Indiana County Marchand Unit

Does anyone have an update on the Marchand Unit in North Mahoning Township.  One unit is producing and four additional permits are on the books.

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Permalink Reply by farmgas on March 29, 2018 at 10:20am

Excellent ideas, BW!  I would like to think it`s because of the  well volume.   The pad is in a country setting without many houses around it, but it is next to a highway.  What you think about the bright yellow center of the flame?

Permalink Reply by Spike's Kin on March 29, 2018 at 12:24pm
Bud said it sounded like a jet engine from 5 miles away... Noise mitigation sounds like a better plan
Permalink Reply by farmgas on April 2, 2018 at 3:42am

SK - is the flaring still taking place today?   What`s next?

Permalink Reply by Bullfrex on April 2, 2018 at 11:24am

This is an informative discourse, thanks to all.

Spike,

Now a question-italicized taken from one of your earlier posts...." it will be very disruptive for them. (18 months of flat high production is much worse versus Marcellus wells with their typical 3 month spike-- which has itself been disruptive.)"

May I ask you to explain that statement in a bit more detail? I am afraid the meaning is lost on me!

Thanks!

Permalink Reply by Spike's Kin on April 3, 2018 at 1:47am
If there isn't new dedicated-to-Utica takeaway pipeline capacity built in Indiana County, conventional low pressure wells are likely to be shut in during the initial peak production of a Utica well nearby. This peak is 14-18 months with a Utica well, per lateral, versus 3 months for a Marcellus well. So the practice of locking up land with old leases held by production from these low-volume stripper wells could be turned upside down by just a few nearby Utica wells. It is most curious that CNX is now selling their coventional wells after all this (already Marcellus disrupted) time, and almost as curious that a company would buy them and expect to make money servicing and plugging shut-in, depleted 10+ year old wells. If the plan is to lose money, it's more readily explained-- but that's likely even more disruptive to holding leases by production.
Permalink Reply by Blueflame_02 on April 3, 2018 at 2:16am

I think though that many of these older fields are on lower line pressure lines and do not have to compete for pressure until a sales point farther down the road.. i.e. they aren't competing as soon as the gas hits surface. Also with the implementation of compression, many companies can lower line pressure significantly to get that gas to sales. 

Permalink Reply by farmgas on April 3, 2018 at 2:56am

BF - interesting points!  The MS/Utica gas will need dedicated pipelines to avoid disruption of conventional wells in lower pressure pipelines.  Is the MS/Utica gas pressure reduced  down to enter the DTI pipeline?   Shallow gas pressure can be boosted up to enter the same pipeline through compression.  How do the gas companies manage pressure at the well head or gathering pipelines  prior to injection into major trunk lines?

Permalink Reply by farmgas on April 3, 2018 at 2:49am

Exactly my point and concern too, SK!   Why would a company buy these old wells knowing many are at the end of their   productive life and incur the cost of plugging them.  Unless if that cost is not planned for and wells are just going to be  abandoned.

I suspect many of these wells are 40-50+ years old. 

I think CNX & XTO plan on having dedicated Marcellus/Utica pipeline takeaway capacity in Indiana County to the DTI pipeline.

Permalink Reply by Spike's Kin on April 3, 2018 at 3:29am
Farmgas, if I understand correctly (mybadmittedly limited understanding, I'm not industry insider), the standard gathering pressure in areas where Marcellus development has occurred is now commonly 1500 psi. But before this, conventional well gathering system was 500 psi. Boosting pressures is certainly possible, but where's the energy to do so coming from? Natural gas from the wells upstream, many cases. A nominally-producing well will likely be shut in rather than have it's cost of operations (e.g. compression) exceed it's profits, I should think.
Utica well type curves show number of months until a well hits line pressure (1500 psi). Pressure and volumes are managed with chokes to limit what leaves the Utica well head, for a number of reasons, not least of which is that ultimate recovery improves by adjusting so that the fractures remain flowing and not plug back up prematurely
Permalink Reply by farmgas on April 4, 2018 at 12:06pm

I drove by the Marchand pad this morning and the well was being flared again, but later in the afternoon it was off.  Anyone know what was happening?    Anyone have testing data yet?  Any information provided to the DEP yet?

Permalink Reply by farmgas on April 4, 2018 at 12:36pm

I have learned the DEP "Completions Report" provided by CNX shows the following information:

24hr. Open-Flow MCF/Day/Date.... 11,000MCF/Day / 3/20/2018

24hr. Shut-in Pressure/Date.... 7,105 PSI / 3/22/18

What do these number show for this well?   Is it a Super Well?

Permalink Reply by Spike's Kin on April 4, 2018 at 1:33pm
That would be roughly 1/6X free-flow volume of either Aikens or Gaut Utica wells (62MM or million cubic feet/24 hrs). The 11MM volume correlates to a good Marcellus completion. Any chance CNX also fracked and completed a complete a second Marcellus DUC alongside Marchand 3M Utica well? Or perhaps they're choking it back Day 1?
Aiken's was 8650 psi, if I'm remembering correctly

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