oil-water interface depth values of the other wells from the oil-water interface depth value of the reference well, so that each well obtains an oil-water interface correction value;
5) reading and recording the top surface depth value of each single well target layer from the single well;
6) subtracting the oil-water interface correction value obtained in the step 4) from the single-well target layer top surface depth value obtained in the step 5), so that the single-well target layer top surface depth is approximately recovered to the depth of the accumulation period;
7) subtracting the bottom depth values of the single well top gas and the top water recorded in the step 2) from the oil-water interface correction value obtained in the step 4) respectively to obtain the corrected bottom depth values of the single well top gas and the top water;
8) performing plane interpolation by using the recovered single well target layer top surface depth value obtained in the step 6), and drawing a recovered top surface construction drawing;
9) determining a gas-oil interface of the reservoir formation period by using the corrected bottom surface depth values of the single well top gas and the top water obtained in the step 7) and the top surface structural diagram obtained in the step 8), thereby obtaining the distribution range of the top gas in the reservoir formation period.
2. The method for predicting the top gas distribution in the oil sand reservoir formation period as claimed in claim 1), wherein in the step 1), the core well determines the oil-water interface depth value through a core photo, the non-core well determines the oil-water interface depth value through well logging fluid interpretation, and the oil-water recognition limit adopts 50% of oil saturation.
3. The method for predicting the top gas distribution during the oil sand accumulation period according to claim 1, wherein in the step 2), if only single well develops the top gas, the bottom depth value of the single well top gas is read and recorded; if the single well is developing the head gas and the head water, or only developing the head water, only the depth value of the bottom surface of the head water needs to be recorded.
4. The method for predicting the top gas distribution in the oil sand accumulation period according to claim 1, wherein in the step 5), the depth value of the top surface of the target layer of each single well is read and recorded based on geological knowledge and geological stratification results.
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| CN102071037A (en) * | 2011-01-04 | 2011-05-25 | 何巨堂 | Dehydration method of low-grade oil |
| CN102994146A (en) * | 2011-09-19 | 2013-03-27 | 中国石油化工集团公司 | System and method for improving liquid yield of reforming device |
| CN104252551B (en) * | 2013-06-28 | 2017-05-03 | 中国石油化工股份有限公司 | Irregular oil-water interface modeling implementation method |
| CN105093348B (en) * | 2014-04-25 | 2017-08-04 | 中国石油化工股份有限公司 | A kind of multilayer petroleum resources amount Forecasting Methodology |
| CN105221144B (en) * | 2015-09-21 | 2018-04-06 | 中国石油天然气股份有限公司 | Determine the method and device of reservoir reserve |
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