Field appraisal with three‐dimensional seismic surveys offshore Trinidad

Geophysics ◽  
1982 ◽  
Vol 47 (2) ◽  
pp. 177-195 ◽  
Author(s):  
Robert M. Galbraith ◽  
Alistair R. Brown
Keyword(s):  
Three Dimensional ◽  
Seismic Survey ◽  
Seismic Surveys ◽  
Multiple Attenuation ◽  
Fault Block ◽  
Geophysical Interpretation ◽  
Complex Fault ◽  
Exploration Risk ◽  
Petroleum Company ◽  
Oil Company

A consortium comprising Texaco Trinidad Inc., Trinidad and Tobago Oil Company Ltd., and Trinidad‐Tesoro Petroleum Company Ltd. commenced exploration in the South East Coast Consortium block offshore Trinidad in 1973. After four years of intensive exploration, a gas/condensate discovery was announced in early 1977 on the Pelican prospect. Later that year, in anticipation of the possible future need to site drilling/production platforms, a three‐dimensional (3-D) seismic survey was recorded over the prospect. This survey resulted in improvements in seismic record quality, multiple attenuation, and fault resolution. A coordinated geologic‐geophysical interpretation based on the 3-D seismic survey, a reevaluation of log correlations, and the use of seismic logs differed significantly from earlier interpretations. Because of this, it is anticipated that development of the field will need to be initiated in a different fault block from that previously envisioned. A second 3-D survey contiguous to the Pelican survey was recorded in 1978 over the Ibis prospect. Results show significant data enhancement in the deeper part of the section and improved fault resolution relative to previous two‐dimensional (2-D) control. The 3-D interpretation has revealed a much more complex fault pattern than originally mapped. Separate fault blocks will have to be individually evaluated, thus greatly increasing exploration risk.

Map displays from an interactive interpretation

Geophysics ◽  
1986 ◽  
Vol 51 (10) ◽  
pp. 1999-2006 ◽  
Author(s):  
J. I. Denham ◽  
H. Roice Nelson
Keyword(s):  
Three Dimensional ◽  
Seismic Interpretation ◽  
Seismic Survey ◽  
Two Dimensional ◽  
Seismic Surveys ◽  
Mapping Techniques ◽  
Gippsland Basin

Map displays built during interactive seismic interpretation provide information not obtainable with traditional mapping techniques. Several map displays derived from the 1983 interactive interpretation of a Gippsland Basin three‐dimensional (3-D) seismic survey are presented below. Similar map display results have since been obtained with the interactive interpretation of two‐dimensional (2-D) seismic surveys. These types of mapping results are among the most important contributions of interactive interpretation procedures.

Application of Three-Dimensional Fine Geological Modeling in Complex Fault-Block Reservoir with Low Permeability

2014 ◽  
Vol 511-512 ◽  
pp. 779-782 ◽  
Author(s):  
Jiang Tao Yu ◽  
Jin Liang Zhang ◽  
Shuang Yan Chen
Keyword(s):  
Water Distribution ◽  
Three Dimensional ◽  
Low Permeability ◽  
Production Test ◽  
Geological Modeling ◽  
Fault Block ◽  
Complex Fault ◽  
Modeling Software ◽  
Reservoir Description ◽  
Geological Research

Three dimensional geologic modeling is a powerful tool for reservoir development stages of geological study, it can solves many traditional problems existing in geological research through the establishment of precise three dimensional geologic modeling and represents an important direction for the further development of oilfield geological research. Low permeability and thin interbed reservoir of complex fault block have the characteristics of severe heterogeneity, complex relations of oil-water distribution, poor development effect, it is necessary to built high precision three dimensional geologic modeling in the process of oilfield exploration and to fine reservoir description and prediction on this basis, finally reach the purpose of reduce the risk of development and improve the economic benefit. This paper makes geological modeling research and builds structural models sedimentary micro-facies models and phased property model for Zhuzhuang block of Jiangsu oilfield by utilizing three dimensional geologic modeling technique and petrel geology modeling software on the basis of integrated using of geology, logging, oil production test, production of dynamic information, thus it provide a solid basis for reservoir's development and adjustment.

GEOPHYSICAL HISTORY OF MAMOU FIELD, EVANGELINE PARISH, LOUISIANA

Geophysics ◽  
1954 ◽  
Vol 19 (3) ◽  
pp. 490-508
Author(s):  
D. Ray Dobyns ◽  
W. B. Roper
Keyword(s):  
Historical Record ◽  
Torsion Balance ◽  
Oil Field ◽  
Seismic Survey ◽  
Total Production ◽  
Average Production ◽  
Engineering Company ◽  
History Of ◽  
Petroleum Company ◽  
Oil Company

This paper presents a chronological historical record of the geophysical activity in the area near the town of Mamou, Louisiana which subsequently led to the discovery of the Mamou Oil Field. The successive stages of geophysical exploration were: 1. Mechanical seismograph refraction survey by North American Exploration Company (German company) in August 1926 for Magnolia‐Union Sulphur‐Harry Hanszen. 2. Torsion balance survey by Shell Oil Company in 1934. 3. Magnetometer survey by Atlantic Refining Company in 1936. 4. Torsion balance survey by Atlantic Refining Company in 1936. 5. Gravity meter survey by Magnolia Petroleum Company the latter part of 1942 and early part of 1943. 6. Three weeks’ seismic work by Petty Geophysical Engineering Company for Magnolia Petroleum Company in June 1943. 7. A few weeks’ work by General Geophysical Company for Cities Service Oil Company in June, 1943. 8. Detailed seismic survey by Independent Exploration Company for Magnolia Petroleum Company from November, 1943 to June, 1945. The discovery well, Magnolia’s No. 1 J. B. Morein, was completed December 28, 1945 through perforations from 11,520 feet to 11,530 feet, producing 208 barrels of 46.3 gravity oil and 770 MCF gas per day through 8/64 inch choke. There are three producing horizons in the upper part of the Wilcox group. The first, or Morein stringer, is approximately 5 feet thick and lies about 18 feet above the second, or Morein sand, which has 19 feet average production thickness. The third, or Deshotels sand, has an average productive thickness of 10 feet and is approximately 230 feet below the Morein sand. Twenty producers and five dry holes were drilled. The field has been unitized and is being water‐flooded. Total production of the field to January 1, 1954 was 2,498,373 barrels. December, 1953 production was 20,604 barrels.

scholarly journals Reservoir Characteristics and Three-dimensional Architectural Structure of a Complex Fault-block Reservoir, Beach Area, China

2017 ◽  
Vol 10 (1) ◽  
pp. 276-286
Author(s):  
Xue Li ◽  
Tao Tong ◽  
Tiedao Lu
Keyword(s):  
Structural Information ◽  
Regional Scale ◽  
Three Dimensional ◽  
Structural Data ◽  
Petroleum Engineering ◽  
Reservoir Modeling ◽  
Trajectory Data ◽  
Reservoir Characteristics ◽  
Fault Block ◽  
Complex Fault

The objective area is a complex fault-block reservoir, and is provided by China Petroleum Engineering Design Competition(CPEDC). Reservoir characteristics, including stratigraphic features, vertical changes and section properties (thickness, percentage sand and percentage amalgamation) are documented. Based on comprehensive analysis on structural architecture and reservoir characteristics, a three-dimensional quantitative reservoir modeling is taken at a regional-scale of 69×97×37 m3 with the application of geostatistics as theoretical guidance, and thus high-resolution hierarchical reservoir model is generated with a combination of hierarchical data, structural data, physical data and well trajectory data. Therefore, the established three-dimensional geological model integrates all well-point information and structural information, and provides a basic model for subsequent sedimentary microfacies modeling and property modeling as well. Finally, three-dimensional fence diagrams, connecting-well sections and well group profiles are built successively.

scholarly journals Seismic characteristics of polygonal fault systems in the Great South Basin, New Zealand

2020 ◽  
Vol 12 (1) ◽  
pp. 851-865
Author(s):  
Sukonmeth Jitmahantakul ◽  
Piyaphong Chenrai ◽  
Pitsanupong Kanjanapayont ◽  
Waruntorn Kanitpanyacharoen
Keyword(s):  
Three Dimensional ◽  
Late Eocene ◽  
Seismic Survey ◽  
Fault System ◽  
Normal Faults ◽  
Tier 2 ◽  
South Basin ◽  
Fault Systems ◽  
Tier 1 ◽  
Polygonal Fault

AbstractA well-developed multi-tier polygonal fault system is located in the Great South Basin offshore New Zealand’s South Island. The system has been characterised using a high-quality three-dimensional seismic survey tied to available exploration boreholes using regional two-dimensional seismic data. In this study area, two polygonal fault intervals are identified and analysed, Tier 1 and Tier 2. Tier 1 coincides with the Tucker Cove Formation (Late Eocene) with small polygonal faults. Tier 2 is restricted to the Paleocene-to-Late Eocene interval with a great number of large faults. In map view, polygonal fault cells are outlined by a series of conjugate pairs of normal faults. The polygonal faults are demonstrated to be controlled by depositional facies, specifically offshore bathyal deposits characterised by fine-grained clays, marls and muds. Fault throw analysis is used to understand the propagation history of the polygonal faults in this area. Tier 1 and Tier 2 initiate at about Late Eocene and Early Eocene, respectively, based on their maximum fault throws. A set of three-dimensional fault throw images within Tier 2 shows that maximum fault throws of the inner polygonal fault cell occurs at the same age, while the outer polygonal fault cell exhibits maximum fault throws at shallower levels of different ages. The polygonal fault systems are believed to be related to the dewatering of sedimentary formation during the diagenesis process. Interpretation of the polygonal fault in this area is useful in assessing the migration pathway and seal ability of the Eocene mudstone sequence in the Great South Basin.

Using relative geologic time to constrain CNN-based seismic interpretation and property estimation

Geophysics ◽  
2021 ◽  
pp. 1-44
Author(s):  
Aria Abubakar ◽  
Haibin Di ◽  
Zhun Li
Keyword(s):  
Large Scale ◽  
Three Dimensional ◽  
Seismic Interpretation ◽  
Seismic Survey ◽  
Geologic Time ◽  
Seismic Amplitude ◽  
Property Estimation ◽  
Constrained Learning ◽  
Seismic Amplitudes ◽  
Multiplicative Regularization

Three-dimensional seismic interpretation and property estimation is essential to subsurface mapping and characterization, in which machine learning, particularly supervised convolutional neural network (CNN) has been extensively implemented for improved efficiency and accuracy in the past years. In most seismic applications, however, the amount of available expert annotations is often limited, which raises the risk of overfitting a CNN particularly when only seismic amplitudes are used for learning. In such a case, the trained CNN would have poor generalization capability, causing the interpretation and property results of obvious artifacts, limited lateral consistency and thus restricted application to following interpretation/modeling procedures. This study proposes addressing such an issue by using relative geologic time (RGT), which explicitly preserves the large-scale continuity of seismic patterns, to constrain a seismic interpretation and/or property estimation CNN. Such constrained learning is enforced in twofold: (1) from the perspective of input, the RGT is used as an additional feature channel besides seismic amplitude; and more innovatively (2) the CNN has two output branches, with one for matching the target interpretation or properties and the other for reconstructing the RGT. In addition is the use of multiplicative regularization to facilitate the simultaneous minimization of the target-matching loss and the RGT-reconstruction loss. The performance of such an RGT-constrained CNN is validated by two examples, including facies identification in the Parihaka dataset and property estimation in the F3 Netherlands dataset. Compared to those purely from seismic amplitudes, both the facies and property predictions with using the proposed RGT constraint demonstrate significantly reduced artifacts and improved lateral consistency throughout a seismic survey.

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