Contents 2018
Contents 2017
Contents 2016
Contents 2015
Contents 2014
Contents 2013
Contents 2012
Contents 2011
Contents 2010
Contents 2009
Contents 2008
Contents 2007
Contents 2006
Contents 2005
Contents 2004
PESGB/IAS members & Geol. Soc. Fellows
Digital Archive
Online Version
Join Our
Mailing List
FREE e-alerts
Sign up to receive free email alerts containing the Table of Contents for the Journal of Petroleum Geology
Journal of Petroleum Geology Journal of Petroleum Geology Journal of Petroleum Geology Journal of Petroleum Geology Journal of Petroleum Geology Journal of Petroleum Geology
Journal of Petroleum Geology April 2015
Published in the UK © 2018 Scientific Press Ltd.

Contents of Vol. 29, no. 1-4 2006

Vol. 29, no. 4, October 2006

Is there a viable petroleum system in the
Carson and Salar Basins, offshore Newfoundland?
J.B.W. Wielens (Geological Survey of Canada Atlantic), C. D. Jauer and G. L. Williams view abstract

Higher plant biomarkers in Paleogene crude oils
from the Yufutsu oil- and gasfield and offshore wildcats, Japan
S. Yessalina (Hokkaido University), N. Suzuki, H. Nishita and A. Waseda view abstract

Petroleum potential, thermal maturity and the oil window
of oil shales and coals in Cenozoic rift-basins,
central and northern Thailand
H. I. Petersen (GEUS Denmark), A. Foopatthanakamol and B. Ratanasthien view abstract

Organic-inorganic interactions in oilfield sandstones:
Examples from turbidite reservoirs in the Campos Basin,
offshore Eastern Brazil 361-380
E. A. Prochnow (Universidade Federal do Rio Grande do Sul, Brazil) et al. view abstract

The origin of dolomite in the Asmari Formation
(Oligocene - Lower Miocene), Dezful Embayment, SW Iran
A.A.M. Aqrawi (Statoil) et al. view abstract

Obituary: G. D. Hobson

Index, 2006

International Events

Cover: The cover figure illustrates a digital model of the Carson Basin, offshore Newfoundland (eastern Canada) and shows a significant moment in the basin's geological history: the reservoir rock (in yellow: sandstones of the Jeanne d'Arc Formation) has been deposited on top of the source rock (brown: shales of the Egret Member). Legend: red - basement; orange - sand/siltstone; green - salt; purple - dolomite; grey - shale; blue - limestone. The orange tip of the grey compass points north. Black crosses are well locations: B: Bonnition H-32; O: Osprey H-84; S: Skua E-41; G: St. George J-55. See the related paper by Wielens et al.

Vol. 29, no. 3, July 2006

Exploring for fan and delta sandstones in the offshore Falklands Basins
P. Richards (BGS) et al. view abstract

Cylindrical and conical fold geometries in the Cantarell structure, Southern Gulf of Mexico: Implications for hydrocarbon exploration
J. J. Mandujano V. (Inst. Mexicano del Petroleo) and J. D. Keppie M. view abstract

Petroleum migration, faults and overpressure, Part I: calibrating basin modelling using petroleum in traps - a review
D. A. Karlsen and J. E. Skeie (University of Oslo) view abstract

Mineralogical, pore and petrophysical characteristics
of the Devonian Jauf Sandstone reservoir, Hawiyah field,
Eastern Saudi Arabia
S. Saner et al. (King Fahd University of Petroleum and Minerals) view abstract

Predicting the timing and characteristics of petroleum formation using tar mats and petroleum asphaltenes: A case study from the Northern North Sea
M. Keym and V. Dieckmann (GeoForschungsZentrum, Potsdam) view abstract

Book review

International Events

Cover: Diagrams illustrate a two-stage model of fault-block filling with petroleum migration across a fault. Stage 1: a petroleum column builds up in carrier sands near the fault zone, and oil is injected into the fault and moves upwards due to buoyancy forces. Petroleum migrates into the first hydrostatic reservoir encountered (i.e. the deepest reservoir strata) until equilibrium is established between the oil in the fault zone and that in the reservoir. Quartz cementation may partly seal the fault zone during progressive burial. Stage 2: continued burial results in source rock maturation and renewed oil expulsion, and another oil charge builds up in the migration avenue. As in stage 1, this oil moves upwards in the fault zone until it meets a hydrostatic reservoir unit -- in this case, a shallower unit than in stage 1. The result is that the reservoir fills from the bottom up, with individual reservoir units containing petroleum of varying maturity, GOR and API. See the related paper by Karlsen and Skeie.

Volume 29, no. 2, April 2006

• Source-rock evaluation and basin modelling in NE Egypt (NE Nile Delta and Northern Sinai)
F. Shaaban (Mansoura University, Egypt), R. Lutz, R. Littke, C. Bueker and K. Odisho view abstract

• Analysis of reserves discovered in petroleum exploration
D. G. Quirk (Maersk Oil and Gas) and R. Ruthrauff view abstract

• Obtaining fracture information for low-permeability (tight) gas sandstones from sidewall cores
S. E. Laubach (University of Texas) and J. F. W. Gale view abstract

• Seismic facies analysis based on 3D multi-attribute volume classification, Dariyan Formation, SE Persian Gulf
P. Farzadi (University of Bergen, Norway) view abstract

• Biomarker geochemistry of crude oils from the Qaidam Basin, NW China
by Yi Duan (Lanzhou Institute of Geology, China) et al. view abstract

• Possible correlations between crude oil chemical composition and reservoir age
Y. M. Polichtchouk (Institute of Petroleum Chemistry, Tomsk, Russia) and I. G. Yashchenko view abstract

• International Events

• Cover: Background photograph shows a fracture swarm in Cambrian sandstones in NW Scotland. Top left: coring underway at a rig in West Texas. Lower left: measurement of fracture size distributions along a line of observation in an outcrop of the Cambrian Eriboll Sandstones (NW Scotland) which is an analogue for a tight gas sandstone reservoir. Middle: open fracture in Jurassic La Boca Formation sandstones, NE Mexico (SEM cathodoluminescence image showing fracture porosity (green) and quartz bridges (blue); scale bar is 200 ?m). Lower right: quartz bridges (white) and fracture porosity (dark) at core scale (La Boca Formation, NE Mexico); fracture aperture is about 2.5 mm. Photos by Steve Laubach, Leonel Gomez and Rob Reed. See the related paper by Laubach and Gale.

Vol.29, no. 1, January 2006

• Depositional environments, organic maturity and petroleum potential of the Cretaceous coal-bearing Atane Formation at Qullissat, Nuussuaq Basin, West Greenland
by G. K. Pedersen (University of Copenhagen), L. A. Andersen, E. B. Lundsteen, H. I. Petersen, J. A. Bojesen-Koefoed and H. P. Nytoft view abstract

• Hydrothermally fluoritized Ordovician carbonates as reservoir rocks in the Tazhong area, Central Tarim Basin, NW China
by Zhijun Jin (SINOPEC, China), Dongya Zhu, Xuefeng Zhang,
Wenxuan Hu and Yucai Song view abstract

• Porosity destruction in carbonate platforms
by S. N. Ehrenberg (Statoil, Norway & UAE University) view abstract

• The Paleocene sandy Siri Fairway: An efficient "pipeline" draining the prolific Central Graben?
by S. E.Ohm (University of Oslo/ConocoPhillips, Norway), D. A. Karlsen, A. Roberts, E. Johannessen and O. Høiland view abstract

• Quantitative assessment of regional siliciclastic top-seal potential:
a new application of proven technology in the Pelotas Basin, Offshore Brazil
by J. A. Deckelman, S. Lou, P. S. D'onfro and R. W. Lahann (ConocoPhillips, USA) view abstract

• International Events

• Cover: Cliff exposures of the deltaic and shallow-marine Atane Formation (Cretaceous) on the coast of Nuussuaq peninsula, ca. 25km north of Qullissat, Western Greenland.
Dark-coloured strata are thin humic coals and coaly mudstones which are the subject of the paper by Pedersen et al. on pp. 3-26 of this issue. The exposed section is around 120m thick.



Search JPG
Sample Issues
The January 2018 issue
(vol. 41, no. 1) is available as a free download from Wiley-Blackwell.
Please click here for more details