Applications of Light Hydrocarbon Molecular and Isotopic Compositions in Oil and Gas Exploration

Walters, Clifford C.; Isaksen, Gary H.; Peters, Kenneth E.

doi:10.1007/978-1-4419-9212-3_10

Cited by 4 publications

(2 citation statements)

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“…Thompson defined stages for maturity estimation of oils based on heptane ratio as follows: the heptane ratio from 18 to 22 is normal uncracked oil, 22 to 30 is classified as mature oil, and heptane ratio > 30 is classified as supermature (Thompson 1983). Not only heptane ration, isoheptane ratio was also introduced by Walters et al (2003) to better characterize maturity stage, who proposed an empirical heptane ratio (H) versus isoheptane ratio (I) diagram based on the C 7 ratios measured for oils/condensates from the North Sea to investigate the thermal maturity of oils/condensates. In this study, thermal maturity is accessed using a crossplot ( Fig.…”

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confidence: 99%

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RETRACTED ARTICLE: Light hydrocarbon geochemistry: insight into oils/condensates families and inferred source rocks of the Woodford–Mississippian tight oil play in North-Central Oklahoma, USA

et al. 2020

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The Woodford-Mississippian "Commingled Production" is a prolific unconventional hydrocarbon play in Oklahoma, USA. The tight reservoirs feature variations in produced fluid chemistry usually explained by different possible source rocks. Such chemical variations are regularly obtained from bulk, molecular, and isotopic characteristics. In this study, we present a new geochemical investigation of gasoline range hydrocarbons, biomarkers, and diamondoids in oils from Mississippian carbonate and Woodford Shale. A set of oil/condensate samples were examined using high-performance gas chromatography and mass spectrometry. The result of the condensates from the Anadarko Basin shows a distinct geochemical fingerprint reflected in light hydrocarbon characterized by heptane star diagrams, convinced by biomarker characteristics and diamantane isomeric distributions. Two possible source rocks were identified, the Woodford Shale and Mississippian mudrocks, with a variable degree of mixing. Thermal maturity based on light hydrocarbon parameters indicates that condensates from the Anadarko Basin are of the highest maturity, followed by "Old" Woodford-sourced oils and central Oklahoma tight oils. These geochemical parameters shed light on petroleum migration within Devonian-Mississippian petroleum systems and mitigate geological risk in exploring and developing petroleum reservoirs.

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Section: Figmentioning

confidence: 99%

“…In this study, thermal maturity is accessed using a crossplot ( Fig. 5) comparing the heptane versus isoheptane ratio (listed in Table 2) with maturity levels according to Walters et al (2003). The heptane ratio ranged from 25.8 to 45.8, and isoheptane ranged from 0.6 to 8.3.…”

Section: Figmentioning

confidence: 99%

RETRACTED ARTICLE: Light hydrocarbon geochemistry: insight into oils/condensates families and inferred source rocks of the Woodford–Mississippian tight oil play in North-Central Oklahoma, USA

et al. 2020

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Determining maturity and maximum burial temperatures of Type II-S oils using light hydrocarbon and polycyclic aromatic hydrocarbon isomer relationships

Srinivasan

Jacobi

Atwah

et al. 2022

Second International Meeting for Applied Geoscience &Amp; Energy

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Origin of the Ultra-Deep Hydrocarbons from the Shunbei No. 1 Fracture Zone in the North of Shuntuoguole Low Uplift, Tarim Basin, North-Western China

et al. 2023

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In order to have a deeper insight into the accumulation mechanism of ultra-deep hydrocarbons, in this paper, the recently discovered ultra-deep Ordovician light oil and gas deposits (>7200 m) in the Shunbei No. 1 fracture zone are studied intensively, including maturity, source kitchens, the extent of secondary alterations, and possible migration directions, based on an analysis of the molecular compositions and stable carbon isotopes of crude oils and natural gases. The average equivalent vitrinite reflectance (Rc) of these oils, estimated from light hydrocarbons (H versus I), MDI, DNR, and MDR, are about 1.50%, 1.58%, 1.48%, and 1.51%, respectively, which suggests that most of the oils are in the late stages of crossing the oil window. The two maturity grades (1.06–1.25% and 1.36–1.67%) of the oil samples calculated from the aromatic compounds indicate the presence of at least two stages of hydrocarbon charge. In addition, the positive correlation plot of DNR and MDR (y = 3.59x − 12.84; R2 = 0.96) indicates that oils in the southwestern region of the F1 (S1-11–S1-16) are slightly more mature than oils in the northeastern region of the F1 and the well at SL1, far from the No. 1 main fault zone. In addition, the study shows that these hydrocarbons belong to the same source kitchen of a reduced marine sedimentary environment with mixed organic matter comprising benthic and planktonic algae, based on biomarker parameters, light hydrocarbons, and carbon isotope compositions. The oil–oil correlation analyses suggest that the studied oil samples are probably derived from the in situ Lower Cambrian Yuertusi formation source rocks. Various geochemical parameters consistently show limited significant hydrocarbon alteration processes, indicating favorable preservation conditions in the study area. The integrated geochemical characteristics of the hydrocarbons allow us to infer that they mainly migrate vertically from the in situ Lower Cambrian Yuertusi formation source rocks toward the Ordovician reservoirs, followed by a certain degree of lateral migration from southwest to northeast.

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Applications of Light Hydrocarbon Molecular and Isotopic Compositions in Oil and Gas Exploration

Cited by 4 publications

References 30 publications

RETRACTED ARTICLE: Light hydrocarbon geochemistry: insight into oils/condensates families and inferred source rocks of the Woodford–Mississippian tight oil play in North-Central Oklahoma, USA

RETRACTED ARTICLE: Light hydrocarbon geochemistry: insight into oils/condensates families and inferred source rocks of the Woodford–Mississippian tight oil play in North-Central Oklahoma, USA

Determining maturity and maximum burial temperatures of Type II-S oils using light hydrocarbon and polycyclic aromatic hydrocarbon isomer relationships

Origin of the Ultra-Deep Hydrocarbons from the Shunbei No. 1 Fracture Zone in the North of Shuntuoguole Low Uplift, Tarim Basin, North-Western China

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