Agreed Whynot. I would really like to see more updates, especially with more technical information so we can get more conclusions.
The Leon Pecha looks encouraging from a geological standpoint that it's been cutting oil and gas since it started flowback.
Production wise it probably won't be too flash as I believe the pumping method (gas lift) relies on gas supplied from the reservoir to pump the liquids up to the surface, which has been slower than expected due to there being less gas than what was expected.
On the Leroy Unruh SEA are using an ESP (Electric Submersible Pump), which pumps back much faster (~2,000 barrels of fluid a day is what RFE have reported using ESP's), and with these higher fluid rates, the success of the well comes down to the oil and gas cuts.
ESP's are good for a quicker recovery of the load water, but are more expensive and you risk pulling fracking sand from the formation (this is similar to the Breeden scenario, where SEA was using a less agressive pump in order to best avoid extracting the sand they pumped during the fraccing to keep the fractures open).
After using an ESP for the frac-water recovery on Leroy Unruh, Eric mentioned that SEA would likely replace it with a gas lift then. So whilst ESP's can be effective to recover the load water, they aren't necessarily good in the long-run.
What I'm looking for with Leon Pecha is the oil and gas cuts. The pump chosen probably rules out a large IP. Also with the conservative pumping system, I'm guessing the decline curve could very well be flatter then normal, at least initially, but that's just speculation on my behalf though.
The Leroy Unruh well is where the flowrate are important to me. With the ESP pump, these flow-rates are what will allow us to compare initial results with the other results in the play, assuming SEA haven't run into sand problems.
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