So, is that it? Are we done?

     I noticed that there is not much activity here on the western edge. I would like some input as to whether the oil companys gave up until new technology is available to squeeze the oil out in the Utica or the price has to go up. There are a lot of people out there with the knowledge of how these companies act in these cases.

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Permalink Reply by Jim on May 23, 2013 at 6:21am

Thanks Jodi for the research.

2,155 BofOil for the year 2012  But here's the but.  The horizontial on this well is only about 2000 feet long, 1/5th to 1/7th the length of the big wells in eastern Ohio.  What would production be if this horizontial was drilled out to 14,000 feet?  Why did the driller stop short?  The drilling unit is over 700 acres.

0i7okn54zwbdoPermalink Reply by 0i7okn54zwbdo on May 23, 2013 at 6:54am

"The horizontial on this well is only about 2000 feet long, 1/5th to 1/7th the length of the big wells in eastern Ohio. "

Man, I'd hate for your 7th grade math teacher to stumble upon this gem.  If 2,000 feet represents 1/5 of the lateral that means total lateral length is 10,000 feet.  I'll buy you a box of Mars bars if you can a whole pile of wells in Ohio drilled that far out.  The average is around 6,000 feet.

Permalink Reply by Jim on May 23, 2013 at 8:06am

Marcus, This article list the longest horizontial in the State of Ohio.

www.ohio.com/news/local/drillers-hit-nearly-670-miles-of-verticle-h...

The vertical on this well in Marion Co.is only down about 1400 feet which leaves the drilling rig with enough torque to drill a long horizontial.  Keep the Mars bars, I'm on a diet.

0i7okn54zwbdoPermalink Reply by 0i7okn54zwbdo on May 23, 2013 at 8:15am

"In 2012, the 625 wells drilled averaged 5,655 feet, the report said."

Outliers are irrelevant to the macro, hence the reason we call them outliers. 

Permalink Reply by Gas Patch Native on May 23, 2013 at 8:57am

the 10,000' thing is irrelevant to this whole debate, and although I'm not wanting to get in on this dispute, but i can't help myself.

From what i've been told and understanding general physics, most rigs push pipe through the horizontal section using the wieght of the vertical section. i find it extremely difficult to think they could push 10,000 feet of pipe horizontally with only a 1400' vertical section. the artical did not specify what type of wells the record setters were, and assuming since they were all set in 2012, they were likely Utica/PP wells (ave. depth to the Utica in OH is about 6000').

Where in the h*ll do you get Mars bars anyways these days, I haven't had one in years...............

0i7okn54zwbdoPermalink Reply by 0i7okn54zwbdo on May 23, 2013 at 9:08am

I think they discontinued the Mars bar and they now call it Snickers with Almond. 

Permalink Reply by Jack Straw on May 23, 2013 at 5:34pm

For Gas Patch Native:

 

Early drilling essentially was done with Cable Tool Rigs. These were simple drilling rigs that look as though they might have been designed by Rube Goldberg. The Cable Tool Rig used gravity to drill, the bit was essentially a chisel that was hammered into the ground. The Cable Tool Rigs drilled (very slowly) perfectly vertical holes; actually the only kind of holes that they could drill were vertical.

 

Next came the Rotary Rigs. These had a powered Rotary Table at the surface which rotated the drill string. The weight of the drill string (along with a rotary drill bit) ground up the rocks. These rigs could be kicked out and drill directional wells (horizontal for shot distances). Gravity was still an critical assist.

 

RE: “From what i've been told and understanding general physics, most rigs push pipe through the horizontal section using the wieght of the vertical section. i find it extremely difficult to think they could push 10,000 feet of pipe horizontally with only a 1400' vertical section.”

These Rotary Rigs have limitations such as referenced above.

 

But, a new drilling technology came out of the Soviet Union.  Downhole Turbines /Mud Motors.

https://sites.google.com/site/directionaldrillingclub/downhole-mud-...

 

This technology eliminates the strong dependence upon gravity and allows the driller to place the bit in places previously impossible. No longer “pushing the pipe”; if you wanted to push 10,000 feet of pipe horizontally with only a 1400' vertical section, it is no longer a problem. The bit is no longer rotated from the surface, but downhole, right behind the drill bit.

 

A bit of a simplified explanation, but should suffice.

 

JS

Permalink Reply by Billy Park Whyde on May 23, 2013 at 4:43pm

 Oh my I want a Midnight MARS BAR, dark chocolate, chilled to a shatter bite , oh my. 

0i7okn54zwbdoPermalink Reply by 0i7okn54zwbdo on May 23, 2013 at 5:01am

This all assumes a number of things that are highly unquantifiable. 

Permalink Reply by Thomas Moss on May 23, 2013 at 7:13am
that is a whopper jodi. I guess one of the best in the state. is there abetter roserun well than these two in licking.
0i7okn54zwbdoPermalink Reply by 0i7okn54zwbdo on May 23, 2013 at 8:18am

I'm not sure where the 16.5 years comes from.  Is that the life of the well that we're talking about? Or is that an estimation of its future production?  Without any data I have no idea how your math is or isn't.

0i7okn54zwbdoPermalink Reply by 0i7okn54zwbdo on May 23, 2013 at 8:25am

Then your math stinks. You and Jim should hang out.  Seriously though, I'd have to sit down with the numbers (or if you give me an API) and look at what the market was like during the peak years. 

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