Member Info for mbarnholdt

Quite right, sorry.

I have no knowledge, but it seems like tweeting outside of normal corporate disclosures might get you into to trouble with regulatory authorities. Maybe not, its a brave new world.

Where are (or aren't) we on the Coho PL?

Appreciate your comments MJ, my reservoir engineering and petrophysical knowledge is amateur at best. I remember hearing about Ekofisk when I was with Shell. Much consternation with Phllips as operator.

MJ, for some reason I got the impression that the Cascadura reservoirs would be considered overpressured, i.e. more than the depth psi gradient? Is that a correct assumption or did I just assume from what was said without doing the math?

A good analysis Scott. Commingling production can also cause cross flow problems between reservoirs, and make difficult allocation and estimation of reserves as well. Better as you say to have a dedicated drainage point or two for each individual reservoir. I did see a few dual completions (multiple tubing strings in one well bore) in my Shell time, but not very often. I think a lot will depend also on how effectively the fluids are transmitted through the reservoir, and if there are any unpenetrated fault blocks which also will likely need a dedicated well. Saw one reservoir at Shell some years back where a pressure transient due to a change in one well was also noticed in a second well at a distance of about 12 miles as a recall. Thats the kind of reservoir continuity and connectivity that the reservoir engineering community dreams about.

Forgive me for being the doubting Thomas. Have we actually started construction of the pipeline for Coho, and if so, when will be first gas?

That would sure be nice-new rig crank out 3 or 4 oil wells in a month. Prices still look good for the moment as well. Not sure what will happen as this delta variant gets out of hand.

Would be interesting to note what they anticipate spud date is on the legacy wells using the new rig. Be nice to add some volumes that could be put on production quickly. Interested to see what happens if they go a bit deeper on the legacy block.

AVD has an interesting business model, one I thought I'd like to do if the opportunity ever presented itself-being a non operator or advisor, picking good partners and opportunities, having a sharp but lean technical staff. There is one similar case here in the states, NOG which works the Bakken primarily. I owned on and off many times, but it never really took off until recently. As usual, I was a few days late and dollars short when it took off. The story of my life.

Exactly, and can help you solve or narrow the ranges for some of the other variables, and see if any kind of skin is present. Odd, for some reason I thought the Kruse would be oil bearing rather than gas.

Wonder if they are running a multi rate test at Chinook. Might explain a few things.

I appreciate the insights on the rig-can't wait until its here and at work!

The only thing that disturbs me a little bit from that tweet is the amount of drilling problems (stuck pipe, blowout, etc.) drilling into the Herrera. Granted, a lot of it is from Shell 50+ years ago. Couple with formation damage on a couple of our wells. Hopefully our boys on the drilling side have learned and can manage the mud weight to provide well control, without being too heavy and encroaching into the objective formations.

If they have that many high return drilling opportunities, I can't imagine that they would want to pay a dividend any time soon, assuming we can get some good cash flow going soon.

I think when Shell originally looked at this was back in the 1960's, and it was essentially a stranded gas situation. I suspect there was some seismic shot way back when, was probably somewhat primitive by today's standards. Not sure how or if would have some value today-when I was with Shell when they started putting up seismic lines and geophysics my eyes would start to cross and brain cease to function.

One other thing its hard to appreciate unless you've worked there, is how long it takes to get decisions (at least at lower and mid management) made within Shell. I had submitted some questions a few weeks back to Touchstone, and Paul was kind enough to respond. He alluded to the fact the the Coho volumes were tied up in Shell's "processes." Shell generally doesn't make a decision without all disciplines signing off on (HR, HSE, Operations, Engineering, Marketing, etc.) which in theory, ensures the best decisions are made, but slows things down like you would not believe. I have been gone since 2015, but I can't imagine that things have changed that much. This is just my opinion as a 32+ year ex-Shell veteran and should not be construed otherwise.

Strange how the three markets (UK, Can, US) move sometimes in different direction. Exchange rates, arbitrage? Seems to be a lag effect of a day sometimes, not sure which market is the real leader in a trend.

Boy do i second that motion. 10-12 mmfc/d would be nice to restore credibility with the markets and supplement activities. Nice to see the minister taking active interest-have heard he would like to see coho online in August. Perhaps if Shell is indeed the obstacle, he can light a fire under the rear ends of my former employer.

Not sure why you would want to do that, being so close to a pipeline. As it mentions, mostly for getting flares out and for stranded gas situations on a small scale. They were a bit pricey as I recall also.

Just bought into this last week, so fairly new into. Assuming this turns out to be a successful well, how long do they reckon to put on production?