Oil Retreats in Face of Renewed Coronavirus Uncertainties - 21 February, 2020 09:21 AM
House Democrats Urge Banks to Not Fund Oil Drilling in Arctic Refuge - 21 February, 2020 09:18 AM
Venezuela’s Maduro Shakes Up PDVSA, Declares Oil ‘Emergency’ - 21 February, 2020 09:16 AM
Guyana Celebrates First Oil Shipment After Major Discovery - 21 February, 2020 09:08 AM
South Sudan Seeks Rise in Oil Exploration and Output After Peace Deal - 21 February, 2020 09:05 AM
Deepwater and LNG GTW - Call for Poster Abstracts
Expires in 34 days
Evaporite Processes and Systems: Integrating Perspectives - Call for Abstracts
Expires in 59 days
As basins such as the Permian have crushed the concept of “peak oil” by doubling past production rates using new ideas and technology, their newly dubbed “super basin” status is inspiring operators on practically every continent to do the same.
Now referred to as a “super basin,” the Gulf of Mexico Basin has joined other top super basins in the world that, despite their maturity, have the potential or have proven to be significant new plays all over again. The driving force behind this renaissance is, for a large part, the evolution of technology over the last two decades that has jumpstarted both offshore and onshore basins.
For the first time in its history, AAPG has hosted a Geosciences Technology Workshop (GTW) in Saudi Arabia. The Integrated Emerging Exploration Concepts workshop took place on 2-4 December 2019 at the Kempinski Al Othman Hotel in Dhahran, Saudi Arabia. For the occasion, we received 47 attendees from 14 different companies and 9 different countries.
AAPG functions because of you, the members, and there are many different ways for you to get involved in your organization. Some choose to start in their local affiliated society, working on committees and holding offices within them. Others get involved through leadership and organizing events within the sections and regions. These are the grassroots of our membership, and AAPG leadership is working to strengthen these roots.
While Blockchain technology is most known for its initial association with the cryptocurrency, Bitcoin, it has since made its way into the fields of banking, technology and healthcare. Now, it is on the verge of being adopted by the oil and gas industry. Although convoluted in concept and often mired in Bitcoin’s tumultuous history, Blockchain technology may be key to tackling the industry’s big data problem, increasing efficiency in operations and transactions, and ultimately lowering costs across the board.
Pity the Permian Basin. Investors complain about disappointing returns from Permian production. Stockholders worry about the financial outlook for operators in the play. Lenders have started to cast a skeptical eye at the basin’s profit potential. So it’s surprising to find that a data-derived solution for addressing the Permian Basin’s current challenges might be readily available. And it’s somewhat startling to hear that, someday, unconventional resource plays in the United States could fly higher than ever.
Producers are feeling the pinch: they’ve got to drill ever more wells to stay ahead of their production declines. Increased production is weighing on crude oil prices – you get the benefit of this supply in resilient markets, but it is shrinking margins and available cashflow to fund this drilling. And at the same time, the financial community is pulling back, restricting access to capital. The industry is reshaping itself yet again in response to new market realities, looking for new ideas and better approaches and operating models.
How can operators increase the stimulated reservoir volume in multi-stage horizontal well completions? That is the key to increasing ultimate recovery and taking an edge off decline curves. Welcome to an interview with Jenna Robertson, ThruTubing. In addition to this interview, she will also be explaining how the technologies work at AAPG's Success with Difficult Unconventionals, Nov 12-13, in Houston.
A seismic acquisition project that would have taken years not too long ago can now be accomplished in months, thanks to “selective hearing” and other recent advances.
A collection of 30 abstracts concerning the mean and methods for a better understanding of fundamental parameters associated with successful hydraulic fracturing. From an AAPG Hedberg convention held in Lakeway, Texas in December, 2014
In 2020, AAPG will launch its first GTW (Geosciences Technology Workshop) in Mozambique, partnering with ENH (Mozambique National Oil and Gas Company) with a focus on deepwater reservoirs and LNG. The goal will be to build scientific knowledge, discover innovations, and network with peers. AAPG has established the GTWs as the primary vehicle for scientific and technological knowledge exchange throughout the world.
Jon Rotzien presents a 1-day course in Singapore on 21st Century Deep-water Clastic Reservoirs: Processes and Products.
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.
Deltas are extremely important depositional systems and often source and contain prolific hydrocarbon accumulations. This workshop includes topical lectures, key cores, and a suite of exercises that integrate core, well logs, experimental flume data, and seismic sections to develop identification and subsurface mapping skills of hydrocarbon accumulations within deltaic settings.
This course has been canceled
Date: Friday 28 – Saturday 29 February 2020 (2 days)
Instructor: John Kaldi, Australian School of Petroleum, University of Adelaide, Australia
This course demonstrates the use of capillary pressure and relative permeability data in conjunction with basic rock properties and wireline logs, to evaluate reservoir rock quality, recovery efficiency and net pay. The course also covers the main aspects of determining seal potential (seal capacity, seal geometry and seal integrity) as well as the main controls on fault seals, and methods used in evaluating these. The course is presented in a workshop format, allowing participants to delve into the details in several practical exercises.
Who should attend:
Geologists, reservoir engineers and managers involved in hydrocarbon exploration and/or development, will benefit from the straightforward and intuitive presentation of principles governing petroleum migration and accumulation, net pay determination, as well as practical applications to determine seal properties for both oil and gas reservoirs.
Introduction to Reservoirs, Seals And Pay
Basic Principles of Capillary Pressure
Caprock And Intraformational Seal Evaluation
Relative Permeability and Recovery Efficiency
Net Pay Determination
John Kaldi is a Professor at the Australian School of Petroleum (ASP) University of Adelaide, Australia and Principle Advisor the Cooperative Centre for Greenhouse Gas Technologies (CO2CRC). He is Adjunct Professor at the Institute of Technology, Bandung (ITB), Indonesia, and Visiting Professor at University of Technology Petronas (UTP), Malaysia. He received his PhD in Geology from Cambridge University, England and then worked for the Saskatchewan Geological Survey, Shell Canada, ARCO (Texas and Indonesia) and VICO. He was Director of the National Centre for Petroleum Geology and Geophysics (NCPGG) at the University of Adelaide, and then served as the Founder and Head of the ASP. Dr. Kaldi served as AAPG President Asia‐Pacific; Vice‐president (International Regions), and was the recipient of AAPG’s Special Commendation Award, Distinguished Service Award and Lifetime Honorary Member Award. He has been an AAPG, PESA and SPE Distinguished Lecturer. He is committed to providing continuing education courses for the oil and gas sector by teaching courses around the world for Professional societies, Universities and energy companies.
This presentation discusses one operator’s approach to fully integrate data captured in the Marcellus Shale in order to optimize horizontal well performance.
Unger Field, discovered in1955, has produced 8.6 million barrels of oil from a thinly (several ft) bedded, locally cherty dolomite containing vuggy and intercrystalline porosity.
Upon successful completion of this course, you will be able to describe geomechanics in shale reservoirs and discuss differences between plays.
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.
This e-symposium covers how to conduct an interdisciplinary evaluation of mature fields to determine the best approach to recover remaining reserves.
Renewable & Non-Renewable Resources is an online course that enables participants to review, analyze, and evaluate opportunities in the rapidly expanding market for renewable energy.
Effective hydraulic fracture stimulation is critical for shale development, and microseismic is the only technology able to map the growth of these hydraulic fracture networks.
Geothermal Energy Basics is an online course that enables participants to review, analyze, and evaluate opportunities in the rapidly expanding market for geothermal energy.
Solar Energy Basics is an online course that enables participants to review, analyze, and evaluate opportunities in the rapidly expanding market for solar energy.
The goal of this e-symposium is to provide an overview of the latest trends and technologies for water management for oil and gas drilling, completions, and production.
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!
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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