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January 9th, 2012
Horizontal Production Logging
Brian Dupuis
Schlumberger Senior Production Log Analyst & Technical Team Lead
November 14th, 2011
Texas Board of Professional
Geoscientists’ Rule Making Process and the “Oil & Gas Exemption.”
Under state law, the TBPG has rulemaking authority and uses this authority to promulgate legislation involving the public practice of geoscience in Texas. Recent proposed rules created a controversy with the oil & gas industry, which enjoys certain exemptions under the enabling statute. This presentation will provide insight and background concerning the rulemaking process within state agencies and the factors to consider when invoking the “oil & gas exemption”.
Y. Lynn Clark, P.G.
October 10th, 2011
Effects of confining stresses and rock strength
on fluid flow in low permeability rocks.
Enderlin, Milton and Alsleben, Helge
School of Geology, Energy, and the Environment
Texas Christian University
TCU Box 298830
Fort
Worth, TX 76129
Changing
stresses can modify rock properties such as porosity and permeability, but can
also affect the ability of fluid to flow along planar mechanical
discontinuities such as faults, shear fractures, tensile cracks, or bedding
planes. The degree to which the flow of fluids will be altered with variation
of confining stress depends on the spatial orientation of the mechanical
discontinuity and the strength of the rock. Similarly, if hydraulic fracture
stimulation is conducted in the vicinity of a mechanical discontinuity and the
pressurized fracture fluids establish hydraulic continuity with the
discontinuity, then the pressurizing fluids can alter the stresses at the
mechanical discontinuity. These changes can cause the mechanical discontinuity
to reactivate in shear resulting in an increase in the ability of the
mechanical discontinuity surface to allow fluid flow, thus potentially
diverting the stimulation fluids off in a direction other than anticipated.
A
key component in the characterization of fluid flow along mechanical
discontinuities is an understanding of the surrounding subsurface stress field.
To constrain the present-day horizontal stress magnitude, a stress-strength
equilibrium approach is employed using overburden rock density estimation and
insights into the present-day tectonic setting. Stress orientation can also be
inferred from structural geology principles via interpretation of mapped active
features and wellbore information such as drilling history and image logs. Once
information about stress magnitudes and orientation is available, one can
calculate the shear and normal stress magnitudes acting on planar mechanical
discontinuities of all possible strikes and dips. Furthermore, one can evaluate
what magnitude of fluid pressure within each mechanical discontinuity would be
required to encourage shear failure reactivation. An example from the Barnett
shale play is presented as an application of the method, offering various
solutions to the likely orientations of fractures that could interact with
hydraulic fracture treatment.
Helge Alsleben
Helge is a structural geologist and Associate Professor in
the School of Geology, Energy, and the Environment at TCU. Helge is a native of
Germany and holds a B.S. equivalent from the University of Hamburg, Germany, a
M.S. in geology from San Jose State University in San Jose, California, and a
Ph.D. in geology from the University of Southern California in Los Angeles,
California.
He teaches undergraduate and graduate courses in
“Structural Geology”, “Global Tectonics and Basin Analysis” and “Geomechanics”
(co-taught with Milt Enderlin). He is primarily a
field-oriented geologist with a background in strain analyses as well as
structural and microstructural analyses of rocks. His academic expertise about
stress and strain provides the theoretical background for applied geomechanical
problems that are part of his current research interests. He has authored or
co-authored numerous publications and regularly presents his research results
at regional, national, and international conferences. He is a member of AAPG,
AGU, and GSA.
September 12th, 2011
‘Microseismic
Mapping of Hydraulic Fracture Treatments: Application of
High-Quality Geophysics to Interface between Geologists, Geophysicists,
Geomechanicists and Engineering’
Yearly, thousands of hydraulic fracture stages are monitored
in the oilfield. Microseismic event locations and basic
characteristics are routinely used for engineering interpretations of hydraulic
fracture
Dr. Joël Le Calvez
Joël Le Calvez graduated with a B.Sc. degree in
Physics from the University of Nice, located in Nice, France. He completed a M.Sc. degree in Geosciences
from the University of Nice-Sophia Antipolis before graduating from the
University of Paris VI with a pre-doctoral degree in Geodynamics. He has since completed a Ph.D. in Geology at
the University of Texas at Austin where he specialized in structural geology,
salt tectonics and physical modeling.
While working for the Bureau of Economic Geology at the Applied
Geodynamics Laboratory, his main interests were graben and fault linkage,
extensional tectonics, and modeling.
Since 2001, he has worked for Schlumberger as a geologist, where his
work responsibilities have led him to the challenge and task of analyzing data
associated with the field of induced microseismicity and hydraulic fracturing.
He actively participates in the development of processing, visualization, and
interpretation software currently utilized by Schlumberger in relation to
hydraulic fracture monitoring using induced microseismicity coupled to
hydraulic fracture treatment. He is currently the US Land Project Manager of
the Hydraulic Fracture Monitoring group based in Houston.
September 13th, 2010
Understanding Lateral
Heterogeneity in Shale Using LWD Measurements
Historically, complete formation evaluation in shale gas
horizontal wells have been infrequent and challenging due to operational
complications. These complications
require extra rig time, can be difficult to obtain, and provide no real-time
benefit for the well being drilled. In recent years, Logging While Drilling
(LWD) measurements have been successfully employed to evaluate formation
heterogeneity, provide assurance for geosteering in more complex reservoirs and
enhance completion design to improve well production.
Early LWD data acquisition in the laterals revealed challenges behind real-time well placement using gamma-ray; a single non azimuthal measurement that is commonly applied for correlating and steering horizontal shale gas wells. With borehole images, the ability to compute structural dips, identify fractures and potential fault along the lateral becomes possible. Information from images can be effectively used to assist in real-time decision making while confirming lateral correlation between the thin beds found in shale plays.
With LWD measurements, the detailed evaluation of the unconventional gas play can be performed using a robust shale gas interpretation that is developed and calibrated using core data. This method combines conventional triple-combo data and spectroscopy to provide a gamma-ray independent clay content while computing the total gas volume consisting of adsorbed gas and free gas. With the addition of sonic acquisition, geomechanical rock properties can be calculated and used to enhance completions design, tuned with key petrophysical information. The additional details offered by today’s technology can be applied to provide an understanding of a reservoir-production relationship with the objective to improve on future well deigns for consistent production results.
Yen Han Shim
Yen Han Shim is a petrophysicist coordinating evaluation of unconventional reservoirs using LWD formation evaluation measurements across the lateral. She joined Schlumberger in 1996 after graduating as a Petroleum Engineer from University Technology of Malaysia. She commenced began her career as a drilling engineer, joined the field as a LWD engineer, then advanced to a well placement engineer. to later advance into the Her next position was petrophysicist providing LWD technical and petrophysics support in land and offshore environments for Malaysia and China prior to her current role in the United States.
October 11th, 2010
Distinguishing Noise from LWD Gamma Ray Data
in Horizontal Wells
Other than drill rate and directional information; Gamma Ray
is often the only MWD/LWD data gathered during the drilling of a horizontal
well. While the tool and the telemetry
system are simple; there are many parts that must work together in order for
the geologist to have usable data to properly place and steer a well. While the Gamma Ray tool is simple by design;
it’s value is often misunderstood or overestimated by those that use it.
Elementary techniques of log/data evaluation are often overlooked because of trust in technology. Understanding the technology, breaking down the parts of the system and a review of available data can often help identify problem data or noise gathered during the drilling of a horizontal well.
Joe Schindler
Joe is a local geologist and has been in the industry for almost 30 years; the last 20 in the DFW area. Much of those 20 years have been spent planning, drilling, and completing horizontal wells in the Austin Chalk, Buda/Georgetown, Cotton Valley, Barnett, and Bakken formations. Joe has luckily had the good fortune to be married to the best geologist and mentor in the world throughout his career.
November 8th, 2010
The Boquillas (Eagle
Ford) Formation of
Potential Outcrop Analogs for Nonconventional
Eagle Ford Shale Reservoirs in the
Subsurface
The Eagle Ford Shale (and the laterally equivalent
Tuscaloosa Shale) of the Gulf Coast Basin has long been considered to be a
source rock for Mexico, Texas, and northern Louisiana production but is now
drawing interest as a resource play. With
industry focus on non-conventional reservoirs and advancements in multilateral
horizontal completion technology, fractured bituminous shales have become
viable exploration targets. Well known examples of shale reservoirs include
Bakken Shale (Mississippian of Williston Basin), Barnett Shale (Mississippian
of Forth Worth Basin), Woodford Shale (Late Devonian/Early Mississippian of Arkoma
Basin), and Marcellus Shale (Middle Devonian of Appalachian Basin). The Cretaceous experienced three major
Oceanic Anoxic Events, including one at the Cenomanian-Turonian boundary,
represented by the Eagle Ford, and it is not surprising that exploration
interest is now being attracted.
The current study is concerned with outcrops observed along
The transition between the lower and middle members is marked by the abrupt end of the unstable slope features and a much higher proportion of organic-rich shales to limestones. At the base of the three deepest road cuts along Highway 90, fresher rock is exposed. When freshly broken, these shales are black. They are very finely laminated on a millimeter scale, and contain planktonic foraminifera and calcispheres. Coarser laminae, ranging from millimeter to centimeter thick, consist of microfossil concentrations that are thought to be a product of winnowing by bottom currents. Inoceramids are also present in the middle member. Some of the interbedded limestones are laterally continuous while others are more nodular in appearance. The preservation of fine laminae, with little to no bioturbation, combined with the fauna present, indicate anaerobic to dysaerobic conditions with a total lack of infauna during the time of deposition. Water depth for the majority of the middle member was probably deeper than for the lower member, with sediment being deposited on the middle to lower basin slope. Nearing the top of this member there is an increase in limestone beds suggesting a decrease in water depth, consistent with the interpretation of a transgressive-regressive cycle.
The upper member consists mainly of somewhat bioturbated limestones that are much thicker than those of the other two members. Trace fossils include Chondrites, which still suggests relatively low oxygen levels. The upper member appears to lack the high organic content present in the rest of the Boquillas. This top unit represents a progressive return to shallower, better oxygenated conditions. Along with pyrite-filled burrows, an abundance of regular and irregular echinoids supports this interpretation.
Lauren Peschier
Lauren Peschier received her B.S. in Geology in 2004 and M.S. in Geology in 2006 from the University of Louisiana at Lafayette. She has 6 years of experience as a geologist in the oil and gas industry working exploration, development, and operations in the Gulf of Mexico. She worked for Marlin Energy, LLC in Lafayette, Louisiana from 2004 through 2006 as an associate geologist and is currently employed as a geologist by Newfield Exploration. At Newfield, she worked the Gulf of Mexico Shelf from 2006 to 2009 and currently works the Eagle Ford in Maverick Basin Texas.
January 10th, 2011
Eagle
Ford Shale Prospecting with 3D Seismic Data within a
Tectonic and Depositional System Framework
Galen Treadgold and Bill McLain, Weinman GeoScience
Steven Sinclair and David Nicklin, Matador Resources Company
The
Eagle Ford Shale in South Texas is one of the more exciting shale plays
in the United States at the current time. Recently published
reports of well tests describe gas well rates exceeding 17 mmcf/d and
oil well rates in excess of 1500 bopd and unconfirmed rates of 2000
bopd. Acreage lease rates continue to climb as more positive
results come from drilling within the trend. A key issue for the
exploration companies is finding where to focus acreage acquisition and
optimize drilling plans for optimal gas and oil recovery. Our
paper will first consider the geologic context of the Eagle Ford and
then look at geophysical techniques, in particular, comparing and
contrasting the value of 3D Processing seismic attributes in building a
successful exploration plan.
Conventional subsurface data, such
as wireline logs, cores and cuttings, are limited in availability to
many companies currently exploring the play. Interpretation of
these data is often ambiguous at best. As a result, thorough
understanding of the regional aspects of the play remains elusive to
many companies. It is our belief that modern seismic data and
interpretation techniques can add significantly to the database and
greatly enhance regional understanding of the play for many companies.
Newly acquired 3D datasets provide a continuous characterization of the
subsurface, which highlights drilling hazards (faults), and also offers
the potential for identifying better reservoir quality intervals
(higher TOC shale sections with greater porosity and fractures).
Extracting rock properties from the seismic should be the goal of any
processing and interpretation effort. Linking the results of well
tests to the attributes derived from the seismic will provide operators
with a far more reliable predictive capability in any shale play.
Ultimately,
the pursuit of Eagle Ford acreage and the designing of an Eagle Ford
drilling campaign is best accomplished through a comprehensive
understanding of the geologic framework coupled with a focused
interpretation of the seismic. This shale is one of the more
exciting domestic shale plays, and presents ample opportunities to make
and lose money. The smart operator will utilize all the tools
available to study the target section while recognizing the limitations
of the technology.
Galen E. Treadgold
February 14th, 2011
A Detailed Look Inside a Complex Channel Belt:
Processes, Rates, and Reservoir Architecture/Connectivity
for an 8K-Duration Mississippi River Meander Belt
with Reach-Restricted Tectonic Signature
The
Lower Mississippi River has long stood as a type model for
meandering-river deposition, and is well understood at both the
regional floodplain and individual meander-loop scales. We have
taken the next step, and produced the first detailed study of a single
and entire channel belt (30 X 100 km) in order to better understand
belt-scale architectural elements, reservoir and baffle structure,
formative processes, and depositional rates for meandering river
systems. The channel belt studied here records a complex and
long-standing (>8 ka) trunk belt from which no less than six
contemporary belts disperse downstream. The belt is also impacted
over its middle third by active tectonics of the New Madrid seismic
zone. This belt serves as a rare type model for complex meander
belts in both tectonically and non-tectonically impacted subsurface
reaches.
Meander amplitude overall is variable, producing
amalgamated and reworked lateral-accretion elements/point bars of 1 km
to 19 km amplitude with 5-6 km as typical. Channel-fill elements
constitute 40% of the belt deposits. While the more familiar
chute and neck cutoff channel fill process are common, additional
process of splay fill, avulsion fill, and re-occupation fill are also
commonly recognized. Splays are common, but generally small and
thin, except where filling tectonic and depositional lows on the
floodplain surface. Overbank fines are generally minimal within
the belt, but thick on the belt flanks. Belt architecture is
hierarchal in the middle fault-influenced 30 km, and includes three
subbelts that record tectonically initiated river straightening and
in-belt avulsion not observed elsewhere within the belt. Meander
growth rates are approximately 5m/year, tectonic response rates are on
the scale of a few centauries, tectonic recovery rates are on the scale
of one millennium, and channels require several hundred years to a few
millennia to fill depending upon process.
Detailed
mapping reveals several levels of potential reservoir and flow barrier
induced by both autocyclic processes and local tectonic
influence. Most notably, mapping reveals that a direct hit into a
Mississippi-type meander belt while drilling still has only a 3-in-5
probability of striking a full interval of reservoir sand.
Reservoir sands are also highly compartmentalized to the bar scale, but
potential exists to connect point bar reservoirs below channel belts as
these rarely fill completely with sealing mud. Likewise,
connectivity between belts has high potential if the belts are not
separated vertically by more than one quarter belt thickness.
John Holbrook, University of Texas at Arlington, holbrook@uta.edu
Current Position: PROFESSOR, DEPARTMENT OF EARTH AND ENVIRONMENTAL SCIENCES, UNIV.TEXAS AT ARLINGTON - Education: Univ. of Kentucky, BS (Geology) 85; Univ. of New Mexico MS (Geology) 88, Indiana Univ. PhD (Geology, Minor Geophysics) 92. Honors & Awards: Outstanding Teacher, UTA College of Sci. and Tech. 09. Professional Experience: Peabody Ventures Petroleum 88, Southeast Missouri St. Univ., Asst.- Prof. 92-04, Univ. of Texas at Arlington Prof. 04-pres., Guest Prof. Enugu St. Univ. (Nigeria) 99 and St Petersburg St. Univ. (Russia) 08, Straight Creek Solutions Env. & Pet. Consulting (Proprietor) 09-pres. Other Positions and Service: GCSSEPM President 10, AAPG/SEPM Annual Meeting Organizing Committee 10,08,99,&98, Assoc. Editor, Jour.Marine and Petroleum Geo..08-11; GSA Sedimentary Geology Division Chiar 09-11, SEPM Research Counselor 08-10, EDMAP panel 09-11, PRF panel 10-12, NSF SG&P panel 06-09, AAPG Academic Liaison Comm. 10-12 Missouri Board of Geologist Registration 03-04 Memberships: GSA, AGU, SEPM, AAPG, Licensed Geologist (P.G., Missouri). Research: Controls on surface processes and patterns of deposition in both modern and ancient sedimentary environments with concentration on terrestrial systems. Patterns of organization in the sedimentary record and application to environmental, resource, and global-change issues.
March 14th, 2011
Wellsite Geochemistry: New Analytical Tools Used
to Evaluate Unconventional Reservoirs to Assist Drive
Smart Completions in Vertical and Horizontal Wells
New field deployable analytical techniques like GC-Tracer, SRA, XRF, and XRD are proving to be valuable tools when drilling and completing horizontal shale wells. Experience in different shale plays throughout the US (including the Barnett, Haynesville, Marcellus and Cretaceous Shale members in the DJ Basin) have shown significant potential in predicting fluid type; delineating potential pay zones, and reservoir compartmentalization for a better placement of fracturing staging based on rock and chemical properties.
The GC-Tracer tool analyzes real-time hydrocarbon (C1 – C8, benzene, toluene) and nonhydrocarbon gases (CO2, N2) dissolved the in drilling fluid. Drill cuttings are collected and evaluated onsite using SRA, XRF, and XRD. The Source Rock Analyzer (SRA) estimates residual oil content in source rock (S1), remaining hydrocarbon generation potential (S2), thermal maturity (Tmax), total organic carbon (TOC); X-Ray Fluorescence provides elemental breakdown while X-Ray Diffraction provides clay, carbonate, and other mineral proportions. Cutting samples are normally collected every 100’ throughout the majority of the wells, while increasing sampling frequency to 10’ or 30’ samples in the zone(s) of interest for a more accurate way to monitor variability.
In unconventional reservoirs, such information can aid in the delineation of pay zones and be used to design horizontal completion and stimulation programs. Unfortunately, logging horizontal wells using downhole tools can be somewhat cumbersome and expensive; therefore, new wellsite techniques can offer a more viable alternative to real-time data gathering and reservoir characterization. This compilation of case histories demonstrates that new analytical tools for well site can provide insights into potential productive shales and identification of potential intervals within lateral sections considering an organic and inorganic geochemical analytical approach.
Diego Ortiz, Weatherford International
Diego Ortiz graduated from The University of Oklahoma with a B.Sc. in Chemistry and currently holds the position of GC-TRACER Formation Evaluation Specialist for Weatherford Surface Logging Systems.
He has helped with the introduction of the GC-Tracer tool in the North American market and now driving the new initiative to growth presence in Latin America.
Before joining Weatherford, Diego worked for Crown Geochemistry as a field chemist where he was first introduced to the worldclass Woodford and Barnett plays in 2006 by studying the gas analyzed with Mass Spectrometry. In 2008 he joined International Logging as a GC-TRACER Analyst where he learned Gas While Drilling and other industry known Gas Evaluation methods.
His main focus has been the development of gas ratio techniques exclusively for Shale evaluation using traditional and advanced gas detection equipment as well as the integration of new field-deployable analytical techniques for geochemical characterization of unconventional reservoirs.
April 11th, 2011
Production of Liquid Hydrocarbons from Organic Shales
The domestic energy industry has undergone a revolution
over the last eight years due to the production of gas from organic shale. The
quantities of gas within these reservoirs are considerable, and shale gas
accounts today for a significant fraction of U.S. gas production. This increase
in gas production has led to a depressed price for gas when compared to the
price of oil. Our industry has responded by focusing significant effort in
producing oil from these same organic shale reservoirs.
Rick Lewis
Rick Lewis is the Shale Petrophysics Technical Manager for Schlumberger Oilfield Services in Oklahoma City. Rick was a developer of the gas shale evaluation workflow that was initially fielded eight years ago and has been applied to well more than 1000 wells in North America. In his current position, Rick manages a group responsible for the continual improvement for this workflow, and for its introduction and application to the international market. He is also the interface to the Schlumberger research and engineering groups for the development of evaluation technologies for organic shales. Prior to this assignment, Rick was responsible for wireline interpretation development for the central and eastern United States. Rick has also worked for Shell Oil and the U.S. Geological Survey. He received a BS degree from UCLA and MS and PhD degrees from Cal Tech, all in geology.
May 9th, 2011
Scholarship Recipient Presentations
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Garrett R. Felda - Baylor
Developing
a 3-dimensional sequence stratigraphic model for the late Triassic
(Norian) Owl Rock Member exposed at Petrified Forest National Park,
Arizona: A reconstruction of paleodepositional environments and
paleoclimatic conditions.
The
In addition to detailed sequence stratigraphic
analysis, this investigation will also assess paleoclimatic conditions
during the time interval preceding the end-Triassic biotic
crisis. Climatic factors to be considered include atmospheric
carbon dioxide concentrations (using stable carbon isotope analysis of
pedogenic carbonate), and mean annual temperatures (using stable oxygen
isotope analysis of both pedogenic and lacustrine carbonate).
Variations in clay mineralogy and abundance will also be measured using
X-Ray Diffractometry to help constrain precipitation amounts and infer
soil moisture conditions.
Finished products include a series of measured sections accompanied by high-resolution digital photopan images depicting fluvial aggradation cycles (FAC’s), as well as, inferred fluvial architectural elements across the southernmost extent of Chinde Mesa. GPS coordinates will be used to precisely locate and orient sections and photopans to a digitized basemap. Alluvial clastic and lacustrine carbonate samples collected in the field will be evaluated using petrographic microscopy and reported in terms of facies specific controls on reservoir quality as indicated by the presence or absence of porous textures and fabrics related to environmental modes of deposition. Calculated atmospheric carbon dioxide concentrations and mean annual temperatures will be presented comparatively in graphic form to identify temporal trends and illustrate potential relationships.
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Clark H. Osterlund - TCU
Overview of the “Atoka Shale” formation in northern
The
Clark Osterlund
Having been born in west Texas, I was fortunate to learn the importance of geology at a young age. Numerous scouting trips to the Guadalupe Mountains initially stimulated my interest in geology. During my undergrad studies, I was most drawn to soft rocks and sequence stratigraphy.
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Krystin Robinson - UTA
Chemostratigraphy of the Pearsall Formation, Lower Cretaceous, Maverick Basin, South Texas
The
lower Cretaceous Pearsall Formation of the