Mechanisms of liquid hydrocarbon evolution and preservation in ultra-deep Ordovician reservoirs, northern Tarim Basin: Insights from laboratory simulation experiments

doi:10.13745/j.esf.sf.2023.2.13

Abstract

Abstract:

A number of oil and volatile oil reservoirs have been discovered in the Cambrian-Ordovician in the northern Tarim Basin expanding the depth scale of hydrocarbon-liquid window. The deep and ultra-deep reservoirs span multiple tectonic periods and have undergone complex tectonic, burial and thermal evolution. To understand the mechanisms of liquid hydrocarbon formation and maintenance, the burial history of key stratigraphic sequences, oil and gas formation and dating, hydrocarbon inclusions and crude oil stability have been investigated. However, in-depth studies on the interactions between hydrocarbons and mineral matrix/formation water and their effects on reservoir evolution and preservation are still lacking. In this paper, laboratory simulation experiments are carried out using constrains from the burial, thermal and paleopressure history of the Shuntuo Guole region, Tarim Basin, and the thermal history of reservoir fluids is reconstructed under conditions mimicking the natural occurrence state, overburden pressure, fluid properties and pressure regimes of the underground reservoirs. The results show that the reservoir temperature controls crude oil cracking, where the highest paleo-temperature and duration of hydrocarbon accumulation dictate the phase behavior of reservoir fluids today. When VR_o is less than 2.0%, crude oil cracking is delayed under effects of formation water and limestone matrix, which is conducive to liquid hydrocarbon preservation in a reservoir. Based on preliminary evaluation, the estimated Oil Preservation Indexes (OPI) for early filled crude oil in Shunbei and Shunnan are 67%-100% and 17%-50%, respectively, which suggests the depth limit for significant hydrocarbon accumulation in Shunbei can be extended to ~10000 m.

Key words: ultra-deep sequence, liquid hydrocarbon, preservation mechanism, simulation experiment, Tarim Basin

CLC Number:

CHEN Qianglu, MA Zhongliang, LI Maowen, XI Binbin, ZHENG Lunju, ZHUANG Xinbing, Yuan Kun, MA Xiaoxiao, XU Jin. Mechanisms of liquid hydrocarbon evolution and preservation in ultra-deep Ordovician reservoirs, northern Tarim Basin: Insights from laboratory simulation experiments[J]. Earth Science Frontiers, 2023, 30(6): 329-340.

Figures/Tables 15

Fig.1 Geographic location, tectonic setting and geological profile of the study area. Modified after [2].

Fig.2 Burial and thermal evolution history graphs for the petroleum systems in Shuntuguole area

Table 1 Mineral composition of limestone sample from well SHB2

黏土含量/ %	石英含量/ %	斜长石含量/ %	方解石含量/ %	白云石含量/ %	菱铁矿含量/ %	重晶石含量/ %	石膏含量/ %
3.8	2.4	0.5	92.4	0.6	0.1	0.1	0.1

Table 2 Chemical composition of formation water in the study area

ρ(Cl^-)/(mg·L^-1)	ρ(S $O 4 2 -$ )/(mg·L^-1)	ρ(OH^-)/(mg·L^-1)	ρ(C $O 3 2 -$ )/(mg·L^-1)	ρ(HC $O 3 -$ )/(mg·L^-1)	pH值
139 443.57	195.08	0.00	0.00	95.10	5.5
ρ(K)/(mg·L^-1)	ρ(Na)/(mg·L^-1)	ρ(Ca)/(mg·L^-1)	ρ(Mg)/(mg·L^-1)	ρ(Sr)/(mg·L^-1)	ρ(Ba)/(mg·L^-1)
1 903.91	72 007.40	13 126.40	939.47	372.98	10.14

Table 2 Chemical composition of formation water in the study area

ρ(Cl^-)/(mg·L^-1)	ρ(S $O 4 2 -$ )/(mg·L^-1)	ρ(OH^-)/(mg·L^-1)	ρ(C $O 3 2 -$ )/(mg·L^-1)	ρ(HC $O 3 -$ )/(mg·L^-1)	pH值
139 443.57	195.08	0.00	0.00	95.10	5.5
ρ(K)/(mg·L^-1)	ρ(Na)/(mg·L^-1)	ρ(Ca)/(mg·L^-1)	ρ(Mg)/(mg·L^-1)	ρ(Sr)/(mg·L^-1)	ρ(Ba)/(mg·L^-1)
1 903.91	72 007.40	13 126.40	939.47	372.98	10.14

Fig.3 Chromatogram of crude oil from well TK686

Table 3 Parameters used in the simulation experiments

类别	体系	温度/℃	VR_o/%	静岩压力/MPa	流体压力/MPa	恒温时间/h
系列A	单一烃体系	350	1.30		0.1	48
		400	2.10		2.6	48
		425	2.50		3.2	48
		450	2.64		3.3	48
		500	3.06		5.7	48
系列B	烃-岩体系	350	1.30	96.0	0.4	48
		400	2.10	152.0	5.8	48
		425	2.50	159.0	7.6	48
		450	2.64	171.0	10.6	48
		500	3.06	208.0	16.6	48
系列C	烃-水-岩体系	350	1.30	96.0	39.0	48
		400	2.10	152.0	62.0	48
		425	2.50	159.0	65.0	48
		450	2.64	171.0	70.0	48
		500	3.06	208.0	85.0	48
系列D	烃-水-岩体系	400	2.10	152.0	62.0	48
		400	2.10	152.0	62.0	96
		400	2.10	152.0	62.0	144
系列E	烃-水-岩体系	400	2.10	127.0	52.0	48
		400	2.10	152.0	62.0	48
		425	2.50	139.0	57.0	48
		425	2.50	159.0	65.0	48

Fig.4 Hydrocarbon gas yield under different experimental systems

Fig.5 Change of residual oil/hydrocarbon gas yields with time duration under isothermal condition

Fig.6 Residual oil yields under different p-T conditions

Fig.7 Change of compositional profile of saturated hydrocarbon with pressure in residual oil at 400 ℃ simulation temperature

Fig.8 OPI vs VRo plot between different experimental systems

Fig.9 GGI (Gas Generation Index) vs. VRo plot between different experimental systems

Fig.10 BGI (Bitumen Generation Index) vs. VRo plot between different experimental systems

Fig.11 Compositional profiles of saturated hydrocarbons in residual oil (VRo<2.0%) between different experimental systems

Fig.12 Quantitative evaluation of liquid hydrocarbon preservation capacity

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