Oklahoma Oil and Gas production data
The Woodford Shale itself is not a new Oklahoma oil and gas play and while some plays begin to lose hype over a few years, there is still quite a bit of emerging play buzz going on, especially in the southern portions.
The Woodford SCOOP, or South Central Oklahoma Oil Province, as coined by Continental Resources a couple of years ago, has grabbed the attention of a handful of large operators.
Continental, the clear leader in the play, plans to spend almost $900 million in 2014 to SCOOP development and exploration – almost double what the company spent in 2013.
What Makes This Play So Attractive?
As most folks already know, the SCOOP is a liquids-rich play, offering high yields of oil and condensate. However, only a few years ago, the Woodford was sought after for its natural gas production, especially in the Arkoma Basin. Here is a map showing the entire Woodford play area broken down into four play regions based on the basin of deposition, GOR, primary product and industry drilling trends. Each well is bubbled and colored by its max month of oil production in barrels per day. This gives a brief, high-level overview of the Woodford’s sweet spot areas and shows the variation in the Woodford’s hydrocarbon thermal maturity.
What’s Going on in the SCOOP?
With that better idea of the Woodford as a whole, I queried up some data and looked for trends or standout data points that make the SCOOP play area special. I used the customized, DI Analytics dataset for my observations. Some of the power users of these datasets call them “analytics ready” and allow for faster workflows and quicker data to answers interpretation.
I want to look at similar plays to make sure I’m not comparing apples and oranges here, so I decided to hone in on the Bakken and Eagle Ford Oil Window since these plays compare favorably in terms of the product produced and GOR. Right off the bat, what stood out was short-term cumulative production levels of Woodford SCOOP wells compared to these other two plays. Observe the table below:
The major points of interest here are the lower initial decline rates, which account for the first 12 months of the well’s production. This is indeed an attractive attribute of the play considering typical shale wells decline 55 %– 70%, roughly, within the first year of production.
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