"In general, the practice of managing flowback to protect a fracture job in a horizontal well is not new. Gas producers working the Haynesville Shale, a relatively soft formation in Louisiana, learned several years ago that managing the release of flowback often meant the difference between a live well and a dead one.

Crafton, who is also an SPE distinguished lecturer and author of several SPE papers on flowback, coined the term “slowback” to describe how his clients in the Haynesville managed to overcome their early failures. While working for an operator there, he found that crews were being paid bonuses to get the flowing surface pressure of gas wells from 1,000 psi to 2,000 psi down to the line pressure of 300 psi within 36 hours.

“I started looking at the production histories and you could see these were awesome completions,” he said. “But when they would impose that…

There is so much stupid stuff being said by internet "experts," on the Marcellus and the Appalachian Basin, in general, it requires clarification. These experts have no access to realized data so they are hoping to bull shit you with self-promoting data from any source they can find that confirms their belief system.

Cum prods., regardless of what these experts say, are less than 7 BCF. The data sources I have access to suggest 24-36 month well productivity in the APP Basin is falling, most certainly from interference and ensuing pressure depletion.

These dry gas wells struggle to make money at <$1.50 per MMBTU, after all royalty, full cycle corporate costs, OPEX and transportation/processing, rental, compression, dehydration, etc. etc. costs are deducted.

Please don't buy the dung heap; multiplying daily production by NYMEX Henry Hub prices or converting dry gas to BOE equivalents to suggest gas is equal to MMBO...that…

and win a cheeseburger with fries from the Dairy Queen in Flatonia, that just had its bathrooms repainted.

No, it's not the burned remnants of R2-D2.