CN110005399B - Experimental method for measuring volume of retrograde condensate oil containing excessive water condensate gas - Google Patents

Experimental method for measuring volume of retrograde condensate oil containing excessive water condensate gas Download PDF

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CN110005399B
CN110005399B CN201910302479.7A CN201910302479A CN110005399B CN 110005399 B CN110005399 B CN 110005399B CN 201910302479 A CN201910302479 A CN 201910302479A CN 110005399 B CN110005399 B CN 110005399B
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volume
pvt
condensate
condensate gas
water
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CN110005399A (en
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韩晓冰
严文德
袁迎中
何昱樟
李继强
黄小亮
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Chongqing University of Science and Technology
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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
    • E21B47/00—Survey of boreholes or wells
    • 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
    • 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
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E30/00—Energy generation of nuclear origin
    • Y02E30/30—Nuclear fission reactors

Abstract

The invention discloses an experimental method for measuring the volume of retrograde condensate oil of condensate gas containing excessive water, which has high reliability of experimental results. The method comprises the following steps: at a pressure P1Preparing saturated condensate gas at temperature T, and measuring water content xiPercent; taking a PVT high-pressure physical property analyzer, and adding a volume V into a PVT main cylinder of the PVT high-pressure physical property analyzeriwAdding the prepared condensate gas into the PVT main cylinder to ensure that the temperature and the pressure of the condensate gas are unchanged, so that the condensate gas contains excessive water; fully stirring the condensate gas in the PVT main cylinder, and measuring the volume V of the gas in the PVT main cylinder by a PVT high-pressure physical property analyzergw(ii) a Releasing the condensate gas until the PVT main cylinder is reduced to the pressure set value P2Reading the volume V of the liquid phase in the PVT main tubewtAnd measuring the water content x% of the condensate gas; finding the value C of the formation water compressibilitywAnd calculating the volume V of water in the liquid phasew(ii) a Subtracting the volume V of water in the liquid phase from the volume of the liquid phase in the PVT main cartridgewObtaining the volume V of the oil which is precipitated by reverse coagulationo。

Description

Experimental method for measuring volume of retrograde condensate oil containing excessive water condensate gas
Technical Field
The invention relates to the technical field of oil and gas field development, in particular to an experimental method for measuring the volume of retrograde condensate oil containing excessive water condensate gas.
Background
In the process of extracting the condensate gas from the ground to the ground, the phenomena of phase state change and the like of separating and dissolving the condensate oil from the gas are accompanied, the purity of the condensate oil is high, the condensate oil can be put into use by simple extraction or even without extraction after being extracted from the ground, and the condensate gas is a category which is worthy of research; meanwhile, research on the reverse condensation phenomenon of the condensate gas can also generate guiding significance for the development of oil and gas fields. At present, researchers summarize the phase change rule and the influence factors of the formation-containing water condensate gas-evolution reservoir through a plurality of research results. In 2006, the study of scholars such as Shidebei and Sunlei finds that: the quantity of the reverse condensate of the condensate gas sample rich in water state is larger than that of the anhydrous condensate gas sample, the extraction degree of the condensate liquid in the condensate gas containing gaseous water is lower than that of the condensate gas containing no water, and the difference between the quantity of the reverse condensate liquid and the extraction degree of the condensate liquid of the two groups of samples is larger and larger along with the reduction of pressure. In 2014, the students of soup courage, severe shivering and the like found that: the higher the temperature, the higher the condensate content in the gas and the exponential increase with decreasing pressure. The existence of the formation water increases both the condensate deposit dew point pressure and the maximum amount of retrograde condensate, which indicates that the formation water exists to intensify the retrograde condensation. Therefore, the influence of the existence of formation water on the phase state and the development process must be considered in the high-temperature and high-pressure condensate gas reservoir. However, when the law of the phase state characteristic change of the condensate gas reservoir containing formation water is researched, the typical fluid composition and the interrelation between fluids in the oil and gas reservoir need to be simulated when the content proportion of condensate oil is analyzed, and experiments prove that the condensate oil content in the condensate gas is low, the content of the condensate oil is difficult to measure, the difficulty of the whole experiment is increased, and the accuracy and the reliability of the condensate gas are difficult to evaluate even if the experiment result can be successfully obtained. When the amount of the condensate oil separated out from the condensate gas is accurately measured, the method can accurately obtain how the content of the formation water specifically influences the development of the condensate gas through experiments, so that the method can have more accurate budget for the original geological reserve of the condensate gas and the recovery ratio of natural gas and the condensate oil, and has clearer budget estimation for the oil storage amount and the gas storage amount in the formation in the process of oil and gas field development, and the labor waste and the economic loss caused by the prediction error can be reduced.
Disclosure of Invention
The invention aims to overcome the defects of the prior art and provide an experimental method for measuring the volume of the retrograde condensate oil containing excessive water condensate gas, and the experimental result has high reliability.
The purpose of the invention is realized as follows:
an experimental method for measuring the volume of retrograde condensate oil containing excessive water condensate gas comprises the following steps:
s1, at pressure P1Preparing saturated condensate gas at temperature T, and measuring water content xi％；
S2, adding water into the PVT main tube of the PVT high-pressure physical property analyzer, wherein the volume of the added water is ViwAdding the prepared condensate gas into the PVT main cylinder, wherein the volume of the condensate gas is VgSo that the condensate gas contains excessive water, and the temperature and the pressure of the condensate gas are ensured to be unchanged in the process of adding the condensate gas;
s3, at pressure P1Fully stirring the condensate gas in the PVT main cylinder at the temperature T, and measuring the volume V of the gas in the PVT main cylinder by a PVT high-pressure physical property analyzergw；
S4, keeping the volume of the PVT main cylinder unchanged, and releasing the condensate gas until the volume of the PVT main cylinder is reduced to a pressure set value P2Reading the volume V of the liquid phase in the PVT main tubewtAnd measuring the water content x% of the condensate gas;
s5, obtaining the value C of the formation water compression coefficient according to the variation curve of the formation water compression coefficient along with the pressure and the temperaturewAnd calculating the volume V of water in the liquid phasewThe calculation method is as follows:
Figure BDA0002028685270000021
Vgw＝Vg×(x％-xi％)
obtaining by solution: vw＝[1-Cw(P1-P2)]×{Viw-Vg(x％-xi％)]；
S6, subtracting the volume V of water in the liquid phase from the volume of the liquid phase in the PVT main cylinderwObtaining the volume V of the oil which is precipitated by reverse coagulation0The calculation formula is as follows:
V0＝Vwt-Vw。
preferably, in S1, a sufficient amount of water and condensate gas are added to the high-temperature high-pressure sample distributor to prepare saturated condensate gas required for the experiment.
Preferably, in S4, the water content of the condensate in the PVT main tube is measured by chromatographic analysis.
Preferably, the temperature T is the temperature of the condensate gas reservoir.
By adopting the technical scheme, the invention solves the problems that the condensate liquid amount is small, the oil-water interface is not obvious, and the volume of the precipitated condensate is difficult to measure, and the reliability of experimental tests is ensured as much as possible by considering the compressibility and volatility of water.
Detailed Description
An experimental method for measuring the volume of retrograde condensate oil containing excessive water condensate gas comprises the following steps:
s1, at pressure P1And at the temperature T, the temperature T is the temperature of the condensate gas reservoir. Adding sufficient water and condensate gas into the high-temperature high-pressure sample injector, preparing saturated condensate gas required by the experiment, and measuring the water content xi％；
S2, adding water into the PVT main tube of the PVT high-pressure physical property analyzer, wherein the volume of the added water is ViwAdding the prepared condensate gas into the PVT main cylinder, wherein the volume of the condensate gas is VgSo that the condensate gas contains excessive water, and the temperature and the pressure of the condensate gas are ensured to be unchanged in the process of adding the condensate gas;
s3, at pressure P1Fully stirring the condensate gas in the PVT main cylinder at the temperature T, and measuring the volume V of the gas in the PVT main cylinder by a PVT high-pressure physical property analyzergw；
S4, keeping the volume of the PVT main cylinder unchanged, and releasing the condensate gas until the volume of the PVT main cylinder is reduced to a pressure set value P2Reading the volume V of the liquid phase in the PVT main tubewtMeasuring the water content x% of the condensate gas in the PVT main cylinder by chromatographic analysis;
s5, obtaining the value C of the formation water compression coefficient according to the variation curve of the formation water compression coefficient along with the pressure and the temperaturewAnd calculating the volume V of water in the liquid phasewThe calculation method is as follows:
Figure BDA0002028685270000041
Vgw＝Vg×(x％-xi％)
obtaining by solution: vw＝[1-Cw(P1-P2)]×[Viw-Vg(x％-xi％)]；
S6, subtracting the volume V of water in the liquid phase from the volume of the liquid phase in the PVT main cylinderwObtaining the volume V of the oil which is precipitated by reverse coagulation0The calculation formula is as follows:
V0＝Vwt-Vw。
example (b):
the phase characteristic experiment of a Q67-2 well rich saturated gaseous water system, the total volume (constant volume) of a PVT main cylinder is 200ml, the experiment temperature is 396.25k, and the following experiment data are provided:
initial pressure P147.8MPa, volume V of water added to the main drum of pvtiw60.52ml, volume of gas Vg139.48ml, water content xi％＝1.69994％，
When the gas is released, the pressure is reduced to P2When the pressure is 36MPa, the water content of the gas is 1.83321%, and the total volume V of the liquid phase is measuredwt63.148ml, Chaudac Cw＝4.49×10-4，
Based on the above data, calculate
Figure BDA0002028685270000042
Figure BDA0002028685270000043
Volume V of condensate0＝Vwt-Vw＝63.148-60.014＝3.134ml
Finally, it is noted that the above-mentioned preferred embodiments illustrate rather than limit the invention, and that, although the invention has been described in detail with reference to the above-mentioned preferred embodiments, it will be understood by those skilled in the art that various changes in form and detail may be made therein without departing from the scope of the invention as defined by the appended claims.

Claims (3)

1. An experimental method for measuring the volume of retrograde condensate oil containing excessive water condensate gas is characterized by comprising the following steps:
s1, at pressure P1Preparing saturated condensate gas at temperature T, and measuring water content xi％；
The temperature T is the temperature of the condensate gas reservoir;
s2, adding water into the PVT main tube of the PVT high-pressure physical property analyzer, wherein the volume of the added water is ViwAdding the prepared condensate gas into the PVT main cylinder, wherein the volume of the condensate gas is VgSo that the condensate gas contains excessive water, and the temperature and the pressure of the condensate gas are ensured to be unchanged in the process of adding the condensate gas;
s3 at pressure P1Fully stirring the condensate gas in the PVT main cylinder at the temperature T, and measuring the volume V of the gas in the PVT main cylinder by a PVT high-pressure physical property analyzergw；
S4, keeping the volume of the PVT main cylinder unchanged, and releasing the condensate gas until the volume of the PVT main cylinder is reduced to a pressure set value P2Reading the volume V of the liquid phase in the PVT main tubewtAnd measuring the water content x% of the condensate gas;
s5, obtaining the value C of the formation water compression coefficient according to the variation curve of the formation water compression coefficient along with the pressure and the temperaturewAnd calculating the volume V of water in the liquid phasewThe calculation method is as follows:
Figure FDA0003611675360000011
Vgw＝Vg×(x％-xi％)
obtaining by solution: vw＝[1-Cw(P1-P2)]×[Viw-Vg(x％-xi％)]；
S6, subtracting the volume V of water in the liquid phase from the volume of the liquid phase in the PVT main cylinderwObtaining volume V of oil precipitated by reverse coagulation0The calculation formula is as follows:
V0＝Vwt-Vw。
2. the experimental method for volume measurement of retrograde condensate oil containing excessive water condensate gas in claim 1, wherein in S1, sufficient water and condensate gas are added into a sample distributor at high temperature and high pressure to prepare saturated condensate gas required by experiment.
3. The experimental method for volume measurement of retrograde condensate oil containing excessive water condensate gas in claim 1, wherein in S4, the water content of condensate gas in PVT main cylinder is measured by chromatography.
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