塔里木盆地超深油气藏流体相行为变化特征

doi:10.11743/ogg20230419

Abstract

Abstract:

The complex geological conditions of ultra-deep reservoirs lead to the diversity and variability of fluid phase characteristics， imposing great challenges to oil and gas exploration and development. This study established a method for studying the fluid phase behaviors of ultra-deep oil and gas reservoirs in the Shunbei area of Tarim Basin through the equal-time-interval downhole sampling to obtain formation fluid samples at different production stages. During the process， the causes of asphaltene deposition in gas condensate wells were revealed by experiments of asphaltene deposition during commingled recovery of hydrocarbon fluids charged in two stages， and suggestions for optimal recovery scheme were put forward from the point of view of fluid phase change. The results show that the fault-karst bodies encountered by Well D1 in the Shunbei No.4 fault zone are receivers of deep oil supply， showing a vertical composition gradient with gas upon oil. The hydrocarbon fluid phase changes first from condensate gas to gas of near critical condensate saturation and finally to gas condensate （volatile oil）， with the latter being the result of mixing of hydrocarbon fluids charged in two stages： the crude contained in condensate gas and the light components extracted by gas from deep crude. The fault-karst body penetrated by Well D2 contains only a closed gas reservoir with hydrocarbon fluid phase changing in a way similar to that of a conventional condensate gas reservoir. The asphaltene deposition in Well D1 is suggested to be related to its commingled production with deep crude， which could lead to the significant increase in initiation pressure and volume of asphaltene deposition within the reservoir and the wellbore. A production scheme that extracts oil before gas with reservoir pressure well controlled is therefore recommended for such gas-over-oil fault-karst reservoirs. The results are of great reference value for the exploration and production of ultra-deep oil and gas reservoirs.

Key words: asphaltene, two-stage charging, phase behavior, fault-karst body, condensate gas, ultra-deep layer, Tarim Basin

CLC Number:

TE372

Wei HU, Ting XU, Yang YANG, Zengmin LUN, Zongyu LI, Zhijiang KANG, Ruiming ZHAO, Shengwen MEI. Fluid phases and behaviors in ultra-deep oil and gas reservoirs， Tarim Basin[J]. Oil & Gas Geology, 2023, 44(4): 1044-1053.

Figures/Tables 13

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流体类型	溶解气油比/（m³/m³）	地层流体体积系数	地层流体饱和压力/MPa	油罐油SARA族组分含量/%				AOP（沥青质沉积起始压力）/MPa	沥青质最大沉积量/%
流体类型	溶解气油比/（m³/m³）	地层流体体积系数	地层流体饱和压力/MPa	饱和烃	芳香烃	胶质	沥青质	AOP（沥青质沉积起始压力）/MPa	沥青质最大沉积量/%
挥发油	193.6	1.474	32.0	55.2	12.3	6.8	2.7	38.9	4.5
凝析气（D1井）	962.3	2.763	40.0	71.5	5.7	2.4	1.3	—	—
混合流体	781.2	3.513	39.3	67.4	13.7	7.3	4.2	50.8	18.9

取样次序	取样点压力/MPa	取样点温度/℃	取样深度/m	露点压力/MPa	气油比/（m³/m³）	地露压差/MPa	油罐油分子量/ （g/mol）	油罐油密度（20℃）/（g/cm³）	凝析油含量/ （g/cm³）	最大反凝析液量百分数/%	井流物组分含量/%
取样次序	取样点压力/MPa	取样点温度/℃	取样深度/m	露点压力/MPa	气油比/（m³/m³）	地露压差/MPa	油罐油分子量/ （g/mol）	油罐油密度（20℃）/（g/cm³）	凝析油含量/ （g/cm³）	最大反凝析液量百分数/%	C₁+N₂	C₂-C₆+CO₂	C₇₊
1	56.56	148.3	4 500	37.17	1 119.0	53.38	119.0	0.749 6	634.7	16.96	76.24	13.21	7.14
2	60.17	148.3	4 500	38.40	1 012.0	52.15	148.0	0.786 6	696.1	17.68	76.30	13.79	9.90
3	58.27	148.3	4 500	40.00	962.3	50.55	151.6	0.787 8	865.1	19.24	77.68	9.55	12.77

取样次序	取样点压力/MPa	取样点温度/℃	取样深度/m	露点压力/MPa	气油比/ （m³/m³）	地露压差/MPa	油罐油分子量/（g/mol）	油罐油密度（20℃）/ （g/cm³）	凝析油含量/ （g/cm³）	最大反凝析液量百分数/%	井流物组分含量/%
取样次序	取样点压力/MPa	取样点温度/℃	取样深度/m	露点压力/MPa	气油比/ （m³/m³）	地露压差/MPa	油罐油分子量/（g/mol）	油罐油密度（20℃）/ （g/cm³）	凝析油含量/ （g/cm³）	最大反凝析液量百分数/%	C₁+N₂	C₂-C₆+CO₂	C₇₊
1	66.7	139	6100	47.19	1036.8	33.04	119.2	0.790 6	605.0	21.60	77.04	13.43	9.32
2	47.5	139	6100	45.50	1584.0	1.83	112.3	0.784 2	477.9	8.40	82.64	10.95	6.39
3	37.6	139	6100	29.25	1914.3	已反凝析	105.5	0.778 5	229.2	4.42	88.12	8.60	3.28

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Fluid phases and behaviors in ultra-deep oil and gas reservoirs， Tarim Basin

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