Organic Geochemical Characteristics of Source Rocks of Permian Lucaogou Formation in Southeastern of Junggar Basin

doi:10.19657/j.geoscience.1000-8527.2022.220

Abstract

Abstract:

Thermal evolution and petroleum potential of the source rocks as well as origin of the hydrocarbons discovered in the southeast Junggar Basin are not clear enough. Geochemical methods including Rock-Eval, GC-MS and carbon isotopic analysis are used to unravel relevant issues. The results show that there are obvious differences in organic matter abundance and kerogen types of the source rocks form the Permian Lucaogou Formation (P₂l) with varying thermal maturity. The total organic carbon (TOC) of the P₂l source rocks is ranged in 0.43 %-12.89 % (averaged 2.84 %), and the petroleum potential of (S₁+S₂) is in the range of 0.52-77.24 mg/g. The source rock quality can be reduced from “excellent” grade at low maturity to “moderate-poor” grade at high maturity (R_c≈0.54%-1.93%). The type of organic matter varies from type Ⅰ-Ⅱ at low maturity to type Ⅱ₂-Ⅲ at high maturity, indicating that it is necessary to properly restores the original value of the kerogen type and hydrocarbon generation potential for the high to over-mature source rocks. Distinguished characteristics of the biomarkers of the P₂l source rocks were observed: a weak advantage of pristine over phytane was observed with the ratios of Pr/Ph ranging from 0.92 to 1.81 (averaged 1.22), indicating a weakly reduced lacustrine sedimentary environment; the relative abundance of C₂₇-,C₂₈-, and C₂₉-regular steranes showed an ascending linear pattern. The source rocks are also characterized by high relative abundance of C₂₈-regular steranes (with the mean value of the C₂₈/ C₂₉-regular steranes ratio to be 0.96), low relative abundance of homohopanes with gammacerane developed, while the abundance of hopanes is low and gammacerane is moderately developed in the source rocks,indicating saline and/or water stratified paleoenvironment of the P₂l source rocks when deposited. Oil-oil and oil-source rock correlations showed that the crude oils from the Lucaogou Formation were mainly derived from the P₂l source rocks. The geochemical and geological investigations of this study shows that the P₂l source rocks with a relatively wide range of burial depth and therefore a wide range of maturity level were well developed, suggesting an excellent hydrocarbons generation potential in the area investigated. It indicates great petroleum exploration prospects for deep and shallow horizons.

Key words: Lucaogou Formation, hydrocarbon generation potential, biomarker, Junggar Basin

CLC Number:

TE122.1

ZHANG Hanjing, LI Sumei, GAO Yongjin, ZHANG Lin, KE Changwei. Organic Geochemical Characteristics of Source Rocks of Permian Lucaogou Formation in Southeastern of Junggar Basin[J]. Geoscience, 2022, 36(06): 1538-1550.

Figures/Tables 11

Fig.1 Regional structural diagram and structural section of the southeastern Junggar Basin

Table 1 Statistical table of Rock-Eval and TOC for the source rocks analyzed

编号	井号	层位	岩性	深度/ m	TOC/ %	T_max /℃	(S₁+S₂)/ (mg/g)	PI	HI	烃指数/ (mg/g TOC)	降解率 /%	((S₁+S₂)/ TOC)/ (mg/gTOC)	氯仿“A” /%	烃源岩评价^*
1	BC1	P₂l	深灰色泥岩	54.68	12.89	455	77.24	0.01	593	1.463	49.73	5.99	0.195	极好-极好-好
2	BC1	P₂l	深灰色泥岩	166	-	-	-	-	-	-	-	-	-	-
3	BC1	P₂l	灰黑色泥岩	225.7	6.83	448	28.82	0.06	398	0.713	34.99	4.22	0.096	极好-极好-中
4	BC1	P₂l	灰黑色泥岩	308	-	-	-	-	-	-	-	-	-	-
5	BC1	P₂l	灰黑色泥岩	394.08	-	-	-	-	-	-	-	-	-	-
6	BC1	P₂l	灰黑色泥岩	506.11	3.76	451	12.3	0.07	302	0.182	27.11	3.27	0.061	极好-好-中
7	BC1	P₂l	灰黑色泥岩	623.53	-	-	-	-	-	-	-	-	-	-
8	BC1	P₂l	灰黑色泥岩	718.44	2.94	451	4.03	0.18	113	0.100	11.22	1.37	0.081	极好-极好-中
9	BC1	P₂l	灰黑色泥岩	868.56	2.12	443	5.04	0.21	189	0.120	19.85	2.38	0.332	极好-中-极好
10	BC1	P₂l	灰黑色泥岩	965.85	-	-	-	-	-	-	-	-	-	-
11	XJC1	P₃w	深灰色云质泥岩	2 912	0.43	453	0.27	0.26	47	0.002	4.69	0.63	0.013	差-差-非
12	XJC1	P₃w	深灰色泥岩	2 918	0.44	458	0.18	0.28	30	0.002	2.29	0.41	0.013	中-差-非
13	XJC1	P₂l₂	深灰色泥岩	3 814.7	0.90	467	0.52	0.25	44	0.003	4.47	0.58	0.021	中-非-差
14	XJC1	P₂l₂	深灰色泥岩	3 974.25	2.49	492	1.68	0.1	61	0.004	5.62	0.67	0.023	极好-非-差
15	XJC1	P₂l₂	深灰-灰黑色碳质泥岩	4 080	0.50	473	0.33	0.27	48	0.002	6.04	0.66	0.017	差-差-差
16	XJC1	P₂l₂	深灰色-灰黑色泥岩	4 146.5	0.94	478	0.84	0.42	52	0.008	7.42	0.89	0.021	中-非-差
17	XJC1	P₂l₂	灰黑色泥岩	4 174.4	-	-	-	-	-	-	-	-	-	-
18	XJC1	P₂l₂	深灰色泥岩	4 198.7	0.90	467	1.05	0.5	58	0.013	10.05	1.17	0.038	中-非-差
19	XJC1	P₂l₂	深灰色泥岩	4 205	-	-	-	-	-	-	-	-	-	-
20	XJC1	P₂l₂	深灰色泥岩	4 235.2	0.79	481	0.79	0.41	60	0.008	8.86	1.00	0.022	中-非-非
21	XJC1	P₂l₁	灰黑色泥岩	4 574.8	4.55	464	3.91	0.09	78	0.008	7.03	0.86	0.081	极好-中-中
22	XJC1	P₂l₁	灰黑色泥岩	4 576.8	2.82	467	2.1	0.09	68	0.004	6.03	0.74	0.022	极好-中-差
23	XJC1	P₂l₁	深灰色泥岩	4 672	1.51	477	0.58	0.28	28	0.003	3.32	0.39	0.026	好-非-差
24	XJC1	P₂l₁	深灰-灰黑色泥岩	4 677	3.61	478	0.78	0.22	17	0.004	1.66	0.22	0.016	极好-非-差

Table 1 Statistical table of Rock-Eval and TOC for the source rocks analyzed

编号	井号	层位	岩性	深度/ m	TOC/ %	T_max /℃	(S₁+S₂)/ (mg/g)	PI	HI	烃指数/ (mg/g TOC)	降解率 /%	((S₁+S₂)/ TOC)/ (mg/gTOC)	氯仿“A” /%	烃源岩评价^*
1	BC1	P₂l	深灰色泥岩	54.68	12.89	455	77.24	0.01	593	1.463	49.73	5.99	0.195	极好-极好-好
2	BC1	P₂l	深灰色泥岩	166	-	-	-	-	-	-	-	-	-	-
3	BC1	P₂l	灰黑色泥岩	225.7	6.83	448	28.82	0.06	398	0.713	34.99	4.22	0.096	极好-极好-中
4	BC1	P₂l	灰黑色泥岩	308	-	-	-	-	-	-	-	-	-	-
5	BC1	P₂l	灰黑色泥岩	394.08	-	-	-	-	-	-	-	-	-	-
6	BC1	P₂l	灰黑色泥岩	506.11	3.76	451	12.3	0.07	302	0.182	27.11	3.27	0.061	极好-好-中
7	BC1	P₂l	灰黑色泥岩	623.53	-	-	-	-	-	-	-	-	-	-
8	BC1	P₂l	灰黑色泥岩	718.44	2.94	451	4.03	0.18	113	0.100	11.22	1.37	0.081	极好-极好-中
9	BC1	P₂l	灰黑色泥岩	868.56	2.12	443	5.04	0.21	189	0.120	19.85	2.38	0.332	极好-中-极好
10	BC1	P₂l	灰黑色泥岩	965.85	-	-	-	-	-	-	-	-	-	-
11	XJC1	P₃w	深灰色云质泥岩	2 912	0.43	453	0.27	0.26	47	0.002	4.69	0.63	0.013	差-差-非
12	XJC1	P₃w	深灰色泥岩	2 918	0.44	458	0.18	0.28	30	0.002	2.29	0.41	0.013	中-差-非
13	XJC1	P₂l₂	深灰色泥岩	3 814.7	0.90	467	0.52	0.25	44	0.003	4.47	0.58	0.021	中-非-差
14	XJC1	P₂l₂	深灰色泥岩	3 974.25	2.49	492	1.68	0.1	61	0.004	5.62	0.67	0.023	极好-非-差
15	XJC1	P₂l₂	深灰-灰黑色碳质泥岩	4 080	0.50	473	0.33	0.27	48	0.002	6.04	0.66	0.017	差-差-差
16	XJC1	P₂l₂	深灰色-灰黑色泥岩	4 146.5	0.94	478	0.84	0.42	52	0.008	7.42	0.89	0.021	中-非-差
17	XJC1	P₂l₂	灰黑色泥岩	4 174.4	-	-	-	-	-	-	-	-	-	-
18	XJC1	P₂l₂	深灰色泥岩	4 198.7	0.90	467	1.05	0.5	58	0.013	10.05	1.17	0.038	中-非-差
19	XJC1	P₂l₂	深灰色泥岩	4 205	-	-	-	-	-	-	-	-	-	-
20	XJC1	P₂l₂	深灰色泥岩	4 235.2	0.79	481	0.79	0.41	60	0.008	8.86	1.00	0.022	中-非-非
21	XJC1	P₂l₁	灰黑色泥岩	4 574.8	4.55	464	3.91	0.09	78	0.008	7.03	0.86	0.081	极好-中-中
22	XJC1	P₂l₁	灰黑色泥岩	4 576.8	2.82	467	2.1	0.09	68	0.004	6.03	0.74	0.022	极好-中-差
23	XJC1	P₂l₁	深灰色泥岩	4 672	1.51	477	0.58	0.28	28	0.003	3.32	0.39	0.026	好-非-差
24	XJC1	P₂l₁	深灰-灰黑色泥岩	4 677	3.61	478	0.78	0.22	17	0.004	1.66	0.22	0.016	极好-非-差

Fig.2 Distribution characteristics of basic geochemical parameters of partial source rocks of the Permian Lucaogou Formation in the southeastern Junggar Basin

Fig.3 Organic matter abundance and maturity of the source rocks in the southeastern Junggar Basin

Fig.4 Tmax-degradation rate (a), Tmax-hydrogen index diagram (b)

Fig.5 Total ion chromatograms (TIC) of saturated fractions from selected source rocks and crude oils

Table 2 Biomarker parameters of the source rocks from XJC1 and BC1 wells in the southeastern Junggar Basin

编号	井号	井深 /m	层位	$C 21 -$ / $C 22 +$	Pr/Ph	CPI	OEP	αββ	C₂₉ 20S	G/ C₃₀H	C₂₈/ C₂₉	Tri/ Pent	C₂₇/ %	C₂₈/ %	C₂₉/ %	DBT/P	F₁	F₂	R_c
1	XJC1	2 912	P₃w	0.26	0.68	1.3	1.1	0.39	0.51	0.76	0.77	0.44	29.9	27.8	42.3	0.14	0.45	0.24	0.79
2	XJC1	2 918	P₃w	0.24	0.61	1.2	1.0	0.44	0.51	0.49	0.58	0.32	27.1	25.4	47.5	0.12	0.46	0.25	0.84
3	XJC1	3 814	P₂l₂	1.05	1.81	1.0	1.0	0.58	0.47	0.47	0.59	0.67	40.6	20.4	39.0	0.03	0.63	0.36	1.16
4	XJC1	3 974	P₂l₂	1.05	0.92	1.1	1.0	0.53	0.51	0.20	0.62	0.78	34.5	22.3	43.2	0.08	0.71	0.41	1.12
5	XJC1	4 080	P₂l₂	1.15	1.36	0.9	1.1	0.39	0.56	0.23	0.57	1.18	44.2	27.7	28.1	0.04	0.73	0.43	1.42
6	XJC1	4 145	P₂l₂	1.10	1.30	1.1	1.1	0.57	0.57	0.14	1.38	1.47	43.2	33.3	23.4	0.01	0.73	0.46	1.51
7	XJC1	4 174	P₂l₂	0.83	1.13	1.2	1.0	0.55	0.53	0.14	1.19	1.15	62.7	19.7	17.6	0.02	0.76	0.45	1.82
8	XJC1	4 198	P₂l₂	0.99	1.25	1.3	1.1	0.57	0.47	0.16	1.01	1.43	47.0	27.8	25.2	0.01	0.76	0.47	1.93
9	XJC1	4 205	P₂l₂	0.84	1.23	1.2	1.1	0.45	0.45	0.23	2.09	1.00	52.6	32.4	15.0	0.02	0.74	0.44	1.80
10	XJC1	4 235	P₂l₂	0.95	1.35	1.1	1.0	0.40	0.60	0.19	0.31	2.24	40.4	23.3	36.3	0.01	0.78	0.47	1.73
11	XJC1	4 547	P₂l₁	1.83	1.27	1.1	1.0	0.56	0.51	0.20	1.11	11.6	19.0	40.0	40.9	0.01	0.60	0.33	1.79
12	XJC1	4 576	P₂l₁	1.14	1.24	1.1	1.0	0.54	0.50	0.18	0.97	4.51	25.6	35.2	39.3	0.01	0.64	0.36	1.74
13	XJC1	4 672	P₂l₁	0.88	1.24	0.9	1.0	0.55	0.49	0.24	0.88	2.17	20.9	35.9	43.2	0.01	0.78	0.48	1.29
14	XJC1	4 677	P₂l₁	0.89	1.10	1.1	1.0	0.58	0.50	0.19	0.92	4.60	24.1	37.1	38.8	0.01	0.79	0.48	1.23
15	BC1	54	P₂l	-	-	-	-	0.55	0.52	0.16	1.05	0.74	16.3	42.6	41.1	0.03	0.19	0.10	0.57
16	BC1	166	P₂l	1.26	1.18	-	-	0.54	0.54	0.19	0.91	0.51	16.8	40.2	43.0	0.04	0.31	0.14	0.61
17	BC1	225	P₂l	0.95	1.18	1.1	-	0.47	0.57	0.18	0.77	0.32	19.4	36.0	44.6	0.05	0.25	0.14	0.54
18	BC1	308	P₂l	0.56	1.07	1.0	1.2	0.51	0.56	0.16	0.98	0.57	19.4	40.2	40.4	0.04	0.31	0.15	0.59
19	BC1	394	P₂l	0.72	1.01	1.1	1.1	0.47	0.56	0.15	1.02	0.36	17.2	41.0	41.8	0.04	0.36	0.18	0.65
20	BC1	506	P₂l	0.29	0.96	1.0	1.0	0.47	0.56	0.18	0.85	0.31	16.4	37.7	45.8	0.03	0.40	0.20	0.68
21	BC1	623	P₂l	0.76	1.09	1.1	0.9	0.53	0.52	0.17	1.20	0.81	12.3	44.6	43.1	0.03	0.46	0.22	0.82
22	BC1	714	P₂l	1.84	1.17	-	0.9	0.51	0.54	0.40	0.76	0.31	7.1	37.5	55.5	0.03	0.53	0.30	0.93
23	BC1	965	P₂l	0.86	1.65	0.9	-	0.53	0.52	0.29	0.91	0.54	9.0	41.4	49.6	0.04	0.43	0.23	0.82
24	BC1	966	P₂l	1.25	1.16	0.9	-	0.53	0.52	0.24	0.92	0.51	8.8	42.0	49.3	0.02	0.44	0.24	0.89
25	XJC1	4 154	Oil	-	1.62	-	-	0.56	0.49	0.23	1.07	1.41	14.5	40.9	44.6	0.03	0.77	0.42	1.68
26	XJC1	4 171	Oil	-	1.59	-	-	0.55	0.49	0.22	1.10	1.29	14.7	40.0	45.3	0.03	0.77	0.42	1.70
27	XJC1	4 195	Oil	-	1.55	-	-	0.56	0.49	0.19	0.98	1.26	13.2	39.3	47.5	0.02	0.77	0.42	1.73
28	XJC1	4 230	Oil	-	1.53	-	-	0.55	0.48	0.20	1.11	1.26	13.6	40.4	46.0	0.01	0.77	0.43	1.72
29	BC1	181	Oil	-	-	-	-	0.46	0.55	0.80	0.79	0.47	22.1	30.1	47.8	0.00	0.60	0.32	1.01
30	BC1	206	Oil	-	-	-	-	0.40	0.51	1.56	0.90	0.33	15.0	36.3	48.6	0.06	0.59	0.33	0.71
31	BC1	405	Oil	-	-	-	-	0.41	0.52	0.45	0.93	0.32	15.3	37.7	47.0	0.07	0.44	0.24	0.75

Table 2 Biomarker parameters of the source rocks from XJC1 and BC1 wells in the southeastern Junggar Basin

编号	井号	井深 /m	层位	$C 21 -$ / $C 22 +$	Pr/Ph	CPI	OEP	αββ	C₂₉ 20S	G/ C₃₀H	C₂₈/ C₂₉	Tri/ Pent	C₂₇/ %	C₂₈/ %	C₂₉/ %	DBT/P	F₁	F₂	R_c
1	XJC1	2 912	P₃w	0.26	0.68	1.3	1.1	0.39	0.51	0.76	0.77	0.44	29.9	27.8	42.3	0.14	0.45	0.24	0.79
2	XJC1	2 918	P₃w	0.24	0.61	1.2	1.0	0.44	0.51	0.49	0.58	0.32	27.1	25.4	47.5	0.12	0.46	0.25	0.84
3	XJC1	3 814	P₂l₂	1.05	1.81	1.0	1.0	0.58	0.47	0.47	0.59	0.67	40.6	20.4	39.0	0.03	0.63	0.36	1.16
4	XJC1	3 974	P₂l₂	1.05	0.92	1.1	1.0	0.53	0.51	0.20	0.62	0.78	34.5	22.3	43.2	0.08	0.71	0.41	1.12
5	XJC1	4 080	P₂l₂	1.15	1.36	0.9	1.1	0.39	0.56	0.23	0.57	1.18	44.2	27.7	28.1	0.04	0.73	0.43	1.42
6	XJC1	4 145	P₂l₂	1.10	1.30	1.1	1.1	0.57	0.57	0.14	1.38	1.47	43.2	33.3	23.4	0.01	0.73	0.46	1.51
7	XJC1	4 174	P₂l₂	0.83	1.13	1.2	1.0	0.55	0.53	0.14	1.19	1.15	62.7	19.7	17.6	0.02	0.76	0.45	1.82
8	XJC1	4 198	P₂l₂	0.99	1.25	1.3	1.1	0.57	0.47	0.16	1.01	1.43	47.0	27.8	25.2	0.01	0.76	0.47	1.93
9	XJC1	4 205	P₂l₂	0.84	1.23	1.2	1.1	0.45	0.45	0.23	2.09	1.00	52.6	32.4	15.0	0.02	0.74	0.44	1.80
10	XJC1	4 235	P₂l₂	0.95	1.35	1.1	1.0	0.40	0.60	0.19	0.31	2.24	40.4	23.3	36.3	0.01	0.78	0.47	1.73
11	XJC1	4 547	P₂l₁	1.83	1.27	1.1	1.0	0.56	0.51	0.20	1.11	11.6	19.0	40.0	40.9	0.01	0.60	0.33	1.79
12	XJC1	4 576	P₂l₁	1.14	1.24	1.1	1.0	0.54	0.50	0.18	0.97	4.51	25.6	35.2	39.3	0.01	0.64	0.36	1.74
13	XJC1	4 672	P₂l₁	0.88	1.24	0.9	1.0	0.55	0.49	0.24	0.88	2.17	20.9	35.9	43.2	0.01	0.78	0.48	1.29
14	XJC1	4 677	P₂l₁	0.89	1.10	1.1	1.0	0.58	0.50	0.19	0.92	4.60	24.1	37.1	38.8	0.01	0.79	0.48	1.23
15	BC1	54	P₂l	-	-	-	-	0.55	0.52	0.16	1.05	0.74	16.3	42.6	41.1	0.03	0.19	0.10	0.57
16	BC1	166	P₂l	1.26	1.18	-	-	0.54	0.54	0.19	0.91	0.51	16.8	40.2	43.0	0.04	0.31	0.14	0.61
17	BC1	225	P₂l	0.95	1.18	1.1	-	0.47	0.57	0.18	0.77	0.32	19.4	36.0	44.6	0.05	0.25	0.14	0.54
18	BC1	308	P₂l	0.56	1.07	1.0	1.2	0.51	0.56	0.16	0.98	0.57	19.4	40.2	40.4	0.04	0.31	0.15	0.59
19	BC1	394	P₂l	0.72	1.01	1.1	1.1	0.47	0.56	0.15	1.02	0.36	17.2	41.0	41.8	0.04	0.36	0.18	0.65
20	BC1	506	P₂l	0.29	0.96	1.0	1.0	0.47	0.56	0.18	0.85	0.31	16.4	37.7	45.8	0.03	0.40	0.20	0.68
21	BC1	623	P₂l	0.76	1.09	1.1	0.9	0.53	0.52	0.17	1.20	0.81	12.3	44.6	43.1	0.03	0.46	0.22	0.82
22	BC1	714	P₂l	1.84	1.17	-	0.9	0.51	0.54	0.40	0.76	0.31	7.1	37.5	55.5	0.03	0.53	0.30	0.93
23	BC1	965	P₂l	0.86	1.65	0.9	-	0.53	0.52	0.29	0.91	0.54	9.0	41.4	49.6	0.04	0.43	0.23	0.82
24	BC1	966	P₂l	1.25	1.16	0.9	-	0.53	0.52	0.24	0.92	0.51	8.8	42.0	49.3	0.02	0.44	0.24	0.89
25	XJC1	4 154	Oil	-	1.62	-	-	0.56	0.49	0.23	1.07	1.41	14.5	40.9	44.6	0.03	0.77	0.42	1.68
26	XJC1	4 171	Oil	-	1.59	-	-	0.55	0.49	0.22	1.10	1.29	14.7	40.0	45.3	0.03	0.77	0.42	1.70
27	XJC1	4 195	Oil	-	1.55	-	-	0.56	0.49	0.19	0.98	1.26	13.2	39.3	47.5	0.02	0.77	0.42	1.73
28	XJC1	4 230	Oil	-	1.53	-	-	0.55	0.48	0.20	1.11	1.26	13.6	40.4	46.0	0.01	0.77	0.43	1.72
29	BC1	181	Oil	-	-	-	-	0.46	0.55	0.80	0.79	0.47	22.1	30.1	47.8	0.00	0.60	0.32	1.01
30	BC1	206	Oil	-	-	-	-	0.40	0.51	1.56	0.90	0.33	15.0	36.3	48.6	0.06	0.59	0.33	0.71
31	BC1	405	Oil	-	-	-	-	0.41	0.52	0.45	0.93	0.32	15.3	37.7	47.0	0.07	0.44	0.24	0.75

Fig.6 Partial m/z=217 mass chromatograms of saturated hydrocarbon fractions from selected source rocks and crude oils

Fig.7 Partial m/z=191 mass chromatograms of saturated hydrocarbon fractions from selected source rocks and crude oils

Fig.8 Relationship between biomarker parameters and burial depth for the samples analyzed

Fig.9 Oil-source correlation for the crude oils and source rocks from the Permian Lucaogou formation in the southeastern Junggar Basin

References 31

[1]	陈建平, 王绪龙, 邓春萍, 等. 准噶尔盆地南缘油气生成与分布规律——烃源岩地球化学特征与生烃史[J]. 石油学报, 2015, 36(7):767-780. DOI
[2]	王剑, 李二庭, 陈俊, 等. 准噶尔盆地吉木萨尔凹陷二叠系芦草沟组优质烃源岩特征及其生烃机制研究[J]. 地质论评, 2020, 66(3): 755-764.
[3]	刘雅慧, 王才志, 刘忠华, 等. 一种评价页岩油含油性的测井方法——以准噶尔盆地吉木萨尔凹陷为例[J]. 天然气地球科学, 2021, 32(7):1084-1091.
[4]	徐银波, 孙平昌, 李昭, 等. 准噶尔盆地吉木萨尔地区二叠系芦草沟组油页岩地球化学特征与成矿条件[J]. 中国地质, 2022, 49(1):311-323.
[5]	匡立春, 唐勇, 雷德文, 等. 准噶尔盆地二叠系咸化湖相云质岩致密油形成条件与勘探潜力[J]. 石油勘探与开发, 2012, 39(6):657-667.
[6]	邱振, 吴晓智, 唐勇, 等. 准噶尔盆地吉木萨尔凹陷二叠系芦草沟组致密油资源评价[J]. 天然气地球科学, 2016, 27(9):1688-1698.
[7]	张林, 张敏, 高永进, 等. 准噶尔盆地南缘博格达山前带二叠系芦草沟组油气源分析和勘探潜力[J]. 中国矿业, 2021, 30(11): 178-188.
[8]	蔡忠贤, 陈发景, 贾振远. 准噶尔盆地的类型和构造演化[J]. 地学前缘, 2000, 7(4):431-440.
[9]	崔泽宏, 汤良杰, 王志欣. 博格达南、北缘成盆过程演化及其对油气形成影响[J]. 沉积学报, 2007(1):59-64+98.
[10]	旷理雄, 郭建华, 梅廉夫, 等. 从油气勘探的角度论博格达山的隆升[J]. 吉林大学学报, 2005(3): 346-50.
[11]	陈涛, 魏东涛, 杨海波, 等. 准南前陆冲断带构造特征及其对油气成藏的影响[J]. 天然气地球科学, 2006, 17(5):711-718.
[12]	JIANG C, LI M, OSADETZ K G, et al. Bakken/Madison petroleum systems in the Canadian Williston Basin.Part 2: molecular markers diagnostic of Bakken and Lodgepole source rocks[J]. Organic Geochemistry, 2001, 32(9): 1037-1054.
[13]	LI S, PANG X, LI M, et al. Geochemistry of petroleum systems in the Niuzhuang South Slope of Bohai Bay Basin.Part 1: source rock characterization[J]. Organic Geochemistry, 2003, 34(3): 389-412.
[14]	卢双舫. 油气地球化学[M]. 北京: 石油工业出版社, 2008:213-219.
[15]	RADKE M, GARRLGUES P, WILLSCH H. Methyllated dicyclic and tricyclic aromatic hydrocarbon in crude oils from the Handil field Indonesia[J]. Organic Geochemistry, 1982, 15: 17-34.
[16]	PRICE L C. Thermal stability of hydrocarbons in nature: Limits, evidence, characteristics, and possible controls[J]. Geochimica et Cosmochimica Acta, 1993, 57(14): 3261-3280.
[17]	张中宁, 刘文汇, 王作栋, 等. 塔北隆起深层海相油藏中原油及族组分碳同位素组成的纵向分布特征及其地质意义[J]. 沉积学报, 2008, 26(4):709-714.
[18]	CLAYTON C J, BJORØY M. Effect of maturity on ¹³C、 ¹²C ratios of individual compounds in North Sea oils[J]. Organic Geochemistry, 1994, 21:737-750.
[19]	周叶骏, 关平, 吴颜雄, 等. 柴达木盆地西部咸水湖相沉积有机质中二苯并噻吩类组成特征及环境意义[J]. 天然气地球科学, 2018, 29(6): 908-920.
[20]	陈建平, 梁狄刚, 王绪龙. 彩南油田多源混合原油的油源(一)——烃源岩基本地球化学特征与生物标志物特征[J]. 石油勘探与开发, 2003(4):20-24.
[21]	VOLKMANKMAN J K. A review of sterol markers for marine and terrigenous organic matter[J]. Organic Geochemistry, 1986, 9(2): 83-99.
[22]	PETERS K E, WALTERS C C, MOLDOWAN J M. The Biomarker Guide, Biomarkers and Isotopes in Petroleum Exploration and Earth History[M]. Cambridge: Cambridge University Press, 2005.
[23]	DEGRANDE S, AQUINONETO F, MELLO M R. Extended tricyclic terpanes in sediments and petroleums[J]. Organic Geochemistry, 1993, 20(7): 1039-1047.
[24]	NETO F A, TRENDEL J M, RESTLE A, et al. Occurrence and formation of tricyclic and tetracyclic terpanes in sediments and petroleums[M]. Bjoroy. Advance in Organic Geochemistry. Chichester: John Wiley & Sons Ltd., 1983: 659-667.
[25]	MOLDOWAN J M, SEIFERT W K, GALLEGOS E J. Identification of an extended series of tricyclic terpanes in petroleum[J]. Geochimica et Cosmochimica Acta, 1983, 47(8): 1531-1534.
[26]	DAMSTÉ J S, KENIG F, KOOPMANS M P, et al. Evidence for gammacerane as an indicator of water column stratification[J]. Geochimica et Cosmochimica Acta, 1995, 59(9):1895-1990. PMID
[27]	BUDZINSKI H, GARRIGUES P, CONNAN J, et al. Alkylated phenanthrene distributions as maturity and origin indicator in crude oils and rock extracts[J]. Geochimica et Cosmochimica Acta, 1995, 59(10): 2043-56.
[28]	HUGHES W B, HOLBA A G, DZUO L I. The ratios of dibenzothiophene to phenanthrenes and pristane to phytane as indicators of depositional environment and lithology of petroleum source rocks[J]. Geochimica et Cosmochimica Acta, 1995, 59:3581-3598.
[29]	KVALHEIM O M, CHRISTY A A, TELN? S N, et al. Maturity determination of organic matter in coals using the methylphenanthrene distribution[J]. Geochimica et Cosmochimica Acta, 1987, 51(7): 1883-8.
[30]	FAN P, PHILIP R P, LI Z, et al. Geochemical characteristics of aromatic hydrocarbons of crude oils and source rocks from different sedimentary environments[J]. Organic Geochemistry, 1990, 16(1/3): 427-435.
[31]	RADKE M, VRIEND S P, RAMANAMPISOA L R. Alkyldibenzofurans in terrestrial rocks: influence of organic facies and maturation[J]. Geochimica et Cosmochimica Acta, 2000, 64(2): 275-286.