HomeScience Discipline Geochemistry and Basin Modeling

Geochemistry and Basin Modeling

Recent Posts
Bogdan Michka posted Welcome to AAPG N.E.T., an online space where y... to Read This First! in Surface Geochemistry TIG Discussions
Bogdan Michka posted Welcome to AAPG N.E.T., an online space where y... to Read This First! in Imaging and Analytics TIG Discussions
Bogdan Michka posted Welcome to AAPG N.E.T., an online space where y... to Read This First! in Geochemistry in Exploration TIG Discussions
Bogdan Michka posted Welcome to AAPG N.E.T., an online space where y... to Read This First! in Geochemistry TIG Discussions
Bogdan Michka posted Welcome to AAPG N.E.T., an online space where y... to Read This First! in Geochemical Direct Hydrocarbon Indicators TIG Discussions
No posts yet.

In a recent EXPLORER, Marlan Downey lamented that he had not fully appreciated the idea that source rocks could serve as reservoir rocks for oil and natural gas. He was not alone.

American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/a-retrospective-on-source-rocks-as-reservoir-rocks-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true A Retrospective on Source Rocks as Reservoir Rocks

“Big Data and Deep Learning in the Oil Industry: Basics and Applications,” a Geosciences Technology Workshop to be held in Houston on May 22 at the CityCentre Norris Conference Center will focus on new analytics involving Big Data, deep learning and machine learning, and how they are transforming all aspects of the oil and gas industry.

American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/big-data-deep-learning-workshop-coming-in-may-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Big Data, Deep Learning Workshop Coming in May

The Next 100 Years: Data management is a crucial component of oil exploration. What does the century ahead look like for Big Data in the oil field?

American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/explorer-hero-2017-04april.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true The Oil Industry's Big Hurdle for Big Data

In 1965, G.T. Philippi, a Shell geochemist, made the novel proposal that petroleum was generated from organic matter in sediments that had been buried deeply enough to be exposed to warmer earth temperatures, converting the organic matter, with heat and time, to petroleum.

American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/source-rock-as-a-reservoir-a-personal-odyssey-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Source Rock as a Reservoir: A Personal Odyssey

TIGs and SIGs are designed to encourage greater Member participation in specific topics or interests – and to enhance Member engagement with other Members, and with AAPG. But what is the current roster of TIGs and SIGs – and who do you contact to join their fun?

American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/meta_AAPG_-200x200.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true SIGs and TIGs: How to Get Involved

Interpretations of thermal maturation provide critical data needed for both conventional and unconventional resource assessments. The absence of true vitrinite in pre-Devonian sediments eliminates one of the most commonly measured geothermometers used for thermal maturity determination. Programmed pyrolysis parameters like Tmax can be of limited utility given the maturity regime. However, other organic macerals are potentially available to constrain thermal maturity. The current organic petrology study has been undertaken to provide a very detailed comparison of reflectance measurements on pyrobitumens, “vitrinite-like” material and graptolites. 

In the Appalachian Basin of North America, Cambrian-aged source rocks were deposited in shallow water mixed carbonate-siliciclastic depositional environments. Solid pyrobitumen material is found to occur in both lenticular lens/layer morphology as well as distinct pore-filling angular varieties. Published formulas to calculate Equivalent Reflectance (Eq. Ro) from solid bitumens have been applied to these discrete morphological populations. In addition, a newly developed formula to calculate Eq. Ro from angular pyrobitumen (VRc=0.866*BRo ang + 0.0274) is introduced based upon statistical evaluation of reflectance readings from a global dataset. “Vitrinite-like” organic macerals were found in rare abundance within these potential source rocks, but their occurrence enables an independent comparison to pyrobitumen Eq. Ro values. Graptolites are another organic maceral that can be evaluated via organic petrology, but caution should be utilized since these tend to show a high degree of anisotropy. The results of this investigation provide additional geochemical guidance to assist geologists in more accurately interpreting thermal maturity in the Rome Trough region of the Appalachian Basin.

Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/sd-Assessing-Thermal-Maturity-in-Cambrian-Source-Rocks-Rome-Trough-Appalachian-Basin-Organic-Petrology-Complexities-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Assessing Thermal Maturity in Cambrian Source Rocks, Rome Trough, Appalachian Basin: Organic Petrology Complexities

Rock-Eval hydrogen index (HI) is often used to compare relative maturities of a source horizon across a basin. Usually, there are several measurements from the source horizon at a single well, and the mean hydrogen index is calculated, or the S2 is plotted against TOC. The slope of the best fit line through that data is used as the representative HI for that well (sometimes referred to as the ‘slope HI ’ methodology). There is a potential flaw in both these methodologies; however, that renders the calculated HI as misleading if the source horizon being examined is not relatively uniform in source quality, vertically in the stratigraphic column. From a geologic perspective, it would be unusual for the source rock quality not to vary vertically in the stratigraphic column. Organic matter input, preservation, dilution, and sediment accumulation rate typically vary in many depositional environments over the millions of years required to create a thick source rock package. Nevertheless, there are source rocks which do display remarkable source-quality uniformity from top to bottom of the stratigraphic package. We have examined source rocks from several basins where the source quality is relatively uniform over the stratigraphic column, and source rocks where the source quality varies greatly over the stratigraphic column. Methodologies to assess hydrogen index at specific wells for the se two scenarios differ. Most geoscientists may not be familiar with why a single technique is not suitable for both these scenarios, or how to correctly use hydrogen index as a relative maturation proxy in the case where source rock quality is not uniform. We will demonstrate how to determine if your source rock quality is uniform or varied relative to HI over the stratigraphic column, and how to assign a hydrogen index to the different source facies when that source rock quality is not uniform. Further we will illustrate how to estimate the original hydrogen index of the different source facies and assign each a transformation ratio. The transformation ratio is a better proxy for relative maturity, since different source facies may have different present-day hydrogen indices, but their present-day transformation ratio should be quite similar.

Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/sd-Hydrogen-Index-as-a--Maturity-Proxy-Some-Pitfalls-and-How-to-Overcome-Them-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Hydrogen Index as a Maturity Proxy - Some Pitfalls and How to Overcome Them

The assessment of the natural temporal variability of source rock units is critical for the understanding of petroleum systems as changes in mineral matrix, organic matter (OM) concentration, and composition can significantly affect expulsion efficiency, primary and secondary migration processes, hydrocarbon quality as well as oil source rock correlation. Already small-scaled fluctuations within sediment successions can critically influence migration efficiency. High-resolution investigation of a well-preserved Lower Jurassic drill core (Toarcian Posidonia Shale) revealed seven discrete and systematic intervals of deviating source rock quality. These were composed of homogenized, non-laminated marls of light grey color, opposed to laminated dark grey background sedimentation. Both lithotypes differentiate not only in mineral composition, but particularly in OM content and quality. An average TOC content of app. 3.9 wt.% reached by the grey marl, is faced by an average TOC content of app. 7.8 wt.% measured for the laminated dark grey marls. Average hydrogen index for grey non-laminated marls was app. 550 mg HC/g TOC, whereas much higher source rock quality with 780 mg HC/g TOC was attained in the dark laminated marls. The marls lower OM concentration and inferior OM quality generates important domains for preferential migration of products, originated from the dark grey layers, or hydrocarbon cluster in case of limited migration into adjacent reservoirs. To assess the potential for preferential intake of hydrocarbons by the coarser-grained light marls and their qualification as migration avenues, artificial maturation experiments were performed with both lithotypes. Hydrocarbon generation was simulated by hydrous pyrolysis in two successive temperature steps 330 °C and 360 °C, covering an early maturity stage, as well as the end of the oil window. Both lithologies show striking differences, not only for the extract yield, but also for the timing of generation. OM quality differences were reflected by variable n-alkane distributions and molecular maturity parameters. High-resolution continuous data produced by non-destructive techniques allows to draw conclusions on i) source rock potential, ii) expulsion and migration processes , and iii) on prediction of petroleum accumulation within the sediment succession. High-resolution investigation in combination with artificial maturation experiments represent an easy-to-use tool in petroleum system analysis.

Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/sd-Assessment-of-Temporal-Source-Rock-Variability-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Assessment of Temporal Source Rock Variability: An Example from the Lower Jurassic Posidonia Shale

The San Joaquin Basin lies west of the Sierra Nevada Mountains and east of the San Andre as Fault. Tens of kilometers of Mesozoic and Cenozoic sediments, including deep-water organic-rich source rocks, deposited in a forearc setting, comprise the basin and have contributed to a petroleum system that generates more than 70 percent of California 's daily oil production and includes three of the 10 largest oilfields in the United States. Based on a comprehensive 3D petroleum systems model of the San Joaquin basin, published by the USGS in 2008, we further refine the modeling to account for the unique depositional and tectonic history of the basin. Here, we compare various basal heat flow scenarios to model hydrocarbon generation and calibrate the results to available temperature and vitrinite reflectance (Vr) data. We investigate two types of crustal models: a McKenzie-type rift model, and a no-rift static crustal thickness model. Crustal stretching models calculate basal heat flow resulting from stretching/thinning of mantle and crust during initial (syn-rift) and thermal (post-rift) subsidence. This method uses rock matrix radiogenic heat production values. It does not account for transient effects resulting from burial and uplift of the basin fill. The static no-rift model, alternatively, calculates the basal heat flow based on a stable or non-thinning crust and mantle over time. This method uses estimated Uranium (U), Thorium (Th), and Potassium (K) concentrations within the rock material to then calculate the rock matrix heat production. Unlike the rift model, it accounts for the transient effects resulting from burial and uplift of the basin fill, which can have a considerable additional effect on the basal heat flow. Given the low probability of crustal stretching as the starting point for basal heat flow in the San Joaquin Basin and considering the forearc nature of the basin as well as the strong concentration of U, K, and Th in the Sierran granites, we focused on and refined the no-rift models. We manually account for the transitional nature of the San Joaquin basement from hot Sierran granite on the east to cool Franciscan oceanic rocks on the west. Radiogenic heat production from solely continental crust results in models that are too warm and cannot be calibrated to well temperature and Vr data. Solely oceanic models are too cool to match well data. ‘Combined crust’ incorporates a seismically derived suture zone that allows for a transition from oceanic to granitic basement, while the ‘intermediate crust’ mixes oceanic and continental radiogenic heat production. These models generate a good match to well data to the east and westward through the transition zone. Additionally, we are able to calibrate to wells off of the Belridge and Lost Hills structures. On structure wells, however, cannot be calibrated with a crustal conductive heat flow scenario and would require (local) elevated heat flows on the order of 20 mW/m 2. This is not in agreement with the generally cooler underlying oceanic crust and suggests that there might be a different and/or additional source of heat flow. Most likely, basin-scale hydrothermal groundwater flow, both along faults and up-structure, could account for elevated Vr and temperature. Convective heat flow would be an additional overprint or enhancement to conductive basal heat flow.

Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/sd-Incorporating-Complex-Geology-in-Basin-Models-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Incorporating Complex Geology in Basin Models: Example from a Forearc Basin; San Joaquin Valley, California

The driving forces for conventional accumulations (structural or stratigraphic traps) are Forces of Buoyancy which are due to differences in densities of hydrocarbons and water. In contrast, the driving forces for unconventional tight accumulations are Forces of Expulsion which are produced by high pressures. That is an enormous difference and creates unconventional petroleum systems that are characterized by very different and distinctive characteristics. The Force of Expulsion pressures are created by the significant increase in volume when any of the three main kerogen types are converted to hydrocarbons. At those conversion times in the burial history, the rocks are already sufficiently tight so the large volumes of generated hydrocarbons cannot efficiently escape through the existing tight pore system, thus creating a permeability bottleneck that produces an overpressured compartment over a large area corresponding to the proper thermal oil and gas maturities for that basin. The forces initially created in these source rocks can only go limited distances into adjacent tight reservoirs (clastics or carbonates) above or below the source. The exact distance will vary depending on the pressure increase, matrix permeability, and fractures of that specific tight reservoir system. In general, the distances are small, in the orders of 10s to 100s of feet for oil and larger for more mobile gas systems. Those exact distance numbers are subject to ongoing investigations.  

A plot of the pressure data versus elevation for a given formation is critical in determining whether an accumulation is conventional or unconventional. Conventional accumulations will have hydrocarbon columns of 10s to 100s of feet with the pressure in the hydrocarbons and that in the water equal at the bottom of the accumulation (at the HC-water contact). In contrast, the unconventional accumulations will show HC column heights of 1000s of feet with the pressure in the hydrocarbon phase and the water phase being the same at the top of the accumulation (at the updip transition zone). Those significant differences are critical for understanding and differentiating these two play types. Because the system is a pore throat bottleneck with very little or minimum lateral migration, the type of hydrocarbon s are closely tied to the thermal maturity required to generate those hydrocarbons. Thus the play concept begins with two important geochemical considerations: (1) where are the source rocks and what are the kerogen types and organic richness (TOC), and (2 ) where are they mature in the basin for oil, condensate, and gas in the basin. These parameters will very quickly define the fairway for the play. Then one has to add the critical information on the reservoirs themselves: composition (brittleness), thickness, and reservoir quality (matrix porosity and permeability). In summary, these tight unconventional petroleum systems (1) are dynamic , and (2) create a regionally inverted petroleum system with water over oil over condensate over gas for source rocks wit h Type I or II kerogen types.

Show more American Association of Petroleum Geologists (AAPG)
Desktop /Portals/0/PackFlashItemImages/WebReady/sd-Our-Current-Working-Model-for-Unconventional-Tight-Petroleum-Systems-Oil-and-Gas-hero.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Our Current Working Model for Unconventional Tight Petroleum Systems: Oil and Gas
In-Person Training
Rio de Janeiro Acre Brazil 22 August, 2017 23 August, 2017 38190 Desktop /Portals/0/PackFlashItemImages/WebReady/gtw-lacr-optimization-of-e-p-projects-integrating-geosciences-and-engineering-from-block-acquisition-through-production-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Development and Operations, Engineering, Infill Drilling, Directional Drilling, Coring, Conventional Drilling, Reservoir Characterization, Geochemistry and Basin Modeling, Basin Modeling, Petroleum Systems, Geophysics, Seismic, Petrophysics and Well Logs, Fractured Carbonate Reservoirs, Stratigraphic Traps, Subsalt Traps
Rio de Janeiro, Acre, Brazil
22-23 August 2017

AAPG and ABGP invite you to participate in an interactive, multidisciplinary workshop featuring presentations and discussions exploring opportunities to improve companies’ efficiency and effectiveness throughout the E&P cycle, from block acquisition and exploration to development and production.

London Aberdeen City United Kingdom 14 October, 2017 15 October, 2017 40511 Desktop /Portals/0/PackFlashItemImages/WebReady/ice-2017-sc-4-basin-and-petroleum-system-modeling-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Member, Geochemistry and Basin Modeling
London, Aberdeen City, United Kingdom
14-15 October 2017

In Conjunction with AAPG/SEG 2017 International Conference & Exhibition (ICE)
This short course provides an introduction to Petroleum Systems Modeling (PSM) in Exploration, with both conventional and unconventional examples.

Robin Hood's Bay North Yorkshire United Kingdom 18 October, 2017 20 October, 2017 40473 Desktop /Portals/0/PackFlashItemImages/WebReady/ice-2017-field-trip-7-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Member, Geochemistry and Basin Modeling, Source Rock, Sedimentology and Stratigraphy, Carbonates, ICE 2017, Field Trips, Conventions, Post-Convention
Robin Hood's Bay, North Yorkshire, United Kingdom
18-20 October 2017

We will visit sections of organic-rich, Lower Jurassic, mudstone-dominated strata where depositional, diagenetic and structural processes can be examined in the context of shale resources, and Zechstein (Upper Permian) lagoonal, reefal and lower slope carbonates which act as tight, fractured reservoirs from the North Sea to Poland.

Marrakech Morocco 01 November, 2017 04 November, 2017 37903 Desktop /Portals/0/PackFlashItemImages/WebReady/gtw-afr-the-paleozoic-hydrocarbon-potential-of-north-africa-past-lessons-and-future-potential-2017-17apr17-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Engineering, Development and Operations, Production, Infill Drilling, Geochemistry and Basin Modeling, Petroleum Systems, Source Rock, Thermal History, Geophysics, Clastics, Sedimentology and Stratigraphy, Conventional Sandstones, Sequence Stratigraphy, Structure, Compressional Systems, Extensional Systems, Tectonics (General), Deep Basin Gas, Stratigraphic Traps, Structural Traps
Marrakech, Morocco
1-4 November 2017

This workshop provides the opportunity to learn and discuss the latest knowledge, techniques & technologies applied to petroleum reservoirs in the Paleozoic of North Africa which can be utilized to explore for and develop these reservoirs. The workshop will provide a set-up for networking, interacting & sharing expertise with fellow petroleum scientists interested in developing and producing hydrocarbon resources within the Paleozoic of North Africa.

Marrakech Morocco 03 November, 2017 04 November, 2017 41272 Desktop /Portals/0/PackFlashItemImages/WebReady/gtw-afr-the-paleozoic-hydrocarbon-potential-of-north-africa-past-lessons-and-future-potential-2017-17apr17-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Structure, Geochemistry and Basin Modeling, Sedimentology and Stratigraphy, Geophysics, Engineering, Compressional Systems, Tectonics (General), Extensional Systems, Source Rock, Petroleum Systems, Thermal History, Sequence Stratigraphy, Clastics, Development and Operations, Production, Structural Traps, Deep Basin Gas, Stratigraphic Traps, Conventional Sandstones, Infill Drilling
Marrakech, Morocco
3-4 November 2017

Location: Atlas; Anti-Atlas of Marrakech and Ouarzazate areas of Morocco**
Field Trip Leader: Abdallah Aitsalem (ONHYM) & Lahcen Boutib (ONHYM)
Field Trip Fee: USD575 *

* Field trip pricing covers accommodation, feeding and transportation for the duration of the Trip. Seats are limited and will be confirmed on a first come first served basis.

Day 1 Departure from Marrakech to Ouarzazate

The Atlas Mountains of Marrakech extend more than 250 km East-West and 50 km North-South. They record the highest mountainous peaks in North Africa with altitudes exceeding 4,000 meters (Toubkal 4,165m and Ouenkrim 4,089m). Northward and southward, they rise hundreds of meters above the Marrakech plain (Haouz plain) and Imini syncline, respectively. The recently incised mountain valleys, created during the last inversion of the Atlas, form the crossing ways of the massif, as is the case of the main road that connects Marrakech to Ouarzazate passing via the Tizi n'Tichka Pass. They also provide the opportunity to view multiple breathtaking landscapes and contain outcrops that shed light on the geological evolution of the mountain from the Precambrian to the present. Day 1 of the field trip will allow participants to view Paleozoic outcrops through the Tizi n'Tichka Pass, which displays a complete Cambrian to Devonian succession and contains several organic-rich intervals. Mesozoic and Cenozoic deposits, which are exposed on the borders of the massif, will also be viewed briefly.

Day 2: Departure from Ouarzazate to Tazzarine and back to Ouarzazate **

Day 2 of the field trip crosses the central Anti-Atlas Paleozoic basin and offers spectacular views of the largest oasis in North Africa, along the Draa River, and its majestic ancient Kasbahs. Participants will examine formations ranging in age from Upper Precambrian to Silurian. Discussions will focus on the evolution of their various depositional environments in relation to sea level changes. The well exposed sandstone formations provide the opportunity to view major Paleozoic reservoirsintervals, as well as the organic-rich "hot shales" that source these reservoirs. Rubble from recent water wells and ingenious sub-cropping irrigation systems (Khattara) provide the chance to sample fresh Ordovician and Silurian organic-rich and fossiliferous black shales. In addition, the participants will have perspective views of gentle folding generated during the Hercynian compression and related regional fractures.

**Field trip will end in Ouarzazate. All participants to arrange their own transport from Ouarzazate following the conclusion of the field trip.

To register for the field trip please click here.

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.

Abu Dhabi - Yas Island Abu Dhabi United Arab Emirates 30 January, 2018 01 February, 2018 32793 Desktop /Portals/0/PackFlashItemImages/WebReady/gtw-mer-carbonate-reservoirs-of-the-middle-east-and-their-future-challenges-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Sedimentology and Stratigraphy, Carbonates, Geophysics, Seismic, Engineering, Reservoir Characterization, Geochemistry and Basin Modeling, Structure, Geomechanics and Fracture Analysis
Abu Dhabi - Yas Island, Abu Dhabi, United Arab Emirates
30 January - 1 February 2018

This three-day workshop builds on the success of the first AAPG Carbonate Reservoirs of the Middle East GTW, held in Abu Dhabi, UAE in 2015. It is dedicated to addressing the hydrocarbon bearing carbonate reservoirs of the Middle East, in the context of a changing oil market within a more challenging exploration and development environment. These challenges include the shift from traditional anticlinal traps to stratigraphic traps, and development strategies for dealing with maturing, long-producing, giant fields.

Al Ain Abu Dhabi United Arab Emirates 01 February, 2018 01 February, 2018 38233 Desktop /Portals/0/PackFlashItemImages/WebReady/gtw-mer-carbonate-reservoirs-of-the-middle-east-and-their-future-challenges-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Structure, Geochemistry and Basin Modeling, Sedimentology and Stratigraphy, Geophysics, Engineering, Geomechanics and Fracture Analysis, Carbonates, Seismic, Reservoir Characterization
Al Ain, Abu Dhabi, United Arab Emirates
1 February 2018

The main objective of this field trip is to offer participants the opportunity to study the structural style and fracturing of carbonate rocks analogous to reservoir units of the globally important UAE Oil Province. The clear exposure of these carbonate rocks in this tectonically complicated area provides a significant opportunity to study and explain the structural style and deformation history of the region. Although the carbonate rocks exposed in Jebal Hafit area are of Early Eocene–Miocene age (Rus, Dammam and Asmari Formations), the emphasis here is to study fractures pattern and fracturing mechanism with relation to the paleostress and the link to fractures conductivity.

The selected stops will demonstrate the stratigraphic relationship of the rock units and their fracture systems that have been developed during long geological deformation. There are significant similarities between these exposed rocks and those units seen in the Abu Dhabi Oil Fields by means of reservoir characteristics and fracture system and fracture related diagenesis (cementation/host rock alteration) with its impact on sealing potential.

Jebal Hafit, an elongated asymmetrical, double‐plunging, NNW‐SSW trending anticline with an elevation reaches up to ~ 1140 m high, is situated at the border between Oman and UAE. It extends ca 30 km in the direction NNW–SSE with average width of 4 to 5 km.

Al Ain Abu Dhabi United Arab Emirates 01 February, 2018 01 February, 2018 38235 Desktop /Portals/0/PackFlashItemImages/WebReady/gtw-mer-carbonate-reservoirs-of-the-middle-east-and-their-future-challenges-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Structure, Geochemistry and Basin Modeling, Sedimentology and Stratigraphy, Geophysics, Engineering, Geomechanics and Fracture Analysis, Carbonates, Seismic, Reservoir Characterization
Al Ain, Abu Dhabi, United Arab Emirates
1 February 2018

The modern carbonate-evaporite depositional environments along the Abu Dhabi shoreline and offshore Abu Dhabi belong to the few areas of the world where the geoscientist can observe the interplay between carbonate and evaporite sedimentation.

Supratidal (sabkha) to intertidal and shallow subtidal (microbial mat and peloid-skeletal tidal-flat) environments will be studied in the vicinity of Al-Qanatir Island.

Al-Qanatir Island

In the vicinity of the road to Al-Qanatir Island participants will be able to study a complete and undisturbed lateral facies succession from the upper supratidal to the lower intertidal and shallow subtidal:

  • Upper supratidal stranded beach ridges
  • Topographic highs, some cm above the adjacent upper sabkha environment
  • Upper sabkha (upper supratidal)
  • Surface covered by polygonally-cracked halite crust
  • Middle sabkha (middle supratidal)
  • Surface covered by finely-crystalline, whitish anhydrite polygons
  • Lower sabkha (lower supratidal)
  • Surface covered by shiny, sparkling gypsum crystals
  • Upper to lower intertidal microbial mat
  • Crenulated or crinkled microbial mat above gypsum mush facies
  • Blistered and pinnacle microbial mat
  • Polygonal and tufted microbial mat
  • Lowermost intertidal to shallow sub-tidal
  • Peloid-skeletal tidal-flat

Many of these depositional environments and facies successions correspond to those observed in cores from the subsurface of the Arabian Peninsula.

Victoria Island Lagos Nigeria 08 February, 2018 09 February, 2018 38212 Desktop /Portals/0/PackFlashItemImages/WebReady/gtw-ar-enhancing-mature-fields-life-cycles-hero-v2.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Business and Economics, Economics, Reserve Estimation, Risk Analysis, Development and Operations, Engineering, Infill Drilling, Production, Drive Mechanisms, Water Drive, Hydraulic Fracturing, Primary Recovery, Secondary Recovery, Gas Injection, Water Flooding, Tertiary Recovery, Chemical Flooding Processes, Thermal Recovery Processes, Reservoir Characterization, Geochemistry and Basin Modeling, Basin Modeling, Petroleum Systems, Petrophysics and Well Logs, Sedimentology and Stratigraphy, Clastics, Structure, Extensional Systems, Diagenetic Traps, Stratigraphic Traps, Bitumen/Heavy Oil
Victoria Island, Lagos, Nigeria
8-9 February 2018

This workshop provides the opportunity to learn and discuss the latest knowledge, techniques & technologies applied to mature fields. The workshop will provide a set-up for networking, interacting & sharing expertise with fellow petroleum scientists interested in enhancing production from maturing fields in the Niger Delta and similar deltaic settings.

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.
19 March, 2015 19 March, 2015 16283 Desktop /Portals/0/PackFlashItemImages/WebReady/New-Insights-into-the-Stratigraphic-Framework-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
19 March 2015

A detailed biostratigraphic analysis and stratigraphic framework of the Paleocene and Eocene Chicontepec Formation in the Tampico-Misantla basin, onshore eastern Mexico, was conducted using 33 wells.

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.

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.

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.

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.

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.

13 December, 2012 13 December, 2012 1494 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-petrophysics-of-shales.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
13 December 2012

The course will review core data, petrophysical comparisons, rock physics modeling (including pseudo logs and mechanical properties).

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.

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.

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.

11 November, 2010 11 November, 2010 1465 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-geochemical-evaluation-of-eagle-ford-group-source.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
11 November 2010

This e-symposium is ideal for geologists, geophysicists, engineers and other geoscientists who are involved in gas shale exploration and production.

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.

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 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.

01 November, 2013 01 November, 9999 452 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-toc-petroleum-exploration-production.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
1 November 2013 - 1 November 9999

This online course provides an overview of the petroleum industry from what is natural gas and crude oil to how to explore, drill, and produce oil and gas.

14 February, 3000 14 February, 3000 7817 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-generic-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true

Request a Visit

The enhanced production of unconventional hydrocarbons, the mitigation of biosourcing, and the advancement of carbon capture and storage, now combine to create significant financial and technical challenges to the global oil and gas industry.  Emerging and especially promising Geobiology approaches to these issues include utilization of the physical and biogeochemical activity of microorganisms that inhabit deeply buried hydrocarbon reservoirs.

Show more

Request a visit from Bruce Fouke!

Desktop /Portals/0/images/_site/AAPG-newlogo-vertical-morepadding.jpg?width=100&h=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
Position Available
Coming Soon

Check back often. "Find an Expert" feature is coming online soon!

Related Interests

See Also ...