Contact

Braden Holt

Denver, CO

email: bradenholt@theenergyharbinger.com

twitter: @energyharbinger

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13 thoughts on “Contact

  1. Brant Littrell

    Do you think we will see EOR applied to traditional plays that are considered pressure depleted? Specifically I have been looking at fields along the Nemaha line at Eldorado KS, & the Garber Field & Sooner Trend in OK. I know they have had some success with those techniques in the Permian Basin but I didn’t know how much (if any) the technology has proliferated.

    Reply
    1. bradenholt Post author

      It has proliferated to an extent. I know Denbury uses EOR in Wyoming and the gulf coast. Whiting uses it in the Permian which is interesting because I know they’ve recently talked about trying it in some of their Bakken acreage, I wanna say the Parshall wells which have been producing for a handful of years (I think they mentioned this on their Q3’12 call). So yea I think companies will look at the economics in certain areas, but I’m not sure about the ones you specifically mentioned.

      Reply
  2. Brant Littrell

    As I’m sure you’ve noticed by now I’m focused on the Mississippian play right now. One of the things I’ve noticed is the high concentration of wells in OK vs. KS. Do you know if the state regulatory enviroment or cost structure is causing that disparity? I’ve been trying to locate cost information on drilling in OK vs KS but have been unsuccessful thus far. Any idea?

    I also know this play produces a lot of water that the drilling companies are disposing of in the arbuckle formation just beneath the Mississippian formation which could also be a driver in the new drilling movement due to the build out required ahead of the production rigs in terms of having water disposel wells already in operation before beginning production.

    Reply
    1. bradenholt Post author

      I don’t believe well cost is significantly different in either state. My guess is there was more existing infrastructure (gathering, pipeline, SWD, proximity to hubs) on the Oklahoma side so companies drilled there first. It could be something as simple as the big first movers (SD, CHK) are Oklahoma companies so it was more practical to start there first. As for SWD build out, what you described has been SD’s strategy.

      Reply
  3. sunny

    PLease comment on Hess-Elliot. Why Hess selling its midstream assets in Bakken? Why loss on sale of Eagle Ford assets? Why so many concessions to placate Elliot?

    Reply
    1. bradenholt Post author

      Sorry for the late response here Sunny. I haven’t followed Hess closely but I’d guess its Bakken portfolio offers a higher return than its Eagle Ford so it sold the Eagle Ford to help fund its continued development of the Bakken. The same could probably be said for the midstream assets in the Bakken. There’s certainly been a trend towards independent producers in the oil and gas world meaning investors don’t value companies who drill their own wells, transport/refine their own oil, it’s a complicated story that is often inefficient and difficult to value. Not to mention that upstream companies have higher margins than mindstream, so why would you tie up capex in a lower return vertical when you have a large portfolio of wells to drill? Hopefully that helps and again sorry for the late response.

      Reply
  4. david street

    BH – Thanks for all your perorations.
    I look forward to a comprehensive well map, and appreciate all the diligence and work entailed. Does anyone happen to know the location of the Roger Swartz field? My understanding is it is somewhere either side of the Nemaha Ridge. The first well has been a modest 17bopd on a vertical frack with possibly seven more targets, which may be turned laterally/horizontally at a future date. Also, I am assuming reservoirs in the area may be described as “thin”.
    (bakoven)

    Reply
    1. bradenholt Post author

      I’m unaware of the Roger Swartz field but I’ll be writing an article on the Nemaha Ridge soon and I’ll keep my eyes open. Companies like Austex who’re drilling vertical wells are having the most success in that area as it’s more of a trap type play (pockets of oil trapped by geological formation) than a resource play (widespread oil across a formation).

      Reply
  5. david street

    My primary focus is the Bakken and Mississippian. As there is a surfeit of oil company information on the web – be it geographical, geological, fundamentals, technicals and other – no attempt will be made to duplicate it. Of some importance and equally interesting is the listing of two startups on the AIM, London. American-led, with experienced management at the helm, both are attracting considerable attention. Magnolia is active in both plays whereas Northcote’s concentration is in the Missi. Their progress will be closely followed.

    http://www.magnoliapetroleum.com/
    http://www.northcoteenergy.com/

    Another area of interest is Daniels, MT – western extension of the Bakken. Apache drilled two horizontals during the winter, talked up the great promise demonstrated, and then disappeared. I am assuming that the code to the Madison and Ratcliff still has to be unlocked. Its secrets may follow a similar pattern to the early development of the Williston Basin, i.e. slow in coming. Someone could provide an explanation on this one.

    Reply
    1. bradenholt Post author

      Thanks for the information David. Like I said above, I’ll be writing a Mississippian article soon and I’ll probably cover both Magnolia and North Cote.

      Reply

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