I am going through it now. A big "thank you" to Don.
Disclaimer: I did this quickly and there may be errors. Note -- one cannot compare certain data points between the Bakken and TMS
Some data points:
Three plays: North Dakota (Bakken), Texas (Eagle Ford), Louisiana (TMS)
Slide 7:
- CAPEX: a 35% decrease in 2014 vs 2013
- Focus: Bakken (49%), Eagle Ford (40%), TMS (10%)
- 90% of Bakken drilling/completion allocated to FBIR
- 100% D&C allocated to "sweet spots"
- for all the talk, only 10% of CAPEX on TMS in 2014
- 307,000 net acres vs 142,000 net acres in the Bakken
- TOC: 3 - 4% vs as much as 11% in the Bakken
- Samson Oil & Gas says 1,000 lbs/linear foot is the industry standard in the Bakken
- HK: average -- 1,747 lbs/linear foot in TMS
- 48 days
- NDIC says ND average is 120 days
- look to save $2.4 million/well on multi-well pad development (that is as much as three times what other operators say they are saving in the Bakken)
- EURs revised higher -- now up to
- slickwater FBIR wells
- potential for up to 16 wells per DSU in FBIR area
- Capitol Pad development plan; McKenzie County; HK with 71% working interest
- middle Bakken (8), TF1 (4), TF2 (4) [nothing in TF3 or TF4]
- saves $1.3 million
- 50% of wells will be on 6-well pads; 42% on 3- and 4-well pads
- fastest 10,000 lateral ever drilled in FBIR (4.15 days)
- fastest 10,000 lateral ever drilled in Williams County (3.5 days)
- rule of thumb: 150,000 bbls pays for the well; if so, wells are paid for in six months
- same payback as EOG
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Glabal Warming Could Set New Records
Being reported by AccuWeather. Some of these records go back to the 1950s.
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