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Super basin applications and analogs continue to drive the future. As we learn more about them, we discover how valuable super basins are to exploration and development. As a result, AAPG continues its initiative to showcase some of the world’s greatest petroleum basins with the fourth Global Super Basins Leadership Conference.
As companies work toward developing alternative sources for a world with ever-increasing energy demands, energy minerals are moving to the forefront of the conversation. AAPG’s Energy Minerals Division finds itself in the spotlight these days for its work in prospecting alternative energy sources, such as geothermal and hydrates, for commercial use. “We’ve got good momentum right now with interest in alternative energy,” said Ursula Hammes, AAPG Member, EMD president and president at Hammes Energy and Consultants.
The AAPG Global Super Basins Leadership Conference 2021 will be a fully online experience taking place 25–26 January 2021. The event will focus on North America’s most productive energy basins. Decision makers and global experts will study geoscience architecture, explore the technology, and anticipate future opportunities.
The North Sea Rift Basin ranks as one of the world’s most famous and indefatigable super basin areas. Like a pugnacious prize fighter, it’s been counted out again and again, only to rebound and punch back into contention. While some explorers consider the North Sea province highly mature, and even late life, it continues to produce plenty of oil and gas. And discoveries.
If you remember from my last column, this is a three-part series on my thoughts on science, membership and budget. I talked about budget last time … we are still working on it, so let’s talk science. The reason most professionals join AAPG is for access to science. That’s not just my opinion – it’s what members tell us. AAPG is very good about disseminating the work of our members and other professionals around the world. That’s our mission.
As discussed in part 1 of this article, when it comes to the attributes used in equation 1 for seismically determining shale capacity, it is difficult to make a manual choice for the cut off values. To alleviate such a problem, application of machine learning techniques could be useful and thus worth exploring.
The goal of reservoir characterization work carried out for a shale play is to enhance hydrocarbon production by identifying the favorable drilling targets. The drilling operators have the perception that in organic-rich shale formations, horizontal wells can be drilled anywhere, in any direction, and hydraulic fracturing at regular intervals along the length of the laterals can then lead to better production. Given that this understanding holds true, all fracturing stages are expected to contribute impartially to the production. However, studies have shown that only 50 percent of the fracturing stages contribute to overall production. This suggests that repetitive drilling of wells and their completions without attention to their placement must be avoided, and smart drilling needs to be followed by operators.
Challenges related to the energy transition have led scientists to seek the ways and means to sequester carbon dioxide. Use of CO2 injection to enhance oil recovery from existing fields and CO2 storage in depleted oil and gas fields provide obvious opportunities for CO2 sequestration. As well as the interest in existing fields, there has been a significant drive to identify potential storage sites in recent years, as well as in the larger saline aquifers in which they are situated.
Using the most advanced technologies combined with a passion for geology leads to an ever-increasing level of understanding of rock properties and reservoirs. Welcome to an interview with Kitty Milliken, who shares her experiences and insights.
Considering that success or failure of unconventional exploration is largely dependent on drilling horizontal wells in the right area and fracturing efficiently, and considering also that geomechanical modeling facilitates these processes, it is easy to see that when industry professionals have a better perspective of the subsurface mechanics, the better chance they have for increased production. That is the point of geomechanical modeling: safer drilling and increased production.
Date: 3rd February 2021
Time: 7am – 4pm
Field Trip Leaders: Mohammed Masrahy and Fawaz Al Khaldi, Saudi Aramco
Registration Fee: $95
Registration Deadline: 16th December 2020
Field Trip Description
Analogues, especially ancient outcrop and modern analogues, have played a crucial role in improving the understanding of subsurface reservoir architectural elements. They provide important information on subsurface reservoir geobody size, geometry, and potential connectivity, which all contribute to better reservoir characterization, mainly in highly heterogeneous siliciclastic or carbonate reservoirs that require the integration and detailed analysis of petrophysics, facies, diagenesis, geometry, depositional environments and lateral and vertical variability.
Subsurface reservoir models are limited by available geological data. Outcrop and modern analogs from comparable systems provide additional input to geological models of the subsurface. This field trip will provide valuable insights into the nature of this complexity.
Aims and Objectives
The field trip will comprise a field study of a range of continental clastic modern systems and marine carbonate ancient systems, and related sedimentary facies, each of which possesses attributes that are comparable in part to the subsurface deposits.
Field trip attendees will gain knowledge about key competencies related to field geology such as measuring vertical sections, describing sedimentary structures and textures, describing sedimentary facies, identifying depositional environments, and linking sedimentological observations to subsurface reservoir modeling.
One specific aim of this field trip is to emphasize that integrated reservoir characterization and modeling processes take into account actual depositional trends and the distribution of the sedimentary bodies.
Intended Learning Outcomes
This field trip will provide explanations and discussions of the following aspects:
Basin age, mechanisms of tectonic development, and regional palaeogeographic setting.
An introduction to techniques and criteria for the recognition of continental (fluvial and aeolian systems), shallow marine and carbonate related sedimentary facies in outcrop and modern system and discussions of the application of these techniques to the study of subsurface sedimentology and geological modeling.
Discussions of the 1D, 2D and 3D facies architecture with particular consideration of the geometry and scale of key stratal bodies that have relevance for understanding subsurface hydrocarbon reservoirs.
Discussion of the nature of autocyclic (intrinsic) interactions between competing sedimentary processes and consideration of the implications of these in terms of reservoir quality.
Discussion of the nature of allocyclic (external) controls on sedimentary processes and consideration of the effects of temporal and spatial changes in these controls on the preserved succession (through introduction of sequence stratigraphic concepts).
The significance of accurately determining the preserved geometry of reservoir successions and how to undertake correlations at the interwell scale.
How to predict the 3D distribution of net versus non-net reservoir.
How best to make region-wide predictions in areas for which palaeogeography is poorly constrained.
Join us in Salzburg, the “castle of salt” and cradle of Mozart and Doppler, for a meeting aimed at bringing together different perspectives in the science of evaporite basins: from their formation to their deformation, from description and characterization to modelling. Exploratory success in evaporite-rich basins worldwide has depended on the role of evaporites as a deformable substrate, as a seal, or even as a good thermal conductor. The aim of this workshop is to improve our understanding and predictive ability by addressing evaporite systems in an integrated manner, all the way from precipitation to structuration, and exploring the multiple properties of evaporite sequences. The pre- and post-meeting field trips will also explore the salt mining heritage of the region, first exploited by the Celts 3500 years ago, and the salt-related structures of the Northern Calcareous Alps.
Upon successful completion of this course, you will be able to describe geomechanics in shale reservoirs and discuss differences between plays.
This work investigates how heterogeneity can be defined and how we can quantify this term by describing a range of statistical heterogeneity (e.g. coefficient of variation and the Lorenz coefficient).
The goal of this e-symposium is to review an important dimension in the ways geologist can build and update geological models using information from performance data.
There are 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.
The presentation will focus on hydraulic fracture geometry in shales, the materials used in the fracturing process, and treatment monitoring via microseismic.
Join two GIS/geoscience experts Scott Sires and Gerry Bartz as they use information from the Teapot Dome Field in Wyoming (DOE/RMOTC program).
This e-symposium focuses on methods for predicting connectivity within clastic fluvial systems.
The Eagle Ford Shale in South Texas is one of the more exciting shale plays in the United States at the current time.
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.
An overview of a new ambient seismic imaging method and applications of the method throughout the lifecycles (exploration through refracing) of unconventional oil and/or gas fields.
This is a less-technical education topic. It can be condensed to an hour or given as 2 two-hour sessions. It stresses selected controversial aspects of fracking that touch some combination of environment and economics and includes a short video of how fracking is done.
Request a visit from David Weinberg!
Hydraulic fracturing has been around for decades. This talk describes some of the first applications of the technology, how it developed over time, and our current understanding of its impacts with some discussion of both water and earthquake hazards.
Request a visit from Sherilyn Williams-Stroud!
This lecture will discuss the differences between carbonates and siliciclastics from their chemical composition through their distributions in time and space. Building on these fundamental differences, we will explore the challenges carbonates pose to petroleum geologists in terms of seismic interpretation, reservoir quality prediction, field development, etc. Peppered with humorous personal stories, still raging academic debates, and the heartfelt frustrations of real industry professionals, the aim is to inspire students and young professionals to rise to the occasion and embrace the reservoir rocks that petroleum geologists love to hate.
Request a visit from Noelle Joy Purcell!
Analysis of microseismicity induced by hydraulic fracture stimulation in the Marcellus Shale shows changes in stress state for different zones of failure. During the treatment, shear failure occurs on both the J1 and J2 fracture orientations in response to different maximum stress orientations, indicating localized changes in the orientation during the treatment. Reactivation of a fault near the wellbore is associated with failure mechanisms with a higher volumetric component, indicating possible inflation of faults and fractures by the introduction of the slurry. Quantification of the stress conditions that are associated with inflation could potentially be used to optimize the stimulation by identifying which fractures will preferentially take on slurry volume.
Microseismicity induced by hydraulic fracture stimulation of a horizontal well was mapped with a near-surface buried array. Distinct linear trends of events were not parallel to the direction of fast shear wave polarization measured in the reservoir with a crossed-dipole anisotropy tool. Analysis of core from a nearby well revealed numerous calcite-filled fractures that did not induce shear wave polarization, but did significantly impact the failure behavior of the reservoir rock during the stimulation treatment. Hydraulic fracture simulation with DFN modeling and source mechanism analysis supports the interpretation of reactivated existing fractures rather than the formation of hydraulically-induced tensile fractures.
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