生烃伴生酸性流体对碳酸盐岩储层改造效应的模拟实验

doi:10.11743/ogg20200120

Abstract

Abstract:

The deep and ultra-deep carbonate reservoirs are the major targets of exploration, but their prediction is quite complicated due to the poor understanding of their formation and maintenance mechanism. It is essential to perform hydrocarbon generation and dissolution simulation experiments to quantitatively and qualitatively clarify the evolution process of source rocks and carbonate reservoirs in deep layers. In this study, a series of experiments were conducted with the limestone samples from the Ordovician Yingshan Formation in the Tarim Basin, and the low maturity source rock samples from Luquan County, Yunnan Province, via self-designed hydrocarbon generation and dissolution simulation equipments. The controlling factors accounting for the alteration of carbonate reservoirs and dissolution modification process by the complex acidic fluids associated with hydrocarbon generation in medium-to-deep burial environments were investigated using petrographic and geochemical methods. In the meantime, the transformation mechanism of surrounding carbonate reservoirs during hydrocarbon generation process of source rocks was explored. The results show that: during the medium-deep burial stage, acidic fluids including organic acid and CO₂ associated with thermal evolution of source rocks could dissolve carbonate reservoirs, expanding their reservoir space, and thus improving porosity. Dissolution would decrease with the increasing burial depth. Whether the migrating fluids could improve the physical properties of reservoir largely depends on such factors as calcium carbonate saturation, fluid velocity, water/rock ratio, and original pore structure. The study can provide a theoretical basis for prediction of high-quality carbonate reservoirs in deep and ultra-deep formations.

Key words: organic acidic fluid, burial dissolution, deep-to-ultra-deep formation, carbonate rock, Ordovician, Tarim Basin

CLC Number:

TE122.2

Qian Ding, Zhiliang He, Jingbin Wang, Dongya Zhu. Simulation experiment of carbonate reservoir modification by source rock-derived acidic fluids[J]. Oil & Gas Geology, 2020, 41(1): 223-234.

Figures/Tables 15

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References 38

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生烃模拟					溶蚀模拟
埋深/m	R_o/%	地温梯度/(℃·km^-1)	模拟生烃温度/℃	体系	埋深/m	温度梯度/(℃·km^-1)	溶蚀温度/℃	溶蚀压力/MPa	体系
3 100	0.90	32	330	封	2 000	32	89	20	开
4 000	1.12	32	350	闭	3 300	32	131	33	放
4 900	1.39	32	375	体	4 000	32	153	40	体
5 700	1.63	32	420	系	4 700	32	169	47	系

样品编号	岩性	层位	TOC/%	有机质类型	T_max/℃	HI/(mg·g^-1)	生烃潜力
LQ-1-2	泥灰岩	D	5.14	Ⅱ₁	427	377	好
LQ-2-2	泥灰岩	D	5.39	Ⅱ₁	431	435	好
LQ-3-2	泥灰岩	D	5.82	Ⅱ₁	431	413	好

生烃温度/℃	溶蚀温度/℃	溶蚀实验前					溶蚀实验后					溶蚀实验前、后变化率/%
		溶蚀前质量m₁	CO₂/%	阳离子含量/(mg·L^-1)			溶蚀后质量m₂	CO₂/%	阳离子含量/(mg·L^-1)			质量	CO₂相对含量	Mg²⁺	Ca²⁺	Ca²⁺+Mg²⁺
		溶蚀前质量m₁	CO₂/%	Mg²⁺	Ca²⁺	Ca²⁺+Mg²⁺	溶蚀后质量m₂	CO₂/%	Mg²⁺	Ca²⁺	Ca²⁺+Mg²⁺	质量	CO₂相对含量	Mg²⁺	Ca²⁺	Ca²⁺+Mg²⁺
330	89	34.734 38	58.68	2.46	87.7	90.16	34.562 87	43.44	9.09	203.0	212.09	0.497	25.97	2.70	1.31	1.35
350	131	37.173 29	43.05	2.28	55.4	57.68	37.085 78	36.42	6.12	106.0	112.12	0.240	15.39	1.68	0.91	0.94
375	153	40.961 26	37.57	4.22	93.9	98.12	40.940 60	34.16	9.63	175.0	184.63	0.050	9.07	1.28	0.86	0.88
420	169	46.957 84	38.01	2.87	16.2	19.07	46.943 57	34.74	6.05	31.1	37.15	0.030	8.61	1.11	0.92	0.95

离子含量/(mg·L^-1)	生烃温度/℃	溶蚀温度/℃	时间/h
离子含量/(mg·L^-1)	生烃温度/℃	溶蚀温度/℃	0.5	1.0	1.5	2.0	2.5	3.0	3.5	4.0	4.5	5.0	5.5	6.0	6.5
Ca²⁺+Mg²⁺	330	89	240.42	-	237.55	-	211.12	-	214.96	-	242.81	-	266.37	-	-
	350	131	153.14	-	172.64	-	259.08	-	231.73	-	211.76	-	245.42	-	246.01
	375	153	153.69	-	-	137.71	-	-	193.30	-	200.90	-	-	291.40	-
	420	169	-	-	145.42	-	-	169.85	-	-	201.54	-	-	226.93	-

生烃温度/℃	溶蚀温度/℃	反应前孔隙度/%	反应前渗透率/(10^-3 μm²)	反应后孔隙度/%	反应后渗透率/(10^-3 μm²)	孔隙度变化率/%	渗透率变化率/%
330	89	1.49	1.300	-	-	-	-
350	131	1.43	0.733	1.54	-	7.7	-
375	153	1.00	0.740	1.10	0.157	10.0	-79
420	169	0.89	1.082	1.03	0.133	16.0	-88

Simulation experiment of carbonate reservoir modification by source rock-derived acidic fluids

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