Colorado Pauses Process to Set Rules for Reducing 'Cumulative Impacts' from Oil, Gas Operations - 25 April, 2024 07:30 AM
French Grid Issues Are Causing Power Prices to Soar in Europe - 25 April, 2024 07:30 AM
Equinor: A Case Study on the Trouble with Greening Oil and Gas Companies - 25 April, 2024 07:30 AM
Galp Announces 10B Barrel Hydrocarbon in Place Estimate at Namibia Prospect - 25 April, 2024 07:30 AM
U.S. Oil Rises Nearly 2 Percent to Top $83 a Barrel as Slowing Manufacturing Raises Interest Rate Cut Hopes - 24 April, 2024 07:30 AM
2nd Edition: Geological Process-Based Forward Modeling AAPG Call For Abstracts Expires in 4 days
litutmMedium
litutmCampaign
Bottoms up! The successful Barnett play is getting a second look, thanks to a new study that took a bottomsup approach to determines areas with the best potential.
Gas generation is a commonly hypothesized mechanism for the development of high-magnitude overpressure. However, overpressures developed by gas generation have been rarely measured in situ, with the main evidence for such overpressures coming from source rock microfractures, the physical necessity of overpressures for primary migration, laboratory experiments, and numerical modeling. Indeed, previous in-situ observations suggest that gas generation only creates highly localized overpressures within rich source rocks. Pore-fluid pressure data and sonic velocity–vertical effective stress plots from 30 wells reveal that overpressures in the northern Malay Basin are primarily generated by fluid expansion and are located basinwide within the Miocene 2A, 2B, and 2C source rock formations. The overpressures are predominantly associated with gas sampled in more than 83% of overpressure measurements and have a sonic-density response consistent with gas generation. The association of fluid expansion overpressures with gas, combined with the sonic-density response to overpressure and a regional geology that precludes other overpressuring mechanisms, provides convincing in-situ evidence for basinwide gas generation overpressuring. Overpressure magnitude analysis suggests that gas generation accounts for approximately one-half to two-thirds of the measured excess pore pressure in the region, with the remainder being generated by coincident disequilibrium compaction. Thus, the data herein suggest that gas generation, if acting in isolation, is producing a maximum pressure gradient of 15.3 MPa/km (0.676 psi/ft) and not lithostatic magnitudes as commonly hypothesized. The gas generation overpressures in this article are not associated with a significant porosity anomaly and represent a major drilling hazard, with traditional pore-pressure prediction techniques underestimating pressure gradients by 2.3 1.5 MPa/km (0.1 0.07 psi/ft).
A joint AAPG–Society of Petroleum Engineers–Society of Exploration Geophysicists Hedberg Research Conference was held in Saint-Cyr sur Mer, France, on July 8 to 13, 2012, to review current research and explore future research directions related to improved production from carbonate reservoirs. Eighty-seven scientists from academia and industry (split roughly equally) attended for five days. A primary objective for the conference was to explore novel connections among different disciplines (primarily within geoscience and reservoir engineering) as a way to define new research opportunities. Research areas represented included carbonate sedimentology and stratigraphy, structural geology, geomechanics, hydrology, reactive transport modeling, seismic imaging (including four-dimensional seismic, tomography, and seismic forward modeling), geologic modeling and forward modeling of geologic processes, petrophysics, statistical methods, numerical methods for simulation, reservoir engineering, pore-scale processes, in-situ flow experiments (e.g., x-ray computed tomography), visualization, and methods for data interaction.
This seems like the perfect time to summarize Canadian oil and gas activity in 2012.
After World War II, the United States suddenly found itself with nuclear explosives, a tool for which there were few obvious uses other than spectacular and indiscriminate destruction.
3-D seismic data are being viewed as the way to reduce drilling cost overruns and maximize ultimate recovery from a shale-producing field – and for relatively minimal additional cost.
A regional database of more than 3,500 producing Eagle Ford wells is helping to highlight production trends and optimal engineering parameters.
What happens in the reservoir following hydrofracturing? Microseismic monitoring is providing some important answers.
Industry and academia are teaming up to pump up activity in the Mississippian of the Midcontinent United States.
An AAPG member is asked to provide a study on fractures and seismicity in New York, putting him at the epicenter of the state's debate over the use of hydraulic fracturing.