Reconstruction of rapid charge of a giant gas field across a major fault zone using 3D petroleum systems modelling (Taranaki Basin, New Zealand)

Evaluation of Re–Os geochronology and Os isotope fingerprinting of Late Cretaceous terrestrial oils in Taranaki Basin, New Zealand

“…Commercial petroleum accumulations have been encountered at every stratigraphic level from the Paleocene to Pliocene (King and Thrasher, 1996). Most accumulations are trapped in fault-related anticlines that formed in the last 30 to 40 Myr in response to compression associated with subduction of the Pacific Plate to the east of New Zealand (King and Thrasher, 1996;Stagpoole and Nicol, 2008;Reilly et al, 2016;Seebeck et al 2019;Kroeger et al, 2021).…”

“…The more recent basin modelling studies favour charging of the Tui Area Field from the northern Kahurangi Trough; the Maui Field, primarily from the Maui sub-basin, with migration across the Cape Egmont Fault Zone; and the Maari-Manaia Field primarily from the Maui sub-basin, potentially with a subordinate local fluid contribution from the small Maari sub-basin (Fig. 2; Smith et al, 2016;Kroeger et al, 2016Kroeger et al, , 2021Seebeck et al, 2019). In all cases, the abundance of gymnosperm-derived diterpene biomarkers within the oils indicates derivation from Late Cretaceous coaly rocks of the Rakopi and North Cape formations (Killops et al, 1994;Sykes et al, 2012;Sykes and Zink, 2018;Sykes, 2019).…”

Reconstruction of palaeo‐oil reservoirs in the ultra‐deep and over‐mature Sinian Dengying Formation of the Central Sichuan Basin: Insights from basin and petroleum system modelling

“…Basin and petroleum system modelling (BPSM) is an important and advanced research method for oil and gas reservoir simulations and evaluations. It is widely used for hydrocarbon generation and expulsion from source rocks (Albriki et al, 2021; Alipour et al, 2022; Lutz et al, 2021; Wang et al, 2023; Zeinalzadeh et al, 2015), pressure and temperature (P–T) evolution (Mohamed et al, 2016; Nguyen et al, 2016), fluid property simulation and formation process prediction (Ahmed et al, 2022; Baur & Katz, 2018; D'Ambrosio et al, 2021; Evenick, 2022; Feng et al, 2020; Kishankov et al, 2022; Kroeger et al, 2021, 2022), and exploration risk assessment in low‐medium maturity and low‐exploration target regions (Badejo et al, 2021; Lawson et al, 2018; Liu & Liu, 2023). Its simulation path from the source rock to the traps has the ability to avoid relying on bitumen observations from massive but limited borehole data, making it possible to reconstruct the PORs distribution in the historical period of present‐day high to over‐mature regions.…”