准噶尔盆地玛湖凹陷二叠系风城组页岩储层润湿性及其主控因素

doi:10.11743/ogg20220516

Abstract

Abstract:

Shale wettability is of great significance to relative permeability and capillary force of a reservoir， ultimately affecting the hydrocarbon accumulation process in shale as well as the shale oil/gas recovery rate. This study focuses on the wettability characteristics and main control factors of the Permian Fengcheng Formation shale in the Mahu Sag， Junggar Basin， by means of contact angle measurement and spontaneous imbibition plus micro-CT experiment. The results are shown as follows. First， the Fengcheng Formation shale in the Mahu Sag is of generally mixed wettability while prone to oil-wet， and the affinity of different lithofacies to water is listed out from the top， that is， felsic shale， limy felsic shale， dolomitic felsic shale， felsic dolomitic shale， and siltstone. Second， the shale wettability is jointly controlled by multiple factors including organic matter abundance， mineral composition， and pore structure. The shale hydrophobicity is positively correlated with the TOC， dolomite content， negatively with the quartz content， and in staged correlation with the calcite content； the larger the pore volume occupied by macro-pores， the more oil-wet is the shale sample. Third， the connectivity of oil-wet pores tends to grow better along the direction of crack and lamina development. A pore system of clustered type and certain connectivity is prone to form in dolomitic glomerates， which can form an unique shale oil storage space and migration pathway together with the interconnected small pores in the shale matrix. Fourth， the pores less than 1 μm have better connectivity and act as the main migration pathways for shale oil， while those larger than 1 μm with poor connectivity serve as the main storage space for shale oil. Fifth， it is preliminarily concluded that the high-quality shale oil reservoirs are of siltstone and dolomitic felsic shale with well-developed cracks， dolomitic glomerates and laminar structures in the study area according to the wettability characteristics of different lithofacies and sedimentary structure characteristics.

Key words: micro-CT experiment, spontaneous imbibition, contact angle, shale wettability, pore connectivity, shale reservoir, Mahu Sag, Junggar Basin

CLC Number:

TE122.2

Guowei Zheng, Zhiye Gao, Liliang Huang, Zhenxue Jiang, Wenjun He, Jiaqi Chang, Longfei Duan, Weihang Wei, Zhiwei Wang. Wettability of the Permian Fengcheng Formation shale in the Mahu Sag， Junggar Basin， and its main control factors[J]. Oil & Gas Geology, 2022, 43(5): 1206-1220.

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流体	密度/（g·cm^-3）	粘度/（mPa·s）	界面张力/（mN·m^-1）
空气	—	0.018	—
去离子水	1.00	1.002	72.0
正癸烷	0.73	0.840	23.9

样品编号	深度/ m	TOC/ %	S₁/ （mg·g^-1）	S₂/ （mg·g^-1）	T_max/ ℃	矿物组分含量/%							岩相类型
样品编号	深度/ m	TOC/ %	S₁/ （mg·g^-1）	S₂/ （mg·g^-1）	T_max/ ℃	石英	长石	方解石	白云石	粘土矿物	黄铁矿	其他	岩相类型
FC1	4 582.6	0.105 6	0.08	0.07	370	28.8	25.0	25.6	4.7	6.3	9.6	0	块状含灰长英质页岩
FC2	4 591.6	0.616 8	1.44	1.53	440	52.0	12.8	0	33.5	0	1.7	0	层状含云长英质页岩
FC3	4 660.7	1.235 0	2.29	5.41	440	9.0	29.2	1.4	51.8	1.2	7.4	0	层状含长英云质页岩
FC4	4 690.8	1.420 0	1.44	6.82	441	39.7	27.9	1.1	18.5	2.3	8.9	1.6	层状长英质页岩
FC5	4 709.6	0.856 2	0.59	2.61	438	22.9	27.5	10.2	27.0	2.4	8.3	1.7	纹层状含云长英质页岩
FC6	4 720.3	0.575 9	2.61	1.41	437	41.6	21.5	4.5	25.7	0	0	6.7	层状含云长英质页岩
FC7	4 750.6	0.812 5	2.97	2.74	432	46.8	38.8	0.7	9.1	0	4.6	0	层状长英质页岩
FC8	4 758.4	0.719 5	4.59	2.28	418	14.5	41.2	2.3	29.5	0	12.5	0	层状含云长英质页岩
FC9	4 764.4	0.579 2	3.76	2.25	416	32.5	47.4	2.2	7.4	0	5.6	4.9	块状粉砂岩
FC10	4 776.6	0.938 3	0.31	3.92	438	33.8	35.8	4.8	12.9	0	8.8	3.9	纹层状长英质页岩
FC11	4 780.5	0.674 2	0.51	1.70	430	19.4	36.5	15.7	18.5	0	9.9	0	纹层状含云长英质页岩
FC12	4 783.1	0.652 3	5.08	2.36	425	58.7	31.3	2.5	3.1	0	4.4	0	块状粉砂岩
FC13	4 820.5	0.414 9	0.15	0.94	440	20.9	29.9	0	41.0	1.1	7.1	0	层状含云长英质页岩
FC14	4 829.1	0.581 3	0.45	1.42	435	35.4	25.8	0	27.2	3.9	6.2	1.5	层状含云长英质页岩
FC15	4 848.6	0.724 6	4.01	1.81	408	14.2	35.4	10.0	22.8	0	15.0	2.6	块状粉砂岩
FC16	4 858.4	0.672 2	0.63	1.47	434	36.2	19.2	21.3	9.8	5.1	8.4	0	纹层状含灰长英质页岩

样品编号	水接触角/（°）
样品编号	实验1	实验2	实验3	平均值
FC1	90.82	74.72	78.51	81.35
FC2	64.67	62.98	80.80	69.48
FC3	80.16	78.78	93.91	84.28
FC4	77.14	45.45	66.49	63.03
FC5	74.65	75.03	59.60	69.76
FC6	67.65	87.02	101.35	85.34
FC7	79.35	85.86	83.83	83.01
FC8	112.33	113.91	102.09	109.44
FC9	112.87	117.47	93.27	107.87
FC10	68.30	78.94	73.74	73.66
FC11	54.66	60.05	84.62	66.44
FC12	119.27	116.08	103.64	113.00
FC13	89.24	63.40	76.47	76.37
FC14	63.62	81.73	85.02	76.79
FC15	113.61	98.50	111.60	107.90
FC16	64.78	63.91	73.74	67.48

样品编号	水相渗吸斜率		油相渗吸斜率
样品编号	顺层（P₁）	穿层（T₁）	顺层（P₂）	穿层（T₂）
FC1	0.558	0.103	0.178	0.645
FC2	0.328	0.255	0.274	0.483
FC3	0.513	0.338	0.238	0.307
FC4	0.126	0.22	0.345	0.249
FC5	0.228	0.167	0.360	0.220
FC6	0.160	0.090	0.624	0.198
FC7	0.273	0.694	0.700	0.425
FC8	0.296	0.253	0.548	0.588
FC9	0.243	0.434	0.424	0.994
FC10	0.326	0.525	0.540	0.384
FC11	0.351	0.378	0.680	0.380
FC12	0.543	0.188	0.320	0.363
FC13	0.160	0.331	0.271	0.380
FC14	0.392	0.209	0.477	0.125
FC15	0.392	0.386	0.365	0.493
FC16	0.380	0.376	0.714	0.526

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Wettability of the Permian Fengcheng Formation shale in the Mahu Sag， Junggar Basin， and its main control factors

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