Investigation on the lignite deposits of Surkha mine (Saurashtra Basin, Gujarat), western India: Their depositional history and hydrocarbon generation potential

Singh, Vikram P.; Singh, Bhagwan D.; Mathews, Runcie P.; Singh, Ashutosh Kumar; Mendhe, Vinod Atmaram; Singh, Prakash; Mishra, Subhashree; Dutta, Suryendu; Shivanna, Mahesh; Singh, Mahendra

doi:10.1016/j.coal.2017.09.016

Cited by 52 publications

(9 citation statements)

References 86 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…It can be seen from Figure 7(a) and (b) that under the same geological mining conditions, the coal pillar principal stress of room temperature is much larger than that of the high temperature. This is mainly because the lignite is a weakly coking coal and average T max value (416 C) (Singh et al, 2017), and the elastic modulus decreases sharply under the high temperature. The ability to resistance deformation has enhanced with the bulk modulus and shear modulus increasing under the high temperature effect.…”

Section: Discussionmentioning

confidence: 99%

“…Coal pillar elastic area will decrease due to weathering, local yielding, or rib spalling (Merwe, 2003; Merwe and Mathey, 2013; Salamon et al., 1998; Vander, 1993) etc., thereby leading to the coal pillar size gradually diminishing and the coal pillar peeling phenomenon occurring. After the peeling, the ruptured coal blocks are scattered and accumulated in the coal pillar vicinity that provides a certain lateral stress, while the actual yield zone width has changed at this time.…”

Section: Coal Pillar State and Stabilitymentioning

confidence: 99%

See 1 more Smart Citation

Stability analysis of hyperbolic coal pillars with peeling and high temperature effects

Guo

et al. 2020

Energy Exploration & Exploitation

View full text Add to dashboard Cite

In this present study, a twice-peeling model was established to analyze the hyperbolic coal pillars stability in underground coal gasification and then propose the concept of stripping degree to show model details for numerical simulation. The data shows that hyperbolic coal pillars stability can be analyzed through the twice-peeling model. Considering the coal pillars peeling and high temperature effects, one side of coal pillars will decrease 3 m, and the stability coefficient is 1.6 which has enough bearing capacity. When the arch depth ratio is 0.6, the critical condition for the coal pillar instability is reached. In this paper, underground coal gasification industrial test area still had strong bearing capacity after twice stripping, and there was no sudden instability. The research results can provide reference for the gasifier design and the stability of non-uniform coal pillars in the future.

show abstract

Section: Discussionmentioning

confidence: 99%

Section: Coal Pillar State and Stabilitymentioning

confidence: 99%

Stability analysis of hyperbolic coal pillars with peeling and high temperature effects

Guo

et al. 2020

Energy Exploration & Exploitation

View full text Add to dashboard Cite

show abstract

“…The study area contains two sets of hydrocarbon source rocks: Middle–Lower Triassic lacustrine source rocks, and coal measure source rocks of the Upper Triassic to Jurassic Taliqike Formation. The organic macerals in both of these source rocks are similar, with the Triassic lacustrine source rocks being dominated by type III organic matter with subordinate type II organic matter, whereas the coal measure source rocks are dominated by type III organic matter (Singh, 2012; Singh and Singh, 1994a, 1994b; Singh et al., 2013, 2017; Wang et al., 2009). According to the carbon isotope data, the shallow Palaeogene and Neogene gas condensates in the Dibei area are derived mainly from Jurassic coal measure source rocks, and the gas condensates in the Ahe Formation are derived mainly from Triassic lacustrine source rocks along with minor amounts of oil derived from Jurassic coal measure source rocks.…”

Section: Distribution and Geochemical Characteristics Of Gas Condensatementioning

confidence: 98%

“…The prevailing view is that the Jurassic petroleum was derived from coal measure source rocks (Lu et al, 2016), although there is some evidence for contributions from lacustrine source rocks (Zhuo et al, 2012). Coal has been reported as a source rock for oil and gas (Powell and Boreham, 1994;Singh et al, 2013) and there are several studies which show the relation of coal with oil and gas (Singh, 2012;Singh andSingh, 1994a, 1994b;Singh et al, 2016bSingh et al, , 2016aSingh et al, , 2017. Most previous studies in this area are focused on the fluid distribution along an N-S cross-section to assess whether the Dibei gas reservoir is a deep basin gas reservoir (Lu et al, 2015;Xing et al, 2011).…”

Section: Introductionmentioning

confidence: 99%

Fluid geochemistry of the Jurassic Ahe Formation and implications for reservoir formation in the Dibei area, Tarim Basin, northwest China

Zhao

Wen

Wang

et al. 2018

Energy Exploration & Exploitation

View full text Add to dashboard Cite

The condensate gas reservoirs of the Jurassic Ahe Formation in the Dibei area of the Tarim Basin, northwest China are typical tight sandstone gas reservoirs and contain abundant resources. However, the hydrocarbon sources and reservoir accumulation mechanism remain debated. Here the distribution and geochemistry of fluids in the Ahe gas reservoirs are used to investigate the formation of the hydrocarbon reservoirs, including the history of hydrocarbon generation, trap development, and reservoir evolution. Carbon isotopic analyses show that the oil and natural gas of the Ahe Formation originated from different sources. The natural gas was derived from Jurassic coal measure source rocks, whereas the oil has mixed sources of Lower Triassic lacustrine source rocks and minor amounts of coal-derived oil from Jurassic coal measure source rocks. The geochemistry of light hydrocarbon components and n-alkanes shows that the early accumulated oil was later altered by infilling gas due to gas washing. Consequently, n-alkanes in the oil are scarce, whereas naphthenic and aromatic hydrocarbons with the same carbon numbers are relatively abundant. The fluids in the Ahe Formation gas reservoirs have an unusual distribution, where oil is distributed above gas and water is locally produced from the middle of some gas reservoirs. The geochemical characteristics of the fluids show that this anomalous distribution was closely related to the dynamic accumulation of oil and gas. The period of reservoir densification occurred between the two stages of oil and gas accumulation, which

show abstract

“…This cross correlation was successfully applied in the current study, and provided a good means of calibration between the TWL-based (i.e., spore colouration) and the RWL-based (i.e., vitrinite reflectance/UV fluorescence) thermal maturity analyses. Furthermore, most hydrocarbon exploration studies have identified the environmental settings of the organic facies mainly based on RWL organic petrography and geochemical analyses (e.g., Singh et al, 2017b). In this study, we will present an interpretation of the depositional environments based mainly on integrating palynological and sedimentological data.…”

Section: Introductionmentioning

confidence: 99%

Organic geochemical, palynofacies, and petrographic analyses examining the hydrocarbon potential of the Kharita Formation (Albian) in the Matruh Basin, northwestern Egypt

Deaf

Tahoun

Gentzis

et al. 2020

Marine and Petroleum Geology

View full text Add to dashboard Cite

A recent study of selected samples from the Cretaceous (Albian) Kharita Formation of Egypt revealed very good to excellent source rock (SR) potential for six intraformational, organic-rich intervals. This work investigates the SR potential of the entire Kharita Formation across the Matruh Basin, using samples from two wells: the Abu Tunis 1X well from the central part of the basin, and the Siqeifa 1X well drilled on the eastern margin of the basin. More strongly reducing conditions were developed in the centre of the basin, and resulted in the deposition of more organic-rich shales by comparison to the less reducing conditions that prevailed on the eastern basin margin, where the shales contain less organic matter. Deltaic intraformational shales and carbonates in the Kharita Formation of Abu Tunis 1X constitute a significant 120 m net of the potential SR. The lower Kharita Formation contains 34 m net shale SR of good to very good/excellent organic richness, yielding values of 1.14-11.59 wt % total organic carbon (TOC). The organic matter has low Hydrogen Index (HI) values (184-389 mg HC/g TOC) and amorphous organic matter (AOM) and relatively high non-opaque phytoclast frequencies indicating mainly gas/oil-prone organofacies (kerogen types II/III). The upper Kharita is more important, containing 86 m net shale/carbonate SR that has fair to good organic richness (0.8-1.8 wt % TOC), and lower HI (126-250 mg HC/g TOC), a dominance of non-opaque phytoclasts, and subordinate AOM frequencies, which together indicate gas/oil-prone organofacies (kerogen Types III/II). In the Siqeifa 1X well, Kharita deltaic intraformational shales and shaley dolostones comprise 80 m net SR, which has mainly fair to good to less very good organic richness (0.8-2.1 wt % TOC), whilst low HI (93-220 mg HC/g TOC), dominance of non-opaque phytoclasts and subordinate AOM indicate gas-prone organofacies (kerogen Type III). A relative upward increase in deposition of lignite and coaly carbonaceous material supports a gas-prone organofacies. Whilst thermal maturity indices only point to immature to early mature (pre-to early oil-window) SRs in both the Abu Tunis 1X and Siqeifa 1X wells, hydrocarbon exploration focussing on this potential source rock may be justified in areas to the southeast of the Matruh Basin, where modelling indicates this unit may have reached the late mature oil-to main gas-generation window.

show abstract

Investigation on the lignite deposits of Surkha mine (Saurashtra Basin, Gujarat), western India: Their depositional history and hydrocarbon generation potential

Cited by 52 publications

References 86 publications

Stability analysis of hyperbolic coal pillars with peeling and high temperature effects

Stability analysis of hyperbolic coal pillars with peeling and high temperature effects

Fluid geochemistry of the Jurassic Ahe Formation and implications for reservoir formation in the Dibei area, Tarim Basin, northwest China

Organic geochemical, palynofacies, and petrographic analyses examining the hydrocarbon potential of the Kharita Formation (Albian) in the Matruh Basin, northwestern Egypt

Contact Info

Product

Resources

About