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Integration of NMR with Other Openhole Logs for Improved Formation Evaluation
Minh, Chanh Cao (Schlumberger Sugar Land Product Center) | Freedman, Robert (Schlumberger Sugar Land Product Center) | Crary, Steve (Schlumberger Sugar Land Product Center) | Cannon, Darrel (Schlumberger Sugar Land Product Center)
Abstract The recently introduced measurement of total porosity from nuclear magnetic resonance (NMR) tools can help to identify the hydrocarbon type and to improve the determination of formation total porosity (t) and water saturation (Swt) in combination with other openhole logs. In shaly formations, porosities are difficult to estimate in the presence of hydrocarbons, especially for gas and light oils. Water saturations are even more difficult to estimate because critical parameters such as clay cation exchange capacities per unit pore volume (Qv), formation factors (F) and formation water resistivity (Rw) might not be known. The latter quantities are essential inputs into the Waxman-Smits and Dual-Water model saturation equations. In the typical case of shaly gas bearing formations, both the total porosity corrected for the gas effect and the gas saturation (Sxgas) in the flushed zone can be derived by combining total NMR porosity (TCMR) and density porosity (DPHI). Adding resistivity logs such as Rxo and Rt helps to differentiate between gas and oil. Furthermore, the flushed zone water saturation (Sxot) computed from 1 - Sxgas can be used in many ways. One procedure uses Sxot in conjunction with the Rxo saturation equation to determine Qv or F. Another technique uses Sxot in conjunction with SP to estimate Qv when Rw is known. Yet, another method estimates Qv directly from the NMR short relaxation time part of the T2 distribution and use Sxot in conjunction with SP to estimate Rw. The new interpretation procedure follows the sequential shaly sands approach: first, determine porosity; second, determine shaliness and third, determine saturation. The new procedure improves on the classical method by offering new ways to compute Qv, F and Rw. The methodology is applied to a number of field examples. P. 245
- Europe (0.68)
- North America > United States > Texas (0.28)
Our data mapping is a "true amplitude" earth model to a different output source/receiver configuration process in the following sense.
These discoveries the play that has seen an It is one of the closest watched natural gas plays in the exponential growth in drilling activity.
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying > Vertical Seismic Profile (VSP) (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Near-well and vertical seismic profiles (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Borehole imaging and wellbore seismic (1.00)
- Well Drilling > Drilling Operations (0.90)
In the absence of caustics, we and we recover the original function. Now, it employed the Generalized Radon Transform (GRT) to follows that carry out the inversion.
Integration of 2D Prestack Depth Migration And Surface Geological Data: A Western Venezuela Case Study
Bernal, Asdrรบbal (PDVSA-INTEVEP, Apto 76343, Caracas 1070A, Venezuela) | Novoa, Enrique (PDVSA-INTEVEP, Apto 76343, Caracas 1070A, Venezuela) | y Omar Uzcรกtegui, Andrรฉs Pilloud (PDVSA-INTEVEP, Apto 76343, Caracas 1070A, Venezuela)
Methodology Seismic interpretation in complex areas with seismic data of poor quality is a difficult task that requires the use and Figure 1 shows a block diagram with the main features of the integration of several tools in order to obtain an the methodology followed in this work.
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (1.00)
- Geophysics > Seismic Surveying > Seismic Processing (0.95)
In a companion paper, Bleistein [1998], we describe a procedure to derive a general we described a "platform" for data mapping.
Brazos A-105 D-sand Reservoir Modeling By Integration of Seismic Elastic Inversion Results With Geostatistical Techniques
Xu, Wenlong (UNOCAL E&PT, Sugar Land, TX) | Wrolstad, Keith (UNOCAL E&PT, Sugar Land, TX) | Kramer, Darrell (International Reservoir Technologies, Golden, CO) | Dooley, Paul (UNOCAL Spirit Energy 76, Lafayette, LA, D.T. Vo, UNOCAL Indonesia) | Domingue, Kirby (UNOCAL Spirit Energy 76, Lafayette, LA, D.T. Vo, UNOCAL Indonesia)
ABSTRACT No preview is available for this paper.
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (0.40)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (0.40)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (0.40)
The Bombay High Field is one of the giant fields still currently producing hydrocarbons. The field is the largest in India with over four hundred wells producing hydrocarbons from Tertiary carbonate and clastic reservoirs. Bombay High Field has been producing hydrocarbons since 1975. P.G.S. (Petroleum Geo Services) under contract to ONGC has undertaken a project of a completely integrated field study of the Bombay High Field. This A.P.I. (Acquisition, Processing, Interpretation) study consists of 3-D seismic acquisition, state of the art seismic processing and integrated interpretation for the Bombay High Field.
- Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Mumbai High Field > L-V Formation (0.99)
- Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Mumbai High Field > L-IV Formation (0.99)
- Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Mumbai High Field > L-III Formation (0.99)
- (2 more...)
Geophysical interpretation A total of 15 wells were present within the area covered by the seismic data. All wells were used to tie the geological boundaries to the compressional seismic data response. Time-depth tables are then created, and time-converted synthetics and formation tops can be used to guide the seismic interpretation. Several key seismic horizons were picked with the assistance of good well control. The base of the Glauconitic compound incised-valley was determined according to the well control and lateral seismic character change. The Top-Base of the Glauconitic incised-valley isochron illustrates well the width extent of the Glauconitic incised-valley as well as its deepest incision, while an isochron between the regional Glauconitic and the Wabamun clearly shows a thickening of the interval (drape) over the less compactable Glauconitic incised-valley deposits.
- Geophysics > Seismic Surveying > Seismic Processing (0.72)
- Geophysics > Seismic Surveying > Seismic Interpretation (0.55)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.49)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Upper Mannville Group Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Pekisko Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Blackfoot Field > Blackfoot Reserv. 10 Th 14-19-22-23 Well (0.99)
In this paper, the integration of borehole data with datasets in other domains is illustrated.
- Europe > United Kingdom > North Sea (0.29)
- Europe > Norway > North Sea (0.29)
- North America > United States > Texas (0.29)