CN110469300B - Method for calculating water-drive recovery ratio of fracture-cave carbonate reservoir - Google Patents

Method for calculating water-drive recovery ratio of fracture-cave carbonate reservoir Download PDF

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CN110469300B
CN110469300B CN201910828176.9A CN201910828176A CN110469300B CN 110469300 B CN110469300 B CN 110469300B CN 201910828176 A CN201910828176 A CN 201910828176A CN 110469300 B CN110469300 B CN 110469300B
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injection
water injection
value
reservoir
water
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李小波
谭涛
李青
张艺晓
刘洪光
吴姗姗
唐海
吕栋梁
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Southwest Petroleum University
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E21B43/20—Displacing by water
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
    • G06F17/10—Complex mathematical operations
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
    • Y02A10/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE at coastal zones; at river basins
    • Y02A10/40—Controlling or monitoring, e.g. of flood or hurricane; Forecasting, e.g. risk assessment or mapping

Abstract

The invention provides a water-drive recovery ratio calculation method for a fracture-cavity carbonate reservoir, and belongs to the technical field of oil field development. The invention overcomes the defects in the prior art, and provides a fracture-cavity carbonate reservoir water drive recovery ratio calculation method obtained by statistics of the indoor multi-factor water drive physical simulation experiment results of a fracture-cavity reservoir, which comprises the following steps: judging the type of a target oil reservoir and collecting actual parameters of the target oil reservoir; converting the collected target oil reservoir actual parameters into formula independent variables according to parameter quantization rules; and finally, assigning the formula independent variable in the formula according to an assignment rule, thereby calculating and obtaining the water drive recovery ratio of the oil deposit in the laboratory. The method quantifies the factors influencing the calculation result of the recovery ratio, simplifies the calculation parameters of the recovery ratio, has real and reliable calculation result, and has scientific guiding significance for the production of mines.

Description

Method for calculating water-drive recovery ratio of fracture-cave carbonate reservoir
Technical Field
The invention relates to a water-drive recovery ratio calculation method for a fracture-cavity carbonate reservoir, and belongs to the technical field of oil field development.
Background
Carbonate oil reserves account for a large proportion (about 60%) of the world's proven reserves, but at present, carbonate oil reserves are poorly understood. The fracture-cavity type oil reservoir development and the enhanced oil recovery research have great difficulties, theoretical research has a large amount of blanks, the research on the fracture-cavity type oil reservoir reserves evaluation and development is less, and the method which can be used for the oil recovery calculation is less.
Disclosure of Invention
The invention overcomes the defects in the prior art and provides a fracture-cavity carbonate reservoir water-drive recovery ratio calculation method obtained by means of statistics of the indoor multi-factor water-drive physical simulation experiment results of the fracture-cavity reservoir.
The technical scheme provided by the invention for solving the technical problems is as follows: a water drive recovery ratio calculation method for a fracture-cavity carbonate reservoir comprises the following steps:
step S10, judging the type of the target oil reservoir and collecting the actual parameters of the target oil reservoir;
step S20, converting the collected target oil deposit actual parameters into formula independent variables according to parameter quantization rules;
and S30, finally, assigning the formula independent variable in the formula according to an assignment rule, thereby calculating and obtaining the water drive recovery ratio of the laboratory oil deposit:
Y＝35.071+7.318x1-15.183x2+3.766x4-11.792x5-7.851x6
+4.686x7+7.151x8+2.615x9-0.405x10+6.28x11
in the formula: y is recovery ratio; x1The expression symbol is an expression symbol of a monomer big karst cave reservoir; x2The expression symbol is the expression symbol of a fractured-vuggy reservoir; x3Is the number of modules; x4Expression symbols for low-note high-pick; x5Expression symbols for high injection and low extraction; x6The number of water injection wells; x7Expression symbols for symmetric water injection; x8Expression symbols for short note long stop; x9Expression symbols for long note short stop; x10The water injection speed is adopted; x11Is the total water injection.
The further technical scheme is that the target oil reservoir in the step S10 is judged to be a monomer big karst cave reservoir, a crack-karst cave reservoir or a crack-hole reservoir.
The further technical scheme is that the actual parameters comprise local communication scale, injection and production well position arrangement, water injection well number, water injection speed, water injection mode and total water injection quantity.
The further technical proposal is that the local communication scale comprises small, medium and large; the injection and production well position deployment comprises low-injection high-production, high-injection low-production and equal-height injection and production; the water injection mode comprises symmetrical water injection, short injection and long stop and long injection and short stop, and the water injection speed comprises low-speed water injection, mild water injection and high-speed water injection.
Further technical solution is that, the specific parameter quantization rule in step S20 is: number of modules X when local connectivity scale is small3Is 1; number of modules X in medium size3Is 2; number of modules X in large scale3Is 3;
when the water injection speed is low speed water injection, the water injection speed is X10The value is 5; when water is injected mildly, the water injection speed X10The value is 10; when water is injected at high speed, the water injection speed X10A value of 20;
when the total injection amount is 0-10 ten thousand tons, the total injection amount X11The value is 1; 10-20 ten thousand tons of water, and the total water injection quantity X11The value is 2; 20-30 ten thousand tons of water, and the total water injection quantity X11The value is 3; when the total water injection quantity is more than 30 ten thousand tons, the total water injection quantity is X11The value is 4.
The further technical solution is that the assignment rule in step S30 is: when the reservoir type is a monomer big cavern type reservoir, X1Has a value of 1, X2Is 0; in fractured-cavernous reservoir type, X1Has a value of 0, X2Is 1; in fractured-vuggy reservoir type, X1Has a value of 0, X2Is 0;
when the injection-production well is deployed to be low-injection high-production, X4Has a value of 1, X5Is 0; high injection and low production, X4Has a value of 0, X5Is 1; when injection and production are performed at equal height, X4Has a value of 0, X5Is 0;
when the injection-production mode is symmetrical water injection, X7Has a value of 1, X8Has a value of 0, X9Is 0; short injection and long stop time, X7Has a value of 0, X8Has a value of 1, X9Is 0; long injection and short stop time, X7Has a value of 0, X8Has a value of 0, X9Is 1.
The invention has the beneficial effects that: the invention overcomes the defects in the prior art and provides a recovery ratio calculation formula obtained by means of statistics of the experimental results of the multi-factor water-drive physical simulation in a fracture-cavity type oil reservoir chamber. By utilizing the water-flooding physical model experiment which follows similar criteria and can relatively truly and accurately reflect the actual development and exploitation conditions of the mine field according to the experimental results, the production parameters of the mine field are equivalently converted into variable parameters required by a formula, so that the water-flooding recovery ratio of the fracture-cavity type oil reservoir is calculated, the formula quantifies the factors influencing the recovery ratio calculation result, the recovery ratio calculation parameters are simplified, the calculation result is true and reliable, and the water-flooding physical model experiment has scientific guiding significance on the production of the mine field.
Detailed Description
The present invention will be further described with reference to the following examples.
The invention discloses a water drive recovery ratio calculation method for a fracture-cavity carbonate reservoir, which comprises the following steps of:
step S10, judging the type of the target oil reservoir and collecting the actual parameters of the target oil reservoir; the actual parameters comprise local communication scale, injection and production well position arrangement, water injection well number, water injection speed, water injection mode and total water injection quantity;
step S20, converting the collected target oil deposit actual parameters into formula independent variables according to parameter quantization rules;
and S30, finally, assigning the formula independent variable in the formula according to an assignment rule, thereby calculating and obtaining the water drive recovery ratio of the laboratory oil deposit:
Y＝35.071+7.318x1-15.183x2+3.766x4-11.792x5-7.851x6
+4.686x7+7.151x8+2.615x9-0.405x10+6.28x11
in the formula: y is recovery ratio; x1The expression symbol is an expression symbol of a monomer big karst cave reservoir; x2The expression symbol is the expression symbol of a fractured-vuggy reservoir; x3Is the number of modules; x4Expression symbols for low-note high-pick; x5Expression symbols for high injection and low extraction; x6The number of water injection wells; x7Expression symbols for symmetric water injection; x8Expression symbols for short note long stop; x9Expression symbols for long note short stop; x10The water injection speed is adopted; x11Is the total water injection.
The local communication scale, the water injection speed and the total water injection quantity in the formula are converted into formula quantization parameters according to the quantization rules in the table 1; the reservoir type, the injection-production well position deployment and the injection-production mode are quantified through the independent variable assignment rule in the table 2.
Independent variable X as a whole1～X11The actually involved parameter is assigned a value of 1 and the non-involved parameter is assigned a value of 0. Substituting the formula into the formula to obtain the theoretical calibration value of the water drive recovery ratio of the fracture-cavity oil reservoir under the corresponding condition.
TABLE 1 actual parameter quantization rules
Figure GDA0002208771050000041
TABLE 2 argument assignment rule
Figure GDA0002208771050000051
Example one
Practical field development example:
taking the development of TK663-TK646 injection-production well pairs in the TK663 well group of the S80 unit as an example, the actual oil field development injection-production data is as follows:
TABLE 1 TK663-TK646 actual injection-production system
Figure GDA0002208771050000052
Experimental data transformation
The above actual development example parameters were converted to the following experimental conditions:
TABLE 2 TK663-TK646 Experimental parameters
Figure GDA0002208771050000061
Algebraic calculation
Y＝35.071+7.318x1-15.183x2+3.766x4-11.792x5-7.851x6
+4.686x7+7.151x8+2.615x9-0.405x10+6.28x11
According to the experimental conditions of the conversion, the values of the parameters of the formula in this example are respectively as follows:
X1＝0X2＝0X3＝2X4＝1X5＝0X6＝1X7＝1X8＝0X9＝0X10＝10X11＝1
the recovery factor calculated by the formula is 33.216 percent
The actual recovery ratio is 28.87%
The deviation was 4.346%.
Although the present invention has been described with reference to the above embodiments, it should be understood that the present invention is not limited to the above embodiments, and those skilled in the art can make various changes and modifications without departing from the scope of the present invention.

Claims (1)

1. A fracture-cavity carbonate reservoir water flooding recovery calculation method is characterized by comprising the following steps:
step S10, judging the type of the target oil reservoir and collecting the actual parameters of the target oil reservoir;
the target oil reservoir in the step S10 is judged to be a monomer big karst cave reservoir, a crack-karst cave reservoir or a crack-cave reservoir;
the actual parameters comprise local communication scale, injection and production well position arrangement, water injection well number, water injection speed, water injection mode and total water injection quantity;
the local communication scale comprises small, medium and large; the injection and production well position deployment comprises low-injection high-production, high-injection low-production and equal-height injection and production; the water injection mode comprises symmetrical water injection, short injection and long stop and long injection and short stop, and the water injection speed comprises low-speed water injection, mild water injection and high-speed water injection;
step S20, converting the collected target oil deposit actual parameters into formula independent variables according to parameter quantization rules;
and S30, finally, assigning the formula independent variable in the formula according to an assignment rule, thereby calculating and obtaining the water drive recovery ratio of the laboratory oil deposit:
Y＝35.071+7.318x1-15.183x2-0.274x3+37.66x4-11.792x5-7.851x6+4.686x7+7.151x8+2.615x9-0.405x10+6.28x11
in the formula: y is recovery ratio; x is the number of1The expression symbol is an expression symbol of a monomer big karst cave reservoir; x is the number of2The expression symbol is the expression symbol when the reservoir is a fracture-karst cave reservoir; x is the number of3Is the number of modules; x is the number of4Expression symbols for low-note high-pick; x is the number of5Expression symbols for high injection and low extraction; x is the number of6The number of water injection wells; x is the number of7Expression symbols for symmetric water injection; x is the number of8Expression symbols for short note long stop; x is the number of9Expression symbols for long note short stop; x is the number of10The water injection speed is adopted; x is the number of11The total water injection amount is calculated;
the specific parameter quantization rule in step S20 is: number of modules x when local connectivity scale is small3Is 1; number of modules x in the case of medium size3Is 2; large scale, module number x3Is 3;
when the water injection speed is low speed water injection, the water injection speed x10The value is 5; at the time of mild water injection, the water injection speed x10The value is 10; when water is injected at high speed, the water injection speed x10A value of 20;
when the total injection amount is 0-10 ten thousand tons, the total injection amount x11The value is 1; 10-20 ten thousand tons of water, and the total water injection quantity x11The value is 2; 20-30 ten thousand tons of water, and the total water injection quantity x11The value is 3; when the total water injection quantity is more than 30 ten thousand tons, the total water injection quantity is x11A value of 4;
the assignment rule in step S30 is: when the reservoir type is a monomer big cavern type reservoir, x1Has a value of 1, x2Is 0; in fracture-karst cave type reservoir, x1Has a value of 0, x2Is 1; in a fracture-pore type reservoir, x1Has a value of 0, x2Is 0;
when the injection-production well is deployed to be low-injection high-production, x4Has a value of 1, x5Is 0; high injection and low production, x4Has a value of 0, x5Is 1; when injection and production are performed at equal height, x4Has a value of 0, x5Is 0;
when the injection-production mode is symmetrical water injection, x7Has a value of 1, x8Has a value of 0, x9Is 0; short injection and long stop time, x7Has a value of 0, x8Has a value of 1, x9Is 0; long injection and short stop time, x7Has a value of 0, x8Has a value of 0, x9Is 1.
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