3d seismic and well log data set stratton field
TRANSCRIPT
3-D SElsrviic
AND
WELL LOG
DATA SET
Fluvial Reservoir Systems Stratton Field,
South Texas
Raymond A. Levey, Bob A. Hardage, Rick Edson, and Virginia Pendleton
Bureau of Economic Geology W. L. Fisher, Director
The University of Texas at Austin Austin, Texas 78713-7508
sri Gas Research Institute
DOE U.S. Department
of Energy 1994
LEGAL NOTICE This seismic and well log data set was prepared by the Bureau of Economic
Geology as an account of work sponsored by the Gas Research Institute (GRI). Neither GRI, members of GRI, nor any person acting on behalf of either
a. Makes any warranty or representation, express or implied, with respect to the accuracy, completeness, or usefulness of the information contained in this seismic and well log data set, or that the use of any information, apparatus, method, or process disclosed in this seismic and well log data set may not infringe privately owned rights, or
b. Assumes any liability with respect to the use of, or for any and all damages resulting from the use of, any information, apparatus, method, or process disclosed in this seismic and well log data set.
This technology transfer product contains the following:
• Text describing the geologic framework, seismic acquisition parameters, data volumes, and installation instructions.
• An 8-mm tape with a SEGY-formatted 3-D seismic data volume for 2 mie.
• A 3.5-inch disk with 24 ASCII-formatted data files.
C ONTENTS
Purpose 1
Introduction 1
Geologic framework 3
Regional structural and stratigraphic setting of South Texas 3
Structural and stratigraphic setting of Stratton field 6
Reservoir characterization of the 3-D seismic and
well log data area 9
Reserve growth in fluvial reservoirs of Stratton field 10
Seismic acquisition parameters 11
Binning 11
Data processing 11
Data volumes 13
3-D seismic data set 13
Well log data set 14
Vertical seismic profile (VSP) calibration data 19 Installation instructions 28
3.5-inch disk 28
8-mm tape 28
Acknowledgments 29
References 29
iii
FIGURES
1. Depositional dip-oriented cross section through the Texas Gulf Coast Basin illustrating the relative position of major sand depocenters 3
2. Chronostratigraphic and lithostratigraphic chart showing the relative rank of the volume of gas produced in the major Cenozoic depositional episodes of the onshore Gulf Coast Basin 4
3. Location map showing the outline of FR-4 gas play and position of Stratton—Agua Dulce field, Nueces and Kleberg Counties, Texas 5
4. Depositional framework of the Frio Formation 6 5. Subregional dip-oriented reflection seismic line through Stratton field
showing the rotation of fault blocks in the lower Frio and Vicksburg Formations 7
6. Reservoir nomenclature of the Vicksburg and Frio Formations in the Stratton—Agua Dulce field complex, Nueces and Kleberg Counties, Texas 8
7. Map of receiver-array geometry used to create uniform ground coverage along each receiver line and side and map views of vibrator source array and pad positions 12
8. Location of well and seismic lines in the 2-mi2 study area 13 9. Calibration of reservoirs using the vertical seismic profile in
well no. 9 15
TABLES
1. Well log types for the 21 wells in the data set 14 2. Depths and seismic two-way times of 10 middle Frio reservoir
horizons in 21 wells 16 3. Time-versus-depth calibration determined from vertical seismic
profile in well no. 9 20
iv
PURPOSE
This seismic and well log data set is part of a technology transfer program conducted by the Bureau of Economic Geology on behalf of the Gas Research Institute and the U.S. Department of Energy. This product provides a versatile data set that can be used for testing hardware and software products, training individuals in the use of 3-D seismic data and well log information, and ultimately illustrating the complex stratigraphy and structure of natural gas reservoirs. This technology transfer product is intended to assist gas operators and contractors in developing the skills and tools to deploy technologies that will ensure an adequate supply of natural gas resources at competitive prices. This 3-D seismic and well log data set is from Stratton field in South Texas.
INTRODUCTION A diverse and vast resource base of 1,295 Tcf of technically recoverable
natural gas resources (including proved reserves, conventional resources, and nonconventional resources) is estimated by a recent analysis of domestic petroleum supplies by the National Petroleum Council (1992). Of this resource base, 230 Tcf is predicted to be recoverable by reserve appreciation from conventional and tight gas reservoirs in the lower 48 states. The integrated application of concepts and cost-effective technologies from the disciplines of geology, engineering, geophysics, and petrophysics will be required to convert these natural gas resources into producible reserves.
In the last decade, characterization of the internal geometry of reservoirs, mainly oil reservoirs, has demonstrated a higher degree of compartmentaliza-tion than previously recognized. Nonstructural compartmentalization is primarily a function of the depositional system and, secondarily, of the dia-genetic history of the reservoir. The research objective of the Bureau of Economic Geology infield reserve growth project is to define the potential for incremental gas recovery through better understanding of depositional and diagenetic heterogeneity within nonassociated natural gas reservoirs.
Keywords: Agua Dulce field, data set, fluvial environment, seismic survey, Stratton field, three-dimensional seismic, vertical seismic profile (VSP), vibroseis, Vicksburg, well log
1
Addition of natural gas resources from reserve growth and reserve appreciation in conventional reservoirs have multiple components. Historically, industry has added infield reserves by extensions and deeper pool drilling. Recompletions of existing wells were often made without considering the concepts of reservoir heterogeneity or compartmentalization. Where significant geologic variation occurs, untapped, incompletely drained, or bypassed reser-voir compartments remain to be drained of natural gas by the drilling of new strategically placed infield wells or by selective recompletions in existing wells. Future infield reserve growth will be based on an understanding of vertical and lateral heterogeneity that leads to recompletions in bypassed and incom-pletely drained reservoirs. In addition to concepts of reservoir heterogeneity and compartmentalization, new surface and downhole tools are being developed that will enhance the operator's ability to define resource targets with greater precision and reliability. Surface 3-D seismic is one of the readily available state-of-the-art technologies for imaging stratigraphically and structurally complex reservoirs.
An increasing trend in the lower 48 states is the reexploration and redevelopment of large known fields with an existing infrastructure. The viability of this trend has important implications for our future domestic gas supply as both major companies and independents seek to recover the sub-stantial remaining gas resources identified in the resource assessment completed by the National Petroleum Council (1992). Evaluation of natural gas resources is part of a continuing research initiative at the Bureau of Economic Geology focusing on strategies to maximize the potential for natural gas production in the lower 48 states.
The Secondary Natural Gas Recovery: Targeted Technology Applications for Infield Reserve Growth research project is a joint venture sponsored by the Gas Research Institute, the U.S. Department of Energy, and the State of Texas through the Bureau of Economic Geology at The University of Texas at Austin, with co-funding and cooperation of the natural gas industry. This project is a field-based program using a multidisciplinary approach that integrates geology, geophysics, engineering, and petrophysics. A major objective of this project is to develop, test, and verify those technologies and methodologies that have near- to mid-term potential for maximizing gas recovery from conventional reservoirs in known fields. Siliciclastic natural gas reservoirs, which yield 50 percent of the cumulative natural gas production in the Gulf Coast Basin of Texas, are targeted as data-rich field-based models for evaluating infield development.
2
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GEOLOGIC FRAMEWORK
REGIONAL STRUCTURAL AND STRATIGRAPHIC
SETTING OF SOUTH TEXAS
The Oligocene Frio Formation is one of the major progradational off-lapping stratigraphic units in the northwest Gulf Coast Basin (fig. 1). The Frio Formation is a sediment-supply-dominated depositional sequence characterized by rapid deposition and high subsidence rates (Galloway and others, 1982; Morton and Galloway, 1991). The thickness of the Frio Formation ranges from less than 2,000 ft near the Vicksburg Fault Zone to greater than 9,000 ft down-dip toward the central part of the Rio Grande Embayment. The Rio Grande Embayment was one of several entry points for major river systems that drained into the ancestral Gulf of Mexico. The structural style of the Rio Grande Embayment is characterized by discontinuous belts of strike-parallel growth faults, deep shale ridges and massifs, and underlying salt that is thin or absent (Galloway and others, 1982). The Oligocene Frio Formation of Texas is volumetrically the largest gas-productive interval of 10 major depositional stratigraphic packages in the Cenozoic Gulf Coast Basin (fig. 2).
Figure 1. Depositional dip-oriented cross section through the Texas Gulf Coast Basin illustrating the relative position of major sand depocenters (from Bebout and others, 1982).
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The middle Oligocene section was deposited during the Catahoula-Frio depositional episode described by Galloway (1977). The entire Frio Formation is divided into 10 gas plays on the basis of regional variations in structure and
depositional setting (Kosters and others, 1989). The Frio Fluvial/Deltaic Sandstone play along the Vicksburg Fault Zone (gas play FR-4 from Kosters and others, 1989) is ranked as the third largest of all 73 gas plays in Texas (fig. 3). Gas play FR-4 is the largest of all nonassociated gas plays in the Gulf Coast; cumulative production had exceeded 12 Tcf as of January 1, 1991. Hydrocarbon trapping in reservoirs of the FR-4 gas play is controlled by a combination of structural and stratigraphic factors, including faulted anticlinal closure, facies change, and reservoir pinch-out (Kosters and others, 1989). Most of the gas production in the FR-4 play is from middle Frio reservoirs. These reservoirs in Stratton field are part of the Gueydan fluvial system (fig. 4), updip from the Norias delta system (Galloway and others, 1982).
Figure 3. Location map showing the outline of FR-4 gas play and position of Stratton—Agua Dulce field, Nueces and Kleberg Counties, Texas.
5
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Figure 4. Depositional framework of the Frio Formation (from Galloway and others, 1982).
STRUCTURAL AND STRATIGRAPHIC SETTING
OF STRATTON FIELD
The 3-D seismic and well log data set is from Stratton field, which lies near the northern limit of the FR-4 gas play (fig. 4). Variation in the structural framework of Frio and Vicksburg reservoirs in Stratton field is illustrated by a structural dip-oriented seismic line crossing the Vicksburg Fault Zone and extending across the study area (fig. 5). Structural attitude of the gas reservoirs in the Vicksburg and lower Frio Formations is affected by a series of normal faults that sole out into the Vicksburg detachment zone within the Jackson Shale. The relatively undeformed and flat-lying middle and upper Frio Forma-tion is structurally much simpler than the underlying Vicksburg and lower Frio, which show the effects of structural rotation above the Vicksburg décollement surface, including antithetic faulting. The middle and upper Frio are character-ized by a relatively gentle north-to-south-elongated subsurface domal closure.
Analysis of both well log correlations and 2-D reflection seismic data indicates that only a few faults extend upward into the middle Frio and that the amount of fault throw in the middle Frio is usually small and fault block rotation minimal. A large part of the middle and upper Frio is relatively undeformed across Stratton field (fig. 5). A type log for Stratton field illustrates the distinct stratigraphic variation between the Vicksburg and Frio Formations (fig. 6).
6
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Figure 5. Subregional dip-oriented reflection seismic line through Stratton field showing the rotation of fault blocks in the lower Frio and Vicksburg Formations. This faulting contrasts sharply with the lack of faulting in the middle and upper Frio Formation.
Analysis of conventional electric wireline logs (spontaneous potential [SP] and resistivity) indicates that the middle Frio contains multiple stacked pay sandstones within a series of vertically stacked reservoir sequences referred to as the B-, C-, D-, E-, and F-series reservoirs (descending stratigraphic order). Reservoir facies of the middle Frio examined in core and borehole images and calibrated to well logs are interpreted as multiple amalgamated fluvial channel-fill and splay sandstones. Channel-fill deposits range from 10 to 30 ft in thickness and show either an upward-fining or a blocky SP log profile. Lateral splay deposits commonly range from less than 5 ft to as much as 20 ft in thickness. The SP log of splay deposits has a classic upward-coarsening textural profile. The lower Frio Formation in the south part of Stratton field occurs at depths between approximately 7,000 and 7,400 ft subsea. These
7
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Figure 6. Reservoir nomenclature of the Vicksburg and Frio Formations in the Stratton-Agua Dulce field complex, Nueces and Kleberg Counties, Texas (modified from Kling, 1972). Ten middle Frio reservoir horizons in table 2 are shown here in larger type; other reservoirs are shown in smaller type.
QAa6266c
SP Res
sandstones range from 5 to 15 ft in thickness and show an upward-coarsening profile on the SP log. These lower Frio Formation sandstone packages are interpreted as lower coastal plain to inner shelf deposits (Kerr, 1990) and are probably related to the Norias wave-dominated delta system delineated by Galloway and others (1982). Correlation of fieldwide resistivity and conduc-tivity markers across Stratton field indicates that these sandstone packages are equivalent to the G-series reservoirs (fig. 6).
8
The Vicksburg Formation contains siliciclastic intervals with SP and gamma-ray logs indicative of upward-coarsening grain-size profiles consistent with deltaic-dominated depositional systems. Genetic stratigraphic analysis by
Han (1981), Han and Scott (1981), and Langford and others (in press) identi-
fied variations in delta morphology within the middle and upper Vicksburg Formation that are thought to represent mostly dip-oriented fluvial-dominated deltas. These sandstones in the upper Vicksburg Formation are commonly greater than 20 ft in thickness (up to 80 ft thick) and show a distinctive upward-coarsening SP log profile, representative of progradational deltaic depositional environments.
RESERVOIR CHARACTERIZATION OF
THE 3-D SEISMIC AND WELL LOG DATA AREA
This seismic and well log data set focuses on natural gas reservoirs in the middle Frio Formation. Reservoir facies of the middle Frio fluvial strata are channel-fill and associated crevasse-splay sandstones. Criteria for identifying these channel-fill and splay deposits from well logs and cores were described by Jirik (1990), Kerr (1990), and Kerr and Jirik (1990). Several giant gas fields (cumulative production more than 1.5 Tcf) that are part of this play include Seeligson and the Stratton—Agua Dulce field complex. Geologic analysis of middle Frio reservoirs in these fields shows that composite channel-fill deposits are as much as 30 ft thick and 2,500 ft wide and probably occur in long linear belts (Kerr and Jirik, 1990). Splay deposits in the middle Frio are up to 20 ft thick and are proximal to channel systems (Kerr, 1990). Porosities in these fluvial reservoirs range from 15 to 25 percent, with air permeabilities of less than 1 to greater than 4,000 md.
Analysis of 3-D seismic imagery and multiple well tests were used to investigate reservoir compartment boundaries identified by geologic, engineer-ing, and formation evaluation techniques. Data volume flattening and seiscrop slicing above and below reference horizons were used to reveal depositional topography and to determine the extent of structural influence on reservoir horizons. Seiscrop imagery and well log analysis have revealed fluvial channels as narrow as 200 ft and as thin as 10 ft at depths as great as 6,750 ft. Some reservoir compartment boundaries were seismically imaged within individual channel systems. Because many of these gas reservoirs are only 10 to 15 ft thick and occur within seismic time windows as thin as 2 to 4 milli-seconds (ms), careful calibration of subsurface stratigraphy with the surface
9
seismic response is required to accurately locate these narrow time windows in the reflection waveforms. This research has demonstrated that a properly calibrated 3-D seismic data volume provides a cost-effective tool for imaging fluvial reservoir topology in the interwell space.
Using pressure buildup test data in middle Frio fluvial reservoirs, project-designed well tests identified long and narrow drainage shapes. These channellike drainage shapes have an average width of 220 ft and range from a minimum of 50 ft to a maximum of 600 ft, matching the dimensions of narrow thin-bed reservoirs imaged on seiscrop slice maps. These well tests confirm geologically based reservoir characterization models and indicate that signif-icant incremental gas resources are trapped by reservoir compartments in fluvial-channel systems (Levey and others, 1992).
RESERVE GROWTH IN FLUVIAL RESERVOIRS
OF STRATTON FIELD
Analysis of reserve growth indicates more than 90 percent reserve replacement after 40 years of production and development across a large contiguous lease block in the south part of Stratton field (Sippel and Levey, 1991; Levey and others, 1993). Deeper pool drilling that was targeted for deltaic reservoirs in the lower Frio and Vicksburg Formations led to recogni-tion of the potential for higher density development of shallower intervals in the middle Frio. Historical analysis of reserve additions indicated that the fluvial reservoirs less than 7,000 ft deep resulted in most of the reserve appreciation. This reserve growth was achieved from the shallower, middle Frio reservoirs and is superior to that obtained by completions in the deeper reservoirs in the lower Frio and Vicksburg, both on a total gas volume basis and on a per-completion comparison. The contrast in gas production between reserves shallower than 7,000 ft and those deeper than 7,000 ft coincides with a major change in the structural and depositional setting in the study area. The middle Frio Formation reservoirs (<7,000 ft) are fluvially dominated; in contrast, the lower Frio and Vicksburg reservoirs (>7,000 ft) are in a predominantly deltaic setting that penetrates the top of geopressure. In addition, structurally rotated fault blocks are encountered in the lower Frio and Vicksburg below 7,000 ft. It is well recognized that drilling costs almost always increase when (1) drilling deeper wells, (2) penetrating geopressured intervals, and (3) drilling in struc-turally deformed intervals. Estimates of incremental recoverable gas range from less than 0.5 to 2.0 Bcf per reservoir completion in the middle Frio.
10
SEISMIC ACQUISITION
PARAMETERS
The 3-D source/receiver geometry consisted of east-west receiver lines spaced 1,320 ft apart and north-south source lines spaced 880 ft apart. Linear, 12-element receiver arrays were constructed so each array spanned 110 ft. The distance between the centers of adjacent arrays was 110 ft, which means there was a continuous ground coverage of uniformly spaced geophones along each receiver line (fig. 7). Vibrator points (VP's) were spaced at intervals of 220 ft. Six sweeps from four inline vibrators were summed at each VP. A linear, 8-120 Hz sweep rate was used, and the sweep length was 14 s. The four vibrators were stationed bumper to bumper with their pads separated 35 ft to create a source array 135 ft long. To minimize ground damage, the vibrators moved forward one pad width after each sweep. At each VP, the final positions of the 24 pad imprints created by the four-element, six-sweep summation were symmetrically distributed on each side of the source flag (fig. 7).
BINNING
The receiver spacing of 110 ft and the source spacing of 220 ft created an acquisition bin measuring 55 by 110 ft. After the 3-D data volume was stacked, the data were interpolated in the source line direction to create interpretation bins measuring 55 by 55 ft.
DATA PROCESSING
The major data processing steps were zero-phase correction of field records, prestack Q compensation to emphasize higher frequencies, surface consistent deconvolution and statics, iterative velocity analysis, stacking, and one-pass 3-D wave equation migration.
11
Ground positions of vibrator pads
1 1 1 1 1 1 1 1 1 1 1 1 1 2
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Figure 7. (a) Map of receiver-array geometry used to create uniform ground coverage along each receiver line. (b) Side view of the position and movement of the four-vibrator source array relative to the source flag as six sweeps were recorded to create the field record at each source point. Each rectangular box labeled "Vibr. l," and so forth, represents the vibrator vehicle. The vibrator pad is located near the center of each box. Vibrator movement between sweeps is from right to left. (c) Map view showing the pad positions of vibrators 1 through 4 relative to the source flag as six sweeps were recorded.
12
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DATA VOLUMES
All of the data volumes presented are from a 2-mie area in Stratton field.
The 3-D seismic grid and well locations are shown in figure 8.
100
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100
200
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Figure 8. Location of wells and seismic lines in the 2-mil study area. Vertical seismic profile (VSP) and calibration to the 3-D seismic are shown in figure 9. Seismic crosslines are numbered 1-200; seismic inlines are numbered 1-100. Well locations are numbered so that coordinates 0, 0 are at lower left corner and coordinates 10945, 5445 are at upper right corner.
3-D SEISMIC DATA SET
The migrated 3-D data volume is written in SEGY format. It comprises 100 inlines (oriented east-west) and 200 crosslines (oriented north-south). The crossline length is 3 s, and the sample rate is 2 ms. Crossline 1 of inline 1 lies in the southwest corner of the grid; crossline 200 of inline 100 defines the northeast corner of the grid. Trace spacing is 55 ft both from east to west and from north to south. The minimum (inline, crossline) _ (1, 1) position should be set at (x, y) coordinates (0, 0), and the maximum (inline, crossline) _ (100, 200) position should be at coordinates (x, y) _ (10945, 5445). The inline number is stored in bytes 9-12 of the trace header, and the crossline number is in bytes 13-16. The amplitude data are stored in 32-bit IBM floating-point format, and the maximum amplitude is 5715.
13
Table 1. Well log types for the 21 wells in the data set
with their abbreviations and units of measure.
Abbreviation Log name Units ASN amplified short normal ohm meters
CALIPER caliper inches
DEPTH depth feet
DRHO delta rho correction on grams per cubic centimeter density log
GR gamma ray American Petroleum Institute
GRD guard ohm meters
LLD induction log—deep ohm meters
ILM induction log—medium ohm meters
LAT lateral ohm meters
IN long normal ohm meters
MINV microinverse ohm meters
MNOR micronormal ohm meters
NPSS neutron porosity (sandstone porosity units matrix)
RHOB bulk density grams per cubic centimeter
RT true resistivity ohm meters
SFLU spherically focused log ohm meters
SGRD short guard ohm meters
SN short normal millivolts
SP spontaneous potential ohm meters
WELL LOG DATA SET
A total of 21 wells, including a vertical seismic profile, from the 2-mi2 area are provided in this data set on 3.5-inch disk. As is typical of many gas fields with a long production history, the log suites vary in the type of logging tools used and in the quality of the data acquired. A list of the abbreviations of various log types in the data set is shown in table 1. The depths of 10 dif-ferent middle Frio reservoir horizons (fig. 9) are provided for each of the 21 wells (table 2). These 10 reservoirs produce natural gas in Stratton field.
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18
VERTICAL SEISMIC PROFILE (VSP)
CALIBRATION DATA
A zero-offset vertical seismic profile (VSP) was recorded in well no. 9 in
the north-central part of the 3-D data volume (fig. 8). The energy source was a single vibrator, positioned 264 ft south of well 9, which generated a 10-120 Hz wavefield. The vibrator sweep was 14 s long and nonlinear so the high-frequency content to the wavefield would be emphasized. This wavefield was recorded by a downhole geophone in well 9, which was first positioned at a depth of 7,050 ft and then moved in increments of 40 ft up to an ending recording depth of 3,810 ft. The downgoing and upgoing seismic wavefields generated by the surface vibra-tor were recorded at each of these 40-ft stations.
These VSP data are critical for interpreting the 3-D data volume because they establish a precise correlation between stratigraphic depth and seismic travel time. To aid interpretation, the VSP information is provided in this data set in two forms: as time-versus-depth spreadsheets (table 3) and as a front corridor stack of the upgoing VSP wavefield (which will be referred to as the "zero-offset VSP image"). In a workstation environment, this zero-offset VSP image can be corre-lated with the 3-D data to confirm where each thin-bed reservoir is positioned in the 3-D reflection waveform. This VSP trace is written as file VSP_9.TXT imme-diately following the well log data files on the floppy disk. The file contains a single seismic trace (fig. 9, the zero-offset VSP image), which is 3 s long and sampled at 2 ms. A portion of this VSP image is compared with the 3-D data volume in figure 9 so those unfamiliar with VSP data can see how the VSP-to-3-D seismic correlation should appear.
19
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20
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21
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INSTALLATION INSTRUCTIONS
3.5-INCH DISK
To place the 21 digitized well logs, VSP data, and tables 2 and 3 on your DOS or Windows PC, you will need at least 6 megabytes of disk space. These 24 ASCII-formatted data files have been compressed into 1 file called BEG.ZIP on the disk. The INSTALL program on the disk will create a directory named C:\BEG and will copy the files from the disk to your hard drive and uncompress them.
Under DOS
type B:\INSTALL or
Under Windows select RUN from FILE under the PROGRAM MANAGER. type B:\INSTALL
8-MM TAPE
The following is a copy of the 3200-byte ASCII header file found on the 3-D seismic data tape. Use this header information to read and load this SEGY-formatted data set using your seismic interpretation software:
3-D Seismic Data Volume Bureau of Economic Geology The University of Texas at Austin 10100 Bumet Road, Bldg. 130 Austin, Texas 78758-4497 (512) 471-1534
This SEGY-formatted data volume consists of 100 inlines and 200 crosslines, or traces, of 2-ms data from 0 to 3 s. Inlines run east to west, and crosslines run north to south. Inline 1 and crossline 1 are in the southwest corner, Inline 100 and crossline 200 are in the northeast corner. The spacing between common depth points is 55 ft. Set the minimum (inline, crossline) = (1, 1) (x, y) location at (0,0) and maximum (inline, crossline) = (100, 200) (x, y) = (10945, 5445). The amplitude data are stored in 32-bit IBM floating point format. Maximum amplitude is 5715. The inline number is in bytes 9-12; the crossline number is in bytes 13-16.
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ACKNOWLEDGMENTS This 3-D seismic and well log data set was developed by the Bureau of
Economic Geology on behalf of the Gas Research Institute (GRI) and the U.S.
Department of Energy (DOE). The materials represent one of several products
from the joint venture "Secondary Natural Gas Recovery: Targeted Technology
Applications for Infield Reserve Growth" conducted by the Bureau of Economic
Geology (GRI contract No. 5088-212-1718 and DOE Contract No. DE-FG21-
88MC25031) and the State of Texas. The cooperation of Union Pacific Resources
Corporation is gratefully acknowledged. Funding for this 3-D seismic and well
log data set was provided by GRI Contract No. 5093-212-2630.
Jeffrey G. Paine, Daniel D. Schultz-Ela, Andrew R. Scott, and Bruno C. Vendeville reviewed the text. Tucker F. Hentz was the technical editor. Figures
were drafted by Joel L. Lardon under the direction of Richard L. Dillon. Editing
was by Susann Doenges. Word processing was by Susan Lloyd. Typesetting and design were by Margaret L. Evans.
REFERENCES Bebout, D. G., Weise, B. R., Gregory, A. R., and Edwards, M. B., 1982, Wilcox sand-
stone reservoirs in the deep subsurface along the Texas Gulf Coast; their po-tential for production of geopressured geothermal energy: The University of Texas at Austin, Bureau of Economic Geology Report of Investigations No. 117, 125 p.
Galloway, W. E., 1977, Catahoula Formation of the Texas Coastal Plain: depositional systems, composition, structural development, ground-water flow history, and uranium distribution: The University of Texas at Austin, Bureau of Economic Geology Report of Investigations No. 87, 59 p. 1989, Genetic stratigraphic sequences in basin analysis II: application to
northwest Gulf of Mexico Cenozoic basin: American Association of Petro-leum Geologists Bulletin, v. 73, no. 2, p. 143-154.
Galloway, W. E., Hobday, D. K., and Magara, Kinji, 1982, Frio Formation of the Texas Gulf Coast Basin—depositional systems, structural framework, and hydrocarbon origin, migration, distribution, and exploration potential: The University of Texas at Austin, Bureau of Economic Geology Report of Inves-tigations No. 122, 78 p.
Han, J. H., 1981, Genetic stratigraphy and associated growth structures of the Vicksburg Formation, South Texas: The University of Texas at Austin, Ph.D. disserta-tion, 162 p.
Han, J. H., and Scott, A. J., 1981, Relationship of syndepositional structures and del-tas, Vicksburg Formation (Oligocene), South Texas: Society of Economic Pa-leontologists and Mineralogists, Gulf Coast Section, Second Annual Research Conference, Program and Abstracts, p. 33-40.
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Jirik, L. A., 1990, Reservoir heterogeneity in middle Frio fluvial sandstones: case studies in Seeligson field, Jim Wells County, Texas: Gulf Coast Association of Geological Societies Transactions, v. 40, p. 335-352.
Kerr, D. R., 1990, Reservoir heterogeneity in the middle Frio Formation: case studies in Stratton and Agua Duke fields, Nueces County, Texas: Gulf Coast Associa-tion of Geological Societies Transactions, v. 40, p. 363-372.
Kerr, D. R., and Jirik, L. A., 1990, Fluvial architecture and reservoir compartmental-ization in the Oligocene middle Frio Formation, South Texas: Gulf Coast As-sociation of Geological Societies Transactions, v. 40, p. 373-380.
Kling, D., 1972, Type field logs in South Texas: volume I; Frio trend: Corpus Christi Geological Society, p. 92.
Kosters, E. C., Bebout, D. G., Seni, S. J., Garrett, C. M., Jr., Brown, L. F., Jr., Hamlin, H. S., Dutton, S. P., Ruppel, S. C., Finley, R. J., and Tyler, Noel, 1989, Atlas of major Texas gas reservoirs: The University of Texas at Austin, Bureau of Eco-nomic Geology, 161 p.
Langford, R. R, Grigsby, J. D., Collins, R. E., Sippel, M. A., and Wermund, E. G., in press, Reservoir heterogeneity and permeability barriers in the Vicksburg S reservoir, McAllen Ranch gas field, Hidalgo County, Texas: The University of Texas at Austin, Bureau of Economic Geology Report of Investigations.
Levey, R. A., Sippel, M. A., Langford, R. P., and Finley, R. J., 1992, Stratigraphic compartmentalization within gas reservoirs: examples from fluvial-deltaic res-ervoirs of the Texas Gulf Coast: Gulf Coast Association of Geological Societ-ies Transactions, v. 42, p. 227-235. 1993, Natural gas reserve replacement through infield reserve growth:
an example from Stratton field, onshore Texas Gulf Coast Basin, in Linnville, B., ed., Third International Reservoir Characterization Technical Conference, p. 943-954.
Morton, R. A., and Galloway, W. E., 1991, Depositional, tectonic and eustatic con-trols on hydrocarbon distribution in divergent basins: Cenozoic Gulf of Mexico case history: Marine Geology, v. 102, p. 239-263.
National Petroleum Council, 1992, NPC natural gas study, v. 2, Supply availability: Washington, D.C., variously paginated.
Sippel, M. A., and Levey, R. A., 1991, Gas reserve growth analysis of fluvial-deltaic reservoirs in the Frio and Vicksburg Formations located in the Stratton field, onshore Texas Gulf Coast Basin: Society of Petroleum Engineers, SPE 22919, p. 337-344.
Xue, L., and Galloway, W. E., 1990, High resolution, log-derived, genetic stratigraphic sequence profile of the Paleogene section, central Texas Gulf Coast; sequence stratigraphy as an exploration tool: concepts and practices in the Gulf Coast: I I th Annual Research Conference, Society of Economic Paleontologists and Mineralogists Foundation, Gulf Coast Section, p. 399-408.
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