Geochemistry and petrology of palaeocene coals from Spitzbergen — Part 2: Maturity variations and implications for local and regional burial models

Marshall, Chris; Uguna, Jacob Onyebuolise; Large, David J.; Meredith, Will; Jochmann, Malte; Friis, Bjarki; Vane, Christopher H.; Spiro, Baruch; Snape, Colin E.; Orheim, Alv

doi:10.1016/j.coal.2015.03.013

Cited by 52 publications

(49 citation statements)

References 14 publications

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“…Throndsen (1982) estimated uplift of about 3.5 km in western central Spitsbergen. Marshall et al (2015) suggested that the base-Paleocene has experienced maximum burial temperatures of 120 °C in the central part of the Central Tertiary Basin. However, Marshall et al (2015) suggested a hyperthermal gradient of approximately 50°C/km which would result in uplift of about 2.5 km.…”

Section: Bolterdalen Bolterdalen Bolterdalen Bolterdalen Bolterdalen mentioning

confidence: 99%

Migrated Petroleum in Outcropping Mesozoic Sedimentary Rocks in Spitsbergen: Organic Geochemical Characterization and Implications for Regional Exploration

Abay

Karlsen

Lerch

et al. 2016

Journal of Petroleum Geology

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The presence of migrated petroleum in outcropping rocks on Spitsbergen (Svalbard archipelago) has been known for several decades but the petroleum has not been evaluated by modern geochemical methods. This paper presents detailed organic geochemical observations on bitumen in outcrop samples from central and eastern Spitsbergen. The samples comprise sandstones from the Lower Cretaceous Carolinefjellet Formation, the Upper Triassic – Middle Jurassic Wilhelmøya Subgroup and the Upper Triassic De Geerdalen Formation; a limestone from the De Geerdalen Formation; and carbonates from the Middle Jurassic – Lower Cretaceous Agardhfjellet Formation. In addition a palaeo‐seepage oil was sampled from a vug in the Middle Triassic Botneheia Formation. This data is integrated with the results of analyses of C1–C4 hydrocarbon fluid inclusions trapped in quartz and calcite cements in these samples. Organic geochemical data suggest that the petroleum present in the samples analysed can be divided into two compositional groups (Group I and Group II). Group I petroleums have distinctive biomarker characteristics including Pr/Ph ratios of about 1.3–1.5, high tricyclic terpanes relative to pentacyclic terpanes, and relatively high methyl‐dibenzothiophenes compared to methyl‐phenanthrenes. By contrast Group II petroleums have low tricyclic terpanes relative to pentacyclic terpanes and low methyl‐dibenzothiophenes compared to methyl‐phenanthrenes, and most Pr/Ph ratios range from 1.90 to 2.57. The petroleum in both groups was derived from marine shale source rocks deposited in proximal to open marine settings. Group I petroleums, present in the sandstones of the Wilhelmøya Subgroup and the De Geerdalen Formation and as a palaeo‐seepage oil in the vug in the Botneheia Formation, are likely to have been sourced from the Middle Triassic Botneheia Formation. Group II petroleums, found in the sandstone of the Carolinefjellet Formation, the limestone from the De Geerdalen Formation and in carbonates of the Agardhfjellet Formation, are inferred to have been generated from the Jurassic‐Cretaceous Agardhfjellet Formation. The analysis of biomarker and aromatic hydrocarbons in the petroleums indicate three relative maturation levels, equivalent to expulsion at vitrinite reflectances of about 0.7–0.8%Rc, 0.8–0.9%Rc and 1.0–1.6%Rc. On average, Triassic host rocks contain petroleum of higher maturity compared to the Jurassic and Cretaceous host rocks. The fluid inclusion data suggest that gaseous hydrocarbons from the sandstones of the Wilhelmøya Subgroup are thermogenic, and are of similar maturity to the petroleum in extracts from these sandstones, suggesting that the gas was generated together with oil in the oil window. By contrast the inclusion gases from carbonate rocks analysed have a mixed (thermogenic / biogenic) origin. The outcropping rocks in which these oils occur are analogous to offshore reservoirs on the Norwegian Continental Shelf. The study may therefore improve our understanding of the subsurface offshore petroleum systems in the...

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Section: Bolterdalen Bolterdalen Bolterdalen Bolterdalen Bolterdalen mentioning

confidence: 99%

Migrated Petroleum in Outcropping Mesozoic Sedimentary Rocks in Spitsbergen: Organic Geochemical Characterization and Implications for Regional Exploration

Abay

Karlsen

Lerch

et al. 2016

Journal of Petroleum Geology

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“…According to Levine (1993) the methane generated at lignite rank is not retained in coal due to absence of structure to retain economic quantity of gas at this stage and is expelled due to compaction. Contributions have also been made by Wilkins andGeorge (2002), Farhaduzzaman et al (2012), Gentzis (2013), Hakimi et al (2013) and Marshall et al (2015).…”

Section: Introductionmentioning

confidence: 88%

Eocene lignites from Cambay basin, Western India: An excellent source of hydrocarbon

Singh

Rajak

et al. 2016

Geoscience Frontiers

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a b s t r a c tIn the present paper lignites from the Cambay basin have been studied for their hydrocarbon potential. The samples were collected from three lignite fieldseVastan, Rajpardi and Tadkeshwar, and were investigated by petrography, chemical analyses and Rock-Eval pyrolysis. The results are well comparable with the empirically derived values. The study reveals that these 'low rank C' lignites are exceedingly rich in reactive macerals (huminite þ liptinite) while inertinite occurs in low concentration. These high volatile lignites generally have low ash yield except in few sections. The Rock-Eval data indicates the dominance of kerogen type-III with a little bit of type-II. The study reveals that the lignites of Vastan (lower and upper seams) and Tadkeshwar upper seam are more gas-prone while Rajpardi and Tadkeshwar lower seams are oil-prone. Further, the fixed hydrocarbons are several times higher than the free hydrocarbons. The relation between TOC and fixed hydrocarbon indicates that these lignites are excellent source rock for hydrocarbon which could be obtained mainly through thermal cracking. The empirically derived values reveal a high conversion (94e96%) and high oil yield (64e66%) for these lignites. Ó 2015, China University of Geosciences (Beijing) and Peking University. Production and hosting by Elsevier B.V. This is an open access article under the CC BY-NC-ND license (http://creativecommons.org/ licenses/by-nc-nd/4.0/).

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“…A recent study by Marshall et al . () suggests that the base Palaeocene has experienced maximum burial temperatures of 120°C in the central part of the Central Tertiary Basin with a hyperthermal gradient of approximately 50°C/km. Log data from Braathen et al .…”

Section: Geological Settingmentioning

confidence: 97%

“…Based on the results of Marshall et al . (), the Tempelfjorden Group in central Spitsbergen (study area) may have been subjected to temperatures up to 180 to 190°C around the Oligocene/Miocene boundary.…”

Section: Geological Settingmentioning

confidence: 99%

Diagenesis of spiculites and carbonates in a Permian temperate ramp succession – Tempelfjorden Group, Spitsbergen, Arctic Norway

Matysik

Stemmerik

Olaussen³

et al. 2017

Sedimentology

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This paper explores little investigated diagenesis of spicule‐dominated sediments, based on Permian spiculites and cool‐water carbonates of the Tempelfjorden Group in central Spitsbergen. Field observations, petrography, stable isotope geochemistry, and mineralogical and chemical analyses reveal that the strata have been subjected to multistage diagenesis as the result of silica phase transitions at medium burial depths and deep‐burial overprinting. The growth of silica concretions occurred during the opal‐A/opal‐CT conversion and was controlled by the content and distribution of clay and spicules in the sediment, resulting in a variety of megascopic silica fabrics. Opal‐CT was subsequently dissolved, and all silica is now in a stable quartz stage. Petrographically, the rocks are characterized by a variety of chalcedony and quartz cements which perfectly preserve precursor textures. Most cements precipitated from silica‐oversaturated fluids, and their shapes reflect the silica saturation state and geometry of the pore space. Some microquartz and cryptoquartz also formed by a solid–solid inversion (recrystallization) of chalcedony. The cements have δ18O values between +30‰ and +20‰ Standard Mean Ocean Water and display a systematic depletion in 18O from the first to the last crystallized, interpreted to reflect a gradual increase in temperature during burial. The precipitation of quartz cements started in the Middle Triassic when the strata passed the 19°C isotherm at burial depths of ca 600 m, and was completed in the mid‐Cretaceous, 2·3 km beneath the sea floor at temperatures of 75°C. Late diagenetic overprinting of the chert includes fracturing, brecciation and cementation with carbonate cements having δ18O values between +2‰ and −30‰ Pee Dee Belemnite and δ13C values between +4‰ and −14‰ Pee Dee Belemnite; they are linked to hot solutions introduced during Cretaceous volcanism or Palaeogene tectonism. This study illustrates the diagenetic pathway during burial of spicule‐rich sediments in a closed system and thereby provides a baseline for studies of more complexly altered chert deposits.

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Geochemistry and petrology of palaeocene coals from Spitzbergen — Part 2: Maturity variations and implications for local and regional burial models

Cited by 52 publications

References 14 publications

Migrated Petroleum in Outcropping Mesozoic Sedimentary Rocks in Spitsbergen: Organic Geochemical Characterization and Implications for Regional Exploration

Migrated Petroleum in Outcropping Mesozoic Sedimentary Rocks in Spitsbergen: Organic Geochemical Characterization and Implications for Regional Exploration

Eocene lignites from Cambay basin, Western India: An excellent source of hydrocarbon

Diagenesis of spiculites and carbonates in a Permian temperate ramp succession – Tempelfjorden Group, Spitsbergen, Arctic Norway

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