Underutilized advanced geochemical technologies for oil and gas exploration and production-1. The diamondoids

Moldowan, J. M.; Dahl, Jeremy E. P.; Zinniker, David; Barbanti, Silvana M.

doi:10.1016/j.petrol.2014.11.010

Cited by 62 publications

(26 citation statements)

References 15 publications

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“…Extended diamondoid fingerprints can be used for oil-oil correlations because higher diamondoids are present in almost all oils, regardless of microbial alteration or thermal maturation (e.g., [ 39 , 62 ]). QEDA fingerprints from triamantane and eight higher diamondoids [ 35 ] in two representative sampled oils were observed ( Figure 7 ). Rosa and Tulipa oils were not differentiated by QEDA.…”

Section: Resultsmentioning

confidence: 99%

“…Four deuterated internal standards were used to quantify triamantane molecule and extended polimantanes, namely, triamantane-d4 and cyclohexamantane-d8, as well as tetramantane-d6 and pentamantane-d6 for the four-cage (T1, T2, and T3) and five-cage (P1, P2, P3, and P4) non-enantiomorphic isomers. Shapes of tetra-, penta-, and hexamantane (H1) compounds measured are shown in [ 35 ].…”

Section: Methodsmentioning

confidence: 99%

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Classical Biomarker and Quantitative Extended Diamondoid Analysis Fingerprints for Crude Oils from Deepwater Developments in Block 17, Lower Congo Basin, Angola

Boente

Márquez

Marín

et al. 2020

IJERPH

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The organic geochemistry of six oil samples from the offshore Block 17 (Lower Congo Basin, northwestern Angola) was studied by a combination of classical biomarker and extended diamondoid analyses to elucidate source rock facies, the extent of biodegradation, and thermal maturity. Based on molecular data, oils are interpreted as depicting a mixture of two pulses of hydrocarbon generation probably from the Bucomazi and Malembo formations. Geochemical results also gave evidence of mixing of a lacustrine siliciclastic-sourced oil charge and a second more terrestrially derived oil type in the samples analyzed. A single genetic oil family was identified through hierarchical cluster analysis; however, two groups of oils were identified on the basis of their biodegradation levels using the Peters/Moldowan scale. Lower and upper Malembo oils have a slight depletion and a notable absence of n-alkanes, suggesting PM levels of 1 and 2, respectively. Most molecular maturity parameters of the oil samples suggest a maturity level equivalent to the onset of the peak of the oil generative window.

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Section: Resultsmentioning

confidence: 99%

Section: Methodsmentioning

confidence: 99%

Classical Biomarker and Quantitative Extended Diamondoid Analysis Fingerprints for Crude Oils from Deepwater Developments in Block 17, Lower Congo Basin, Angola

Boente

Márquez

Marín

et al. 2020

IJERPH

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“…Oil and condensate samples have undergone quantitative diamondoid analysis (QDA) at Biomarker Technologies to add a further constraint to source rock maturity and to estimate volumes of thermally cracked oil (Moldowan et al, 2014). The concentration of methyl diamantanes were determined by spiking the samples with a deuterated standard (1,-d 3methyldiamantane) followed by HPLC and zeolite concentration.…”

Section: Methodsmentioning

confidence: 99%

“…Diamondoids are most commonly used to estimate levels of thermal maturity (Chen et al, 1996) and the extent of oil-to-gas cracking (Dahl et al, 1999). They have also been used to estimate degrees of biodegradation (Grice et al, 2000) and to distinguish source rock depositional facies (Schultz et al, 2001;Jiang et al, 2018) including the geochemical correlation of source rocks with high maturity condensates (Moldowan et al, 2014).…”

Section: Introductionmentioning

confidence: 99%

“…Most conventional organic geochemical biomarkers are of limited use in studies of the source rocks for gascondensate accumulations due to their relatively low thermal stability; they break down at the temperatures required to generate primary gas-condensate phase fluids (Moldowan et al, 2014). When present, they can often be misleading for the bulk presence of fluids, only representing a minor, low maturity proportion of the fluid.…”

Section: Introductionmentioning

confidence: 99%

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Diamondoids and Basin Modelling Reveal One of the World's Deepest Petroleum Systems, South Caspian Basin, Azerbaijan

Goodwin

Abdullayev²,

Javadova³

et al. 2020

Journal of Petroleum Geology

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The South Caspian Basin has been one of the world's most prolific petroleum provinces since the 19th Century. However, despite the large number of discovered petroleum accumulations, the source rock sequence has not been penetrated by the drill in the offshore basin and is therefore poorly defined. In this paper, geochemistry together with broad estimates of in‐place volumes of petroleum fluids, onshore outcrop data and basin modelling have been used to place constraints on the source rock description. Diamondoids, the most thermally stable group of hydrocarbons, have been measured in a suite of liquid petroleum samples from Pliocene fluvio‐deltaic sandstone reservoirs at the Shah Deniz gas‐condensate field and the Azeri‐Chirag‐Gunashli oil field, offshore Azerbaijan. Samples from both fields exhibit elevated concentrations of diamondoids and C29 steranes, indicating a mixture of thermally cracked and non‐cracked petroleum. We use diamondoid concentrations to estimate that 4.8 B brl of oil may have been cracked to 12 Tcf of gas below the Shah Deniz reservoirs. Source rock properties from the outcropping Oligocene – Miocene Maikop and Diatom Formations have been used to model source rock maturation. The results indicate that pre‐cracking volumes of petroleum could be explained reasonably by the presence of source rock intervals in the offshore that are of similar richness but increased thickness compared to measured onshore outcrops. Relatively high diamondoid concentrations in Shah Deniz condensate (up to 160 ppm 3‐ + 4‐methyldiamantanes) are in agreement with gas isotope compositions (δ13C1 – δ13C3) with respect to thermal maturity. Both parameters indicate the presence of source rock that is at a high level of thermal maturity at a vitrinite reflectance equivalent (VRE) of ca. 1.5–2.0% Ro. Given the low geothermal gradients in the South Caspian Basin (16 – 17°C/km at Shah Deniz) and the relatively high temperatures required for maturation due to rapid, relatively recent burial and heating, the source rock must be buried to depths in excess of 13 km in the Shah Deniz drainage area. In the absence of any evidence of a working Mesozoic petroleum system in the South Caspian Basin, this depth of burial highlights the significant thickness of Paleogene sediments in the offshore basin. Of prolific petroleum‐producing basins, only in the deep‐water Gulf of Mexico are actively‐generating source rocks buried to similar depths.

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Biomarkers: Assessment of Source Rock Thermal Maturity

Peters¹,

Moldowan²

2017

Selective Neck Dissection for Oral Cancer

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Underutilized advanced geochemical technologies for oil and gas exploration and production-1. The diamondoids

Cited by 62 publications

References 15 publications

Classical Biomarker and Quantitative Extended Diamondoid Analysis Fingerprints for Crude Oils from Deepwater Developments in Block 17, Lower Congo Basin, Angola

Classical Biomarker and Quantitative Extended Diamondoid Analysis Fingerprints for Crude Oils from Deepwater Developments in Block 17, Lower Congo Basin, Angola

Diamondoids and Basin Modelling Reveal One of the World's Deepest Petroleum Systems, South Caspian Basin, Azerbaijan

Biomarkers: Assessment of Source Rock Thermal Maturity

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