Migration effects on the composition of hydrocarbon accumulations in the OML 67–70 areas of the Niger Delta

Matava, Tim; Rooney, Melodye A.; Chung, Hyen-Mi; Nwankwo, Basil C.; Unomah, George I.

doi:10.1306/02190300116

Cited by 25 publications

(15 citation statements)

References 19 publications

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“…Abundant of higher plant input to the source kerogen is believed to characterize the superfamily of oils as evident from the presence of high Pr/Ph ratio, high oleanane indices and high %C 29 steranes in the oils studied. Matava et al (2003) buttressed this point with their report that the oils from OML 67-70 area (joint venture acreage) fall in the regional superfamily group. However, from most of these geochemical studies, there is always a small group of samples that usually has marine organic matter characteristics, which may suggest a marine petroleum system.…”

Section: Niger Delta Petroleum Systemmentioning

confidence: 92%

“…Most of the geochemical data available from the onshore and shelf of Niger Delta suggests one super-family of oil in the Delta from one source type, which should suggest one petroleum system (a terrigenous system) for the basin (Ekweozor and Okoye 1980;Bustin 1988;Rooney et al 1998;Matava et al 2003;Akinlua et al 2007). Abundant of higher plant input to the source kerogen is believed to characterize the superfamily of oils as evident from the presence of high Pr/Ph ratio, high oleanane indices and high %C 29 steranes in the oils studied.…”

Section: Niger Delta Petroleum Systemmentioning

confidence: 99%

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Geochemical evaluation of Niger Delta sedimentary organic rocks: a new insight

Akinlua

Torto

2010

Int J Earth Sci (Geol Rundsch)

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A geochemical evaluation of Niger Delta organic matter was carried out using supercritical fluid extraction (SFE) sample preparation procedure. Comparison of geochemical significance of gas chromatographic data of rock extracts of SFE with those of Soxhlet extraction method from previous studies was made in order to establish the usefulness of SFE in geochemical exploration. The assessment of geochemical character of the rock samples from the comparison and interpretation of other geochemical parameters were used to give more insights into understanding the source rocks characteristics of onshore and shelf portions of the Niger Delta Basin. The results of the gas chromatographic (GC) analysis of the rock extracts across the lithostratigraphic units show that Pr/Ph, Pr/nC 17 , Pr/nC 18 , CPI and odd/even preference ranged from 0.07 to 12.39, 0.04 to 6.66, 0.05 to 13.80, 0.12 to 8.4 and 0.06 to 8.12, respectively. The Rock-Eval pyrolysis data and geochemical ratios and parameters calculated from the GC data showed that most of the samples are mature and have strong terrestrial provenance while a few samples have strong marine provenance. The few marine source rocks are located in the deeper depth horizon. Pr/Ph and standard geochemical plots indicate that most of samples were derived from organic matter deposited in less reducing conditions, i.e. more of oxidizing conditions while a few samples have predominantly influence of reducing conditions. The results of trace metal analysis of older samples from Agbada Formation also indicate marine and mixed organic matter input deposited in less reducing conditions. The results obtained in this study are comparable with those obtained from previous studies when Soxhlet extraction method was used and also indicated the presence of more than one petroleum systems in the Niger Delta.

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Section: Niger Delta Petroleum Systemmentioning

confidence: 92%

Section: Niger Delta Petroleum Systemmentioning

confidence: 99%

Geochemical evaluation of Niger Delta sedimentary organic rocks: a new insight

Akinlua

Torto

2010

Int J Earth Sci (Geol Rundsch)

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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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“…High sulfur oils of the second oil type is indicative of carbonate evaporate source rocks, while the low sulfur concentrations are typical for siliciclastic source rocks (Gransch and Posthuma, 1974). The diversity of the gross geochemical characteristics of the crude oils is consistent vertically with a gradual change in API gravity and maturity variation (Matava et al, 2003).…”

Section: Gross Geochemical Characteristicsmentioning

confidence: 58%

“…It shows that there is a direct relationship between C 29 20S/(S+R) and both TAS/(MAS+TAS) and C 29 ßß/( ßß+ ) increasing with burial depth of the source rocks (Matava et al, 2003). Type-II oil has a maximum value of 0.71 for the sterane isomerization ratio and 0.59 for the C 29 20S/(S+R) ratio, while these ratios for type-I oil is 0.53 and 0.36 respectively.…”

Section: Maturation-dependent Biomarker Distributionsmentioning

confidence: 93%

Crude Oil Geochemistry Dependent Biomarker Distributions in the Gulf of Suez, Egypt

Younes¹

2012

Crude Oil Exploration in the World

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Migration effects on the composition of hydrocarbon accumulations in the OML 67–70 areas of the Niger Delta

Cited by 25 publications

References 19 publications

Geochemical evaluation of Niger Delta sedimentary organic rocks: a new insight

Geochemical evaluation of Niger Delta sedimentary organic rocks: a new insight

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

Crude Oil Geochemistry Dependent Biomarker Distributions in the Gulf of Suez, Egypt

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