Welcome to the Million Dollar Way

The purpose of this site is educational only. It is an attempt to provide an overview of "the Bakken" and to direct folks to the news stories coming out of the North Dakota oil industry. It is very, very superficial in scope. I probably understand about 1 percent of all that goes on in the industry (if that much). I have a poor memory and often make simple mistakes, but will correct them when I become aware of them. I find myself making more typographical errors as the years go by.

I grew up in Williston, in the heart of the Williston Oil Basin (WOB) and have followed the oil industry my entire life, in a very general way. I invest in publicly traded companies through the stock market, but my investments in WOB are trivial compared to my overall investment portfolio. I own no mineral rights, and have no inside information regarding the WOB. I do talk with people who live there and occasionally receive information second- and third-hand. I do not subscribe to any newsletters or the North Dakota Industrial Commission website tools, although I may do that sometime in the future (subscriptions are relatively inexpensive).

I enjoy following the activity in the WOB, but am not sure that investing in the oil companies in the WOB is the best way to go; there are many other opportunities in the stock market that might be better. At the current time, of the Williston Oil Basin-related companies, I am invested in the following: MDU, BR (COP), CLR, NOG, ENB, EPD, EEP, BNI, SLB. I trade in and out of these companies with others in the WOB. I would never recommend any companies because everyone's investment styles are different. I am often accused of being too exuberant about the WOB, and I admit it. I find the oil activity in North Dakota very interesting. It's easy to be negative about things in life, so I tend to over-compensate in some areas by being too optimistic when it comes to the oil industry.

I am definitely a novice at all this, so if something I say doesn't seem correct, it may not be. There are many ways on the web to cross-check "facts."


The largest continuous oil reservoir in the continental United States.

NEWS

Hess will double the number of rigs in the Bakken from three in 2009 to six or seven in 2010, and will spend approximately $1 billion/year in capital expenditures for the next four to five years in the Bakken. November 14, 2009.

The excitement continues. Even minor players are announcing major plans for 2010. Another example is GeoResources, Inc. Posted November 12, 2009.

North Dakota reports record oil lease auction. North Dakota holds an auction to lease a portion of state lands every three months. The most recent auction resulted in a record $72 million for the state; the previous high was $30 million in 1980 (but adjusted for inflation, about $80 million). Average lease was $1000/acre with highest rate paid in prolific Mountrail county, about $3000/acre. By the way, almost all the money goes for public schools. Comment: producers don't pay top dollar for leases just to lose them; this record auction suggests a very, very active 2010 drilling program in North Dakota. November 6, 2009.

Buffett Buys Burlington: Although BNI is a national (perhaps, better said, a regional) railroad, it has a significant presence in North Dakota. Today (November 3, 2009) Warren Buffett announced he will buy what he already doesn't own of BNI. November, 3, 2009.

BEXP announces another great well. Meanwhile, BEXP announces another great well (with first day production of 1,776 barrels of oil equivalent), this time northwest of Williston, pretty much at the extreme of their acreage. Although the well is in a designated oil field (the Bull Butte), it might as well be a wildcat as remote and lonely as it is. We've gotten spoiled in the Bakken oil patch. We are no longer surprised by wells producing greater than a thousand barrels the first day; they only hit the headlines when they approach 4,000 barrels. Oh, well. By the way, this was a 28-stage fracture stimulation. November, 2009.

Denbury buys Encore. Denbury announced a couple days ago that it was buying Encore and that was the top news story almost everywhere; it was certainly the top news story in the oil patch. Denbury becomes one of the largest independent oil exploration and producing companies overnight by buying Encore, whose main base is in North Dakota.
Denbury's assets are primarily located in Mississippi; Denbury now goes nationwide on the shoulders of the Bakken and the Three Forks Sanish. If you think "the Bakken" is over-hyped, check out "monster wells." Remember, the list of monster wells is only the tip of the iceberg, as they say. November, 2009.

What's not to love: a) oil back to a new, higher trading range; b) the major oil companies losing money or reporting lower earnings (forestalls talk of windfall profits tax, driving Congress nuts); and, c) a well in the Bakken at almost 5,000 boepd on initial production -- a new record (reported this week). At $50/barrel, that is $250,000 a day. That's more than a million dollars a week. If I'm wrong on my math, someone will correct me. Yes, the Bakken has severe production declines but let's see what this well is doing a year from now. October, 2009.

The Grenora "barnburner." And, I'm still waiting to hear how the "barnburner" up by Grenora is doing. October, 2009.

And now, another monster well, the Chandler James, in production for one full year, producing at a rate of 35,000 barrels/month, which at $50/barrel, is $19 million/year. Yeah, I'm excited. October, 2009.

Now, about the blog.

The "old" Million Dollar Way was very eclectic: literature, music, "the Bakken," energy in general, and personal musings. Ninety-nine percent of visitors to the site visited only Bakken-related sites, and even then, only one or two specific pages. So, this site will, at least for the time being, concentrate on "the Bakken," more correctly the North Dakota oil industry. I have an emotional interest in "the Bakken." I wear my heart on my sleeve when it comes to "the Bakken." This is where I grew up. I have no background or connection with the oil industry. I own no mineral rights.

I am an investor, but my investments in "the Bakken" are trivial compared to my overall investments. I am more emotionally attached to "the Bakken" than interested in investments. I have no inside information. I do not subscribe to any premium services regarding "the Bakken." I no longer live in North Dakota, but I visit at least once a year and see first-hand what is going on. My information comes primarily from the NDIC website and the internet in general.

Occasionally I will get input third-hand or fourth-hand from someone I know still living in the Williston area. (Williston, North Dakota, USA, is at the center of the Williston Oil Basin, home of "the Bakken.") Bottom line: I'm pretty much a novice at all this. I know I will make many mistakes on this website but will correct them when brought to my attention.

I would not use my site to make investment decisions, although it may be one of several data points to lead you in certain directions. Much of what I write can look factual, when in fact it is opinion or my general understanding of the issue. Over time, I assume this site will evolve, based on reader feedback. As expected, it was hard not to have op-ed pieces, and some have already been added.

The site's name. The friends of the "old" Million Dollar Way know that the name of the site has nothing to do with money -- at least not directly in terms of me or investing. When I was growing up, the road leading out of Williston was known as the "Million Dollar Way" because of the automobile dealerships and businesses related to the oil industry.

The "Million Dollar Way" was my road out of town to an exciting life. This "Million Dollar Way" site is a new road leading me to new destinations.

Profile of Williston, North Dakota, USA.
North Dakota: Most Economically Stable State, November 2, 2009
The Oil Drum's Assessment of the Bakken, November 2, 2009

*****

This blog seems to be optimized for Firefox/MacOS. I find errors in formatting when I check the blog on Internet Explorer browsers; perhaps they are older versions of Internet Explorer.

Last updated: November 14, 2009.

Oil Services Companies of Interest

Disclaimer: this is not an investment site; do not make any decisions based on anything you read here or what you think you may have read here. 

SLB: several stories today, October 17, 2013 --

• SLB reached new 52-week high yesterday
• how SLB could outpace Weatherford and Halliburton, Motley Fool
• SLB is not done climbing, TheStreet

SLB: raises dividend; replaces Intel at #27 on the S&P 500, January 25, 2013. 

Misc: 7 small oil / natural gas companies with continues upside potential, SeekingAlpha, April 6, 2011.

DWSN: Dawson Geophysical, Inc (Seismic). Yahoo!Financial: DWSN.

ERF: Enerplus: complex tax reporting, September 23, 2010.

HEK: first mention; salt water disposal. February 22, 2011.

SLB: Yup, here it is; the speculation was correct: SLB buys Smith International. Meanwhile, Baker Hughes is buying BJ Services. February 21, 2010.

TPLM: Triangle Petroleum

• 16.5 million shares offering; 15% over-allotment authorized, March 4, 2011.

WMB: huge dividend increases following split announcement, February 20, 2011.  

Miscellaneous

Investopedia, Feb 9, 2010. Nothing new here; it's all on my site, but it's kind of fun to see a "big" site say what I've been saying for the past year.

Investor's Recap of the Bakken, 2009.

Investing: HES

Yahoo!Financial: HES (Hess Oil)

NEWS AND COMMENT

January 26, 2011: 4Q10 earnings.

December 29, 2010: Hess completes AEZ acquisition; bought TRZ one month ago. Acquisitions push Hess acreage to over 750,000 net acres in the Bakken.

First quarter, 2010, earnings call.

Fourth quarter, 2009, earnings call (4Q), Bakken specific highlights:

CAPEX, 2010: $1 billion
Increase rig count from 3 to 10 by middle of 2011; gradual ramp up

Expectation: EUR of one million barrels per dual lateral

Hess has only four (4) dual laterals in the Bakken right now
Expectation: 10,000 bopd currently to 80,000 bopd by 2015
Bakken wells economical at $40/barrel

For EUR, see FAQs, # 7.

Down below I talked about the relative poor IPs for Hess. Some have commented on my observation; note comments.

We now have another data point for a Hess well; apparently #18194 (RS-ENANDER A-155-91- 0607H-1) is still on confidential status, but reports suggest this well produced 4,387 barrels (this link is now broken; total oil, does not include gas) in October, which would be about 140 bbls/day. I don't (yet) understand the Hess nomenclature but the "0607H-1" suggests a "long" lateral and looking at the GIS map server, most of the producing wells in the immediate area are "long" (2 sections; 1280-acre spacing) wells. On a "per section" basis, this well produced, on average about 70 bbls/day in October, early in its production history. Lots of questions: has the well been frac'ed? If so, how many stages? Is the well choked back for some reason? Does Hess have a different strategy for maximizing EUR? Does Hess calculate IPs significantly different than other producers? Be that as it may, Hess has been granted two permits in the Clear Water field which is being aggressively pursued by EOG. I have all those wells on my wells-to-watch list. December 16, 2009. 

From the 3rd quarter, 2009, analyst's call via Bakken Shale Discussion Group, November 13:

Hess will double number of rigs in "the Bakken," from 3 (2009) to 6 or 7 (2010)
Hess will move toward $1 billion/year in capital expenditure next 4 - 5 years

 But the discussion group noted something much more interesting: lackluster wells.

We have all noted that some producers seem to have lackluster wells compared to others. One of the folks noted that Hess is one of those with less-than-stellar results in North Dakota. But an exception: Hess reported an IP of 1,998 boepd for the RS-Feldman. This was reported in NOG's recent update; NOG also noted that Hess used a 14-stage completion on the RS-Feldman well. That may be Hess's best well to date in the Bakken. (The RS-Feldman well is file # 17696, about 3.75 miles northwest of Stanley.) UPDATE: NDIC reported that the IP for the RS-Feldman well -- file # 17696 (this link is now broken) -- was 570 bbls/day. Also, note the decline rate from 16,000 bbls in the first full month of production to 9,000 barrels in the third month of production (most recent data). January 19, 2010. [Update, November 5, 2013: to date, this well has produced almost 200,000 bbls of oil; 198,979 bbls to be exact.]

Comment: some weeks ago I opined on the Bakken Shale Discussion Group that "in the old days [two months ago]," no one was doing multi-stage fracturing, but now it was becoming the norm. Someone responded, taking me to task, saying that multi-stage fracturing had been around for at least two years. [In fact, multi-stage fracturing has been around for at least two decades.]

I was mis-read. I was using hyperbole; of course I was aware that multi-stage fracuring was being used in the Bakken. The point I was making was that it was my opinion that not all producers were using multi-stage fracturing. It appears I may have been correct.

People who follow the industry much more closely than I do were surprised to see Hess using a 14-stage fracture stimulation. Hess has had lackluster results in the Bakken according to some; with the multi-stage fracture stimulation they may have a good well.

The thread also states: Hess drilled a Bakken/TFS stacked lateral (EN-Uran-154-93-1213H-1 / file number 18228). This well: 225, reported Mar 3, 2010; not exciting.

Fidelity (MDU): same problem?

On another note, I have also been struck by the uniformly poor Fidelity (MDU) wells in the Bakken. My hunch is that they have also been using one-stage fraction stimulation. November 14, 2009.

When reviewing the entire database, I did find a couple of very good Fidelity wells based on IPs. December 16, 2009.

Investing: XTO

Yahoo!Finance: XTO.

September 21, 2012: With all the talk about XOM maybe buying into the Bakken after its deal with DNR (September, 2012): Flashback: XOM - XTO deal

• XOM paid $41 billion
• XOM bought XTO for the natural gas
• the Bakken was simply serendipity
• a 25 percent to CLR's current market cap: $22 billion
• 1 million acres at $15,000/acre --> $15 billion

June 20, 2010: XOM shares to rise after XTO deal closes. June 20, 2010.

December 14, 2009: WOW! WOW! WOW! XOM to buy XTO at 25% premium.

The XTO web page is very, very east to navigate. Find their most recent presentations at their web page.

FAQ

1. What is the average longevity of a Bakken well?

This is probably one of the most asked questions I see. Everyone will opine on this one. Right now, the decline rate is such that the wells are probably marginal producers after seven years. However, it appears that the producers will keep these wells producing as long as possible. New technology comes along, especially the opportunity to "re-frac" and thereby extending the lifetime of the well. Producers are not allowed to "cap" oil wells in North Dakota which is allowed elsewhere. When a producer abandons a well, it is plugged with cement and cannot be re-entered. If one wants to go return to that location, the entire process starts over. At least that's my understanding.

2. What is the status of the "fill in the blank with the name of your favorite well."

I may not have that data because I don't subscribe to the NDIC database. If you cannot find the status of a certain well, pose your question on the Bakken Shale Discussion Board. If the data is available, it's likely someone will provide the information.

3. Can you give me an example of how big a royalty check should be by owning "fill in the blank with the amount of mineral acres you own."

A mineral rights owner in North Dakota might mention over a cup of coffee that she gets "a 1/8 royalty" on her mineral rights That individual might have no idea what that means; I certainly did not know what it meant years ago when my dad would tell me that he would get 1/8th royalty if they struck oil where he owned mineral rights.

Here's not an uncommon example. Someone inherits or buys or is given 10 mineral acres. The typical well in North Dakota right now "drains" 640 acres. Therefore, the mineral owner with 10 mineral acres only has 1.56% of the 640 acres that that particular well drains. Of that percent, the mineral rights owner will get 1/8th royalty (or 12.5%) of the oil. If one multiplies those two numbers (1.56% x 12.5%) one owns 0.20 percent of the oil that comes out of that well. It is not unusual for a Bakken well in North Dakota to produce about 300 barrels/day for the first month, but declines quickly after that. Multiplying the 300 barrels by the 0.20 percent (300 * 0.20) one gets 0.6 barrel/day. At $60/barrel, that would work out to about $36/day, or about $1,080/month. I don't know the tax penalty, but a 12% extraction tax would not be unreasonable so, at least $135 would be taken out by the state before you got your royalty check. There may be other taxes/fees I am not aware of, but at least that's a start. How much would it have cost you to buy those 10 mineral acres in the first place? At $2,000/acre it could have cost you $20,000 and there is every possibility that the land would never be drilled on.

I am no authority or expert on this, so I could be wrong, but this is my limited understanding.  It will be tedious, but there is a long discussion regarding royalty checks, the time line for receiving a royalty check, and other information at this site. When you get there, scroll down to the comments. Lots of interesting information.

4. What is meant by fracking?

Here's a nice 5-minute video of fracking. Or click here and scroll down. How much does it cost to frac? How long, how many workers involved? Click here and scroll down to "Degas."

5. What is the typical spacing of oil wells in North Dakota?

This will change over time. At the beginning of the current boom, most wells were spaced at either 640 acres or 1280 acres. I refer to them as "short laterals" or "long laterals," respectively. In early 2010, the state ruled that operators did not have to request permission to go to 1280-acre spacing and that appears to be the norm. However, more and more requests for 2560-acre spacing are being seen for multi-well pads. These wells will all be long laterals -- stretching the diagonal distance of two sections, about two miles.

In North Dakota most townships have 36 sections and most sections have 640 acres. (The townships and sections along the state border may be truncated). Therefore, a "short lateral," 640 acres, affects one section, whereas a "long lateral," 1280 acres, affects two sections. One can see examples of both, side-by-side, at the NDIC GIS server (map).

It is my feeling that Whiting (WLL) pioneered 1280-acre spacing in North Dakota but now these longer laterals seem to be the norm. (Oasis, November, 2009; EOG, December, 2009, are both recent examples. Someone has opined that 90% of Hess' 130 wells in ND are long laterals.)

A 640-acre well has a lateral that is about one mile long; a 1280-acre well has a lateral that is about two miles long. Remember, a section is one square mile (one mile wide, one mile long); a township is generally six miles on a side; 36 square miles. And as long as I'm rambling, the federal government gave the local school district the mineral rights in one section (generally, I believe, section 16) in each township. States were given authority to give local school districts additional sections; North Dakota gave sections 16 and 36 to the schools.

Update:  An example of how fast things are moving in North Dakota, EOG has been granted a permit for 2560-acre spacing and placing six (6) wells in one section, each spaced 50 feet from the next in a straight line. CLR, I believe, has a plan to put its EcoPads along the Williams County-Divide County border. January 22, 2010.

Update: CLR announced its first Eco-Pad; it will be in McKenzie County.

6. When will the EOG/BNI railroad oil tanker operation become operational (Stanley, ND)? Are there plans for more such terminals?

The EOG/Stanley operation was scheduled to come on line in February, 2010. In fact, it came in early: the first train left Stanley, North Dakota, on New Year's Eve, December 31, 2009.  Initially one 100-unit train will depart daily with plans to run as many as four trains per day. EOG, in its April, 2010, presentation, said two trains/week were running.

Note: when oil produced exceeds capacity to ship, the value of ND oil at the wellhead can drop as much as $12 per barrel from the benchmark price; with adequate capacity to transport oil, that figure may drop to as low as $3 - $4 per barrel.

In March, 2010, county commissioners approved a new railroad oil loading facility just outside of Dickinson, ND, which should be operational by October, 2010. The Dickinson terminal (98 miles southwest of Stanley) is also expected to ship 60,000 barrels of oil in one unit train on a daily basis.

7. How much oil can one reasonably expect that a Bakken well will produce over the lifetime of that well?

The oil industry refers to this figure as the estimate of ultimate recovery (EUR). Back in 2007, EOG opined that the EUR from each of its wells in the Parshall could be 750,000 barrels of oil equivalent. In January, 2010, CLR opined that dual laterals will add another 400,000 barrels to the EUR. By the way, this comes with a newly revised EUR of 280,000 boe in east Texas (Texas Barnett Combo). It should be noted that EOG sits in one of the "sweet spots" in the Williston Basin and their wells are probably going to return much, much more than the "average" well in the basin. But there are "crazy numbers" out there.

8. What is the record IP to date in the Williston Basin?

Again, the initial production of any well, self-reported by the producer, is becoming less meaningful over time. However, having said that,  the record IP in the Williston Basin is a Whiting well which had an IP of 4,761 boepd: file #17612, 4,761 boepd IP, Whiting, Maki 11-27H, Mountrail County, Sanish field.  This is still current as of February 20, 2010 -- sometimes I forget that I have this site, and I could forget to post a new record well.

9. What is "pooling" and the Pugh clause?

The Pugh clause is too complicated for me. See this site. If you know of a better site, let me know. Here's a bit more on the Pugh clause. Pooling is easier to describe: instead of finding every last mineral rights owner and contracting with each mineral rights owner on an individual basis (lots of time wasted), the producer/operator asks the state for permission to "pool" all mineral rights owners, thereby setting remuneration based on agreement reached with a majority of the mineral rights owners. It appears that the right to pool is the last step in the paperwork/bureaucratic process before preparation for drilling actually begins.

10.  How much can I expect to lease mineral acres for? What is the record oil lease?

This is impossible to answer; there are too many factors to consider. I will try to remember to watch lease rates and post them, but it seems for the acres with least likelihood to produce, the acres may go for as little as $100/acre. In 2009, it was common to see $2000/acre, but in some places they actually went as high as $8000/acre (very, very unusual). You may want to search this discussion group for a better answer: the Bakken Shale discussion group.

Here is one discussion on lease rates, back in April, 2008. Since then, rates have gone up considerably depending on location.

But record leases were those recorded in the late-2009 North Dakota land lease sale (somewhere I read that at least one lease sold for $8,000/acre: I will try to find that lease, but regardless, the numbers are spectacular). In February, 2010, it was reported that 120 acres in a relatively mediocre (but potentially exciting) field was leased for $7,300/acre, working out to $4.7 million/640 acres (one section). 

11. What is an Eco-Pad? What are "Dakota Candles" and "Orion Belts"?

Click here for information on Eco-Pads. "Dakota Candles" and "Orion Belts" are terms I use for multi-well sites. Dakota Candles are a series of wells on one site running north and south; Orion Belts are a series of wells on one running from east to west. The direction of the series of wells on one site makes no difference. It is just shorthand for me to help remember these sites.

12. What is the "IP"? And the 24-hour flowback?

"IP" stands for initial production. This is a self-determined and a self-reported number provided by the producer. Each producer can determine its own method for determining the initial production of a new well, but it must be based on 24 hours of production. Obviously, this means that the numbers can be easily manipulated and many seasoned oil analysts put no stock in these numbers. Unfortunately, these are often the only numbers one has to work with early on. Whether IPs are that reliable or that reproducible, I think one can get a general idea of the helpfulness of the IPs by following them over time. At the end of the day, the best data point may be the cumulative oil produced at the end of the first year, and at the end of the fifth year, but that's a long time to wait, and not always easily available unless one subscribes to the NDIC database. If interested, here is a discussion thread regarding IPs, as well as a link to decline rates in the Bakken. One more personal note: if a legitimate company was found to be inappropriately manipulating IPs, the state agency regulating the industry would probably step in; and, investors would probably lose faith in the company.  It's likely that comparing IPs within one company is internally consistent but it may not be accurate comparing IPs from producer to another producer.

Here's another great discussion on IPs: for the same well, NOG (a partner) reports an IP of 1,998, while Hess (the producer/operator) reports an IP of 570. That's a huge spread. Looking at the monthly production, it is obvious that Hess reported the initial 10-day average whereas NOG reported the first day's production, or even possibly the first hour and then multiplied by 24. Hess is an established company and one well has minimal impact on its overall operations; NOG is a small company (one could argue it's a penny stock out of Denver) and one big well can greatly influence investors.

In early 2010, more and more companies were switching to 24-hour flowback as their initial production number. This results in a) more confusion; and, b) significantly higher IPs (with subsequent more horrific decline rates. 

13.  What does it cost the operator/producer to extract a barrel of oil equivalent  (BOE extraction cost) from the Bakken?

I have refrained from talking about the BOE extraction cost because I think the numbers can be manipulated even more than the IPs. However, more and more folks are asking that question, and I will start posting some numbers as I see them. I doubt I will go looking for them. For me, it's not worth the effort. BEXP and WLL have been particularly forthcoming with their estimates of their BOE extracton cost in their corporate presentations which are easy to access at their home page. I was unable to find comparable reporting by EOG. In general, in 2009, the number I saw most frequently was $12 - $14 to extract a barrel of oil from the Bakken. In WLL's June, 2010, corporate presentation, WLL stated the cost was $10/bbl.

On page 5 of the 4Q, 2010, Hess earnings conference call, Hess said "the Bakken is robust at $40. It returns the cost of capital at $40. So that’s why we feel very confident kind of pulling the trigger on the Bakken now and aggressively going after a five year program."

14. What information is available for a well on the confidential list, what is the definition of a completed well, and how long can a well remain on the confidential list?

The following was taken from the Bakken Shale Discussion Group thread. When I locate NDIC information on this subject, I will post that. "All information furnished to the director on new permits, except the operator name, well name, location, spacing or drilling unit description, spud date, rig contractor, and any production runs, shall be kept confidential for not more than six months if requested by the operator in writing. The six-month period shall commence on the date the well is completed or the date the written request is received, whichever is earlier. If the written request accompanies the application for permit to drill or is filed after permitting but prior to spudding, the six-month period shall commence on the date the well is spudded."

The obvious question is "when is a well considered to be completed?" For wells that will be fracked, the well is considered "completed," when the well has been fracked. This has been the opined explanation for many EOG wells coming off the confidential list in January and February, 2010.

15. What is the average daily oil production coming out of North Dakota?

At the end of 2009, North Dakota was producing about 250,000 barrels of oil per day. With a new pipeline project completed and the introduction of EOG's railroad tanker project, oil capacity increased by about 110,000 barrels per day. It will be interesting to see if North Dakota reaches that capacity (360,000 barrels/day) by the end of 2010. Note: in March, 2010, it was announced that another railroad tanker project, this one at Dickinson, will be operational as early as October, 2010. If that comes online, then one can add another 60,000 barrels to current capacity estimated to be 360,000 barrels/day, reaching a new capacity record of 420,000 barrels per day.

16.  What cities and towns in North Dakota are most affected by the Bakken?

Williston (northwest) and Dickinson (southwest) are the two largest cities in "the Bakken." Next comes Watford City, Stanley, and Bowman. Smaller towns include Tioga (home of the first well in North Dakota, discovered by Hess in 1951), New Town, Alexander, and Ross. 

Sixteen Reasons, Connie Stevens

17. Can you discuss the thinking of infill wells?

Gladly, by directing you to a discussion group. It is my understanding that the issue of infill wells in the Bakken in North Dakota is still being explored. With a well in almost every section of the Parshall oil field, EOG is now ready to experiment with infill wells. But it is still very early in the game to be talking a whole lot about infill wells.

18. How long will "the Bakken" last? 

Obviously that question cannot be answered with any degree of certainty. But in January, 2010, analysts suggested North Dakota's oil output will increase to 400,000 bopd by mid-2011, and that level of production will be sustained for 10 - 15 years.

Industry experts suggest that the drilling program will not be completed until 2030, and that production will continue to at least 2100.

19. What oil fields in North Dakota are "in play"?

Various oil fields are looked at in more depth elsewhere on this blog. At the sidebar on the right, scroll down to find updates of various fields.  The Parshall oil field and the Sanish oil field have been the most prolific fields in the current boom. Other fields of interest: Big Bend and Van Hook; Clear Water; Little Knife, Jim Creek and Murphy Creek; Alger; Painted Woods, Squires, and Round Prairies.

20. How many active oil wells are there in North Dakota?

For me, this question is irrelevant, but I see it is often asked. According to the NDIC, there were 4,693 active wells in North Dakota in 2009. How many permits (wells drilled from these permits) are being granted on an annual basis in North Dakota? 2006: 422 (195); 2007: 497 (336); 2008: 953 (734); 2009 626 (208). Obviously the numbers inside the parentheses (wells drilled) will increase over time (as the wells are drilled). March 10, 2010.

21. How soon does a company stimulate a well after completion of drilling?

This varies. Buried deep in this site one learns that EOG spudded a well on January 19, 2009, but did not plan to fracture stimulate it until July, 2009. I assume that most wells are fractured within a month of when drilling is completed but I do not know. I will watch for more examples.

22. What is meant by a "top lease"?

I have no idea, but "Teegue's clarification" deep in that thread is enlightening.

23. Is there a "basic analysis of the current Bakken boom?

Yup: right here. I don't know if this document is dated. I downloaded it February 13, 2010, and the document itself suggests that it was published in 2010. The takeaway: 30 years of drilling in North Dakota [until 2030] and oil production in North Dakota until 2100 (the Bakken formation).

24. What is the difference between "boepd" and "bopd"?

Barrels of oil equivalent per day (boepd) includes natural gas.  "Bopd" is only the oil.  Generally speaking, one can divide the number of cubic feet of natural gas by 6,001 to get the equivalent of oil. The number can vary depending on quality of the natural gas but 6,001 seems to work well every time I've used it. Note that there are different grades of oil: sweet oil is most expensive. North Dakota oil is sweet oil. Likewise, natural gas has different amounts of energy and much more difficult for me to understand. Natural gas quality is defined in British thermal units (BTU).

25. Can you talk about the confusion between the Bakken formation and the Three Forks Sanish formation as it relates to the "Bakken pool"? See this posting. Related to this issue is whether the TFS and the Bakken communicate?

Continental Resources (CLR) recently completed a test to determine whether the Three Forks Sanish and the Bakken are separate formations. Interestingly enough, in that report, CLR projected that these wells, one of which was drilled in 2008, will see an increase of 400,000 additional barrels over the lifetime of those wells, out to 2029. Yes, out to 2029, twenty years from when these wells were drilled. And these wells were not all that outstanding to begin with. Note: EOG has estimated that their good wells in the Parshall have an estimated ultimate recovery of 700,000 barrels, so an estimate of another 400,000 barrels is almost incredible. Click here for the referenced report.

26. How much does it cost to drill a horizontal well in North Dakota?

"Currently cost estimates for a 22-stage frac job for completed Bakken Three Forks wells is $5.4 million, and we are keeping that relatively flat from last year."  March, 2010

27. How long does it take to drill a Bakken well?

Drilling a well and completing a well are two different things.

The drillers in North Dakota are setting new records in completing wells. There are two components for completing a "Bakken well." The first component is drilling the well; the second component is fracking the well. 

It used to take 30 - 45 days to drill a well; "they" are now drilling wells in about 25 days.
Once the well is drilled, the operator must then wait for the fracking crews to complete their job. For various reasons, fracking is not always done immediately after the well has reached total depth. 

Having said all that, this may be the record for completing a well in the Bakken. Before clicking on the link: who do you think has the record? a) BEXP  b) WLL  c) EOG  d) HES

28. What is meant by "Zone I, II, III, and IV" and spacing units? Click here. Also here for EOG spacing strategy first noted in 2010.

29. Regarding the GIS map at the NDIC website, why is there not an icon for a rig where there is "drilling" depicted (the open green circle)? The well has been drilled to depth but is waiting to be fracked, completed, and/or placed on the confidential list. Answer provided by "David" at Bakken Shale Discussion Group.


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Updated March 21, 2010.