CN105547961A - Method for determining retrograde condensation oil saturability in depletion development sandstone condensate gas reservoir reservoir - Google Patents

Method for determining retrograde condensation oil saturability in depletion development sandstone condensate gas reservoir reservoir Download PDF

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CN105547961A
CN105547961A CN201610006465.7A CN201610006465A CN105547961A CN 105547961 A CN105547961 A CN 105547961A CN 201610006465 A CN201610006465 A CN 201610006465A CN 105547961 A CN105547961 A CN 105547961A
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rock core
core
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CN105547961B (en
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汪周华
涂汉敏
郭平
袁昭
杜建芬
周小杰
刘旭
朱世立
秦松海
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Southwest Petroleum University
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Abstract

The invention discloses a method for determining retrograde condensation oil saturability in a depletion development sandstone condensate gas reservoir reservoir. The method comprises the following steps: 1, obtaining a core of the actual reservoir, and cleaning and drying the core; 2, testing the gas phase effective permeability Kegi under different oil saturation Soi conditions, and determining the values of the parameter a and the pameter b in the formula Soi=aln (kegi) +b; 3, preparing formation fluid samples; 4, restoring the core to the original reservoir state; 5, lowering the pore pressure in the core, and recording the core inlet end pressure, the outlet end pressure and the core outlet end output air volume; 6, calculating the gas phase effective permeability Kfegi under the mean pressure condition in the core depletion process; 7, calculating the retrograde condensation oil saturability Soi in the sandstone condensate gas reservoir under different pressure conditions. The method is reliable in principle, simple and applicable, influence of porous media, water saturation and condensate oil flowing is taken into consideration comprehensively, and wide market prospect is achieved.

Description

Retrograde gas condensate saturation degree defining method in exhaustion formula exploitation sandstone gas condensate reservoir reservoir
Technical field
The present invention relates to retrograde gas condensate saturation degree defining method in petroleum natural gas exploration field exhaustion formula exploitation sandstone gas condensate reservoir reservoir.
Background technology
Gas condensate reservoir refers to that the hydro carbons assembled underground is under the temperature and pressure of reservoir, heavy component gasoline fraction is that homogeneous steam condition is dispersed in rock gas to kerosene distillate and a small amount of macromolecule hydro carbons, when reservoir pressure is lower than its dew-point pressure, in system, heavy constituent (white oil) is separated out, composing with liquid form is stored in hole, reduces vapor phase stream kinetic force.Therefore, determine retrograde gas condensate saturation degree under different pressures condition, on quantitative evaluation white oil loss and significant on the impact of vapor phase stream kinetic force.Current high temperature and pressure experiment is the main method determining gas condensate reservoir retrograde gas condensate saturation degree: a kind of constant volume depletion experiment (SY/T5542-2000) determined for gas condensate reservoir retrograde gas condensate saturation degree being industry standard and specifying, another adopts the core experiment method of testing by means of modern physics measuring technology.But do not consider the impact that porous medium, water saturation and white oil flow due to the experiment of conventional constant volume depletion, differ greatly in the retrograde gas condensate saturation degree determined and porous medium (Wang Zhouhua. LOW PERMEABILITY POROUS MEDIA affects containing condensation oil type Phase Behavior of Gas Condensate height, drilling technique, 2009,32 (3), 56-59); In addition, utilize the modern physics measuring technologies such as ultrasound wave directly to test porous medium retrograde gas condensate saturation degree, experiment test is complicated, difficulty large (Guo Ping, the application of ultrasound wave in the test of white oil critically connected graph, gas industry, 2001,21 (3): 22-25).
Summary of the invention
The object of the invention is to based on conventional core depletion experiments and phase percolation curve method of testing, set up a kind of defining method determining retrograde gas condensate saturation degree in exhaustion formula exploitation sandstone gas condensate reservoir reservoir core under actual reservoir condition, the method principle is reliable, simple applicable, consider the impact of porous medium, water saturation and white oil flowing, there are wide market outlook.
For reaching above technical purpose, the invention provides following technical scheme.
Retrograde gas condensate saturation degree defining method in exhaustion formula exploitation sandstone gas condensate reservoir reservoir, comprises the following steps successively:
(1) obtain the rock core of actual reservoir, cleaned, dry, test diameter D (cm), length L (cm), permeability K 0(mD), factor of porosity φ (%);
(2) use for reference in industry standard SY/T5345-2007 " gas-aqueous phase oozes curve test method ", test different oil saturation S oigas phase effective permeability K under condition egi, determine the parameter a in following formula, b value:
S oi＝aln(K egi)+b
Detailed process is as follows:
1. the rock gas of actual gas condensate reservoir well head output, white oil and local water is obtained;
2. rock pore volume V=0.25 π LD is calculated 2φ, and the local water to injected slurry volume in rock core being V (ml), make it saturated;
3. to rock core, white oil is injected from core entry end, until the not water outlet of rock core endpiece, metering accumulation water outlet volume V w(ml), this volume is initial saturated oil volume V o, calculate irreducible water saturation S or=(V-V w)/V × 100%, determines initial oil saturation S in rock core o=(1-S or) × 100%;
4. to rock core, rock gas is injected from core entry end, at interval of △ t 1(s) record core entry end pressure P 1i, outlet pressures P 2i, rock core endpiece gives vent to anger volume V gi(ml), oil volume V is gone out oi(ml), oil saturation S in rock core is calculated oi=(V o-V oi)/V o× 100%;
5. the corresponding oil saturation S of rock core is calculated oigas phase effective permeability K under condition egi(mD):
K e g i = ( V g i / Δt 1 ) μ g i L 10 A ( P 1 i 2 - P 2 i 2 )
In formula:
μ gi-gas viscosity, mPas, according to the pseudocritical temperature T of rock gas pcwith pseudocritical pressure P pccha Kaerkebeishe
CarrKobayshi and Bu Lu Burrows viscosity plate checks in;
L-rock core length, cm;
A-rock core cross-sectional area, cm 2, A=0.25 π D 2, D-core diameter, cm;
6. oil saturation S in rock core is analyzed oi, gas phase effective permeability K egirelation between the two, determines formula S oi=aln (K egi) coefficient a, b value in+b;
(3) according to industry standard SY/T5542-2000, with reference to dew-point pressure P in gas reservoir prime stratum fluid properties analysis report b, single degas oil compares GOR 1preparation formation fluid sample, i.e. condensate gas sample;
(4) rock core is returned to initial reservoir state, detailed process is: used stratum water saturation, then progressively heat up, pressurize, until rock core pore pressure, temperature and gas reservoir initial formation pressure, temperature are consistent, is applied to the radial pressure P of rock core dthan pore pressure P fhigh 3MPa, then the formation fluid sample injecting preparation in rock core, at interval of 0.5 hour testing rock core endpiece output gas oil ratio GOR 2, until and GOR 1unanimously;
(5) gas reservoir depletion experiments process is simulated: according to certain pressure drop rate by reducing rock core outlet pressures P 2irealize reducing rock core mesoporosity pressure, in pressure reduction, remain the radial pressure P of rock core dthan pore pressure P fhigh 3MPa, at interval of △ t 2(S) core entry end pressure P is recorded 1i, outlet pressures P 2i, rock core endpiece gives vent to anger volume V gi, until rock core outlet pressures P 2ibe reduced to gas reservoir abandonment pressure;
(6) mean pressure P in rock core depletion experiments process is calculated according to following formula igas phase effective permeability K under condition fegi, P ifor core entry end pressure P 1iwith outlet pressures P 2imean value:
K e g i = ( V g i / Δt 2 ) μ g i L 10 A ( P 1 i 2 - P 2 i 2 ) ;
(7) by each P ithe K that point is corresponding fegibring S into oi=aln (K egi)+b, according to a, b value that step (2) is determined, to calculate in sandstone gas condensate reservoir reservoir retrograde gas condensate saturation degree S under different pressures condition oi.
Compared with prior art, exhaustion formula exploitation gas condensate reservoir retrograde gas condensate saturation degree defining method provided by the invention, principle is reliable, easy and simple to handle, economic and practical, consider the impact of porous medium, water saturation and white oil flowing, there are wide market outlook.
Accompanying drawing explanation
Fig. 1 is oil saturation and gas phase effective permeability relation curve.
Fig. 2 is gas phase effective permeability and pressure relationship plot in gas condensate reservoir During Natural Depletion process.
Fig. 3 is gas condensate reservoir exhaustion exploitation retrograde gas condensate saturation degree change curve.
Embodiment
Further illustrate the present invention according to drawings and embodiments below.
Retrograde gas condensate saturation degree defining method in a kind of exhaustion formula exploitation gas condensate reservoir porous medium, comprises the following steps successively:
(1) certain gas condensate reservoir reservoir core Y-1 is obtained, cleaning, oven dry, test diameter D (6.5cm), length L (7.9cm), permeability K 0(1.12mD), factor of porosity φ (9.5%);
(2) use for reference in industry standard SY/T5345-2007 " gas-aqueous phase oozes curve test method ", test different oil saturation S oigas phase effective permeability K under condition egi, as shown in Figure 1, and set up equation between the two:
S oi＝－0.39ln(K egi)－1.105
Detailed process is as follows:
1. certain gas condensate reservoir well head output rock gas, white oil and local water is obtained;
2. rock pore volume V=0.25 π LD is calculated 2φ=24.9ml, in rock core, injected slurry volume is the local water of 24.9ml;
3. core entry end injects white oil in rock core, until the not water outlet of rock core endpiece, and measures accumulation water outlet volume V w(16ml), this volume is initial saturated oil volume V o; Calculate irreducible water saturation S or=100% × (V-V w)/V=35.7%, determines initial oil saturation S in rock core o=100% × (1-0.357)=64.3%;
4. to rock core, inject rock gas from core entry end, record core entry end pressure P at interval of 1200s 1i, outlet pressures P 2i, rock core endpiece gives vent to anger volume V gi(ml), oil volume V is gone out oi(ml), oil saturation S in rock core is calculated oi=100% × (V o-V oi)/V o;
5. corresponding oil saturation S is calculated oigas phase effective permeability K under condition egi:
K e g i = ( V g i / Δt 1 ) μ g i L 10 A ( P 1 i 2 - P 2 i 2 ) ;
6. oil saturation S in rock core is analyzed oi, gas phase effective permeability (K egi) relation between the two, determine S oi=aln (K egi) coefficient a, b in+b, as shown in Figure 1;
(3) according to industry standard SY/T5542-2000, with reference to dew-point pressure (34MPa), single degas oil ratio (3010m in gas reservoir prime stratum fluid properties analysis report 3/ m 3) preparation formation fluid sample;
(4) adopt same rock core, saturated local water, progressively heats up, pressurizes, until rock core pore pressure, temperature and gas reservoir initial formation pressure, temperature are consistent, is applied to rock core radial pressure P dthan pore pressure P fhigh 3MPa, then injects preparation formation fluid sample, at interval of 0.5 hour testing rock core endpiece output gas oil ratio GOR in rock core 2, until 4 times of volume of voids test GOR 2(3008m 3/ m 3) and GOR 1(3010m 3/ m 3) consistent;
(5) simulate gas reservoir exhaustion recovery process, progressively reducing rock core mesoporosity pressure by discharging resident fluid in rock core, in pressure reduction, remaining rock core pore pressure P fbe applied to rock core radial pressure P ddifference is 3MPa, reduces rock core outlet pressures P according to pressure drop rate (1MPa/h) 2irealize reducing rock core pore pressure, at interval of △ t 2(3600s) corresponding core entry pressure P is recorded 1i, release gas volume V gi, until P 2ibe reduced to gas reservoir abandonment pressure;
(6) according to core diameter D, length L, inlet port pressure P 1i, outlet pressures P 2i, time interval △ t 2, endpiece gives vent to anger volume V gi, according to Darcy formula calculate mean pressure P in rock core depletion experiments process i(0.5 × (P 1i+ P 2i)) gas phase effective permeability K under condition fegi(as shown in Figure 2);
(7) K fegibring S into oi=aln (K egi)+b, calculate white oil saturation degree S under reservoir conditions oi, draw pressure P iwith S oirelation, thus retrograde gas condensate saturation degree (as shown in Figure 3) in rock core under determining different pressures condition.

Claims (3)

1. retrograde gas condensate saturation degree defining method in exhaustion formula exploitation sandstone gas condensate reservoir reservoir, comprises the following steps successively:
(1) obtain the rock core of actual reservoir, cleaned, dry, test diameter D, length L, permeability K 0, factor of porosity φ;
(2) different oil saturation S is tested oigas phase effective permeability K under condition egi, determine formula S oi=aln (K egi) parameter a, b value in+b, detailed process is as follows:
1. the rock gas of actual gas condensate reservoir well head output, white oil and local water is obtained;
2. rock pore volume V=0.25 π LD is calculated 2φ, and the local water to injected slurry volume in rock core being V (ml), make it saturated;
3. to rock core, white oil is injected from core entry end, until the not water outlet of rock core endpiece, metering accumulation water outlet volume V w, this volume is initial saturated oil volume V o, calculate irreducible water saturation S or=(V-V w)/V × 100%, determines initial oil saturation S in rock core o=(1-S or) × 100%;
4. to rock core, rock gas is injected from core entry end, at interval of △ t 1record core entry end pressure P 1i, outlet pressures P 2i, rock core endpiece gives vent to anger volume V gi, go out oil volume V oi, calculate oil saturation S in rock core oi=(V o-V oi)/V o× 100%;
5. the corresponding oil saturation S of rock core is calculated oigas phase effective permeability K under condition egi:
K e g i = ( V g i / Δt 1 ) μ g i L 10 A ( P 1 i 2 - P 2 i 2 )
In formula:
μ gi-gas viscosity, mPas;
L-rock core length, cm;
A-rock core cross-sectional area, cm 2, A=0.25 π D 2, D-core diameter, cm;
6. oil saturation S in rock core is analyzed oi, gas phase effective permeability K egirelation between the two, determines formula S oi=aln (K egi) coefficient a, b value in+b;
(3) with reference to dew-point pressure P in gas reservoir prime stratum fluid properties analysis report b, single degas oil compares GOR 1preparation formation fluid sample, i.e. condensate gas sample;
(4) rock core is returned to initial reservoir state;
(5) by reducing rock core outlet pressures P 2irealize reducing rock core mesoporosity pressure, in pressure reduction, remain the radial pressure P of rock core dthan pore pressure P fhigh 3MPa, at interval of △ t 2record core entry end pressure P 1i, outlet pressures P 2i, rock core endpiece gives vent to anger volume V gi, until rock core outlet pressures P 2ibe reduced to gas reservoir abandonment pressure;
(6) mean pressure P in rock core depletion experiments process is calculated according to following formula igas phase effective permeability K under condition fegi:
K e g i = ( V g i / Δt 2 ) μ g i L 10 A ( P 1 i 2 - P 2 i 2 ) ;
(7) by each P ithe K that point is corresponding fegibring S into oi=aln (K egi)+b, according to a, b value that step (2) is determined, to calculate in sandstone gas condensate reservoir reservoir retrograde gas condensate saturation degree S under different pressures condition oi.
2. retrograde gas condensate saturation degree defining method in exhaustion formula exploitation sandstone gas condensate reservoir reservoir as claimed in claim 1, it is characterized in that, rock core is returned to initial reservoir state by described step (4), detailed process is: used stratum water saturation, then progressively heat up, pressurize, until rock core pore pressure, temperature and gas reservoir initial formation pressure, temperature are consistent, be applied to the radial pressure P of rock core dthan pore pressure P fhigh 3MPa, then the formation fluid sample injecting preparation in rock core, at interval of 0.5 hour testing rock core endpiece output gas oil ratio GOR 2, until and GOR 1unanimously.
3. retrograde gas condensate saturation degree defining method in exhaustion formula exploitation sandstone gas condensate reservoir reservoir as claimed in claim 1, is characterized in that, described step (6) mean pressure P ifor core entry end pressure P 1iwith outlet pressures P 2imean value.
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CN106501300A (en) * 2016-10-09 2017-03-15 中国石油天然气股份有限公司 Method for testing nonequilibrium phase transition of high-water-content dense condensate gas reservoir
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