E2E Service

Analysis and Predictions

Site Specific Evaluation

Upwing's Enhanced Production Simulator™ (EPS) uses an integrated approach to simulate gas production enhanced by the Upwing Subsurface Compression System™ (SCS) and to predict reservoir response. 

The SCS is a form of artificial lift, which increases wellbore drawdown at the compressor intake and boosts wellbore pressure at the compressor discharge. To date, the increased gas production, ranging from 20 to 200+%, simulated with a subsurface gas compressor in gas wells is consistent with the increased drawdown by artificial lift in oil wells. Parametric studies completed by Upwing have illustrated the different degree of impact by various reservoir dynamics, well geometry and compressor factors on the well productivity with artificial lift downhole.

How does EPS work?

Upwing EPS evaluates the production enhancement achieved with subsurface compression using two independent methodologies. The first model uses an analytical approach to calculate gas flow rate and pressure drop across the production tubing for a single phase compressible fluid by integrating the mechanical balance equation. The second model uses numerical simulation to converge mass flow rate and isentropic efficiency derived from the momentum equation across the compressor to compute suction pressure and production increase. Both models use a known surface boundary condition to calculate the ratio of downstream to upstream pressure across the subsurface compressor.


What can EPS tell me about my wells?

Working with an Upwing specialist, customers can input commonly known well data, including wellhead pressure, wellhead temperature, bottom hole temperature, inflow performance relationship, gas well depth, pipe length, pipe ID, pressure ratio and fluids composition to simulate the increased gas flow rate with a subsurface compressor and compare it with gas production without artificial lift to explain the impacts of subsurface compression on their gas production and recoverable reserves. The simulations provide insights on how to plan completion geometry and leverage the capability of subsurface compression to maximize the production gain potential.

The technology provides operators with numerous new analytical measurements of well efficiency and performance, which were previously impossible to gather. 



  • Absolutely Required
  • Required
  • Optional
  • Upwing Input
  • Bore Icon
    • Tubing & Casing Data
    • Perforation & Profile Depths
    • Wellhead Conditions
    • Directional Survey
  • Reservoir Icon
    • Reservoir Pressure
    • Reservoir Temperatures
    • Thickness
    • Porosity & Permeability
    • Petrophysical Summaries
    • Well Logs
    • Geomechanics Geochemistry
  • Fluid Icon
    & PVT
    • Gas Gravity
    • Liquid Density
    • Gas Composition
    • Compositional PVT
    • Well Logs
    • Geomechanics Geochemistry
  • Bulb Icon
    Production &
    Pressure Data
    • Production History
    • Static/Dynamic Pressure Data
    • IPR/VLC Data
    • Well Tests
    • Simulation Model
    • Completion Reports
  • Decline Icon
    • Baseline Rate
    • EUR
    • Final Rate
    • Production Period
    • Well Tests
    • Effective Decline Rate
    • Terminal Decline
  • Design Icon
    • Power Input
    • # Stages
    • Max Speed
    • Min Prod. Gain

Output Data