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In this Issue
G e o l o g i c a l
DECEMBER 1997
Volume 40 Contents
S o c i e t y
VOLUME 40
1997 was a blast!
NUMBER 4
!
Will 1998 be better?
Also in this issue:
Petroleum Systems in Offshore Brazil Featured at the December 15
HGS Dinner and International Explorationists Joint Meeting.
Feature Articles:
Yowlumne Field Study, San Joaquin Basin, California
The Tuscaloosa Marine Shale:
7 Billion Barrel Poten,tial in the Louisiann/Mississippi Onshore.
HGS 1998 Field Trips Planraed to the Grand Canyon and Jackson Hole, Wyoming
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TEXAS
In this Issue
Volume 40 Contents
CRUDE
AN INDEPENDENT OIL & GAS COMPANY SINCE 1941
TEXAS CRUDE BUILDING
2803 Buffalo Speedway, Houston, Texas 77098
P. 0. Box 56586, Houston, Texas 77256-6586
Telephone: 713-599-9900
Peter J. Fluor, President & C.E. 0 .
K. C. Weiner, Vice-president
Doug O'Brien, Exploration Manager
A1 Curry, Operations Manager
Mike Huhnke, Drilling/Production Manager
We moved our lab
Guhn Road.
Please call on us for:
Routine Core Analysis - Full Diameter and Plug
Sidewall Core Analysis - Rotary and Percussion
Unconsolidated Core Analysis
NMR Evaluation
Advanced Petrophysical Rock Properties
Reservoir Flow Studies
Formation Damage Assessment
Completion Recommendations
Reservoir Description
Reservoir Geology and Petrographic Services
Reservoir Fluid Analyses - PVT and Compositional
Organic Geochemistry
Environmental and Geotechnical Analyses
Grow
\
Hempstead Hwy
Q 1997 Core Laboratories. Ail rights reserved
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0 I 0 g
DECEMBER
1997
HOUSIDN GEOLOGICALSOCIETY
7457 Harwin, Suite 301
Houston,TX 77036-2190
Office Hours: 8 a.m.-5 p.m.
Phone 713-785-6402
Fax 713-785-0553
In this Issue
.
I
c a I
s
Volume 40 Contents
.
0 C I e
VOLUME 40
t Y
NUMBER 4
Table of Contents
Columns
Letter from the President. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4
Letter from the Editor. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6
Meetings
HGS Web Page
http://www.hgs.org
Jobs Hotline is on Web Page or at
713-785-9729
Environmental and Engineering Meeting, December 10 . . . . . . . . . . . . . . . . 9
"Landfill Siting Criteria with Emphasis on Karst Hydrogeology"
by Diane Yeager, Dames and Moore.
Joint HGS DinnerlInternational Explorationists Meeting, December 15 . . . 10
"Geologic Evolution of Passive Margins, South Atlantic"
by Vitor Abreu, Rice University.
Feature Articles
Reservation Codes
Use these codes to make voice mail
meeting reservations
Dinner Meeting (5-0-1)
Environmental and Engineering (5-0-2)
International Explorationists (5-0-3)
North American Explorationists (5-0-4)
Luncheon Meeting (5-0-5)
Emerging Technology (5-0-6)
"Characterization of a Turbidite Reservoir, Yowlumne Field, California". . 12
by Michael S. Clark, ARCa Western Energy.
"Unconventional 7 Billion Barrel Oil Resource in the Tuscaloosa
Marine Shale" . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16
by Chacko J. John, Basin Research Institute, Louisiana.
"PC Workstation Technology and Its Impact on the
Independent/Consultant"...
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37
by Deborah Sacrey, DKS Exploration.
Committee News
HGS Technical Symposium, March 31, 1998. . . . . . . . . . . . . . . . . . . . . . . .8
People on the Move. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 29
Computer Applications Committee: New Web Site Forum. . . . . . . . . . . . . 30
Library Committee Report. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30
Field Trips Planned to the Grand Canyon and Jackson Hole, Wyoming. . . 32
North Harris College December Course Schedule. . . . . . . . . . . . . . . . . .. 43
Legislative Update. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 44
On the Cover: Discovery wellflaring gas, offshoreAfrica, courtesy of anonymous source.
The HoustonoGeological Society Bulletin is published monthly except for July and August by the Houston
Geological Society, 7457 Harwin, Suite 301, Houston TX 77036-2190. Subscription to this publication is included in the membership dues ($20.00 annually). Subscription price for non-members within the contiguous U.S. is
$25.00 per year. For those outside. the contiguous U.S., the subscription price is $46.00 per year. Single-copy
price is $3.00. Periodicals postage paid in Houston, Texas.
POSTMASTER: Send address changes to Houston Geological Society Bulletin, 7457 Harwin, Suite 301,
Houston TX 77036-2190.
December 1997
Houston Geological Society Bulletin
1
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In this Issue
Volume 40 Contents
PRESIDENT
Jeffrey Lund . . . . . . . . . . . . . . . . Ashland Exploration ......281-531-2953....................rockheadl @aol.com
PRESIDENT-ELECT
Sandi Barber . . . . . . . . . . . . . . . . GeoQuest . . . . . . . . . . . .713-723-1480 . . . . . . . . . [email protected]
Calvert Scholaships . . . . . Dan Smith. . . . . . . . . . . .281-558-8080
Undergrad. Scholarships . Hugh Hardy. . . . . . . . . . .713-729-9208
21st Century Symposium. John Adarnick . . . . . . . . . 7 13-754-6714 . . . . . . . . . [email protected]
Guest Night. . . . . . . . . . . Greg Gregson . . . . . . . . . 7 13-222-9291
VICE PRESIDENT
Charles Sternbach. . . . . . . . . . . . Jordan 0 & G . . . . . . . . .281-679-7333 . . . . . . . . . [email protected]
Emerging Technology . . . Shawn Porche . . . . . . . . .281-343-7500 . . . . . . . . [email protected]
International Expl. . . . . . . Martin Cassidy . . . . . . . . 7 13-616-5853 . . . . . . . . . [email protected]
North American Expl. . . . Steve Levine . . . . . . . . . .28 1-293-1862 . . . . . . . . . [email protected]
Environmental Geol. . . . . Craig Dingler . . . . . . . . . 28 1-930-2394 . . . . . . . . . [email protected]
Poster Sessions . . . . . . . . Gene Colgan . . . . . . . . . . 28 1-579-3398 . . . . . . . . . [email protected]
Hotel Arrangements. . . . . Lee Boatner . . . . . . . . . . .713-650-0008 . . . . . . . . . fax:713-650-6112, [email protected]
TREASURER
Deborah Sacrey . . . . . . . . . . . . .DKS Exploration. . . . . .281-493-5059 . . . . . . . . [email protected]
Finance Committee . . . . . Steve Brachrnan . . . . . . .713-297-5088 . . . . . . . . . [email protected]
TREASURER-ELECT
Michael Deming . . . . . . . . . . . . . Amoco . . . . . . . . . . . . . .281-366-4458 . . . . . . . . [email protected]
Publication Sales. . . . . . . Tom Mather. . . . . . . . . . .281-556-9539 . . . . . . . . .fax: 281-556-9543
SECRETARY
Dan Bonnet . . . . . . . . . . . . . . . . . Houston Energy. . . . . . .713-650-8008 . . . . . . . . . [email protected]
Historical Committee. . . . Kes Barcas . . . . . . . . . . .28 1-530-7950 . . . . . . . . . [email protected]
Membership . . . . . . . . . . Paul Babcock . . . . . . . . .28 1-878-3810
Remembrances . . . . . . . . Bill Robbins . . . . . . . . . . 713-986-6767 . . . . . . . . . [email protected]
EDITOR
Linda R. Sternbach . . . . . . . . . . . Exploration Consultant. 713-768-0803 . . . . . . . . [email protected]
EDITOR-ELECT
Craig Dingler. . . . . . . . . . . . . . . . Laidlaw Environmental. 281-930-2394
. . . . . . . . . [email protected]
EXECUTIVE COMMITTEEMEN
Paul Hoffman . . . . . . . . . . . . . . . Duncan Energy . . . . . . .713-840-8755 . . . . . . . . . [email protected]
Advertising . . . . . . . . . . . Annette Mather. . . . . . . .281-556-9539 . . . . . . . . .fax: 281-556-9543
Continuing Education . . . Elizabeth Watkins . . . . . . 7 13-972-6718 . . . . . . . . . 1iz.watkins@ waii.com
Directory. . . . . . . . . . . . . Greg Gregson . . . . . . . . . 7 13-222-9291
Exhibits. . . . . . . . . . . . . . Jerry Cooley . . . . . . . . . .713-665-8432
Craig Moore . . . . . . . . . . . . . . . . Craig Moore & Assoc. . .713-782-0881 . . . . . . . . . [email protected]
Awards . . . . . . . . . . . . . . Dean Grafton. . . . . . . . . .281-497-5983
Entertainment . . . . . . . . . Bill Hill. . . . . . . . . . . . . . 7 13-584-6107
Field Trips. . . . . . . . . . . . Bill Baehr . . . . . . . . . . . . 7 13-771-4812 . . . . . . . . . [email protected]
Bass Tournament. . . . . . . Greg Doll . . . . . . . . . . . .28 1-579-9695 [email protected]
Golf Tournament. . . . . . . Fred Jenson . . . . . . . . . . .713-850-8255
Shrimp Peel. . . . . . . . . . . Matt Bognar . . . . . . . . . . 7 13-512-8510 . . . . . . . . [email protected]
Skeet Shoot. . . . . . . . . . .Tom McCarroll ....... .713-507-5867
Computer Applications . . Bill Osten . . . . . . . . . . . .7 13-669-2146 . . . . . . . . . [email protected]
HGS Web Page . . . . . . . . Dave Crane . . . . . . . . . . .28 1-531-5800 . . . . . . . . . [email protected]
Personnel Placement . . . . Art Leibold . . . . . . . . . . . 28 1-366-7063 . . . . . . . . . [email protected]
Paul Britt . . . . . . . . . . . . . . . . . . . Texplore . . . . . . . . . . . . .281-341-1800 . . . . . . . . . [email protected]
Explorer Scouts. . . . . . . . Gretchen Hopper. . . . . . .281-398-0108
Government Affairs. . . . . Jim Bennett . . . . . . . . . . . 7 13-650-1378
Public Relations . . . . . . . Robert Pledger. . . . . . . . . 281-558-8585
Mus. Nat. Science . : . . . . Clint Moore. . . . . . . . . . .281-874-8730 . . . . . . . . . [email protected]
State Registration . . . . . . Dave Rensink ......... 28 1-496-0067
Bob West . . . . . . . . . . . . . . . . . . . Kerr McGee. . . . . . . . . .281-618-6286 . . . . . . . . . [email protected]
Academic Liaison . . . . . . Dr. Bill Dupre . . . . . . . . .713-743-3425 . . . . . . . . . [email protected]
Hou. Geol. Auxiliary. . . . Joy Payne . . . . . . . . . . . .713-622-5435
Log and Book Library. . . Evelyn Moody. . . . . . . . .713-789-5999
New Publications. . . . . . . John Turmelle . . . . . . . . . 7 13-583-2328
2
December 1997
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In this Issue
Volume 40 Contents
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December 1997
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In this Issue
Volume 40 Contents
Letter from the President
by Jeff Lund
Geology, Public Policy and Fossil Fuels
I
believe we are about to experience a national, possibly worldwide, debate on the
.
constraint of fossil fuel use, a topic of great
significance to many of our members.
HGS is not a political organization. Unfortunately, I am afraid this particular issue
promises to become very political. As geologists we understand certain natural processes because we are students of the earth. It may be wise for us to share our insight.
Geologic education and work experience instill appreciation for topics such as the
enormous time span represented in earth's history, the magnitude of natural processes,
climate change, glaciation, volcanic eruptions, sedimentation and erosion rates. I am
always struck by the naivete of people who build houses on flood plains and then ask the Corps of Engineers to build
dams when their houses are flooded! I marveled over a CNN report showing the citizens of the Caribbean island of
Montserrat praying to stop the volcanic eruption (good luck folks!).
My current concern is that the debate over "global warming" is becoming politicized. Mean global temperature
graphs show a clear warming trend over the past few years. But graphs going back decades, centuries or millennia
suggest there are statistical variations on a small scale that are merely "noise" in the long term-trend. Do we know
the stock market's trend by plotting the Dow Jones Average for a week or a month?
Most of us have experience in avoiding attaching too much emphasis to small-scale patterns on seismic traces or well
logs letting them obscure the larger scale correlation we see when we "stand back" and look at the bigger picture.
Reconciling data from nature that seems inconsistent or contradictory is a special skill most geologists have developed. Ask any petroleum engineer!
What triggered my concern? It was a CNN report about President Clinton reading the book The Heat is On by Ross
Gelbspan. Gelbspan is not a geologist or a meteorologist or a climatologist, but a journalist. A quick check inside the
book's dust jacket reveals this summary of the contents:
"exposes the deliberate campaign by oil and coal interests teamed with conservative politicians, to
confuse the public about global warming and the disruptive weather patterns that mark its initial stages. "
I wonder if either the author or his readers would be shocked to learn there was a mile of ice covering Chicago 20,000
years ago? Maybe carbon dioxide is increasing because of human activity and maybe that can lead to long-term climate change, but we'd better base policy decisions on scientific investigation and demand informed debate on the
part of our political leaders.
What can we do as geologists to share our scientific insights about the history of the earth? How do we help nongeologists make judgments on political policy issues that factor in concepts of the geologic time scale and
geologic processes with which we are uniquely familiar?
1. Communicate: Be proactive in conversations, write to your elected officials, write to publications when you
see poorly reasoned or pseudo-scientific statements.
2. Educate: Support the national program of science fairs in our school systems. Contribute scholarship money,
be a judge, encourage students to participate. A real attempt at hypothesis testing by experiment is a very
significant educational experience.
3. Participate: Support the Houston Museum of Natural Science. Become a certified volunteer geologist!
Volunteer to visit schools as a geologist through the HGS Academic Liaison Committee.
Remember-geology,
(
it:s our prJjession, not just our jobs.
Committees ReDortina to the HGS President
Ballot Committee. . . . . . . .Dean Grafton. . . . . .713-497-5983 Fund Development. . . . . . . Bob Ardell ... .713-260-7402
Nominations Committee. .Jim Ragsdale. . . . . .713-681-5873 Workstation Training. . . . Jeff Lund
.713-531-2953
4
December 1997
I
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Volume 40 Contents
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In this Issue
Volume 40 Contents
The Christmas Tree that Roared
by Linda R. Sternbach
This month's cover photo of a gas flare on a
nameless offshore rig is an apt symbol for the end
of 1997. This past year was a turnaround event
for geologists and geophysicists in Houston,
marked by an upswing in demand for our services and the resulting drilling success that a
more stable employment environment brings.
For geologists who work primarily in the office
environment, actually being in the presence of
flowing hydrocarbons is a memorable experience. Field trips to the district office to see the
"Christmas trees" can be very exciting: a chance
Editor Linda Sternbach on site at a "Christmas tree" in Hidalgo
to see in person wells previously known only as
County, Texas (in 1989), holding the well's log.
drafted locations on a base map. On one excursion in 1989 to the district office in the not-very-populated town ofPenitas, Texas, near the Mexican border, I had a
memorable meeting with the top producing well in Tabasco Field: the Carter #2.
The Carter #2 has the dual distinction of being both the first and best well in a deep Vicksburg horizon called the "Z"
sands in the center of the field. I knew it was making 10-12 million cubic feet a day, but I was unprepared for what
that actually sounds like when you stand next to the well. I remember driving up to the well facilities pad in the middle of a plowed farmer's field under the bright South Texas sun on one of those hot fall days that puts the color into
the oranges grown down in the "valley." The rest of the area was quiet, but the wellhead sounded like a screaming
demon. The sound got much louder the closer you got to the Christmas tree. Twelve million cubic feet a day rushing through the valves sounded like the well was saying, "ARRRHHHH," and not in a very friendly way. Plus the
painted silver pipes on the well facilities were HOT, so hot you couldn't stand close to the pipes coming out of the
ground and you certainly didn't want to touch the metal.
More recently, my occasional geophysical advisor and fellow HGS member Americo Korompai showed me a photo
he took of his Coastal Oil and Gas Wilcox discovery flaring gas from a zone at 16,000 ft. He happened to be driving
by the well location coming back from a vacation when he passed by Hinze's Barbecue on Highway 59 in Wharton
County, certainly a well-known landmark in the area. But Hinze's wasn't heating
up the local countryside as loudly as Americo's Zeidman Trust #2, which was
emitting a deafening roar during a flare test of 21.9 million cubic feet per day up
into the big skies of Texas. "There was a siren going off at the well," reported
Americo. "Maybe it had to do with an H2S warning. But what I remember was
the sound of the flare. It sounded like the turbine engines of a jet. Once you see
and hear something like that, you never forget it."
The discovery of a deep petroleum reservoirs deserves more than a passing measure of respect for both its force and its potential energy. It makes you realize that
releasing reserves from the ground is like liberating a creature from Hades and is
not to be trifled with.
The Coastal Zeidman Trust #2 flaring
21 MMcf/D AOF off Highway 59 in Wharton County.
6
December 1997
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Volume 40 Contents
Letter to the Editor
Fred Marshall wrote to give his feedback on my
October editorial column.
Dear Linda,
I enjoyed your comments about "mentoring" in your
"Leaerfrom the Editor." You do have some good points
for me to ponder. However, it has been my recent experience that th: young thirty and forty year olds like to
hear what us sixty year olds have to say about current
activities in the "oil patch." Too bad there are not any
twenty year olds around to ask questions. I wonder
wbere they are? You do good work. Please keep it up. I
leave you with the old adage, 'Without a knowledge of
the paat, you are damned to make the same mistakes of
the past" I'm seeing this happen mote and more in our
industry. The ''bean counters" did our industry (and
other inc&stries) a great disservice.
Sincerely Yours,
Fred H. Marshall, consulting petroleum geologist,
Qler, TX
[email protected]
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In this Issue
Volume 40 Contents
HGS 75th Anniversary Year
Technical Symposium
MARCH31,1998
"Countdown to the 21st Century"
by John Adamick, chairman
The Houston Geological Society is celebrating its 75th anniversary this year. As part of that celebration, the HGS
will sponsor a one-day technical symposium on March 31, 1998, at the Marriott Galleria Hotel Exhibition
Center. The theme for the program is "Countdown to the 21st Century."
The symposium is intended to focus on where HGS members will be heading for the next 75
years,rather than dwelling on the past. To that extent, three forward-looking session topics
have been developed. The first session is "The Geology of Deepwater Areas (Worldwide)."
This all-day session will stress regional geology rather than case studies.
The second session is "The Macroeconomics of Oil and Gas." This half-day program will
forecast supply and demand for hydrocarbons well into the 21st century and discuss the
many factors expected to influence supply and demand. The other half-day session is
"Emerging Technology," which will cover expected new developments in geological, geophysical and engineering technology. Approximately 40 papers will be presented at the symposium.
Join us for the technical symposium! Attendance will be limited to 600. The registration fee is only $50.00,
which includes lunch. To register, fill out the form below and send it with a check to the HGS office, attention:
Technical Symposium Coordinator.
For more information about the HGS technical symposium, contact John Adamick at 713-754-6714 or e-mail at
[email protected].
---------------------------------------------------------------------------------------------------------------------------------------
-
HGS TECHNICAL SYMPOSIUM REGISTRATION FORM
March 31, 1998 - Marciot Galleria Hotel- 8:00 a.m. to 5:00 p.m.
5150 Westheimer Road
Name
Company
Address
Phone
Fax
Please return this form along with a check for $50 (made out to HGS-Technical Symposium) to:
Houston Geological Society, 7457 Harwin, Suite 301, Houston, TX, 77036-2190,
attn: Technical Symposium Coordinator.
8
December 1997
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Landfill Siting Criteria with Emphasis on Karst Hydrogeology
by Allan Biddlecomb,RG.,
Diane Yeagel; RG.,* and
Laurie Irwin
Karst landscapes result from the subsurface solution of rock and are usually
characterized by sinkholes, caverns, and
drainage of surface water to the subsurface. Karst terrane covers an estimated 15
percent of the earth's land surface and is
usually associated with carbonate rock.
Once these surfaces become buried, they
may comprise very prolific aquifers. Karst
may continue to develop (in areas where
the groundwater table is near the surface
and unconfined) after the rock has been
buried and becomes the matrix for the
aquifer. An example of this type of aquifer
is the Floridan Aquifer located throughout
most of central a d north-central Flkda.
Where the karst aquifer is near surface or
relatively unprotected by thin soils,
impacts to the aquifer are likely. In areas
where the limestone is buried beneath a
thick sequence of clay (example:
Hawthorn Formation, Florida), the
groundwater is confined and the aquifer is
generally perceived as protected from surface influences. However, the paleo-karst
development within the limestone may
breach the clay unit and fill with permeable sediments such as sands and silts.
These breaches are also avenues for contamination to enter the aquifers and are not
easily mapped from surface features.
Other karst features, such as fractures and
conduits, do not have predictable patterns,
are difficult to trace, and enhance the
aquifer's porosity (secondary porosity).
In many areas of the country, landfills
have been built over these h s t aquifers.
Where the landfills have been constructed
prior to establishing landfill siting criteria,
drinking water supplies (recovered from
the karst aquifers) have most likely been
impacted. For example, several landfills
i
December 1997
in north Florida have impacted the
Floridan Aquifer and numerous potable
drinking water wells. Contaminants
impacting the karst aquifer tend to
migrate rapidly in both the lateral and vertical directions. The impacted area of the
aquifer makes active remediation impractical. Once these aquifers become impacted, alternative dnnking water supplies
need to be established for the population
and the aquifer monitored for contaminant
migration.
For these reasons, establishing practical
landfill siting criteria is critical. In karst
hydrogeologic environments geologic
investigations should provide the necessary detail to determine if paleo-karst has
breached clay units and other features that
cannot easily be established from surface
mapping. Other siting features are inherent& related to the hydrogeologic environment and should be considered prior
to conceptual development of the landfill
design.
BIOGRAPHICAL
SKETCHES
Diane Yeager has worked in the environmental arena for approximately 10 years
focusing on hydrogeology. Ms. Yeager
obtained her B.S. in geology at Ball State
University in Muncie, Indiana. She studied civil engineering at the University of
Florida and has her professional registration in Florida. She has worked as both a
consultant and government contractor to
NASA in California and Florida. As a
government contractor at the Kennedy
Space Center, Ms. Yeager oversaw the
hydrogeology compliance issues affiliated
with the Space Center's landfill closure
and construction. Her work with Allan
Biddlecomb, P.G., of Jones Edmunds &
Associates, Inc. included landfill siting
investigations in north Florida that are the
basis of this paper. Ms. Yeager is currently with Dames & Moore in Houston,
Texas, working on a variety of environmental projects.
.
Laurie Irwin is the manager of the
Geosciences Unit at Dames & Moore
Houston, Texas. Ms. Irwin has worked in
the environmental field for 15 years. She
has a wide variety of experience with solid
waste facilities throughout the U.S. with
emphasis on hazardous waste landfills.
AUan Biddlecomb has an M.S. degree in
hydrogeology from the University of
Florida (Gainesville). He has worked as a
consultant for JEA in Gainesville for
approximately 10 years. His current work
involves a variety of hydrogeologic investigations for landfill sitings, closures,
and contamination investigations. Mr.
Biddlecomb has his professional registration in the States of Florida and Georgia.
* Denotes speaker other than senior authol:
Chairman's note: We would like to
thank Faizur R. Khan, RE.,
Project Manager for Laidlaw
Environmental Services Columbia
Engineering Department (Houston),
for substituting at the last moment
for October's speakes His talk was
entitled "Cut-OfSWall System for
Subsurface Liquid Containment."
reservation code for this meeting is 5-0-2.
9
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Volume 40 Contents
Geologic Evolution Of Conjugate Volcanic Passive Margins:
Influence on the Petroleum Systems of the South Atlantic
by Ktor Abreu, Peter R. Vail,
Albert Bully; Rice University, and
Edith Wilson, Amoco
Tivo contrasting types of passive margins
are 1) thick-crusted volcanic margins and
2) thin-crusted nonvolcanic margins.
Examples of conjugate nonvolcanic margins in the South Atlantic Ocean are the
Santos and Campos basins along the
Brazilian margin and Kwanza and offshore Lower Congo basins along the
African margin (Fig. 1).
In these basins, the ocean-continent
transition is marked by crustal thinning
caused by to extensional deformation preceding the continental breakup. During
extension, normal synthetic faulting generated half-graben systems in Campos
Basin and offshore Lower Congo and
Kwanza basins during the Neocornian
(Fig. 2), with deposition of thick syn-rift
fluvio-lacustrine deposits (Syn-Rift I). A
second phase of rifting, developed during
the Barremian (Syn-Rift 11), is marked by
thermal subsidence and minor extension
(Fig. 2). The Syn-Rift I1 sediments are
referred to as the Lagoa Feia Formation in
the Campos Basin (Brazil) and Sag phase
(e.g., Henri et al., 1995) or Pre-Salt
Wedge (e.g., Wilson et al., in press) along
the African margin and are characterized
by transitional sediments with increasing
marine influence in the upper portion
(e.g., Rodrigues and Takaki, 1988; SilvaTelles, 1996; Wilson et al., 1997). The rift
deposits are the major source of hydrocarbons in the South Atlantic. After breakup,
evaporites were deposited during the early
drift phase. Salt movement during
Cretaceous and Cenozoic generated salt
pillows and domes, deforming the sediments deposited during the drift phase.
Volcanic passive margins are a major type
of large igneous provinces, characterized
by seaward-dipping reflectors (SDRS),
normally associated with subaerially
emplaced basalt flows and intercalated at
least in part with continental sediments. In
the South Atlantic, the volcanics extend
laterally for hundreds of kilometers and
can reach a thickness of about 15 kilome-
Rlo (irando R b r
nUnont.1 Flood Ba8alb
ters. A number of questions remain concerning their formation. These include the
influence of hotspots, the timing of volcanic emplacement with respect to continental breakup, the nature of the crust
associated with the volcanics, and the
symmetry of the volcanics with respect to
the breakup axis.
syn-~ift
II
Barnmien
syn-~ift
I
Nmcomian
F w 2 Schematic dip se& from K w m
Basin shaving the two Lower Cmkzceousphasesof
n@g.
The Paran-Etendeka flood basalts and the
SDRS of the Pelotas and Walvis basins
(Fig. 1) are the result of the rifting and
subsequent breakup of the South
American and African plates under an initial influence of the Tristan da Cunha
hotspot. The SDRS wedges were probably emplaced after continental breakup at
least partially over an extended continental crust. The Pelotas and Walvis SDRS
wedges are part of two major SDRS
provinces in the South Atlantic: SantosSan Jorge (South America) and WalvisOrange (Africa) provinces (Fig. 1).
These provinces form a broad and symmetrical volcanic complex, extending
over more than 3,000 km linearly in the
South Atlantic. It is proposed that these
SDRS provinces were emplaced as a subaerial oceanic ridge, representing the
initial stage of formation of the oceanic
crust in most passive margins.
Figure 1 : Present configuration of the South Atlantic showing the basins discussed in this study,
the thick volcanic ridges of the Rio Grande Rise and Walvis Ridge, and the Mid-Atlantic Ridge.
The subsidence in the Pelotas and Walvis
basins started in the continentauinitial
oceanic crust transition. The oceanic crust
December 1997
L
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---,
,.,,,,,,
/
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In this Issue
and shallow platform
in both margins since
the Barremian, creating a barrier between
the South Atlantic
and the Southern
Ocean during the
early Aptian.
SOUTH AMERICA
N
,.,
Search
~
.
,
~
During the Barremian, while continental
breakup started in
Pelotas and Walvis
basins with the emplacement of a subaerial mid-oceanic
AFRICA
ridge, the second
phase of rifting (SynRift II or Pre-Salt
Wedge) dominated.
the northern basins
of
the South Atlantic.
200 km
-=:J
Geochemical
and
paleontological data
Figure 3: Paleogeographic reconstructionfor the lowermost Aptian
from the Brazilian
showing the distribution of volcanics and salt deposits in the South
margin (Rodrigues
Atlantic. SDRS formed a shallow basement in the early Aptian,
and Takaki, 1987;
restricting a wide connection to the ocean for the basins to the North
and allowing the deposition of salt in the South Atlantic.
Silva-Telles, 1996)
and
observations
kept close to sea level or in shallow water
from Angola (Burwood et aI., 1992;
depths almost until the Turonian, at least
Wilson et aI., in press) suggest an increase
in the northern portion of the Pelotas and
of marine influence toward the top of the
Walvis basins. The subsidence close to the
section in a time that precedes continental
continental crust generated a narrow seabreakup and oceanic crust formation in
the Campos and Kwanza basins. One
way parallel to the coast in both margins.
The initial oceanic crust formed a broad
explanation for the presence of marine
BIOGRAPHICAL
SKETCH
Vitor
Dos Santos Abreu
Vitor Abreu received
his B.S. (1984) and
M.S. (1989) at the
Federal University of
Rio Grande do SuI in
Brazil. Abreu has
worked for Petrobras
since 1987 and was previously the manager of biostratigraphy and paleoecology.
Currently, Abreu is at Rice University
studying for a Ph.D. on the topic
"Geologic Evolution in Conjugate Volcanic Passive Margins: Pelotas Basin,
Brazil, and offshore Namibia, Africa."
His research interests include sequence
stratigraphy in passive margins and stable
isotope stratigraphy.
strata in the rift section of, Campos and
Kwanza basins is the fast subsidence rate
during the Syn-Rift II combined with
marine invasions through the seaways in
the Pelotas and Walvis basins during periods of high sea level in the Barremian.
Marine waters could invade the northern
basins of the South Atlantic during the
sea-level high in the Barremian, transgressing over transitional sediments and
infilling depressions formed by the
second phase of rifting, allowing restricted deposition of marine evaporites and
carbonates.
Limited circulation occurred along the seaways and the sides of the shallow oceanic
ridge since the Barremian in the Pelotas
and Walvis basins. After continental
breakup and oceanic crust emplacement in
the Campos and Kwanza basins, periods of
low sea level during the early Aptian would
practically have isolated the South Atlantic
from the Southern Ocean, allowing seawater evaporation and salt precipitation
in a broad area along the South Atlantic
continental margins (Fig. 3).
"South Atlantic Sag Basins: New
Petroleum System Components"
By Steve Henry, Geoleam and
Webster Mohrak, Marcel Mello, Petrobras
References
Burwood, R., Leplat, P., Mycke, B., and
Paulet, J., 1992, Rifted margin source
rock deposition: a carbon isotope and
biomarker study of a West African
Lower Cretaceous "lacustrine" section,
Organic Geochemistry, v. 19, p. 41-52.
Silva-Telles, A. c., Jr., 1996, Marine ingression events of Jiquia age (early Aptian)
in the Afro-American rift system from
the viewpoint of tectono-eustasy,
Congresso Brasileiro de Geologia, 39,
Bahia, Anais, p. 360-363.
Henri, S. G., Brumbaugh, w., and
Cameron, N., 1995, Pre-salt source rock
development on Brazil's conjugate margin: West African example, 1st Latin
American Geophysical Conference, Abs.
Wilson, E., Abreu, V. S., Asley, M. P.
Brandao, M., and Telles, A. S., in press,
Lower Cretaceous stratigraphy and
source rock distribution in the South
Rodrigues, R., and Takaki, T., 1987,0
Cretaceo Inferior nas bacias sedimentares
Atlantic: Comparison of Angola and
southern Brazil, South Atlantic Source
Rocks, AAPG/SBG Meeting,
Rio de Janeiro.
da costa sudeste do Brasil: analise isotopica e suas implicacoes ambientais. Revista
Brasileira de Geociencias, v. 17, n. 2, p.
177-179.
December 1997
Volume 40 Contents
11
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Volume 40 Contents
Field Study Article
Characterization and Exploitation of the Distal Margin of a Layered, Low-Permeability
Thrbidite Reservoir, Yowlumne Field, San Joaquin Basin, California
by Michael S. Clark, John D. Melvin,
Rick K. Prather, and Anthony W Marino,
ARCa Western Energy
James R. Boles and Douglas P. Imperato,
University of California, Santa Barbara
ABSTRACT
Yowlumne is a giant oil field in the San
Joaquin basin, California that has produced over 100 MMBO from the Stevens
sandstone, a clastic facies of the Miocene
Monterey Shale. Most Yowlumneproduction is from the Yowlumne sandstone, a
fan-shaped, layered, prograding Stevens
turbidite complex deposited in a slopebasin setting. Well log, seismic, and pressure data indicate seven depositional
lobes with left-stepping and basinwardstepping prograding geometries.
Log-derived petrophysical data, constrained by core analyses, indicate trends
in reservoir quality. Concentration of
channel and lobe facies along the fan axis
results in average net/gross sandstone
ratios of 80%, porosity (0) of 16%, and
liquid permeability (Kliquid)of 10-20 md.
By contrast, more abundant levee and distal margin facies along the east (righthand) side result in shale-bounded reservoir layers with higher clay contents, and
lower net/gross (65%), 0 (12%), and
Kliquid(2 md). Although a waterflood will
enable recovery of 45% of the original oil
in place along the fan axis, reservoir simulation indicates 3 MMBO trapped at the
fan margins will be abandoned with the
current well distribution. Economic
recovery of this bypassed oil will require
highly deviated to horizontal wells with
multiple hydraulic fracture stimulations to
provide connectivity between the reservoir layers.
Introduction
Turbidite sandstones deposited in slopebasin settings contain a significantportion
of the petroleum reserves of the United
States (Weimerand Link, 1991).Although
12
these sandstones represent deposition in
a wide spectrum of sedimentary environments, most are characterized as either
submarine fans or fan-shaped turbidite
complexes.
Many turbidite reservoirs are located in
mature oil fields characterized by declining production. In several, reservoir quality, measured as increasing porosity and
permeability, improves with increasing
sand thickness. Because fans thicken in the
middle, production generally increases
toward the depositional axes. Consequently, recoverable oil is more likely to
be uneconomic along fan margins owing
to decreasing reservoir thickness and quality. Also, pockets of bypassed oil, which
represent parts of the reservoir not swept
by waterflooding, are more likely to exist
Economic recovery of bypassed oil trapped
along fan marginsrequires a detailedunderstanding of the reservoir in order to design
a cost-effective exploitation strategy. This
paper presents an analysis of prolific
Stevens sandstones (Upper Miocene) at
Yowlumne field, San Joaquin basin,
California in which geologic modeling,
reservoir characterization,and flow simulation are used to locate highly deviated to
horizontal wells along a thinning fan
margin, and to design multiple hydraulic
fracture stimulations that maximize
production rates by improving the connectivity of flow units in a layered, low-permeability turbidite reservoir.
Geologic Setting
Slope-basin reservoirs are abundant in the
southern San Joaquin basin (Figure 1),
where much of
the oil and gas
production comes
-13,000',
from turbidite
i
sandstones (Weimer
S:------..
and Link, 1991).
The "Stevenssandstone" is an informal unit, known
primarily from the
subsurface, which
represents a deepwater clastic facies
of the Monterey
Shale (Upper Mio-
-12,000~
slructure contours drawn on N-Poinl marker
c.I.=200It161
m)
I
cene). It is also
one of the most
prolific reservoirs
in the basin and
has contributed
about 15% of the
nearly 1.9 billion
m3 of oil (12 BBO) produced here since
1864. Yowlumne is the last giant oil field
discovered in the basin, and the field has
produced more than 15.9 million m3of oil
(100 MMBO) from Stevens turbidites.
Because Stevens oils derive from
Monterey Shale source rocks (Grallam and
Williams, 1985), Yowlumne is part of a
Figure 1: Structure map of Yowlumnefield drawn on the N-Point marker,
a regional correlation horizon that marks the approximate top of the
Stevens sandstone. The map shows the relationship of Units A and B to the
small anticlinal closure at Yowlumne.
along fan margins. Furthermore, waterflood patterns may sweep additional oil
toward fan margins, where it becomes
trapped. Thus, potentially recoverable,
bypassed oil remaining along t11inningfan
margins and oil trapped against these margins by waterfloodingrepresent significant
remaining reserves.
December 1997
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source rock and reservoir pair known as
the Monterey-Stevens petroleum system.
The oil accumulation at Yowlumne is controlled in part by a small anticline, with
less than 61 m (200 ft) of structural fourway dip closure, that formed during
Mio-Pliocene deformation of the south
margin of the basin (Metz and Whitworth,
1984; Graham and Williams, 1985).
Texaco discovered the field in 1974, and
Tenneco set up Yowlumne Unit A in 1978
to waterflood the area of closure. Because
subsequent drilling established production
on the north-dipping flank of the structure
as well (Figure 1), Unit B was created in
1982 to waterflood the flank accumulation (Metz and Whitworth, 1984).
In this Issue
A digital database of petrophysical values
was constructed from well log data constrained by core analyses (Figure 2). Total
porosity (0total) is derived from sonic log
data, and shale volumes (V sh) from
gamma ray curves. Effective porosity
(0eff) is obtained from 0eff =0total - (0sh
* Vsh ) where 0sh is shale porosity (V sh >
90%). Liquid permeability (Kliquid)is calculated from 0eff using an algorithm
derived from core data, and validity of
log-derived Kliquid and 0eff distributions
(of net sand) is confirmed by comparison
to core data corrected for overburden
pressure. Net sand is defined as Vsh =0 to
30% and 0eff =8% to 30%. Water saturation (Sw) is calculated from 0sh using the
Archie equation.
Volume 40 Contents
tion from plutonic and metamorphic
terranes in the nearby Tehachapi-San
Emidio Mountains (Whelan, 1984; Tieh
et aI., 1986).
Reservoir Architecture
Well log, 3-D seismic, and core data indicate that the Yowlumne sandstone is a fanshaped, layered, turbidite body up to 150 m
(493 ft) thick buried 3,410 to 4,050 m
(11,200 to 13,300 ft) deep (Figure 1). Also,
the fan in cross section is lens shaped and
does not significantly incise underlying
strata (Figure 3). Because large-scale channeling beneath the fan is absent, deposition
was primarily as sheet sands transported by
sediment-gravity flows.
Thin shales divide the fan into
Reservoir Statistics
Methodology
several lobe-shaped reservoir
"
D;"""YD,re
1974
= ..
R"'No;'Ik,th
Field exploitation is enhanced with
layers. Five of these layersA"'.Thkkn,,, (gro")
.~]
M". Thkk"" (gro,,)
A",
a thorough knowledge ofthe resercalled the A, B, C, D, and E
voirs. Most production
at
sands-produce oil from Unit
Yowlumne is from the Yowlumne
B (Figure 3). A basal sixth layer
sandstone, one of several disconcalled the W sand is pressure
Rock Properties
fl
tinuous sand bodies of fairly localisolated
from the overlying
rao~i,
""'m,,,.;.
ized extent that collectively are
sands and is wet. Layers A
12%
Err,,,I,,poro,;,,
5-lOmd
Ai,P'",,"b"It,
referred to as the Stevens.
2 md
LiqoIdP,"""b"i',
through E merge into homogey owlumne
65%
N,uGro" S""d"oo,
=
>12%
sand
C(" VoIom,(V,h)
Elsewhere within the same basin,
nous, clean sandstone on the
'" "
Q B
other sandstones make up the :§ 1
west margin of the fan yet con... '"
Fluid Properties
Stevens. A better understanding of
tain interbedded shale layers on
co. "
O;IG,,"Ity
the Yowlumne reservoir is desir- ;;;;co. '"-"~
"*
FmW","D,"';ty
the east. For example, horizon:~;;8;~~2~~;;m~PI)
OIIVI"o<i',
Dri",M"h""I'm
able to reduce a 35% annual
tal Well 16X-4 on the west side
R".T'm""""
OngI,,'R," P""o"
G.O.R.
decline in field production and to
penetrates a thick interval of
AIohm.m
develop remaining reserves before
clean sandstone (Marino and
aging facilities need to be replaced
Schultz, 1992). By contrast,
or abandoned. Five steps were per- Figure 2: Type log for Yowlumnefield showing producing reservoirs, Well 73X-3 on the east side
and the rock and fluid properties of the main reservoir (the Yowlumne
formed to achieve these goals:
penetrates shale layers, some
sandstone)
1. Description of reservoir archiseveral feet thick, interbedded
with the reservoir sandstones.
tecture (i.e., stratal geometries, flow
Results - Lithology
units, and facies distributions) using
well log correlations, pressure data,
The Yowlumne sandstone is a clay-bearReflection geometries evident on 3-D
and an existing 3-D seismic survey.
ing arkosic wacke containing quartz,
seismic data indicate downlap within the
potassium feldspar, and plagioclase with
fan, with basinward progradation to the
2. Determination of reservoir properties
subordinate plutonic and metamorphic
north and lateral progradation to the west.
using core, log, borehole-breakout, and
rock fragments. Most plagioclase is
In other words, lobe-shaped, shale-boundalbitized and was altered in the source
micro-seismic ~ata.
ed reservoir layers in Unit B step to the
area before transport. Porosity is primarileft facing basinward in the direction of
3. Construction of a digital petrophysical
ly intergranular and results from comsediment
transport
(Jessup
and
database (e.g., porosity, permeability,
paction of original depositional porosity
Kamerling, 1991; Clark et aI., 1996b).
and water saturation).
that is reduced by minor carbonate and
Thus, the basal productive layer (sand E)
quartz cementation, and slightly enhanced
is thickest on the right (east) side of the
4. Contour mapping of petrophysical
by plagioclase dissolution. The clays are
Yowlumne fan, and the top layer (sand A)
properties by individual flow units.
dominantly authigenic kaolinite which
is thickest on the left (Figure 3).
lines pores and is derived from feldspar
5. Location and quantification of
diagenesis. Some mixed-layer smectite/
Compartmentalization and Flow Units
bypassed reserves using a model to
illite, probably detrital in origin, is also
Variations in reservoir pressures and
simulate fluid flow in the reservoir.
injection of radioactive tracers indicate
present. The mineralogy indicates derivaOi
01
is::
0
l
&1
Prod",;ogW,II,
W",,,Ioj,";ooW,II,
ComoI",;", Prodo",oo
(,II "0'" thru 1995)
3.410-4.050 m (I 1.200-1 3.300 h)
69 m (225 h)
I50m(493h)
1,243 h,(3.070"",)
48 "t;"
& 40 51
30,"1,,&
9SI
16.38, 10",ofoII (103 MMBO)
2.60, 1&",01 g" (92 BCF)
==
NPoi",m"~ee
16%
50-IOOmd
1O-20md
80%
<6%
01
01
~
01
~
10-4"od
Pm"tee
,,",=IIj
Rw@2500C
.52,p,@""nmi,,,mp,,,to,,
floId",'o<Ioo
I I3- I 32-C (23S-27o-F)
39.02 MP,(5,660p,i)
107o<m3(600dlbbI)
continued
December 1997
on next page
13
l
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~
1.6km
1 mile
A
Search
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In this Issue
.:;.
63X-4
S5X-5
45X-7
76X-3
44X-3
23X-3
16-2
A'
2.5
see
3.0,.
see
East
West
-+
85X-5
Left-stepping
25X-4
44X-4
63X-4
Geometries
23X-3
45-3
44X-3
76X-3
16-2
64-3RD 16-2RDI
A
A'
IV POint rn.rker
-
A sand
!IIB sand
!IIC sand
II!D sand
II!E sand
Yowlumne Reservoir
4.0km
(2.5miles)'
'"
""'
Figure 3: Seismic line and cross section A-A showing the lens shape of the Yowlumnefan. The
line and section cut from west to east across the main body of thefan, perpendicular to the direction of sediment transport.
/
weak compartmentalization of the reservoir that results in separate permeability
pathways along which fluids flow at different rates (Metz and Whitworth, 1984;
Berg and Royo, 1989). Most likely, these
pathways represent different flow units
which, for the most part, are in pressure
communication over geologic time.
Consequently, these compartments, which
correlate to the six shale-bounded, lobeshaped reservoir layers already discussed,
develop the same oil/water contact over
thousands of years yet acquire slightly
different pressures as the field is rapidly
produced over tens of years.
Compartmentalization exists on an even
larger scale. (1) The gross reservoir interval in Yowlumne Unit A has consistently
been pressured differently than the same
interval in Unit B. Gross sand isopachs
indicate separate northern (Unit B) and
14
southern (Unit A) depocenters (loci of
thickening) representing different depositional accumulations. Sandstones in Unit
B have more quartz, less clay, and higher
original porosity those in the Unit A, indicating different sediment sources
(Whelan, 1984). (4) The oil/ water contact
in Unit B is 660 m (2,180 ft) structurally
lower than the contact in Unit A. Although
a few studies (e.g., Berg and Royo, 1990)
interpret a single contact steeply tilted at
50 (480 ft/mi), a large density difference
of 0.154 glcc between the oils (320 API)
and formation waters (TDS of 22,000
ppm) results in buoyant oils unlikely to
support a contact tilted more than 10 (100
ft/mi) even in the presence of a strong
water drive. Thus, Units A and B appear to
be separate compartments. If so, basinward progradation to the north indicates
that compartments in Unit B are younger
than those in A (Figure 4).
Volume 40 Contents
A common oil/water contact, tilted less
than 10 (100 ft/mi), appears to exist
between Unit A and South Yowlumne
field, a lobate sand accumulation located
to the west of the main Yowlumne field
(Figure 1). If a common contact exists,
then there is depositional continuity, with
Unit A and South Yowlumne field representing adjacent depositional lobes.
Furthermore, lateral progradation to the
west indicates that the South Yowlumne
compartment is younger than the Unit A
compartment (Figure 4).
Reservoir Rock Properties
Log-derived petrophysical data, constrained by core analyses, indicate
decreasing reservoir quality towards the
east margin of the fan. For example, values
of net/gross sandstone = 80%, Vsh < 6%,
0eff = 16%, and Kliquid= 10-20 md along
the fan axis decrease to net/gross = 65%,
Vsh> 12%, 0eff = 12%, and Kliquid
= 2 md
along the eastern fan margin (Figure 2).
Most likely, this eastward degradation in
reservoir quality results from an increase
in the frequency and thickness of interbedded shales (net/gross), increasing clay
content (Vsh)of the sands, and decreasing
gram SIze.
Close proximity of Yowlumne field to the
San Andreas fault is probably the main
influence on stress orientations in the
reservoir. Borehole breakouts indicate
maximum horizontal stresses oriented N-S
(Castillo and Zoback, 1994), whereas
micro-seismic data collected during a fracture stimulation indicate NW-SE fracture
propagation in the main reservoir. Thus,
induced fracturing is likely to be most
effective in deviated wellbores oriented
NE-SW, perpendicular to the fractures.
N
r
1 mil,
,
1km
Figure 4: Map showing left-stepping and basinward-stepping geometries exhibited by depositionallobes that compose the Yowlumnefan.
December 1997
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Discussion - Depositional model
The Yowlumne sand lobes are part of a
trend of Stevens sandstones that includes
Landslide field, a northward-prograding
complex located about 6.4 km (4 mi) to
the south of Yowlumne. Seismic data
indicates continuity between these
fields (Stolle et aI., 1988; Quinn, 1990).
Therefore, depositional lobes should exist
between Landslide and Yowlumne, and
additional lobes may exist basinward of
Unit B.
Most likely, basinward-stepping geometries in the Yowlumne-Landslide system
resulted, in part, from increased sediment
input into the southern San Joaquin basin
during renewed uplift of the basin margins. These geometries probably also
resulted, in part, from decreasing accommodation (i.e., tectonic subsidence plus
eustatic sea-level change). Decreasing
subsidence rates elsewhere in the basin
resulted in decreased accommodation,
which in turn had a profound effect on the
aggradational and progradational geometries of Stevens sandstones (Clark et al.,
1996a). Because the Miocene Yowlumne
fan was located close to a tectonically
active transform margin represented by
the modem San Andreas fault, subsidence-driven accommodation was probably just as important during deposition of
the Yowlumne system.
Left-stepping geometries probably resulted from Coriolis forces, which in
Northern Hemisphere basins cause ocean
currents to circulate clockwise around
basin margins. Consequently, Northern
Hemisphere fans preferentially deposit
levees on the right sides of channels, forcing lobe deposition to the left (Menard,
1964). Abundant interbedded shales,
indicative of overbank processes, on the
right side of the Yowlumne fan (e.g., Well
73X-3), and homogeneous sandstones,
characteristic of lobe facies, on the left
(e.g., the Well 16X-4) are consistent with
this interpretation (Clark et al., 1996b).
Alternatively, the clean sands represent
channel facies instead of lobes (Metz and
Whitworth, 1984; Berg and Royo, 1990).
However, a channel complex is inconsistent with progradational geometries and a
lack of major incision beneath the fan.
Also, left-stepping geometries in Unit A
and South Yowlumne field indicate lobe
December 1997
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deposition where the alternative model
requires a channel axis. Furthermore,
facies distributions in which reservoir
quality decreases toward the east (right)
margin of the fan and increases on the
west (left) side is more consistent with the
lobe model.
Flow Simulation
Remaining field reserves are identified by
further subdividing reservoir layers A; B,
C, D, E, and W into 10 flow units and
exporting digital contour maps (grids) of
values for net/gross, 0eff, Kliquid,and Sw
of net sand in each flow unit to a computer model that simulates fluid flow into and
out of the reservoir. Although a full-field
model indicates ultimate recovery of 45%
of original oil in place, 477,000 m3 of
bypassed oil (3 MMBO) will remain
along the thinning fan margins. These
reserves represent oil banked against the
fan edge by waterflood and reserves not
exploited due to decreasing reservoir
quality and thickness.
From detailed (partial-field)modeling of a
prospective area indicated by the full-field
model, a high-angle well, the ARCO 91X3, was located to exploit 73,900 m3 of
bypassed oil (465,000 BO) banked
against the east margin of the fan
(Figure 1). This well deviates up to 85° to
the west, resulting in tangential penetration of over 335 m (1,100 ft) of reservoir
with a true thickness of only about 57 m
(190 ft). Three proposed fracture stimulations, spaced 76 m (250 ft) apart, will
improve connectivity across shale-bounded reservoir layers by inducing fractures to
propagate vertically through the reservoir
and NW-SE, oblique to the well path.
Thus, one deviated well potentially provides the same productive capacity as
three vertical wells, resulting in more costeffective exploitation of the field margin.
Conclusions
The interaction of climate with rapid
uplift dramatically increased sediment
input into the southern San Joaquin basin
during the Miocene and resulted in the
northward progradation of a fan-shaped,
layered turbidite complex called the
Yowlumne sandstone. Subsequent deposition resulted in the formation of seven
lobe-shaped reservoir compartments with
basinward-stepping geometries attributed
In this Issue
Volume 40 Contents
to decreasing accommodation ,and high
sediment flux, and left-stepping geometries attributed to Coriolis forces.
More abundant shale-bearing levee facies
on the east (right) margin fan and lobe
facies on the west result in decreasing
reservoir quality toward the east. Costeffective exploitation of bypassed oil
trapped in tight sandstones along the east
margin is achieved using horizontal to
high-angle deviated wells with multiple
fracture stimulations in individual well
bores. A thorough understanding of the
reservoir architecture and computer models that simulate reservoir geometries,
rock properties, and fluid flow help to
effectively locate wells and design completion programs that maximize productivity from the layered, low-permeability
turbidite reservoir that characterizes the
thinning fan margin along the east side of
the field.
BIOGRAPHICAL
SKETCH
Michael S. Clark
received a B.S.
degree in earth sciences from the
University of California at Santa
Cruz in 1975, an
M.S. in geology
from the University of California at Davis in 1979, and
a Ph.D. in geology from the Colorado
School of Mines in 1991. He is currently
a development geologist with ARCO
Western Energy in Bakersfield, California.
Editor's Note: Due to space constraints
we could not list the references cited in
this article. The references are available
from Mike Clark at:
P.O. Box 147
Bakersfield, CA 93302-0147
Telephone (805) 632-6254
e-mail [email protected]
15
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-
An Unproven Unconventional Seven Billion Barrel Oil Resource the ~ s c a l o o s aMarine Shale
by Chacko J. John,
Bobby L. Jones, James E. Moncriej
Reed Bourgeois, and Brian J. Harder
Basin Research Institute, Louisiana State
University, Baton Rouge, LA 70803
ABSTRACT
Oil production from fractured, self-sourced
shales occurs in many areas, yet the magnitude and resource potential of such
unconventional hydrocarbon sources is not
well defined. The purpose of this paper is
to bring industry attention to what may be
a very significant potential reserve of
hydrocarbons contained in the Tuscaloosa
marine shale (TMS) underlying a large
area of southwestern Mississippi and
southern Louisiana. While it has long been
known by operators and drillers in the area
that the TMS contains petroleum under
sufficient pressure to release
oil and gas into the mud and
on to the pits, not much
progress has been made or
much interest shown by
industry in evaluating and
testing the formation.
tain a potential reserve of about 7 billion
barrels of oil. Horizontal drilling could
maximize production and minimize environmental impacts.
Many studies have been conducted on
hydrocarbon production associated with
shale formations; for example: the Bakken
Shale, Williston Basin; and Antrim Shale,
Michigan Basin. However, no published
information is available relative to
the existence of hydrocarbons in the
Tusca-loosa marine shale or its lithological
characteristics.
Introduction
.
The Gulf Coast region of the United
States is considered a mature producing
province. To maintain andlor increase
hydrocarbon production, future industry
basins include the Upper Devonian-Lower
Mississippian-age Bakken shale of the
Williston basin (Meissner, 1991a; Hansen,
1991; LeFever, 1991; Price and LeFever,
1992); Cane Creek shale of the Pennsylvanian Paradox basin, Utah (Morgan,
1992; Morgan et al., 1992); Woodford
shale in the Anadarko basin of Oklahoma
(Hester, Schmoker and Sahl, 1990a,
1990b; Fertl and Chilingarian, 1990;
Comer, 1992); Mississippian- Devonian
New Albany shale of the Illinois basin
(Cluff and Dickerson, 1982;Comer et al.,
1993; Minihan and Buzzard, 1995, 1996);
Antrim shale of the Michigan basin; Ohio
shale occupying the Appalachian basin
area; Miocene Monterey shale of
California; Mississippian Barnett shale,
Fort Worth basin (Lancaster et al., 1993);
and Upper Cretaceous Niobrara shale
formation of northwestern
Colorado (Vincelette and
Foster, 1992; Pollastro, 1992).
Stratigraphy
Sands and shales of the
Tuscaloosa Group are over
1,000 ft (305 m) thick
The Tuscaloosa marine shale
(Howe, 1962) and represent
section lies between sands
a complete depositional
of the upper and lower
cycle (Spooner, 1964). The
Tuscaloosa formation and
Tuscaloosa in this area also
varies in thickness from 500
represents the lowest formaft (152.4 m) in southwestern
tion of the Gulfian CretaMississippi to more than 800
ceous series (Forgotson,
ft (243.8 m) in the southern
1958). The study area (Figure
part of the Florida parishes,
1) covers the Florida parishes
southeastern Louisiana. The
(St. Helena, East and West
primary zone of interest is a
Feliciana, East Baton Rouge,
high log resistivity (5 ohm) Figure 1 : Index map showing the study area and locations of cross sections Livingston, Tangipahoa,
zone at the base of the shale compiledfor this investigation.
Washington and St. Tamsection, which varies in thickmany), the counties of southtrends should include research and evaluness from 0 to 325 ft (99 m) over the area.
west Mississippi (Amite, Wilkinson,
It is found at the shallowest depth of
ation of potential nonconventional hydroAdarns, Franklin, Pike, and Walthall) and
approximately 10,000 ft (3048 m) in the
carbon resources.
westward through central Louisiana
study area. Two wells are known to have
(Avoyelles, Catahoula, Concordia, Pointe
produced from the marine shale in southDescriptions of U.S. shale basins and curCoupee, Rapides, Vernon, Allen,
eastern Louisiana with one having prorent drilling activity information
St. Landry, Beauregard, Grant and
is provided by Reeves et al. (1996).
duced over 20,000 bbl of oil in the last 19
Evangeline Parishes) to the Texas border.
years. Preliminary evaluations indicate
Published literature information available
The study is located between Cretaceous
that the Tuscaloosa marine shale may conon hydrocarbon production from such
and Wilcox production in north Louisiana
16
December 1997
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and in south Mississippi, and the Miocene
production to the south in south Louisiana
(Howe, 1962).
The Tuscaloosa Group comprises three
units. The lower Tuscaloosa represents a
transgressive stage of the depositional
cycle (Spooner, 1964) and consists of an
arenaceous and argillaceous lower unit.
The marine shale forms the middle
Tuscaloosa unit and represents the inundated phase of the depositional cycle. The
marine shale is mostly gray to black, fissile, and sandy at some locations thickening downdip. In the McComb Field (Pike
County, Mississippi) the marine shale is
500 ft (152.4 m) thick increasing to 800 ft
(24 m) in the south-central area of
Washington Parish, Louisiana. The upper
Tuscaloosa sands and clays represent the
regressive phase of the depositional cycle.
It is difficult to distinguish the upper
Tuscaloosa from the overlying Eutaw
Formation because of their lithologic similarity (Howe, 1962).
Reports of Oil and Gas from the
lbscaloosa Shale
One of the earliest geoscientists who noted
the hydrocarbon potential of the TMS was
the late Alfred C. Moore (Dwight "Clint"
Moore, 1997, personal communication),
who wrote in his unpublished notes in
1969 that the Tuscaloosa was believed to
be the "source b e d for most of the underlying lower Tuscaloosa oil trapped in sand
bars draped over and around structural
highs between the Brookhaven (Lincoln
County) and Gillsburg oil fields (Amite
Co., Mississippi). Moore evaluated over
50 dry wells drilled in the general area and
concluded that the TMS was fractured and
that the fractures were interconnected.
He stated that there was significant fracturing of the TMS probably by pressure
increases from oil generation. Meissner
(1991b) believed that overpressuring
from oil generation in the Bakken Shale
is related to the vertical fracturing.
Unpublished records from Alfred C.
Moore, provided to us by his son, Clint
Moore, also contain core information from
the Callon Petroleum #2 Cutrer well
(Section 55-T1S-R7E), Tangipahoa
Parish, Louisiana. The analysis of 110 section plugs from the cored interval 11,550
ft-11,653 ft (3520 m-3552 m) showed a
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range of figures, from lowest to highest, as
follows: permeability - from less than 0.01
to 0.06 md; porosity - from 2.3% to 8.0%;
oil - from 0.7% to 4.3% (vol.); gas - from
0.2% to 1.3% (vol.); and, water - from
3 1.8 to 88.2%. Although the permeability
and porosity figures appear to be quite
low, this is the well that produced some
2,500 barrels of oil from the TMS from
perforations between 11,584 and 11,644 ft
(3531 m-3549 m). The cores were predominantly described as silty shale and
sometimes calcareous.
Our study information also contains lithologic descriptions of cores from the
Sun #1 Spinks well (Section 7, T2NR7E) Pike Co., Mississippi, in the TMS
section over the interval 10,750-1 1,067 ft
(3277 m 3373 m). The upper 120 ft
(36.5 m) of the core were described as
shale, with the section below being shale
and siltstone with cross-bedding and fracturing with oil shows.
Moore's unpublished 1971 notes say "visible fractures containing live oil are apparent in the diamond cores commencing at
10,940 ft. Frequency of the fractures
increases steadily with depth and are most
extensive between 11,000 ft and 11,055 ft
(40% of diamond core lengths contain visible fractures)."
In this Issue
Volume 40 Contents
cial oil production. He estimated that the
geographic area commencing in western
Washington Parish and extending through
northern Tangipahoa, southern Pike,
northern St. Helena, southern Amite,
northeast Feliciana and southern Wilkinson parishes was underlain by the TMS
"fracture fairway" covering an area of
approximately 750,000 acres, based on
isopach and subsurface studies.
In 1974 Moore estimated the recoverable
reserves from the TMS to range from 3 to
10 billion barrels of oil. Later, in 1978, he
revised and increased his estimate of
acreage to be over one million acres. In his
calculations he used an average thickness
of saturated rock of 160 ft (49 m), which
computed to 160 million acre feet. He also
used a oil in place estimate of 300 barrels
of oil per acre foot which computed to 48
billion barrels of oil-in-place reserves in
the TMS. He believed that at least 5% of
oil in place could be recovered by present
and near future technology.
This information would indicate some
enhanced porosities and permeabilities in
areas where fracturing may be present.
Obviously, more fracturing would be
expected in areas of stress where folding,
faulting, or movement of the shale may
have occurred. It would appear that none
of the wells produced or tested is located
on proven structures, so it is suggested that
locations at or near the apex of structure
may have considerably greater fracturing.
Jones and Moncrief (co-authors of this
paper) have conducted preliminary investigations of the occurrence of hydrocarbons in the Tuscaloosa shale zone prior to
becoming knowledgeable of Moore's
earlier work. They determined that the
overall shale interval between sands of
the upper Tuscaloosa and the lower
Tuscaloosa section varies from approximately 500 ft (152.4 m) at McComb field
in Pike County, Mississippi, to more than
800 ft (244 m) in central Tangipahoa
Parish, Louisiana. The primary zone
of interest bears high log resistivity
(5+ ohm), a fact also noted by Moore, and
lies at,the base of the above-referenced
shale section and varies from 0 to 325 ft
(99 m) in thickness over the prospective
area of interest.
Moore observed from his evaluation of
wells in the area penetrating the TMS that
they generally had an abnormal pressure
of 6200 psi in the TMS whereas the normal pressure for the upper and lower
Tuscaloosa in the area ranged from 4400
to 5200 psi. Drillers in the area increase
mud weights to create a hydrostatic pressure equal to 6200 psi to prevent blowouts
while drilling through the TMS section.
Moore's opinion was that wells completed
in the TMS would be capable of commer-
Both investigations of the TMS independently confirm the resource potential
of the TMS and the viability of cornmercial production from it. Schmoker and
Hester (1990) studied log formation resistivities in the upper Devonian-lower
Mississippian Bakken Formation of the
Williston Basin, North Dakota. They concluded that an abrupt resistivity increase
on the electrical logs was an indication of
oil generation and was not due to change
in the physical properties of the shale.
continued on next page
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continued from urevious ua,ane
Extent of Tuscaloosa Play
In this study the writers have attempted
to generally delineate the location and
depth of the TMS within the study area
(Figure 3) and determine more specifically areas where the shale shows electrical
log characteristics (higher resistivity) that
create commercial value.
Hundreds of electric logs from the simplest (1940's vintage) to the sophisticated
logs available today have been examined
and correlated. It became evident that the
zones with the greatest potential were
those of the highest resistivity in the lower
part of the TMS and that these zones do
not cover the entire region.
Much consideration has been given to
what guidelines or parameters should be
used to determine which were the potentially productive zones. The type log and
standard used for this study was from the
Texas Pacific Oil Company #1 Winfred
Blades well in Tangipahoa Parish
Louisiana. At present this is the only
well producing oil from the TMS. It has
produced over 20,000 bbl of oil with no
water from perforations between 11,073
and 11,644 ft (3375 m-3549 m) since its
completion in 1978. Schlumberger log
analysts believe the oil is coming primarily from the higher resistive section from
11,460 to 11,645 ft (3493 m-3549 m).
The current owners of this well inform us
that the well is presently producing about
1.2-2 bbl of oil per day with no water.
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In this Issue
TMS resistive zone are reasonable and
valid. High resistivity (generally 5 ohm or
more) or a dramatic increase in resistivity
(3.5 ohm or more) required consideration.
Obviously, vintage or type of logging
device, drilling mud characteristics
(logging tool environments, resistivity),
etc., are factors in determining "high-resistivity" log readings. In determining net
thicknesses, high resistive sections that
were not separated by more than 20 ft
(6 m) of low-resistive shales were counted.
Smaller resistive sections separated by 20
ft (6 m) or more of shale were omitted for
the count. Fairly highly resistive zones
with more than 1 ohm of separation
between the short normal resistive curve
reading and the lower long normal resistive
or conductivity reciprocal were considered
to be questionably potential, in which case
surrounding wells were checked and influenced decisions. In some cases, instinct or
"feel" might have been a factor in determining net section thickness.
There seems to be little doubt that the
highly resistive section of the TMS is
hydrocarbon laden. It is also obvious that
some permeability and porosity exist, but
how much of each would be of great
importance in dealing with economic
aspects. Unfortunately, little is known
G
-
Volume 40 Contents
about the porosity and permeability of the
TMS. Basically our knowledge is limited
to knowing that two wells produced
enough volume of oil to warrant attention,
and the information available from well
logs or cores.
To determine the regional extent of the
TMS, an east-west, basically strike section
(S-1) was constructed. This cross section
graphically demonstrates the lateral extent
of the resistive TMS section. It also
demonstrates the overall loss of the resistive TMS section west of Avoyelles Parish,
Louisiana, as well as its thinning to the
east in Washington and St. Tarnrnany
Parishes of Louisiana. Seven north-south
dip sections (D-1 to D-7) were also compiled crossing the strike section. The eastern most dip cross section (D-1, Figure 2)
reflects the regional updip thinning of the
resistive TMS in the northern portion of
Washington Parish, Louisiana, and its
downdip thickening of 100 ft (30.5 m)
toward the south in Washington Parish.
There is a regional downdip fading of the
section further to the south in Tangipahoa
Parish, Louisiana. The D-2 dip section
extends from just west of McComb, in
Pike County, Mississippi, to north of
Amite in Tangipahoa Parish, Louisiana. It
goes through the Texas Pacific Oil
Sun Exploration 8 ProductionCo.
i Ballew - Moss
A second well with some production from
the TMS is the Callon #2 Cutrer well locatd i n Sec. 55-T1S-R7E, about 7 miles (11.2
km) northwest of the Texas Pacific #1
Blades well and about 7 miles (11.2 km)
east-southeast of Gillsburg Field, Amite
County, Mississippi. It encountered the
top of the TMS at a measured depth of
11,520 ft (351 m) and was perforated
over the interval 11,544-11,678 ft (3519
m-3559.5 m). This well produced about
2,500 barrels of oil from the TMS before
being plugged and abandoned in 1991.
Our discussions with Schlumberger log
analysts on several logs have led us to
believe that the criteria established for
delineating the potential areal extent of the
Figure 2: North-south dip section (D-1) across the eastern part of the study area from
Washington Parish to Tangipahoa Parish, Louisiana.
December 1997
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noteworthy
that
Company Winfred
even
on
this
scale
well,
Blades #1
some small undulawhich represents the
tions
a r e noted
standard or type log
in
northeastern
used for this study
Rapides
Parish
and is the only well
(Big
Island
Field),
producing from the
Gillsburg
Field
TMS. The lower
at
the
Louisianaresistive TMS secMississippi border
tion has a maximum
in Amite County,
thickness of 185 ft
Mississippi,
and at
(56.4 m) in the southLockhart
Crossing
western portion in
Field in Livingston
Tangipahoa Parish, Figure 3: Structure map of the study area on top of the Eagle Ford Formation.
Also
note the very
Parish,
Louisiana.
cross section is seen in the Shell Oil
Louisiana, and thins to 9 ft (2.7 m) to the
sparse
control
below
12,500
ft (3810 m)
Company Edwin Barbin No. 1 well locatnortheast in Pike County, Mississippi.
in
parishes
to
the
west
of
Rapides
Parish,
ed in Avoyelles Parish, Louisiana, and is
Louisiana.
found at a depth of 12,060 ft (3676 m).
The TMS section also dips from 10,225 ft
The D-6 cross section shows the beginning
(3 116.5 m) in Pike County, Mississippi, to
Isopach maps have been created on the
of the overall thinning of the Eagle
a depth of 12,155 ft (3705 m) in
resistive Tuscaloosa marine shale on a
Ford-TMS section in the western part of
Tangipahoa Parish, Louisiana. The D-3
20 ft (6.1 m) contour interval. The "heart"
the study area. The resistive TMS section
cross section is the longest dip section in
or thickest zone is located from Avoyelles
is completely missing (not developed) in
the study area traversing what may be conParish on the west to Washington Parish
some wells on this cross section. The D-7
sidered "the heart of the potentially proto the east. A net isopach of this resistive
dip cross section constructed at the westductive area." The thinnest part of the
Tuscaloosa
marine shale section is
em end of the study area again shows the
TMS section here is about 65 ft (19.8 m)
contoured
on
a 10 ft. (3 m) interval and
thinning
of
the
overall
interval
of
the
Eagle
and is found at the north end of the cross
shows
the
most
attractive areas for potenFord
to
the
TMS
section,
possibly
influsection in Amite County, Mississippi , and
tial
production.
enced
by
the
Sabine
uplift
to
the
north.
it thickens to more than 220 ft (67 m) to
Another notable factor is the lower resisthe south as seen in the Amoco, Corona
Tuscaloosa Shale as Source Rock
tivity demonstrated at the base of the secNo. 1 well located in East Baton Rouge
The
TMS has been thought by many to be
tion
in
comparison
with
wells
farther
east
Parish, Louisiana. The D-4 dip cross secthe
source
rock for the production from the
in
the
study
area.
tion is located in the central part of the
Tuscaloosa
sand reservoirs. This has been
study area more or less along the
substantiated by a geochemical analysis of
Structure maps were made on several layLouisiana-Mississippi border. This cross
ers along with isopachous maps of the inoil from two wells in the study area: the
section traverses the "golden trend of
between intervals. Figure 3 reflects the
Canadian Delta (formerly Norcen)
good thick resistive TMS section. The
general structural configuration on top of
#A- 1 Calhoun (upper Tuscaloosa sand) at
Humble Oil & Ref. Company well in
the Eagle Ford Formation and base of
Gillsburg Field in Amite County,
Adams County, Mississippi shown at the
Tuscaloosa marine shale through out the
Mississippi, and the Long Leaf (formerly
north end of this cross section encountered
Texas Pacific) #1 Blades well in
study area. There are only slight differa thick 135 ft (41 m) resistive TMS section
ences in strike and dip rates between these
Tangipahoa Parish, Louisiana (Silvercreek
at a depth of 10,100 ft (3078 m), which is
structures and other structure maps previField). These analyses were performed by
shallower than in most other areas. The
ously published on well-known geological
DGSI, Houston, for the Basin Research
thickest resistive TMS section of 305 ft
horizons. An isopach map from the top of
Institute, Louisiana State University.
(93 m) is seen in the Pennzoil Laborde No.
Eagle Ford-base of Tuscaloosa marine
1 well located at the southern end of the
shale interval shows thickening to the
Reserve Potential
cross section in Point Coupee Parish,
northeast and thinning of section northWell logs have shown an average section
Louisiana, at a depth of 16,190ft (4935 m).
westward. Major thickening to the
thickness of 93 ft (28.3 m) of prospective
southwest is based on minimum well conTMS section within the 50 ft (15.2 m) net
The D-5 cross section demonstrates our
trol and may be incomplete.
resistive TMS contour. If this figure is
belief that shale encountered above
used as a lower average thickness limit of
10,00(&10,500ft (3048-3200 m) does not
The regional structural nature of the resisthe shale and if even only 40% of the resishave resistivity necessary to indicate
tive Tuscaloosa marine shale section is
tive TMS section has fracture-induced
hydrocarbon content in the study area. As
similar to other regional maps of this area
porosity and permeability, then there
shown on the cross section, the resistive
with only slight differences in strike and
would still be a net effective section of
TMS section thins toward the north end,
dip rates between structural maps in this
but thickens toward the south. The thickest
approximately 37 ft (11.3 m) that could
study and those previously published. It is
potentially yield hydrocarbons. If fracturTMS section of 166 ft (50.5 m) on this
(
December 1997
onfinurd on nrxf puge
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continued f r o n ~previous page
ing is not widespread andlor if porosities
are low, then a conservative figure of
50 bbl per acre foot could probably be
assumed. Because the shale section within
the 50 ft (15.2 m) thickness contour covers
an area of about 5900 square miles or
3,776,000 acres (15,281 square krn) it
potentially could produce approximately
7 billion barrels of oil.
Horizontal Drilling
Horizontal drilling technology has significantly advanced in recent years particularly in the Austin Chalk. Using the horizontal drilling technology available today it
probably would be feasible to drill a carefully planned horizontal well in the TMS
section. Such a well would increase the
possibility of commercial production from
the TMS and result in a significant
increase in the recoverable reserves that
could not have been technically or economically obtained with traditional vertical well technology. Preliminary evaluations point to the strong possibility that the
TMS may contain significant hydrocarbon
reserves. This now awaits confirmation by
the drill bit using horizontal drilling technology to maximize production and minimize environmental impacts.
Conclusions
The lower resistive section of the
Tuscaloosa marine shale is a potentially
significant commercial oil reservoir under
a large area straddling the MississippiLouisiana boundary south of McComb,
Mississippi, and covering the Florida
parishes of Louisiana, the southwestern
counties in Mississippi and extending
westward through central Louisiana to the
Texas border. The most prospective section covers an area of approximately 5900
*TN. &f
sq. miles (15,281 sq.krn) and has potential
reserves of 7 billion barrels of oil. The
marine shale section lies between the
sands of the upper and lower Tuscaloosa
sections and varies in thickness from
500 ft (152.4 m) in southwestern Mississippi to more than 800 ft (244 m) in the
southern part of the Florida parishes,
southeastern Louisiana. The primary zone
of interest, a high log resistivity (5+ ohm)
zone is located at the base of the
Tuscaloosa marine shale section and is
found at the shallowest depth of approximately -10,000 ft. (3048 m).
Production from this section by conwntional drilling and production methods has
been established by the Texas Pacific Oil
Company, #I Blades well (Sec. 42, TlS,
RSE) located in Tangipahoa Parish of
southeastern Louisiana. This well has produced over 20,000 bbl of oil with no water
at a rate of 1-2 barrels per day for the last
19 years. There are a number of reports of
oil shows in mud logs from wells penetrating the section throughout the study area.
The mud logs generally describe the shale
as being light to dark gray or brown,
splintery, brittle, micaceous, calcareous
silty shale with sporadic stringers of white
to light gray sand that, in most cases, has
a yellow fluorescence indicating oil in
the sample.
Horizontal drilling of the resistive Tuscaloosa marine shale section is proposed
because it is the most up-to-date technique
presently available to maximize production and minimize environmental impacts.
These features are especially important
because production from a single well
(vertical completion) may not yield commercially economic quantities of oil.
If proved economic, the Tuscaloosa
marine shale oil would be a huge addition
to the domestic United States oil reserves.
It will also lead to the further possibility
of opening up exploration and exploitation
of similar deep fractured shale resources
throughout the country and other areas of
the world.
Acknowledgements
The authors would like to acknowledge
Dwight "Clint" Moore, who very kindly
provided us with copies of notes written
by his father, the late Alfred C. Moore, and
gave us valuable suggestions for this
paper. We would like to thank Larry Day
and Gerald Howell of the Long Leaf Oil
and Gas Company, who provided us with
information about the Winfred Blades #I
well and an oil sample for geochemical
analysis, and Whitney Pansano of
Canadian Delta, Inc., for the oil sample
from the #A-1 Calhoun Well (Gillsburg
Field). The Oil & Gas Journal and
the Gulf Coast Association of Geological
Societies gave permission to use modified
versions of figures originally published
in their publications.
HGS Editor's Note: This article was
originally published in the Basin
Research Institute Bulletin, Volume 7,
August 1997. To get a copy of the complete literature references, cross-sections, structure and isopach maps referenced in this article, please contact
Chacko John at the LSU Basin Research
Institute. His e-mail is:
[email protected].
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SeisX NT is a fully integrated 2D/3D seismic interpretation software system designed to offer
exceptional value by providing comprehensive functionality at an affordable price. I t provides comprehensive seismic interpretation of 2D, 3D, multiple 3D and well data, within the same project,
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SeisX NT is also a powerful mapping and display tool. Most importantly, at a significantly lower
overall cost than comparable UNIX-based seismic interpretation systems, SeisX NT is the right
choice for the value-minded geoscientist.
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A 2 D TECHNOLOGIES I N C LOG-LINEm
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HGA Bridge-Briar Club
GCSSEPM Research
Conference
Adam's Mark Hotel
GCSSEPM Research
Conference
Adam's Mark Hotel
Volume 40 Contents
HGA Christmas Luncheon
at Great Caruso restaurant
''LaJrayilL Siting CnterialKarst
Hydrogeology "by Diane Yeager
Steak and Ale, 530 p.m.
3300 Post Oak
GCSSEPM Conference ends
15 Jdnt Meetbg Dinner and
International Esplorationigts.
"Geologic Evolurion of Volcanic
Passive Margins, South Atlantic"
by Vitor Abreu. Westchase Hilton,
9999 Westheimer, Social Hour
5:30 p.m.. taJk at 6:30p.m.
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HGS Office
Closed for Holidays
December *Jan 4.
(re-opens on January 5th)
Happy Holidays!
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The source for solutions to geological, log evaluation,
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1-
7 Deeember7-10
GCSSEPM Research Conference
''Shallow Marine and NonMarine Reservoirs"
Adam's Mark Hotel, Houston
call 1-8004361424 for info.
HGS office closed
5 0 3 Inteanational Meeting
5-0-2 En-and5-04 North American Meebng
5 0 5 hnchecm Meeting
5-06
5 01 Dinner Meering
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Emwg.mg Technology
Volume 40 Contents
E*ab
Jaumrg 8,1998
EhcIgiq '-r&mlogy
Meeting
"PreStaek Prtmphysical Inversion
fnrm Saimric" by Rick Wallace.
J a n v 15 1998
Dinna Nltecing
"Deepwater G w of Mexico: Lessons
Learned" by Bruce Applebum,
Texaco
January 13 1996
Abstracts due for Corpus Christi
W A G S Meeting
October 21-23.1998.
January 19,1998
International Explorationists Meeting
"Dccpw&r Sandr, Niger Deb"
by Ronald Kreim, Mobil.
January 24,19m, sntnrday
'Itaining meeting for HGS volunteers
at the Housron Mureurn of
N a n d Science
call Clint Moore 713-874-8730.
January 22-23,1!BS
"From 3-0 Seismic to DriUbit: An
OtG Technology Confcnnce"
at the Monteleone Hotel, New
(Means. Call 504-388-8328
for info.
Jmnarg 28 1998
HGS Lunchson Meeting
F e b m q %25,1998
Landmark 1998 Worldwide
Technology Forum
Adam's Mark H o d .
March 31,19!M
HGS 21' Century Sympoeium
Pvlarriott Gall& Hoatl Exhibition
center Resavetioar arc S50,
call HGS office.
Jmae 13,1998
HGS Guest Nigh and Gala
Petroleum Club, downtown,
Houston.
June blS,19)8
HGS Field Wp to the
Grand Canyon.
Call Dave Lam at 7 1 3 - 7 W17.
Jdy 27-30,1998
HGS FuId Trip to Jackson Hole, W Y
Call Rob K&w& at 713-951-4793
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BLUE DOLPHIN
EXPLORATION COMPANY
promcatbe, madable, well illustrated and thoroughly researched
assessment of Mure world oil supply: "The Coming Oil Crisis". The
210page paperback discusses how much conventional oil remains
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or distorted by vested interests.
Author Colin J. Campbell interlaces personal anecdotes fmm a lifetime in oil exploration wlth eyeopening insights into the mechanics
of oil depletion and a series of interviews wtth other experts in the
field of finite resource prediction.
The book shows how the world is running out of cheap oil. It
comblnes technical knowledgewith a thorough grasp of the political
and economic factors central to oil. It is above all a timely book, providing uttlcal reading for oil industry management, governments,
international agencies and investors, and is excellent academlc
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THESCOTlAOROI.JP
DOMESTIC 8 INTERNATIONAL
PETROLEUM ADVISORY SERVICES
Evaluation & Development Studies
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To all generating geologists and geophysicists working the
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The Gulf Coast Society of Economic Paleontologists and Mineralogists
(GCSSEPM) announces their 18th Annual Research Conference
%hallow Marine and Non-Madne R&sewoPrsM
December 7-10,1997--Adam's
Mark Hotel, Houston
Featuring:
Sequence Stratigraphy, Reservoir Architecture and Production Characteristics of Shallow Marine
and Non-Marine Reservoirs with Examples From:
West Afnca (Niger Delta), North Sea, South America, Mid-Continent U.S., Rocky Mountains,
Gulf Coast and Alaska Areas
Papers will highlight concepts and techniques developed from outcrop and subsurface core studies and case histories.
Check the web page at http://www.gcssepm.org
To R-r
for the Convention:
For information and forms contact GCSSEPM Foundation by telephone at 1-8004361424,Fax: 8@738-3542. Email address is:
[email protected]. Send payment by check, money order, or credit card. Written c o n f i t i o n and a detailed program of
events will be sent to people preregistering by Nov 15. After that date confinnations will be sent by email only.
Confenme registration fee is $285 (througb November 15, 1997) includes admission to all technicaVposter sessions, opening
reception and poster preview on Sunday, December 7; and group luncheons and buffets on December 8 and 9. After November 15
and on the day of the convention the registration fee is $350 on a spaceavailable basis only. A limited number of student places
are available until Nov. 15 at $100 each. Spouse registration of $50 admits spouse to opening reception and one evening buffet.
No r e h & for cancellations received after Nov. 15. Cancellations must be in writing and are subject to a $25 processing fee.
BASIN RESEARCH INSTITUTE OF LOUISIANA STATE UNIVERSITY
presents
Date: January 22-23,1998, Monteleone Hotel, New Orleans
The conference agenda will include presentations on 3-D seismic, horizontal and other drilling technology, advanced
logging techniques, improved recovery applications, and geochemical exploration. This is the fourth event in BRI's
successful ongoing series of oil and gas technology conferences.
How to get advance registration:
Registration is limited to 200 attendees. Brochures were mailed in early November. The cost is $ 195.00 per person
and includes luncheons, refreshment breaks, and hosted reception. Contact BRI at 208 Howe-Russell Geoscience,
Complex, Baton Rouge, Louisiana 70803-4101. Phone: 504-388-8328, Fax 504-388-3662. Website: www.bri.lsu.edu
BRI invites sponsors for the conference. Please call 504-388-8328 for more information regarding conference
sponsorship, or if you want a conference brochure.
December 1997
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Computer Applications Committee News
New Web Site Workstation Forum Open for Discussion
by Dave Crane
The Houston Geological Society web
site is now hosting its third on-line
forum, entitled "Using Interpretative
Workstationsfor E&P". You are invited to
participate; simply point your browser at
http://www.hgs.org.
The HGS forum Using Interpretive
Workstations for E & P will be a discussion about the role of the interpreter, the
workstation, and the interpretation software applications that have become tools
of choice for modem geoscientists.
Discussion of virtually any' workstationrelated topic will be welcomed, from how
the use of interpretive workstations has
changed the job of the geoscientist, to
case studies where using ComputerAssisted Interpretation has helped or hindered your work. The forum will also be a
place where you may bring up specific
problems you are having in an interpretation and see if anyone else has found ways
to deal with them.
Moderators are Kara Bennett and Jeffrey
Yarus. Kara is a petroleum geologist with
many years of experience in exploration
in the US and internationally, in the
Houston
Geological
majors and as an independent. She has
worked with interpretive workstations
extensively in exploration and production
settings, including Landmark, Geoquest,
and Charisma. Currently she is working
for Landmark designing their new
SeisWorks training program.
Jeffrey is also a petroleum geologist with
domestic and international experience. He
has worked on a variety of computer platforms as an applied scientist specializing
in quantitative methods, specifically
mathematical and statistical applications
(computer mapping, risk assessment,
3D modeling, geostatistics, etc.) He is
presently working for GEOMATH,Inc., a
subsidiary of Beicip/Franlab (a French
Institute of Petroleum Group Co).
Vendor information is welcome, particularly experiences of users of different
types of software. Brand names are
allowed, and user comparisons between
systems and applications are also welcome. Sales pitches are not allowed. The
moderators will decide when vendor information strays into the "sales pitch" category, and will remove sales pitch postings.
Moderators of the newsgroup speak only
for themselves as users and interpreters,
and not for their employers. Here are the
do's and don'ts: Do feel free to ask any
question that falls within the general topic
area under discussion. In the case of
workstation interpretation, it is loosely
defined to include mainframe and PC
applications, so don't be shy. Do remain
polite and professional.
Auxiliary
by Dene Grove, Third Vice President
Our 1997 season has gotten off to a fabulous start. It was delightful to visit with so many H.G.A. members at our luncheon in
September at the H.E.S S. Club.
I hope to see all of you at our Christmas luncheon on December 4th at The Great Caruso. The music,"Christmas on Broadway,"
is certain to get us in a festive mood for the holidays.
Hats off to Jan Stevenson, our effervescent Vice President, who has planned so many exciting programs for this year. You will not
want to miss a single one of these events. On behalf of the Houston Geological Auxiliary, we wish each of you and your family a
very healthy, happy, and safe holiday season.
Bridge Schedule
December 3
Briar Club
Timmons & Westheimer
30
December 8
St. Martin's Episcopal Church
Woodway & Sage
December 15
Rudi Lechner's Restaurant
Westheimer & Gessner
December 1997
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January 19 & 20,1998. Marriot Hotel, Denver, Colorado
Registration Costs: $130 RMAG member. $165 non-RMAG member
Technical sessions will address:
. Logging and seismic technologies for fractured reservoir analy~is
Practical application of advanced methods: Application, potential and pitfalls
Modeling of fracture genesis, reservoir properties and production history
Case histories from fractured reservoirs: domestic and international
..
.
Speakers include:
R. Aguilera;T.Apotria; T.Barrett; W.Belfield; R. Bereskin; A. Cheng; K. Corbett; J. De Graff;
T. Engelder;G. Forrest;L. Foulk;C. Garvey; M. Gross; H. Harstad; P.Hennings; T. Hoak;
N. Hurley; A Klawitter; A. Lacazette; P.La Pointe; S. Laubach;J. Lorenz; R. Loucks;H. Lynn;
E. Mancini; R. Marrett; P.Mescher;M. Mullen; W.Narr; D. Nielson; R. Nelson; P.Ortoleva; D. Rhett;
W.Rizer; W.Rossen; L. Teufel, R. VanDok
To register, obtain a speaker title list, RMAG membership and sponsorship info,
contact: Paul Gagnon or Ray Gorka, (303)623-0987phone; (303)893-0709fax; email: [email protected]
Or visit the RMAG website at: www.rmag.org for information or to become an RMAG member.
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The Teton Range, Jackson Hole, WYoming
Jackson Hole Field Trip Planned for July, 1998
by Bill Baehr, Field Trip Committee chairman
The Field Trip Committee reviewed the results of its survey posted on the Web page in August and in the September Bulletin.
Seven people responded. While that may not be a fair representation, two of the responses were very descriptive and helpful.
The survey indicated that our members have a need for both low-budget weekend trips and high-budget vacation type trips
and that we should do better in accommodating children.
This month we give some higWightsof our next summer's trip to Jackson Hole, Wyoming. Every month or two, we will add
information on another trip, updating members on our plans.
Jackson Hole-Teton Structural Geology Field Trip, July 27-30,1998
Observe four different orogenic processes and view geology on a grand scale in one of North America's most famous and
scenic resort areas. Participants will spend four days observing 1) evidence for faulting along the main Wind River thrust,
2) the fold and thrust belt near the Hoback basin, 3) the Laramide and thrust belt tectogenic sediments, and 4) Jackson
Hole-Teton area, where the thrust belt impinges on the Tetons at Teton Pass. The instructor for this trip will be either Dr. Jim
Steidtman or Dr. Ron Marrs from the University of Wyoming.
This four-day adventure is scheduled for July 27-30, 1998. It will be necessary to arrive in Jackson by plane on Sunday, July
26, 1998. The maximum number of participants will be 20, with a minimum of 10 to make the trip go. The cost including
guide books, air fare, lodging, transportation, and lunches is estimated at $1900.00 per person but could be less.
If you are interested please call Rob Kukowski at Seagull Energy 713-951-4793 or at home 281-530-5202. It is important to
get a participant count as soon as possible so we can make necessary reservations.
Sign Up for the June 1998 Field Trip to the Grand Canyon
by Dave Lazor
The Houston Geological Society Grand Canyon rafting field trip June 8-15, 1998, is now accepting reservations. Enjoy spectacular scenery, more than 100 rapids, side-canyon hikes, first-class rainbow trout fishing, and "live" textbook geology. This
may be the last trip for a while, so make your reservation early by sending a deposit of $100 to Dave Lazor, 5950 Beaudry
Dr., Houston, TX 77035. Make your check payable to "HGS."
The field trip is nonprofi~,and the cost is expected to be between $1700 and $1800. This includes transportation from Las
Vegasto Lees Ferry, g~de fee and tip, guidebook, lodging on the evening of June 7, food and drinks while in the canyon, helicopter ride out, and private plane back to Lees Ferry or Las Vegas. HGS members and guests will have priority only until the
end of 1997.
A geology instructor from one of our local colleges would like to participate in this trip, but cannot afford the fee. If any reader or company can assist with a scholarship pledge, please contact Dave Lazor at 713-728-0917.
32
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PLACE.
IT'SLOUISIANA
ANDTEXAS,
TOO.
hniques (bright spot) and
ck migration are critical to your exploration
r data base offers you distinct advantages:.
, -. .
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Volume 40 Contents
<-
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narrow azimuth (swath) acquisition method
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P.O. Box 37188 Houston,TX 77237-7188
(713)785.7900 FAX 785-7923
December 1997
Acquiring well defined drilling prospects
and producing properties with
development potential.
Will consider both open acreage ideas and
assembled prospects with reasonable
promote.
South Louisiana onshore and state waters.
Operations required. Minimum
participation 50-75%.
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rig is drilling!"
We meet your deadlines
I
CONTACT: ED EB1.E
PEL-TEX OIL C O W M Y
nwdollhr:
ausdOpeca(laaUd.
la-120WJh SaeeS Msldenhsrd
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Tele: (44) (0) 1ma 7BOD90
Fax: (44) (0) 1
m 76m340
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d admhOqOM.oD.uk
Five Post Oak Park, S u b 1530
TEL (713) 439-1 530
FAX (713) 439-1 023
December 1997
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CADX
Geotechnlcal Services
Horizon ExpZuration Company
A Division of Horizon Resources, Inc.
Digital Base Maps
Texas Base Maps
Generator of High Quality
2-D and 3-D Wildcat Prospects
for 20 Years
G E Maps
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Consulting
Data Conversion
Drafting
CADX Inc.
2727 Allen Parkway
Suite 1700
Houston, Texas 77019-2115
FAX: (713) 522-1881
(713) 522-5800
Wddwide oil and gas exploration
a d pr@u&on with o f f b s ~in:
Hoegton
London
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petrochemical
opearrtions in Louisiana
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UnionTexas
Petroleum
1330 Poet Oak Boulevard, Houston, TX 77056
P.O. Box 2120, Houston, TX 77252-2120
Phone: 7131623-6544 Fax: 7 131968-2771
Phone 281 -362-1 440
Fax 281 467-7208
e-mail: salesbcadxinc.com
Computer-aided Oil & Gas Exploration
Integrated Workstation
Consulting !$enices
TS Brown, President
FE Jenson, VP. Operations
wnail:tbrown 8 caexsew.com
Ph. 713.850.8255
Marathon Tower, Suite 500
5555 Sen Fellpe
l-lwsm,TX 77056
Fax: 713.860.8256
December 1997
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PC Workstati()n Technology and Its Impact on The Independ~niJConsultant
by Deborah Sacrey,
HGS Treasurer and Independent
Consultant, DKS Exploration
Blessings of the Boom
Many in the oil patch today are experiencing increased activity. Some optimists
would label this past year as the beginning
of a "boom". This increased activity level
is not price-driven like last boom in
the late seventies and early eighties. This
one is technology-driven. Price stability
plays a large part in increased
drilling/explorationbudgets, but new technology has allowed the bottom line to be
an ever increasing number.
~
have come down
drastically in the
last few years,
while speed and
efficiency
have
increased almost
exponentially. In
1992, a I-gigabyte
hard drive cost
$1600.00. Today a
9-gigabyte hard
drive costs just
$1100.00. In 1992,
a state-of-the-art
PC was a 486/
33MHz running DeborahSacreyof DKSExploration
Windows 3.1. Now
listing many of the software programs now
Advanced technology has come in the
there are chips available up to 500 MHz,
in use. This list covers seismic interpretaform of 1) 3-D seismic, 2) horizontal
running 686 machines with Windows NT
tion, geophysical tools, modeling, map4.0! This has only been a span of five
drilling techniques, 3) logging/evaluation
ping, geostatistical, GIS, petrophysical,
tools, 4) computer hardware and software
years. Imagine what may happen in the
engineering and other types of packages
and, 5) geophysical processing (including
next five years!
available for use on a Pc.
coherence and prestack depth migration).
PC application software is usually much
The biggest advance in technology arrived
Changing Role of the Consultant
less expensive than comparable UNIX
from the computer industry. Without the
How has the PC revolution changed the
versions, so the yearly maintenance fees
massive "super computers," 3-D seismic
are also much lower. For the cost of mainrole of the independent and consultant?
acquisition, processing and interpretation
It has allowed the creation of the PC worktaining a Landmark workstation for one
would not have happened!
station capable of doing 90% of the work
year, one can literally purchase a PC workHow PC Workstations Affect
being done on a UNIX workstation, at
station, including software and a plotter!
one-fifth the cost. This has allowed small
Consultants
With the advance in hardware, a correto medium independents (for example,
The biggest change for the independent
and consultant has been the "PC
Amerada Hess) to put a workstation on
sponding advance occured in PC applicaevery geologist's and geophysicist's desk!
tion software, much of which is geared to
Revolution." Personal computers are now
Not only does it allow maximum use and
the exploration industry. Table 1 is a
becoming competitive in price and speed
performance of available personnel, but
spreadsheet compiled a few months ago,
with the high-end UNIX computers. Costs
because of the relative ease in support!
Table 1
maintenance of the systems compared to
Hardware
PC Seismic Software
Cost/License
Maintenance
Leasing
UNIX systems. The overall need for comAvailable?
Requirements
puter support and systems management
SMT 2D/3D Pak
$10,000
yes
Top PC System
14% per year
no
personnel
is much less.
$9500
Top
PC
system
SeisVision (Geographix)
15% per year
GMA 2D/3D Interpret.
Vest 3D Seis
$9900 for all
$6000
17% per year
$40 per month
yes
yes
Top PC system
PC system
Mappin Software
GES (Geographix)
Leasemap (Geographix)
GeoCAD (DigiRule)
Terrastation II
$5500 min.
$5000 min.
$2200
$25,000
15% per year
15% per year
12% per year
18% per year
no
no
no
yes
PC System
PC System
PC System
PC or UNIX
Software costs and maintenance for independents and consultants to purchase seismic interpretation software. The cost figures may be dated, please check with the individual manufacturers for price quotes.
Contacts: SMT, Bill Vance 713-464-6188: SeisVision, Jim Pentico, 713-268-1119; GMA, Rob Meyers,
281-589-6898; Vest, Robert Vest, 915-682-7317; Terrascience, Jim Engstrom, 713-690-0101; Digirule,
Butch Butler, 1-800-344-4785.
December 1997
With a workstation on every geoscientist's
desk, a company can participate in more
deals. The number of 3-D seismic surveys
being shot seems to be growing exponentially, and there are increasing occurrences
of joint ventures and partnerships between
companies. Every partner sees the need
for their own interpretation, which has led
to outsourcing to consultants, because of
lack of staff.
continued on next page
37
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PC impact continuedfrom previous page
The PC revolution has changed the role of
the consultant drastically. The lower cost
of a typical PC workstation and associated
software has allowed the interpretive consultant to have all of the tools at hisher
fingertips without going deeply into debt!
The consultant is now competitive with
the big companies and can be available for
the overflow of interpretive work. Consultants can produce a quality product at a
much reduced price.
Technology Transfer Among
Consultants
This increased visibility is leading to
increased workloads for many consultants.
Help
In this Issue
Volume 40 Contents
*
-
Therefore it is imporG R D c Gallagher Research and
tant to belong to a very
Development Company
close networking orgaThe
leader in Surface Techniques for the
nization, such as HGS
Exploration of Petroleum
or SIPES. Members
have a tendency to
Hydrocarbon Surveys
State of the art:
Eh, pH, conductivity
Sample Acquisition
refer or use other memMicrobial
Statistical
Analysis
bers for consulting.
Iodine
Mapping & Interpretation
Because consultants
Radiometrics
have a tendency to
embrace new technolo1576 South Robb Way Lakewood, CO 80232
gy, they are called upon
(303) 986-2783 (303) 986-1593 Fax
http://www.geotech.org/survey/grdc.html
by the developers of
the PC software applications to be directly involved in beta-testop functionality, but further enables
ing, development and training. This not
members to stay on the leading edge of
only helps the software companies develtechnology.
GCAGS 48TH ANNUAL CONVENTION
Call For Papers at
the 1998 GCAGS
in Corpus Christi.
T
1998 GCAGS
Annual Convention
Corpus Christi, Texas
October 21-23, 1998
Abstract Deadline:
January 12,1998
For Camera-Ready Abstrad
Guidehes Contaci:
1998 GCAGS Abstracts
AAPG Convention Department
P.O.Box 979
Tulsa, OK 74101-0979
Gloria D Sprague
Frank G. Combh, OCACS
(512) 882-5750
( 5 q 884-7428
Jennifer Routy, GCSSEPM
(512) 9945746
he Gulf Coast Association of
Geological Societies (GCAGS) is
holding their 48th annual meeting in
Corpus Christi October 21-23,1998. The
theme will be "Bridging the Gulf: New
Growth to the New Millennium." Topics
planned include: 3-D case studies, structural styles, rejuvenated old plays, tectonic
framework of the Gulf, future groundwater reserves, modem depositional processes, depositional models, applied biostratigraphy and paleoecology, chronostratigraphy, and environmental concerns on
groundwater, wetlands and oillgas. Papers
are encouraged on these topics.
The manuscripts of oral presentations will
be published in an GCAGS Transactions
volume. Poster presentations will be
included as one page abstracts. Papers
should be prepared in "camera ready"
format.
Notification of acceptance occur by
February 20,1998. Completed papers
will be due April 1,1998.
GCAGS chairmen are Gloria D. Sprague,
Frank G. Cornish, Bob Travis and Jennifer
Prouty (SEPM). Abstracts are to mailed to
AAPG Convention Department,
PO.Box 979, Tulsa, OK, 74101-0979.
December 1997
.
i
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PROPRIETARY
AND
REGIONAL INTERPRETATIONS
Verticd@htegrated 3-0 Seismic
Consulthg Senices
Centrally coordinated 3-D design, processing, and
interpretation minimize project time frames.
Sequence Stratigraphy
2D and 3D Structure
Integrated Biostratigraphy
A "brain trust" of geoscientists with inkrnational
and domestic experience work a s a team to meet
your project requirements.
Goal oriented planning from inception achieves
superior costeffective project results.
II
II
In-house processing capabilities provided by
Coherence Technology Company.
"CM ~tsb help p u achieve your 3-0 project goals."
1010 Lamar Suite 1400 Houston. Texas 77002
(713) 650-9824 fax: (713) 654-3699
by
Experienced Rofessionals
0
I
1
BruceE. B o w n
Ii. Edward Denman
David J. Hall
RashelN.Rosltn
333 CL4E SUITE 3900 HOUSTON, TEXAS 77W2
far:(713) 739-7130
(713) 951-0853
Paleo Control, Inc.
Petroleum Paleontologists and Geologsts
ABSOCIATES, INC.
H.J.
HJ."BANK" GRUY
ARBITRATION
EXPERT TESTIMONY
RESERVOIR SIMULATION
EOUSl-UN:
DALLAS:
TWOAUENCENTER
1200 SMITH SlRBT,
SUITE3040
HOUSTON. TEXAS 77002
TELEPHONE: (7 13)739-1000
FAX: (713) 73% 112
PLAZA OF THE AMERICAS BLDG.
700 N. PEARL STREET, LB 332
SUITE 950
DALLAS, TEXAS 75201
TELEPHONE: (214)72@1900
FAX: (214) 720-1913
December 1997
Volume 40 Contents
Houston, Texas
71 3-849-0044
I
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QEOMAPn
COMPANY
Ndonwide Coverage
Homton's Most Comprehensive
Geological Data Center
Featuring National Coverage
We Pride Ourselves In Service
Our friendly research staff is always available for
your data search and retrieval.
Wedge International Tower
1415 Louisiana, Suite 2200
Tel: 713458-9573 / Fax: 7 13658-0187
www.herold.com
Contact Susan Neighbors, Manager
Palso Fibs (Avmllabk from
w Dams orno.)
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Aerom
Contact.
Phone.
Fax.
e-mall:
Web S ~ t e :
@
c Data
Jeff Rowe
(6 131731-9571
(613)731-0453
[email protected]
www geoterrex.ca
rotm-d#em
P ~ o n e r r ~ nGeo~crerrce
e
m
December 1997
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December
WORKSTATION-BASED GEOGRAPHICAL INFORMATION SYSTEMS I1
This course teaches students the basic ARCIINFO commands which create, edit, and produce geographic data. Topics include using
logical queries to create new data, changing existing data, producing maps, linking geographic data to external spreadsheets.
Prerequisite: knowledge of basic mapping techniques or instructor approval.
CGTTC 2C0 12 NN004 M/W
1211 - 12/17 6:00 p.m. - 10:00 p.m. WNSP 261
WORKSTATlON INTERPRETATION: SEISMIC MICRO TECHNOLOGY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .24 hours
Students will utilize 2dJ3dPAK seismic interpretation software to interpret a seismic data set on PC's. Students will interpret faults, horizons, create time slices, polygons, create various vertical seismic displays, and manipulate colors using a variety of workstation viewing
options and utility functions.
CGTTC 2E07 1 NNO 18 M/W
1211 - 12/17 600 p.m. - 10:00 p.m. CMED 207
PETROWORKS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24hours
This course will enable the student to view and edit well logs in a digital format; calculate lithology, porosity, permeability, water saturations, and other reservoir characteristics; generate cross plots of data; edit curve data; and generate various reports and displays using
Landmark Graphics PetroWorks package.
CGTTC 2K01 1 NN022 T/W/Th
1212 - 1214 8:00 a.m. - 5:00 p.m. WNSP 261
G1S:ERMAPPER . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24hours
ERMapper is a powerful package for processing satellite images, photographs, and seismic horizons into finished maps. The course will
teach basic commands to process several kinds of information including land and geophysical information. Both rasters and vectors will
be used in final displays, as well as converting between them. Geolinking is used in turning images into properly projected maps.
CGTTC 2C05 1 NN008 S
1216 - 12/20 8:00 a.m. - 5:00 p.m. WNSP 261
WORKSTATION INTERPRETATION: Z-MAP PLUS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 4 hours
This course will utilize ZYCOR software to explore the mapping of geophysical and geological data on a computer workstation. It will
cover mapping coordinate systems, projection types, importing of data files, gridding, Base map generation, contouring, editing and display techniques.
1216 - 12/20 8:00 a.m. - 5:00 p.m. WNSP 261 24 hours
CGTTC 2E061 NNOl5 S
...................................................................................
GEOGRAPHIX
24hours
Students will utilize GeoGraphix interpretation software to interpret a seismic data set on PC's. Students will interpret faults, horizons,
create time slices, polygons, create various vertical seismic displays, and manipulate colors using a variety of workstation viewing
options and utility functions.
CGTTC 2MOll NN027S
1216 - 12/20 8:00 a.m. - 5:00 p.m. CMED 207
WORKSTATION INTERPRETATION: GEOQUEST . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 4 hours
Students will utilize a UNIX workstation, GEOQUEST IEX-IESX and 3D seismic data to interpret faults and horizons, create time slices,
and contour maps using a variety of workstation viewing options and utility functions.
CGTTC 2E031 NN012 T/W/Th 12/16 - 12/18 8:00 a.m. - 5:00 p.m. WNSP 261
Academic Course
COMPUTER APPLICATIONS IN GEOLOGY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 hours
A semester-long workstation interpretation course featuring four weeks of UNIX, six weeks of GeoQuest IESX, and six weeks of
Landmark SeisWorks geophysical interpretation. Students learn basic UNIX commands and syntax. Students will also interpret two 3D
seismic prospects while learning the basic interpretation components of Landmark Graphic and GeoQuest interpretation software.
Evaluation is in the form of a written UNIX exam and interpretation skills tests.
GEOL 2404 12001
T/TH SpringIFall Semesters 6:30 p.m. - 9:20 p.m. WNSP 261
REGISTRATION and GENERAL COURSE INFORMATION: Community Education Registration Desk: 281-443-5600 Fax: .28 1443-5633
For course content or instructional software please contact: Sarah G. Stanley, coordinator Geoscience Technology Training Center, North
Harris College, 2700 W. W. Thorne Drive, Houston, Texas, 77073-3499, telephone:281-443-5715.
1
December 1997
41
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New In The USA
But Proven In The Industry
Discover what the European exploration
community has known for many years.
In the marine seismic processing market Ensign competes with the
integrated acquisition-based contractors and sets tihe standard in
terms of price, quality and turnaround.
For an alternative view from a major league player. contact our Houston office today.
N S GN
~ Geophysics (US)
10200 Richmond Avenue Suite 120 Houston TX 77042
Tel: (713) 780-1080 Fax: (713) 780-0919
December 1997
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ITPORf9
a"' ~eologicalservices
I-un
am mmnII1l
A rapid turnaround petrologic service has beeen initiated by Westport
for the Gulf Coast area to assist clients in real time
geologic evaluation of prospective reservoir intervals.
Seetion Analysis
Services includes: Thln
sEm hhr,r
X-ray DMraetion (bulk & clay)
The primary focus of this service is to provide a rapid description of diagenetic
components of concern during well completion procedures. For more
information concerning this new service contact:
Mike Dix at 281-560-3873
~
Pat Jacobs at 281-560-3272
NORCEN EXPLORER, INC.
DOW;rnIE
ENERGY, INC.
2 0 0 Westlake Park Blvd., Suite 800
(281) 558-661 1
Is seeking quality Guij Coast.
South Teuu and offshore pmpccts.
Close in, low to moderate risk Open acreage or ready to drill.
John W.Doughtie (713) 650-8646
1100 Louisiana Ste. 2910 Houston, TX 77002
Byron F. Dyer
Select by Block...
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1600 Smith St,Suite 4900
Houston. ?X 77002
Ph: (7 13) 659-220 1
Web: www.energygraphics.com
~
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Legislative Update
by James B. Bennett,
Government Affairs Committee
Registration of Geologists
Registration Task Force members met in
Dallas
with representative
Kent
Grusendorf (R-Arlington) on September
6, 1997, arranged by Larry Doyle, president of the AIPG, Texas section. The
meeting was preceded by a regular
AIPG Texas Section board meeting.
Representative Grusendorf is to be commended for agreeing to attend this meeting. He stated that he would be glad to
work with the task force for registration of
geologists and geophysicists in Texas.
Representative Grusendorf had raised a
point of order during the last week of the
1997 Texas legislative session causing
the "Registration of Geologists and
Geophysicists in Texas" bill to fail to
come to a vote on the floor, thereby killing
it for the 1997 legislative session. The bill
cannot be rescheduled until the Texas
Legislature convenes in a regular session
in January 1999.
At the meeting, Rep. Grusendorf initially
stated that as head of the House
Republican Caucus, it was the job of the
caucus to distinguish between "good"
bills and "bad" bills and that the Texas
Geoscience Registration bill was a bad
bill. He stated that it constrained trade
and represented a manifestation of too
much government, to which he is
opposed. He also stated that it would create a bureaucracy that would eventually
harm us. He was asked if this bill represented any more constraint to trade than
the Registration of Engineers and other
similar government licensed professional
entities. When asked if anything was
being done to rid the government of these
unnecessary licensed groups, he admitted
there was little difference to the engineers' registration and that virtually nothing was being done to reduce the size of
government along these lines.
44
EPA Update
With the new clean air standards imposed
by the Environmental Protection Agency
(EPA), studies have commenced in various regions of the United States to determine if states will be able to meet the new
standards over the next 10 years. In the
Washington, D.C., area, federal officials
began a three-year study in starting in
September of ozone levels from 16 monitoring stations throughout the area. The
new limit for ozone will be 80 parts per
billion as opposed to 120 parts per billion
for the old standards. A spokesman
for a Washington-based environmental
research group stated that it would be
unlikely for state governments to impose
restrictions on driving by the public, but
they would be likely to devise stricter auto
emissions tests. (Source: WashingtonPost
through the SIPES National Director)
Cars and Trucks
Auto emissions testing in Texas was
required as of January 1, 1997. Originally
begun in 1996 for a few weeks, the
requirement was delayed while questions
of propriety were settled as to who in the
state government guaranteed emission
testing operators a payout for the cost of
their testing equipment. Additionally a
recalibration for acceptable emissions
was made.
In the meantime, the American Automobile Association (AAA) reports that
cars and small trucks account for less than
one-third of smog-causing air pollution in
major cities. The AAA reported that a
study of air pollution in 24 major cities
shows that 70 percent of the chemicals
that cause smog comes from factories,
utilities smokestacks, refineries, and other
stationary sources. Perhaps this is illustrated by a singular phenomenon that
occurs in Houston, where from late spring
through the summer and into early fall
when the prevailing winds are primarily
southeasterly, the skyline is often obliterated by smog. When the first" northers"
come in, the smog clears away, presumably with the same number of automobiles entering the city. It is not likely that
air quality will improve significantly as a
result of mandatory testing of automobile
emissions, particularly when buses and
18- wheelers are exempt.
Government Agency Budgets
The Senate Appropriations Committee
passed the Interior and Related Agencies
spending bill with minor changes recommending $758.2 million for the U.S.
Geological Survey. This is $2.4 million
more than approved by the House, and
also $18.1 million above fiscal year 1997.
The bill also contains language to sell
$207 million worth of oil from the
Strategic Petroleum Reserve. The Independent Petroleum Association of
America (IEPAA) is working with several
senators on an amendment to block
this sale. (Source: AGI Government
Affairs Program)
The Senate also approved $6.98 billion
for the EPA which is $250 million less
than the House and $7.65 million less than
the President's request. Neither the House
nor the Senate approved extra money
requested for Superfund. Subcommittee
Chairman Kit Bond (R-MO) explained
the rationale as, "Given that the
Superfund program is sorely in need of
reform and reauthorization, with the GAO
designating it as a high risk program subject to fraud, waste and abuse, coupled
with budget restraints, a $700 million
increase could not be justified." (Source:
AGI Government Affairs Program)
Legislation to Note
President Clinton signed into law the
National Geologic Mapping Reauthorization Act of 1997 on August 5. The law
authorizes appropriations of $26 million
in FY 1998, $28 in FY 1999, and $30 million in FY 2000. The law further stipulates that not less than 20 percent of the
funds are to be allocated for state mapping
December 1997
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activities and not less than 2 percent for
educational mapping activities. (Source:
AGI Government Affairs Program)
In this Issue
industry to police itself against abuse by
monopolies. The code establishes five
standards designed to give customers fair
and equitable rates and services and it does
not require transporters to disclose the
terms of individual transportation contracts with producers.
Representative Wes Watkins (R-OK) introduced H.R. 1648, the National Energy
Security Act of 1997, on May 14, 1997.
Rep. Watkins explained the purpose of the
bill as "encouraging domestic oil and gas
production through a variety of tax incentives". The bill revises existing laws to
ensure producers can deduct ordinary and
necessary costs related to oil and natural
gas production. It eliminates the net
income limitation on percentage depletion,
includes a recovery tax credit and allows
deductions for geological and geophysical
expenses.
Several incentive bills were passed by the
Seventy-Fifth Texas Legislature. Bill
SB126lHB655 provides for a 10 year severance tax exemption on production from
wells being brought back on stream after
being inactive for at least two years. Bill
SB582kiB1179 extends a 50 percent severance tax exemption to qualifying
enhanced oil recovery projects that would
have expired at year's end. Governor
George W. Bush signed a law taking effect
September 1, 1997, that will give operators a 50 percent cut in the state's oil and
gas severance tax for sustained increased
production from oil and gas wells that previously produced less than the equivalent
of seven barrels of oil per day.
H.R. 2072, the Inactive Well Recovery
Act, was introduced by Representative
Mac Thornberry (R-TX) on June 26,1997.
This bill amends the Internal Revenue
Code to exclude from gross income and
the income attributable to independent
producer's oil from a recovered inactive
well.(Source: AGI Government Affairs
Program)
International Political Deals
As reported in the October 7, 1997 issue of
the Houston Chronicle, President Clinton
plans to sign an energy treaty with
Venezuela designed to expand cooperation
on renewable energy, energy efficiency,
and natural gas conversion projects.
President Clinton will also announce that
several hundred million dollars in export
financing loans from the Export-Import
Bank and the Overseas Private Investment
Corp. will be made to Venezuela. Officials
say these loans will help U.S. businesses
with energy-related contracts in Venezuela. Venezuela which is the United
States' largest foreign supplier of oil,
delivers about 1.4 million barrels of oil a
day. This is 51 1 million barrels of oil per
The Texas Railroad Commission unanimously adopted the Natural Gas
Transportation Standards and Code of
Conduct in August 1997. Railroad
Commissioner Barry Williamson proposed the code more than a year ago and
Texas is the first state to adopt such a code
since the Federal Energy Regulatory
Commission made the decision not to
exercise jurisdiction over gathering
systems that had been spun off from interstate pipelines.
Commissioner Williamson stated the goal
is to establish a system that will allow
Volume 40 Contents
year. Based on a hypothetical cost of $20
per barrel, this is $10.2 billion dollars a
year. The article also reports that the stateowned company Petroleos de Venezuela
SA is expected to invest about $10 billion
in the United States this year and an additional $20 billion next year. The article did
not state how or in what form these investments would be made.
An article by Tad Szulc appearing in the
Chronicle on the same day about the
impact that China is going to have on the
global oil market is worth partially repeating. The article stated that China is now
the world's second largest energy consumer. Predictions by the U.S. Department
of Energy are that Chinese consumption
will rise from 3.3 million barrels a day in
1996 to 4.6 million in 2000, and by 2015
China will have the highest consumption
in the world at 10.5 million barrels a day.
The article reports that China plans to
spend $ 100 billion annually over the next
20 years to expand domestic production of
oil. It seems reasonable to assume that
China will also become one of the top
competitors for the discovery and development of the world's hydrocarbon deposits.
That's all from the quarterly legislative
committee report. Data for this article
were compiled from several sources.
Special thanks are due to C. Ray Scurlock
and Victor L. Cooper, SIPES National
Directors from Shreveport and Oklahoma
City, respectively.
PALEO-DATA, ZNC.
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New Orleans, LA 70124
(504) 488-3711 PHONE
FRANCIS S. PLAISANCE, JR.
ARTHUR S. WATERMAN
MICHAEL W. CENTER
WELL ANALYSIS-DATABASE
December 1997
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ALBERT F. PORTER, JR.
NORMAN S. VALLETTE
WILLIAM H. McKEE
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ELLINGTON & ASSOCIATES, INC.
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A A PG
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and Managernenl
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SIPES
=w-Em==dG-e#5
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Steve H. Hill
ViRddent-olicfceda@
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Hauton. T k u 7'1042
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Far: (713) 974-3687
dlandtrOscqc-ur.ccm~l.compuaerve.eom
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Check out Cambe at
www.cambe.com
When looking for petroleum information on the Internet, check out
www.cambe.com. With new well log listings updated monthly and
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