Analysis of organic matter in small rock samples using combined thermal extraction and pyrolysis—gas chromatography

Solli, H.; Bjorøy, Malvin; Leplat, P.; Hall, Keith

doi:10.1016/0165-2370(84)80044-3

Cited by 25 publications

(8 citation statements)

References 21 publications

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“…It is associated with a high relative abundance of specific aromatic hydrocarbons (benzene, toluene and xylene) and a low ratio of cadalene to xylene (Cd/xylene) (0.06 to 0.12). This is consistent with a dominant input from vascular higher plants (Solli et al, 1984).…”

Section: Maceral Characteristics From Petrography and Kerogen Typingsupporting

confidence: 88%

Source Rock Potential of Organic‐rich Shales in the Tertiary Bhuban and Boka Bil Formations, Bengal Basin, Bangladesh

Farhaduzzaman

Abdullah

Islam

et al. 2012

Journal of Petroleum Geology

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Sandstones in the Miocene Bhuban and Lower Pliocene Boka Bil Formations contain all of the hydrocarbons so far discovered in the Bengal Basin, Bangladesh. Organic‐rich shale intervals in these formations have source rock potential and are the focus of the present study which is based on an analysis of 36 core samples from wells in eight gasfields in the eastern Bengal Basin. Kerogen facies and thermal maturity of these shales were studied using standard organic geochemical and organic petrographic techniques. Organic matter is dominated by Type III kerogen with lesser amounts of Type II. TOC is 0.16–0.90 wt % (Bhuban Formation) and 0.15–0.55 wt % (Boka Bil Formation) and extractable organic matter (EOM) is 132–2814 ppm and 235–1458 ppm, respectively. The hydrogen index is 20–181 mg HC/g TOC in the Bhuban shales and 35–282 mg HC/ g TOC in the Boka Bil shales. Vitrinite was the dominant maceral group observed followed by liptinite and inertinite. Gas chromatographic parameters including the C/S ratio, n‐alkane CPI, Pr/Ph ratio, hopane Ts/Tm ratio and sterane distribution suggest that the organic matter in both formations is mainly derived from terrestrial sources deposited in conditions which alternated between oxic and sub‐oxic. The geochemical and petrographic results suggest that the shales analysed can be ranked as poor to fair gas‐prone source rocks. The maturity of the samples varies, and vitrinite reflectance ranges from 0.48 to 0.76 %VRr. Geochemical parameters support a maturity range from just pre‐ oil window to mid‐ oil window.

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Section: Maceral Characteristics From Petrography and Kerogen Typingsupporting

confidence: 88%

Source Rock Potential of Organic‐rich Shales in the Tertiary Bhuban and Boka Bil Formations, Bengal Basin, Bangladesh

Farhaduzzaman

Abdullah

Islam

et al. 2012

Journal of Petroleum Geology

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“…This suggests that the samples from Gongila Formation are more mature than the Fika Formation. The calculated cadalene to xylene (cd/xy) ratios in the samples which range from 0.04 to 0.14, also imply a significant input from land-derived plants (Solli et al, 1984).…”

Section: Pyrolysis -Gc Data Of Kerogenmentioning

confidence: 93%

Kerogen characterisation and petroleum potential of the Late Cretaceous sediments, Chad (Bornu) Basin, northeastern Nigeria

Kayode¹,

Abdullah²,

Babangida³

et al. 2015

BGSM

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Detailed microscopic observations (palynofacies) and organic geochemical analyses were conducted on insoluble sedimentary organic matter (kerogens) from the Late Cretaceous sediments in the Chad (Bornu) Basin, northeastern Nigeria. This is to assess their origin, paleoenvironment and types, as well as their petroleum potential. The organic matter is mainly composed of mixed terrestrial plant and marine algae-derived AOMs. Phytoclasts are also present in significant amount in most of the samples, especially those obtained from the upper section of Fika Formation. However, most of the AOMs appears to be degraded and were not well preserved. The variations of relative abundances of marine and terrigenous organic matter may be controlled by terrestrial input in ocean and/or preservation rather than marine production. This organic matter was likely deposited in marine environment under environmental conditions that were mostly dysoxic. The intense degradation observed in most of the organic matter may be as a result of high thermal maturity. Further evidences in this study confirmed that most of the potential source rocks in Chad (Bornu) Basin contain Type III kerogens, but Type III/II kerogens were also present in some parts of the basin, especially at the upper section of Fika Formation. It was also revealed that most of the samples, especially those at the deeper sections of the basin display high aromatic character which suggest a dominant gas-prone nature of the organic matter. This study confirmed that a potential for gas generation exist in this basin.

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“…Thereby the furnace unit is not directly connected to an FID, but the produced hydrocarbons are collected in a cooling trap and released to a GC-FID or GC-MS (mass spectrometer) after the pyrolysis is completed. Also combined systems are possible (Bjorøy et al, 1986;Solli et al, 1984), enabling the simultaneous measurement of bulk parameter S1 and S2 and measurement of molecular compounds by GC. The main differences between the developed systems are found in the heating units (Bordenave, 1993).…”

Section: Pyrolysis Coupled With Gas Chromatography (Py-gc)mentioning

confidence: 99%

“…This leads to differences to closed pyrolysis, most evident in the yields of alkenes and aromatics. In open anhydrous pyrolysis higher yields of alkenes were observed than in closed pyrolysis techniques (Behar and Pelet, 1985;Solli et al, 1984). If the products are not removed immediately after generation, like in closed pyrolysis, they can be alkylated or hydrogenated by present hydrogen donors (kerogen, bitumen, water).…”

Section: Open Vs Closed Pyrolysismentioning

confidence: 99%

Experimental Simulation Of Hydrocarbon Expulsion

Schwark¹,

Stockhausen²,

Galimberti³

et al. 2014

International Petroleum Technology Conference

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Investigating generation, expulsion and primary migration usually suffers from inadequate methodologies, failing in the provision of natural conditions, prevailing during the genesis of oil and gas. Destructive sample preparation, inappropriate pressure regimes and pyrolysis in closed mode and/or in the absence of water caused results not representative for natural processes. To overcome these limitations, a newly designed apparatus was developed and built, capable to perform pyrolysis experiments with intact rock samples under pressure regimes, prevailing during catagenesis. In detail, lithostatic (or overburden-) pressures and hydrostatic (or pore-) pressures, corresponding to 3000 m depth and beyond, can be simulated by this apparatus, the "Expulsinator" device. Additionally, the experiments are conducted as hydrous, semi-open pyrolysis, allowing the time-based sampling of the expelled products. Thus, generation/expulsion profiles are generated for each investigated source-rock. Comparison of generation and expulsion efficiency of the Expulsinator with established pyrolysis methodologies (MSSV, HyPy, Rock Eval and closed small vessel pyrolysis (CSVP)) reveals striking differences: Expulsinator experiments yielded more bitumen and released lower gas amounts than classic pyrolysis. This is caused by secondary alteration of products in case of classic pyrolysis, e.g. oil to gas cracking at higher temperatures and polymerization to pyrobitumen. The open setup of the Expulsinator experiments prevents successfully secondary alteration, increasing the liquid product yields and lowering the gas formation. This is mirrored in TOC conversion rates as well: Expulsinator conversion exceeds 81 %, whereas those of hydrous CSVP remains at 65 %. Further, interactions between kerogen, bitumen, pyrobitumen and pyrite are reduced in case of Expulsinator experiments. In contrast, CSVP experiments residues show enrichment of nitrogen and oxygen and depletion of sulphur, indicating intense interaction between the mentioned components. Investigating the impact of catagenesis onto the yields and composition of expelled products was carried out by a stepwise experimental setup, simulating burial depths of ~2000 m, ~2500 m and 3000 m, implementing overburden pressures from 600 bar to 900 bar and hydrostatic pressures from 200 bar to 300 bar. Each experiment step shows a distinct expulsion maximum of liquid hydrocarbons, reaching the total maximum at 3000 m. Confrontation of Expulsinator results with comparative CSVP and MSSV experiments reveal expulsion and primary migration effects onto the n-alkane distribution in dependence of maturation and subsidence. An n-alkane increase towards larger molecular size with ongoing expulsion is associated with molecular size controlled retention effects. The expulsion progress is mirrored in trends of isoprenoid-ratios (pristane vs. phytane) and isoprenoidn-alkaneratios (pristane vs. n-C17), caused mainly by generation controlled effects. However, both ratios qualify as expulsion indicator, taking ...

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Analysis of organic matter in small rock samples using combined thermal extraction and pyrolysis—gas chromatography

Cited by 25 publications

References 21 publications

Source Rock Potential of Organic‐rich Shales in the Tertiary Bhuban and Boka Bil Formations, Bengal Basin, Bangladesh

Source Rock Potential of Organic‐rich Shales in the Tertiary Bhuban and Boka Bil Formations, Bengal Basin, Bangladesh

Kerogen characterisation and petroleum potential of the Late Cretaceous sediments, Chad (Bornu) Basin, northeastern Nigeria

Experimental Simulation Of Hydrocarbon Expulsion

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