<!-- AAPGprofilelink = /profile/userid/54403--><!-- AAPGprofilelink = /profile/userid/212--><!--ASDFUnderstanding Expulsion Capacity and Organic Porosity in Unconventional Petroleum Systems -->
<!--ASDFASDF&lt;p&gt;With the increasing importance of unconventional resource plays, efforts have been made to better estimate the storage capacity of unconventional reservoirs. Proper estimation of oil/gas in-place requires, among other considerations, improved determination of the expulsion capacity and porosity of tight reservoirs. In organic-rich rocks, permeability of the hydrocarbon-wet pore network (i.e., organic pores) can be significantly higher than that of the inorganic matrix and fracture pore network. Therefore, organic porosity can be an important factor on the economic viability of unconventional plays.&lt;/p&gt;
&lt;p&gt;Unlike conventional systems, where a substantial portion of the generated hydrocarbons are presumed to be expelled from the source rock into the carrier system, economically successful unconventional plays require a significant percentage of the generated hydrocarbons be retained within the source interval. Many unconventional plays consist of a self-sourced petroleum system, where source and reservoir are contained within the same geologic unit. In this type of “massive source-reservoir” system (e.g., Marcellus Fm.), generated hydrocarbons are largely retained within the source rock, limited amounts of resource “bleed” from the source rock’s edge, and the overall expulsion efficiency is limited. Limited primary migration or expulsion leads to the development of excellent shale plays and somewhat reduced conventional resources. Thickness of the source interval is a major control on the effectiveness of these systems. Further examination of unconventional plays reveals two additional plausible expulsion models. In “sandwiched reservoirs,” a reservoir (conventional or unconventional) lays between organic-rich source intervals, with the upper and lower source intervals feeding into a common reservoir (e.g., Bakken Fm.) Expulsion efficiency in this type of system is greater than in “massive source-reservoirs.” Depending on the nature of the reservoir/carrier, secondary migration may occur, and the thermal maturity of the reservoir may be less than that of the produced hydrocarbon. The third expulsion model is defined by “interbedded source-reservoir couplets” such as those characteristic of the Wolfcamp Fm. (Permian Basin). This model is characterized by the highest expulsion efficiency. Secondary migration is likely, and the net reservoir interval is not easily defined. &lt;/p&gt;
&lt;p&gt;Porosity is another parameter critical to hydrocarbon in-place estimates, with organic porosity potentially playing a key role on hydrocarbon storage, migration, and production, particularly in massive source-reservoirs. Organic pores, if present in situ, provide space for hydrocarbon storage and increase surface area resulting in higher absorption capacity. However, organic pore size can restrict the influence of organic porosity in liquid-rich plays. Additionally, the connectivity of these pores may be somewhat limited and dependent on the nature of the organic network, thus limiting their impact on permeability. Detailed review of the available literature on organic porosity reveals contradictory information regarding where (e.g., in kerogen macerals, bitumen, and/or pyrobitumen), when (prior to diagenesis, within the oil window, or beyond), and how (e.g., inherited or authigenic) organic pores form. The influence of organic richness on organic porosity development is also up for debate. Many of these apparent contradictions are a function of the nature of the data sets upon which the studies are based. Some of the key issues that need to be clarified when addressing organic porosity are terminology (i.e., terms vary depending on authors’ expertise) and differences in pore morphology (e.g., spongy, isolated bubbles, or fractures). Diverse pore morphologies indicate multiple mechanisms for formation and/or growth of organic pores, suggesting more complexity to organic porosity development than often implied. Finally, it is important to evaluate the extent by which the acts of obtaining and observing the samples containing these pores may result in alteration of the rocks and the pores themselves, potentially producing “organic pores” not reflective of native conditions.&lt;/p&gt;-->
<!--ASDFASDFASDFWith the increasing importance of unconventional resource plays, efforts have been made to better estimate the storage capacity of unconventional reservoirs. Proper estimation of oil/gas in-place requires, among other considerations, improved determination of the expulsion capacity and porosity of tight reservoirs. In organic-rich rocks, permeability of the hydrocarbon-wet pore network (i.e., organic pores) can be significantly higher than that of the inorganic matrix and fracture pore network. Therefore, organic porosity can be an important factor on the economic viability of unconventional plays.-->

<!--ASDFReconstructing Earth's Climate Dynamics at the Dawn of Animals-->
<!--ASDFASDF&lt;p&gt;In the Bergmann Lab at MIT, we use a combination of approaches to reconstruct ancient climate conditions. Carbonate, phosphatic and siliciclastic rocks retain significant information about climatic conditions in Earth’s deep history in their sedimentological, petrographic and geochemical character. Determining absolute temperature ranges and seawater oxygen isotope (δ18O) fluctuations over geologic time is one crucial component of understanding Earth&#39;s long term climate history and the co-evolution of Earth and life.  Carbonate clumped isotope thermometry (D47) of ancient carbonates and fossils has the potential to unravel competing effects on δ18O records.  However, diagenetic effects must be considered using strategies of analysis of two or more co-existing minerals (i.e. calcite, dolomite and apatite), comparisons between co-existing fabrics (i.e. late-stage cements vs. primary shells), and micro-analytical screening techniques based on petrographic and chemical indicators of alteration. I will present results that utilize all of these strategies to assess the climate variability in the latest Precambrian and earliest Phanerozoic. Our results suggest critical differences between recent paleoclimate conditions and those of the deep past both in terms of the response of the climate system to external perturbations as well as the controls that govern the climate system&#39;s recovery to perturbations.&lt;/p&gt;-->
<!--ASDFASDFASDF<p>In the Bergmann Lab at MIT, we use a combination of approaches to reconstruct ancient climate conditions. Carbonate, phosphatic and siliciclastic rocks retain significant information about climatic conditions in Earth’s deep history in their sedimentological, petrographic and geochemical character. Determining absolute temperature ranges and seawater oxygen isotope (δ18O) fluctuations over geologic time is one crucial component of understanding Earth's long term climate history and the co-evolution of Earth and life.  Carbonate clumped isotope thermometry (D47) of ancient carbonates and fossils has the potential to unravel competing effects on δ18O records.  However, diagenetic effects must be considered using strategies of analysis of two or more co-existing minerals (i.e. calcite, dolomite and apatite), comparisons between co-existing fabrics (i.e. late-stage cements vs. primary shells), and micro-analytical screening techniques based on petrographic and chemical indicators of alteration. I will present results that utilize all of these strategies to assess the climate variability in the latest Precambrian and earliest Phanerozoic. Our results suggest critical differences between recent paleoclimate conditions and those of the deep past both in terms of the response of the climate system to external perturbations as well as the controls that govern the climate system's recovery to perturbations.</p>-->

<!--ASDFCoupling Geoethics to Sustainability-->
<!--ASDFASDF&lt;p&gt;This lecture will provide insights on why and how geoscientists can build a solid ethical foundation for sustainability purposes. Incrementally, professionals of all specializations of geosciences are called to assess local, regional, and global risks and vulnerabilities related to main issues of our planet, people and prosperity. Upholding geoethics can be challenging in all stages of our career paths and is now more relevant than ever. Our individual or corporate standings and decisions have potentially great impacts on issues like climate change, environmental health, geologic hazards, energy transition, food safety, energy poverty, and the management of air, water, resources and land. AAPG’s Code of Conduct will be described as a relevant component of ethical approaches to advance the science of geology, promote technology and facilitate networking and collaboration between professionals within the world’s geosciences community.&lt;/p&gt;
A special emphasis will be placed on explaining how the concepts of equity, fairness, professionalism and harassment have taken a new angle and relevance in geosciences, and attendees will take away from this lecture an understanding on how our personal choices are key to advance best practices for a sustainable future.-->
<!--ASDFASDFASDF<p>This lecture will provide insights on why and how geoscientists can build a solid ethical foundation for sustainability purposes. Incrementally, professionals of all specializations of geosciences are called to assess local, regional, and global risks and vulnerabilities related to main issues of our planet, people and prosperity. </p>-->

<!--ASDFSustainable Development and the Energy Transition-->
<!--ASDFASDF&lt;p&gt;Sustainable development is defined by the United Nations as “meeting the needs of the present without comprising the ability of future generations to meet their own needs.” Sustainability defines a framework of the economic, environmental and social factors that need to be balanced with energy development. It is a system or lifecycle concept and not a stand-alone property.&amp;nbsp; When we speak of the “energy transition” and broadly defined terms such as “carbon intensity,” “decarbonization” and “net-zero emissions,” we need to account for present-day energy realities, as well as the consequences of energy choices on the future.&lt;/p&gt;
&lt;p&gt;Pressure to make energy more sustainable is driving financial investments, business models and technology. Investment companies have established criteria for sustainability or ESG ratings that highlight the value of sustainable investing. Petroleum companies are addressing sustainable development with exploration and development projects and broadening into energy companies with investments in carbon capture, geothermal and low carbon fuels. Technology and innovation are essential to sustainable energy development and are improving extractive industry practices and alternative energy efficiencies. &lt;/p&gt;
All energy projects are dependent on access to resources, be they fossil fuels, critical minerals for energy storage or land use for biomass. Geoscientists play a pivotal role in understanding the resources, risks, and rewards of each. Sustainable development is more than a framework to provide energy. On a personal level it reflects our values. On a community level it affects deep-rooted energy cultures. And on a global level it affirms our commitment to both people and the planet.-->
<!--ASDFASDFASDF<p>Sustainable development is defined by the United Nations as “meeting the needs of the present without comprising the ability of future generations to meet their own needs.” Sustainability defines a framework of the economic, environmental and social factors that need to be balanced with energy development. It is a system or lifecycle concept and not a stand-alone property. </p>-->

<!--ASDFWhat it Takes to be Successful in Exploration-->
<!--ASDFASDF&lt;p&gt;Despite the rapid growth in unconventional resource identification and extraction, exploration continues to be crucial for discovering the economic resources needed to meet the global demand for energy. This talk will describe what I have learned are important attributes of an economically successful exploration program. Many of these learnings are applicable for ensuring success in innovation as well.&lt;/p&gt;
&lt;p&gt;Historically, more companies have failed than have made a profit through exploration. Critical criteria for success include:&lt;/p&gt;
&lt;ol&gt;
    &lt;li&gt;Excellent technical work that results in multiple interpretations consistent with all available data.&lt;/li&gt;
    &lt;li&gt;Processes and tools that lead to the objective quantification and understanding of the probability of success (and failure) for each exploration opportunity.&lt;/li&gt;
    &lt;li&gt;A relentless focus on learning from every success and failure. When applied to the individual geoscientist, it builds intuition over time that adds real value and should be listened to. It also builds corporate institutional memory and learning leading to better decision making.&lt;/li&gt;
    &lt;li&gt;Building a team(s) of geoscientists, engineers and negotiators that are passionate about seeking out and incorporating new ideas. A high performing team of people who are curious, open minded critical thinkers who love solving mysteries and creating value. &lt;/li&gt;
    &lt;li&gt;A deep understanding of country oil and gas financial regulations and models. Understanding country culture can be differentiating for ultimate financial success for company and country.&lt;/li&gt;
    &lt;li&gt;Strategic alignment and commitment to exploration by the CEO and Board of Directors with an understanding of risk, reward, and what it takes to be successful in exploration.&lt;/li&gt;
    &lt;li&gt;Leadership. Passion, vision, processes and decisions that are made knowing that we really don’t know.&lt;/li&gt;
&lt;/ol&gt;
&lt;p&gt;My talk will emphasize these points and more by reference to studies, experiences and observations made throughout my career, both within and leading exploration and innovation. I will share examples and stories of successes (such as the Tamar and Leviathan discoveries offshore Israel) and failures which can be applied to any industry where a deep understanding of risk and reward is important for personal and financial success.&lt;/p&gt;-->
<!--ASDFASDFASDFDespite the rapid growth in unconventional resource identification and extraction, exploration continues to be crucial for discovering the economic resources needed to meet the global demand for energy. This talk will describe what I have learned are important attributes of an economically successful exploration program. Many of these learnings are applicable for ensuring success in innovation as well.-->

<!--ASDFImpact of Diagenesis on Rock Properties in Shales-->
<!--ASDFASDF&lt;p&gt;Marcellus Shale and Canning Basin shale samples were used to study diagenetic effects on the mineral and organic matter and their impact on petrophysical and geomechanical response.&lt;/p&gt;
&lt;p&gt;
The Marcellus Shale contained an anomalously low electrical resistivity interval within high thermal maturity organic matter. Multiple techniques were used to elucidate the micro- and nano-scale structure of the Marcellus Shale which showed highly porous bitumen residing in the original pore network of the rock. This organic matter had been transformed to a partially ordered proto-graphite structure under temperatures in excess of 250&#176;C, determined by multiple geothermometric lines of evidence, causing the low resistivity observed.&lt;/p&gt;
&lt;p&gt;
For the Canning Basin Ordovician shales, here we have two shales, the Goldwyer and Bongabinni Formations, which have similar burial history (100m apart) but different depositional environments and diagenetic histories. Early diagenetic precipitation of dolomite and anhydrite in the Bongabinni prevented grain rotation and compaction resulting in a relatively stiff rock and isotropic rock physics response. The Goldwyer underwent later quartz overgrowth development and contained more well-aligned illite, giving a weaker, more compressible shale with stronger fabric orientation and significant velocity anisotropy.&lt;/p&gt;
&lt;p&gt;
These studies highlight the strong impact that organic matter, minerals and their transformation during diagenesis can have on the evolution of rock properties and emphasize that multi-disciplinary studies can be crucial to unravelling often complex geological history in shale formations.&lt;/p&gt;-->
<!--ASDFASDFASDF<p>Marcellus Shale and Canning Basin shale samples were used to study diagenetic effects on the mineral and organic matter and their impact on petrophysical and geomechanical response.</p>-->

<!--ASDFStratigraphic Record of Late Cenozoic Basin Development Along the Pacific – North America Plate Boundary in the Gulf of California and Salton Trough-->
<!--ASDFASDF&lt;p&gt;The Pacific-North America plate boundary south of Palm Springs, Calif., is defined by a series of fault-bounded transtensional basins that have evolved to sea floor spreading in response to dextral relative plate motion over the past 10 million years. Research in this setting seeks to understand complex interactions and feedbacks among two major sets of governing processes: (1) lithospheric deformation that drives basin subsidence, deformation, inversion and erosion; and (2) sediment routing and space-time variations in sediment flux that control depositional paleoenvironments, delta migration, basin filling, crustal recycling and efficiency of extension that leads to continental break-up. Field-based studies show that, starting ~ 7-9 Ma when Baja California was still part of mainland Mexico, relative plate motion became localized along a narrow belt of newly forming strike-slip and normal faults. Terrestrial pull-apart basins were quickly flooded by marine waters as a result of rapid extension and subsidence that outpaced sediment input from adjacent rift-flank uplifts. By 6.3–6.5 Ma, a narrow belt of linked basins was inundated by marine incursion along &amp;gt; 1,000 km of the plate boundary from Palm Springs in the north to the south end of the Gulf of California. In addition, diffuse strain in the eastern California shear zone produced slow subsidence in transtensional sag basins that formed a broad inland sea along the lower reaches of the modern Colorado River valley, shortly prior to integration of the Colorado River to the Gulf of California. Since ca. 5 Ma a large volume of crust has been eroded from the Colorado Plateau, funneled as sediment through the Colorado River routing system, and deposited in large transtensional basins along the evolving plate boundary in the Salton Trough and northern Gulf of California. Construction of dams in the mid-1900’s created extremely effective traps (reservoirs) that abruptly ended the long-term flux of sediment and water to the delta, creating severe environmental impacts and dependence on river water resources that currently are shrinking in the face of prolonged drought.&lt;/p&gt;
&lt;p&gt;
It is now understood that the presence or absence of thick sediment exerts a first-order control on the fate of large deltas, deformation style, crustal recycling and rate at which extension proceeds to continental break-up. Uncertainty persists, however, regarding the nature of the control and influence of sediments on heat flow, strain rate, normal faulting and other rift processes. Recent studies document a history of unsteady, punctuated sediment discharge from the Colorado River to plate-boundary basins during the first ~0.5 Myr of river evolution, highlighting large gaps in our understanding of sediment routing processes and factors that control mass transfer from an eroding source to receiving basinal sinks. Future progress on this problem will require new studies that integrate field data with numerical models to decipher dynamic feedbacks between surface processes and 3D crustal strain over geologic timescales.&lt;/p&gt;-->
<!--ASDFASDFASDF<p>The Pacific-North America plate boundary south of Palm Springs, Calif., is defined by a series of fault-bounded transtensional basins that have evolved to sea floor spreading in response to dextral relative plate motion over the past 10 million years.</p>-->

<!--ASDFReservoir Quality Analysis and Prediction in Diagenetically Complex Reservoirs: A Challenging New Frontier-->
<!--ASDFASDF&lt;p&gt;Reservoir quality analysis is aimed at characterizing and locating favorable pore systems in the subsurface. Over the past two decades, and especially in the major deep-water plays, typical siliciclastic exploration targets have evolved from quartzose sandstones found in shallow, cool burial environments to sandstones that contain abundant chemically unstable grains and occur in deeper, hotter, and older burial settings. Sandstones containing such reactive grains are subject to extensive chemical diagenesis during burial that includes grain dissolution and precipitation of a variety of mineral cements and grain replacements. The increasing complexity of plays provides new challenges to reservoir quality specialists when evaluating reservoir quality away from well control. Standard industry modeling tools were primarily designed to emulate physical compaction and quartz cementation on a genetic basis, and most of the remaining non-quartz cements in these models are evaluated by ad hoc, non-genetic methods. Prediction of clay, zeolite, and carbonate cements may be especially challenging in emerging exploration areas.&lt;/p&gt;
&lt;p&gt;A brief retrospective will be given on the evolution of reservoir quality analysis and the prediction tools currently employed by industry. This will be followed by a synopsis of existing, but not commonly used geochemical approaches that can be effectively employed for the evaluation and prediction of complex diagenetic mineral overprints. The talk will conclude with an overview of recent research efforts aimed at extending the predictive capabilities of the existing compaction-quartz cementation modeling tools to include more comprehensive genetic models for complex chemical diagenesis.&lt;/p&gt;-->
<!--ASDFASDFASDF<p>Reservoir quality analysis is aimed at characterizing and locating favorable pore systems in the subsurface. Over the past two decades, and especially in the major deep-water plays, typical siliciclastic exploration targets have evolved from quartzose sandstones found in shallow, cool burial environments to sandstones that contain abundant chemically unstable grains and occur in deeper, hotter, and older burial settings. Sandstones containing such reactive grains are subject to extensive chemical diagenesis during burial that includes grain dissolution and precipitation of a variety of mineral cements and grain replacements. The increasing complexity of plays provides new challenges to reservoir quality specialists when evaluating reservoir quality away from well control. Standard industry modeling tools were primarily designed to emulate physical compaction and quartz cementation on a genetic basis, and most of the remaining non-quartz cements in these models are evaluated by ad hoc, non-genetic methods. Prediction of clay, zeolite, and carbonate cements may be especially challenging in emerging exploration areas.</p>-->

<!--ASDFExploring the Limits of Seismic Interpretation Techniques Through the Use of Computational Stratigraphy Models-->
<!--ASDFASDF&lt;p&gt;Seismic interpretation of the subsurface geologic record has evolved over the years from simple 2D wavelet visualizations on paper to dynamic 3D visualizations in computer programs. Proven 2D manual approaches gave the interpreter ample time to think about and validate geologic relationships as they built their seismic interpretation. But now we can automatically extract and view thousands of seismic reflections as movies in 3D and these accelerated mapping capabilities leave us little time to think about what we are seeing. High-definition monitors and dynamic visualization techniques encourage us to believe seismic images are “photographs” of the geologic record and make it easy to assume that seismic reflections &lt;em&gt;are &lt;/em&gt;geologic surfaces. We must not forget that the recorded geophysical response relates to a complex interplay between rock properties, depth and frequency and that these relationships impact interpretive uncertainty. In order to frame this uncertainty, we must understand how frequency loss impacts the accuracy of the seismic to geologic tie. And, in a future where automated seismic mapping is the norm, we must ensure interpretations are validated within the constraints of the data quality. &lt;/p&gt;
&lt;p&gt;At what frequency do seismic signals fail to accurately record geologic response? It is well established that seismic signals respond to impedance contrasts associated with variations in rock properties and fluid type in the subsurface, and it is also generally accepted that maximum seismic resolution is approximately &#188; of the seismic wavelet. It is well known that seismic frequency decreases with increasing depth so it should be obvious that deeper seismic reflections can represent a composite of responses from multiple geologic layers. Yet, our accelerated interpretive methods make it easy to overlook this simple reality. In a low-price environment we aim to minimize this geophysical and geologic uncertainty to improve project decisions and insure profitable outcomes. &lt;/p&gt;
&lt;p&gt;To address this challenge, Chevron developed &lt;em&gt;CompStrat&lt;/em&gt;, a high-resolution 3D computational forward stratigraphic modeling method that allows us to generate reservoir facies models constrained by the physics of clastic depositional process. Additionally, we have developed a convolutional model-to-seismic workflow that can transform these stratigraphic models into 3D synthetic seismic volumes at frequency ranges varying from 10 – 1500 Hz. We begin by generating a &lt;em&gt;CompStrat &lt;/em&gt;model (a field-scale, high-resolution depositional model representing the environment of deposition of the targeted reservoir) then we convert it into 3D synthetic seismic volumes at a range of frequencies using a variety of rock-physics relationships. We compare the various seismic results which allows us to measure the scale-dependent relationship between seismic frequency and geologic surfaces and to visualize how frequency loss degrades the accuracy of our interpretation.&lt;/p&gt;
&lt;p&gt;When conditioned &lt;em&gt;CompStrat &lt;/em&gt;models (using well data, stratigraphic interpretations or conceptual ideas) are converted to synthetic seismic, interpreters gain an interpretive framework in which they may test hypotheses. These integrated models allow interpreters to vary rock property and fluid assumptions, evaluate the observed seismic response, compare the modeled response to field data and to use these results to predict potential reservoir facies complexity. These comparisons allow interpreters to frame seismic uncertainty within the context of geologic possibility and to refine resource estimations in low-resolution scenarios. The ability to convert bed-scale computational models to 3D synthetic seismic models at high frequencies is allowing us to visualize the interpretive limits of seismic data and is substantiating the cautionary statements of our seismic interpretation pioneers. &lt;/p&gt;-->
<!--ASDFASDFASDF<p>Seismic interpretation of the subsurface geologic record has evolved over the years from simple 2D wavelet visualizations on paper to dynamic 3D visualizations in computer programs. Proven 2D manual approaches gave the interpreter ample time to think about and validate geologic relationships as they built their seismic interpretation. But now we can automatically extract and view thousands of seismic reflections as movies in 3D and these accelerated mapping capabilities leave us little time to think about what we are seeing. High-definition monitors and dynamic visualization techniques encourage us to believe seismic images are “photographs” of the geologic record and make it easy to assume that seismic reflections <em>are </em>geologic surfaces. We must not forget that the recorded geophysical response relates to a complex interplay between rock properties, depth and frequency and that these relationships impact interpretive uncertainty. In order to frame this uncertainty, we must understand how frequency loss impacts the accuracy of the seismic to geologic tie. And, in a future where automated seismic mapping is the norm, we must ensure interpretations are validated within the constraints of the data quality. </p>-->

<!--ASDFRe-evaluating the Relationship Between Relative Sea Level and Sediment Distribution Using Numerical Stratigraphic Forward Models-->
<!--ASDFASDF&lt;p&gt;Changes in relative sea level are often cited as the principal control on sediment distribution, stratal architecture, and the overall development of continental margins. Implicit to the assumptions of sequence stratigraphic models are that sediment supply is constant, the depositional system response to relative sea-level change is linear, and autogenic processes operate at relatively short spatio-temporal scales. Field studies, numerical, and physical tank experiments suggest these assumptions may not adequately characterize the behavior of sediment routing across continental margins.&lt;/p&gt;
&lt;p&gt;This presentation will review the results of recent 3D diffusion-based numerical stratigraphic forward model studies of the impact of relative sea-level on deep-water sand delivery. Model results were analyzed for the total volume of deep-water sand, and the timing, magnitude, frequency, and spatial distribution of delivery events.&lt;/p&gt;
&lt;p&gt;Key results show that:&lt;/p&gt;
&lt;ol&gt;
    &lt;li&gt;Autogenic and allogenic processes may produce similar depositional system responses,&lt;/li&gt;
    &lt;li&gt;The timing of deep-water sand delivery with respect to the relative sea-level curve may not be predicable&lt;/li&gt;
    &lt;li&gt;Relative sea-level does influence the short-term character of deep-water sand delivery, but not the total volume of sand delivered&lt;/li&gt;
    &lt;li&gt;Relative sea-level does not adequately capture the dimensional space in which depositional systems reside.&lt;/li&gt;
&lt;/ol&gt;
&lt;p&gt;These results are comparable to observations in natural settings because they can account for multiple controls on sedimentation in multidimensional space. Applying a sedimentological processed-based approach to the stratigraphic record can prove critical in the exploration, assessment, and characterization of hydrocarbon reservoirs.  Finally, the insights derived from well-validated numerical models can be used in continued development of sequence stratigraphic concepts.&lt;/p&gt;-->
<!--ASDFASDFASDF<p>Changes in relative sea level are often cited as the principal control on sediment distribution, stratal architecture, and the overall development of continental margins. Implicit to the assumptions of sequence stratigraphic models are that sediment supply is constant, the depositional system response to relative sea-level change is linear, and autogenic processes operate at relatively short spatio-temporal scales. Field studies, numerical, and physical tank experiments suggest these assumptions may not adequately characterize the behavior of sediment routing across continental margins</p>-->

<!--ASDFWhat Processes Control Widely Observed Patterns in Deep-Water Channel Fill Stratigraphy? Integrating Seafloor and Outcrop Data Uncovers Surprising Results-->
<!--ASDFASDF&lt;p&gt;I will review patterns of deep-water channel fill stratigraphy, based largely on outcrop investigations of Upper Cretaceous units in southern Chile (Tres Pasos Formation, Magallanes Basin). Linking observations from Chile to those from many other basins around the world, I will identify a series of channel fill characteristics that have been unsatisfactorily explained to date. To demonstrate a relatively poorly established link between sedimentary processes and stratigraphic products in deep-water channel systems, I will compare deep-water channels and their deposits to the more comprehensive meandering river facies model. I will then introduce observations of the modern Bute Inlet submarine channel system (British Columbia, Canada), including time-lapse bathymetry data, which reveals that upstream migrating knickpoints are the most important mechanism of deep-water channel maintenance. These observations inspire reinterpretation of the stratigraphic record in Chile, providing a unique opportunity to link sedimentary processes to products. In addition to the fundamental relevance of this work to understanding deep-water sedimentary systems, the outcomes of the analyses are useful for multi-scale predictions of connectivity in subsurface reservoirs.&lt;/p&gt;-->
<!--ASDFASDFASDF<p>I will review patterns of deep-water channel fill stratigraphy, based largely on outcrop investigations of Upper Cretaceous units in southern Chile (Tres Pasos Formation, Magallanes Basin). Linking observations from Chile to those from many other basins around the world, I will identify a series of channel fill characteristics that have been unsatisfactorily explained to date. To demonstrate a relatively poorly established link between sedimentary processes and stratigraphic products in deep-water channel systems, I will compare deep-water channels and their deposits to the more comprehensive meandering river facies model. I will then introduce observations of the modern Bute Inlet submarine channel system (British Columbia, Canada), including time-lapse bathymetry data, which reveals that upstream migrating knickpoints are the most important mechanism of deep-water channel maintenance. These observations inspire reinterpretation of the stratigraphic record in Chile, providing a unique opportunity to link sedimentary processes to products. In addition to the fundamental relevance of this work to understanding deep-water sedimentary systems, the outcomes of the analyses are useful for multi-scale predictions of connectivity in subsurface reservoirs.</p>-->

<!--ASDFEvolution of the Salina del Bravo, Mexico: The Bravo Trough, Sigsbee Canopy and Perdido Fold Belt -->
<!--ASDFASDF&lt;p&gt;The Salina del Bravo region, on the continental slope just south of the Texas border, is dominated by four structures. From landward to seaward: the Bravo trough, Sigsbee Canopy, Perdido fold belt, and BAHA high. The Bravo trough lies beneath the updip part of the slope, and is characterized by a thick, intensely folded Tertiary section beneath which the Mesozoic section is thin or absent. The Bravo trough runs for roughly 400 km along strike, and is at least 40 km wide, with the west edge lying beyond the limits of our dataset. The downdip end of the Bravo trough is connected to the Sigsbee canopy by a feeder or weld. The Sigsbee canopy lies almost entirely seaward of the Bravo trough, and in most places overlies the Perdido fold belt. In many places the Perdido fold belt folds the base of the Sigsbee canopy. Elsewhere, Perdido folds are truncated beneath an unconformity on which the canopy is emplaced. At the seaward end of the system is the BAHA high, named for the first well drilled in it. The BAHA high is a structural high in the base of salt, with 1-2 km of relief in most places. Like the Bravo trough, it runs over 400 km along strike. The Perdido fold belt lies on top of or updip of the BAHA high. &lt;/p&gt;
&lt;p&gt;We interpret the Bravo trough as a former salt wall (the Bravo diapir) that was loaded by sediments during a major depositional phase in the early Cenozoic. These sediments expelled salt from the Bravo diapir into the Sigsbee canopy. This depositional phase also destabilized the margin, leading to extension beneath the present onshore (Burgos basin) detached near the top of the Cretaceous. This extension was accommodated partly in the Bravo trough, where the detachment ramped down to the base of salt, and in the Perdido fold belt. The Perdido fold belt was buttressed against the BAHA high, which formed the downdip end of the system. We constructed a physical model to test the viability of our hypothesis. This model was able to reproduce all of the major features of the Salina del Bravo region.&lt;/p&gt;-->
<!--ASDFASDFASDF<p>The Salina del Bravo region, on the continental slope just south of the Texas border, is dominated by four structures. From landward to seaward: the Bravo trough, Sigsbee Canopy, Perdido fold belt, and BAHA high. The Bravo trough lies beneath the updip part of the slope, and is characterized by a thick, intensely folded Tertiary section beneath which the Mesozoic section is thin or absent. The Bravo trough runs for roughly 400 km along strike, and is at least 40 km wide, with the west edge lying beyond the limits of our dataset. The downdip end of the Bravo trough is connected to the Sigsbee canopy by a feeder or weld. The Sigsbee canopy lies almost entirely seaward of the Bravo trough, and in most places overlies the Perdido fold belt. In many places the Perdido fold belt folds the base of the Sigsbee canopy. Elsewhere, Perdido folds are truncated beneath an unconformity on which the canopy is emplaced. At the seaward end of the system is the BAHA high, named for the first well drilled in it. The BAHA high is a structural high in the base of salt, with 1-2 km of relief in most places. Like the Bravo trough, it runs over 400 km along strike. The Perdido fold belt lies on top of or updip of the BAHA high.</p>-->

<!--ASDFCommon Pitfalls and Limitations in Seismic Attribute Analysis-->
<!--ASDFASDF&lt;p&gt;Seismic amplitude volumes continually grow in number, size and spatial resolution. Meanwhile, a reduced number of seismic interpreters are tasked with mapping an expanded list of geologic targets ranging from traditional hydrocarbon traps, through shallow drilling hazards, to reservoirs for CO2 sequestration. To aid in these efforts, modern seismic attributes convert the seismic wiggles into images that more closely resemble geology. These images enable geoscientists to directly apply their understanding of the depositional environment, tectonic history, and diagenetic alteration to construct interpretations that go well beyond the simple time-structure maps of the past.&lt;/p&gt;
&lt;p&gt;
Today’s seismic interpreters are generalists rather than specialists, with a responsibility to understand both geologic processes and engineering data, to coordinate with drilling teams and partners and to integrate all these tasks within the corporate project management framework. Most companies have outsourced seismic processing and imaging to service providers, resulting in limited hands-on learning experiences for their newer generation of employees. This limited knowledge on how the seismic data volumes are generated, coupled with the high quality of these data, can lead to a false sense of confidence in the data, leading to interpretation pitfalls. &lt;/p&gt;
&lt;p&gt;
In this presentation, I will focus on common pitfalls in seismic attribute analysis. False structure due to velocity pullup and pushdown and fault shadows on time-migrated data predate but are enhanced by modern seismic attributes. Acquisition footprint is actually enhanced by many attributes. Spectral decomposition measures apparent (vertical) tuning rather than the tuning perpendicular to a thin bed. Other pitfalls arise by choosing attribute parameters that inadvertently mix stacked stratigraphy or by choosing parameters that exacerbate noise in the data. A common pitfall is blindly trusting the default parameters of a given attribute or interpretation tool. Although they are not seismic processors, interpreters have rudimentary processing tools at their disposal that allow them to balance the spectrum and enhance edges, thereby enhancing both vertical and lateral resolution. A common pitfall here is to accept the nicer looking result without correlating with well log data or examining the part of the data that was rejected. Depth-migrated data introduces a new suite of attribute pitfalls and limitations. Depth migration is needed to image steep dips and areas with significant velocity heterogeneity in the overburden. Here, an attribute algorithm may not be able to differentiate steeply dipping fault plane reflections or steeply dipping migration artifacts from steeply dipping stratigraphic reflections. Whereas the dominant period in time-migrated data may vary by a factor of two from shallow to deep, in depth-migrated data the dominant wavelength may vary by a factor of eight, requiring more careful attribute computation strategies.  &lt;/p&gt;
&lt;p&gt;
The most common pitfall is expecting an attribute to give you what you want rather than what it measures. I will illustrate these pitfalls through examples; where possible, I will suggest ways to avoid them or minimize their impact.
&lt;/p&gt;-->
<!--ASDFASDFASDF<p>Seismic amplitude volumes continually grow in number, size and spatial resolution. Meanwhile, a reduced number of seismic interpreters are tasked with mapping an expanded list of geologic targets ranging from traditional hydrocarbon traps, through shallow drilling hazards, to reservoirs for CO2 sequestration. To aid in these efforts, modern seismic attributes convert the seismic wiggles into images that more closely resemble geology. These images enable geoscientists to directly apply their understanding of the depositional environment, tectonic history, and diagenetic alteration to construct interpretations that go well beyond the simple time-structure maps of the past.</p>-->

<!--ASDFIlluminating Fractures: Geophysics and Machine Learning-->
<!--ASDFASDF&lt;p&gt;The modern energy economy often relies on the injection and withdrawal of fluids through fracture networks in rock. Whether for geothermal systems or the sequestration of anthropogenic waste (e.g. CO2), knowledge of the fracture system geometry and how it responds to perturbations in stress and fluid chemistry is crucial for safe and sustainable long-term management of a site. While many geophysical methods can locate and delineate fractures or faults, there is a need to extract physically measurable parameters that are directly linked to hydraulic and mechanical properties of fractures. I will present what we have learned from active and passive monitoring of fractures in the laboratory to illuminate and characterize fractures and an example of machine learning to identified changes in fluid saturation within a fracture set.&lt;/p&gt;-->
<!--ASDFASDFASDF<p>The modern energy economy often relies on the injection and withdrawal of fluids through fracture networks in rock. Whether for geothermal systems or the sequestration of anthropogenic waste (e.g. CO2), knowledge of the fracture system geometry and how it responds to perturbations in stress and fluid chemistry is crucial for safe and sustainable long-term management of a site. While many geophysical methods can locate and delineate fractures or faults, there is a need to extract physically measurable parameters that are directly linked to hydraulic and mechanical properties of fractures. I will present what we have learned from active and passive monitoring of fractures in the laboratory to illuminate and characterize fractures and an example of machine learning to identified changes in fluid saturation within a fracture set.
</p>-->

<!--ASDFData Analytics and Machine Learning for Energy Geoscience and Engineering-->
<!--ASDFASDF&lt;p&gt;Every energy company that I visit is interested in growing internal capabilities to add value with data analytics and machine learning.  Energy has a long history of working with large, complicated geoscience and engineering datasets and there is a growing toolbox of old and new emerging data-driven methods available that may offer improved efficiency and potentially new insights from vast and complicated subsurface datasets. This talk is an opportunity to link subsurface data analytics and machine learning to fundamental concepts from probability, statistics, geoscience and engineering and to provide an enthusiastic, but at times critical perspective on what we may expect in the data-driven science revolution.&lt;/p&gt;-->
<!--ASDFASDFASDF<p>Every energy company that I visit is interested in growing internal capabilities to add value with data analytics and machine learning.  Energy has a long history of working with large, complicated geoscience and engineering datasets and there is a growing toolbox of old and new emerging data-driven methods available that may offer improved efficiency and potentially new insights from vast and complicated subsurface datasets. This talk is an opportunity to link subsurface data analytics and machine learning to fundamental concepts from probability, statistics, geoscience and engineering and to provide an enthusiastic, but at times critical perspective on what we may expect in the data-driven science revolution.</p>-->

<!--ASDFTemplate-based modeling: Bridging the gap between quantitative outcrop studies and subsurface reservoir characterization-->
<!--ASDFASDF&lt;p&gt;Reservoir modeling workflows that test sensitivity to fluid flow and/or seismic response are typically performed at a sector-scale (i.e., grid cells at 10’s meters areally and ~1 m vertically). Even at this “fine scale”, there is a gap between observations gathered from core and analogue outcrops at the bed-scale and the model scale. Furthermore, the link between the sector model and subsurface seismic responses are often difficult to understand. Outcrop modeling studies designed to investigate realistic heterogeneity through the construction of single deterministic 2-D or 3-D interpolated models are often limited in direct application to subsurface modeling workflows.&lt;/p&gt;
&lt;p&gt;This work introduces the use of model templates derived from outcrop analogue studies that explicitly capture bed- to geobody-scale architecture (i.e., grid cells 2 m areally and 0.25 m vertically). The model templates serve as foundational depositional system building blocks and are used to gain a fundamental understanding of the impact of sedimentologic architecture in deep-water channels on subsurface fluid flow and seismic responses. Specifically, the objectives of this work are to use template-based models to investigate how intra-channel (bed-scale) and inter-channel (geobody-scale) stacking patterns control 1) both static and dynamic connectivity, and 2) seismic reflectivity response.&lt;/p&gt;
&lt;p&gt;Template-based models are constructed from the Laguna Figueroa section of the well-exposed Upper Cretaceous Tres Pasos Formation in Chilean Patagonia. The models are derived from observations and statistical analyses from &amp;gt; 1,600 meters of cm-scale measured section from an ~2.5 km long by 130 m thick outcrop belt. A single representative deep-water channel element is constructed as a base case. Fluid flow and seismic amplitude responses are compared from a single channel element to those from a model composed of two stacked channel elements. This simplified approach fosters the ability to differentiate influences of stacking patterns from changes in internal architecture on connectivity and imaging.&lt;/p&gt;
&lt;p&gt;Results show that flow connectivity and seismic responses are a function of both intra-channel architecture (bed-scale) and inter-channel architecture (stacking patterns) at the scale of sub-seismic and subsequently, sub-sector grid scale heterogeneity. Under waterflooding conditions, axial channel element deposits act as thief zones to injected water with vertically stacked templates, while marginal channel element deposits baffle and block flow between elements in laterally-offset stacked templates. Bed-scale architecture and smaller model grid-cell sizes are therefore more critical in channel systems (or parts of the channel systems) that predominantly contain laterally-offset stacked elements. Seismic amplitude and apparent thickness responses show discernable differences between single element and dual element models at realistic subsurface frequencies, particularly in vertically stacked templates and laterally-offset stacked templates. Two channel elements are more difficult to differentiate from one channel element in intermediate stacking patterns, but clues to multiple elements are revealed in interpreted horizon rugosity and in the length-scale of the seismic amplitude ( &amp;gt; than 1 channel element width). These models produce guidelines for coarse-scale model building (e.g., optimal grid-cell size and degree of fine-scale detail) and more informed seismic interpretation. This work also provides foundational models for seismic- and/or flow-based machine learning approaches.&lt;/p&gt;-->
<!--ASDFASDFASDF<p>Reservoir modeling workflows that test sensitivity to fluid flow and/or seismic response are typically performed at a sector-scale (i.e., grid cells at 10’s meters areally and ~1 m vertically). Even at this “fine scale”, there is a gap between observations gathered from core and analogue outcrops at the bed-scale and the model scale. Furthermore, the link between the sector model and subsurface seismic responses are often difficult to understand. Outcrop modeling studies designed to investigate realistic heterogeneity through the construction of single deterministic 2-D or 3-D interpolated models are often limited in direct application to subsurface modeling workflows.</p>-->

<!--ASDFEvolution of Antarctic vegetation cover from the Paleocene to the Pliocene: A review of case studies from the Antarctic Peninsula, the Ross Sea, the Sabrina Coast and the Dry Valleys-->
<!--ASDFASDF&lt;p&gt;Here we review the results of a series of Antarctic palynological studies that were conducted over the past fifteen years to evaluate the type of vegetation changes that occurred in Antarctica in the Paleogene and Neogene, and better constrain the timing and amplitude of these changes. Sites reviewed include a Paleogene section sampled off the Sabrina Coast, a Mio-Pliocene outcrop section sampled on King George Island, a Mio-Pliocene record obtained by SHALDRIL core NBP0602A-5D on the Joinville Plateau in the Weddell Sea, the Mio-Pliocene core obtained by the ANDRILL 2A campaign, and a series of Neogene outcrop samples obtained from the Dry Valleys.&lt;/p&gt;
&lt;p&gt;Fossils of pollen and spores recovered at these sites provide a record of vegetation changes that occurred in each of these regions of Antarctica. The timing of these changes are evaluated against known driving factors such as atmospheric concentration in carbon dioxide, plate tectonic activity (or lack of), precipitation, and temperature (sea-surface and atmospheric) changes.&lt;/p&gt;-->
<!--ASDFASDFASDF<p>Here we review the results of a series of Antarctic palynological studies that were conducted over the past fifteen years to evaluate the type of vegetation changes that occurred in Antarctica in the Paleogene and Neogene, and better constrain the timing and amplitude of these changes. Sites reviewed include a Paleogene section sampled off the Sabrina Coast, a Mio-Pliocene outcrop section sampled on King George Island, a Mio-Pliocene record obtained by SHALDRIL core NBP0602A-5D on the Joinville Plateau in the Weddell Sea, the Mio-Pliocene core obtained by the ANDRILL 2A campaign, and a series of Neogene outcrop samples obtained from the Dry Valleys.</p>-->

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            	<a href="/">Home</a><span id="dnn_dnnBREADCRUMB_lblBreadCrumb" itemprop="breadcrumb" itemscope="" itemtype="https://schema.org/breadcrumb"><span itemscope itemtype="http://schema.org/BreadcrumbList"><span itemprop="itemListElement" itemscope itemtype="http://schema.org/ListItem"><a href="https://www.aapg.org/career" class="Breadcrumb" itemprop="item"><span itemprop="name">Career</span></a><meta itemprop="position" content="1" /></span> <span itemprop="itemListElement" itemscope itemtype="http://schema.org/ListItem"><a href="https://www.aapg.org/career/training" class="Breadcrumb" itemprop="item"><span itemprop="name">Training</span></a><meta itemprop="position" content="2" /></span> <span itemprop="itemListElement" itemscope itemtype="http://schema.org/ListItem"><a href="https://www.aapg.org/career/training/online" class="Breadcrumb" itemprop="item"><span itemprop="name">Online</span></a><meta itemprop="position" content="3" /></span> <span itemprop="itemListElement" itemscope itemtype="http://schema.org/ListItem"><a href="https://www.aapg.org/career/training/in-person/distinguished-lecturers" class="Breadcrumb" itemprop="item"><span itemprop="name">Distinguished Lecture Program</span></a><meta itemprop="position" content="4" /></span> <span itemprop="itemListElement" itemscope itemtype="http://schema.org/ListItem"><a href="https://www.aapg.org/career/training/in-person/distinguished-lecturers/archives" class="Breadcrumb" itemprop="item"><span itemprop="name">Past DL Talk Titles</span></a><meta itemprop="position" content="5" /></span></span></span>
            
                 <h1>Past DL Talk Titles</h1>
            
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	<div id="dnn_ctr17339_HtmlModule_lblContent"><div class="list-without-images author dnnClear">
			<div class="text">
				<div class="name">Irene Arango</div>
			</div>
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    <li class="list-no-images dnnClear">
		<!---->
            <a href="http://www.aapg.org/career/training/in-person/distinguished-lecturer/abstract/articleid/50014">Understanding Expulsion Capacity and Organic Porosity in Unconventional Petroleum Systems </a>
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				<div class="name">Kristin Bergmann</div>
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		<!---->
            <a href="http://www.aapg.org/career/training/in-person/distinguished-lecturer/abstract/articleid/55549">Reconstructing Earth's Climate Dynamics at the Dawn of Animals</a>
	</li>
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				<div class="name">Maria Angela Capello</div>
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    <li class="list-no-images dnnClear">
		<!---->
            <a href="http://www.aapg.org/career/training/in-person/distinguished-lecturer/abstract/articleid/61257">Coupling Geoethics to Sustainability</a>
	</li>
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				<div class="name">Denise Cox</div>
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    <li class="list-no-images dnnClear">
		<!---->
            <a href="http://www.aapg.org/career/training/in-person/distinguished-lecturer/abstract/articleid/61249">Sustainable Development and the Energy Transition</a>
	</li>
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				<div class="name">Susan Cunningham</div>
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    <li class="list-no-images dnnClear">
		<!---->
            <a href="http://www.aapg.org/career/training/in-person/distinguished-lecturer/abstract/articleid/50016">What it Takes to be Successful in Exploration</a>
	</li>
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			<div class="text">
				<div class="name">Dave Dewhurst</div>
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		<!---->
            <a href="http://www.aapg.org/career/training/in-person/distinguished-lecturer/abstract/articleid/61261">Impact of Diagenesis on Rock Properties in Shales</a>
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				<div class="name">Rebecca J. Dorsey</div>
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    <li class="list-no-images dnnClear">
		<!---->
            <a href="http://www.aapg.org/career/training/in-person/distinguished-lecturer/abstract/articleid/61259">Stratigraphic Record of Late Cenozoic Basin Development Along the Pacific – North America Plate Boundary in the Gulf of California and Salton Trough</a>
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				<div class="name">William L. Esch</div>
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    <li class="list-no-images dnnClear">
		<!---->
            <a href="http://www.aapg.org/career/training/in-person/distinguished-lecturer/abstract/articleid/55545">Reservoir Quality Analysis and Prediction in Diagenetically Complex Reservoirs: A Challenging New Frontier</a>
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				<div class="name">Lisa Goggin</div>
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    <li class="list-no-images dnnClear">
		<!---->
            <a href="http://www.aapg.org/career/training/in-person/distinguished-lecturer/abstract/articleid/55546">Exploring the Limits of Seismic Interpretation Techniques Through the Use of Computational Stratigraphy Models</a>
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				<div class="name">Ashley Harris</div>
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    <li class="list-no-images dnnClear">
		<!---->
            <a href="http://www.aapg.org/career/training/in-person/distinguished-lecturer/abstract/articleid/49590">Re-evaluating the Relationship Between Relative Sea Level and Sediment Distribution Using Numerical Stratigraphic Forward Models</a>
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