To be classified 1p.Additional oil and gas expected to be...

To be classified 1p.

Additional oil and gas expected to be obtained through the application of fluid injection or other improved recovery techniques for supplementing the natural forces and mechanisms of primary recovery should be included as “Proved Developed Reserves”only after testing by a pilot projector after the operation of an installed program has confirmed through production response that increased recovery will be achieved.

2p

•Probable reserves are reserve estimates in known reservoirs which cannot yet be considered reasonably proved on the basis of current geologic and engineering information.

Comment
These volumes are expected to become proved as additional information becomes available, and it is important to be able to define the event which will allow the reserves to become proved.

SPE/WPC Reserve Definitions -Probable
•Typical Examples
–Down-spacing with questionable drainage patterns
–Market, contract limitations
–ENHANCED RECOVERY WITHOUT SUCCESSFUL TESTING
–Certain step-out development wells
–Work-over treatments without analogies
–Alternative performance interpretation

DATA NEEDED FOR ANALYSIS
•Need a good estimate of OOIP (STB) for both the analogy reservoir and the reservoir being studied.
•CO2 Flood Area OOIP (STB)
•Initial Oil Formation Volume Factor –Boi(RB/STB)
•Current Oil Formation Volume Factor –Bo (RB/STB)
•Current Reservoir Temperature and Pressure (ºF and psia)
•Carbon Dioxide Formation Volume Factor –Bco2 (RB/MCF)
•Initial and Residual Oil Saturation
•Historical production and injection rates

info from http://www.ryderscott.com/CO2-05-Slide-Stell.pdf.

No where does it say you need to have a Co2 supply lined up to be classed as 2p but that last bit about Historical production and injection rates may be a problem. I don't know?