Ann: Rafael Test Completion and Corporate Update, page-62

It appears their are quite a junior few oil/gas opportunities in the market at the same time all with potential company making news in the wings, and when the new is promising, but isn't clear or requires further testing I wonder how much churn there is between them all.

I think the news is quite positive, but I do admit that with only layman knowledge of oil and gas I get confused when they change the measurements from one announcement to the next. Could any of the more learned of you please explain the difference between wellhead flowing pressure and flowing tube head pressure. I assuming there is because why would they use another term if there wasn't.

The gas rate was estimated to be between 4 to 5 million cubic feet per day on a 32/64” fixed choke with a wellhead flowing pressure of 970 psi.

Flow rates increased as projected to some 6.52 mmcfd on a 128/64 inch choke with a stable flowing tubing head pressure of 164 psi.

The well was then turned to flare to obtain rates that were not impeded by the test equipment. This produced estimated rates of 7.6 mmcfd at a tubing head pressure of 165-170 psi.

In terms of flow, I am assuming the flowrate is the most important measure, but do the pressure readings have add any positive or negative interpretations of the rate?