Petrophysics and Well Logs

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Data derived from core and well-logs are essentially one-dimensional and determining eolian system type and likely dimensions and orientation of architectural elements present in subsurface eolian reservoir successions is typically not possible from direct observation alone. This is problematic because accurate predictions of the three-dimensional distribution of interdune and dune-plinth elements that commonly form relatively low-permeability baffles to flow, of net:gross, and of the likely distribution of elements with common porosity-permeability properties at a variety of scales in eolian reservoirs is crucial for effective reservoir characterization.

Direct measurement of a variety of parameters relating to aspects of the architecture of eolian elements preserved as ancient outcropping successions has enabled the establishment of a series of empirical relationships with which to make first-order predictions of a range of architectural parameters from subsurface successions that are not observable directly in core. In many preserved eolian dune successions, the distribution of primary lithofacies types tends to occur in a predictable manner for different types of dune sets, whereby the pattern of distribution of grain-flow, wind-ripple, and grain-fall strata can be related to set architecture, which itself can be related back to original bedform type.

Detailed characterization of individual eolian dune sets and relationships between neighboring dune and interdune elements has been undertaken through outcrop studies of the Permian Cedar Mesa Sandstone and the Jurassic Navajo Sandstone in southern Utah. The style of transition between lithofacies types seen vertically in preserved sets, and therefore measurable in analogous core intervals, enables predictions to be made regarding the relationship between preserved set thickness, individual grain-flow thickness, original bedform dimensional properties (e.g., wavelength and height), the likely proportion of the original bedform that is preserved to form a set, the angle of climb of the system, and the likely along-crest variability of facies distributions in sets generated by the migration of sinuous-crested bedforms. A series of graphical models depict common facies arrangements in bedsets for a suite of dune types and these demonstrate inherent facies variability.

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With technical advances in surface seismic and downhole electrical imaging techniques, it is now possible to not only map the distribution of reservoir sandstones in the subsurface, but to accurately define the orientation of productive fairways, or “sweet-spots”, within the sequence.

Channel sands frequently have favourable reservoir characteristics. Having often been laid down in higher energy settings, they commonly have coarser and better sorted grains, less clay and improved poroperm characteristics. However, they often have limited lateral extent and shoe-string geometries which make them more difficult to predict in the subsurface.

This paper will summarize the results of four case studies and some additional examples of how channel sands, laid down in different depositional settings, have been recognized with borehole imaging. From sedimentary features and palaeocurrent directions within the sands it has been possible to determine their orientation and evolve improved exploration and development strategies.

Further complexities in reservoir characterization, caused by thin beds or bioturbation; and how these effects can be recognized on the images, and quantified using other electric log data, will be discussed.

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Geosteering takes advantage of subsurface data being interpreted in real time in order to enable steering decisions during the process. The object if identifying target versus non-target stratigraphic horizons. Learn more about advancements made in this area.

American Association of Petroleum Geologists (AAPG)
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It’s now been shown that the “sweet” aspect of an identified sweet spot can change – not only stratigraphically, but also laterally within the zone itself.

American Association of Petroleum Geologists (AAPG)
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The West Virginia Division of Energy is currently evaluating several deep saline formations in the Appalachian Basin of West Virginia that may be potential carbon dioxide (CO2) sequestration targets. The Silurian Newburg Sandstone play, developed in the 1960s and 1970s, primarily involved natural-gas production from reservoir rock with well-developed porosity and permeability. High initial pres-sures encountered in early wells in the Newburg indicated that the overlying Silurian Salina Formation provides a competent seal. Be-cause of the large number of CO2 point sources in the region and the favorable reservoir properties of the formation (including an esti-mated 300 bcf of natural-gas production), the Newburg Sandstone was evaluated for the potential geologic storage of CO2. Within the Newburg play, there are several primary fields separated geographi-cally and geologically by saltwater contacts and dry holes. Previous studies have determined the storage potential within these individual fields. This study shows that the Newburg is more suitable for small-scale injection tests instead of large-scale regional storage operations.
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Field analogs allow a better characterization of fracture networks to constrain naturally fractured reservoir models. In analogs, the origin, nature, geometry, and other attributes of fracture networks can be determined and can be related to the reservoir through the geodynamic history. In this article, we aim to determine the sedimentary and diagenetic controls on fracture patterns and the genetic correlation of fracture and diagenesis with tectonic and burial history. We targeted two outcrops of Barremian carbonates located on both limbs of the Nerthe anticline (southeastern France). We analyzed fracture patterns and rock facies as well as the tectonic, diagenetic, and burial history of both sites. Fracture patterns are determined from geometric, kinematic, and diagenetic criteria based on field and lab measurements. Fracture sequences are defined based on crosscutting and abutting relationships and compared with geodynamic history and subsidence curves. This analysis shows that fractures are organized in two close-to-perpendicular joint sets (i.e., mode I). Fracture average spacing is 50 cm (20 in.). Fracture size neither depends on fracture orientation nor is controlled by bed thickness. Neither mechanical stratigraphy nor fracture stratigraphy is observed at outcrop scale. Comparing fracture sequences and subsidence curves shows that fractures existed prior to folding and formed during early burial. Consequently, the Nerthe fold induced by the Pyrenean compression did not result in any new fracture initiation on the limbs of this fold. We assume that the studied Urgonian carbonates underwent early diagenesis, which conferred early brittle properties to the host rock.

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The Marcellus Shale is considered to be the largest unconventional shale-gas resource in the United States. Two critical factors for unconventional shale reservoirs are the response of a unit to hydraulic fracture stimulation and gas content. The fracture attributes reflect the geomechanical properties of the rocks, which are partly related to rock mineralogy. The natural gas content of a shale reservoir rock is strongly linked to organic matter content, measured by total organic carbon (TOC). A mudstone lithofacies is a vertically and laterally continuous zone with similar mineral composition, rock geomechanical properties, and TOC content. Core, log, and seismic data were used to build a three-dimensional (3-D) mudrock lithofacies model from core to wells and, finally, to regional scale. An artificial neural network was used for lithofacies prediction. Eight petrophysical parameters derived from conventional logs were determined as critical inputs. Advanced logs, such as pulsed neutron spectroscopy, with log-determined mineral composition and TOC data were used to improve and confirm the quantitative relationship between conventional logs and lithofacies. Sequential indicator simulation performed well for 3-D modeling of Marcellus Shale lithofacies. The interplay of dilution by terrigenous detritus, organic matter productivity, and organic matter preservation and decomposition affected the distribution of Marcellus Shale lithofacies distribution, which may be attributed to water depth and the distance to shoreline. The trend of normalized average gas production rate from horizontal wells supported our approach to modeling Marcellus Shale lithofacies. The proposed 3-D modeling approach may be helpful for optimizing the design of horizontal well trajectories and hydraulic fracture stimulation strategies.

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Size fractions (<4 and 0.4–1.0 μ) of Brent Group sandstones from the northern North Sea contain mostly illite-smectite mixed layers with kaolinite, whereas the same size fractions of Fulmar Formation sandstones from the south-central North Sea consist of illite-smectite mixed layers with minor chlorite. Transmission electron microscope observations show elongated illite laths or agglomerates consisting of small laths when larger individual laths are lacking.

The K-Ar data of the fractions less than 0.4 μm of Brent Group samples plot on two arrays in a 40Ar/36Ar vs. 40K/36Ar diagram that have isochron characteristics with ages of 76.5 ± 4.2 and 40.0 ± 1.5 Ma, and initial 40Ar/36Ar ratios of 253 ± 16 and 301 ± 18, respectively. For the Fulmar Formation samples, the data points of the fractions less than 0.2 and less than 0.4 μ also fit two isochrons with ages of 76.6 ± 1.4 and 47.9 ± 0.5 Ma and initial 40Ar/36Ar ratios of 359 ± 52 and 304 ± 2, respectively. Some of the coarser 0.4–1.0-μ fractions also plot on the two isochrons, but most plot above indicating the presence of detrital components more than 0.4 μ. The almost identical ages obtained from illite-type crystals of sandstones with different deposition ages that are located about 600 km (373 mi) apart record two simultaneous illitization episodes. These events were not induced by local burial conditions, but are related to episodic pressure and/or temperature increases in the studied reservoirs, probably induced by hydrocarbon injection. This interpretation is indirectly supported by notably different K-Ar illite ages from cores of a nearby reservoir at hydrostatic pressure.

Illite is not as well crystallized as expected for potential crystallization temperatures above 160°C measured by fluid-inclusion determinations. In both the northern and south-central North Sea, the two illite generations remain unaffected after crystallization despite continued burial, suggesting notably higher crystallization temperatures than those estimated from geothermal gradients. No recent illite crystallization or alteration is recorded in the K-Ar ages, despite a dramatic regional acceleration of the subsidence in the southern North Sea. ±

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Pore-volume reduction of sediments by plastic deformation during compaction and by cementation of grains has been evaluated for different proportions of ductile and hard grains. We represent the compaction behavior of grains with a purely geometric model, which uses the cooperative rearrangement algorithm to produce dense, random packings of partly interpenetrating spheres. We varied the fraction of grains assumed to be ductile and the radius of the rigid core of the ductile grains. The predicted relationship between the fraction of ductile grains in the sediment and the porosity after compaction agrees well with previously published experimental data in the literature. The radius of the rigid core of the ductile grains is an effective way to represent different kinds of ductile material, ranging from brittle (rigid radius gt0.9) to extremely ductile (rigid radius lt0.7). We simulated quartz cementation in our compacted rock by adding isopachous cement. Cement thickness was reduced on the smaller grains and increased on the larger grains to account for presumed export of pressure-dissolved material from finer grained regions and the import of material into coarser grained regions. These simulations yield descriptions of pore-scale geometry resulting from processes common in sandstones. Modeled pore geometry provides insight into transport properties of such rocks. For example, the models predict, to within a factor of five, the permeability of samples of tight-gas sandstones having little intragranular porosity.
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Exploration for oil and gas in Saskatchewan was initiated in 1888 with the spudding of a 472-meter (1,548.5 feet) well near the settlement of Belle Plaine some 32 kilometers (20 miles) west of Regina.

American Association of Petroleum Geologists (AAPG)
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In-Person Training
Vilnius Lithuania 25 October, 2016 26 October, 2016 32641 Desktop /Portals/0/PackFlashItemImages/WebReady/er-gtw-gtw-hydrocarbon-exploration-lithuania-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Business and Economics, Economics, Reserve Estimation, Development and Operations, Engineering, Conventional Drilling, Coring, Production, Hydraulic Fracturing, Primary Recovery, Secondary Recovery, Gas Injection, Tertiary Recovery, Reservoir Characterization, Environmental, Natural Resources, Pollution, Geochemistry and Basin Modeling, Basin Modeling, Maturation, Migration, Oil and Gas Analysis, Oil Seeps, Petroleum Systems, Source Rock, Thermal History, Geophysics, Direct Hydrocarbon Indicators, Petrophysics and Well Logs, Sedimentology and Stratigraphy, Carbonates, Clastics, Conventional Sandstones, Deep Sea / Deepwater, Deepwater Turbidites, High Stand Deposits, Low Stand Deposits, Marine, Shelf Sand Deposits, Transgressive Deposits, Sequence Stratigraphy, Structure, Tectonics (General), Structural Analysis (Other), Salt Tectonics, Geomechanics and Fracture Analysis, Fold and Thrust Belts, Extensional Systems, Compressional Systems, Deep Basin Gas, Fractured Carbonate Reservoirs, Shale Gas, Stratigraphic Traps, Structural Traps, Subsalt Traps, Alternative Resources, Gas Hydrates
Vilnius, Lithuania
25-26 October 2016

AAPG Europe are excited to announce the first event to be held in the beautiful capital city of Vilnius, Lithuania. This Geosciences Technology Workshop will be based around the main theme "Hydrocarbon Exploration in Lithuania and the Baltic Region" and we expect interests from Latvia, Estonia, Poland and Kaliningrad.

Lithuania 26 October, 2016 26 October, 2016 33520 Desktop /Portals/0/PackFlashItemImages/WebReady/gtw-er-core-workshop-lithuanian-geological-society-2016-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Alternative Resources, Gas Hydrates, Deep Basin Gas, Fractured Carbonate Reservoirs, Shale Gas, Stratigraphic Traps, Structural Traps, Subsalt Traps, Business and Economics, Economics, Reserve Estimation, Development and Operations, Engineering, Conventional Drilling, Coring, Production, Hydraulic Fracturing, Primary Recovery, Tertiary Recovery, Secondary Recovery, Gas Injection, Water Flooding, Reservoir Characterization, Environmental, Natural Resources, Pollution, Water Resources, Geochemistry and Basin Modeling, Basin Modeling, Migration, Oil and Gas Analysis, Oil Seeps, Petroleum Systems, Source Rock, Thermal History, Geophysics, Direct Hydrocarbon Indicators, Petrophysics and Well Logs, Sedimentology and Stratigraphy, Carbonates, Clastics, Conventional Sandstones, Deep Sea / Deepwater, Deepwater Turbidites, Low Stand Deposits, Marine, Shelf Sand Deposits, Transgressive Deposits, Sequence Stratigraphy, High Stand Deposits, Structure, Fold and Thrust Belts, Extensional Systems, Salt Tectonics, Tectonics (General), Geomechanics and Fracture Analysis, Structural Analysis (Other), Compressional Systems
26 October 2016

Join AAPG Europe and the Lithuanian Geological Survey for this exciting Core Workshop. This workshop will follow on from the 'Hydrocarbon Exploration in Lithuania and the Baltic Regions' event taking place at Vilnius University on 24th – 25th October.

The Early Palaeozoic Hydrocarbon System in the Baltic Basin and adjacent territories involves Middle-Late Cambrian, the Late Ordovician (Mossen & Fjacka Formations) and the Early Silurian Graptolitic Shales source rocks and the major complexes of reservoirs, associated with Middle Cambrian sandstones, Ordovician and Silurian reefogenic and carbonate build-ups.

The major reservoirs of the Baltic Basin are:

  • The Middle Cambrian (Deimena Fm). Sandstones - Producing
  • The Early Ordovician (Tremadoc, Salantai Fm.) sandstones
  • Late Ordovician (Early Ashgill) organogenic limestones/carbonate buildups
  • Late Silurian (Late Ludlow/Pridoli) reefogenic carbonate build-ups
Core Presentation:
Cores presented from the following 3 reference wells:

1. The Middle Cambrian - the Early Ordovician quartz sandstone reservoirs

The Middle Cambrian Deimena Group sandstones comprises all the major economically important oil fields located Lithuania, Latvia, Kaliningrad district and Polish onshore and Baltic Sea offshore. The other, much less significant, potential reservoirs are the Late Ordovician carbonate build-ups of Gotland (Sweden) and Southern part of Lithuania and the Late Silurian carbonate reefogenic buildups in South Lithuania (Zdanaviciute O., Sakalauskas J. eds., 2001, Zdanaviciute, Lazauskiene 2007; Kanev et al., 1994).

The reference sections would demonstrate core from fine-grained (dominated by 0.25-0.1 mm fraction (30-75%)) quartz sandstones containing thin clay and siltstone interlayers. The sandstones are to a different degree litified by compaction and predominantly cemented by quartz and diagenetic quartz cement that has the major control on reservoir properties.

The Early Ordovician

The early Ordovician Tremadoc age (Pakerort Regional Stage, Salantai Fm.) strata distributed rather locally are a reservoir unit at the base of the Ordovician succession, comprising quartz sandstones and quartz siltstones of only 0.5 to 4 m thick. It overlays directly to the Middle Cambrian Deimena Group sandstones and together form one reservoir unit with similar reservoir properties. The formation is overlain by the Early Ordovician shales. Several small oil fields are producing from this reservoir unit in the western part of Lithuania.

2. The Late Ordovician (Early Ashgill) and Late Silurian (Late Ludlow/Pridoli) organogenic limestone and reefogenic carbonate buildups reservoirs

The Late Ordovician - The Late Silurian

The reservoir rocks within the Silurian succession are the Wenlock - Early Ludlow and Pridolian reefogenic carbonates comprising secondary dolomites and reefal limestones with thicknesses of tens of meters. Silurian sequences are locally distributed along the Eastern slope of the Baltic Basin. The Wenlockian - Early Ludlow strata are up to 28 m thick; the effective porosity ranges from 12% to 17% and average permeabilities – 12-15 mD. The most favourable conditions for the formation of non-structural traps (reef-associated, lithologic-stratigraphic and combined) are associated with the carbonates (mainly stromoporoidal and crinoidal limestones) sucession of about 90 m thick of the late Ludlow- earliest Pridoli (Minija and Ventspils Formations). The reservoir rocks has mean porosities of 6-15 % and up to 26% and permeability ~465mD, reaching up to 2400mD. The Late Silurian reservoir rocks mainly occur in central and southern Lithuania in the central part of the basin.

3. Late Ordovician (Mossen & Fjacka Formations) and the Early Silurian Llandovery Black Shales

The Late Ordovician Shales

In the central and eastern part of the Baltic Basin the potential source rocks comprises dark grey and black shales of the Late Ordovician Late Caradoc-Early Asghill Fjacka and Mossen formations. Both units are generally thin, reaching only up to 5–10 m; the thicknesses of Fjack & Mossesn Formations are 6 m and 4 m respectively. TOC content are mostly in the 0.9 to 10 % range, with occasional higher values of up to 15 %. The source rock facies are kerogen type II and II-III.

The Early Silurian Shales

Potential source rocks in the Silurian succession are found within the Llandovery, Wenlock and, presumably, Ludlow-aged strata. The Silurian source rocks are composed of dark grey and black graptolite shales and dark grey and black clayey marlstones. Within the Baltic Basin organic matter content generally ranges from 0.7 to 9–11%, but can be as high as 16.46 % (fig. 5.5.b; Zdanaviciute, Lazauskiene, 2004). In terms of petrography, the organic matter is dominated by syngenetic, sapropelic and marine material, together with vitrinite-like particles and abundant faunal remains. Detrital sapropel is scattered as very fine-grained particles and lenses. Liptinite (up to 20%) generally occurs together with dispersed liptodetrinite in sapropelic organic matter, or more rarely as scattered particles. (Zdanavičiūtė, Swadowska 2002, Zdanaviciute, Lazauskiene, 2004, 2007, 2009).

Maturities in the area of interest attain at pre-Silurian level 1.3% Ro and around 1.0% Ro at Silurian source rock level, and reach 1.9% on the prominent West-Lithuanian local temperature high Zdanaviciute, Lazauskiene, 2004, 2007, 2009)

Please note registration for the Core Workshop is available to attendees of the upcoming GTW "Hydrocarbon Exploration in Lithuania and the Baltic Region" on the 24th - 25th October 2016. Please click here for information about the event.

Buenos Aires Argentina 16 November, 2016 18 November, 2016 33655 Desktop /Portals/0/PackFlashItemImages/WebReady/lacr-gtw-moving-toward-the-prediction-of-unconventional-plays-hero-new.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true Development and Operations, Engineering, Directional Drilling, Production, Hydraulic Fracturing, Reservoir Characterization, Geochemistry and Basin Modeling, Oil and Gas Analysis, Source Rock, Geophysics, Seismic, Petrophysics and Well Logs, Carbonates, Sedimentology and Stratigraphy, (Carbonate) Shelf Sand Deposits, Clastics, Deep Sea / Deepwater, Marine, Transgressive Deposits, Slope, Structure, Geomechanics and Fracture Analysis, Structural Analysis (Other), Oil Shale, Shale Gas
Buenos Aires, Argentina
16-18 November 2016

Join leading scientists and industry practitioners at Moving toward the Prediction of Unconventional Plays: Lessons Learned from Tight and Shale Reservoirs in Neuquén Basin, Argentina, a Geosciences Technology Workshop (GTW) hosted by the American Association of Petroleum Geologists (AAPG) and the Argentine Association of Petroleum Geologists and Geophysicists (AAGGP).

Houston Texas United States 06 December, 2016 08 December, 2016 13606 Desktop /Portals/0/PackFlashItemImages/WebReady/sc-basic-petroleum-geology-for-the-non-geologist.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, Petrophysics and Well Logs, Basin Modeling, Source Rock, Petroleum Systems, Production
Houston, Texas, United States
6-8 December 2016

Here is an introduction to the tools and techniques that geologists and geophysicists use to locate gas and oil, that drillers use to drill the wells and that petroleum engineers use to test and complete the wells and produce the gas and oil. Exercises throughout the course provide practical experience in well log correlation, contouring, interpretation of surface and subsurface, contoured maps, seismic interpretation, well log interpretation, and decline curve analysis.

Online Training
02 October, 2014 02 October, 2014 10593 Desktop /Portals/0/PackFlashItemImages/WebReady/esymp-concepts-of-scale-horizontal-development-of-wolfcamp-shale-oil-of-the-southern-midland-basin-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
2 October 2014
This course is ideal for individuals involved in Midland Basin exploration and development. Successful development of Wolfcamp shale oil relies on complex inter-relationships (ultimately interdependencies) within and between a wide variety of scientific disciplines, financial entities, and company partnerships. 
09 September, 2014 09 September, 2014 10591 Desktop /Portals/0/PackFlashItemImages/WebReady/esymp-fluid-migration-and-accumulation-within-the-mississippian-why-2-oil-cut-here-15-one-mile-away-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
9 September 2014
Water cut is a big factor in gauging the success of horizontal drilling in the Mississippi Lime Play (MLP). The contributing factors are related in part to the spectrum of producing lithofacies and reservoir quality encountered that varies laterally and vertically, sometimes dramatically. 
24 October, 2013 24 October, 2013 1499 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-geomechanical-data-from-petrophysical-logs.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
24 October 2013

This e-symposium will be introducing signal processing techniques as a means to maximize extracting geomechanical data from petrophysical logs.

15 March, 2012 15 March, 2012 1484 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-exploring-the-geopressure-risk-in-deep-water-frontier-plays.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
15 March 2012

This e-symposium presents techniques for predicting pore pressure in seals by examining case studies from the Gulf of Mexico and incorporating the relationship between rocks, fluids, stress, and pressure.

29 September, 2011 29 September, 2011 1478 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-application-of-inversion-and-clustering-analysis.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
29 September 2011

This study will focus in the combination of λρ – μρ inversion with clustering analysis techniques in order to discriminate brittle zones in the Barnett Shale.

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.

10 September, 2013 10 September, 2013 1498 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-using-production-preformance-data-to-improve-geological-models.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
10 September 2013

The goal of this e-symposium is to review an important dimension in the ways geologist can build and update geological models using information from performance data.

30 August, 2012 30 August, 2012 1489 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-mississippian-carbonates-in-kansas.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
30 August 2012

The entire Middle Pennsylvanian–to–top Precambrian basement (500 m) interval was cored in early 2011 in the BEREXCO Wellington KGS #1-32 well in Wellington Field, Sumner County, KS.

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).

07 November, 2013 07 November, 2013 1500 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-from-qualitative-to-quantitative-interpretations.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
7 November 2013

This e-symposium presentation places the interpretation of deep-water turbidites discernible in 3-D seismic inversion data within a geological context.

10 November, 2011 10 November, 2011 1481 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-heterogeneity-in-carbonate-reservoirs.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
10 November 2011

This work investigates how heterogeneity can be defined and how we can quantify this term by describing a range of statistical heterogeneity (e.g. coefficient of variation and the Lorenz coefficient).

21 February, 2013 21 February, 2013 1495 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-petrophysics-of-carbonates.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
21 February 2013

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

07 June, 2012 07 June, 2012 1488 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-new-production-in-oil-fields.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
7 June 2012

Unger Field, discovered in1955, has produced 8.6 million barrels of oil from a thinly (several ft) bedded, locally cherty dolomite containing vuggy and intercrystalline porosity.

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.

25 August, 2011 25 August, 2011 1475 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-overview-of-hydraulic-fracturing-mechanics-analysis-and-design.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
25 August 2011

This e-symposium provides highlights of the hydraulic fracturing mechanics, analysis, and design, and is derived from a two and one-half (2-1/2) day course which is designed for drilling, completion, production engineers, engineering technicians, geologists, well-site and completion supervisors, and managers, who desire to possess a comprehensive and integral knowledge of Hydraulic Fracturing.

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.

17 February, 2011 17 February, 2011 1469 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-siliclastic-sequence-stratigraphy.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
17 February 2011

This presentation is designed for exploration/production geologists and geological managers or reservoir engineers.

25 March, 2010 25 March, 2010 1458 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-mapping-natural-fractures-using-3d-seismic-and-well-data.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
25 March 2010

The presentation describes a well established fracture modeling workflow that uses a standard 3D seismic, conventional logs, image logs and data from one core to build predictive 3D fracture models that are validated with blind wells.

25 January, 2011 25 January, 2011 1454 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-integrating-discipline-data-and-workflows-in-resource-play.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
25 January 2011

This esymposium takes a close look at workflows associated with resource plays, and analyzes where integration must occur between disciplines, data, and workflows at all phases of the process.

22 October, 2009 22 October, 2009 1452 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-fluvial-stratigraphy.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
22 October 2009

This course can help you gain the ability to describe the complex and highly variable reservoirs, which are typified by complex internal heterogeneity.

11 February, 2010 11 February, 2010 1441 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-predicting-gas-hydrates.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
11 February 2010

Gas hydrates, ice-like substances composed of water and gas molecules (methane, ethane, propane, etc.), occur in permafrost areas and in deep water marine environments.

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
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