thuja wrote:Ugh- you win Oil-Finder- we will have oil....forever!
Now you're beginning to see the light.
thuja wrote:Ugh- you win Oil-Finder- we will have oil....forever!
Oil-Finder wrote:Let's see how doable this is . . .
The US side of the Williston Basin, which contains the Bakken formation, encompasses approximately 143,000 square miles.
My research on Bakken well production indicates that, after an initial period of high production lasting a few months to a year, flow rates stabilize at around 150-300 bpd and stay that way for an extremely long time (source, source, and source).
I have read well spacing patterns in the Bakken including 160 acres, 40 acres, and 640 acres (1 square mile). Let's be conservative and go with 1-square-mile spacing.
Let's say that only 1/4 of the square miles in the Williston Basin end up with oil wells on them (sounds reasonable?). That would be 35,750 square miles, and thus, 35,750 wells using our spacing pattern.
Let's assume a low-ish average production rate of 200 bpd per well. With that figure, 35,750 wells would produce 7.15 million barrels/day.
According to this here, the average cost of a well in the Williston Basin is up to $3-$5 million, though I've seen figures as low as $2 million, and even less for some Canadian sources.
Let's go with an average of $4 million each. At that price, 35,750 wells would cost $143 billion total.
Sounds like a lot, doesn't it? But keep in mind that Petrobras expects to spend $50-$100 billion just to develop the 5-8 billion barrels in Tupi. Suddenly the Bakken looks like a bargain.
And before you gasp at the 35,750 wells, keep in mind that Pemex expects to drill 13,500 wells to develop Chicontepec over the next 15 years.
To be sure, developing the Bakken to high production rates could take 10-20 years, but there's nothing un-doable about it. And it would hardly be the first time a large oil formation took a decade or more to fully develop!
The Bakken is a geological formation of siltstone and sandstone about 300 metres below the Mississippian formation, where most Saskatchewan light oil production comes from. Bakken wells tend to be highly productive (200 barrels a day or more), producing sweet, light crude oil with 41 degree gravity, basically the highest grade of crude oil you can find anywhere.
thuja wrote:Well done! Hey I'm done with the debate tonight brother...
But just a comment- the arguments you make for how oil production will last...forever..needs to be backed up by petroelum geologists, think tanks and reserach institutes to have much validity here. I tried to point to the most cornucopian of the bunch, CERA, to describe their views. You seem to be meandering past their rosy views to a world that has a ceaseless supply of never ending crude...
No credible person believes that...because the evidence isn't there...
Take it back a notch. We'll still dabate you...but we won't think you're a loon...
Nicholai wrote:That's not what he means.
Everything is coming up roses, eh Oil Finder?
thuja wrote:But I am a tad surprised by your talk JD- I seem to remember you always talking about how peak oil is a joke- it doesn't matter, etc. But here you are talking about being at a plateau phase. Plateau is another word for peak- just a longer and less sharp peak...have you come around to that idea that we are surfing the top of the peak now?
A little perspective on the Bakken formation:
My grandfather had a little spare cash and bought a piece of land (1/2 section) from a real estate broker who had bought it at a tax sale shortly after WWI. Just into Montana from the North Dakota border where the Yellowstone River is located (Richland County). They knew there was oil when he bought or soon after.
The problem--it was too little, too deep. In today's dollars it might cost a million dollars to drill down 2 miles to the oil. If you borrowed the money from a bank, you would get enough oil to pay about 1/3 of the interest on the loan. The rest you would have to pay out of your own pocket. If you didn't have it the bank would foreclose, sell the well (and associated mineral rights (leased or owned) and take a loss and someone would buy it at fair value of a couple of hundred thousand. You would not drill again and the bank would not lend again on such a venture.
About 10 years ago horizontal drilling became good enough to exploit oil in the Bakken and similiar formations. A horizontal well might cost 3 million dollars but a bilateral horizontal well would have about a mile of pipe exposed to the Bakken and bring up mayvbe 20x the oil of a vertical well. Enough oil to pay off the well in 3-9 months. After that a lot of profit. There are about 70 drilling rigs operating in Richland County according to a cousin who took a look last summer. So this is a "hot" area for drilling today. Scary because wells there according to 1-2 year old statistics I looked up from the Montana Oil Conservation Board show Bakken horizontal wells produce from zero to about a thousand barrels a day (initially). Call it 500 barrels average.
What is scary to me is that this is an exciting and "hot" drilling area today. Remember that the Spindletop well that started the Texas oil rush in that particular field initially produced over 100,000 barrels per day. One figure I saw was 140,000 barrels per day. Now that was something to get excited about! 500 barrels per day is pretty pathetic by comparison. Yet that is what excites oil drillers today.
But that is where we are today. Exploration companies can make good money on the Bakken. But it will never replace the big stuff that was discovered in the past.
FWIW
p.s.
The Bakken wells seem to have a short life. The first well on grandfathers mineral rights (the land was sold without rights) and adjacent (it takes 1280 acres (2 square miles)) to drill a horizontal Bakken well in Montana) after about 2 1/2 years is only producing about 1/3 of initial rate. If Spindletop had been drilled as a horizontal well it might have had a shorter life too. But if they got 20x the flow that would be almost 3,000,000 barrels per day. So horizontal wells do produce faster. But with just so much oil in place, they do not last as long.
No free lunch. Higher production rates do produce shorter lived wells.
TheDude wrote:Bakken is held back by its flow rates, as I've explained about 20 times.
Oil-Finder wrote:The US side of the Williston Basin, which contains the Bakken formation, encompasses approximately 143,000 square miles.
My research on Bakken well production indicates that, after an initial period of high production lasting a few months to a year, flow rates stabilize at around 150-300 bpd and stay that way for an extremely long time (source, source, and source).
I have read well spacing patterns in the Bakken including 160 acres, 40 acres, and 640 acres (1 square mile). Let's be conservative and go with 1-square-mile spacing.
Let's say that only 1/4 of the square miles in the Williston Basin end up with oil wells on them (sounds reasonable?). That would be 35,750 square miles, and thus, 35,750 wells using our spacing pattern.
Let's assume a low-ish average production rate of 200 bpd per well. With that figure, 35,750 wells would produce 7.15 million barrels/day.
According to this here, the average cost of a well in the Williston Basin is up to $3-$5 million, though I've seen figures as low as $2 million, and even less for some Canadian sources.
Let's go with an average of $4 million each. At that price, 35,750 wells would cost $143 billion total.
Sounds like a lot, doesn't it? But keep in mind that Petrobras expects to spend $50-$100 billion just to develop the 5-8 billion barrels in Tupi. Suddenly the Bakken looks like a bargain.
And before you gasp at the 35,750 wells, keep in mind that Pemex expects to drill 13,500 wells to develop Chicontepec over the next 15 years.
To be sure, developing the Bakken to high production rates could take 10-20 years, but there's nothing un-doable about it. And it would hardly be the first time a large oil formation took a decade or more to fully develop!
The first well drilled was the Burau 4 well in Burau County. Although oil and gas indications were not detected during drilling, the well was completed and is producing at a stabilized rate of approximately 25 barrels per day of oil with 65% water cut.
Oil-Finder wrote:If you mean why haven't CERA, the EIA and the IEA not included these things in their analyses, it's probably because they all prefer to be very conservative when putting out figures to be digested by the public.
Oil-Finder wrote:Nicholai wrote:That's not what he means.
If you mean why haven't CERA, the EIA and the IEA not included these things in their analyses, it's probably because they all prefer to be very conservative when putting out figures to be digested by the public. And in some cases, they might not be aware of some of these very recent developments. CERA's analysis last November, for example, was made before both the Bohai Bay discovery in May of this year and the Tupi discovery early last month were announced. Both Bohai Bay and Tupi, it now appears, are just tips of the icebergs. And I've got a hunch CERA did not know about the Bakken. The only one of those entities I'm aware of that's been aware of the Bakken is the EIA, but they've chosen to minimize its significance until the USGS finishes its study.Everything is coming up roses, eh Oil Finder?
Things usually do work out for the best, don't they.
JohnDenver wrote:thuja wrote:But I am a tad surprised by your talk JD- I seem to remember you always talking about how peak oil is a joke- it doesn't matter, etc. But here you are talking about being at a plateau phase. Plateau is another word for peak- just a longer and less sharp peak...have you come around to that idea that we are surfing the top of the peak now?
Personally, I think liquids still have some room to grow. Ordinary crude appears to have peaked in May 2005, but it's still too early to call it for sure. It's very important to remember that oil prices only began to move up in 2004 -- 3 years ago -- and the oil industry can't respond immediately to price signals. We'll have a much better idea where things are going in a year or two.
That said, I think it's good, from a debunking standpoint, to accept the peak oiler claim that we are peaking now, and show that, even then, we aren't in serious trouble. If it turns out that we aren't peaking now, so much the better.
What a bizarre statement. So you're saying that it's good to believe something because it allows yiou to rubbish the ideas of others? Well, believing something is rather different from it actually being true, so that belief does nothing to help your debunking arguments other than to make them look weak.JohnDenver wrote:That said, I think it's good, from a debunking standpoint, to accept the peak oiler claim that we are peaking now, and show that, even then, we aren't in serious trouble. If it turns out that we aren't peaking now, so much the better.
skyemoor wrote:Yes, though some persist in spinning cornucopian fantasies. Let's examine one such...
Let's walk through the problems with the above one at a time;
1. The paper on nd.gov that Oil-Finder relies on is non-attributed; there are no authors or date of publication on it anywhere. Hence, we have little to go on with regards to the knowledge and veracity of the author/authors besides the gross indicator of the website itself.
2. The author/authors state "The methods used by Price to determine the amount of hydrocarbons generated by the Bakken are different from the traditional petroleum geochemical practices and are under dispute."
3. The 'research' performed by Oil-Finder (OF) resulted in these findings;The first well drilled was the Burau 4 well in Burau County. Although oil and gas indications were not detected during drilling, the well was completed and is producing at a stabilized rate of approximately 25 barrels per day of oil with 65% water cut.
Hardly suggesting that "flow rates stabilize at around 150-300 bpd and stay that way for an extremely long time", whatever 'extremely' means. While 2007 production from Elm Coulee averaged ~53,000 barrels per day, there is no confidence in extrapolating any figure over 1000s of wells without well-documented drilling data from all of the sites in question.
4. Well numbers and spacings: OF's provided reference ( http://www.secinfo.com/d11MXs.v1Eu2.c.htm ) states that well spacings are 640 acres and the gross acreage of the Williston Basin - Bakken Oil Play is 90,000 acres. This translates to 140 wells, not 35,000. 140 wells at the above referenced 25 barrels per day equates to 3500 barrels of oil per day, which is chump change at best. Even at 'higher' production figures of 200 barrels per day, Williston-Bakken is still a very minor player at best.
thuja wrote:Oil-Finder- this is why I am suggesting you are treading into loon category here. For you to say that you have learned about finds that are likely to change everything forever, and to state that groups such as the EIA, IEA and CERA are minimizing or worse, haven't seen the data yet...while you are aware of how unbelievably tremendous they are...is ludicrous.
Step back from the edge Finder...on the other side you will be laughed at for making assumptions based on your own research without any backing from established Agencies and thinktanks.
Take a look back at a lot of old threads where people went tooth and nail at each other over Yergin/CERA vs. Campbell/ASPO. You aren't even in the Yergin camp anymore- you are in the world of make-believe. Again, take it back a notch. Most folks won't agree with you if you take a CERA position here...but at least you'll be in the realm of the sane...
TheDude wrote:One more bit of Bakken, comments on the 24th at TOD: Permalink
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Sounds like this horizontal drilling right from the start is having the same effect as when applied in EOR. 35,750 wells might face a few land use snags, too.
I'd like to see a detailed analysis of the Bakken formation's potential.
There doesn't seem to be much interest in it at the moment online though, making me think there's bigger fish to fry.
Estimates of URR are all over the map, according to your link your link. High as 50%, low as 3%, which equates to a whopping 12 billion. How long will that take to make much difference?
Oh, and did I mention financial mayhem or global warming or natural gas peaking soon?
JD will bring up Laherre's figure of 2020 as a repost for NG. Too bad we can't build pipelines under the Pacific! Or more than four LNG terminals in the lower 48.
thuja wrote:I guess when you say debunking, you mean peaking and then declining oil production won't cause "serious trouble". If by that you don't believe we will turn into Mad Max road warriors overnight...then sure.
But we are already experiencing "serious trouble" in the form of accelerating energy prices... which in turn has had an effect on the world economy, inflation, which in turn is already having an effect on the world's poor and middle class. Extrapolating out with a continued plateau and then a deline in available oil is likley to exacerbate these economic effects. So to say there is no "serious" effect is just strange...because I consider you to be intelligent.
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