Another Trivial Note on the Silurian Formation -- North Dakota, USA

Another interesting well:

• 7566, IA/682, Hess, T.P. Riggs 15-31, spud in 1980; test date 2/4/1981; cum 858,98 bbls 7/11;

This well continues to produce (on a pump) although since December, 2010, it looks like it might have been shut in.

This was another Silurian formation well. I talked about Silurian wells back on July 17, 2011.

This Silurian well was spud back in 1980 and has been active for 30 years.

I find it amazing how these companies can tease the oil out of the formation when it looks like production is dropping:

1. 1981 time period -- note the horrendous decline rate, which is also seen in the Bakken:

SILURIAN	4-1981	30	9967	9883	800	18667	18667	0
SILURIAN	3-1981	31	14030	14094	769	26149	26149	0
SILURIAN	2-1981	28	16510	15725	840	25958	25958	0

2. 1983 time period -- for some reason, production was shut down for part of a couple months, and then brought back up, producing at similar levels when first spud:

SILURIAN	1-1984	30	14415	13895	1630	22221	22221	0
SILURIAN	12-1983	31	16016	15963	2216	26659	26659	0
SILURIAN	11-1983	17	7155	7118	1700	12405	12405	0
SILURIAN	10-1983	11	935	1081	397	2328	2328	0

3. 1991 time period -- now it's getting serious. But then they go back in and manage to get production back to very good levels; this well was now 10 years old:

SILURIAN	8-1991	29	5347	5574	1762	8960	8960	0
SILURIAN	7-1991	14	4811	4601	2031	7455	7455	0
SILURIAN	6-1991	0	0	0	0	35	35	0
SILURIAN	5-1991	0	0	0	0	44	44	0
SILURIAN	4-1991	0	0	0	0	13	13	0
SILURIAN	3-1991	0	0	0	0	10	10	0
SILURIAN	2-1991	2	56	217	0	32	32	0
SILURIAN	1-1991	10	106	0	0	54	54

4. This year -- are we finally going to see the well abandoned? Or will see yet another comeback?

SILURIAN	2-2011	0	0	0	0	275	275	0
SILURIAN	1-2011	1	62	62	1	58	58	0
SILURIAN	12-2010	28	273	265	785	608	608	0
SILURIAN	11-2010	30	391	370	922	757	757	0

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

Another Silurian well in the neighborhood as the one above:

• 7571, 482, Hess, Reitsch NCT-2 4, Blue Buttes, t4/81; cum 997,798 bbls 8/14;

This well was spud in 1980; test date 4/3/81. and continues to produce, on a pump. This well has also celebrated its 30th birthday. Incredible.

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

By the way, another spectacular well in the same neighborhood:

• 9057, 731, Hess, Riggs 10-31, Blue Buttes, Stonewall formation, t5/85; cum 808K 8/14;

This well was spud in 1981; test date 5/5/85. and continues to produce, on a pump. It targeted the Red River formation, which was DRY, and then targeted the Stonewall formation, which is still producing, on a pump. Again, incredible.

On Track for 1,753 Permits in North Dakota for 2011 -- Bakken, North Dakota, USA

With the recent flurry of new permits these past few days, North Dakota is on track to issue 1,753 new oil and gas permits for calendar year 2011 (a very small number will be salt water disposal wells).

When this was last reported on July 25, 2011, the number was 1,712 new permits.

• 2006: 422
• 2007: 497
• 2008: 953
• 2009: 628
• 2010: 1,682
• 2011: 1,753 (estimate based on July 25, 2011, data). 

My numbers will be slightly different from the official NDIC numbers, but not by much (+/- 5 each year) because I missed a few taking them from the daily activity reports.

So far, 1,042 new permits have been issued in calendar year 2011.

Update On Highway 22 Near Killdeer -- Still a Mess -- Moving The Road West -- $10 Million -- Bakken, North Dakota, USA

Updates

August 8, 2011: Work begins, but they will only get to gravel road before winter sets in; will have to wait until next year to complete.

Data points:

• 18 miles north of Killdeer, ND.
• Martin Construction, Gladstone, will relocate a half-mile section, $2 million.
• The new stretch will be gravel due to winter setting in.
• The permanent road will be completed in the spring; separately-bid project.

Original Post

Link here.

The even worse news is that it will be closed until at least the end of the year (2011), and that's if all goes well in a huge project that will involve relocating a half-mile stretch of the highway about 500 feet west and moving some 500,000 cubic yards of earth to cut down a substantial hill to do it.

"This is a very big project," said Larry Gangl, engineer for the Department of Transportation Dickinson District.

The department has already spent $700,000 to construct a temporary bypass around the slide and was just ready to open the bypass last week when the road slid a second time.

Now, the department will spend an estimated $10 million more for what it hopes is a permanent fix.

Week 31: July 30 -- August 5, 2011

Bakken Pipeline Project Scaled Back Due to Uncertainty of Keystone XL

The Bakken: Possibly The Largest Construction Project in the United States

Results of the August, 2011, North Dakota State Land Lease Auction

Slawson To Put Six (6) Wells on 640-Acre Spacing Unit

Surge Energy to Increase Significantly Number of Wells in Bottineau County, Spearfish Formation

BR, QEP Look to Drill Fourteen (14) Wells on One 2560-Acre Spacing Unit

August, 2011, NDIC Hearing Dockets Posted

Unitization in the Bakken

MRO To Re-Frack 18 Wells in the Bakken

Personal Thoughts On the Effects of That 2,500-Bed Man Camp in Tioga on Williston

2,500-Bed Man Camp Breaks Ground in Tioga, North Dakota

Fracking Sand Operations in Wisconsin

WLL and CLR Both Have Interests in the Scallion Formation

CHK Conference Call: Utica is a Game-Changer; Missed the North Dakota Bakken, but Back

Patent Gate Oil Field Update -- Bakken, North Dakota, USA

The Williston Basin really has a great history; many, many stories could probably be told.

The other day I saw a permit in Patent Gate oil field. That was the first time I had heard of the oil field, didn't pay any attention to it at the time, but somehow I thought of it again.

Six miles east and one mile north of Alexander is a 4-section oil field, the Patent Gate oil field. Driving into and out of Alexander on the north side on US-2, one cannot see that far to the east due to the rolling hills, but it's probably just beautiful farmland in the summer; snowy desert in the winter.

Right now (August 6, 2011) there is one new permit, confidential:

• 21191, 1,094, CLR, Berlain 1-30H/Leahy1-30H, Patent Gate, Bakken; t12/11; cum 73K 8/12;

There are two other producing wells in the field, one horizontal, and on vertical:

• 8439, Zavanna, Nygaard 1-19, first spudded in 1981; Red River and Madison formations; cumulative oil: 180,000 bbls; Madison is still producing a little; on a pump
• 9300, G3 Operating, Bertinuson 1-30, first spudded 1982; Red River and Madison formations; cumulative oil: 250,000 bbls; Madison still producing

There are three plugged and abandoned wells:

• 13407, Slawson, Bertinuson 11-30X, first spudded in 1992; Madison, Duperow formations; cumulative oil: 90,000 bbls
• 9689, XTO, Bertinuson 11-30, spudded in 1982; Duperow, Red River formations; cumulative oil: 303,726 bbls
• 13416, Columbus Energy, Bertinuson 1-31, Madison, Tyler formations; cumulative oil: 25,000 bbls; the Tyler was dry

You just get the feeling that with new technology and the right price for oil, some of those legacy formations have a lot more to give up.

Potash in North Dakota Could Be Worth $2.7 Trillion

Link here, from the Williston Herald.

The total amount of potash in northwest North Dakota is currently unknown.

Nick Horob, who described himself as a concerned private mineral holder, used a study done by the Solution Mining Research Institute for southern Saskatchewan as a basis.

Southern Saskatchewan is major producer of potash and it is believed by some that northwest North Dakota has relatively the same amount per acre as that of southern Saskatchewan. Horob took that believe and the amount of potash being produced per 640 acres in southern Saskatchewan according to the study to come up with his estimate of the value of potash.

"I took all of Burke county and Divide county size times the potash rate in southern Saskatchewan," Horob said. "I then took half of that just to be conservative."

The number he came up with is $2.7 trillion, although he stresses that it is a very rough estimate.

Someone should probably check the placement of that decimal point. I think this is the first time I have used the word "trillion" in any posting.

Large Expansion of Crude-By-Rail Facility Planned for Dore, North Dakota -- Expansion To Increase Capacity 7X -- Bakken, North Dakota, USA

According to the on-line edition of the Williston Herald, Musket Corporation, Oklahoma City, has announced a large expansion of its crude-by-rail (CBR) facility at Dore, McKenzie County, North Dakota.

I think I first blogged about this facility at Dore, back in May, 2010. It seems like a very, very long time ago. A lot has happened in one year.  Search "Dore" at this website to read more about the facility.

The expansion will increase its outbound capacity from 10,000 bbls of oil per day to 70,000 bbls per day.  It is expected that the facility will be fully operational by 1Q12.

Musket signed a long-term agreement with Banner Pipeline Company to deliver oil to the facility.

In light of the Bakken Pipeline project scaling back, this is a significant development.

Comments From the Trenches: Mud and Fracking -- Bakken, North Dakota, USA

I was sent the following information from someone visiting the North Dakota oil patch recently. He is in Stanley for a few days.

He says that last year in the Stanley area, drilling rigs were everywhere but this year, it appears there are fewer in that immediate area.

He also noticed that an "inventory" of fracking equipment was sitting right off the side of the highway around Ray, North Dakota (this would be the Hess, Tracker, American Oil area, I suppose), waiting to be moved.

Apparently some fracking trailers and "older" oil equipment was still on some pads, unable to be moved, because of muddy conditions that still existed despite less rain the past few weeks.

His hunch is that the "fracking backlog" is aggravated by mud still remaining in so many areas, in addition to so many wells that need to be fracked. He saw the same thing I did when I was in North Dakota a few weeks ago: North Dakota now has many, many more ponds than we were both used to seeing. If Minnesota is the land of 10,000 lakes, North Dakota is the land of 10,000 ponds.

By the way, adding to the problem is that the fracking teams do have a schedule, and when the schedule is disrupted, it no doubt adds to the delay downstream.

Idle chatter, but I thought some folks might enjoy hearing something from the trenches.

A Piece of Trivia That Adds to My Understanding of the Oil Patch -- Bakken, North Dakota, USA

Updates

April 2, 2012: The Anschutz (now OXY USA):

• 18644, 1,148, Lime Rock Resources/OXY USA/Anschutz, State 1-25-36H-144-97X; Bakken, Cabernet, s1/10; t4/10; cum 370K 5/17;

... was an outstanding well. It was not on a pump and had not been stimulated and had produced 254,000 bbls in less than a couple of years. Then in January, it was taken off-line by OXY USA, and has not come back on-line as of latest reporting date, the end of February. "Anonymous" suggested that problems occurred while putting on a pump. Elsewhere they are asking questions. Also, see comments below.

Original Post

I really appreciate folks taking time to point out things I've missed or don't understand.

In this case, in the process of updating the Cabernet oil field, "anonymous" pointed out something about the Matthew Schmidt well (originally Anschutz, but now an OXY USA well).

Take a look at the posting and the comments.

I do know that not all horizontal Bakken wells need to be fracked, but I assume it is a small minority of Bakken wells that are not fracked within the first year, but I really don't know.

I have assumed (wrongly, it appears) that by the time the NDIC posts the IPs for Bakken wells, the wells had been fracked, completed, and, generally, in full production (within regulatory restraints, of course).

In that post linked above, I omitted the Matthew Schmidt well based on its IP until it was pointed out to me that it should be on the list of "good" wells in the Cabernet. So I added it, but still looked askance.

• 18427, 876, Lime Rock Resources/OXY USA/Anschutz, Matthew Schmidt 1-35-2H-143-97; s2/10; t5/10; cum 190K 5/17; almost no production since 11/11; problems with the well; I looked at the well file very, very quickly; it appears a pump was put on the well in May, 2011; and the well was fracked in November/December, 2011; ever since the pump/fracking, the well has not been good -- original post. Update, October 12, 2013 -- well back on line and producing nicely;

Then this zinger, at least for me: that well has produced 91,000 bbls of oil to date (it was tested May, 2010, so we are barely into a full year of production) and it's almost at 100,000 bbls, a critical milestone for me.  But here's the zinger: this well has not been fractured. Nor is it on a pump.

Not been fractured, and it's almost at 100,000 bbls in about a year. Yeah, that's pretty impressive.

But there is more. There is another well that has produced 200,000 bbls in the first year, and, it, too, has not been fracked is not yet on a pump (original post; now it is on a pump):

• 18644, 1,148, Lime Rock Resources/OXY USA/Anschutz, State 1-25-36H-144-97X; Bakken, Cabernet, s1/10; t4/10;  cum 370K 5/17;  I read the well file; it appears there have been two pumps put on this well; now the status of the well is reported as IA, although there was production and runs in August 2012; it almost looks like OXY worked on these two wells about the same time; not good results? - original post; update - it is now back on-line and producing, October 2013; 

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

When I look at the Cabernet oil field on NDIC's GIS map server, it certainly appears there has not been much activity considering how "rich" it must be (based on the few wells there). My hunch is that limited Anschutz resources hindered a faster development program in the Cabernet which OXY USA will now rectify, and in addition, because it's a relatively small field, it probably doesn't take many wells to hold leases by production. Of the 21 sections that make up the Cabernet oil field, only four sections do not have wells on them yet: sections 14, 23 (T144N-R97W) and sections 6 and 7 (T143N-R96W).  But depending which direction well #20797 goes and which direction wells 18503, and 18463, go, those last four sections may have their wells any day now.

So, I need to follow-up on:

• 20797, 1,208, CLR, Entzel 1-26H, Bakken, Cabernet, s8/11; t12/11; cum 391K 5/17; 30 stages. 2.8million lbs including 850K ceramics
• 18503 [now 21299], PNC/1,242, BR, Cecilia Stroh 1-18-19H-143-96, Bakken, Fayette; t3/12; cum 39K 6/12;
• 18463 [now 21298], PNC, BR, Elizabeth Stroh 1-7-6H-143-96, Bakken, Cabernet;
• 21298, 1,803, BR, Elizabeth Stroh 34-7MBH, Bakken, Cabernet, t3/12; cum 390K 5/17;
• 21299, 1,242, BR, Cecilia Stroh 34-7MBH, Bakken, Fayette, t3/12; cum 209K 5/17;
• 20147, 378, Slawson, Dagger 1-10H, Bakken, Cabernet; s3/11; t10/11; cum 53K 5/17; 6 stages only; problems with fracking; will see workover and then resume fracturing;
• 20537, 630, CLR, Carl 1-11H, Bakken, Cabernet; s6/11; t10/11; cum 140K 5/17; 30 stages; 2.9 million lbs; including 885K ceramics;

By the way, section 36-144-97 is held by production by a vertical Madison well:

• 14442, TA/283/IA, Armstrong, Beaudoin 36-1, Madison-Cabernet, spudded in 1996 this well has produced 128,000 bbls of oil; however, it appears shut in right now, having reported no production since September, 2010. Being considered for conversion to SWD well as of 2014.

Don't Forget Those Legacy Formation Wells -- CLR -- Bakken, North Dakota, USA

Red River Units (link to press release)

The Company’s production in the Red River Units averaged 14,328 Boepd in the second quarter of 2011, a two percent increase over first quarter 2011 production. The increased production reflects the ongoing one-rig drilling program and production optimization in these enhanced oil-recovery units.

“Our team working in the Red River Units is doing a tremendous job of enhancing the value of this legacy field,” Mr. Hamm said.

That one-rig team must feel kind of lonely. But doing great work. Mr Hamm probably knows those folks personally.

Deeper Oil-Bearing Zone in the Three Forks Formation? CLR Thinks There May Be -- Bakken, North Dakota, USA

Update

August 15, 2011: If you want to see a huge TFS well, click here. In four months: 114,000 bbls; still in DRL status when that production was reported. (DRL status means the well has not yet been completed, or if it has, it is still within the 30-day window of required reporting.)

Original Post

Press release.

The Company is currently drilling a North Dakota Bakken horizontal well to test the productivity of a deeper oil-bearing zone in the Three Forks formation. Five cores taken by the Company across the play reveal several oil-saturated dolomitic layers in the Three Forks as much as 220 feet below the bottom of the Lower Bakken shale. “Evidence from the cores indicates the potential for incremental reserves in the Three Forks,” Mr. Hamm said.

Some folks keep talking about multiple pay zones in the Alberta Bakken. I contend that we will see the same thing in the North Dakota Bakken, although "we" may be "comparing apples and oranges."

I posted the following which was a comment I received regarding this well:

I don't know which well it is; but I am very, very curious as to its location vis a vis what Whiting is doing in southwestern North Dakota,and particularly what Chesapeake is doing in southwestern North Dakota.

Is it possible, CLR, WLL, and CHK have noticed something exciting about that part of the state?

CLR: Up to 23 Rigs; 5 Fracking Crews -- Bakken, North Dakota, USA

Press release.

CLR will replace the Cyclone 18 rig it recently lost.

In addition, CLR says it will increase number of operated rigs in early 2012. Note the word "early."

Continental Resources (CLR) Closes In On One Million Net Acres in the North Dakota Bakken

CLR has grown its Bakken lease position to 901,370 net acres.  We're getting close to that "magic" number of one million net acres. 
 
Previously, 1Q11 --

• Previously:  Total Bakken acreage: 855,936 net acres 
• Previously:  BEXP presentation says CLR has 868,900 net acres
• Additional BLM acreage (8,266 acres) as of early December, 2010,  not included in that 864,559 net acres 

Source: press release.

Comment: some folks have commented that some operators are overextended and won't be able to get to all their leases before they expire. That may or may not be. I don't know. But I think these folks are smart enough to figure out how to manage their property. Regardless, in this operator's case, they are not selling their acreage; they are adding to it. Seed corn. 

CLR Press Release: Notable Company-Operated Wells in North Dakota -- 2Q11 -- Bakken, North Dakota, USA

• Carson Peak 2-35H (39% WI) in Dunn Co. – 2,239 boepd
• Carson Peak 3-35H (39% WI) in Dunn Co. – 2,237 boepd
• Morris 3-26H (39% WI) in Dunn Co. – 1,917 boepd
• Don 1-23H (47% WI) in McKenzie Co. – 1,680 boepd
• Vardon 1-14H (42% WI) in McKenzie Co. – 1,550 boepd
• Winston 1-12H (64% WI) in Williams Co. – 1,525 boepd
• Pittsburgh 1-19H (95% WI) in McKenzie Co. – 1,504 boepd
• Dolezal 2-5H (50% WI) in Dunn Co. – 1,456 boepd
• Akron 1-27H (74% WI) in McKenzie Co. – 1,407 boepd
• Morris 2-26H (39% WI) in Dunn Co. – 1,400 boepd
• Nordeng 1-8H (53% WI) in McKenzie Co. – 1,400 boepd
• Chicago 1-26H (44% WI) in McKenzie Co. – 1,395 boepd

Source: press release.

From same source, in CLR's prospect in southwestern North Dakota:

In late July, an additional North Dakota Bakken completion of note was the Debrecen 1-3H (39% WI) completed in Stark County. The Debrecen 1-3H targeted the Three Forks zone and tested in early production at 1,667 Boepd, flowing at 2,052 psi on a 24 choke. It is Continental’s strongest well to date in the Normandy prospect.

“This is a key test that sets up accelerated drilling activity in future years,” Mr. Hamm said. The Company has 103,334 net acres in Normandy, which covers parts of Billings, Dunn, McKenzie and Stark counties.

CLR has grown its Bakken lease position to 901,370 net acres.  We're getting close to that "magic" number of one million net acres. 
 
Previously, 1Q11 --

• Previously:  Total Bakken acreage: 855,936 net acres 
• Previously:  BEXP presentation says CLR has 868,900 net acres
• Additional BLM acreage (8,266 acres) as of early December, 2010,  not included in that 864,559 net acres

Some Random Notes and Comments Regarding Continental Resources (CLR) -- August, 2011 -- 2Q11 -- Bakken, North Dakota, USA

Some random notes and comments from the 2Q11 earnings report from Continental Resources and other sources reported at about the same time.

Some of these items are huge. The market has had a huge pullback, and many of the Bakken companies have been hit hard, the price of oil is way down, but step back a few moments, and look at some of things CLR is doing and saying. It really is quite remarkable.

First: CLR says they will increase 2011 oil production by almost 40% year-over-year. That's huge. Remember, this was a horrendous year in North Dakota for the first half: worse blizzards and worse winter in recent memory (maybe setting all-time records) and then the flooding, road closures and continued muddy conditions slowed down things in the North Dakota oil patch significantly in the 2Q11, but even with all that, CLR says it will increase production almost 40% year-over-year. Think if XOM, or COP,  or CVX said they were going to increase production by a similar amount.

Second: CLR is going to raise its CAPEX. It was already huge. CLR will raise their CAPEX to $2 billion. I can't get a handle on that; I don't have a feeling for $2 billion, but there are some states in the union with a budget crisis and a gap of $2 billion. And here, we have one company that will allocate just a portion of their earnings to CAPEX. Incredible. CLR is not the only Bakken company raising its CAPEX for the year. I think WLL said they were going to; someone else said the same thing the other day, that they were selling some weak-performing assets to raise cash to increase CAPEX. I see increased CAPEX across the board for 2H11 in the Bakken and it will continue into 2012. For investors, think of how this will effect oil service companies. (That link regarding state budget deficits: Florida: $4 billion deficit; Washington State: $5 billion deficit; Minnesota: $5 billion shortfall; Wisconsin: $3.6 billion deficit; Connecticut borrows $1 billion to cover budget gap. And one company, in the Bakken, will spend $2 billion on CAPEX. That provides some perspective.)

Third: quick, what's the average EUR for a Continental Bakken well? Increasing, decreasing, staying the same? CLR now raises the average EUR for a CLR Bakken well to 603,000 boe per well. That's an average folks. That means there will be some huge wells to offset wells that come in "only" at 300,000 boe EUR. Investopedia commented on this on August 11, 2011.

Fourth: CLR earnings up more than 30% in 2Q11. Again, this was a horrible quarter for operations in North Dakota, and CLR increased earnings by more than 30 percent.

Fifth: production for 2Q11 grew almost 39%. Either right on target, or slightly above target, and again, despite horrendous operating conditions this spring.

Sixth: data point -- snapshot -- CLR has 46 gross wells yet to be completed. These wells have sunk costs; they've reached total depth. They're waiting to be fracked. That will take a couple of days once the team is at the site. Some wells will tap into existing pipeline; others will have to truck out the oil. Many of the wells will be restricted in production due to flaring regulations. But 46 gross wells just waiting to be completed. And, again, that's just CLR.

Seed corn.

Twenty-Two Wells Completed -- August 4, 2011 -- Bakken, North Dakota, USA

For newbies:

The NDIC posts a daily activity report for the North Dakota oil patch every business day (which is free by the way, not even requiring one to sign in) usually about 5:00 p.m. The report is divided into many components. Some days there is very little to report; other days a lot.  (One segment that is almost always empty: DRY holes.)

The NDIC divides two segments that have to do with new wells reporting. One segment is the list of wells that are released from the CONFIDENTIAL list. Regardless of whether the well is completed, producing, or whatever, if the six months is up, the six months is up and the well comes off the CONFIDENTIAL list. In the old days that was more than enough time for a well to be completed, tested, and reported. With the backlog in fracking, etc., often wells released from the CONFIDENTIAL list still report no data, and are generally placed  on DRL (drill) status.

A second segment of the daily activity report is "Producing Wells Completed." These are wells that came off the confidential list earlier (sometime months earlier), have now been completed, given an additional 30 days to complete their reports, and now are reported out by the NDIC.

We can sometimes go several days before we see any wells on the "Producing Wells Completed" list, but most days one will see two or three such wells.

On August 4, while I was traveling, and still catching up, the NDIC's daily activity report was stunning in the number of producing wells completed. It may not have set an all-time record, but it was certainly a recent high: 22 wells were reported as completed.

Some highlights (most of these have been reported out already -- press releases, corporate presentations, etc):

Zavanna reported out four wells; two of them:

• 18064, 1,085, Zavanna, Cougar 1-35H, Williams County
• 19328, 853, Zavanna, Earl 1-13H, Williams County

Enerplus, reported one well:

• 18103, 915, Enerplus, Look Out Ridge 4-31H, Dunn

Zenergy, reported one well:

• 20026, 1,355, Zenergy, Nordeng 24-13H, McKenzie County (this looks like a nice well)

BTA reported two nice wells:

• 18758, 714, BTA, 20711 Paulson 49-1H, Williams County
• 19906, 823, BTA, 20711 Kreidle 3229 1H, Williams County

Petro-Hunt reported one well:

• 20011, 949, Petro-Hunt, Sovig 150-100-22C-15-1H, McKenzie County

So, that gives you some idea. It's exciting for me when I see these long lists. I am hoping to see similar things as the backlog of wells are completed this autumn. 

Of course, BEXP never fails to disappoint. It is unusual to see BEXP on this list; they usually get their wells fracked, completed, and reported within the six months, but here was one that was delayed:

• 19830, 1,835, BEXP, Irwin 15-22 1H, Williams County

Cabernet Field Updated -- Bakken, North Dakota, USA

Someone asked if I might update Cabernet oil field.

I updated the field; all IPs and cumulatives have been updated on the Cabernet oil field page.

Here are some very, very good wells from the Cabernet field. The "number" in bold (e.g., 198K, is the cumulative total of oil produced so far. I consider any well getting to 100k within a year to be a very good well.

• 18644, 1,148, Lime Rock Resources/OXY USA/Anschutz, 322K 2/14, test date 4/10, State 1-25-36H-144-97X; t4/10; cum 362K 9/16; 420K 11/23;
• 17899, TA/1,191/IA/AB, OXY USA/Anschutz, test date 9/9, Stroh 11-1H, the only short lateral in this field; 142,336 as of August 2011; t9/09; cum 157K 12/14; no real production since 1/12;
• 18423, 2,405, Lime Rock Resources/OXY USA/Anschutz, test date 11/10, Raphael Stroh 1-13-24H-143-97, actually in Fayette; 92K as of August, 2011; t11/10; cum 386K 9/16; 568K 11/23;
• 18193, TA/1,666, Lime Rock Resources/OXY USA/Anschutz, 188K, test date 10/09, Martin 34-31H; t10/09; cum 320K 12/14; mostly off-line since 7/14;
• 18424, 2,409, Lime Rock Resources/OXY USA/Anschutz, Kenneth Stroh 1-12-1H-143-97; t9/10; cum 560K 9/16; cum 705K 11/23;
  
• 18427, 876, Lime Rock Resources/OXY USA/Anschutz, 91K, test date 5/10, Matthew Schmidt 1-35-2H-143-97; 100K as of August 2011; t5/10; cum 182K 9/16; cum 242K 11/23;