Integrating Solvent Extraction With Standard Pyrolysis to Better Quantify Thermal Maturity and Hydrocarbon Content in the Oil Window

Collins, Dylan R.; Lapierre, Scott G.

doi:10.15530/urtec-2014-1922397

Cited by 10 publications

(10 citation statements)

References 6 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The post solvent extraction (pre-cleaning using hot water and detergent followed by two stages of Soxhlet solvent extraction using dichloromethane) pyrogram contains a smaller S1 peak (0.9 mg/g) with no low temperature S2 shoulder and a smaller S2 peak (3.9 mg/g) ( Figure 3). These results confirm the previous published findings (Collins and Lapierre, 2014) there is a significant spill over of generated hydrocarbon and non-hydrocarbon material (free hydrocarbons) into the S2 kerogen peak within LRU source rocks. Note that the S1 still contains a significant amount of material (0.9 mg/g) even after a rigorous solvent washing process.…”

Section: Programmed Pyrolysis Before and After Solvent Extractionsupporting

confidence: 92%

“…Several studies have shown standard programmed pyrolysis S1 will not capture all the total free and adsorbed in-situ oil due to evaporative losses during sample collection and processing; and the S2 carry over (Jarvie, 2012;Collins and Lapierre, 2014;Michaels et al, 2013;Abrams, 2014; Carvajal-Ortiz and Gentzis, 2015).…”

Section: Examination Of Free Hydrocarbon Using Programmed Pyrolysis Smentioning

confidence: 99%

“…Heavier, free and adsorbed hydrocarbon and non-hydrocarbon material will only vaporize at higher temperatures and thus may not be included in the S1 measurement. These higher molecular weight hydrocarbon and non-hydrocarbon compounds such as high molecular weight resin compounds and asphaltenes will show up as a low temperature shoulder prior the standard S2 peak (Abrams, 2014) as well as within the S2 peak (Jarvie, 2012;Collins and Lapierre, 2014;Carvajal-Ortiz and Gentzis, 2015).…”

Section: Examination Of Free Hydrocarbon Using Programmed Pyrolysis Smentioning

confidence: 99%

See 2 more Smart Citations

A new thermal extraction protocol to evaluate liquid rich unconventional oil in place and in-situ fluid chemistry

Abrams

Gong²,

Garnier

et al. 2017

Marine and Petroleum Geology

View full text Add to dashboard Cite

Section: Programmed Pyrolysis Before and After Solvent Extractionsupporting

confidence: 92%

Section: Examination Of Free Hydrocarbon Using Programmed Pyrolysis Smentioning

confidence: 99%

Section: Examination Of Free Hydrocarbon Using Programmed Pyrolysis Smentioning

confidence: 99%

See 1 more Smart Citation

A new thermal extraction protocol to evaluate liquid rich unconventional oil in place and in-situ fluid chemistry

Abrams

Gong²,

Garnier

et al. 2017

Marine and Petroleum Geology

View full text Add to dashboard Cite

“…However, a much higher oil content revealed by multistage pyrolysis than that from standard pyrolysis and a large difference between solvent extracted and unextracted pyrolysate yields indicated that a significant amount of solvent extractable hydrocarbons was not captured in the S 1 and rolled over into the S 2 peak (Jarvie, 2012 [4]; Han et al, 2015 [23]; Raji et al, 2015 [9]). Collins and Lapierre [24] noted that 20%-65% of the S 2 peak was soluble in common organic solvents. Zink et al [10] found that the total oil included the extractable S 2 component was 2.2 to 3.6 times higher than that determined from S 1 only.…”

Section: Introductionmentioning

confidence: 99%

Investigation on Oil Physical States of Hybrid Shale Oil System: A Case Study on Cretaceous Second White Speckled Shale Formation from Highwood River Outcrop, Southern Alberta

2022

View full text Add to dashboard Cite

Nine samples collected from the Upper Cretaceous Second White Speckled Shale Formation at the Highwood River outcrop in southern Alberta were geochemically characterized for their oil contents, physical states, and chemical compositions. Cold extraction was performed on 8–10 mm and 2–5 mm chips sequentially to obtain the first and second extractable organic matter (EOM-1 and EOM-2), while Soxhlet extraction was performed on powder from previously extracted chips to obtain the third extract (EOM-3). EOM-1 can be roughly regarded as free oil and EOM-2 is weakly adsorbed on mineral surfaces, while EOM-3 may represent the oil strongly adsorbed on kerogen. While both extraction yields and Rock-Eval pyrolysates differed from their original values due to the evaporative loss during outcropping, there was a generally positive correlation between the total EOM and total oil derived from Rock-Eval pyrolysis. EOM-1 was linearly correlated with Rock-Eval S1, while the extractable S2 content was well correlated with the loss of TOC, suggesting that TOC content was the main constraint for adsorbed oils. A bulk composition analysis illustrated that EOM-1 contained more saturated hydrocarbons, while EOM-3 was enriched in resins and asphaltenes. More detailed fractionation between the free and adsorbed oils was demonstrated by molecular compositions of each extract using quantitative GC-MS analysis. Lower-molecular-weight n-alkanes and smaller-ring-number aromatic compounds were preferentially concentrated in EOM-1 as compared to their higher-molecular or greater-ring-number counterparts and vice versa for EOM-3. Fractionation between isoprenoids and adjacent eluted n-alkanes, isomers of steranes, hopanes, alkylnaphthalenes, alkylphenanthrenes and alkyldibenzothiophenes was insignificant, suggesting no allogenic charge from deep strata. Strong chemical fractionation between saturated and aromatic hydrocarbon fractions was observed with EOM-1 apparently enriched in n-alkanes, while EOM-3 retained more aromatic hydrocarbons. However, the difference between free and adsorbed state oils was less dramatic than the variation from shales and siltstones. Lithological heterogeneities controlled both the amount and composition of retained fluids. Oil that resided in shales (source rock) behaved more similar to the EOM-3, with diffusive expulsion leading to the release of discrete molecules from a more adsorbed or occluded phase to a more free phase in siltstones with more connected pores and/or fractures (reservoir). Under current technical conditions, only the free oil can flow and will be the recoverable resource. Therefore, the highest potential can be expected from intervals adjacent to organic-rich beds. The compositional variations due to expulsion and primary migration from source rocks to reservoirs illustrated in the present study will contribute to a better understanding of the distribution of hydrocarbons generated and stored within the shale plays.

show abstract

“…Pure kerogen separates have been prepared and analyzed by pyrolysis; 4 slower pyrolysis heating rates have been used to separate S2a and S2b peaks; 6,7,9 and solvent extraction has been used to remove adsorbed hydrocarbon. 2,3,5,7,10,11 Synnott et al 1 also performed solvent extraction on a subset of samples from the Cape Phillips Formation. These experiments indicated a large difference in S2 curves between pre-and post-solvent-extracted samples, with the S2 peak being reduced by up to 30% and decreasing T max post-extraction by several degrees.…”

Section: ■ Introductionmentioning

confidence: 99%

Correcting T_max Suppression: A Numerical Model for Removing Adsorbed Heavy Oil and Bitumen from Upper Ordovician Source Rocks, Arctic Canada

et al. 2019

View full text Add to dashboard Cite

A Rock-Eval 6 dataset of 66 samples from the Cape Phillips Formation in the Canadian Arctic region was studied to investigate source rock characteristics and petroleum generation potential. Bulk geochemical characteristics and thermal decomposition behavior of the samples indicate an initial generation potential close to 700 mg HC/g TOC and show an unusually low onset T max temperature for petroleum generation. This led to an examination of possible T max suppression due to a large amount of high-molecular-weight heavy oil and bitumen derived from the early breakdown of kerogen in the samples. Application of a numerical method based on kerogen decomposition kinetics allows for the numerical removal of thermal evaporative products of oil and bitumen adsorbed in the sample without requiring additional pyrolysis experiments or solvent extraction treatments of sample replicates. The removal of the adsorbed hydrocarbon from samples increases the T max value up to 17 °C. The estimated petroleum in the sorption phase varies from 1 to about 9 mg HC/g rock, depending on the total organic content (TOC) and maturity, and is the main form of the total oil yield in this area. The corrected T max–HI cross-plot suggests an onset of petroleum generation around 435 °C of T max, consistent with the general consensus for a normal marine source rock in this region. The constructed kinetic model shows a maximum of 75% transformation ratio (TR), and most samples show TR ranging from 10 to 50% in the early oil generation window on Cornwallis Island. This reconstructed source rock thermal decomposition model in a geological time scale indicates the onset of massive petroleum generation at a temperature of 120 °C, and the maximum transformation ratio of 75% corresponds to a temperature of 140 °C over geological time.

show abstract

Integrating Solvent Extraction With Standard Pyrolysis to Better Quantify Thermal Maturity and Hydrocarbon Content in the Oil Window

Cited by 10 publications

References 6 publications

A new thermal extraction protocol to evaluate liquid rich unconventional oil in place and in-situ fluid chemistry

A new thermal extraction protocol to evaluate liquid rich unconventional oil in place and in-situ fluid chemistry

Investigation on Oil Physical States of Hybrid Shale Oil System: A Case Study on Cretaceous Second White Speckled Shale Formation from Highwood River Outcrop, Southern Alberta

Correcting T_max Suppression: A Numerical Model for Removing Adsorbed Heavy Oil and Bitumen from Upper Ordovician Source Rocks, Arctic Canada

Contact Info

Product

Resources

About

Integrating Solvent Extraction With Standard Pyrolysis to Better Quantify Thermal Maturity and Hydrocarbon Content in the Oil Window

Cited by 10 publications

References 6 publications

A new thermal extraction protocol to evaluate liquid rich unconventional oil in place and in-situ fluid chemistry

A new thermal extraction protocol to evaluate liquid rich unconventional oil in place and in-situ fluid chemistry

Investigation on Oil Physical States of Hybrid Shale Oil System: A Case Study on Cretaceous Second White Speckled Shale Formation from Highwood River Outcrop, Southern Alberta

Correcting Tmax Suppression: A Numerical Model for Removing Adsorbed Heavy Oil and Bitumen from Upper Ordovician Source Rocks, Arctic Canada

Contact Info

Product

Resources

About

Correcting T_max Suppression: A Numerical Model for Removing Adsorbed Heavy Oil and Bitumen from Upper Ordovician Source Rocks, Arctic Canada