On: “3-D seismic imaging and seismic attribute analysis of genetic sequences deposited in low‐ accommodation conditions” (B. A. Hardage, D. L. Carr, D.E. Lancaster, J. L. Simmons Jr., D. S. Hamilton, R. Y. Elphick, K. L. Oliver, and R. A. Johns, GEOPHYSICS, 61, 1351–1362)

The paper deals with the results of a multidisciplinary study of the Bend Conglomerate (Middle Pennsylvanian fluvio‐deltaic clastics) in a portion of Boonsville gas field in the Fort Worth Basin of North‐Central Texas, especially with those related to the Caddo sequence, at the top of the Bend Conglomerate. The purpose of the study was “to determine how modern geophysical, geological, and engineering techniques could be combined to understand the mechanisms by which fluvio‐deltaic depositional processes create reservoir compartmentalization in a low‐ to moderate‐accommodation basin.” According to Hardage et al. (1996), complexly arranged key chronostratigraphic surfaces are major controls on compartmentalization and architecture of reservoirs. These key chronostratigraphic surfaces are flooding surfaces, maximum flooding surfaces, and erosion surfaces.

Download Full-text

3-D seismic evidence of the effects of carbonate karst collapse on overlying clastic stratigraphy and reservoir compartmentalization

Geophysics ◽

10.1190/1.1444057 ◽

1996 ◽

Vol 61 (5) ◽

pp. 1336-1350 ◽

Cited By ~ 51

Author(s):

B. A. Hardage ◽

D. L. Carr ◽

D. E. Lancaster ◽

J. L. Simmons ◽

R. Y. Elphick ◽

...

Keyword(s):

Karst Collapse ◽

Seismic Profiles ◽

Gas Field ◽

Cross Sectional ◽

Fort Worth Basin ◽

Vertical Seismic Profiles ◽

Valley Fill ◽

Depositional Processes ◽

Reservoir Compartmentalization ◽

Central Texas

A multidisciplinary team, composed of stratigraphers, petrophysicists, reservoir engineers, and geophysicists, studied a portion of Boonsville gas field in the Fort Worth Basin of north‐central Texas to determine how modern geophysical, geological, and engineering techniques can be combined to understand the mechanisms by which fluvio‐deltaic depositional processes create reservoir compartmentalization in a low‐ to moderate‐accommodation basin. An extensive database involving well logs, cores, production, and pressure data from more than 200 wells, [Formula: see text] [Formula: see text] of 3-D seismic data, vertical seismic profiles (VSPs), and checkshots was assembled to support this investigation. We found the most important geologic influence on stratigraphy and reservoir compartmentalization in this basin to be the existence of numerous karst collapse chimneys over the [Formula: see text] [Formula: see text] area covered by the 3-D seismic grid. These near‐vertical karst collapses originated in, or near, the deep Ordovician‐age Ellenburger carbonate section and created vertical chimneys extending as high as 2500 ft (610 m) above their point of origin, causing significant disruptions in the overlying clastic strata. These karst disruptions tend to be circular in map view, having diameters ranging from approximately 500 ft (150 m) to as much as 3000 ft (915 m) in some cases. Within our study area, these karst features were spaced 2000 ft (610 m) to 6000 ft (1830 m) apart, on average. The tallest karst collapse zones reached into the Middle Pennsylvanian Strawn section, which is some 2500 ft (760 m) above the Ellenburger carbonate where the karst generation began. We used 3-D seismic imaging to show how these karst features affected the strata above the Ellenburger and how they have created a well‐documented reservoir compartment in the Upper Caddo, an upper Atoka valley‐fill sandstone that typically occurs 2000 ft (610 m) above the Ellenburger. By correlating these 3-D seismic images with outcrops of Ellenburger karst collapses, we document that the physical dimensions (height, diameter, cross‐sectional area) of the seismic disruptions observed in the 3-D data equate to the karst dimensions seen in outcrops. We also document that this Ellenburger carbonate dissolution phenomenon extends over at least 500 mi (800 km), and by inference we suggest karst models like we describe here may occur in any basin that has a deep, relatively thick section of Paleozoic carbonates that underlie major unconformities.

Download Full-text

3-D seismic imaging and seismic attribute analysis of genetic sequences deposited in low‐accommodation conditions

Geophysics ◽

10.1190/1.1444058 ◽

1996 ◽

Vol 61 (5) ◽

pp. 1351-1362 ◽

Cited By ~ 19

Author(s):

B. A. Hardage ◽

D. L. Carr ◽

D. E. Lancaster ◽

J. L. Simmons ◽

D. S. Hamilton ◽

...

Keyword(s):

Seismic Data ◽

Sediment Accumulation ◽

Gas Reservoirs ◽

Seismic Attribute ◽

Gas Field ◽

Reservoir System ◽

Depositional Processes ◽

Genetic Sequences ◽

Data Windows ◽

Reservoir Facies

A multidisciplinary team, composed of stratigraphers, petrophysicists, reservoir engineers, and geophysicists, studied a portion of Boonsville gas field in the Fort Worth Basin of North‐Central Texas to determine how modern geophysical, geological, and engineering techniques could be combined to understand the mechanisms by which fluvio‐deltaic depositional processes create reservoir compartmentalization in a low‐ to moderate‐accommodation basin. An extensive database involving well logs, cores, production, and pressure data from 200‐plus wells, [Formula: see text] [Formula: see text] of 3-D seismic data, vertical seismic profiles (VSPs), and checkshots was assembled to support this investigation. The reservoir system we studied was the Bend Conglomerate, a productive series of gas reservoirs composed of Middle Pennsylvanian fluvio‐deltaic clastics 900 to 1300 ft (275 to 400 m) thick in our project area. We were particularly interested in this reservoir system because evidence suggested that many of the sequences in this stratigraphic interval were deposited in low‐accommodation conditions (that is, in an environment where there was limited vertical space available for sediment accumulation), and our objective was to investigate how fluvio‐deltaic reservoirs were compartmentalized by low‐accommodation depositional processes. Using an extensive well log database (200 plus wells) and a core‐calibrated calculation of rock facies derived from these logs, we divided the Bend Conglomerate interval into ten genetic sequences, with each sequence being approximately 100 ft (30 m) thick. We then used local VSP and checkshot control to transform log‐measured depths of each sequence boundary to seismic two‐way time coordinates and identified narrow seismic data windows encompassing each sequence across the [Formula: see text] [Formula: see text] 3-D seismic grid. A series of seismic attributes was calculated in these carefully defined data windows to determine which attributes were reliable indicators of the presence of productive reservoir facies and which attributes could, therefore, reveal distinct reservoir compartments and potentially show where infield wells should be drilled to reach previously uncontacted gas reservoirs. Our best success was the seismic attribute correlations we found in the Upper and Lower Caddo sequences, at the top of the Bend Conglomerate. These sequences were deposited in a low‐accommodation setting, relative to other Boonsville sequences, and we found that reflection amplitude and instantaneous frequency, respectively, were reliable indicators of the areal distribution of reservoir facies in these low‐accommodation sequences.

Download Full-text

Surface-Bounded ReservoIr Compartmentalization in the Caddo Conglomerate, Boonsville (Bend Conglomerate) Gas Field, Fort Worth Basin, Texas: ABSTRACT

AAPG Bulletin ◽

10.1306/64eda6d6-1724-11d7-8645000102c1865d ◽

1996 ◽

Vol 80 ◽

Author(s):

David L. Carr, Kenneth L. Oliver

Keyword(s):

Fort Worth ◽

Gas Field ◽

Fort Worth Basin ◽

Reservoir Compartmentalization

Download Full-text

Warping prestack imaged data to improve stack quality and resolution

Geophysics ◽

10.1190/1.2829986 ◽

2008 ◽

Vol 73 (2) ◽

pp. P1-P7 ◽

Cited By ~ 5

Author(s):

Gabriel Perez ◽

Kurt J. Marfurt

Keyword(s):

Vertical Component ◽

Vertical Position ◽

Fort Worth ◽

Seismic Attribute ◽

Prestack Migration ◽

Fort Worth Basin ◽

Attribute Analysis ◽

Recent Developments ◽

Land Survey ◽

Corrected Data

Accurate seismic imaging requires that a geologic feature be located at the same lateral and vertical position in images obtained by 3D prestack migration from different data bins, such as common-offset or common-angle subvolumes. Misalignment of those images degrades the quality of the stack. For dipping reflectors and lateral discontinuities, imperfect imaging causes both lateral and vertical misalignment. In current practice, the vertical component of the misalignment is used to estimate updates in velocity and other imaging parameters; the lateral component is largely ignored. We show that recent developments in seismic-attribute analysis allow us to examine the lateral misalignment of prestack volumes with similar resolution to that achieved in examining vertical moveout. To measure lateral moveout, we pick maxima from local 2D crosscorrelations computed between slices from 3D attribute volumes. We then use these measurements to correct for the lateral misalignment by applying a warping procedure to the corresponding slices in the prestack migrated seismic data. We apply our technique to a 3D land survey acquired over the Fort Worth basin in Texas, and obtain subtle, but potentially important, improvements in the quality and resolution of the stack as well as in the attribute images computed from the corrected data.

Download Full-text

Study of fault configuration related mysteries through multi seismic attribute analysis technique in Zamzama gas field area, southern Indus Basin, Pakistan

Geodesy and Geodynamics ◽

10.1016/j.geog.2016.04.002 ◽

2016 ◽

Vol 7 (2) ◽

pp. 132-142 ◽

Cited By ~ 1

Author(s):

Shabeer Ahmed Abbasi ◽

Shazia Asim ◽

Sarfraz Hussain Solangi ◽

Fareed Khan

Keyword(s):

Indus Basin ◽

Seismic Attribute ◽

Gas Field ◽

Attribute Analysis ◽

Analysis Technique ◽

Field Area

Download Full-text

Enhanced delineation of reservoir compartmentalization from advanced preand post-stack seismic attribute analysis

First Break ◽

10.3997/1365-2397.32.3.73897 ◽

2014 ◽

Vol 32 (3) ◽

Author(s):

Clark Chahine ◽

Leigh Truelove ◽

Mauricio Herrera Volcan

Keyword(s):

Seismic Attribute ◽

Attribute Analysis ◽

Reservoir Compartmentalization

Download Full-text

THE INTEGRATION OF MODERN TECHNOLOGY IN GIPPSLAND'S CENTRAL FIELDS STUDY

The APPEA Journal ◽

10.1071/aj93041 ◽

1994 ◽

Vol 34 (1) ◽

pp. 513

Author(s):

P.V.Hinton P.V.Hinton ◽

M.G.Cousins ◽

P.E.Symes

Keyword(s):

Seismic Data ◽

Field Performance ◽

Simulation Models ◽

Modern Technology ◽

Depositional Environments ◽

Seismic Attribute ◽

Sequence Stratigraphic ◽

Multidisciplinary Study ◽

Attribute Analysis ◽

Definition Of

The central fields area of the Gippsland Basin, Australia, includes the Halibut, Cobia, Fortescue, and Mackerel oil fields. These large fields are mature with about 80% of the reserves produced. During 1991 and 1992 a multidisciplinary study, integrating the latest technology, was completed to help optimise the depletion of the remaining significant reserves.A grid of 4500 km of high resolution 3D seismic data covering 191 square kilometres allowed the identification of subtle structural traps as well as better definition of sandstone truncation edges which represent the ultimate drainage points. In addition, the latest techniques in seismic attribute analysis provided insight into depositional environments, seal potential and facies distribution. Sequence stratigraphic concepts were used in combination with seismic data to build complex multi million cell 3D geological models. Reservoir simulation models were then constructed to history match past production and to predict future field performance. Facility studies were also undertaken to optimise depletion strategies.The Central Fields Depletion Study has resulted in recommendations to further develop the fields with about 80 work-overs, 50 infill wells, reduction in separator pressures, and gas lift and water handling facility upgrades. These activities are expected to increase ultimate reserves and production. Some of the recommendations have been implemented with initial results of additional drilling on Mackerel increasing platform production from 22,000 BOPD to over 50,000 BOPD. An ongoing program of additional drilling from the four platforms is expected to continue for several years.

Download Full-text

COOL-WATER CARBONATE FACIES PATTERNS AND DIAGENESIS-THE KEY TO THE GIPPSLAND BASIN 'VELOCITY PROBLEM'

The APPEA Journal ◽

10.1071/aj97007 ◽

1998 ◽

Vol 38 (1) ◽

pp. 137 ◽

Cited By ~ 8

Author(s):

D.A. Feary ◽

T.S. Loutit

Keyword(s):

Submarine Canyon ◽

Velocity Variation ◽

Carbonate Facies ◽

Seismic Attribute ◽

Seismic Reflection Data ◽

Cool Water ◽

Depositional Processes ◽

Attribute Analysis ◽

Gippsland Basin ◽

Water Carbonate

Throughout much of the exploration history of the offshore Gippsland Basin it has been difficult to achieve acceptable accuracy or precision for time-depth conversions beneath the stratigraphically and sonically complex Seaspray Group, overlying exploration targets within the hydrocarbon-rich Latrobe Group. A regional seismic stratigraphic and seismic attribute analysis of the Oligocene-Recent Seaspray Group has been carried out as the first step towards resolving this long-standing Gippsland Basin 'velocity problem'.High-resolution 2D seismic reflection data and downhole logs were used to determine the depositional history and sequence characteristics of the Seaspray Group. This analysis was based on the premise that velocity variation must be related to, or controlled by, the nature and distribution of the dominantly cool-water carbonate facies of the Seaspray Group, and that solution of the velocity problem must be based on understanding the particular depositional and geochemical characteristics of cool-water carbonates.Detailed seismic stratigraphic analysis of the G92A dataset shows that the 16 unconformity-bounded seismic sequences within the Seaspray Group form four mega-sequences, each separated by major erosional (channel-cutting) events, with sequences reflecting variable sediment inputs from northeasterly and southwesterly sources. Seaspray Group characteristics result from interaction of complex depositional and post-depositional processes, including river incision, submarine canyon erosion, slumping, subaerial exposure, karstification, and subsurface diagenesis and erosion. Seismic attribute analysis records the variability of diagenesis and shows that diagenetic effects are predominantly concentrated along sequence boundaries, sometimes to significant depths below the sequence boundary.Results to date indicate that application of a velocity model based on this new interpretation will enable improved precision of depth estimates to the top Latrobe Group unconformity to less than five per cent.

Download Full-text