The complexity, secondary geochemical process, genetic mechanism and distribution prediction of deep marine oil and gas in the Tarim Basin, China

Zhu, Guangyou; Zhang, Zhiyao; Zhou, Xiaofeng; Li, Tingting; Han, Jianfa; Sun, Chunwei

doi:10.1016/j.earscirev.2019.102930

Cited by 83 publications

(34 citation statements)

References 121 publications

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“…Many secondary reservoir processes (e.g., biodegradation, thermal cracking, TSR, and gas washing fractionation) occur in the Tarim Basin that alter primary oil composition . Oils in the East Lungu area exhibit no evidence for biodegradation or TSR.…”

Section: Resultsmentioning

confidence: 99%

“…Marine reservoirs in the Lunnan Lower Uplift of Tarim Basin have been shown to have undergone secondary thermal cracking and gas invasion involving multiple stages of hydrocarbon charging and accumulation . Two of the most important effective hydrocarbon charging processes are oil charging in the Late Hercynian period and gas charging in the Late Himalayan period …”

Section: Resultsmentioning

confidence: 99%

“…Diamondoids are widely used to identify highly mature products from oil cracking. ,,− To compare these compounds in the East Lungu oils, the samples were analyzed first by GC × GC-TOFMS to obtain full mass spectra and the diamondoid compounds were identified qualitatively according to their retention time and mass fragmentation. Then, the contents of diamondoid compounds were calculated semiquantitatively comparing the peak area of the internal standard and the peak area of each compound.…”

Section: Resultsmentioning

confidence: 99%

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The Influence of Gas Invasion on the Composition of Crude Oil and the Controlling Factors for the Reservoir Fluid Phase

Zhu

Chi

et al. 2020

Energy Fuels

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Oil and gas in deep strata is complex in property and variable in phase type, which imposes great challenges to exploration. This is particularly true in the deep Ordovician of Tarim Basin (NW China) where abundant oil and gas resources were discovered with various phase types including gas, condensate, volatile oil, normal oil, and heavy oil. The prediction of the composition and phase type of deep fluid is a crucial issue in future development. In this study, typical oils from different types of reservoirs from the East Lungu area (north Tarim Basin) were sampled and analyzed with two-dimensional gas chromatography/time-of-flight mass spectrometry (GC × GC-TOFMS) for the reconstruction of gas invasion on its impact oil compositions and reservoir phase type. The concentration of diamondoids in crude oil and the loss of n-alkane decreased gradually along the westward direction of gas invasion. Coupled with several other parameters, the quantitative evaluation of the gas invasion intensity indicated that gas invasion occurs from east to west in the late period (12–2 Ma) in the study site and altered the paleo reservoirs formed in the Late Hercynian (293–255 Ma), and thus formed the condensate (strong gas invasion), volatile oil (weak gas invasion), and normal oil reservoir (no gas invasion), successively. The prediction of the phase type distribution provides a scientific basis for deep oil and gas exploration and resource assessment.

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Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

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The Influence of Gas Invasion on the Composition of Crude Oil and the Controlling Factors for the Reservoir Fluid Phase

Zhu

Chi

et al. 2020

Energy Fuels

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“…8 The complex diversity of oil and gas phases has brought many difficulties to resource assessment and exploration. 9 The phase state of oil and gas reservoirs is controlled by the chemical composition of the fluid and the temperature and pressure conditions. 10 The maturity of source rocks and charging of hydrocarbons determine the chemical composition of fluids, and the adjustment and transformation of the oil and gas reservoirs by tectonic movements are accompanied by changes in temperature and pressure conditions.…”

Section: Introductionmentioning

confidence: 99%

Fluid Phase Modeling and Evolution of Complex Reservoirs in the Halahatang Depression of the Tabei Uplift, Tarim Basin

2022

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The diversity of fluid phases in the oil-gas system and complexity of petroleum genesis bring difficulties to the exploration and development of oil and gas. The phase state and evolution of the complex reservoirs in the Halahatang Depression, Tabei Uplift of the Tarim Basin remains unresolved. In this paper, we simulated the phase characteristic of reservoirs in different blocks and layers including Xinken (O), Ha6 (C), Repu (K), and Yueman (O) distributed from north to south of this area using PVTsim software; rebuilt the burial, temperature, and pressure histories of different blocks and layers by using the PetroMod (1D) software; and recovered the fluid phase evolution process by combined basin modeling, PVT simulation, and fluid inclusion thermal metrics results. The phase modeling results show that the Xinken (O), Ha6 (C), and Yueman (O) reservoirs are confirmed to be oil reservoirs, and the Repu (K) reservoir is in the condensate gas phase currently. The vital time points and temperature and pressure conditions for the three oil reservoirs of Xinken (O), Ha6 (C), and Yueman (O) that transited from the gas–liquid phase to the liquid phase are 356 Ma (57.45 °C, 12.93 MPa), 331 Ma (35.67 °C, 4.03 MPa), and 454 Ma (63.63 °C, 13.27 MPa), respectively. The Ordovician reservoir in the Xinken block underwent three stages of accumulation, which occurred at 400–379 Ma (Devonian), 282–256 Ma (Permian), and 18–16 Ma (Neogene), respectively, and after final accumulation, it remained in a single oil phase state. The Ordovician reservoir in the Yueman block underwent two stages of accumulation in the 294–290 Ma (Permian) and 25–12 Ma (Paleogene–Neogene) and remained in a single oil phase state until now. The Carboniferous reservoir in the Ha6 block was deduced to be charged in the 94–86 Ma (Cretaceous) according to the published authigenic illite K–Ar isotope dating results and then stayed in a single oil phase state unalterably. As for the Cretaceous reservoir in the Repu block, the time point of 11 Ma (98.86 °C, 35.56 MPa) is vital for changing from the gas–liquid coexistence phase state to the condensate gas phase one. In contrast with the Ordovician (ZG7–5) and Cambrian reservoirs (ZS1, ZS5) in the Tazhong Uplift, the oil and condensate gas reservoirs in the Tabei Uplift enjoy a lower pressure range, lower GOR, and a heavier oil density and viscosity. This study provides a quantitative way to rebuild the geologic evolutionary process, phase characteristics, and phase evolution process in complex reservoirs.

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“…5 Although the scale of oil field exploration continually expands, oil–oil/source correlation remains a controversial topic for most marine basins, particularly in the Tarim oil field. 6 − 8 …”

Section: Introductionmentioning

confidence: 99%

Pyrolytic Evidence for Unsubstituted Aromatics as Potential Oil–Oil/Source Correlation Indicators

Chen

Zhang

et al. 2022

ACS Omega

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Most oil source correlation indicators are invalid because of the high maturity of the deep marine strata. Thus, a suitable indicator with high thermal stability requires to be established. In this study, to understand the effect of thermal maturation on the carbon isotopic composition of unsubstituted aromatics, we performed a number of anhydrous thermal simulation experiments involving two typical Chinese shales (lacustrine and marine shales), their corresponding expelled oils, three crude oils, and their associated oil fractions, that is, saturates, aromatics, resins, and asphaltenes (SARA). The generated unsubstituted aromatics were examined in terms of molecular distributions and carbon isotopic composition. The results show that unsubstituted aromatics in different types of samples demonstrated similar variation characteristics. Phenanthrene can be formed continuously in 0.45%/0.55–2.30% R o (equivalent vitrinite reflectance), especially in the high-over maturity stage. However, their carbon isotope composition shows minor variations. The unsubstituted aromatic carbon isotopic information in source rocks can be preserved during the whole pyrolysis process. Their carbon isotopic values in source rocks and their corresponding expelled oils are extremely similar. Furthermore, no evident difference exists in the carbon isotopes of unsubstituted aromatics formed by crude oil and associated oil fractions. These results indicate that these types of parameters are suitable for oil–oil/source correlation in deep marine strata with high-over maturity.

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The complexity, secondary geochemical process, genetic mechanism and distribution prediction of deep marine oil and gas in the Tarim Basin, China

Cited by 83 publications

References 121 publications

The Influence of Gas Invasion on the Composition of Crude Oil and the Controlling Factors for the Reservoir Fluid Phase

The Influence of Gas Invasion on the Composition of Crude Oil and the Controlling Factors for the Reservoir Fluid Phase

Fluid Phase Modeling and Evolution of Complex Reservoirs in the Halahatang Depression of the Tabei Uplift, Tarim Basin

Pyrolytic Evidence for Unsubstituted Aromatics as Potential Oil–Oil/Source Correlation Indicators

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