by, scientific inquiry. Without the appropriate care and scholarly caution, even the most neutral scientist's work can be perceived as compromised to both scholarly and non-scholarly audiences.

Du, F., Nojabaei, B., 2020. A black-oil approach to model produced gas injection in both conventional and tight oil- rich reservoirs to enhance oil recovery. Fuel 263, 116680.

http://www.sciencedirect.com/science/article/pii/S0016236119320344 A robust compositionally extended black-oil simulation approach is developed, which is capable of including the effect of large gas-oil capillary pressure for first contact miscible (FCM), and immiscible gas injection. The simulation methodology is applied to gas flooding in both high and very low permeability reservoirs. For a high permeability conventional reservoir, simulations use a five-spot pattern with different reservoir pressures to mimic both FCM and immiscible displacements. The results show that the simple modified black-oil approach can model well both immiscible and miscible floods, as long as the minimum miscibility pressure (MMP) is matched. For a tight oil-rich reservoir, primary depletion and huff-n-puff gas injection are simulated including the effect of large gas-oil capillary pressure in flow and in flash calculation on recovery. Finally, a dynamic gas- oil relative permeability correlation that accounts for the compositional changes owing to the produced gas injection is introduced and applied to correct for changes in interfacial tension (IFT), and its effect on oil recovery is examined. The results show that the new black-oil approach can model these processes well and could be implemented when fully compositional simulations are computationally too time consuming. For the first time, a black-oil type reservoir simulation method is used to simulate near-miscible and immiscible produced gas injection enhanced oil recovery. It provides a fast and robust alternative for large-scale reservoir simulation with the purpose of flaring/venting reduction through reinjecting the produced gas into the reservoir for EOR.

Du, X., Lu, Y., Duan, D., Liu, Z., Zhao, K., Jia, J., Fu, H., 2020. Was volcanic activity during the Ordovician- Silurian transition in South China part of a global phenomenon? Constraints from zircon U - Pb dating of volcanic ash beds in black shales. Marine and Petroleum Geology 114, 104209.

http://www.sciencedirect.com/science/article/pii/S0264817219306634 Whether volcanic activity during the Ordovician-Silurian transition (OST) in South China (SC) contributed to global volcanic activity has always been a controversial subject. Volcanic ash is the most direct evidence for volcanic activity and represents a good marker to compare SC with the global stratigraphic correlation. Here, we analyze the distribution of volcanic ash beds in three outcrops in SC and precisely determine the ages of volcanic ash zircons using the LA-ICP-MS and SHRIMPII methods. A comparison of the volcanic ash beds in three different outcrops of SC during the OST; indicates that relatively large-scale volcanic activity occurred during this period. The newly obtained zircon U - Pb ages show that the starting time of the Ordovician Wufeng Fm. was approximately 449.2 Ma (or 449.3 Ma), the starting time of the Ordovician Guanyingqiao bed (the ending time of the Wufeng Fm.) was approximately 445.6 Ma, and the starting time of the Longmaxi Fm. was approximately 444.2 Ma. In addition, the durations of the Wufeng Fm. and Guanyingqiao bed were 3.6 Ma and 1.4 Ma, respectively, and the duration of the Hirnantian stage in SC was 1.4 Ma. Most of the ages obtained in this study were basically consistent with that of the International Commission on Stratigraphy (GST 2018). These results provide insights into the volcanic activity during the OST in SC as well as age data for a global stratigraphic framework.

Duan, S., Gu, M., Tao, M., Xian, X., 2020. Adsorption of methane on shale: Statistical physics model and site energy distribution studies. Energy &Fuels 34, 304-318.

https://doi.org/10.1021/acs.energyfuels.9b03746 Adsorption behaviors of methane on four Sichuan Basin shales at different temperatures (318, 338, and 358 K) were experimentally investigated. The adsorption equilibrium data were best fitted by using the modified Hill-