Application of tetracyclic polyprenoids as indicators of input from fresh-brackish water environments

Holba, Á.; Dzou, Leon; Wood, Gordon D.; Ellis, Leroy; Adam, Pierre; Schaeffer, Philippe; Albrecht, Pierre; Greene, Todd J.; Hughes, William B.

doi:10.1016/s0146-6380(02)00193-6

Cited by 180 publications

(58 citation statements)

References 37 publications

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“…From alkane and biomarker distributions, three oil families were deduced on the basis of source (terrigenous, mixed marine-terrigenous and dominant marine). Biomarker distributions including C 30 tetracyclic polyprenoids (TPPs) were used to calculate the TPP proxy (Holba et al 2003), oleanane indices (Eneogwe & Ekundayo 2003;Matava et al 2003), and the tricyclic terpane index (TTTI) to discriminate between the marine (mostly western deepwater oils) and terrigenous source rocks, and also to suggest mixing of lacustrine and terrestrial-derived oils.…”

Section: Africamentioning

confidence: 99%

Carbon and hydrogen isotopic compositions of n -alkanes as a tool in petroleum exploration

Pedentchouk

Turich

2017

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Compound-specific isotope analysis (CSIA) of individual organic compounds is a powerful but underutilized tool in petroleum exploration. When integrated with other organic geochemical methodologies it can provide evidence of fluid histories including source, maturity, charge history and reservoir processes that can support field development planning and exploration efforts. The purpose of this chapter is to provide a review of the methodologies used for generating carbon and hydrogen isotope data for mid-and high-molecular-weight n-alkanes.We discuss the factors that control stable carbon and hydrogen isotope compositions of n-alkanes and related compounds in sedimentary and petroleum systems and review current and future applications of this methodology for petroleum exploration. We discuss basin-specific case studies that demonstrate the usefulness of CSIA either when addressing particular aspects of petroleum exploration (e.g. charge evaluation, source rock-oil correlation, and investigation of maturity and in-reservoir processes) or when this technique is used to corroborate interpretations from integrated petroleum systems analysis, providing unique insights which may not be revealed when using other methods. CSIA of n-alkanes and related n-alkyl structures can provide independent data to strengthen petroleum systems concepts from generation and expulsion of fluids from source rock, to charge history, connectivity, and in-reservoir processes.Gold Open Access: This article is published under the terms of the CC-BY 3.0 license.Petroleum geoscientists use organic geochemistry as an essential tool in oil and gas exploration and field development planning. Relatively low-cost, high-throughput bulk data are commonly used to screen for source rock quality (e.g. per cent total organic carbon (%TOC), hydrogen and oxygen indices) and thermal maturity (Tmax, vitrinite reflectance equivalent). More in-depth geochemical analytical techniques are used in the context of full fluid and reservoir properties to correlate source rocks and reservoir oils, to determine fluid generation and migration history, including presentday reservoir connectivity, and to understand in-reservoir processes, such as biodegradation of in-reservoir oils. These tools are especially powerful when coupled with other measurements made during the exploration and development process, such as compositional analysis during drilling, downhole fluid analysis and other wireline measurements, and pressure, volume, temperature (PVT) and chemical analyses, integrated in the context of geological static and reservoir dynamic models.Molecular biomarkers have been employed in petroleum exploration for several decades (Peters et al. 2005). The usefulness of bulk stable isotope measurements of gases and oils was well demonstrated in the petroleum industry through the decades of the 1970s and 1980s (Stahl 1977;Schoell 1984;Sofer 1984). However, the use of compound-specific isotopic composition of light hydrocarbons, alkanes and biomarkers is less common....

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Section: Africamentioning

confidence: 99%

Carbon and hydrogen isotopic compositions of n -alkanes as a tool in petroleum exploration

Pedentchouk

Turich

2017

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“…Thus, it might be possible that the lower bb/(bb + aa) isomerisation values reflect uptake from organic-rich strata, or that carbonate and evaporitic source rocks contributed to these petroleums. C 24 tetracyclic terpanes and C 28 and C 29 tricyclic terpanes: possible evidence for Triassic-or Palaeozoic-derived petroleum The extended tricyclic terpane ratio (ETR) ((C 28 + C 29 tricyclic terpanes)/Ts) was used to differentiate between Jurassic (ETR ≤2.0) and Triassic (ETR ≥2.0) derived oils, although Holba et al (2003) noted that the ETR can be influenced by marine upwelling. The ratio is based on high C 28 and C 29 (R+S) tricyclic terpanes in Triassic petroleums, compared to low concentrations in Jurassic petroleums.…”

Section: Variations In Maturation Parameters As Indications Of Mixingmentioning

confidence: 99%

Organic Geochemistry of Barents Sea Petroleum: Thermal Maturity and Alteration and Mixing Processes in Oils and Condensates

Lerch

Karlsen

Matapour

et al. 2016

Journal of Petroleum Geology

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The petroleum system in the Barents Sea is complex with numerous source rocks and multiple uplift events resulting in the remigration and mixing of petroleum. In order to investigate the degree of mixing, 50 oil and condensate samples from 30 wells in the SW Barents Sea were geochemically analysed by GC-FID and GC-MS to INTRODUCTIONRecent oil discoveries in the Barents Sea, such as Gotha, Alta, Wisting, Johan Castberg (Skrugard and Havis), Nucula and Goliat ( Fig. 1) (Norwegian Petroleum Directorate, 2014), are evidence for the presence of commercial volumes of liquid petroleum in an area which was long considered to be gas-prone (Stewart et al., 1995). These discoveries led to renewed geochemistry-based investigations of the petroleum systems in the Barents Sea (Bjorøy et al., 2009;Killops et al., 2014;Rodrigues-Duran et al., 2013). The presence of multiple potential source rocks may have resulted in the occurrence of mixed petroleum charges (Ohm et al., 2008;Vobes, 1998). Petroleum distribution and composition was influenced by several episodes of Cenozoic uplift and burial (Cavanagh et al., 2006;Ohm et al., 2008). Cenozoic uplift had a negative effect on the petroleum systems because it resulted in the cessation of hydrocarbon generation and expulsion (Henriksen et al., 2011). In addition, uplift resulted in alterations to the physical properties of trapped hydrocarbons, including changes to gas-to-oil ratios and associated expansion of gas columns, causing oil to be forced out of structures below the spill point (Nyland et al., 1992). Remigration/leakage of petroleum phases also occurred as a result of cap-rock failure or fault reactivation (Ohm et al., 2008;Ostanin et al., 2013). Thus geochemical interpretations in the Barents Sea suggest that uplift-related remigration/long-distance migration may be the key to understanding the complex petroleum systems present (Lerch et al., 2016;Ohm et al., 2008;Rodrigues-Duran et al., 2013).While Rodrigues Duran et al. (2013) focused mainly on the gaseous and light hydrocarbon maturation and alteration parameters in samples from the Hammerfest Basin, Ohm et al. (2008) among others investigated isotope signatures of oils from a larger area to identify potential source rocks. Bjorøy et al. (2009) correlated source rock extracts with oils to determine genetic relationships, and Killops et al. (2014) used novel age-related biomarkers to identify possible source rocks. However, until now few studies have attempted to correlate maturity signatures in order to understand regional variations in petroleum composition.The purpose of this study is to investigate the molecular evidence for the presence of mixed or transformed (biodegraded or water-washed) petroleum in the Barents Sea, and to assess regional similarities and/or differences in petroleum. Saturated and aromatic maturity parameters from the medium molecular (C 14 -C 18 ) and biomarker-range (C 20+ ) hydrocarbon fractions were analysed. Results were compared with results obtained by Lerch et al. (2016), who investigat...

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“…Gammacerane has been interpreted to indicate water column stratification (Sinninghe Damsté et al, 1995;Zhu et al, 2005;Peters et al, 2005), and is thought to originate from ciliates feeding on phototrophic bacteria (ten Haven et al, 1985;Peters and Moldowan, 1993). High abundances of gammacerane are usually found in evaporites or high salinity environments (Fu et al, 1990;Chen et al, 1996;Ritts et al, 1999;Hanson et al, 2001;Holba et al, 2003;Manzi et al, 2007;Gürgey et al, 2007;Summons et al, 2008). The paucity of these components in the Triassic samples (example in Fig.…”

Section: Depositional Environmentsmentioning

confidence: 99%

Biomarker Characteristics of Potential Source Rocks in the Jabal Nafusah Area, Nw Libya: Petroleum Systems Significance

Abohajar¹,

Littke

Schwarzbauer

et al. 2015

Journal of Petroleum Geology

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Application of tetracyclic polyprenoids as indicators of input from fresh-brackish water environments

Cited by 180 publications

References 37 publications

Carbon and hydrogen isotopic compositions of n -alkanes as a tool in petroleum exploration

Carbon and hydrogen isotopic compositions of n -alkanes as a tool in petroleum exploration

Organic Geochemistry of Barents Sea Petroleum: Thermal Maturity and Alteration and Mixing Processes in Oils and Condensates

Biomarker Characteristics of Potential Source Rocks in the Jabal Nafusah Area, Nw Libya: Petroleum Systems Significance

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