Replies to This Discussion

Permalink Reply by farmgas on February 7, 2019 at 6:06am

Sounds like the well has been plugged and effort is in-place to flare off any shallow well contamination.  How much water could have been released into the shallow gas formation?  Anything new in the remediation effort?  It sounds like CNX has done a very good job to stop any further damage.   Kudos to them!

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Permalink Reply by farmgas on February 7, 2019 at 7:14am

Could the flow back water migrate naturally to the surface?

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Permalink Reply by farmgas on February 7, 2019 at 2:44pm

What`s next now?

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Permalink Reply by farmgas on February 17, 2019 at 5:59am

Given the circumstances of this well problem, is it possible to remove the 5.5" pipe to a point below the defective section and replace or repair it, and then reinstall it or new pipe?   Can the heavy mud be removed from the well?

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Permalink Reply by farmgas on February 17, 2019 at 12:05pm

OT - what could the reduced production be by %?   It would just mean a longer ROI for CNX with a reduced production volume, right?   It seems to me that they have responded appropriately and aggressively to correct this problem.   Hopefully investors will agree.  Is there a rule of thumb for gas volume per inch of pipe size?

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Permalink Reply by william Allen. Ladd on February 18, 2019 at 5:58am

Old Timer hello!

Slide rule...Hmmmm.  My father did a lot of slide rule figuring back in the 1940's. He worked for telephone company and about 1946 figured out circuitry that connected the old STEP SYSTEM to work with the DIRECT DIAL SYSTEM we use today.  In fact he was invited to attend an important meeting  that was held concerning the invention of the TRANSISTOR  and how it worked. As you know the transistor effectlvly did away with vacuum tubes in radio and Television. 

Dad tried to teach me the basics of slide rule  but my brain was just too feeble.

Take care my friend and keep warm.

Granddad Ladd

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Permalink Reply by farmgas on February 18, 2019 at 2:19pm

Ha ha!  It sounds like you guys had the pleasure & challenge of using a Slide rule.  I never could use one!   The calculator & computer are my friends!!   So OT,  it sounds feasible to redo this well albeit at lower production.   Has this been done before?   It seems to me that well pressures could force the mud back up the 5.5 pipe and into a ground container.  As you replied recently, time is needed by CNX to figure out what to do.   Could this problem on the Shaw pad divert their attention back into the Northern part of the Central PA area?   I hear a Slide rule makes a good paper weight!

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Permalink Reply by farmgas on February 19, 2019 at 4:47am

Do you think CNX will divert their drilling activity away from the Beaver Run Reservoir for awhile?  If so, would they move towards their other holdings in Indiana or Jefferson counties?

Junk pipe sounds like a big problem potential for the industry.  Does a gas company specify standards for this pipe, and origin (country) of manufacture?

I`m not from the northern counties of Central PA, but it really sounds like your area has and will experience a lot of growth.   Do you have growth incentive due to being located closer to major pipelines and market?

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Permalink Reply by farmgas on February 19, 2019 at 10:43am

An article in Pittsburgh Business Times is saying the Shaw well will cost CNX $30 million.   Wonder if that includes the cost to drill the well plus clean-up or just the remediation?   Ouch!  

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Permalink Reply by farmgas on February 20, 2019 at 3:01pm

The Pittsburgh Post Gazette has reported that CNX will plug the Shaw 1G well and postpone fracking the other 3 wells on the pad.   The delay to frack the other 3 wells may not happen until 2021.   It has been reported that no harm is found to the environment.   What do you think of this news, OT?

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Permalink Reply by farmgas on February 21, 2019 at 1:32pm

Thanks OT for sharing your knowledge of this industry.   Sure sounds like a risky venture with known and unknown pitfalls to overcome.   Will the industry know someday exactly what happened to this well?  With regard to the swelling or water soaking issue, I`m confused how the shale can swell if it isn`t porous rock?   In other words, how does the shale absorb water?  Will this water eventually exit along with the gas to the well bore? 

In other related wells with apparent water issues are two Utica wells each drilled by CNX and XTO Energy in Indiana County.  It has been speculated that each well was less then expected because of excess water in the shale layer.   Could this "water soaking" condition occur naturally?   This sounds like one of those unknown pitfalls!

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Permalink Reply by farmgas on February 22, 2019 at 2:31am

Do the initial well core samples help to identify the composition of the shale and it`s likely hood of absorbing more or less water?   The gas company should know early on how to manage water removal based upon these core samples ... right?   Can there be a naturally occurring flood of water in the shale causing them to be "water soaked" beyond usability?

Is the "hydration of shale" or "expansive soils" (see I did google how shale absorbs water) present for both Marcellus or Utica wells? 

Is the case study you discuss taking place in your region of Northern Central PA?   Do all regions pose the same problems?

Will leaving unfracked wells soak for several years cause them to be unusable?

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