Amplitude response and interpretation of subsalt reservoir architecture and quality using PP and PS imaging: a multiple-well 3D VSP modeling case study from the Gulf of Mexico Paleogene

PreviousNext No AccessSEG Technical Program Expanded Abstracts 2017Amplitude response and interpretation of subsalt reservoir architecture and quality using PP and PS imaging: a multiple-well 3D VSP modeling case study from the Gulf of Mexico PaleogeneAuthors: Peter LanzaroneElizabeth L'HeureuxZhiyong JiangDouglas StauberPeter LanzaroneBP AmericaSearch for more papers by this author, Elizabeth L'HeureuxBPSearch for more papers by this author, Zhiyong JiangSaudi AramcoSearch for more papers by this author, and Douglas Stauberformerly BPSearch for more papers by this authorhttps://doi.org/10.1190/segam2017-17674468.1 SectionsAboutPDF/ePub ToolsAdd to favoritesDownload CitationsTrack CitationsPermissions ShareFacebookTwitterLinked InRedditEmail Abstract The Gulf of Mexico (GoM) Paleogene is an emerging oil and gas industry trend characterized by subsalt reservoirs deposited as submarine turbidites, where significant depths to drilling targets have led to high-pressure regimes. Rock properties modeling suggests that sands and shales, as well as sand quality variations, are distinguishable using seismic amplitudes across the trend, however, surface seismic technology is limited in its ability for interpreters to predict reservoir quality and stratigraphic associations due to poor angular illumination in subsalt environments. A detailed rock property model was utilized to generate synthetic 3D elastic vertical seismic profile (VSP) data at 3 well locations at a Paleogene oil field. Vertical component data (treated as PP) and horizontal component data (treated as PS) were used to produce corresponding migrated images, both using the exact velocity model. Migrated 3D VSP PP and PS images allowed robust interpretations of the model data which was tested to determine the efficacy of delineating reservoir quality, stratigraphic, and fluid variations built into the model. Results show that 3D VSPs are capable of providing meaningful subsalt amplitude images that reflect reservoir properties, data that can have a significant impact on well placement and oil recovery. Additionally, despite the excellent synthetic data quality derived from this modeling study, there are limited industry borehole seismic tools available to perform a realistic field acquisition as depicted in this model due to the depth and pressure regimes unique to the Paleogene, supporting the need for the future development of expanded arrays rated for high-pressure environments. Presentation Date: Tuesday, September 26, 2017 Start Time: 2:40 PM Location: 371A Presentation Type: ORAL Keywords: VSP, finite difference, Gulf of Mexico, subsalt, converted wavePermalink: https://doi.org/10.1190/segam2017-17674468.1FiguresReferencesRelatedDetailsCited byThe value of VSP data through early phases of field appraisal and development: A modeling and acquisition case study in the Gulf of MexicoPeter Lanzarone, Elizabeth L'Heureux, and Qingsong Li1 November 2019 | The Leading Edge, Vol. 38, No. 11 SEG Technical Program Expanded Abstracts 2017ISSN (print):1052-3812 ISSN (online):1949-4645Copyright: 2017 Pages: 6093 publication data© 2017 Published in electronic format with permission by the Society of Exploration GeophysicistsPublisher:Society of Exploration Geophysicists HistoryPublished Online: 17 Aug 2017 CITATION INFORMATION Peter Lanzarone, Elizabeth L'Heureux, Zhiyong Jiang, and Douglas Stauber, (2017), "Amplitude response and interpretation of subsalt reservoir architecture and quality using PP and PS imaging: a multiple-well 3D VSP modeling case study from the Gulf of Mexico Paleogene," SEG Technical Program Expanded Abstracts : 6024-6028. https://doi.org/10.1190/segam2017-17674468.1 Plain-Language Summary KeywordsVSPfinite differenceGulf of Mexicosubsaltconverted wavePDF DownloadLoading ...