Creating a 3D Hydrocarbon Profile to Increase Production and Reduce Poor Economic Wells: a Utica Case Study
Abstract
Shale plays represent a difficult arena in which to explore since each shale play is unique in terms of organic content and rock property. While general lessons can be translated from one play to another there are important differences which control exploration and development decisions. Due to the heterogeneity of resource plays they can even differ within a single field. This means that effectual development of shale plays requires extensive evaluation and coordination of various data sources such as geology, geophysics, geomechanics, petrophysics, and engineering. However, while these conventional disciplines bring a wealth of important data to the discussion, one important data set is often lacking – hydrocarbon data.
Given the heterogeneity of shale plays, it is important to identify the variability of hydrocarbon richness, pore pressure, and porosity in a 3-dimentional sense across a field. This variability is often one of the primary reasons for production differences across a field. Traditionally these parameters is assessed by analyzing core or cuttings samples as wells are drilled and then this single-point data is extrapolated field wide. However, extrapolating this data across the field is suspect and numerous wells must be drilled to develop a remotely accurate model. Thus, the data could be deemed more postmortem rather than predictive.
This case history will demonstrate how ultrasensitive surface hydrocarbon mapping was used, with little well control, to:
Additionally, the case history will demonstrate how ultrasensitive downhole geochemical logging was used to demonstrate:
AAPG Datapages/Search and Discovery Article #90258 © 2016 AAPG Eastern Section Meeting, Lexington, Kentucky, September 25-27, 2016