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The West Texas (Permian) Basin is a complexly structured intracratonic (IC) basin with prolific oil and natural gas production. It began as a subsidence basin ('Tobosa Basin') from Middle Ordovician to Devonian time, a response to the Cambrian rifting that separated Gondwana and Laurentia. In the Pennsylvanian to early Permian, it formed part of the Ancestral Rocky Mountains (ARM) orogen. The Texas-New Mexico segment of the ARM contains small to medium basement-cored uplifts, folds, thrust faults and two trends of strike-slip faults, with a pattern that is consistent with SW-NE compression. The largest thrust fault known in the basin is SW-vergent, and faces the deepest part of the Delaware Basin. This direction of compression is similar to that observed in the southern Oklahoma part of the ARM, which shows NE-vergent thrusting and left-lateral faulting.

This SW-NE compressive stress is grossly inconsistent with the northwestward convergence of the Ouachita-Marathon thrust belt southeast of the ARM. The ARM-generating stress may have originated either from the Pacific side (by flat subduction) or from strong continental collision in the Appalachian Orogen. Lines of weakness generated during the Proterozoic and/or Cambrian concentrated stress and created the complex structures.

The West Texas branch of the ARM is buried by over 2.5 km of post-deformational Permian strata -- the Permian Basin. Subsidence began during ARM deformation, then increased in rate and continued to the end of the Permian. Permian subsidence resulted in the maintenance of isolated deep-water marine basins until Late Permian time. The Marathon orogen also subsided, and shed little clastic material into the basin. Despite Mesozoic basin-margin modifications, the Permian isopach pattern suggests a bowl-shaped subsidence centered on the Central Basin axis of uplift. The size and shape of the Permian Basin are similar to other IC basins (Illinois, Michigan, Williston). Similar to some IC basins, the central basin area hosts a 1100-Ma mafic complex, which was subjected to compression in Pennsylvanian time. Sinking of a mafic crust or its subjacent lithosphere, begun during compression, may have been a driving force for Permian subsidence.

Over most of the basin, later Permian subsidence was responsible for putting source rocks into the oil window. Further maturation to gas occurred within the deep basins generated by ARM deformation and Marathon thrust loading.

Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/dl-thomas-ewing-tectonics-and-subsidence-in-the-west-texas-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Tectonics and Subsidence in the West Texas (Permian) Basin, A Model for Complex Intracratonic Basin Development
 

Comparison of the hydrocarbon systems and geometries of the complex intracratonic West Texas (Permian) Basin and the complex postrift subsidence basins of the Gulf Coast / Gulf of Mexico yield useful insights for basin evolution and play development. The West Texas basin contains source rocks in the Ordovician and Devonian, but much generation comes from the Late Mississippian, Pennsylvanian and Permian basinal sediments. These were deposited in a poorly ventilated remnant basin during compression and strike-slip of the Ancestral Rocky Mountains orogeny, and subsidence of the intracratonic Permian Basin. Maturation resulted from Permian intracratonic subsidence, with hydrocarbons sealed from later leakage by late Permian salt and a fortunate tectonic setting. By contrast, the major Jurassic source rocks of the Gulf basins are at the base of the postrift subsidence, and are matured by further subsidence. Later Cretaceous source rocks (Eagle Ford) are mature in the main Gulf basin, but again lie near the bottom of the thick sedimentary package in the area. The younger part of the succession yields mostly gas formed during outbuilding of the shelf margin by Cenozoic deltaic progradation. No cap is present on the basin (except for subsalt plays), and seepage is widespread.

Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/dl-thomas-ewing-tale-of-two-basins-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true A Tale of Two Basins: Sources and Timing of Petroleum and Natural Gas Generation in the Mature Gulf Coast/Gulf of Mexico and West Texas (Permian) Basins
 

The Yegua Formation (Late Middle Eocene) is a minor siliciclastic progradation of the Gulf of Mexico shelf margin between the larger Early Eocene and Oligocene shelf-margin progradations. During Yegua time (and unlike the other units of the Middle and Late Eocene), four to eight sea-level fluctuations with a 100-300 ka period alternately pushed marine rocks toward the basin margins and pushed deltaic sedimentation to and past the shelf edge. Because of limited to moderate sand supply and the flat coastal plains, the updip (highstand) depositional complexes are nearly entirely separated from the downdip (lowstand) shelf-edge deltas and slope fans. Maximum flooding surfaces can be mapped over much of the area and correlated along and across the basin. The Yegua is truly a laboratory for sequence stratigraphy. A number of plays in the downdip and 'mid-dip' (incised valley complexes) trends have produced over 4 TCF of gas and condensate, and new discoveries await the return of exploration capital. The Yegua story is significant to all those interested in siliciclastic stratigraphy in passive-margin settings.

Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/dl-thomas-ewing-yegua-formation-late-middle-eocene-in-gulf-coast-basin-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Yegua Formation (Late Middle Eocene) in the Gulf Coast Basin, as a Type Laboratory for Sequence Stratigraphy in Hydrocarbon Exploration
 

Considering a career in industry? The oil and gas industry? In Exploration? Maybe Production? Perhaps Planning? This presentation of the Top Ten Tips for Working in Industry was developed during my 34 year career working for Mobil and ExxonMobil as a technical professional, supervisor, manager, and researcher. I’ll use examples and stories from my career, working with foreign governments in Azerbaijan and Kazakhstan, working in Mobil’s Headquarters in Fairfax, Virginia, being a supervisor and manager in exploration, and working as a senior research associate in ExxonMobil’s Upstream Research Company, recruiting for ExxonMobil at top American Universities interviewing students; and working as the Planning Manager, in Mobil’s Norwegian Affiliate in Stavanger, Norway. All of my experiences over the past 34 years have taught me how to be a successful in these fields, and I enjoy sharing these lessons with others who may be considering careers in the oil and gas industry.

Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/dl-marsha-french-my-top-ten-tips-for-working-in-industry-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true My Top Ten Tips for Working in Industry: Lessons Learned Over My 30-Plus-Year Career Working in Oil and Gas Exploration, Production, Planning and Research
 

Authigenic quartz overgrowths are the most common pore-occluding mineral in deeply buried (>2500 m) quartzose sandstones. But, deeply buried reservoirs of this kind in the North Sea contain more porosity than expected when the influence of authigenic microcrystalline quartz (microquartz, or the good quartz) is ignored. However, we know relatively little about the nature and origin of this porosity-preserving microquartz, which inhibits the bad and ugly quartz overgrowths from growing and occluding pores. Therefore, advanced analytical techniques have been utilized to improve our understanding of the controls on microquartz development in several examples where porosity is preserved in these and similar sandstone reservoirs.

In this study, several advanced analytical techniques were used to evaluate the crystallographic and compositional controls on the formation of microquartz. SEM/Cathodoluminescence (CL) confirms that (bad and ugly) quartz overgrowths have a complex growth history. Electron Backscatter Diffraction (EBSD) combined with Wavelength Dispersive Spectrometry (WDS) confirmed and elaborated on the complex growth history: the complex banding visible in CL is not due to changes in crystallographic orientation but more likely variations in quartz composition associated with changes in pore fluid composition and/or reservoir conditions. Finally, Secondary Ion Mass Spectrometry (SIMS) analysis provides oxygen isotope data providing insight into those initial reservoir conditions and temperature of formation of microcrystalline quartz.

Integrating the results from these advanced analytical techniques has developed an understanding of the processes controlling the formation of porosity-preserving microquartz and improved our ability to reconstruct the reservoir diagenetic history of microquartz growth leading to a proposed model for predicting porosity preservation in deep, hot sandstone reservoirs.

Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/dl-marsha-french-authigenic-quartz-the-good-the-bad-the-ugly-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Authigenic Quartz: The Good, The Bad, and the Ugly: Developing a Model for Preserving Porosity in Deep, Hot Sandstone Reservoirs
 
The Ice Age and the Giant Bakken Oil Accumulation

The USGS estimated (2013) that the Late Devonian to Early Mississippian Bakken Formation holds in excess of 7 billion barrels (~1.1 billion m3) of recoverable oil, making it one of the top 50 largest oilfields in the world. Most of the production comes from shallow-marine sandstones of the Middle Bakken Member that are directly over- and underlain by extremely organic-rich shale source rocks (Upper and Lower Bakken Shale members respectively). Although not oil-productive everywhere, the Middle Bakken forms a relatively sheet-like unit that covers an area of over 200,000 square miles (~520,000 km2) of the intracratonic Williston Basin.

The vertical juxtaposition of shallow-marine reservoir and more distal source rocks over such a large area, without intervening transitional facies, is unusual from a stratigraphic perspective. One possible explanation would require global fluctuations of sea level to drive geologically rapid and extensive shoreline movements in this relatively stable basin. Forced regression associated with falling sea level could explain the lack of transitional facies (e.g., inner shelf) between the distal Lower Bakken Shale and the overlying Middle Bakken (a sharp-based shoreface). Subsequent sea-level rise would have caused rapid and extensive transgression, leading to the observed stratigraphic relationships between the Middle and Upper Bakken members. But what could have caused the changes in sea level?

A considerable body of evidence points to a Late Devonian-Early Mississippian ice age that covered portions of Gondwana (e.g., parts of present-day Brazil) that were situated close to the paleo South Pole. This ice age consisted of more than one glacial/interglacial cycle and was probably triggered by massive removal of CO2 from the atmosphere by land plants and organic-rich shales. Some evidence indicates that at least 100 m of sea-level drop took place during one of the Famennian glaciations, which would have effectively drained the Williston Basin and induced major shoreline progradation. Melting of the ice sheets would have caused transgression and reflooding of the basin and deposition of the Upper Bakken Shale. Other basins around the world record similar evidence for glacioeustacy near the Devonian-Mississippian transition. The glacial/interglacial cycles are expressed differently from basin to basin, reflecting the interplay between fluctuations of global sea level and each basin’s history of subsidence and sediment supply.

Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/dl-bruce-hart-the-ice-age-and-the-giant-bakken-oil-accumulation-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Ice Age and the Giant Bakken Oil Accumulation
 
Five Things Geophysicists Should Know About Shale Plays

The Shale Revolution caught geophysicists off guard. Shales had been studied for a variety of reasons (e.g., relationships between velocity, compaction and pore pressure) but not as low-porosity reservoirs that show vertical heterogeneity at all possible scales. Consequently, many geophysicists have framed shale-play imaging problems using inappropriate tools and paradigms. In this presentation, I present five characteristics of shale plays that should enable improved geophysical analyses.

  1. The term “shale play” has become meaningless. Originally intended to describe gas production from fine-grained source rocks (“source-rock reservoirs”), the term is now applied almost indiscriminately to production from many types of low-permeability rock (e.g., shaly sandstones, carbonates).
  2. Source-rock reservoirs aren’t clay dominated. Hydraulic fracturing is needed to establish commercial production from these rocks. Clays make the rocks ductile and harder to fracture. As such, the clay content of shale plays is generally less than 50%. The remainder of the rock is usually composed of fine-grained calcite and/or quartz, organic matter and other minerals.
  3. Links between VTI anisotropy and clay or organic content are not straightforward in source-rock reservoirs. Scanning electron microscopy often reveals textures that are incompatible with the conceptual models used to develop mathematical models of shales.
  4. HTI anisotropy is complicated by natural fracture geometries. Aligned natural fractures generally combine with bedding to produce systems that are best described as orthorhombic. In some cases, multiple fracture orientations produce systems that are effectively isotropic.
  5. Integration of geophysical and geological data and concepts is needed to significantly advance geophysical research on shale reservoirs. This effort will allow geophysicists to define, for a specific shale, which assumptions are reasonable, which analogs are appropriate, what appropriate ranges of properties are, etc.
Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/dl-bruce-hart-five-things-geologists-should-know-about-shale-plays-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Five Things Geophysicists Should Know About Shale Plays
 

As U.S. production continues to grow, all eyes are focused on OPEC and its recent May 25 meeting to determine whether to keep production cuts in place in an effort to maintain oil prices.

American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/curtiss-david.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true All Eyes Are on Unconventionals
 

Geologists, engineers, geophysicists and entrepreneurs are invited to the Mid-Continent Playmakers Forum on May 11 in Oklahoma City at the headquarters of the Oklahoma Geological Society.

American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/mid-continent-playmakers-forum-in-okc-in-may-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Mid-Continent Playmakers Forum in OKC in May
 

For anyone interested in the methods of observing and quantifying the pore systems that control hydrocarbon and flow in unconventional reservoirs, AAPG’s new volume is what you’ve been waiting for. AAPG recently released Memoir 112: “Imaging Unconventional Reservoir Pore Systems.”

American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/imaging-unconventional-reservoir-pore-systems-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Imaging Unconventional Reservoir Pore Systems
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In-Person Training
Saskatoon Saskatchewan Canada 18 November, 2016 18 November, 2016 34482 Desktop /Portals/0/PackFlashItemImages/WebReady/dl-kitty-milliken-univ-saskatchewan-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Geochemistry and Basin Modeling, Sedimentology and Stratigraphy, Engineering, Source Rock, Reservoir Characterization, Oil Shale, Shale Gas, Student
 
Saskatoon, Saskatchewan, Canada
18 November 2016

Short Course: “Micro to Nano-Scale Features of Mudrocks”
Lecture Title: “Mudrocks (shales, mudstones) at the Scale of Grains and Pores: Current Understanding.”
Venue: University of Saskatchewan, Department of Geological Sciences, 114 Science Place, Saskatoon, SK SK7 3H5
Time: 9:00am

Saskatoon Saskatchewan Canada 18 November, 2016 18 November, 2016 34465 Desktop /Portals/0/PackFlashItemImages/WebReady/dl-kitty-milliken-univ-saskatchewan-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Student, Engineering, Reservoir Characterization, Geochemistry and Basin Modeling, Source Rock, Sedimentology and Stratigraphy, Oil Shale, Shale Gas
 
Saskatoon, Saskatchewan, Canada
18 November 2016

Short Course: “Micro to Nano-Scale Features of Mudrocks”
Lecture Title: “Mudrocks (shales, mudstones) at the Scale of Grains and Pores: Current Understanding.”
Venue: University of Saskatchewan, Department of Geological Sciences, 114 Science Place, Saskatoon, SK SK7 3H5
Time: 3:30pm

Georgetown Barima-Waini Guyana 09 November, 2017 10 November, 2017 38161 Desktop /Portals/0/PackFlashItemImages/WebReady/sc-lacr-reservoir-characterization-of-deep-water-systems-impact-from-exploration-to-production-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Business and Economics, Risk Analysis, Production, Engineering, Primary Recovery, Secondary Recovery, Geochemistry and Basin Modeling, Petroleum Systems, Petrophysics and Well Logs, Clastics, Sedimentology and Stratigraphy, Conventional Sandstones, Deep Sea / Deepwater, Deepwater Turbidites, Low Stand Deposits, Marine, Regressive Deposits, Slope, Structure, Tectonics (General), Deep Basin Gas, Shale Gas, Stratigraphic Traps, Tight Gas Sands
 
Georgetown, Barima-Waini, Guyana
9-10 November 2017

This course emphasizes key changes in reservoir models that have a major impact in exploration and production of these reservoirs. The course will include lectures, exercises, and observations from cores, well logs and seismic profiles. Participants will learn how to interpret and map environments of deposition (EoD’s) in deep water systems and understand how the different EoD’s and sub-EoD’s behave as reservoirs.

Online Training
23 April, 2015 23 April, 2015 16809 Desktop /Portals/0/PackFlashItemImages/WebReady/an-analytical-model-for-shale-gas-permeability-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
23 April 2015
Recent laboratory studies have revealed previously unknown behaviors in shale gas which unlock secrets of permeability and sweet spots in shale gas reservoirs. The presentation presents the findings and also goes into detail about how the new information can be applied in order to potentially improve recovery in reservoirs.
02 December, 2014 02 December, 2014 11967 Desktop /Portals/0/PackFlashItemImages/WebReady/esymp-multiscale-modeling-of-gas-transport-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
2 December 2014

The gas transport in organic-rich shales involves different length-scales, from organic and inorganic pores to macro- and macrofractures. In order to upscale the fluid transport from nanoscale (flow through nanopores) to larger scales (to micro- and macrofractures), multicontinuum methodology is planned to be used.

30 October, 2014 30 October, 2014 11390 Desktop /Portals/0/PackFlashItemImages/WebReady/sc-kerogen-maturity-determinations.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
30 October 2014

Cross disciplinary workflows play an important part of successful characterization of shale reservoirs. This course discusses how the artificial kerogen maturity of organic-rich Green River shale affects the petrophysical, micro-structural, geochemical and elastic properties.

01 January, 2014 01 January, 9999 3160 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-toc-strategic-decision-making.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
1 January 2014 - 1 January 9999

Learn to critically evaluate current issues that can impact growth and sustainability of oil and gas ventures.

09 February, 2012 09 February, 2012 1477 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-seismic-reservoir-characterization-of-us-shales.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
9 February 2012

Projects in several shales will be discussed, including Marcellus, Eagle Ford, Haynesville, Fayetteville, Montney, and Barnett, as will several seismically-detectable drivers for success including lithofacies, stress, pre-existing fractures, and pore pressure.

31 October, 2012 31 October, 2012 1492 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-3-dimensional-approach-t-hydrocarbon-mapping.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
31 October 2012

This e-symposium will focus on how surface geochemical surveys and Downhole Geochemical Imaging technologies can be utilized jointly to directly characterize the composition of hydrocarbons vertically through the prospect section.

29 September, 2011 29 September, 2011 1478 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-application-of-inversion-and-clustering-analysis.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
29 September 2011

This study will focus in the combination of λρ – μρ inversion with clustering analysis techniques in order to discriminate brittle zones in the Barnett Shale.

16 February, 2012 16 February, 2012 1483 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-seismically-driven-characterization-of-unconventional-shale-plays.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
16 February 2012

This presentation describes a proven workflow that uses a standard narrow azimuth 3D seismic, conventional logs, image logs and core data to build five key reservoir properties required for an optimal development of shale plays.

01 January, 2013 01 January, 9999 1459 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-cc-giant-oil-and-gas-fields.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
1 January 2013 - 1 January 9999

There are more approximately 1,000 oil and gas fields in the world that have been classified as "giant," containing more than 500 million barrels of recoverable oil and /or 3 trillion cubic feet of gas.

24 October, 2013 24 October, 2013 1499 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-geomechanical-data-from-petrophysical-logs.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
24 October 2013

This e-symposium will be introducing signal processing techniques as a means to maximize extracting geomechanical data from petrophysical logs.

20 January, 2012 20 January, 2012 1482 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-eagle-ford-shale-prospecting-with-3d-seismic-data.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
20 January 2012

The Eagle Ford Shale in South Texas is one of the more exciting shale plays in the United States at the current time.

26 September, 2013 26 September, 2013 1497 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-overpressure-in-shale-gas.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
26 September 2013

The presentation will discuss key reservoir information and how to develop a predictive pressure model.

10 May, 2012 10 May, 2012 1486 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-genetic-sequences-in-eagle-ford-austin.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
10 May 2012

Recognition and Correlation of the Eagle Ford, Austin Formations in South Texas can be enhanced with High Resolution Biostratigraphy, fossil abundance peaks and Maximum Flooding Surfaces correlated to Upper Cretaceous sequence stratigraphic cycle chart after Gradstein, 2010.

12 July, 2012 12 July, 2012 1490 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-shale-wells-making-the-engineering-fit-what-geology-offers.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
12 July 2012

This presentation will look at well placement vertically in the pay, well azimuth and well trajectory with explanations of how geology and post-depositional effects can make the difference between a successful well and a failure.

19 May, 2011 19 May, 2011 1474 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-shale-gas-prospectivity-case-study.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
19 May 2011

This e-symposium presents and discusses the results of laboratory tests and research relating to determining shale prospectivity in general, and specifically in the Black Warrior Basin, Alabama.

28 April, 2011 28 April, 2011 1471 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-niobrara-petroleum-system-a-major-tight-resource-play.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
28 April 2011

The Niobrara Petroleum System of the U.S. Rocky Mountain Region is a major tight petroleum resource play.

17 March, 2011 17 March, 2011 1470 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-basic-tools-for-shale-exploration.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
17 March 2011

This e-symposium will provide information on which tools, processes, and procedures all geoscientists, engineers, and technical professionals working in shale plays need to understand and implement.

14 December, 2010 14 December, 2010 1467 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-sale-gas-in-quebecs-sedimentary-basins.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
14 December 2010

Recent interest in unconventional gas resources has attracted several oil and gas explorers to sedimentary basins in Southern Quebec.

09 December, 2010 09 December, 2010 1466 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-bakken-petroleum-system-of-the-williston-basin.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
9 December 2010

The Mississippian-Devonian Bakken Petroleum System of the Williston Basin is characterized by low-porosity and permeability reservoirs, organic-rich source rocks, and regional hydrocarbon charge.

09 September, 2010 09 September, 2010 1463 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-hydraulic-fracturing-of-shale-gas.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
9 September 2010

The presentation will focus on hydraulic fracture geometry in shales, the materials used in the fracturing process, and treatment monitoring via microseismic.

22 July, 2010 22 July, 2010 1461 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-all-shale-gas-reservoirs-are-not-the-same.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
22 July 2010

Upon successful completion of this course, you will be able to describe geomechanics in shale reservoirs and discuss differences between plays.

03 June, 2010 03 June, 2010 1460 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-marcellus-utica-in-the-field.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
3 June 2010

Upon successful completion of this course, you will be able to describe faults and fractures in carbonates, black shales, and coarser clastics as they occur in the northern Appalachian Basin.

25 March, 2010 25 March, 2010 1458 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-mapping-natural-fractures-using-3d-seismic-and-well-data.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
25 March 2010

The presentation describes a well established fracture modeling workflow that uses a standard 3D seismic, conventional logs, image logs and data from one core to build predictive 3D fracture models that are validated with blind wells.

29 October, 2009 29 October, 2009 1445 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-application-of-thermal-maturation.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
29 October 2009

Expanded package for CEU credit is $100 for AAPG members, and $145 for non-members. Special Student Pricing: $25 for Webinar only; $35 for Expanded package.

20 August, 2009 20 August, 2009 1444 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-geothermal-energy-in-the-oil-field.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
20 August 2009

This e-symposium covers advances in geothermal energy, integration with petroleum operations, and lessons learned in recent cases.

21 May, 2009 21 May, 2009 1443 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-how-tight-is-your-gas.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
21 May 2009

This e-symposium introduces you to the practical benefits of thermal profiling for a variety of unconventional oil and gas projects, including tight gas sands, oil shale, low-gravity oil.

23 July, 2009 23 July, 2009 1437 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-3d-seismic-profiles-of-us-shale-plays.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
23 July 2009

As commodity prices have dropped, many shale plays have become uneconomical as statistical plays and have increasingly become recognized as geological plays demanding new insights from data.

16 August, 2011 16 August, 2011 1436 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-green-river-shales-geochemical-basin-study.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
16 August 2011

The geochemistry of formation fluids (water and hydrocarbon gases) in the Uinta Basin, Utah, is evaluated at the regional scale based on fluid sampling and compilation of past records.

01 January, 2013 01 January, 9999 1473 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-cc-unconventional-resources.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
1 January 2013 - 1 January 9999

Unconventional Resources is an online course that enables participants to learn about shale gas, shale oil and coalbed methane.

01 January, 2013 01 January, 9999 1472 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-cc-introduction-to-shale-gas.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
1 January 2013 - 1 January 9999

This course introduces the learner to the fundamentals of shale gas, including current theories that explain its origin, and how to determine which reservoirs are commercially viable.

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Over the past ten years, oil and natural gas production has boomed. At the same time, the public has grown more concerned about the impact of energy production on health, safety and the environment. This presents an especially interesting science policy problem because of the paucity of scientific data regarding the sources, composition and volumes of air and water emissions from oil and gas operations. These data are necessary to guide emission-mitigation technology and regulation.

This presentation will examine two examples of data limitations that affect energy policy.

  • Several years ago, hydraulic fracturing was indicted for causing methane in Appalachian aquifers. However, a careful look at historic data and new geochemical studies show that most of the methane is naturally occurring, and from formations other than the Marcellus. Thus, policies simply banning hydraulic fracturing may do little to solve this problem.
  • Scientists have long known that energy production may be associated with increased seismicity and recently hydraulic fracturing and wastewater disposal wells have been implicated in the increasing numbers of small, felt earthquakes in the mid-continent. Recent research shows that a small percentage of wastewater injection wells and an even smaller percentage of hydraulic fracturing treatments are inducing earthquakes. In addition, the results of mitigation procedures implemented in Oklahoma will soon be available.
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Request a visit from Edith Allison!

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