AUTOMATED, PROACTIVE RESERVOIR & PRODUCTION ENGINEERING SURVEILLANCE

Automation: Let the computer do the ‘heavy lifting’

  1. 1
    Rate Validation and/or Rate Calculations (3-phases with Gas Lift Gas that’s a different composition than the reservoir gas)
  2. 2
    Mid-Completion BHP Calculation (Failure to do so results in artificially high skin and perm as well as incorrect P* values)
  3. 3
    Lift inefficiency check (do you have excess pressure drop in the well bore?)
  4. 4
    Check for Pressure Transients, flag test start & end times, and create Delta Times (for importing into manual PTA software)
  5. 5
    Screen & examine the transients for analyzable results (validity check)
  6. 6
    Analyze every valid build-up, drawdown and 2-rate tests
  7. 7
    Use the P*’s from the PBUs and the calculated produced volumes to run Static MBALs (In-place Volumes)
  8. 8
    Recognize boundaries & use the boundary distances and configurations to determine the In-place Volumes (see if any of the boundaries are moving – that could be water!)
  9. 9
    Recognize when the well is in pseudo steady-state (PSS) or steady-state (SS) in the reservoir. When it is in some form of steady-state, perform decline analysis to determine the Connected Volumes and the Mobile Hydrocarbon Volumes
  10. 10
    Keep track of all important parameters (and how they’re changing)

The surveillance engineer’s job is then to:

  1. 1
    Rate Validation and/or Rate Calculations (3-phases with Gas Lift Gas that’s a different composition than the reservoir gas)
  2. 2
    Mid-Completion BHP Calculation (Failure to do so results in artificially high skin and perm as well as incorrect P* values)
  3. 3
    Lift inefficiency check (do you have excess pressure drop in the well bore?)
  4. 4
    Check for Pressure Transients, flag test start & end times, and create Delta Times (for importing into manual PTA software)
  5. 5
    Screen & examine the transients for analyzable results (validity check)
  6. 6
    Analyze every valid build-up, drawdown and 2-rate tests
  • Productivity or Injectivity Index
  • Skin, DPskin/Q & Completion Efficiency
  • Perm & Mobility-Thickness
  • In-Place (MBAL and BV), Connected and Mobile Volumes
  • DPwellbore (is there efficient lift?)
  • Reservoir P* or Pavg
  1. 7
    Figure out why the key parameters are changing (skin, wellbore scale, waxing or asphaltenes, compaction, moving water contact, etc.)
  2. 8
    Determine the Excess Production or Injection Potential of the well (Maximum Safe Production Rate). Generate ODSI’s Transient Nodal Projections
  3. 9
    Make sure all of this information is populated in the Dashboard
  4. 10
    Look for anywhere in the system where there are inefficiencies (Wellbore-Completion-Reservoir). Recommend ways to Optimize the System
  5. 11
    Explain the results to the operator & answer their questions!

SCHEDULE A MEETING WITH US 

We’re looking forward to helping you remove the guesswork and uncertainty around your wells so that you can make better, more profitable decisions.

Before you spend a lot of money figuring out a problem, call us and send us your data. You may already have the answer!