Oil and gas geochemistry and petroleum systems of the Fort Worth Basin

AAPG Bulletin ◽  
2007 ◽  
Vol 91 (4) ◽  
pp. 445-473 ◽  
Author(s):  
Ronald J. Hill ◽  
Daniel M. Jarvie ◽  
John Zumberge ◽  
Mitchell Henry ◽  
Richard M. Pollastro
Keyword(s):  
Oil And Gas ◽  
Fort Worth ◽  
Fort Worth Basin ◽  
Petroleum Systems ◽  
Gas Geochemistry

Barnett Gas Geochemistry and Thermal Maturity, Fort Worth Basin

2013 ◽  
Author(s):  
Harold Illich ◽  
Kevin Ferworn ◽  
Gary Nilson ◽  
Frank Hernandez ◽  
David Williamson
Keyword(s):  
Fort Worth ◽  
Thermal Maturity ◽  
Fort Worth Basin ◽  
Gas Geochemistry

scholarly journals Porosity estimation in the Fort Worth Basin constrained by 3D seismic attributes integrated in a sequential Bayesian simulation framework

Geophysics ◽  
2017 ◽  
Vol 82 (4) ◽  
pp. M67-M80 ◽  
Author(s):  
Martin Blouin ◽  
Mickaele Le Ravalec ◽  
Erwan Gloaguen ◽  
Mathilde Adelinet
Keyword(s):  
Oil And Gas ◽  
Reservoir Characterization ◽  
Geophysical Methods ◽  
Seismic Attributes ◽  
Seismic Inversion ◽  
Fort Worth ◽  
3D Seismic ◽  
Reservoir Properties ◽  
Fort Worth Basin ◽  
Porosity Estimation

The accurate inference of reservoir properties such as porosity and permeability is crucial in reservoir characterization for oil and gas exploration and production as well as for other geologic applications. In most cases, direct measurements of those properties are done in wells that provide high vertical resolution but limited lateral coverage. To fill this gap, geophysical methods can often offer data with dense 3D coverage that can serve as proxy for the variable of interest. All the information available can then be integrated using multivariate geostatistical methods to provide stochastic or deterministic estimate of the reservoir properties. Our objective is to generate multiple scenarios of porosity at different scales, considering four formations of the Fort Worth Basin altogether and then restricting the process to the Marble Falls limestones. Under the hypothesis that a statistical relation between 3D seismic attributes and porosity can be inferred from well logs, a Bayesian sequential simulation (BSS) framework proved to be an efficient approach to infer reservoir porosity from an acoustic impedance cube. However, previous BBS approaches only took two variables upscaled at the resolution of the seismic data, which is not suitable for thin-bed reservoirs. We have developed three modified BSS algorithms that better adapt the BSS approach for unconventional reservoir petrophysical properties estimation from deterministic prestack seismic inversion. A methodology that includes a stochastic downscaling procedure is built and one that integrates two secondary downscaled constraints to the porosity estimation process. Results suggest that when working at resolution higher than surface seismic, it is better to execute the workflow for each geologic formation separately.

scholarly journals CHARACTERISTIC OF SHALE GAS RESERVOIR USING LMR (LAMBDA-MU-RHO) INVERSION: CASE STUDY BARNETT SHALE, FORT WORTH BASIN TEXAS, USA

2016 ◽  
Vol 28 (1) ◽  
pp. 43
Author(s):  
Hagayudha Timotius ◽  
Yulinar Firdaus
Keyword(s):  
Shale Gas ◽  
Alternative Energy ◽  
Oil And Gas ◽  
Barnett Shale ◽  
Physical Parameters ◽  
Fort Worth ◽  
Fort Worth Basin ◽  
Avo Inversion ◽  
Amplitude Versus Offset ◽  
Energy Needs

The decreasing of fossil fuel reserves in the conventional reservoir has made geologists and geophysicists to explore alternative energy source that could answer energy needs in the future. Therefore the exploration of oil and gas that is still trapped in the source rock (shale) is needed, and one of them still developed in shale gas. The method of Amplitude Versus Offset (AVO) Inversion is used for Lambda-Mu-Rho attributes, that is expected to assess values of physical parameters of shale. Fort Worth Basin is chosen to be a study area because, the Barnett Shale Formation has proven contains of oil and gas. This study using synthetic seismic data, based on geological model and well log data obtained from Vermylen (2012). It is expected from the study of Barnett Shale that related to shale gas development could be applied. Keyword: Shale gas, Barnett Shale, Fort Worth Basin, AVO Inversion, Lambda-mu-rho attributes Penurunan cadangan bahan bakar fosil pada reservoar konvensional membuat ahli geologi dan geofisika mengeksplorasi sumber energi alternatif guna menjawab kebutuhan energi di masa depan. Oleh karena itu dibutuhkan eksplorasi minyak dan gas yang masih terperangkap dalam batuan induk (serpih), dan salah satunya yang dikembangkan saat ini adalah “shale gas”. Penggunaan metode inversi Amplitudo Versus Offset (AVO) untuk atribut Lambda-Mu-Rho diharapkan dapat menghasilkan nilai-nilai parameter “fisis shale”. Cekungan Fort Worth dipilih sebagai lokasi penelitian ini karena terdapat Formasi “Barnett Shale” yang telah terbukti mengandung minyak dan gas. Penelitian ini menggunakan data seismik sintetik berdasarkan model geologi serta data sumur yang diperoleh dari Vermylen (2012). Diharapkan dari penelitian tentang Barnett Shale yang berkaitan dengan pengembangan shale gas dapat diaplikasikan. Kata kunci: “Shale gas”, “Barnett Shale”, Cekungan Fort Worth, Inversi AVO, atribut Lambda-Mu-Rho

Sign in / Sign up

Export Citation Format

Share Document