CN112285201B - Method for testing gas injection, reverse evaporation and condensate oil saturation of low-permeability condensate gas reservoir - Google Patents
Method for testing gas injection, reverse evaporation and condensate oil saturation of low-permeability condensate gas reservoir Download PDFInfo
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Abstract
The invention relates to a method for testing the gas injection and reverse evaporation condensate oil saturation of a low-permeability condensate gas reservoir, which comprises the following steps: preparing condensate gas, and measuring the maximum reverse condensate oil saturation pressure P1(ii) a Putting the long rock core into a rock core holder, and connecting the long rock core with a gas injection anti-evaporation experimental device; injecting a separator gas sample into the core to gradually increase the pore pressure of the core to P1(ii) a Injecting the separator oil sample into the rock core, and obtaining a calculation formula S through a relation curve of condensate oil saturation and acoustic wave time differenceoi＝A·ΔTi+ B; restoring the core to the original stratum state; the pressure at the outlet end of the rock core is decreased from the original formation pressure P according to the decreasing speed of 2MPa per hour0Decrease to P1Obtaining the current pressure P1Retrograde condensate saturation S in lower coreo1(ii) a Injecting the separator gas sample into the rock core to obtain the current pressure P2Retrograde condensate saturation S in lower coreo2(ii) a The current pressure P is likewise obtainediRetrograde condensate saturation S in lower coreoi. The method is simple and convenient to operate and high in applicability, and the retrograde condensate oil saturation of the true stratum core in the gas injection process of the condensate gas reservoir can be determined.
Description
Technical Field
The invention relates to a method for testing the gas injection reverse evaporation condensate oil saturation of a low-permeability condensate gas reservoir in the field of petroleum and natural gas exploration and development.
Background
The condensate gas reservoir is different from a common oil reservoir or a gas reservoir, has the characteristics of both the oil reservoir and the gas reservoir and also has the characteristic of complex phase state. In the process of condensate gas reservoir development, when the reservoir pressure is lower than the dew point pressure, condensate oil can be separated out from a gas phase and is accumulated in a near well region in a large amount, so that the original seepage pore canal is blocked, the gas phase permeability is reduced, and particularly in a compact sandstone reservoir, the blocking phenomenon is more serious, and even the gas well stops spraying. Therefore, the determination of the retrograde condensate saturation in the stratum under different pressures has important significance for evaluating the retrograde condensate pollution damage of the near well region and quantitatively determining the condensate loss and the influence on the gas phase seepage capability.
At present, for testing the anti-condensate oil saturation of a condensate gas reservoir, scholars at home and abroad develop a great deal of research, which mainly comprises the following steps: experimental method, numerical simulation method, thermodynamic model method, etc. The experimental method is mainly based on constant mass expansion and constant volume failure of a physical property analysis method of oil and gas reservoir fluid (GB/T26981-2011), and the reverse condensate oil saturation is quantitatively determined through a PVT cylinder. The numerical simulation method mainly adopts an oil reservoir numerical simulation software Eclipse to carry out CCE and CVD experimental simulation (Wanzhouhua, Wangzhen Jun, Yang Hongzi, and the like. Anyue low-permeability condensate gas reservoir single-well dry gas throughput parameter optimization [ J ] special oil and gas reservoir, 2013,20(6): 84-88). The thermodynamic modeling method mainly uses a non-equilibrium phase transition model to perform reverse condensate saturation simulation (Hanmin Tu, Ping Guo, Na, Jia, et al. numerical evaluation of phase behavor properties for gas condensate under non-equilibrium conditions [ J ] Fuel,226(15): 675) 685). However, the existing experimental method mostly adopts the constant mass expansion and constant volume depletion experiments in the PVT cylinder to carry out the retrograde condensate saturation test, although the retrograde condensate volume can be intuitively and quantitatively determined, the influence of a real core porous medium is not considered, and the method has the defect of accurately evaluating the retrograde condensate saturation change in the reservoir. Therefore, the method for testing the reverse condensate saturation of the real stratum under the condition of considering the porous medium has more practical significance, and provides important technical support for evaluating and relieving the reverse condensate pollution of the condensate gas reservoir.
Disclosure of Invention
The invention aims to provide a method for testing the gas injection anti-evaporation condensate saturation of a low-permeability condensate reservoir, which has the advantages of reliable principle, simple and convenient operation and strong applicability, can determine the change rule of the anti-condensate saturation in a real stratum core in the gas injection process of a condensate gas reservoir, and has wide market application prospect.
In order to achieve the technical purpose, the invention adopts the following technical scheme.
The invention tests the condensate oil saturation degree by a gas injection and reverse evaporation mode, wherein the gas injection and reverse evaporation mode comprises the following steps: in the development process of a condensate gas reservoir, when the reservoir pressure is lower than the dew point pressure, condensate oil can be separated out from a gas phase, the condensate oil is continuously subjected to reverse condensation along with the reduction of the pressure, the volume of the reverse condensate oil is continuously increased, and when the reservoir pressure is reduced to the maximum reverse condensate pressure, the volume of the reverse condensate oil reaches the maximum value; at this point, a separator gas sample is injected into the reservoir, so that the light components in the system equilibrium gas are increased, while the intermediate and heavy components are relatively decreased, and the corresponding components in the condensate are redistributed into the gas phase in order to achieve phase equilibrium, so that the condensate volume is decreased.
A method for testing the gas injection reverse evaporation condensate oil saturation of a low-permeability condensate gas reservoir sequentially comprises the following steps:
(1) obtaining a separator gas sample and a separator oil sample under the current production condition of a gas well in a low-permeability gas condensate reservoir, and obtaining the separator gas sample and the separator oil sample at the original formation temperature T2011 according to an oil-gas reservoir fluid physical property analysis method (GB/T26981-0(° c) and virgin formation pressure P0Preparing condensate gas under (MPa) condition to make the gas-oil ratio meet the original gas-oil ratio GOR of reservoir0(GOR0＝Vg/Vo) And measuring the maximum retrograde condensate saturation pressure P1；
(2) Obtaining a plurality of sample blocks of the core sample of the gas condensate reservoir plunger, cleaning and drying the sample blocks, and measuring the diameter D of the sample blocksi(cm) length Li(cm) and porosity
Combining plunger core samples into a long core, putting the long core into a core holder, and calculating the total pore volume V of the core0(cm3)；
(3) Connecting a gas injection reverse evaporation experimental device: connecting the inlet end of a rock core holder with a middle container and an injection pump, wherein the middle container is respectively provided with a separator gas sample, a separator oil sample, formation water and condensate gas, the outlet end of the middle container is respectively connected with a back pressure valve and a separator, the back pressure valve is connected with a back pressure pump, the separator is connected with a gas meter, two ends of the rock core holder are provided with a pressure gauge and a sound wave transmitting-receiving device, and are simultaneously connected with a confining pressure pump, the rock core holder and the middle container are positioned in an oven, and the temperature of the oven is raised to the original formation temperature T0；
(4) Starting the confining pressure pump, gradually increasing confining pressure of the core holder, injecting the separator gas sample into the core through the injection pump, and gradually increasing pore pressure of the core to P1The surrounding pressure is always kept higher than the pore pressure by 5MPa in the process;
(5) injecting the separator oil sample into the rock core by an injection pump at a constant speed, wherein each injection is 0.1V0Volume, by means of acoustic transmitter-receiver, the volume V of the core injected at both ends is measured and recordedi(Vi＝i×0.1×V0I-1, 2,3, …, n) sound wave time difference Δ TiAccording to the total pore volume V of the core0And the volume V of the separator oil sample injectediCalculating condensate saturation Soi＝100×Vi/V0As condensate saturation SoiAs ordinate, with acoustic time difference Δ TiAs the abscissa, the calculation formula S is obtained through the relation curve of the condensate saturation and the acoustic wave time differenceoi＝A·ΔTi+ B, and obtaining A, B specific numerical value;
(6) taking out the core, cleaning, drying, putting into the core holder again, and raising the temperature of the oven to the original formation temperature T0Injecting formation water into the core by an injection pump, wherein the formation water appears in a separator at the outlet end of the core when the pore pressure of the core is increasedRaising to the original formation pressure P0Stopping injecting formation water, injecting the separator gas sample into the core until the formation water in the separator is not increased, finishing building of core bound water, and injecting the formation water with the volume V1(cm3)；
(7) Regulating injection pump pressure versus virgin formation pressure P0The height of the core is 2MPa, condensate gas is injected into the core under a constant pressure mode, and the gas-oil ratio of the outlet end of the core holder is GOR0Stopping the process, and recovering the rock core to the original stratum state;
(8) closing the inlet end of the rock core, and adjusting the back pressure pump to ensure that the pressure at the outlet end of the rock core is decreased from P according to the decreasing speed of 2MPa per hour0Decrease to P1Testing P by acoustic wave emitting-receiving means1Acoustic time difference delta T between two ends of lower core1Obtaining the current pressure P1Retrograde condensate saturation S in lower coreo1；
(9) Closing the outlet end of the rock core, and injecting a separator gas sample into the rock core through an injection pump, wherein the injection volume of the separator gas sample is 0.1V2，V2＝V0-V1At this time, the core pressure is P2Testing P by acoustic wave emitting-receiving means2Acoustic time difference delta T between two ends of lower core2Obtaining the current pressure P2Retrograde condensate saturation S in lower coreo2Will So1And So2The comparison was made to obtain an injection of 0.1V2After the separator gas sample, the reduced value of retrograde condensate saturation in the core;
(10) repeating the step (9), and performing sound wave time difference delta T under different gas injection timesiObtain the current pressure PiRetrograde condensate saturation S in lower coreoi。
Compared with the prior art, the invention has the following beneficial effects:
compared with the existing method for testing the condensate oil saturation in the porous medium, the method can calibrate the condensate oil saturation in the real porous medium through the sound wave transmitting-receiving device, so that the experimental test result is more consistent with the actual condition of a reservoir; after the relation between the condensate oil saturation and the sound wave time difference is calibrated, the change rule of the condensate oil saturation in the real porous medium after each gas injection can be accurately tested.
Drawings
FIG. 1 is a schematic structural diagram of a long core gas injection and reverse evaporation experimental apparatus.
In the figure: 1. 2,3, 4, 5, 6, 7, 8, 9, 10, 11, 12-valves; 13. 14, 15, 16-injection pump; 17-confining pressure pump; 18-a back pressure pump; 19-separator gas sample intermediate vessel; 20-separator oil sample intermediate vessel; 21-formation water intermediate container; 22-condensate gas intermediate vessel; 23-inlet pressure gauge; 24-outlet pressure gauge; 25-core holder; 26-acoustic wave transmitting-receiving means; 27-a back pressure valve; 28-a separator; 29-gas meter; and (30) drying in an oven.
FIG. 2 shows the acoustic time difference (Δ T) and retrograde condensate saturation (S) for long coreso) The relationship of (1).
FIG. 3 shows the gas injection times (n) for a long core and the corresponding retrograde condensate saturation (S)on) The relationship of (1).
Detailed Description
The invention is further illustrated below with reference to the figures and examples in order to facilitate the understanding of the invention by a person skilled in the art. It is to be understood that the invention is not limited in scope to the specific embodiments, but is intended to cover various modifications within the spirit and scope of the invention as defined and defined by the appended claims, as would be apparent to one of ordinary skill in the art.
See fig. 1.
Fig. 1 shows a long core gas injection and anti-evaporation experimental apparatus, an inlet end of a core holder 25 is respectively connected with a separator gas sample intermediate container 19, a separator oil sample intermediate container 20, a formation water intermediate container 21, a condensate gas intermediate container 22 and injection pumps 13, 14, 15 and 16, an outlet end is respectively connected with a back pressure valve 27 and a separator 28, the back pressure valve is connected with a back pressure pump 18, the separator is connected with a gas meter 29, pressure meters 23 and 24 and a sound wave transmitting-receiving device 26 are arranged at two ends of the core holder, and are simultaneously connected with a confining pressure pump 17, and the core holder and the intermediate container are located in an oven 30.
Examples
In the example, the separated gas sample and the separator oil sample are from a BZ condensate gas reservoir 2Sa block, and condensate gas samples are prepared under the original formation pressure and temperature; gas injection was performed at maximum retrograde condensate saturation pressure and the change in condensate saturation after gas injection was tested.
A method for testing the gas injection reverse evaporation condensate oil saturation of a low-permeability condensate gas reservoir sequentially comprises the following steps:
(1) obtaining a separator gas sample (see table 1) and a separator oil sample under the current production condition of a gas well in a low-permeability gas condensate reservoir, and preparing the gas condensate under the conditions of the original formation temperature of 152 ℃ and the original formation pressure of 46.93MPa according to an oil-gas reservoir fluid physical property analysis method (GB/T26981-0＝1150m3/m3(GOR0＝Vg/Vo) And measuring the maximum retrograde condensate saturation pressure P1Measured at 23MPa, the condensate dew point pressure is Pd＝43.96MPa；
TABLE 1 separator gas sample chromatography test results
(2) 6 plunger core samples (average diameter 2.52cm) of the actual reservoir of the condensate gas reservoir are obtained, and the core diameter D is measuredi(cm) length Li(cm), after the core is cleaned and dried, testing the porosity of the core according to a core analysis method (GB/T29172-
Permeability Ki(mD), the results of the tests are shown in Table 2:
TABLE 26 core Property test results
Combining the plunger core samples into a long core, wherein the length of the combined core is 30.778cm, putting the combined long core into a core holder 25 shown in figure 1, and calculating the total pore volume of the core
(3) Connecting an experimental device according to the figure 1, connecting an inlet end of a core holder with a middle container and an injection pump, wherein the middle container is respectively provided with a separator gas sample, a separator oil sample, formation water and condensate gas, an outlet end of the core holder is respectively connected with a back pressure valve and a separator, the back pressure valve is connected with the back pressure pump, the separator is connected with a gas meter, two ends of the core holder are provided with a pressure meter and a sound wave transmitting-receiving device and are simultaneously connected with an enclosing pressure pump, the core holder and the middle container are positioned in an oven, and the temperature of the oven is raised to the original formation temperature of 152 ℃;
(4) starting a confining pressure pump 17, gradually increasing confining pressure of the core holder, injecting a separator gas sample 19 into the core through an injection pump 13, gradually increasing pore pressure of the core to 23MPa, and keeping confining pressure higher than 5MPa of pore pressure all the time in the process;
(5) the injection pump 14 injects the separator oil sample 20 into the core at a constant rate, 0.1 x V per injection0＝0.1×15.294＝1.5294(cm3) Volume, through the acoustic transmitter-receiver unit 26, the core ends at the injection volume V are tested and recordedi(Vi＝i 0.1×V0I-1, 2,3, …, n) sound wave time difference Δ TiAnd the test results (see table 3). According to the total pore volume V of the core0And the volume V of the separator oil sample injectediCalculating condensate saturation Soi＝100×Vi/V0As condensate saturation SoiAs ordinate, with acoustic time difference Δ TiAs an abscissa, a calculation formula S is obtained by a relation curve of condensate saturation and acoustic time difference (see FIG. 2)oi＝-7.9371·ΔTi+792.91；
TABLE 3 core acoustic time difference test results
(6) Taking out the core, cleaning, drying, putting the core into the core holder again by 25 ℃, raising the temperature of the oven to 152 ℃ of the original formation temperature, injecting formation water 21 into the core by an injection pump 15, wherein the formation water appears in a separator at the outlet end of the core, stopping injecting the formation water when the pore pressure of the core is raised to 46.93MPa of the original formation pressure, injecting a separator gas sample 19 into the core until the formation water in the separator is not increased any more, and at the moment, the formation bound water is completely built, and the volume of the injected formation water is 4.894 (cm)3)；
(7) Adjusting the pressure of an injection pump 16 to be higher than the original formation pressure of 46.93MPa by 2MPa, injecting the condensate gas 22 into the rock core in a constant pressure mode, and setting the gas-oil ratio of the outlet end of the rock core holder to be 1150m3/m3Ending the displacement to restore the core to the original stratum state;
(8) closing the inlet end of the rock core, adjusting a back pressure pump 18 to ensure that the pressure at the outlet end of the rock core is reduced from 46.93MPa to 23MPa according to the reduction speed of 2MPa per hour, separating condensate oil from gas phase when the pore pressure of the rock core is lower than the dew point pressure of 43.97MPa, continuously carrying out reverse condensation on the condensate oil along with the reduction of the pore pressure of the rock core until the pore pressure of the rock core is reduced to 23MPa, wherein the volume of the reverse condensate oil reaches the maximum value, and testing the sound wave time difference delta T at two ends of the rock core under 23MPa by a sound wave transmitting-receiving device at the moment1Obtaining the retrograde condensate oil saturation degree S in the rock core under the current pressure of 23MPa in 96.094 muso1＝30.20％；
(9) Closing the outlet end of the rock core, injecting a separator gas sample 19 into the rock core through an injection pump 13, wherein the injection volume of the separator gas sample is 0.1V2＝0.1×(15.294-4.894)＝1.04(cm3) At the moment, the core pressure is 23.45MPa, and the acoustic wave time difference delta T of two ends of the core under 23.45MPa is tested by an acoustic wave transmitting-receiving device2The retrograde condensate saturation S in the core was obtained at a current pressure of 23.45MPa ═ 96.175 μ So229.56%, mixing So1And So2The comparison was made to obtain an injection of 0.1V2Separation ofAfter sampling gas, the reduction value of the retrograde condensate saturation in the core is that delta So is 0.64%;
(10) repeating the step (9), and performing sound wave time difference delta T under different gas injection timesiObtain the current pressure PiRetrograde condensate saturation S in lower coreoiThe test results are shown in table 4 and fig. 3.
Table 4 test results of the retrograde condensate saturation in the core under different gas injection times
Claims (2)
1. A method for testing the gas injection reverse evaporation condensate oil saturation of a low-permeability condensate gas reservoir sequentially comprises the following steps:
(1) obtaining a separator gas sample and a separator oil sample of a gas well of a low-permeability gas condensate reservoir under the current production condition of the gas well at the original formation temperature T0And the pressure P of the original formation0Preparing condensate gas under the condition that the gas-oil ratio of the condensate gas meets the original gas-oil ratio GOR of the reservoir0And measuring the maximum retrograde condensate saturation pressure P1；
(2) Obtaining a plurality of blocks of the core sample of the gas condensate reservoir plunger, combining the blocks into a long core, putting the long core into a core holder, and calculating the total pore volume V of the core0；
(3) Connecting a gas injection reverse evaporation experimental device: connecting the inlet end of a rock core holder with a middle container and an injection pump, wherein the middle container is respectively provided with a separator gas sample, a separator oil sample, formation water and condensate gas, the outlet end of the middle container is respectively connected with a back pressure valve and a separator, the back pressure valve is connected with a back pressure pump, the separator is connected with a gas meter, two ends of the rock core holder are provided with a pressure gauge and a sound wave transmitting-receiving device, and are simultaneously connected with a confining pressure pump, the rock core holder and the middle container are positioned in an oven, and the temperature of the oven is raised to the original formation temperature T0；
(4) Starting the confining pressure pump, gradually increasing confining pressure of the core holder, injecting the separator gas sample into the core through the injection pump, and gradually increasing pore pressure of the core to P1The process startsThe final holding confining pressure is 5MPa higher than the pore pressure;
(5) injecting the separator oil sample into the rock core by an injection pump at a constant speed, wherein each injection is 0.1V0Volume, by means of acoustic transmitter-receiver, the volume V of the core injected at both ends is measured and recordediAcoustic time difference atiCalculating the condensate saturation Soi＝100×Vi/V0As condensate saturation SoiAs ordinate, with acoustic time difference Δ TiAs the abscissa, the calculation formula S is obtained through the relation curve of the condensate saturation and the acoustic wave time differenceoi＝A·ΔTi+ B, and obtaining A, B specific numerical value;
(6) taking out the core, cleaning, drying, putting into the core holder again, and raising the temperature of the oven to the original formation temperature T0Injecting formation water into the core by an injection pump, and when the pore pressure of the core is increased to the original formation pressure P0Stopping injecting formation water, injecting the separator gas sample into the core until the formation water in the separator is not increased, finishing building of core bound water, and injecting the formation water with the volume V1；
(7) Regulating injection pump pressure versus virgin formation pressure P0The height of the core is 2MPa, condensate gas is injected into the core under a constant pressure mode, and the gas-oil ratio of the outlet end of the core holder is GOR0Stopping the process, and recovering the rock core to the original stratum state;
(8) closing the inlet end of the rock core, and adjusting the back pressure pump to ensure that the pressure at the outlet end of the rock core is decreased from P according to the decreasing speed of 2MPa per hour0Decrease to P1Testing P by acoustic wave emitting-receiving means1Acoustic time difference delta T between two ends of lower core1Obtaining the current pressure P1Retrograde condensate saturation S in lower coreo1；
(9) Closing the outlet end of the rock core, and injecting a separator gas sample into the rock core through an injection pump, wherein the injection volume of the separator gas sample is 0.1V2，V2＝V0-V1At this time, the core pressure is P2Testing P by acoustic wave emitting-receiving means2Acoustic time difference delta T between two ends of lower core2Obtaining the current pressure P2Retrograde condensate saturation S in lower coreo2；
(10) Repeating the step (9), and performing sound wave time difference delta T under different gas injection timesiObtain the current pressure PiRetrograde condensate saturation S in lower coreoi。
2. The method for testing the gas injection and reverse evaporation condensate saturation degree of the hypotonic condensate reservoir of claim 1, wherein the injection volume V of the separator oil sample in the step (5)i＝i×0.1×V0，i＝1,2,3,…,n。
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