Legacy -- Spearfish -- Producing -- Press Release -- North Dakota, USA

Link here.

Of a dozen accomplishments highlighted by Legacy in their 2Q11 operations and financial results, this was the first item mentioned:

At Bottineau County, North Dakota, three of the five wells drilled and completed in late 2010/early 2011 are on production, with an average 60 day initial production rate of 100 Boe per day, per well. These wells have confirmed the presence of an emerging light oil resource play in the Spearfish Formation and proven the productive potential of a large portion of Legacy’s Bottineau County acreage.

 A big thanks to another "Bruce" alerting me to this. I would not have found it on my own.

Abraxas Update -- Bakken, North Dakota, USA

Link here.

In McKenzie County, North Dakota, Abraxas drilled the Stenehjem 27-34 1H to a total measured depth of 16,504 feet, including a 5,965 foot lateral in the middle Bakken formation, and completed the well with a 17-stage fracture stimulation. The well was placed on production in late June and in 44 days the well has produced (on a restricted choke) 20,000 barrels of oil.

In various counties in North Dakota and Montana, fourteen non-operated horizontal wells, targeting the Bakken or Three Forks formation, in which Abraxas owns a working interest are currently in progress or recently placed on-line.

In early July, Abraxas announced the purchase of a drilling rig that is in the process of being refurbished. After completion, the rig will be mobilized to McKenzie County, North Dakota and it is anticipated that the rig will begin drilling on the first pad site in October.

Yup, another active rig coming to the basin.

Stop the Presses: President Obama Wants More Drilling In Alaska -- Interior Secretary Salazar

Link here.

Interior Secretary Ken Salazar came to Anchorage on Monday and said the Obama administration supports more oil drilling in Alaska, potentially including offshore Arctic development.

Salazar joined Alaska Sen. Mark Begich and Rhode Island Sen. Jack Reed, both Democrats, for a meeting with Alaska businesspeople and said the president's feeling toward Arctic offshore drilling is "Let's take a look at what's up there and see what it is we can develop."

Oh, I knew it was too good to be true. This is a summary of the rest of his remarks:

But any Arctic oil development must be done carefully, he said. Salazar said the Arctic lacks needed infrastructure for responding to potential offshore oil spills and cited painful lessons from the Deepwater Horizon spill in the Gulf of Mexico last year.  

That's the end of that discussion. The permitorium lives on. Let's see. The Gulf spill was more than a year ago and we all now how that worked out.

Bull Moose 1X-15: A Vertical Well Producing Since 1981 -- 556,000 Bbls of Oil and Still Counting -- Bull Moose 23-43X -- 1.3 Million Bbls -- North Dakota,USA

In yesterday's daily activity report, the following permit was noted:

• 21290, 1,068, BR, Red Wing 16-1H, Wildcat, t5/12; cum 12K 12/12;

It's unimportant why I was curious about this well, but something about it piqued my interest. I found the location on the NDIC GIS map server, though it has not yet been placed there on the map.

This Burlington Resources permit is out in the middle of nowhere. When I see that, it's always interesting to find the nearest well and see if there is any information that might be interesting to others.

In this case, Bull Moose 1X-15 (#7944), a conventional, vertical well, spud in 1981, is located one mile to the east from that new BR permitted location.

Bull Moose was spudded in 1980, and the Red River formation was targeted and tested. The IP was 437 and it turned out to be a good well, but finally petered out in 1999. The well was shut in from 1999 to 2002 when it was re-entered/re-spud. This time the target was the Madison, with an IP of 32.

How has the well done?

• From the Red River, that well produced 501,902 bbls of oil (now PNA).
• From the Madison, the well has produced 68,406 bbls (through December, 2012) and is still pumping about 300 bbls/month. 
• Note: when they re-entered the Madison in 2002, they also tested the Birdbear, but that was DRY.

Again, just an exciting story in the North Dakota oil patch. This well has been producing since 1981 -- 30 years and is still pumping. Of course, the original formation was shut in back in 1999. It should be noted that the well was still pumping around 1,500 bbls/month from the Red River when it was shut in.

One understands why folks are talking about Red River and Madison EOR.

*********BREAK******BREAK***********BREAK**********BREAK***********

I swear on a stack of Bibles that I did not check this out ahead of time. I was truly curious about the wells noted above, and then just for the fun of it, thought I would look at one more well (and I might look at a couple more) in the same little field, the Bull Moose field.

One-half mile south of #7944, Bull Moose 1X-15 is:

• 6718, Bull Moose 22-32F

This well has the following history:

• Madison, spud/tested 3/30/1979 with an IP of 123
• Red River, spud/tested 3/10/1981 with an IP of 486
• Birdbear, spud/tested 4/25/2000 with an IP of 200

So, how has this well done?

• From the Madison: 43,000 bbls
• From the Red River: 1.3 million bbls (yup, million)
• From the Birdbear: 136,000 bbls

It is now producing from the Birdbear, but it was still producing 1,200 bbls from the Madison, when they switched to the Red River. The Red River was still producing about 400 bbls when they switched to the Birdbear.

From the Birdbear, on a pump, starting in the year, 2000, it pumped 136,000 bbls of oil until 2008. The well has not been abandoned.

***********************

It looks like Sequel Energy, LLC, is going to see if there is some life still left in this old little field.

• 19765, 55/19, Sequel, Bull Moose 22Y-32, Bull Moose field, Duperow/Red River; t9/11 and t10/11; cum 5K 12/12; and 290 bbls 12/12; (no typo)

The Winnepeg pool is as deep as you go in the Williston Basin. The Winnipeg formation is below the Red River formation, the deepest formation, as far as I know.

Oasis: Forms A New Company -- Oasis Wells Services -- Bakken, North Dakota, USA

One of the joys of hosting a blog on the oil patch is the education one receives in the process. [See also: manufacturing vs drilling.]

Earlier today I learned about "zipper fracks" for the first time and perhaps helps explain why BEXP has had the success it has been having in the Bakken.

Now we may be seeing something new in the oil patch. Chesapeake mentioned it earlier: setting up their own in-house oil services support. This time it has to do with Oasis. From  the Seeking Alpha.com transcript:

In June we formed a new company underneath Oasis Petroleum Inc., called Oasis Wells Services or OWS to provide pumping services to our operator wells. The crew is expected to begin operations in early 2012. The current operations team in our Williston office alone has over 100 combined years of experience in the frac business including experience with some of the larger providers as well as in pure start-up operations, most of that specifically in the Williston Basin.

So managing the hiring operations, consumables and logistics is nothing new to our team. The broader overall economics of this decision are quite compelling to us. In total completions make up anywhere from 45% to 60% of our well cost. Pressure pumping services alone comprise about 30% to 40% of our well cost. And there’s a relatively higher margin embedded in each job.

We’ll be able to capture that margin in the form of CapEx savings. So when we frac our own well, Oasis can save approximately $800,000 to $1 million per well gross, and that’s the way that you should think about modeling it. Additionally, we’ll earn a small profit margin on the services we provide to non-op partners, which would show up on our income statement and EBITDA in the neighborhood of about 300,000 per gross well-completed.

So, if I have that correctly, here are the data points:

• Well completions account for half of the total cost of a Bakken horizontal well. Wow.
• Pressure pumping services alone account for a third of the cost of the well. Wow.
• So, Oasis says, why aren't we doing that ourselves? 
• They did: they set up Oasis Wells Services?
• Why a separate company? Why not just part of "OAS"?
• Because other operators can contract with OWS; voila: another income stream.
• Clever.

And that's why I love following the Bakken. It's about a lot more than just oil.

Six (6) New Permits -- Bakken, North Dakota, USA

Daily activity report, August 9, 2011 --

Operators: Hess (3), Newfield (2), OXY USA

Fields: Wheelock, Willmen, Avoca, East Fork, Cherry Creek

The report was otherwise unremarkable.

Hess has another 2-well pad.

1,000,000 Page Views For The MillionDollarWay -- The Millionth Visitor From Wayzata, Minnesota -- Thank You For All Your Support

The purpose of this site started out as being educational. Over time it has added a fair amount of information about investing in the Bakken. It is almost impossible to discuss the Bakken without acknowledging the role that capitalism plays. Having said that, the site 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 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.

A few months ago I began subscribing to an "energy newsletter" for the first time, if you can call it that: the NDIC's basic services which provides more specific information regarding oil and gas wells in North Dakota.

About the Name of the Blog

For newbies, "MillionDollarWay" has nothing to do with money per se, at least not in the way most folks might think.

"Highway 2 & 85" heading out of Williston was known as "Million Dollar Way" to all of those watching late night television on Friday and Saturday nights in Williston in the 1960's -- due to the car dealerships (one?), the bowling alley (1), and the A&W Root Beer stand on that highway.

I saw the "Million Dollar Way" as my way out of Williston to see the rest of the world. In fact, in 1973, I hitchhiked from Williston to New York City where I caught Air Luxembourg and then hitchhiked through western Europe for one summer. My mother offered to drive me out to the highway, but I was too proud, and walked. To say the least, I have never been so embarrassed as I was that day when the first car that stopped while I was holding out my thumb was my mom, who drove out to get a photograph of me. (I've never seen that photograph.)

So, "MillionDollarWay" has a significant emotional meaning for me -- it has nothing to do with investing (unless, of course, if you consider opportunities in that one car dealership, the bowling alley, and the A&W Root Beer stand as investment opportunities).

And, coincidentally, I might add that the road that was my way out of Williston has turned out to be my road back into Williston.

So, that's it.

For newbies, or for those who have never read it, you might enjoy the "welcome" page.

[Over the past year, some internal links have been broken because I have moved some of the posts around to make the site easier to navigate. The search engines and search applications at the site are the best way to find information. And, of course, the sidebar on the right is chock full of data. If you don't find something you would like to know about, send me a note.]

The Millionth Visitor (and a few before and a few after)

The 1,000,000th viewer was from Wayzata, Minnesota,
Then, following after that:

• Cottonwood, California
• Minot, North Dakota
• Becker, Minnesota
• Casper, Wyoming
• Puchong Selangor (Malasia) -- Hess natural gas expansion
• Dickinson, North Dakota,
• Garland, Texas
• Parker, Colorado
• Council Bluffs

Just before Wayzata, Minnesota's visit:

• Calgary, Alberta (999,999)
• Gig Harbor, Washington (999,998)
• Wichita, Kansas (999,997)
• Seoul, South Korea (999,996)
• Belgrade, Maine (999,995)
• Boulder, Colorado (999,994)
• Scarborough, Ontario (999,993)
• Pasadena, Maryland (999,992)

Crude-By-Rail: Re-Posted for Newbies -- Bakken, North Dakota, USA

Because of so much posting today, so many stand-alone posts, a very important story might have been buried.

Because of that, I am reposting the link and suggesting that folks new to the Bakken take a look at the crude-by-raid phenomenon.  Here's the link on a paradigm shift in shipping oil.

This is even more important now that the US Army Corps of Engineers has instituted a permitorium on new pipelines.

Chesapeake - Clean Energy Fuels Partnership: America's Natural Gas Highway

Link here.

From SeekingAlpha.com's transcript of Clean Energy Fuels' conference call on 2Q11 earnings:

One of our biggest accomplishments so far this year, is obtaining Chesapeake Energy’s $150 million investment in Clean Energy that will allow us to accelerate the formation of America’s Natural Gas Highway. 

Some data points:

• Backbone of the corridor: 150 natural gas stations
• Major corridors involved: I-10, I-5, I-40 and I-95 (not said on conference call, but I assume in California, Nevada)
• 250-mile separation
• Utilize many Flying J locations
• Clean Energy's Northstar subsidiary will play a major role in constructing the stations

National Fleet Program:

• Completing permitting on LNG station in Las Vegas; anchored by 48 UPS trucks
• Beginning to fuel the Dillon transport fleet in Dallas
• Also, Owens Corning in Chicago
• Expect to expand in Ohio 
• Coca-Cola and Pepsi: adding 50 vehicles for operations in Texas and California

190: New Record, New Milestone -- 190 Active Drilling Rigs -- North Dakota, USA

Dynamic link.

In less than a month, 10 additional active drilling rigs:

• 190 rigs -- August 9,2011
  
• 185 rigs -- August 8, 2011
• 180 rigs -- July 18, 2011

The Permitorium Lives -- Worse Than Ever -- So Much For Shovel-Ready Jobs -- And Folks Wonder Why The Economy Falters

US Army Corps of Engineers shuts down new pipelines in the Marcellus, Pennsylvania. New rules might as well simply say: no more pipelines.

The new U.S. Army Corps of Engineers rules, effective July 1, 2011, replaced federal regulations that expired in June controlling pipeline construction and other surface-water impacts in Pennsylvania. A change in the regulations requires companies to detail all of the streams and wetlands to be crossed by a pipeline project - some of which stretch for hundreds of miles - rather than outlining only the impacts of each stream crossing individually.

Delays caused by the new permit reviews have stranded 128 of the company's drilled and completed Marcellus Shale wells without pipelines and are "costing Pennsylvanians royalty income," [Chesapeake says].

So much for "more jobs" except, I guess, job security for bureaucrats. Although these reports could be written up be college biology students, I suppose.

Oasis Conference Call -- 2Q11 -- Bakken, North Dakota, USA

Transcript has been posted.

Some of what we have learned:

Like all players in the Bakken, Oasis production was up 77% over 2Q10, but was flat following 1Q11. But the flooding in 2Q11 was awful and impacted production significantly.

Oasis has a third frack crew now; each team can frack three wells/month, and should get Oasis backlog down over the next three months (others have said the same thing; backlog should be less of a problem by November, 2011).

Time from spud to TD: 21 days
Time from spud to release rig: 25 days
In 2010: the time from spud to release rigs was 31 days; more efficient. If I understood the transcript correctly, Oasis has about 18 wells waiting completion; with increased efficiency, Oasis should normalize back to 10 to 14 wells.

Oasis will increase number of frac stages from 28 to 36.

Oasis will add two more rigs (a total of 9) in 4Q12.

Recognizes: well cost escalation.

Accelerating salt water disposal infrastructure.

Increase CAPEX for field operations in Williston, North Dakota.

But this may have been the high point of the conference call: Oasis plans to manage its own fracking in-house:

In June we formed a new company underneath Oasis Petroleum Inc., called Oasis Wells Services or OWS to provide pumping services to our operator wells. The crew is expected to begin operations in early 2012. The current operations team in our Williston office alone has over 100 combined years of experience in the frac business including experience with some of the larger providers as well as in pure start-up operations, most of that specifically in the Williston Basin.

So managing the hiring operations, consumables and logistics is nothing new to our team. The broader overall economics of this decision are quite compelling to us. In total completions make up anywhere from 45% to 60% of our well cost. Pressure pumping services alone comprise about 30% to 40% of our well cost. And there’s a relatively higher margin embedded in each job.

We’ll be able to capture that margin in the form of CapEx savings. So when we frac our own well, Oasis can save approximately $800,000 to $1 million per well gross, and that’s the way that you should think about modeling it. Additionally, we’ll earn a small profit margin on the services we provide to non-op partners, which would show up on our income statement and EBITDA in the neighborhood of about 300,000 per gross well-completed.

Bakken Companies Reporting Today -- Production Records Being Set -- Bakken, North Dakota, USA

USEG reports, 2Q11.

GEOI reports, 2Q11.

NOG reports, 2Q11: sales up 200% year-over-year; production volumes rose 130% year-over-year, and 12% over previous quarter (1Q11). These are incredible results considering the flooding in North Dakota this quarter. Remember how we all thought production was going to be severely impacted this quarter?

VOG reports, 2Q11: production doubled, year-over-year.

Remember: earnings for all Bakken companies at "Earnings Central" linked at the sidebar on the right.

Michael Filloon weighs in on many of the Bakken stocks. 

In addition to whatever Michael Filloon writes, some random observations:

1. NOG partnered with one of the premier operators in the Bakken: Slawson.

• Mustang 1-22H, 1,829
• Alamo 2-19-18H, 1,287
• Diamondback 2-21H, 1,909
• Cruiser 2-16-9H, 1,115
• Hunter 1-8-17H, 1,668

2.  How much are the accrued costs for a boe for NOG? $5.94/boe in 2Q11; it was $5.24/boe in 1Q11; and $3.30/boe in 2Q10. NOG says "the increase in production expense is primarily due to lower production volumes due to heavy rain, flooding and road restrictions, the continued addition of producing oil and gas properties, exposure to new operators and new development areas, an increase in working interests, mature wells utilizing artificial lift and the general aging of production." Not necessarily in that order, I assume.

3.

189: Number of Active Rigs Drilling In North Dakota

Dynamic link, but at 11:25 a.m., August 9, 2011, the number of active rigs drilling in North Dakota is reported to be one shy of 190.

BEXP: Montana Looking As Good As North Dakota -- Increased De-Risked Acreage in Montana -- Focus on Smart Pads -- Cutting Frack Time In Half -- Some Very Nice Wells -- Bakken, North Dakota, USA

Link here.

The press release calls this the "Montana Bakken" which can be confusing for newbies. There are two plays going on in Montana right now: the Williston Basin Bakken, and the (Southern) Alberta Basin Bakken (I hope I have that right). 

The "Montana Bakken" referred to here by BEXP is their prospect of the Williston Basin just across the state line. This is the eastern counties, and maybe even more specifically, the northeastern counties of Montana abutting against the western counties of North Dakota.

The Alberta Basin in Montana is much farther west -- in central Montana south of the Canadian border.

Data points:

• Two new Montana wells have de-risked BEXP's 33,500 acres in eastern Montana; increase from previously announced 24,400 net acres
• Total de-risked Williston Basin acreage: 235,200 net acres (note: BEXP total acreage about 380,000 net acres)
• At least 794 net drilling locations remain
• Storvik 7-6 1H: 2,066 (boe; early 24-hour peak rates; IPs will come in less); 34 frac stages
• Charley 10-15 1H: 1,069 (boe; early 24-hour peak rates; IPs will come in less); 30 frac stages
• To date: BEXP -- 79 consecutive long lateral high frac stage wells; average: 2,803 boe

Smart Pad Update

• Efficiency gained: 20%
• Seven rigs drilling Smart Pads
• To date, BEXP has completed 8 Smart Pads
• BEXP: 70% of rest of 2011 drilling will be Smart Pads
• Will acquire 2 additional specially built walking rigs in 1Q12; two more by July, 2012
• Option to add 4 more less efficient conventional rigs upon receipt of the walking rigs

Zipper fracks

• A new term for me; see comment below. Apparently it's plug and perf technique used on multiple wells on same pad, moving things along more quickly
• To date, BEXP has completed 6 zipper fracks
• 6 stages per day; 5 days per well in one case; another case, 8 stages/day --> 4 days/well; in comparison, conventional fracking has taken BEXP 9 days

Working with BHI and Halliburton to compare methods

Brigham is currently completing wells that have approximately 15 stages, or half of the well, with new frac sleeves installed. The remaining half of the wellbores will be completed with perf and plug and production from these wells will be compared to direct offset wells that were completed entirely with perf and plug. 

BEXP working to reduce infrastructure problems related to bad weather: increasing water gathering lines, to include disposal

BEXP Beats Expectations -- Despite Horrendous Weather -- News Will Be Lost Due to Market Plunge -- Bakken, North Dakota, USA

BEXP beats by two cents.

Data points (some numbers rounded):

• Production overall increased by 80% year-over-year; 10% better than previous quarter
• Production in Williston Basin increased by 90% y-o-y; 10% better than previous quarter
• Average realized price for crude oil was $93.86 per barrel, which included a $3.15 per barrel cash loss due to crude oil derivative contracts
• Net income: 60 cents vs 16 cents

Remember: this was the quarter in which flooding, muddy roads, and shut-in wells had folks on the street (including me) opining that production would be down from the first quarter. Wow, was I wrong. This was true for most (all?) Bakken producers.

I think folks would find it hard to believe is BEXP and others could maintain this level of activity, increasing production 80% year-over-year for another year, but ...

A separate stand-alone post for update on BEXP operations follows. Why put all the good stuff in one post?

Another Huge Investment in the Bakken: Titan Machinery Sets Up Operations in Dickinson -- Bakken, North Dakota, USA

Legend here.

Those looking to purchase or rent large equipment need to look no further — Titan Machinery is open in Dickinson.

“Titan Machinery as a whole, we are the closest thing that a customer can get to a one-stop-shop,” said Luke Norton, business manager of the Dickinson location. “We have the parts, we have sales, we have service and we also do rentals. We have the ability to provide the customers with best in class service with some of the best equipment on the market, in my opinion.”

Customers for Titan include contractors, oilfield-related companies, earthmovers, excavators and landscapers, said Greg Burgman, Titan general manager.

“We have 87 stores over a seven-state footprint,” Burgman said.

 According to Titan Machinery, their operations in Bismarck were just not close enough to meet the needs of their customers in the oil patch, and thus the reason for opening another operation in Dickinson.

Hess Has a Great Well in Big Butte -- 31,000 Bbls The First Month -- IP Yet To Be Reported -- Bakken, North Dakota, USA

This well is still on DRL status, but production data is available. This well is one of three on a 3-well pad in Big Butte oil field.  It was spud 8/27/10.

• 19227, 793, Hess, EN-Wefald-156-94-1324H-3, 31K the first month! t6/11; cum 124K 3/12;

This is why I'm following this well. 

Update on the Nine (9) Wells Along Hess Long Lateral 17117 -- Bakken, North Dakota, USA

Updates

June 10, 2012: since the original post about permit/well file #17117, two more wells have been completed and are parallel to this well:

• 20669, 601, Hess, EN-Person-156-94-1102H-2, Big Butte, middle Bakken; t1/12; cum 169K 4/17; 38 stages; 4 million lbs sand, ceramics; up to 3,000 units gas; 5 - 10' flare;
• 20670, 635, Hess, EN-Person-156-94-1102H-2, Big Butte, t1/12; cum 159K 4/17; frac info not yet provided; 18 days to reach total depth; up to 1,500 units gas (average 1,000) and a continuous 1 - 2' flare; in hindsight may not have been in "exact" target; the file report alludes to the numerous vertical holes being used to monitor these laterals

Original Post

Do you remember this story?

That post started out with:

There are nine (9) wells alongside the Hess long lateral #17117. I first talked about six monitoring wells along this long lateral back on March 18, 2011.

The original six wells all had "observation" in their names. The newest three wells no longer have "observation" in their names and are located immediately around the original well site of Hess #17117: EN-Person-156-94-1102H-1.  Based on their names, these three new wells will not be monitoring #17117 but will be production wells. Note that the most recent permit (#20772) is the odd-man out of these four wells. #20772 is not a "Person" well but an "Enger" well and it will be going south, where the other three are going north.

• 17117, 345, Hess, EN-Person-156-94-1102H-1, Big Butte, Bakken, 80K as of June, 2011; no production since April, 2011; back on-line 2/13; cum 119K 4/17;

Here are the nine (9) wells, as of March, 2012:

• 20500, A/SI, EN-Person Observation 11-33, east side of the lateral, Three Forks; no production data 12/12;
• 20315, A/SI, EN-Person Observation 11-22, west side of the lateral (rig on site), Duperow; no production data 11/12;
• 20442, A/SI, EN-Person Observation 2-24, west side of the lateral, Three Forks; no production data 11/12;
• 20361, A/SI, EN-Person Observation 11-31, west side of the lateral, Three Forks; no production data;
• 20539, A/SI, EN-Person Observation 2-32, east side of the lateral, Three Forks; no production data;
• 20599, A/SI, EN-Person Observation 2-43, east side of the lateral, Three Forks; no production data;
• 20669, 601, EN-Person-156-94-1102H-2, at the wellhead, east side; t1/12; cum 170K 4/17;
• 20670, 635, EN-Person-156-94-11-2H-3, at the wellhead, west side; t1/12; cum 159K 4/17;
• 20772, 1,181, EN-Enger-156-94-1423H-1at the wellhead, south side; t12/11; cum 241K 4/17;

Go to the link above for more about these wells.

According to well file reports:

• The EN-Person Observation 11-33 is straight hole meant to serve as a vertical monitor well in the East Nesson field.
• The EN-Person Observation 11-22 is straight hole meant to serve as a vertical monitor well and coring location in the East Nesson field.

There is one long lateral, producing, well one mile to the east (one section over) to the 17117:

• 17852, PA/374, Hess, EN-Hein-156-94-0112H-1, t5/13; cum 147K 8/14;  producing about 2,000 bbls/month.

Other Bakken wells in the immediate area:

• 17835, 366, Hess, EN-Person A-156-94-1522H-1, Big Butte, cum 141K 4/17; spud 2/09; tested 5/09
• 16928, 82, Hess, EN-Davenport-156-94-1003H-1, Big Butte, cum 71K 4/17; spud 12/07; tested 11/08
• 17956, 511, Hess, EN-Belik-156-93-0607H, Big Butte, cum 213K 4/17;  spud 6/09; tested 8/09

Just to the southeast of 17117, Hess has a three-well pad:

• 19225, 667, Hess, EN-Wefald-156-94-1324H-1, Big Butte, cum 203K 4/17; spud 8/10; no pump; still no pump 7/16;
• 19226, 275, Hess, EN-Wefald-156-94-1324H-2; t9/11; cum 138K 4/17;
• 19227, 723, Hess, EN-Wefald-156-94-1324H-3, 31K the first month! t6/11; cum 138K4/17;