Tuesday, December 18, 2018

Break Even Costs? Where Does One Even Start? -- December 18, 2018

Disclaimer: there may be some hyperbole in this post, but I think it's pretty accurate. I am inappropriately exuberant about the Bakken. 

The well:
  • 17498, 498, MRO, Chimney Butte 34-11H, API: 33-025-00804, Bailey, t11/08; cum 344K 10/18;
So, this well was drilled back in 2008, at the beginning of the Bakken. At that time, it may or may not have been a good well. It may have paid for itself; it may have been a financial disaster. Who knows? But 2008? That's ancient history for the Bakken. Those costs have long been "booked." But the well did what it was intended to do:
  • provide the company with knowledge about the geology of the drilling unit; and,
  • hold the lease by production (and the well held the lease for ten years) until the company was ready to drill in the area again
Production after the initial frack:
BAKKEN7-20092924632490685113611360
BAKKEN6-20093027922758760152115210
BAKKEN5-20093134933571770183818380
BAKKEN4-20093034913605738214321430
BAKKEN3-20093135753420600214221420
BAKKEN2-20092834003399553171417140
BAKKEN1-20093049154829862263526350
BAKKEN12-20082634313808200115611560
BAKKEN11-20082877537263232740108223188
BAKKEN10-20082228462703135146801468

Then in late 2017/early 2018, MRO went back into the area and drilled a few more wells. See graphic at this post.

And then look what this well did when MRO went back into drill some more wells in that area.
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN10-2018312230022476160062309421357130
BAKKEN9-20183030240303654553522432187881531
BAKKEN8-20183135012351913022722880963210784
BAKKEN7-20182832033320783508720329516612950
BAKKEN6-20182840585395717999239267636507
BAKKEN5-20180000000
BAKKEN4-20180000000
BAKKEN3-20180000000
BAKKEN2-20180000000
BAKKEN1-20180000000
BAKKEN12-20170000000
BAKKEN11-20170000000
BAKKEN10-201700320000
BAKKEN9-2017296756903566380397
BAKKEN8-201731828914335722045

This well was a stripper well by 2017, producing less than 1,000 bbls/month. But then in 2018, production jumped to 41,000 bbls/month.

The company did not have to pay exorbitant costs for a new lease; did not have to prepare a new pad; did not have to build a new 10-mile road out out to the pad; did not have to re-negotiate new leases with a gazillion mineral rights owners; did not have to run a new electricity line out to the site; did not have to bring out a new fractionator; and, it's possible frack water/produced water/crude oil pipelines were already in the area.

For the cost of a re-frack, MRO got a huge well. The original frack was an open-hole frack with less than 500,000 pounds of sand. Most of the cost of this well back in 2008 was the cost of drilling, not much cost in fracking it. Now in 2018, no costs of drilling, but simply fracking. That's not quite true.

MRO put a rig back on this site. In 2008, setbacks were 500 feet. Now, under new rules, the horizontal could be extended. MRO redrilled part of the lateral, drilling a sidetrack, straightening out the heel portion of the well, and extending the original length. Pretty cool, huh?

The frack data is not posted by NDIC yet but according to FracFocus, this was a small/medium frack: 5.7 million gallons; 89.4% water.

Frack sand is plentiful; has come down in cost. This was a small/medium re-frack. This well will go on to produce for 35 years. It will undergo multiple re-works; small re-fracks; major re-fracks; probably see more target zones drilled; and, benefit from neighboring fracks.

How does one even begin to calculate the break even costs of Bakken wells? The experts still use the same methods that were used by folks calculating break-even costs in conventional drilling.

By the way, how does one even "appraise" these Bakken wells? This is absolutely fascinating. When a grandfather has a trust, and the trust "goes" to his six grandchildren, for tax purposes, etc., the wells must be appraised at some point. How do they even begin to appraise these wells? I have no idea.

Full production profile for this well can be found here.

4 comments:

  1. Great breakdown of the issue. Break even point is such a moving target. As I stated earlier, it is almost a moot point.
    More to the point is where the producers determine what is profitable price/Barrel for them.
    That is when they will reduce or cut production. Another of my 2 cents worth

    ReplyDelete
    Replies
    1. Unfortunately, with the price of oil falling as fast as it is, we may find out sooner than later.

      Delete
  2. Wouldn't the appraisal start with potential bbls/acre URR, then evaluate what's been extracted vs what's left? It's not the total resource so much as the rate and timing of production.

    ReplyDelete
    Replies
    1. That's how I see it. The problem is that the USGS really only knows much about the middle Bakken; a little bit about the first bench of the Three Forks and nothing about the lower benches.

      Delete

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