CN111236899A - Gas cap oil reservoir development seepage testing method - Google Patents

Gas cap oil reservoir development seepage testing method Download PDF

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CN111236899A
CN111236899A CN202010036531.1A CN202010036531A CN111236899A CN 111236899 A CN111236899 A CN 111236899A CN 202010036531 A CN202010036531 A CN 202010036531A CN 111236899 A CN111236899 A CN 111236899A
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oil
core
gas
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water
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郭平
李鑫
汪周华
胡义升
刘煌
王烁石
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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
    • E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q50/00—Systems or methods specially adapted for specific business sectors, e.g. utilities or tourism
    • G06Q50/02—Agriculture; Fishing; Mining

Abstract

The invention relates to a gas cap oil reservoir development seepage testing method, which comprises the following steps: preparing simulated oil and formation water, and adopting nitrogen in the experiment; obtaining the core length L, the cross-sectional area A, the volume V and the porosity
Figure DDA0002366215740000011
Measuring permeability K by gas, and performing a test mode of oil extraction first and gas production second, wherein the process comprises ① oil-driving water to establish irreducible water saturation, performing a gas-driving oil-phase permeability test, and making oil-phase and gas-phase relative permeability K of the corero、KrgWith gas saturation SgThe relationship curve of (1);② without taking out the core, performing oil-drive gas-phase permeability test to obtain the relative permeability K of gas phase and oil phaserg、KroAnd oil saturation So③ performing water flooding and residual gas phase permeation test without taking out the core, and making the relative permeability K of the oil phase and the water phase of the corero、KrwWith the water saturation SwThe relationship of (1). And a seepage test mode of gas production first and oil production second can also be adopted. The method can accurately evaluate the oil, gas and water three-phase flow condition and the seepage rule under the real reservoir conditions, and has wide market prospect.

Description

Gas cap oil reservoir development seepage testing method
Technical Field
The invention relates to a seepage test method of different developing formula oil, gas and water three phases of an oil-gas reservoir in an underground porous medium in the field of petroleum and natural gas exploration and development, and belongs to the technical field of improving recovery efficiency.
Background
Gas-cap reservoirs are a special and important type of reservoir. In recent years, China successively discovers a series of gas cap oil reservoirs which are quite rich in reserves. The gas cap oil reservoir mainly has three development modes, including oil production before gas production, gas production before gas production and oil and gas simultaneous production (Liuqian. gas cap edge water heavy oil reservoir development strategy research [ J ]. petrochemical technology, 2019,26(05): 86-87). Different development modes have corresponding displacement processes, for example, the oil extraction and gas production comprises three displacement processes of water displacement, gas displacement and water displacement plus residual gas. Gas-cap reservoirs have many problems in development due to their complexity. The dynamic change of oil-gas and oil-water interfaces is always required to be noticed in the development process of the gas-cap reservoir, once the change of the oil-gas and oil-water interfaces is out of control, the original oil-gas balance relation is broken, so that gas cone is formed nearby an oil well to generate gas channeling (lotus, research on the complex gas channeling problem of a condensate gas-cap reservoir [ J ]. special oil-gas reservoirs, 2013,20(4): 110-; or oil-cut gas cap (loyalty, correct selection of gas cap reservoir efficient development mode [ J ] oil exploration and development, 2003(02):70-72), loss of crude oil.
The gas-cap oil deposit is characterized in that oil, gas and water are distributed in a staggered mode, the driving types comprise gas-cap oil deposit, dissolved gas oil deposit, side water oil deposit and the like (Yuan, the characteristics of gas-cap oil deposit development and the outline of exploitation modes [ J ]. natural gas exploration and development, 2008(01):18-20+76), the movement of oil, gas and water is very complex, the energy of gas-cap and side bottom water is utilized to uniformly propel an oil-gas-oil-water interface, the flowing condition and seepage rule of oil, gas and water three phases under the stratum condition are correctly known, and water channeling and gas channeling are prevented from occurring prematurely between the stratum and the plane, so that the method is a core problem of development control and adjustment and is also a key for improving the recovery ratio of the oil deposit.
The current phase permeability test is mainly designed according to a displacement mode, mainly comprises water displacement, gas displacement water, water displacement gas and the like, does not take system consideration for the development process of the gas-cap oil reservoir, can reproduce the seepage rule in the development process by carrying out the phase permeability test according to different development modes and stages, and has important guiding significance for the development of the gas-cap oil reservoir. On the basis of a conventional phase permeability test, a matched phase permeability displacement flow is established according to a gas cap oil reservoir development mode and phase, so that the rule in the development process is reproduced.
Disclosure of Invention
The invention aims to provide a gas cap reservoir development seepage testing method which is reliable in principle, simple and applicable, can accurately evaluate the oil, gas and water three-phase flow condition and the seepage rule under the real reservoir condition and has wide market application prospect.
In order to achieve the technical purpose, the invention adopts the following technical scheme.
The gas cap oil reservoir development seepage testing method sequentially comprises the following steps:
(1) obtaining a separator oil sample and a separator gas sample under the current production condition of a certain gas cap oil reservoir, and obtaining the viscosity mu of the oil sample according to the industrial standard GB/M326981-2011' oil reservoir fluid physical property analysis methodoPreparing simulated oil according to the viscosity;
(2) obtaining the mineralization degree of the formation water according to the field formation water analysis report, preparing the formation water according to the mineralization degree, and obtaining the viscosity of the formation water with muwDensity, densityP, the experimental gas sample is nitrogen and has a viscosity of mug；
(3) Obtaining a plunger core meeting the experimental requirements, measuring to obtain the length L, the cross section area A and the volume V of the core, and placing the core into a helium porosity tester to measure the porosity of the core
Figure BDA0002366215720000021
(4) Cleaning and drying the rock core, and then putting the rock core into a gas permeability tester to test the gas permeability K of the rock core;
(5) the method comprises the following steps:
① washing and drying the core, injecting formation water into the core under formation conditions to saturate the formation water, placing the core into a core holder, injecting simulated oil into the core, and establishing the saturation S of the irreducible water by oil-driven waterwcRecord the volume V of oil injected at this timeoFlow q of oil at core inlet endoCore inlet pressure PIntoCore outlet pressure PGo outCalculating to obtain the effective permeability K of the oil phase in the state of bound watero(Swc)：
Figure BDA0002366215720000022
Testing gas flooding oil phase seepage:
injecting nitrogen into the core under the stratum condition for gas-drive oil-phase permeability test, and recording the flow q of gas at the inlet end of the core at the momentgFlow q of outlet oiloAnd volume V of oiloiCore inlet pressure PIntoCore outlet pressure PGo outThe effective permeability K of the gas phase is calculated by the following formulageEffective permeability of oil phase KoeAnd relative permeability to gas phase KrgRelative permeability of oil phase Kro：
Figure BDA0002366215720000023
Sg＝1-So
Figure BDA0002366215720000024
Figure BDA0002366215720000025
Figure BDA0002366215720000031
Figure BDA0002366215720000032
In the formula Pa-a value of atmospheric pressure (MPa);
So、Sg-oil saturation, gas saturation;
oil phase and gas phase relative permeability K of prepared corero、KrgWith gas saturation SgThe relationship curve of (1);
② oil flooding gas phase permeation test:
injecting the simulated oil into the core under the stratum condition without taking out the core to carry out the oil-drive gas-phase permeability test, and recording the volume V of the injected simulated oilojFlow q of oil at core inlet endoFlow q of outlet gasgLikewise, the effective permeability K of the gas phase is obtainedgeEffective permeability of oil phase KoeAnd relative permeability to gas phase KrgRelative permeability of oil phase KroAccording to the following formula
Figure BDA0002366215720000033
Making gas phase and oil phase relative permeability K of corerg、KroAnd oil saturation SoThe relationship curve of (1);
③ Water flooding + residual gas phase permeation test:
without taking out the core, injecting formation water into the core under the formation condition for water flooding and residual gas phaseAnd (5) performing seepage test, recording the flow q of water at the inlet end of the rock core at the momentwFlow q of oil at outlet end of rock coreoAnd volume V of oilomCore inlet pressure PIntoCore outlet pressure PGo outCalculating the water saturation Sw：
Figure BDA0002366215720000034
The effective permeability K of the oil phase is calculated by the following formulaoeEffective permeability of aqueous phase KweRelative permeability to oil phase KroRelative permeability of the aqueous phase Krw：
Figure BDA0002366215720000035
Figure BDA0002366215720000036
Figure BDA0002366215720000037
Figure BDA0002366215720000038
Relative permeability K of oil phase and water phase of prepared rock corero、KrwWith the water saturation SwThe relationship curve of (1);
(6) the seepage test mode of gas production first and oil production later comprises the following processes:
gas drive water establishment of irreducible water saturation Swc：
After the rock core is cleaned and dried, vacuumizing saturated formation water, putting the rock core of the saturated formation water into a rock core holder, injecting nitrogen into the rock core under the formation condition, and establishing the saturation S of the irreducible water by gas drive waterwc；
Oil-drive gas-phase permeation test:
simulated oil is injected into the core under formation conditions, and the volume of simulated oil injected at that time is recordedProduct VojFlow q of oil at core inlet endoFlow q of gas at outlet end of rock coregCore inlet pressure PIntoCore outlet pressure PGo outCalculating the effective permeability K of the gas phase according to the same method as ② in the step (5)geEffective permeability of oil phase KoeAnd relative permeability to gas phase KrgRelative permeability of oil phase KroMaking the relative permeability K of gas phase and oil phase of the corerg、KroAnd oil saturation SoThe relationship curve of (1);
testing water flooding and residual gas phase infiltration:
without taking out the core, injecting formation water into the core under the formation condition, and recording the flow q of water at the inlet end of the corewFlow q of outlet oiloAnd volume V of oilomCore inlet pressure PIntoCore outlet pressure PGo outCalculating the effective permeability K of the oil phase according to the same method as ③ in the step (5)oeEffective permeability of aqueous phase KweRelative permeability to oil phase KroRelative permeability of the aqueous phase KrwMaking relative permeability K of oil phase and water phase of rock corero、KrwWith the water saturation SwThe variation of (2).
Compared with the prior art, the invention has the following beneficial effects:
(1) carrying out the phase permeation test of multiphase continuous displacement at different stages according to the displacement mode of the gas cap oil reservoir until all experiments are finished, and having strong data continuity and good regularity;
(2) the original independent displacement process is changed into a continuous displacement process, so that the real displacement process under the formation condition is better reflected;
(3) the cost and the experimental time can be well saved in the continuous displacement process, and the calculation result accords with the actual situation.
Drawings
FIG. 1 shows relative permeability K of oil and gas in gas drivero、KrgWith gas saturation SgThe relationship of (1).
FIG. 2 shows the gas-oil two-phase opposition of oil-drivePermeability Krg、KroAnd oil saturation SoThe relationship of (1).
FIG. 3 shows relative permeability K of water-flooding oil, residual gas, oil and waterro、KrwWith the water saturation SwThe relationship of (1).
Detailed Description
The invention is further illustrated below with reference to the accompanying drawings.
The gas cap oil reservoir development seepage testing method comprises the following steps:
(1) obtaining a separator oil sample and a separator gas sample under the current production condition of a certain gas cap oil reservoir, and obtaining the viscosity mu of the oil sample according to the industrial standard GB/M326981-2011' oil reservoir fluid physical property analysis methodoA simulated oil sample was prepared at this viscosity of 0.16 mp.s.
(2) Obtaining the mineralization degree (26885mg/L) of the formation water according to the in-situ formation water analysis report, preparing the formation water according to the mineralization degree, and obtaining the viscosity of the formation water as muw0.67mp.s, density rho 1.016g/cm3The experimental gas sample adopts nitrogen and has the viscosity of mug＝0.01758mp.s。
(3) Obtaining a plunger core meeting the experimental requirements, and measuring to obtain a core length L of 5.0cm and a cross-sectional area A of 4.91cm2Volume V is 24.54cm3Measuring the porosity of the sample by a helium porosity measuring instrument
Figure BDA0002366215720000051
(4) And (3) cleaning and drying the rock core, and then putting the rock core into a gas permeability tester to measure that the gas permeability is 78.2 mD.
(5) The method comprises the following steps:
① washing and drying the core, injecting formation water into the core under formation conditions by an injection pump to saturate the formation water, injecting simulated oil into the core by the injection pump, and simulating oil-driven water to establish irreducible water saturation Swc33 percent; recording the volume V of injected simulated oiloFlow rate q of oil at core entranceoCore inlet pressure PIntoCore outlet pressure PGo outCalculating to obtain the effective permeability K of the oil phase in the state of bound watero(Swc)＝0.7895mD。
Injecting nitrogen into the rock core by using an injection pump under the stratum condition to perform a gas drive oil phase permeation experiment, and recording the flow q of inlet end gasgFlow q of outlet oiloAnd volume VoiCore inlet pressure PIntoCore outlet pressure PGo outCalculating to obtain the effective gas phase permeability KgeEffective permeability of oil phase and KoeAnd relative permeability to gas phase KrgRelative permeability of oil phase KroAnd a relation curve of the oil-gas two-phase relative permeability and the gas saturation is made according to the calculation result and is shown in figure 1.
② gas-drive oil-phase permeation experiment, injecting simulated oil into the core by using an injection pump under stratum condition on the basis of not taking out the core, and recording the volume V of the injected oilojFlow q of oil at core inlet endoFlow q of outlet gasg(ii) a Obtaining the effective permeability K of the gas phase by the same method (gas-in-gas oil displacement)geEffective permeability of oil phase KoeAnd relative permeability to gas phase KrgRelative permeability of oil phase KroAnd (3) making a relation curve of the relative permeability of the gas phase and the oil saturation according to the calculation result, and referring to fig. 2.
③ after oil-drive gas-phase permeation is finished, on the basis of not taking out the core, injecting formation water into the core by using an injection pump under the stratum condition to carry out the water-drive oil + residual gas-phase permeation experiment, and recording the flow q of the formation water at the inlet end of the corewFlow q of outlet oiloAnd volume V of oilomCore inlet pressure PIntoCore outlet pressure PGo outCalculating the water saturation SwEffective permeability of oil phase KoeEffective permeability of aqueous phase KweRelative permeability to oil phase KroRelative permeability of the aqueous phase KrwAnd (3) making a relation curve of relative permeability of the oil phase and the water phase and water saturation according to the calculation result, wherein the relation curve is shown in figure 3.
(6) And (5) performing a gas production-oil production seepage test mode process in step (5) without adding the description.

Claims (2)

1. The gas cap oil reservoir development seepage testing method sequentially comprises the following steps:
(1) obtaining the separator oil sample of a certain gas cap oil reservoir under the current production condition according to the viscosity mu of the oil sampleoPreparing simulation oil;
(2) preparing formation water to obtain the formation water with the viscosity of muwThe density is rho, the experimental gas sample adopts nitrogen, and the viscosity is mug；
(3) Obtaining a plunger core, and measuring to obtain the length L, the cross-sectional area A, the volume V and the porosity of the core
Figure FDA0002366215710000011
(4) Cleaning and drying the rock core, and then putting the rock core into a gas permeability tester to test the gas permeability K of the rock core;
(5) the method comprises the following steps:
① washing and drying the core, injecting formation water into the core under formation conditions to saturate the formation water, placing the core into a core holder, injecting simulated oil into the core, and establishing the saturation S of the irreducible water by oil-driven waterwcRecord the volume V of oil injected at this timeoFlow q of oil at core inlet endoCore inlet pressure PIntoCore outlet pressure PGo outCalculating to obtain the effective permeability K of the oil phase in the state of bound watero(Swc)：
Figure FDA0002366215710000012
Testing gas flooding oil phase seepage:
injecting nitrogen into the core under the stratum condition for gas-drive oil-phase permeability test, and recording the flow q of gas at the inlet end of the core at the momentgFlow q of outlet oiloAnd volume V of oiloiCore inlet pressure PIntoCore outlet pressure PGo outBy the formulaCalculating to obtain the effective permeability K of the gas phasegeEffective permeability of oil phase KoeAnd relative permeability to gas phase KrgRelative permeability of oil phase Kro：
Figure FDA0002366215710000013
Sg＝1-So
Figure FDA0002366215710000014
Figure FDA0002366215710000015
Figure FDA0002366215710000016
Figure FDA0002366215710000017
In the formula Pa-a value of atmospheric pressure (MPa);
So、Sg-oil saturation, gas saturation;
oil phase and gas phase relative permeability K of prepared corero、KrgWith gas saturation SgThe relationship curve of (1);
② oil flooding gas phase permeation test:
injecting the simulated oil into the core under the stratum condition without taking out the core to carry out the oil-drive gas-phase permeability test, and recording the volume V of the injected simulated oilojFlow q of oil at core inlet endoFlow q of outlet gasgLikewise, the effective permeability K of the gas phase is obtainedgeEffective permeability of oil phase KoeAnd relative permeability to gas phase KrgRelative permeability of oil phase KroAccording to the following formula
Figure FDA0002366215710000021
Making gas phase and oil phase relative permeability K of corerg、KroAnd oil saturation SoThe relationship curve of (1);
③ Water flooding + residual gas phase permeation test:
without taking out the core, injecting formation water into the core under the formation condition to carry out water flooding and residual gas phase permeation test, and recording the flow q of water at the inlet end of the core at the momentwFlow q of oil at outlet end of rock coreoAnd volume V of oilomCore inlet pressure PIntoCore outlet pressure PGo outCalculating the water saturation Sw：
Figure FDA0002366215710000022
The effective permeability K of the oil phase is calculated by the following formulaoeEffective permeability of aqueous phase KweRelative permeability to oil phase KroRelative permeability of the aqueous phase Krw：
Figure FDA0002366215710000023
Figure FDA0002366215710000024
Figure FDA0002366215710000025
Figure FDA0002366215710000026
Relative permeability K of oil phase and water phase of prepared rock corero、KrwWith the water saturation SwThe relationship of (1).
2. The gas cap reservoir development seepage test method of claim 1, wherein a gas production before oil production seepage test mode can be adopted, and the process is as follows:
gas drive water establishment of irreducible water saturation Swc：
After the rock core is cleaned and dried, vacuumizing saturated formation water, putting the rock core of the saturated formation water into a rock core holder, injecting nitrogen into the rock core under the formation condition, and establishing the saturation S of the irreducible water by gas drive waterwc；
Oil-drive gas-phase permeation test:
simulated oil is injected into the core under formation conditions, and the volume V of simulated oil injected at that time is recordedojFlow q of oil at core inlet endoFlow q of gas at outlet end of rock coregCore inlet pressure PIntoCore outlet pressure PGo outCalculating to obtain the effective gas phase permeability KgeEffective permeability of oil phase KoeAnd relative permeability to gas phase KrgRelative permeability of oil phase KroMaking the relative permeability K of gas phase and oil phase of the corerg、KroAnd oil saturation SoThe relationship curve of (1);
testing water flooding and residual gas phase infiltration:
without taking out the core, injecting formation water into the core under the formation condition, and recording the flow q of water at the inlet end of the corewFlow q of outlet oiloAnd volume V of oilomCore inlet pressure PIntoCore outlet pressure PGo outCalculating to obtain the effective permeability K of the oil phaseoeEffective permeability of aqueous phase KweRelative permeability to oil phase KroRelative permeability of the aqueous phase KrwMaking relative permeability K of oil phase and water phase of rock corero、KrwWith the water saturation SwThe variation of (2).
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Application publication date: 20200605