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Title : Produced Water Problem In The Permian -- June 30, 2018
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Produced Water Problem In The Permian -- June 30, 2018

I don't know how many caught this from FracFocus yesterday. It was the first time I noticed it, but it's likely there are other examples that I simply missed.

Look at the frack data for this well, from FracFocus:

• 17100, 240, CLR, Mountain Gap 31-10H, Rattlesnake Point, t6/08; cum 123K 5/18; 
• original frack, May 30, 2008; open hole, 1.1 million lbs sand;
• more recently, 17 days of 26,682 production extrapolates to 47,000 bbls over 30 days; API 33-025-00734; according to FracFocus, this well was fracked in Jan/Feb, 2018 (recently); 9.97 million lbs of water, but look at this:
• • water: 70.797%
  • sand: 11.85%
  • produced brine water: 4.85%
• those percentages add up to 87.49%
• I can't account for the other 12%
• the chemical cocktail is very, very small, maybe a percent or two 

The reason I bring that up is the subject of the article in North American Shale. Data points:

• produced water is becoming a significant problem in the Permian
• what to do with it
• people talk about the "produced water" problem in the Bakken, but look at this data, with regard to the ratio of produced water (to crude oil, I assume):
• • DJ (Basin): might be 1:1
  • Delaware Basin (the "most prolific basin" in the Permian):
  • • generally, 4:1
    • extreme cases, 7:1
    • worst cases: 10: 1
• the Permian operators are dealing with an unprecedented amount of water out
• could impact pricing by as much as $6/bbl

More:

What’s different now it that unconventional development in the Permian doesn’t allow for the same water management practices. By that I mean if you’re drilling conventional wells, most of the produced water can be reinjected for water floods or EOR (enhanced oil recovery). Whereas now, the operators, many are testing some of the tertiary recovery techniques, but nothing’s being done on a wide scale.

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