Wanted: Data Sets For Barrel Award

The AAPG Imperial Barrel Award has had two years now of dramatic growth and enthusiasm. Teams for universities all around the world are looking forward to competing each year in their sectional and regional programs, all hoping to make the final at the AAPG Annual Convention and Exhibition.

With more schools participating, the need for more datasets to be used in the program continues to increase.

An IBA dataset comprises a 3-D survey (of 400 to 1,000 square kilometers), 2-D data (1,000 to 5,000 kilometers) and a minimum of four to six wells with full suites of wireline logs.

The dataset can be anywhere and does not have to be located over existing production.

The IBA Technical Subcommittee gratefully accepts any donation of a dataset – and works to ensures that all datasets are fairly matched for universities to use for the IBA program.

If you have a dataset and can make a donation, or have any questions related to the datasets for the IBA program, contact Steven Veal at the AAPG European Office in London at +44 (0)207-434-1399.

We need your help to continue to present a quality IBA program.


Three AAPG Sections and one Region are making final preparations for their annual meetings as the fall meeting schedule nears.

Upcoming Region and Section meetings are:

  • Eastern Section – Sept. 20-22, Evansville, Ind.
  • GCAGS – Sept. 27-29, Shreveport, La.
  • Mid-Continent Section – Oct. 10-14, Tulsa.
  • Europe Region – Nov. 23-24, Paris-Malmaison, France.

Check out the details on all meetings.


The theme of this year’s Eastern Section meeting is “Forging the Future from the Past,” reflecting the challenges in exploring, developing and responsibly utilizing energy resources in the Section’s mature basins.

The technical program – 76 oral and poster presentations are scheduled – emphasizes unconventional natural gas resources, with technical sessions on Devonian black shale’s, coalbed methane, reservoir geology and new carbon sequestration research.

Also offered are:

  • Three workshops – Geophysics and Geology Applied in Industry, a student workshop presented by Fred Schroeder of ExxonMobil; and Appraising Shale Gas Reservoirs and Appraising Coalbed Methane Reservoirs, both led by Creties Jenkins, past president of AAPG’s Energy Minerals Division.
  • Three PTTC-sponsored field trips –a pre-meeting trip on the New Albany Shale; a trip to Pennsylvanian-age coal deposits in Indiana and eastern Illinois to examine the paleoclimate and depositional features that created mineable coal deposits; and a post-meeting field trip to Middle Devonian carbonate reservoir strata exposed in east central Indiana.

The Geneva Dolomite is host to prolific fields in Illinois and Indiana. Spectacular corals, other fossils, and dissolution features that provide reservoir analogues will be seen.

Space is limited for field trips and workshops, so early registration is encouraged. Visit the Eastern Section meeting Web site for details.


A full-day symposium on the Haynesville and other shale plays will kick-off the GCAGS annual meeting, built on the theme “A Fusion of Geology and Technology.”

The symposium will feature 17 talks that assess in detail the Haynesville, Marcellus, Woodford and other shale plays.

Field trips are:

  • Midway Formation and Wilcox Group (Paleocene) Contact.
  • Chemard Lake Lignite Lentil – A Paleocene Upper Deltaic Interdistributary Swamp Environment.
  • Haynesville Shale – Natural Gas Producton from an Unconventional Resource.

For details see the GCAGS meeting site.

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Regions and Sections

Regions and Sections Column - Carol McGowen
Carol Cain McGowen is the development manager for AAPG's Regions and Sections. She may be contacted via email , or telephone at 1-918-560-9403.

Regions and Sections Column

Regions and Sections is a regular column in the EXPLORER offering news for and about AAPG's six international Regions and six U.S. Sections. News items, press releases and other information should be submitted via email or to: EXPLORER - Regions and Sections, P.O. Box 979, Tulsa, OK 74101. 

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See Also: Book

This special issue honors the legacy of J. Fred Read, a pioneer in carbonate sedimentology and stratigraphy. He taught at Virginia Tech for 38 years and, along with his students, published more than 120 papers. Many of these students have become leaders in carbonate research.

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See Also: Bulletin Article

Jurassic deposition in the Maghrebian tethys was governed by eustasy and rifting. Two periods were delineated: (1) a carbonate shelf (Rhaetian–early Pliensbachian) and (2) a platform-basin complex (early Pliensbachian–Callovian). The carbonate shelf evolved in four stages, generating three sedimentary sequences, J1 to J3, separated by boundary sea level falls, drawdown, exposure, and local erosion. Sediment facies bear evidence of sea level rises and falls. Lateral changes in lithofacies indicate shoaling and deepening upward during the Sinemurian. A major pulse of rifting with an abrupt transition from carbonate shelf to pelagic basin environments of deposition marks the upper boundary of the lower Pliensbachian carbonate shelf deposits. This rifting episode with brittle fractures broke up the Rhaetian–early Pliensbachian carbonate shelf and has created a network of grabens, half grabens, horsts, and stacked ramps. Following this episode, a relative sea level rise led to pelagic sedimentation in the rift basins with local anoxic environments that also received debris shed from uplifted ramp crests. Another major episode spanning the whole early Pliensbachian–Bajocian is suggested by early brecciation, mass flows, slumps, olistolites, erosion, pinch-outs, and sedimentary prisms. A later increase in the rates of drifting marked a progress toward rift cessation during the Late Jurassic. These Jurassic carbonates with detrital deposits and black shales as the source rocks in northeastern Tunisia may define interesting petroleum plays (pinch-out flanking ramps, onlaps, and structurally upraised blocks sealed inside grabens). Source rock maturation and hydrocarbon migration began early in the Cretaceous and reached a maximum during the late Tortonian–Pliocene Atlassic orogeny.
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This article reviews the mechanisms of shale gas storage and discusses the major risks or uncertainties for shale gas exploration in China. At a given temperature and pressure, the gas sorption capacities of organic-rich shales are primarily controlled by the organic matter richness but may be significantly influenced by the type and maturity of the organic matter, mineral composition (especially clay content), moisture content, pore volume and structure, resulting in different ratios of gas sorption capacity (GSC) to total organic carbon content for different shales. In laboratory experiments, the GSC of organic-rich shales increases with increasing pressure and decreases with increasing temperature. Under geologic conditions (assuming hydrostatic pressure gradient and constant thermal gradient), the GSC increases initially with depth due to the predominating effect of pressure, passes through a maximum, and then decreases because of the influence of increasing temperature at greater depth. This pattern of variation is quite similar to that observed for coals and is of great significance for understanding the changes in GSC of organic-rich shales over geologic time as a function of burial history. At an elevated temperature and pressure and with the presence of moisture, the gas sorption capacities of organic-rich shales are quite low. As a result, adsorption alone cannot protect sufficient gas for high-maturity organic-rich shales to be commercial gas reservoirs. Two models are proposed to predict the variation of GSC and total gas content over geologic time as a function of burial history. High contents of free gas in organic-rich shales can be preserved in relatively closed systems. Loss of free gas during postgeneration uplift and erosion may result in undersaturation (the total gas contents lower than the sorption capacity) and is the major risk for gas exploration in marine organic-rich shales in China.
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