2019 AAPG Annual Convention and Exhibition:

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Diagnostics and Uncertainty Characterization of Tight Liquid Production with Phase Behavior: Insights from Case Study in the Delaware Basin.

Abstract

Fluid composition and recoverable subsurface volumes are key drivers behind sustainable asset development. We can now refine calculations and assessment of Expected Ultimate Recovery (EUR) in low permeability laminated mixed minerals and macerals systems. Mobility and volumes are different in the porosity systems and the fracture network. Even more important is the differences for the flow potential for the different types of fluids and charge history. Decision makers are aided by a workflow that can be used to let them better exploit spatial variation of produced fluids characteristics. This works illustrates a data driven analysis complemented with modeling of produced oil and gas to characterize the uncertainty and spatial variability of in place resource. Different depositional environments have differing spatial variation in both horizontal and vertical dimension. Characterizing uncertainty of volumes retained and expelled is improved with a map based approach. For this Delaware basin case study we illustrate which assumptions lead to greatest variability of Original Oil in Place (OOIP), Expected Ultimate Recovery, and compositional difference between subsurface and produced fluid compositions and volumes. Production decline curves, and early gas onset for wells under different maturity and phase constrains are used as a supporting line of evidence. There are three main controls on the production of fluids: presence, properties and mobility. Presence requires generation of fluids from solid organic matter and the ability to trap those fluids in the subsurface. The properties of the subsurface fluids are dependent on both composition and spatial distribution in 3D of the type of solid organic matter as well as the thermal and pressure histories that drive generation and cracking of oil to