Knowing when child wells are stealing production from parents wells
Determining Drained Rock Volume (DRV) provides insights to completion optimization and potential completion savings
Creating a development plan to maximize recovery, without stealing production or leaving resources in the subsurface
1. Baseline Generation
Fluid family generation via core/SWC, cuttings or produced fluid analysis
2. Phased Fluid Characterization
Produced fluid composition and properties (family, mobility, and maturity) over time
3. Quantitative Production Allocation
Delivery of oil family/stratigraphic contribution to production
This case study presents the application of Time-Lapse Geochemistry on a pad of three wells to determine if Lower Eagle Ford lateral wells are producing from the Upper Eagle Ford.
Principal Component Analysis (PCA) performed on the produced and baseline fluids (Lower Eagle Ford and Upper Eagle Ford) highlight the produced fluids being characteristic of the Lower Eagle Ford.
Check out the Episode 115 of the PBE Podcast on Spotify!
Or read about it here:
Timelapse Geochemistry production allocation; end member definition and selection; case studies, Delaware Basin and Eagle Ford
Adam Turner*¹, Catherine Donohue¹, J. Alex Zumberge¹, Andrew Muñoz², Philip Bergeron²
1. GeoMark Research, Houston TX
2. Ensign Natural
Resources, Houston TX
Analysis of our results concluded that additional development is required to access and produce the Upper Eagle Ford resource.
This case study was completed on the Hydraulic Fracturing Test Site-2 (HFTS-2), which is a well-studied industry and government consortium project area to better understand the hydraulic fracturing interaction efficiencies within the subsurface. Several techniques were deployed at the test site to better understand flow units from the initial Stimulated Rock Volume (SRV) to the actual Drained Rock Volume (DRV) over time in the Wolfcamp Formation.
Principal Component Analysis (PCA) performed on the geochemical data identified a variation in fluid properties over time. Wells 2H and 4H maintained a similar famly throughout production with wells 1H and 3H hosting a similar oil family at the start and then deviating from one another over production time. This observation reflects the variation in oil character between Wolfcamp Y and Wolfcamp A.
The implication of these results clearly indicated some sort of permeability ‘baffle’ between Wolfcamp A and Wolfcamp Y. From other subsurface monitoring analysis (microseismic), and early oil production, it was noted that fracturing event did propagate up into Wolfcamp Y which is further confirmed by the presence of Wolfcamp Y oils in the Wolfcamp A landed wells (1H & 3H).
Ultimately, this information can assist in the optimization of both development and completion approaches to maximize wellbore contact and drainage within the subsurface, while reducing expenses on ineffective completions.