Innovative fluorescence spectroscopic techniques for rapidly characterising oil inclusions

Liu, Keyu; George, Simon C.; Lu, Xuesong; Gong, Shengkai; Tian, Hui; Gui, Lili

doi:10.1016/j.orggeochem.2014.04.010

Cited by 35 publications

(34 citation statements)

References 28 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The TSF had the same test procedures with the QGF‐E. The UV excitation wavelength and the recorded emission wavelength of the TSF spectra had values of 220–340 and 250–540 nm, respectively, and were different from those of the QGF and QGF‐E (Liu et al, ). The R 1 of TSF was a ratio of fluorescence intensities at 360 nm over that at 320 nm corresponding to the 270 nm excitation wavelength (Equation ; Liu et al, ).…”

Section: Sampling and Methodsmentioning

confidence: 99%

“…The R 1 of TSF was a ratio of fluorescence intensities at 360 nm over that at 320 nm corresponding to the 270 nm excitation wavelength (Equation ; Liu et al, ). The R 1 values had a negative relationship with the hydrocarbon maturity (Liu et al, ).

R_{1} = I_{360 nm} / I_{320 nm} @ {Ex}_{270 nm},

where I means the fluorescence intensity; “Ex” means the excitation wavelength.…”

Section: Sampling and Methodsmentioning

confidence: 99%

“…Oils can be divided into three types based on fluorescence spectral characteristics and R 1 values. Generally, condensates usually have spectral peaks <420 nm with multiple centres in the TSF and double peaks in the QGF‐E as well as R 1 values <2.0 (Liu et al, ). Most of the normal to light oils have fluorescence spectral peaks of approximately 420–450 nm and R 1 values of 2.0–3.0.…”

Section: Sampling and Methodsmentioning

confidence: 99%

“…Most of the normal to light oils have fluorescence spectral peaks of approximately 420–450 nm and R 1 values of 2.0–3.0. Medium to heavy oils have spectral peaks >450 nm and R 1 values of >3.0 (Liu et al, ).…”

Section: Sampling and Methodsmentioning

confidence: 99%

“…Hydrocarbon fluids, which can trace the hydrocarbon composition, maturity, and temperatures, proved to be a valid tool to reconstruct the hydrocarbon properties and the charging history (Arouri, Jenden, & Al‐Hajji, ; Baron et al, ; Eadington, Lisk, & Krieger, ; George, ; George, Ahmed, Liu, & Volk, ; George, Lisk, Summons, & Quezada, ; Gong, George, Volk, Liu, & Peng, ; Lisk & Eadington, ; Parnell, Middleton, Chen, & Hall, ; Zeng & Yu, ). In recent years, the quantitative grain fluorescence (QGF) technology has been developed to identify the paleo‐oil layers and to describe the distribution and properties of the residual oil in reservoirs (Liu & Eadington, ; Liu, Eadington, & Coghlan, ; Liu, Eadington, Middleton, Fenton, & Cable, ; Liu et al, ).…”

Section: Introductionmentioning

confidence: 99%

See 4 more Smart Citations

The diagenetic and tectonic significance of hydrocarbon accumulation in the southern Junggar Basin, NW China

Tian

Zhang

et al. 2017

Geological Journal

View full text Add to dashboard Cite

The Jurassic petroleum system plays an increasingly important role in petroleum explorations in the southern Junggar Basin. To assess the hydrocarbon distribution and the accumulation history of the Jurassic reservoirs in this area, we carried out reservoir petrographic, fluorescence spectroscopic, and fluid inclusion petrographic analyses on the core and cutting samples from the QQ‐2 well in the Qigu Anticline. The oil accumulation has the partiality for high‐quality sandstone reservoirs that have the high porosity and permeability with values of 14–18% and (1–450) × 10−2 μm2, respectively, in the Middle Jurassic Toutunhe Formation (J2t) reservoirs. The pores are big with average diameters of 60–100 μm, and the pore throats are wide with values of 3.45–6.92 μm in the oil reservoirs. The intergranular pores survive thanks to the poor compaction and the poor cementation, and the dissolved and mould pores develop attributed to the strong dissolution in the oil reservoirs. Two episodes of oil charging and one episode of gas invasion were identified in the Middle Jurassic reservoirs in the southern Junggar Basin. The low‐maturity paleo‐oil charged the sandstone reservoirs at about 35 Ma when the paleo‐traps took shape during the Cretaceous–Eocene. A large number of faults and anticlinal traps was developed in the southern Junggar Basin at about 7 Ma, caused by the reactivation of the Tianshan Mountains in the late Cenozoic. Simultaneously, the leakage of the paleo‐oil, the accumulation of late oil, and the gas invasion all took place. Fault activities led to the leakage of paleo‐oil and helped the oil and gas accumulate in the Middle Jurassic reservoirs in the anticlinal trap shaping at about 7–8 Ma in the southern Junggar Basin.

show abstract

Section: Sampling and Methodsmentioning

confidence: 99%

R_{1} = I_{360 nm} / I_{320 nm} @ {Ex}_{270 nm},

where I means the fluorescence intensity; “Ex” means the excitation wavelength.…”

Section: Sampling and Methodsmentioning

confidence: 99%

Section: Sampling and Methodsmentioning

confidence: 99%

Section: Sampling and Methodsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 3 more Smart Citations

The diagenetic and tectonic significance of hydrocarbon accumulation in the southern Junggar Basin, NW China

Tian

Zhang

et al. 2017

Geological Journal

View full text Add to dashboard Cite

show abstract

Charging history and fluid evolution for the Carboniferous volcanic reservoirs in the western Chepaizi Uplift of Junggar Basin as determined by fluid inclusions and basin modelling

Shi

Chang

et al. 2019

Geological Journal

View full text Add to dashboard Cite

Fluid inclusions are rich in the Carboniferous volcanic reservoirs in the western Chepaizi Uplift, occurring in liquid, gaseous, and gas–liquid phases. In this study, the fluid inclusions were investigated in terms of petrographic, optical, and microthermometric characteristics, coupled with pressure–volume–temperature–composition (PVTX) simulations. Two periods of hydrothermal activities in the Carboniferous volcanic reservoirs were suggested by the bimodal distributions of Th (homogenization temperatures) of fluid inclusions with 120–140°C and 160–190°C as the main peaks. The early charged fluids were characterized by a low temperature, low salinity, relatively higher density, and low G/L (gas–liquid volumetric ratio) of aqueous inclusions, whilst the late charged fluids featured a high temperature, moderate salinity, moderate density, and high G/L of aqueous inclusions. The oil inclusions hosted in calcite or quartz veins exhibited light yellow and yellowish‐green fluorescence, whereas those in the microcracks cutting or within quartz or calcite veins showed blue‐white fluorescence. The burial and geothermal histories imply an existence of abnormal hydrothermal activity under overpressure and high temperature, which is evidenced by the simulated trapping pressure that is higher than the lithostatic pressure and the measured Th values that are higher than the formation paleo‐temperatures. The Th range is widely and continuously distributed and, in combination with the burial history, indicates that the hydrocarbon accumulation in the research area has been a continuous process since the Paleogene. Combined with the reconstruction of tectonic evolution and hydrocarbon generation and expulsion, two oil‐charging episodes were defined, that is, the Late Oligocene–Early Miocene (23–16 Ma) and the Late Miocene–Holocene (6 Ma–). The western section of the Aika Fault Belt (F2), together with the sheet sandbodies of the Toutunhe Formation (J2t), and the unconformities between Carboniferous–Cretaceous may have served as the migration pathways.

show abstract

Interactions between hydrocarbon-bearing fluids and calcite in fused silica capillary capsules and geological implications for deeply-buried hydrocarbon reservoirs

Jin

Yuan

Cao

et al. 2021

Sci. China Earth Sci.

Self Cite

View full text Add to dashboard Cite

During the burial processes of deep/ultra-deep hydrocarbon reservoirs, the interactions between hydrocarbon-bearing fluids and reservoirs significantly affect the quality evolution of hydrocarbons and reservoirs; thus, this topic requires further investigation. In this study, the continuous evolution and the coupling mechanisms in various anhydrous and hydrous nC 16 H 34 -(water)-(calcite) systems in fused silica capillary capsules (FSCCs) were investigated using laser Raman spectroscopy, fluorescence color analysis, and fluorescence spectroscopy, and the mineral alterations were analyzed using scanning electron microscopy (SEM). The experimental results show that extensive organic-inorganic interactions occur in the systems if water is present, and different inorganic components have different effects on hydrocarbon degradation. Distilled water promotes freeradical thermal cracking and steps oxidation, forming more low-molecular-weight hydrocarbons, CO 2 , and organic acids (e.g., acetic acids) but suppresses the free-radical cross-linking, generating less high-molecular-weight hydrocarbons. However, in the presence of CaCl 2 water, the yields of hydrocarbon gases are lower than in the distilled water system because high concentrations of Ca ions inhibit the generation of free radicals. Calcites, which exhibit different surface reactivities in different fluid conditions, affect hydrocarbon degradation in different ways. In the anhydrous nC 16 H 34 -calcite system, calcites promote the generation of both hydrocarbon gases and high-molecular-weight hydrocarbons. In contrast, in the hydrous nC 16 H 34 -distilled (CaCl 2 ) watercalcite system, calcites promote the generation of hydrocarbon gases and suppress the generation of high-molecular-weight hydrocarbons. Calcite also reacts with organic acids via surface reactions to form secondary pores. Therefore, except for the formation temperature and pressure, organic-inorganic interactions are controlled by multiple factors, such as the water saturation, water type, water salinity, and the mineral content, resulting in different evolutions of the hydrocarbon degradation and reservoir properties.

show abstract

Innovative fluorescence spectroscopic techniques for rapidly characterising oil inclusions

Cited by 35 publications

References 28 publications

The diagenetic and tectonic significance of hydrocarbon accumulation in the southern Junggar Basin, NW China

The diagenetic and tectonic significance of hydrocarbon accumulation in the southern Junggar Basin, NW China

Charging history and fluid evolution for the Carboniferous volcanic reservoirs in the western Chepaizi Uplift of Junggar Basin as determined by fluid inclusions and basin modelling

Interactions between hydrocarbon-bearing fluids and calcite in fused silica capillary capsules and geological implications for deeply-buried hydrocarbon reservoirs

Contact Info

Product

Resources

About