深层页岩含气量评价及其差异变化——以四川盆地威荣、永川页岩气田为例

苏海琨; 聂海宽; 郭少斌; 杨振恒; 李东晖; 孙川翔; 卢婷; 刘秘

doi:10.11781/sysydz202205815

深层页岩含气量评价及其差异变化——以四川盆地威荣、永川页岩气田为例

doi: 10.11781/sysydz202205815

苏海琨^{1, 2,},
聂海宽^{2, 3, ,},
郭少斌¹,
杨振恒⁴,
李东晖²,
孙川翔²,
卢婷²,
刘秘²

1.
中国地质大学能源学院, 北京 100083
2.
中国石化石油勘探开发研究院, 北京 102206
3.
页岩油气富集机理与有效开发国家重点实验室, 北京 102206
4.
中国石化石油勘探开发研究院无锡石油地质研究所, 江苏无锡 214126

基金项目:

国家自然科学基金项目 41872124

国家自然科学基金项目 42130803

中国石化股份公司科研项目 P20046-1

详细信息

作者简介:
苏海琨(1997-), 男, 硕士研究生, 从事非常规油气地质研究。E-mail: shk970306@163.com

通讯作者:
聂海宽(1982-), 男, 博士, 研究员, 从事非常规油气地质研究。E-mail: niehk.syky@sinopec.com

中图分类号: TE122.35
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- 文章访问数: 441
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- 被引次数: 0
出版历程
- 收稿日期: 2022-02-14
- 修回日期: 2022-08-13
- 刊出日期: 2022-09-28

Shale gas content evaluation for deep strata and its variation: a case study of Weirong, Yongchuan gas fields in Sichuan Basin

SU Haikun^{1, 2
,},
NIE Haikuan^{2, 3
, ,},
GUO Shaobin¹,
YANG Zhenheng⁴,
LI Donghui²,
SUN Chuanxiang²,
LU Ting²,
LIU Mi²

1.
School of Energy Resources, China University of Geosciences (Beijing), Beijing 100083, China
2.
Petroleum Exploration and Production Research Institute, SINOPEC, Beijing 102206, China
3.
Shale Oil and Gas Enrichment Mechanism and Effective Development of State Key Laboratory, Beijing 102206, China
4.
Wuxi Research Institute of Petroleum Geology, SINOPEC, Wuxi, Jiangsu 214126, China

摘要

摘要: 近年来我国页岩气勘探开发逐渐走向深层，但对高温高压条件下页岩吸附特征、游离气的赋存特征还不清楚，制约了深层页岩气大规模开发。以四川盆地威荣、永川地区深层页岩为研究对象，对不同有机碳含量和孔隙度的样品开展了高温高压(135 ℃、80 MPa)等温吸附实验和孔隙度实验，计算了页岩吸附气量、游离气量和总含气量的理论值，并与实际值进行对比。研究表明：①页岩吸附气含量随着压力增大逐渐增加，当压力大于40 MPa后，吸附气量增加趋于平缓，最大可达4.46 cm³/g。②页岩理论含气量随着地层压力的增加而增加，当地层压力达到80 MPa时总含气量达到最大，此时理论最大值为11.3 cm³/g；计算的游离气含量为6.8 cm³/g，吸附气含量为4.5 cm³/g，分别约占总含气量的60%和40%；游离气/吸附气比例随深度增加逐渐增加。③基于现场解吸实验，实测威页11-1井总含气量最大值为5.95 cm³/g，最小值为3.29 cm³/g，平均为4.52 cm³/g，对比理论含气量10.3 cm³/g，表明有近50%的气体在抬升过程中散失，同时一定程度上也说明了深层页岩气保存条件的复杂性，建议加强对保存条件的研究。
- 吸附气 /
- 游离气 /
- 深层页岩气 /
- 含气量 /
- 定量评价 /
- 四川盆地
Abstract: The exploration and development of shale gas in China are recently focusing on the deep layers. However, the occurring characteristics of shale gas under high temperature and high pressure are not clear, which imposes great restrictions to deep shale gas development on a massive scale. Taking the deep shale in Weirong and Yongchuan regions of Sichuan Basin as research objects, for core samples with different organic carbon content and porosity, the isothermal adsorption experiments and porosity testing at high temperature and high pressure (135 ℃, 80 MPa) were carried out, and the theoretical values of shale adsorption gas, free gas and total gas content and compared with actual values. Results show that: (1) The content of adsorbed gas in deep shale increases gradually with pressure growing up. When the pressure surpasses 40 MPa, the increment flattens out, making 4.46 cm³/g the maximum of adsorbed gas content. (2) The theoretical gas content of shale increases with the growing formation pressure. The total gas content reaches its maximum 11.3 cm³/g under 80 MPa, which is made up with calculated free gas with an average of 6.8 cm³/g and adsorbed gas with an average of 4.5 cm³/g, accounting for about 60% and 40% of the total gas content, [JP]respectively. The ratio of free gas versus adsorbed gas gets larger with a greater buried depth. (3) Based on field desorption experiment, the actual measurement maximum gas content of well Weiye 11-1 is 5.95cm³/g, the minimum value is 3.29cm³/g, and the average content is 4.52 cm³/g. Compared with the theoretical value of 10.3 cm³/g, the result indicates that nearly 50% of gas leaked in the process of formation uplift, displaying the complexity of the deep shale gas preservation conditions. It is recommended to strengthen research on preservation conditions.
- adsorbed gas /
- free gas /
- deep shale gas /
- gas content /
- quantitative evaluation /
- Sichuan Basin

HTML全文

图 1 容积法等温吸附实验仪器(a-b)及原理图(c)

Figure 1. Experiment instrument(a-b) and schematic diagram(c) of isothermal adsorption with volumetric method

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图 2 孔隙度实验装置

Figure 2. Porosity test device

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图 3 四川盆地威荣、永川地区龙马溪组深层页岩等温吸附曲线(135 ℃, 0~80 MPa)

Figure 3. Isothermal adsorption curves of deep shale of Longmaxi Formation in Weirong and Yongchuan regions, Sichuan Basin (135 ℃, 0-80 MPa)

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图 4 四川盆地威荣、永川地区龙马溪组深层页岩孔隙度变化(10~70 MPa, 60~120 ℃)

Figure 4. Porosity changes of deep shale in Longmaxi Formation in Weirong and Yongchuan regions, Sichuan Basin (10-70 MPa, 60-120 ℃)

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图 5 四川盆地威荣、永川地区WY23-1井和YY2井龙马溪组页岩游离气含量(135 ℃，0~80 MPa)

Figure 5. Shale free gas content in Longmaxi Formation, wells WY23-1 and YY2 in Weirong and Yongchuan regions, Sichuan Basin (135 ℃, 0-80 MPa)

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图 6 四川盆地威荣、永川地区龙马溪组页岩含气量图版(135 ℃, 0~80 MPa)

Figure 6. Shale gas content of Longmaxi Formation in Weirong and Yongchuan regions, Sichuan Basin (135 ℃, 0-80 MPa)

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图 7 四川盆地威荣地区WY11-1井实际含气量

Figure 7. Actual gas content of well WY11-1, Weirong region, Sichuan Basin

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表 1 四川盆地威荣、永川地区页岩样品信息

Table 1. Information of shale samples in Weirong and Yongchuan regions, Sichuan Basin

岩样编号	井号	深度/m	目数	ω(TOC)/%	实验温度/℃	压力范围/MPa
样品1	WY23-1	3 847.65	60~80	4.0	135	0~80
样品2	WY23-1	3 847.15	60~80	4.0	135	0~80
样品3	YY2	4 089.97	60~80	5.0	135	0~80
注：实验参照国家标准《页岩甲烷等温吸附测定容积法：GB/T 35210.1—2017》。

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表 2 不同温压下的Z值

Table 2. Z value at different temperature and pressure

压力/MPa	温度/℃	Z值
0.5	135	0.998
1	135	0.997
2	135	0.995
4	135	0.988
8	135	0.980
12	135	0.975
18	135	0.983
24	135	0.987
30	135	1.040
40	135	1.060
50	135	1.180
65	135	1.310
80	135	1.465

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表 3 四川盆地威荣地区WY11-1现场解吸气含量

Table 3. Site desorbed gas content of well WY11-1, Weirong region, Sichuan Basin

样品号	深度/ m	解吸气量/ (cm³·g^-1)	解吸时间/ min	解吸速率/ (cm³·min^-1)	岩心质量/ g	提钻时间/ min	地表暴露时间/ min
样品1	3 746.35	0.874	731	3.89	3 256	460	60
样品2	3 747.09	0.826	740	3.87	3 467	460	60
样品3	3 748.25	0.924	728	4.30	3 392	460	60
样品4	3 749.07	0.663	726	2.92	3 204	460	60
样品5	3 750.30	0.676	724	2.95	3 163	460	60
样品6	3 751.45	1.027	723	5.00	3 523	460	60
样品7	3 752.65	1.001	721	4.16	3 002	460	60
样品8	3 754.34	0.920	719	3.97	3 104	460	60
样品9	3 755.60	1.290	661	6.81	3 489	390	60
样品10	3 756.73	1.211	660	5.98	3 261	390	60

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