BEXP reports another nice well northwest of Williston in the Bull Butte oil field. This is the only well in that field at the current time (November 2, 2009).
The initial production (IP) is reported as 1,776 bbls of oil equivalent, details to follow. This really is quite incredible. Somewhere down the road this well will decline down to about 1,000 bbls/day, but if the average for one year is 750 bbls/day, at $65/bbl, this could generate $18 million in the first year.
Not only is this a nice well, but it is practically a wildcat. Yes, it's in a designated field (Bull Butte) but there are no wells in the immediate area. The other wells near Williston of interest are due west of Williston, and much closer.
The BCD Farms 16-21 #1H was completed with 28 frac stages and is the sixth overall 18+ stage fracture stimulation completed by Brigham in the Williston Basin. The press release said the same thing I noted above: the well sits pretty much at the far extent of BEXP's acreage northwest of Williston. The press release mentions two other wells that have reached total depth and will be fractured in the next week or so: Lee 16-21 #1H and Strand 16-9 #1H.
The press release says that BEXP has also a third rig to its operations in the Williston area. I assume USEG has some interest in these wells.
Monday, November 2, 2009
Investing: Pipelines
Locator: 10010Pipelines.
Pipeline news is at the top; general information about the pipeline industry in North Dakota is below the YouTube video below.
NOTE: ENB and the "family" of ENB investments now has its own stand-alone page among Bakken Investing sites.
I track pipelines of interest here.
NEWS
November 7, 2025: officials approve WMB-NG pipeline into NYC and Long Island. WMB has scrapped plans after originally being disapproved by same officials. Link here. Called the NESE Pipeline -- the Northeast Supple Enhancement project -- NESE for short.
August 21, 2025: MDU wins the lottery: link here. A $500 million guarantee to build a new pipeline from the Bakken to the Red River of North Dakota.
February 22, 2025: KMI, Hiland, Outrigger deal closed. Link here.
February 15, 2025: Constitution Pipeline -- update -- President Trump wants it completed.
January 29, 2023: Ruby Pipeline.
August 18, 2022: DCP, Colorado, PSX, Enbridge.
July 22, 2022: Matterhorn Express Pipeline; Waha to Houston, natural gas; huge.
June 20, 2022: Enbridge Line 5 update.
June 18, 2022: North Dakota Bridger Pipeline approved and being laid.
February 19, 2022: Canada kills the Trans Mountain pipeline.
January 25, 2022: US Federal court vacates permit for Mountain Valley natural gas pipeline.
September 27, 2021: PennEast becomes the latest to scuttle a natural gas pipeline project.
PennEast Pipeline Co. said that although it received federal approval for the 116-mile pipeline from Luzerne County to Mercer County in New Jersey and some permits, it has not received water quality certification and wetlands permits required under the Clean Water Act.
May 24, 2021: Capline Pipeline reversal coming; implications for the DAPL.
May 21, 2021: federal judge allows DAPL to remain open.
May 21, 2021: Bridger Pipeline, Johnson's Corner to south of Watford City approved.
May 11, 2021: largest gasoline line in the US, Colonial Pipeline shut down by hackers; shutdown lasted about a week;
February 27, 2020: Williams (WMB) cancels Marcellus to "New York" Constitution Pipeline.
January 9, 2020: North American build-out.
June 11, 2019: $1.6 billion, 200,000 bopd, Liberty Pipeline proposed for North Dakota.
April 24, 2019: after Canadian federal government delays decision, TransMountain pipeline will likely miss another summer construction season.
March 4, 2019: Enbridge Line 3 delayed at least a year. I will be surprised if it ever gets built.
November 6, 2018: Voyager Pipeline proposed. Cushing to Houston; perhaps Corpus. Would ultimately connect Bakken directly to Gulf Coast refineries, export terminals.
September 18, 2018: Iowa Supreme Court has heard both sides for/against the DAPL. We will get judgment in four to six weeks. Very, very bad news. To say the least.
February 28, 2018: update on Enbridge Line 3 over at SeekingAlpha. This has dragged on so long, I had completely forgotten about it. I'm not holding my breath on this one. Pretty frustrating.
November 20, 2017: Nebraska regulators vote "no" with a 3-2 "yes" vote to approve the Keystone XL.
May 16, 2017: there are reports suggesting that oil is now flowing through the DAPL. Also, a third lawsuit against the DAPL asking for a court injunction to stop the flow has been filed within the last 24 hours.
March 27, 2017: DAPL pipeline oil under the lake.
February 13, 2017: Enbridge's Alberta Clipper one step closer to being approved. We're talking a 3-mile section of pipeline.
December 22, 2016: Blackstone Group in talks to buy a stake in ETP, builder of DAPL.
December 4, 2016: US Army Corps of Engineers won't issue easement for DAPL.
November 28, 2016: huge, huge story. Spectra Energy to expand pipeline from Guernsey, WY, to Patoka, IL.
August 12, 2016: how others see the Dakota Access Pipeline, a pipeline that is only 7 miles shorter than the Keystone XL would have been. Mother Jones has a nice overview.
August 5, 2016: update on the Bakken Pipeline System -- the Dakota Access Pipeline from North Dakota to Illinois via Iowa; and the Energy Transfer Crude Oil Pipeline from Illinois to Texas; funding complete; calls Sandpiper into question
August 5, 2016: Sandpiper in trouble; MRO pulls out; Enbridge to re-evaluate.
August 3, 2016: ETP and Sunoco sell their stake in the Dakota Access Pipeline to Marathon and Enbridge. Marathon will discontinue funding the Enbridge Sandpiper pipeline.
June 7, 2016: movement on the Dakota Access Pipeline noted.
May 27, 2016: Dakota Access Pipeline keystoned in Iowa, as predicted.
May 18, 2016: photograph of storage site/pump station for Dakota Access pipeline; photograph from reader; site on west side of ND State Highway 23 between Johnsons Corner and Keene, maybe about 2.8 miles north of Johnsons Corner.
April 11, 2016: Iowa formally issues Dakota Access pipeline permit -- Dickinson Press.
January 20, 2016: North Dakota approves Dakota Access Pipeline; only Iowa is yet to approve; company expects Iowa to approve "next month." I'll believe it when I see it.
October 19, 2015: RBN begins series on Enbridge Line 9 reversal and what it means for the Bakken.
October 16, 2015: ND PUC approves 23-mile McKenzie County pipeline; the NST Express 12-inch-diameter pipeline will move 100,000 bopd.
September 18, 2015: was the Sandpiper Keystoned?
June 6, 2015: Enbridge Sandpiper and Line 3; still going through the process. Sandpiper is farther along the regulatory process than Line 3. Enbridge still hopes to complete Line 3 in calendar year 2017 and flow oil starting in 2017.
April 26, 2015: ONEOK cancels Lone Creek Pipeline after Native Americans try to extort company for $10 million/mile of pipeline easement.
May 28, 2015: update of the ETP Bakken-to-Illinois Dakota Access Pipeline. Nothing new; company has only 56% of landowners signed on; wants to begin this year. My two cents worth: this pipeline won't be completed before 2021, if ever.
May 20, 2015: Enbridge to begin construction of the Sandpiper pipeline this summer; first phase in North Dakota.
April 14, 2015: Minnesota judge rules Enbridge's Sandpiper pipeline is "needed."
March 24, 2015: ETP, Bakken-to-Illinois, Dakota Access Pipeline, miles of pipeline being brought in, stored near Aberdeen, SD; South Dakota state has until December 15, 2015, to make decision.
February 27, 2015: Vantage ethane pipeline to be expanded, Tioga, ND, to Canada.
January 21, 2015: KMI buys Harold Hamm's Hiland pipeline company.
December 12, 2014: EPD cancels 1,200-mile pipeline from Stanley, ND, to Cushing, OK. See June 24, 2014, entry below.
November 1, 2014: ONEOK acquires Chevron's natural gas liquids pipelines; a Permian story.
October 28, 2014: update on new Bakken pipeline. ETP to take pipeline from the Bakken, through South Dakota, through Iowa, to Illinois (the Dakota Access Pipeline); and then a second pipeline from Patoka to Nederland, Texas. First mentioned at the blog by RBN Energy. Update at BizJournals:
Energy Transfer Partners announced a joint venture with Phillips 66 to build two pipelines to move crude oil out of North Dakota (75% / 25% respectively). Dakota Access Pipeline (DAPL) from the Bakken to Pakota; ETP Crude Oil Pipeline (ETCOP) south from Patoka.
September 8, 2014: a June 26, 2014-article in The WSJ suggests there could be almost one million bopd more pipeline takeaway capacity in North Dakota by 2016.
June 24, 2014: EPD announces first-of-its-kind, 1,200-mile, 30-inch-diameter pipeline, Stanley, ND, to Cushing, ND, to be completed by 4Q14;
June 7, 2014: Canadian government approves Enbridge's Northern Gateway pipeline, from Alberta, to the western British Canadian coast. It will be many years before this pipeline is completed (if ever).
March 6, 2014: Enbridge to replace aging Line 3, Canada to Superior; regulators approve reversing Line 9, Sarnia, Ontario, to Montreal.
January 22, 2014: Koch won't build the 250,000 bopd Dakota Express pipeline from the Bakken to Illinois. No explanation given.
January 21, 2014: EPD increases its distribution.
January 20, 2014: GE buying a company that provides flow equipment for oil and gas production.
January 3, 2014: Warren Buffett buys PSX company specialist in optimizing crude oil flow through pipelines.
December 6, 2013: EPP begins the ethane line fill for ATEX (Marcellus-Utica to Texas).
November 29, 2013: SeekingAlpha has an article on ETP.
November 26, 2013: Marathon to become biggest shipper on Sandpiper.
June 12, 2013: RBN Energy update on Enbridge and Energy Transfer Partners projects to convert two major natural gas pipelines to crude oil pipelines.
June 9, 2013: Glass Mountain Pipeline (crude oil) from Mississippi Lime / western Oklahoma to Cushing;
210 miles; two laterals; initial capacity of 140,000 bopd and
intermediate storage of 440,000 bbls; to be commissioned by late 2013.
May 30, 2013: MDU subsidiary to built $700 million natural gas pipeline.
April 4, 2013: Harold Hamm to build the Double H pipeline, should be on-line by August, 2014. $300 million. Initially 50,000 bopd; to reach 100,000 bopd. Dore, ND, to Baker, MT; joins the Butte Pipeline south to Guernsey, WY; new pipeline from Guernsey down to Tallgrass Pony Express pipeline (converted from natural gas to crude during this time period); to Cushing, OK.
January 4, 2013: update on EPD/ENB Seaway reversal and expansion; update on ENB Flanagan South pipeline.
December 3, 2012: ONEOK vs BNSF, SeekingAlpha.com.
November 27, 2012: for investors only (note disclaimer at this site) -- EPD, three stories today for those interested in EPD
- a) investment ideas from IEA's world energy outlook, from SeekingAlpha.com
- b) ECHO: Enterprise Crude Houston -- RBN Energy
- c) drought affecting Mississippi barge traffic, and EPD, from Bloomberg
September 2, 2012: Update on the ONEOK Bakken NGL Pipeline;
August 30, 2012: Enterprise Products offering additional capacity on ATEX Express ethane pipeline: Co announced the start of a binding open commitment period to determine additional shipper demand for capacity on the partnership's Appalachia-to-Texas ("ATEX Express") pipeline. The 1,230-mile system will deliver growing ethane production from the Marcellus/Utica Shale areas of Pennsylvania, West Virginia and Ohio to Mont Belvieu, Texas. [See January 23, 2012, entry.]
June 12, 2012: major Rangeland COLT update.
June 8, 2012: EPD has begun accepting deliveries for and commissioning the first phase of its Eagle Ford crude oil pipeline between Wilson County and Sealy, TX.
The 147-mile, 24-in. OD pipeline, scheduled to start up in July, can carry 350,000 b/d of oil.
May 29, 2012: SemGroup to build DJ Basin crude oil gathering system. (originally May 18, 2012).
May 23, 2012: Kinder Morgan announces deal to twin 714-mile pipeline from Alberta to Canadian west coast; increased capacity from 300,000 to 500,000 bopd
March 28, 2012: Enbridge/TransCanada race -- the Calgary Herald
A project that beefs up pipeline capacity to move crude from the U.S. Midwest to the world's largest refining market by Enbridge Inc. and Enterprise Products Partners LP is set to lift heavily discounted U.S. oil prices but won't boost even cheaper Canadian barrels, Enbridge chief executive Pat Daniel said Tuesday.
The more than doubling of a previously planned expansion of the Seaway pipeline between Cushing, Okla., and the Texas Gulf Coast, announced by Enbridge and Enterprise Monday night, will eat away at stockpiles of crude in the Midwest to bring U.S. oil prices closer in line with global barrels, but will not reduce Canada's reliance on one customer - the United States, Daniel said.February 15, 2012: new Bakken-to-Clearbrook, MN, pipeline proposed.
February 8, 2012: takeaway capacity constrained --
Calgary-based pipeline operator Enbridge has launched projects to add 10,000 barrels per day of rail oil capacity to its Clearbrook terminus by July, with another 70,000 barrels per day planned by 2013.January 23, 2012: EPP will build the ATEX express pipeline
Simmons forecasts the congestion may see some relief in May, when Enbridge and Enterprise Products Partners begin to fill their reversed Seaway Pipeline, from Cushing, Okla., to the Gulf Coast, which will require two to three million barrels of capacity.
delivering ethane production from the Marcellus-Utica shale areas of Pennsylvania, West Virginia, and Ohio to the US Gulf Coast. ATEX Express will transport as much as 190,000 b/d from Appalachian production areas to EPP’s storage and distribution assets in Texas.
Originating in Washington County, PA, the system’s first leg would involve construction of about 595 miles of new pipeline extending to Cape Girardeau, MO, closely paralleling an existing Enterprise pipeline. At Cape Girardeau, EPP will reverse a 16-in. OD pipeline and place it into ethane service.
At the southern terminus of the ATEX Express pipeline, EPP will build a 55-mile, 16-in. OD pipeline providing access to its NGL storage complex at Mont Belvieu, TX. Expected operational date: 1Q14.August 19, 2011: Enterprise Products Partners will NOT be building the 584-mile crude oil pipeline from Cushing, Oklahoma to Houston. There was a lack of commitment by oil producers to go forward with the project.
August 6, 2011: Reuters update of US mid-continent and Texas pipeline projects, completed and proposed.
April 14, 2011: Tesoro Logisitics, LP, to offer IPO of 14.375 million shares.
April 7, 2011: WMB announces three new pipelines from the Marcellus to metropolitan areas.
March 22, 2011: Update on Enbridge's proposed North Dakota Bakken to Cromer, Manitoba, pipeline expansion project; 74 miles; $180 million; service date: early 2013.
February 2, 2011: Motley Fools -- published earlier, but I just noted it -- ONEOK might be one of your better choices for dividend growth.
February 2, 2011: EPD announces that it is selling assets to focus on core business. Will sell barges and towboats for $53 million. Will build seven new marine vessels.
January 24, 2011: Problems for TransCanada's Keystone XL Pipeline: Texas landowners and Texas refiners don't want it.
January 14, 2011: EPD announces 26th consecutive quarterly distribution rate increase.
December 9, 2010: Keystone XL hearings in Nebraska. My hunch is the Keystone XL pipeline will not be completed in my investing lifetime. Any state from Montana to Oklahoma can scuttle the deal; and even if the states allow it, getting the necessary rights of way will take forever in light of recent Gulf of Mexico spills.
November 24, 2010: EEP's pipeline 6B will re-open this week following a several-month closure due to two pipeline oil spills earlier this year.
November 22, 2010: EPD will build a new crude oil terminal in Houston to handle growing production coming out of Eagle Ford, south of San Antonio.
November 15, 2010: Two huge pipeline acquisitions in the Bakken.
November 3, 2010: Plains All American to add Bakken North Project resulting in 50,000 to 75,000 more barrels/day starting in 4Q2012; will get Bakken oil directly to Cushing.
October 25, 2010: Update on TransCanada's Marketlink Pipeline, the first direct link from the Bakken to Cushing and the Gulf Coast.
October 14, 2010: Enterprise Products Partners (EPD) announces a 5.8% increase in its quarterly distribution. This is EPD's 34th distribution increase since its IPO in 1998, and its 25th consecutive distribution increase.
September 11, 2010: Enbridge signs agreement to provide services for Husky-operated Sunrise Oil Sands Project.
September 6, 2010: Just to give you an idea how much money is involved in the oil industry -- ENB announced it will be investing $185 million in a Canadian pipeline that will be completed in 2013.
July 20, 2010: Kinder Morgan to go public; Questar to spin off its E&P division, QEP; TransCanada Pipeline delivers its first oil to Chicago; TransCanada Keystone XL project on track but political issues may cause delays.
May 5, 2010: Enbridge's Alberta Clipper project on-line, April 1, 2010.
May 5, 2010: ENB 1Q 2010 Earnings Conference Call
February 19, 2010: North Dakota pipeline taking natural gas to Chicago. Big deal.
February 12, 2010: Pipelines let cash flow to shareholders (EPD, OGE, MMP).
February 12, 2010: Prairie Rose pipeline, 76 miles, natural gas, completed. The pipeline was laid by Pecan Pipeline, a subsidiary of EOG.
February 3, 2010: ENB -- a very nice 2009, and even better 2010 predicted.
February 1, 2010: EPD profits rise 78%; beat street.
January 27, 2010: Bridger Four Bears pipeline. 85-mile from fields to Tesoro in Mandan, 10-inch, 40,000 bopd.
... the 85-mile Four Bears pipeline through McKenzie, Dunn and Billings counties in western North Dakota later this year, according to state Public Service Commission filings.January 25, 2010: Bison pipeline on track, OGJ.
The proposed line is intended to connect with three pipeline networks that supply crude to the Tesoro Corp. refinery at Mandan, and to refineries in Minnesota and Wyoming.
January 13, 2010: Bison pipeline update, Bowman county.
January 7, 2010: Wall Street Journal transcript -- very positive on EEP , ENB, and TransCanada.
January 5, 2010: ENB upgrade completed; ND still short on capacity. Actually, it's EEP -- EEP's principal crude oil system is the largest transporter of oil production from western Canada. The system's deliveries to the United States account for approximately 11 percent of total U.S. oil imports.
December 9, 2009: ENB to have largest photovoltaic solar energy facility in North America.
December 2, 2009: ENB increases its dividend 15%.
December 1, 2009: EPD bought another pipeline, probably small news item in the big scheme of things, but linked here just to be complete. The pipeline originates in Odessa, west Texas, and 265 miles later connects with a Pemex pipeline at the Mexico-US border near El Paso. EPD is NOT in the Bakken.
November 20, 2009: I missed reporting on this one earlier: EPD bought TEPPCO Pipeline this summer. This merger creates a massive new player in the pipeline business. It pays 7.5% and with the merger has significant share appreciation potential. The "EPD Family" is now the largest MLP in the US. EPD is NOT in the Bakken, as far as I know.
November 12, 2009: Keystone Pipeline nearly complete.
October 14, 2009: ENB: 52-week high; pays 3.5%. Compare with money market funds. Nice Barron's article on ENB, T. 2010 Guidance Conference Call scheduled for December 2, 2009.
November 3, 2009: EEP: $0.99/share payable November 13 for those holding the shares November 5, 2009. Ex-div: November 3, 2009. Pays 8.3%. I use EEP as a place to hold funds while deciding what to buy. If dividend looks questionable, will look for other high dividend payers in the oil patch.November 28, 2009: In addition to the 570 new wells requested by EOG in case 11939, I count about 241 additional wells by EOG and other producers.
Note: until this month, I had never paid attention to "dockets." It turns out that a docket with 19 pages is not unprecedented. The July 21, 2009, docket had 19 pages, and in that same month (July 29, 2009), there was another docket with 14 pages. In 2009, there were an average of 18 pages of requests if one excludes the month of July. In July, there were 39 pages of requests, total. The number of pages by month shows a trend: Jan (16 pages); Feb (14); Mar (13); Apr (14); May (16); Jun (15); Jul (39); Aug (24); Sep (18); Oct (21); Nov (28); and, Dec (29). This continues to validate my hunch that 2010 is going to be a watershed year for the North Dakota oil industry if oil stays above $70/barrel. CLR has hedged 5,000 bopd for $80 between January and July, 2010.November 4, 2009: The Mountrail County Promoter states that North Dakota, already the 4th leading oil producer in the United States, would produce more oil if pipeline capacity was adequate. The writer notes that there is talk of two more pipelines in the Stanley area: one would take oil into Canada and then back into the states through another pipeline; and the second additional pipeline would take oil out of the local area. I have opined elsewhere that one starts to get the feeling that the Williston Basin could become another "Tulsa" over the next two decades.
For investors, I think the pipeline companies are going to be able to charge a surcharge to transport all the oil that will be produced.
*****
Pipeline, The Ventures (I couldn't resist.)
*****
American Pipelines
ESPO.
Pipeline, The Ventures (I couldn't resist.)
*****
Morgan Kinder to go public in 2010.
ENB, EEP, EEQ (family): ENB and EEP are my favorite (as noted below, I don't follow EEQ). I have ENB as a long-term hold, and I trade in and out of EEP for the distribution. Stand-alone page.
STR: Questar -- an E&P company but a conglomerate focused on energy; one of its five core competencies is pipeline. Might be a better alternative to MDU during current recession. March 9, 2010. Questar will spin off its E&P division at end of July, 2010: QEP.
EEQ: I don't follow. Pays 8.5%.
MDU: If interested in pipelines, this is a very interesting play. Safe, conservative, Fortune 500, nice dividend, particpating in the Bakken in many ways. Has had some tough quarters during the 2008 - 2010 recession; I used to hold / accumulated shares, but sold all my MDU during the recession. Switched to ENB and EEP.
Pecan Pipeline: wholly-owned subsidiary of EOG, according to third-hand source. Not verified.
Pipeline network in North Dakota, a "pdf" file.
EPD: not in North Dakota, as far as I know, but I follow and often invest in due to high dividend and good outlook. [With the June 24, 2014, announcement, EPD will now be building a pipeline in North Dakota.]
****************************
Overseas Pipelines
Overseas Pipelines
ESPO.
Investing: Denbury / Encore
DNR: Yahoo!Financials
4Q10, earnings, triple, February 23, 2011.
3Q10, earnings, Zacks, November 8, 2010
2Q10, earnings transcript. August 5, 2010.
4Q10, conference call. February 24, 2010.
2Q, 2010, earnings, August 5, 2010.
New presentation, June, 2010.
Investopedia: Update on DNR, May 30, 2011. 266,000 net acres under lease in North Dakota (Bakken).
Seeking Alpha on DNR, March 4, 2011.
521 wells transferred to Denbury Onshore, LLC. See Daily Activity Report, March 3, 2011.
Calculating DNR's Worth, Investopedia. February 14, 2011.
Denbury increased its reserves by 92 percent in 2010. February 3, 2011.
Motley Fool: Is Denbury a "Buy"? Just one month later the fools seem to be very bullish on DNR. Not only a buy, but a bargain. January 12, 2011.
Motley Fool: Is Denbury a "Sell"? It failed four of five Motley Fool tests, but it's not a "sell". Go figure. December 11, 2010.
Investopedia: Denbury is king of tertiary recovery. November 23, 2010.
Vanguard Natural Resources LLC said it has signed an agreement to acquire the ownership interest in Encore Energy Partners LP held by Denbury Resources, Inc. The deal is valued at $380 million. After the transaction closes December 31, 2010, Vanguard will own Encore's general partner and about 21 million Encore common units, representing a 46-percent stake. November 17, 2010.
Buying EAC makes Denbury one of the largest independent oil and gas producers overnight. Originally posted November 5, 2009; link added November 17, 2009.
With the recent announcement of Denbury buying Encore, one might be interested in seeing Encore's presentation just before that announcement. Shareholders approve the deal. March 8, 2010.
On the first trading day following the announcement, EAC rose $8, from $37 to $45, while Denbury (DNR) dropped a dollar. Regardless of whether this represents an opportunity to buy DNR, there is no question that this helps establish the value of holdings in the Bakken. It may take awhile for this to sink in, but all things being equal, the value of Bakken holdings across the spectrum just increased.
I am absolutely convinced we are seeing just the beginning of a new age in North Dakota oil industry. I still think that there is a chance that the Williston Basin will become the new "Tulsa" -- without all the people. It's just too cold, too distant, for that kind of population growth. But in terms of production, pipeline, and potential, we could be seeing another Tulsa.
For those who may have missed it, there is movement on Capitol Hill (Washington, DC) to make natural gas a significant part of the "green" energy movement and energy independence going forward. Interestingly enough, there are others who feel natural gas should not be part of the "green" energy movement.
4Q10, earnings, triple, February 23, 2011.
3Q10, earnings, Zacks, November 8, 2010
2Q10, earnings transcript. August 5, 2010.
4Q10, conference call. February 24, 2010.
2Q, 2010, earnings, August 5, 2010.
New presentation, June, 2010.
NEWS
Investopedia: Update on DNR, May 30, 2011. 266,000 net acres under lease in North Dakota (Bakken).
Seeking Alpha on DNR, March 4, 2011.
521 wells transferred to Denbury Onshore, LLC. See Daily Activity Report, March 3, 2011.
Calculating DNR's Worth, Investopedia. February 14, 2011.
Denbury increased its reserves by 92 percent in 2010. February 3, 2011.
Motley Fool: Is Denbury a "Buy"? Just one month later the fools seem to be very bullish on DNR. Not only a buy, but a bargain. January 12, 2011.
Motley Fool: Is Denbury a "Sell"? It failed four of five Motley Fool tests, but it's not a "sell". Go figure. December 11, 2010.
Investopedia: Denbury is king of tertiary recovery. November 23, 2010.
Vanguard Natural Resources LLC said it has signed an agreement to acquire the ownership interest in Encore Energy Partners LP held by Denbury Resources, Inc. The deal is valued at $380 million. After the transaction closes December 31, 2010, Vanguard will own Encore's general partner and about 21 million Encore common units, representing a 46-percent stake. November 17, 2010.
Buying EAC makes Denbury one of the largest independent oil and gas producers overnight. Originally posted November 5, 2009; link added November 17, 2009.
******
Original Blog
March 2008
Original Blog
March 2008
With the recent announcement of Denbury buying Encore, one might be interested in seeing Encore's presentation just before that announcement. Shareholders approve the deal. March 8, 2010.
On the first trading day following the announcement, EAC rose $8, from $37 to $45, while Denbury (DNR) dropped a dollar. Regardless of whether this represents an opportunity to buy DNR, there is no question that this helps establish the value of holdings in the Bakken. It may take awhile for this to sink in, but all things being equal, the value of Bakken holdings across the spectrum just increased.
I am absolutely convinced we are seeing just the beginning of a new age in North Dakota oil industry. I still think that there is a chance that the Williston Basin will become the new "Tulsa" -- without all the people. It's just too cold, too distant, for that kind of population growth. But in terms of production, pipeline, and potential, we could be seeing another Tulsa.
For those who may have missed it, there is movement on Capitol Hill (Washington, DC) to make natural gas a significant part of the "green" energy movement and energy independence going forward. Interestingly enough, there are others who feel natural gas should not be part of the "green" energy movement.
Welcome to the "new" Million Dollar Way
The news coming out of North Dakota oil patch is almost coming too fast to keep up.
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 frac.
Denbury announcing a couple days ago that it was buying Encore was the top news story almost everywhere; it was certainly the top news story in the oil patch. Denbury becomes the fourth largest independent oil exploration and producing company 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.
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
Last updated: November 2, 2009.
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 frac.
Denbury announcing a couple days ago that it was buying Encore was the top news story almost everywhere; it was certainly the top news story in the oil patch. Denbury becomes the fourth largest independent oil exploration and producing company 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.
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. And, I'm still waiting to hear how the "barnburner" up by Grenora is doing.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.
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
Last updated: November 2, 2009.
Sunday, November 1, 2009
Monster Wells in the Williston Basin, North Dakota, USA
Locator: 10001MONSTER.
Note, as of October 31, 2018, no more Bakken wells will be added to this page. New "monster Bakken wells" will be linked at "third generation wells."
Note, August 27, 2017: due to the number of wells reporting cumulative production of 500,000 bbls of crude oil, future wells to make the "monster well" page will require 750,000 bbls. Of course, there will be exceptions.
Note: this page has been completely revamped; some of the "older" comments reference the original "Monster Well" page. [Memo to self: start with 19220; second time through, start with 16119. Also check #16435 later. First Bakken ~15525 (maybe earlier; working backwards, no Bakken wells from 15525 all the way back to 15455).]
Monster wells based on cumulative production, not IPs.
Miscellaneous
Single "Other" payzone wells
- 7002, 754, Petro-Hunt, Silurian 6-1, Charlson, t2/80; cum 642K 5/22; Silurian; see this post; cum 651K 12/23; cum 661K 10/25;
- 7571, PA/AB/482, Hess, Reitsch NCT-2 4, Blue Buttes, Silurian; s7/80; t4/81; cum 1.006 million 8/14;
- 9057, PA/731/AB, Hess, Riggs 10-31, Blue Buttes, Stonewall, t5/85; cum 817K 10/17; producing only 250 bbls/month but still active; good for them; went off line 10/17;
- 9069, 992/PA, Hess, R. L. Olson 9, Blue Buttes, t1/82; cum 647K 11/98;
- 11211, PA/AB/372, Hess, W. Kamp 3-21, West Capa, t5/85, Silurian, cum 927K 5/18; still producing 400 bbls/month 32 years later; occasionally goes off-line;
- 11785, PA/594, Petro-Hunt, Charlson Federal 13D-1-1SWD, s12/85; t2/86; PNA/SWD; cum 1.1 million bbls; Silurian; last produced 8/10;
- ***12268, 800, Petro-Hunt, Silurian 63-1, Keene, t1/88; cum 988K 5/22; cum 993K 7/23; off line; 1 million bbls 4/26!
- 1937, 362/PA, Hess, Beaver Lodge-Devonian Unit E-309, t11/58; cum 2.23 million bbls 4/01; cum 2.29 million bbls 5/2001
- 1982, 609/AB/PA, Hess, Beaver Lodge-Devonian Unit F-206, s8/58; t11/58; cum 564K 5/15; Silurian
- 1982, 263/AB/PA, Hess, Beaver Lodge-Devonian Unit F-206, s8/58; t11/58; cum 958K 4/74; PNA; Devonian
- 2462, 340/564/AB, Hess, Beaver Lodge-Devonian Unit C-3051, Silurian/Devonian, t11/59; cum 706K/2.74 million bbls --> total, over 3.4 million bbls; was producing 4,000 bbls/month in 1997 when it was taken off-line; produced for almost 40 years;
- 35, 503/PNA, Hess, Beaver Lodge-Devonian Unit H-310, s8/51; t4/52; Madison, 216K; PNA
- 35, PA/AB/63, Hess, Beaver Lodge-Devonian Unit H-310, t3/60; Devonian, 2.092 million bbls; still active; almost 1,500 bbls monthly, 11/16; around 1,000 bbls monthly in 2015; Went inactive 12/13; back on line as of 8/15; last production 7/17;
- Note: #35 is no longer the oldest well in North Dakota still producing; all but two or three wells earlier than #35 were dry. Well #2 was completed in 1923; well #1 was completed in 1916, in Ward County; it tested positive for trace oil. The Clarence Iverson well that started it all was drilled in 1951. #35 last produced in 7/17;
- 5200, White Rock Oil & Gas, Carl Olson 1-13, Horse Creek,
- Red River Unit t 9/72, 384, cum 675K 12/23; cum 688K 4/26;
- Red River, t12/02; 80, cum 124K 12/23; cum 132K 4/26;
- 1202, 224/PNA, Hess, Antelope-Madison Unit I-519, t9/56; Madison; cum 364K; PNA
- 1202, 210/PNA, Hess, Antelope-Madison Unit I-519, t6/59; Sanish; cum 619K; PNA
- 235, 478/PNA, Hess, Lalim-Borstad 35-41, Tioga field, Madison; t1/53; cum 283K
- 235, 429/PNA, Hess, Lalim-Borstad 35-41, Tioga field, Ordovician; t8/67; cum 956K
- 235, 265/PNA, Hess, Lalim-Borstad 35-41, Tioga field, Devonian; t7/84; cum 1.40 million
- 6757, 768/PNA, Encore, Clark 1, Missouri Ridge, Red River; t8/79; cum 588K
- 6757, AB/262, Encore, Clark 1, Missouri Ridge, Stonewall; t8/79; cum 361K 9/14;
- 6757, 3/PNA, Encore, Clark 1, Missouri Ridge, Birdbear; t11/01; cum 329 bbls
- 7142, 318/PNA, Whiting, E. B. Green 1-1, Sioux Field, Red River; t2/80; cum 588K
- 7142, 59/PA, Whiting, E. B. Green 1-1, Sioux Field, Madison; t7/02; cum 215K 8/16; AL; 1,000 bbls/month 9/15; still producing from the Duperow, cum 79K 6/19; see next entry;
- 7142, 167/PA, Whiting, E. B. Green 1-1, Sioux Field, Duperow; t7/02; cum 80K 11/19; AL; 7/09;
- 11700, 118/PA, SM Energy, B. A. Green 1, Sioux Field, Stonewall; t3/03; cum 236K 11/16; AL; 400 bbls/month 1/13;
- 11700, 59/PNA, SM Energy, B. A. Green 1, Sioux Field, Red River; t11/85; cum 841K
- 11700, N/D/PA, SM Energy, B. A. Green 1, Sioux Field, Duperow; t--; cum 194K 11/16; AL; 1,000 bbls/month 1/13;
- 6362, 234/PNA, Hess, BLDU G-303, Silurian, t2/79, cum 354K thru 8/02
- 6362, 157/AB, Hess, BLDU G-303, Devonian, t8/03, cum 269K 3/17; last produced 10/17;
- 6362, 140/PNA, Hess, BLDU G-303, Ordovician, t7/78, cum 8K two months of production
- 6362, AB, Hess, BLDU G-303, Duperow, t7/03; cum 90K 3/17; last produced 10/17;
- 9144, AB/641, Amerada Federal 32-22, Beaver Creek, Birdbear, s10/81, t12/98; cum 1.04 million bbls 8/16 (only a couple of days each month now (Red River cumulative from same well, 372K as of 11/11); 8/16; last produced 6/18;
Dawson Bay
- See this link
- 12086, AB/360, CLR, Osborne 1, Dawson Bay pool, Dolphin field, s1/59; t4/59; AL; cum 1,241,243 bbls 2/17; only one or two days each month; sometimes no days in any month;
- 12114, 250/IA, CLR, WSP 21-30, Dolphin, t9/87; cum 577K 11/19; back on status as of 9/14; cum 589K 5/25; IA;
Devonian
- 35, AB/263, Hess, Beaver Lodge-Devonian Unit H-310, Beaver Lodge, t3/60; cum 2.091755 million bls 5/18; off-line 7/17;
- 718, IAW/188, Hess, Beaver Lodge-Devonian Unit F-311, Beaver Lodge, t6/65; cum 1.869286 million bbls 8/15;
- 1403, 351/IA, Hess, Beaver Lodge-Devonian Unit B-304, Beaver Lodge, t11/57; cum 2.5553567 million bbls 6/9; still producing almost 2,000 bbls/month, 6/17; 1,000 bbls in 4/19;
- *****2009, 179, Cobra/Enduro, North Dakota C A 2, McGregor, t12/58; cum 1.2316675 million bbls; still producing about 650 bbls/month, 9/20; going on 62 years of age; cum 1.33 million bbls 5/22; 1.35 million bbs; 68 years old.
- 2150, PA/387, Amerada/Hess, Herfindahl + Davidson #1, Beaver Lodge, Devonian pool, Beaver Lodge field, s1/59; t4/59; AL; cum 918,970 bbls as of 7/74; last production numbers in 1974: 4,000 bbls/month;
- 2501, PA/115, Hess, BLDU G-311D, t1/60; cum 1.11 million bbls 4/01; last production in 1997; SWD;
- 2515, PA/306, Hess, Beaver Lodge-Devonian Unit C-303, t2/60; cum 1.335636 million bbls; last produced 5/09 (55 years of production)
- 3900, AB/102, Hess, Beaver Lodge-Devonian Unit D-307, Beaver Lodge, t11/65; cum 1.059911 bbls 5/18; back on active status as of 8/17;
- *****3983, 234, Cobra/ Operating, North Dakota C A 3, a Devonian well, vertical, 320-acre spacing, t1/66, cum 1.411065 million bbls 9/20; celebrated its 54th anniversary January, 2020; still producing about 500 bbls/month, 6/17; up to 800 bbs/month, 6/19; cum 1.423 million bbls 5/22; 56 years old; um 1.45 million bbls 4/26; 60 years old;
- 7141, 521, Wesco, Hamre 1-14, Cherry Creek, Duperow; s8/79; t2/80; cum 845K 11/19; inactive 6/15; active as of 8/15; 500 bbls, 11/19 over 17 days; cum 863K 5/22;
- 11137, 191-->IA (3/22), Rim Operating, Pederson 5-24, Hardscrabble, t6/85; cum 816K 10/18; still active; but just barely; last production, 3/22; now IA;
- 11269, AB/874, XTO, Martin 3 1, Bear Creek, Duperow; s11/84; t12/84; cum 1.172 million bbls 7/15; no production since 8/15 - first month in a very long time with no production;
- 8499, PA/1,652, Citation Oil & Gas, Skachenko A 1, Jim Creek, Duperow pool, t10/81; cum 1.536 million bbls; last produced 11/11; 30 years of production
- 2949, 260, Denbury Onshore, Cedar Creek Unit 8B 14X-2A-8, Cedar Creek, target: Ordovician, unitized, t8/61; cum 480K 11/19; producing for 64 years; cum 494K 7/25; 61 years old;
- 2993, AB/392, Denbury Onshore, Cedar Creek Unit 8B-23-11A-11, t11/61; cum 1.00 million 8/04;
- 12592, 221/AB, Hess, Beaver Lodge-Ordovician Unit 7, Ordovician, s5/89, t8/89; cum 774K 6/12 (last production); never on a pump; 1,500 bbls/month most of this past decade; was still producing about1,000 bbls/month after some 20+ years still not on a pump;
Madison
- The Lone Butte oil field Madison wells; see linked post
- The Red Wing Creek field Madison wells, True Oil Company; see linked post
- 42, 521/PA, Amerada Hess, Beaver Lodge-Madison Unit V-26, t2/52; cum 911K 9/82;
- 165, 645/PNA, Hess, Beaver Lodge-Madison Unit G-11, Beaver Lodge; t6/53; cum 1.02 million bbls;
- 345, 504/PNA, Hess, Tioga-Madison Unit L-144, Tioga, t8/53; cum 2.1 million bbls; 5/07
- 498, AB/292, Hess, Tioga-Madison Unit L-132HR, Tioga, t7/54; cum 534K 11/18;
- 1361, PA/177, Hess, Hawkeye-Madion Unit G-613 HR, Hawkeye oil field; t7/59; cum 621K 10/17; vertical (1959; lateral (1999); second lateral (2000); back on status 12/15; almost 60 years old (as of 2019)
- 1571, PA/IA/225, Hess, Antelope-Madison Unit D-519HR, re-entered 2001 to test Hastings formation, t12/57, cum 695K 7/17; last produced 8/17;
- 1824, 328/PA, Hess, Blue Buttes-Madison Unit L-306, t6/58; cum 1.01 million bbls 2/05;
- 1884, 131/PA, Petro-Hunt, Spangrud 2, North Tioga, t7/58; cum 681K bbls 10/14;
- 1902, 135/PA, Amerada Hess, Blue Buttes-Madison Unit L-309, t7/58; cum 640K 6/95;
- 1918, 187/PA, Hess, Blue Buttes-Madison Unit M-405, Madison, Blue Buttes, s7/58; t8/58; PNA 8/09; 1.28 million bbls;
- 1951, PA/108, Petro-Hunt, CMSU A-327, Charlson, t9/58; cum 522K 1/09;
- 1971, 236/PA, SM Energy, Bear Den 2, t9/58; cum 745K 3/05;
- 2275, PA/AB/160, Taqa North USA/Pan American, Clara Kostad #1/Rival-Madison Unit 14, t4/59; cum 659K 8/16; (back on status as of 9/15; 57 years old); then back off line as of 6/16; went inactive 7/16;
- 2469, 1,526/PA, Shell/Petro-Lewis, N.P.R.R. 32-15-1/N. Pacific 32-15, t12/59; cum 813K PA; Jun, 1977
- 2669, A/IA/102, Scout Energy Management, LLC / Denbury Onshore, Wilms A 1, Wiley oil field; t6/60; cum 445K 8/19; still active after 59 years, just plugging away, day after day, 500 bbls/month ~ $40,000/month, costing about a dollar a day to operate, I suppose. It is classified as a horizontal re-entry; it looks like it was re-entered in 2003; only one (1) day in 2/16; INACTIVE as of 3/16; appears to be back on status as of 10/16; but then back off-line 8/17; back on line as of 12/17; cum 451K 5/22; 62 years old; looking good now; cum 455K 12/23;
- ******3580, 480, Cobra/Enduro, Rusch B 1, Sherwood, t6/64; cum 2.383598 million bbls 9/20; (that's 56 years of production); cum 2.387 million bbls 5/22; 58 years old;cum 2.39 million bbls 4/26; 62 years old;
- 5166, PA/AB/30, Genesis St Operating, Vendsel 1 (a vertical well), Lake Darling, Madison, t4/72; cum 759K 3/14;
- 5212, 430, True Oil, Red Wing Creek Unit 11-27, Red Wing Creek, t11/72; cum 681K 12/23;
- *****5260, 396, True Oil, Red Wing Creek Unit 33-27, Red Wing Creek, F, t2/74; cum 3.640743 million bbls 12/23; still producing upwards of 6,000 bopm; cum 3.73 million bbls 4/26; still very productive;
- 6399, PA/1,360, Petro-Hunt, Lillian Glovatsky 1-19-1A, Madison, Little Knife, t5/78; cum 1.14 million bbls 5/16 (none in 2/16); off-line as of 8/16;
- 6165, 772, Petro-Hunt, Klatt 2-19-3D, Madison, Little Knife, t7/77; cum 1.538964 million bbls 8/19; cum 1.559 million bbls 5/22;
- 6225, 1,392/AB,
Petro-Hunt/Gulf Oil, Zabolotny 2-3-3-C, Little Knife field, Madison
Pool, t12/77; cum 3.0617 million bbls 8/19; and still producing 1,200
bbls/month; 8/19; cum 3.086 million bbls 5/22;
- 6082, 470/AB, Petro-Hunt, Martin Weber 1-18-1C, Madison, Little Knife, t5/77; cum 958K 8/19; cum 972K 5/22;
- 6118, 597/PNA, Petro-Hunt, Martin Weber 2-18-4D, Madison, Little Knife; t5/77; cum 1.12 million bbls 3/13
- 6212, 926/AB, Petro-Hunt, Tachenko 1-15-1B, Madison, Little Knife, t3/78; cum 889K 11/19; cum 896K 5/22;
- 6421, PA/731, Petro-Hunt, Rose Glovatsky 1-20-1A, Madison, Little Knife; t10/78; cum 1.368135 million bbls 8/19;
- 1312, PA, Amerada Hess, Hawkeye-Madison Unit F-616, s11/56; s12/56; cumulative 416,393 bbls;
- 4013, PA, Hess, Hawkeye-Madison Unit B-616, t2/66; cum 413,464, a Madison well
- 1295, AB/288, Hess, short lateral, Hawkeye-Madison Unit E-613HR, s12/56; t1/57; cum 240K 6/12; this was a vertical that was re-entered and was a very short lateral
- 1246, PA/IA/161, Hess, Hawkeye-Madison Unit G-603HR, Madison, Hawkeye, s9/56; re7/05; t10/56; cum 487K 11/17; spud 1956 (producing for 56 years); was inactive early in 2015; now active again; for an in-depth look at this well, click here; just went off-line 11/17; remains off line 11/19;
- 6258, PA/370, Citation Oil & Gas, Federal 1-17, Madison; t12/78; cum 985 11/17; still active (about 1,000 bbls/month)
- 6618, PA/132, Denbury, Franks Creek State 1-22, T.R., Madison; t10/78; cum 1.18 million bbls; 34-year-old vertical Madison well with >
- 7123, 450/PA, Whiting, Big Stick (Madison) Unit 9550, t4/80; cum 1.87 million 8/19; still producing 1,300 bbls/month, 8/19; cum 1.91 million bbls 5/22;
- 7274, 1,100/PA, Whiting, Big Stick (Madison) Unit 2502, t5/80; cum 2.05 million 11/94
- 7447, AB/932, Whiting, Big Stick (Madison) Unit 3002, t10/80 cum 1.09 million 8/19; was inactive for a couple of months in 2013; ready to die? only 30 bbls/month 8/19;
- 7485, AB/702, Whiting, Big Stick (Madison) Unit 1302, t5/81; cum 2.31 million 11/16;
- 7495, AB/368, Sequel Energy, Flat Top Butte 15-24, Madison, t8/80; cum 769K 8/15;
- 9295, 1,324, Whiting, North Elkhorn Ranch Unit 2001 a Madison well, t9/82; cum 1.249236 million bbls 7/17; this well has produced for about 35 years; cum 1.26 million bbls 5/22; cum 1.265 million bbls 4/26; 44 years old;
- 9772, 1,128/PNA, Whiting, North Elkhorn Ranch Unit 2101 a Madison well, t10/82; cum 1.2 million bbls 10/13; this well is still active and producing 1,000 bo per month;
- ******10973, 183, Petro-Hunt, CMNU A-203X, Charlson, t9/84; cum 946K 11/18; see this post; cum 982K 5/22; cum 990K 2/23; cum 1.01 million bbls 4/26;
- 11059, 377, Kaiser-Francis/Oasis/SM Energy, Anderson 10 32, Camp, t9/84; cum 733K 7/17; 1,000 bbls/month; cum 784K 5/22; ccum 795K 2/23;
- 12487, 272, Petro-Hunt, Texaco Otto Boss 18-1, Stockyard Creek, Madison; s8/88; t9/88; cum 703K 7/17; cum 740K 5/22; cum 745K 2/23; 36 years old;
- 16638, 143, Mercury Resources, LLC/Zenergy/Zavanna, Charbonneau 1-14H, Madison, Briar Creek, spacing one section; t9/07; cum 358K 8/19; cum 393K 5/22; cum 405K 2/23;
- 5209, 281, Luff Exploration, Dronene 33-20, Amor field, Red River, t11/72; cum 1.273020 million bbls 12/23; 700 bbls/month -- fairly good for such an old well;
- ****5227, 624, Luff Exploration, Greni 33-26, State Line, t11/72; cum 1.381895 million bbls 11/23; still producing 1,000 bbls / month;
- 5269, AB/IA/380, Abraxas, Miller 7X-27, Coyote Creek, s5/73; t7/73; cum 952K 9/17; still producing; 2 bbls/month; 40 years old in 2013; INACTIVE 5/16; back on status 6/16; producing only one or two days recently; IA again, as of 11/18; remains inactive 10/19;
- 5930, 300/PA, Petroleum, Inc., Arithson C 1, t9/76; cum 1.0246 million bbls; last produced July, 1997; about 21 years of production
- 15659, 301, Denbury/BR, CHSU 11D-33SH 15, t2/05; Cedar Hills field, cum 1.011060 million bbls 7/25; still producing 2,000 bbls/month;
- 15786, TA/1,119, Denbury Onshore, CHUSE 24A-18SH 15, Cedar Hills, a South Red River well, t9/05; cum 658K 11/13;
- 15828, 673, Denbury Onshore, CHSU 13C-11SH 16, Cedar Hills, t12/05; cum 958K 1/20; cum 1.041012 million bbls 7/25;
- 15829, 374, Denbury Onshore, CHSU 13C-11NH 16, Cedar Hills field, t10/05; cum 813K 1/20; South Red River B well; cum 833K 5/22;
- 15837, 634, Denbury Onshore, CHSU 13C-14NH 16, Cedar Hills, t12/05; cum 699K 1/20; cum 719K 5/22; cum 742K 4/26;
- 15847, 342, Denbury Onshore, CHSU 24C-14NH 16, South Red River B, t9/05; cum 910K 1/20; cum 954K 5/22; cum 970K 4/26;
- 15849, 188, Denbury Onshore, CHSU 31B-3NH 26, South Red River B, t8/05; cum 733K 1/20; cum 762K 5/22;
- 15850, 190, Denbury Onshore, CHSU 33B-33NH 26, South Red River B, t8/05; cum 486K 1/20; cum 498K 5/22;
- 15907, 752, Denbury Onshore, CHSU 33C-10SH 16, Cedar Hills, South Red River B, t2/06; cum 1.2966 million bbls 1/20; still producing 1,700 bbls/month; cum 1.34 million bbls 5/22;
- 15939, 773, Denbury Onshore, CHSU 13C-10SH 16, Cedar Hills, t3/06; cum 927K 3/21; cum 943K 5/22; cum 971K 4/26;
- 15940, 483, Denbury Onshore, CHSU 13C-10NH 16, Cedar Hills t4/06; cum 659K 1/20; cum 686K 5/22; cum 710K 4/26;
- 16008, 329, Denbury Onshore, CHSU 42C034NH 26, s2/06; Cedar Hills field, cum 986K 1/20; cum 1.027 million bbls 5/22;
- 16120, 383, Denbury Onshore, CHSU 13C-29SH 26, Cedar Hills, South Red River B, t6/06; cum 665K 1/20; cum 695K 5/22;
- 16122, 155, Denbury Onshore, CHUS 22C-5SH 16, Cedar Hills, South Red River B, t6/06; cum 774K 1/20; cum 813K 5/22;
- 16123, 349, Denbury Onshore/BR, CHSU 22D-5NH 16, t6/06; Cedar Hills, cum 1.036929 million bbls 1/20; see this note; cum 1.075 million bbls 5/22;
- 16125, 199, Denbury Onshore, CHSU 11B-29SH 26, Cedar Hills, South Red River B, t8/06; cum 582K 1/20; cum 605K 5/22;
- 16126, 605, Denbury Onshore, CHUS 33C-5SH 15, Cedar Hills, South Red River B, t8/06; cum 853K 1/20; cum 885K 5/22;
- 16127, 362, Denbury Onshore, CHSU 33C-5NH 15, Cedar Hills, South Red River B, t8/06; cum 790K 1/20; cum 822K 5/22;
- 16149, 410, Denbury Onshore, CHUS 44D-29NH 26, Cedar Hills, South Red River B, t5/06; cum 629K 1/20; cum 648K 5/22;
- 16150, 316, Denbury Onshore, CHUS 44C-29SH 26, Cedar Hills, South Red River B, t5/06; cum 803K 1/20; cum 830K 5/22;
- 16151, 551, Denbury Onshore, CHUS 24C-29NH 26, Cedar Hills, South Red River B, t8/06; cum 670K 1/20; cum 703K 5/22;
- 16152, 37, Denbury Onshore, CHUS 24C-29SH 26, Cedar Hills, South Red River B, t8/06; cum 630K 1/20; cum 661K 5/22;
- 16155, 120, Denbury Onshore, CHUS 41D-32NH 26, Cedar Hills, South Red River B, t7/06; cum 684K 1/20; cum 713K 5/22;
- 16156, 231, Denbury Onshore, CHUS 41D-32SH 26, Cedar Hills, South Red River B, t5/06; cum 548K 1/20; cum 570K 5/22;
- 16242, 405, Denbury Onshore/BR, CHSU 11C-5NH 05, t8/06; Cedar Hills, cum 1.012623 million bbls 1/20; ccum 1.04 million bbls 5/22;
- 16916, 385, CLR, JWT 11-34SH, Cedar Hills, North Red River B, t4/08; cum 564K 1/20; still producing 5,000 bbls of oil per month; no decline whatsoever; cum 585K 5/22;
- 16699, 277, CLR, Jones 11-33NH, Cedar Hills, North Red River B, t11/07; cum 555K 1/20; cum 597K 5/22;
- 16820, 382, CLR, Evelyn 31-25NH, Cedar Hills, North Red River B, t5/08; cum 486K 1/20; cum 543K 5/22;
- 16821, 283, CLR, Sharon 44-28SH, Cedar Hills, t2/08; cum 582K 1/20; cum 657K 5/22; cum 674K 2/23;
- Several incredible CLR Red River wells in Medicine Pole Hills, southwest corner of the state;
Spearfish
- 1645, A/30, Cobra/Enduro Operating, Newburg-Spearfish-Charles Unit Q-715, Spearfish/Charles pool, t11/57; cum 1.14 million bbls 3/17; still producing about 150 bbls/month
- 1655, 20, Cobra/Enduro Operating, Newburg-Spearfish-Charles Unit Q-711, t1/58; cum 822K 4/19; cum 824K 5/22;
- 1853, IA/31, Cobra/Enduro, Newburg-Spearfish-Charles Unit H-718, Newburg, t5/58; cum 521K 3/17;
- 1864, IA/25, Cobra/Enduro, Newburg-Spearfish-Charles Unit N-716, Newburg, t6/58; cum 809K 10/19;
- 1877, 25, Cobra/Enduro, Newburg-Spearfish-Charles Unit O-709, Newburg, t6/58; cum 632K 8/16;
- 1940, 132, Cobra/Enduro, Newburg-Spearfish-Charles Unit S-715, Newburg, t8/58; cum 114K 8/16;
- 1941, 66, Cobra/Enduro, Newburg-Spearfish-Charles Unit O-717, Newburg, t7/58; cum 624K 8//16;
- 1943, AB/52, Cobra/Enduro, Newburg-Spearfish-Charles Unit R-7101, Newburg, t7/58; cum 531K 10/00
- 1954, 33, Denbury Onshore, Croak A 1, South Westhope, t8/58; cum 518K 8/16;
- 1985, 123, Cobra/Enduro, Newburg-Spearfish-Charles Unit T-712, Newburg, t10/58; cum 661K 12/01;
- 13447, 419, ConocoPhilips, Dickinson-Lodgepole Unit 74, Dickinson, t2/93; F; cum 3.215588 million 8/19; cum 3.32 million bbls 5/22; see this note; cum 3.431003 million bbls 8/24;
- 13724, 1,752, Scout Energy / Denbury, Ridl 11-1, Lodgepole, Eland; t3/95, cum 1.077969 million 8/19; cum 1.088 million bbls 5/22;
- 13745, 2,571, Scout Energy / Denbury, Klein 1-23, Lodgepole, Eland; t3/95, cum 4.531606 million 8/19; cum 4.61 million bbls 5/22; cum 4.659141 million bbls 8/24;
- 13755, 2,016, Scout Energy / Denbury, Ranchos 1, Lodgepole, Eland; s3/95, t5/95, cum 4.860827 million 8/19; cum 4.9 million bbs 5/22; 4.900254 million bbls 8/24;
- 13773, 2,908, Scout Energy / Denbury Onshore, Privratsky 12-2, a Lodgepole well, Eland, t5/95; cum 812K 3/21; cum 821K 5/22; cum 849K 4/26;
- 13788, 398, Scout Energy / Debury Onshore, Patterson Lake 41-13, Eland, t4/96; cum 1.313216 million 8/19;
- 13790, 1,229, Scout Enegy Management/COP, Kadrmas 36 1, Lodgepole, West Dickinson, t7/96; F; cum 3.795399 million 8/19; cum 3.85 million bbls 5/22; cum 3.92 million bbls 4/26;
- 13819, A (noted 7/24/2022)/IA/279, Scout Energy Management/Denbury, Privratsky 12A-3, Lodgepole, Eland; t10/95, cum 2.29474 million 5/18; last produced 6/03;
- 13886, 1,214, Scout Energy/Denbury, Roller 1-24, Lodgepole, Eland, s11/95, t12/95, cum 2.376889 million 8/19; 2.41 million bbls 5/22;
- 14209, 5,106, Scout Energy/Denbury, Dinsdale 1-3, Lodgepole, Stadium, s12/96, t2/97, cum 4.021159 million bbls 3/21; 4.053910 million bbls 5/22; 4.111455 million bbls 8/24;
- 14212, 4,331, Scout Energy/Denbury, Heart River 1-4, Lodgepole, Stadium, t11/96, cum 2.215332 million 8/19; it looks like this well is on its last legs; cum 2.242130 million bbls 5/22; cum 2.259318 million bbls 8/24;
- 14213, 3,357, Scout Energy/Denbury, Dinsdale 2-4, Lodgepole, Stadium, t12/96, cum 4.965561 million 8/19; 5 million bbls 5/22; cum 5.000034 million bbls 8/24;
- 14307, 876, Scout Energy/Denbury, HR 1-9, Lodgepole, Stadium, t3/97; cum 1.492071 million 8/19; came off line 3/19; nothing going on in the area according to the NDIC map; no recent sundry form; back on line as of 4/19; 1.56 million bbls 5/22; cum 1.603774 million bbls 8/24;
- 18190, 463, Armstrong Operating, Laurine Engel 1, Patterson Lake, t9/09; F; cum 882K 10/19; cum 918K 5/22; cum 941K 8/24;
- 18496, 474, Armstrong Operating, Gruman 18-3, Patterson Lake, t3/10; F; cum 971K 1/20; still producing upwards of 4,000 bbls of oil per month; 1/20; cum 1.081476 million bbls 8/24;
- 1304, 1,224/PA, TXO Production, Lucy Fritz 1, Rocky Ridge, t1/57; cum 1.05 million 5/83;
- 3700, PA/204, C12 Energy: North Dakota LLC/Cline, Dickinson-Heath-Sand Unit 20, Heath, Dickinson, t11/64; cum 510K 3/20;
- 3939, PA/264, Scout Energy, Medora Heath-Madison Unit 06, NWSE 12-139-102, Medora oil field (Billings County); last produced, 6/05; t12/65; cum 1.474999 million bbls (Heath) and 116,193 bbls Madison; approved for re-entry, 10/24.
- 4326, 245, C12 Energy: North Dakota LLC/Cline, Dickinson-Heath-Sand Unit 10, Heath, Dickinson, t10/67, cum 760K 11/18;
- 4345, 382, C12 Energy: North Dakota LLC/Cline, Dickinson-Heath-Sand Unit 17, Heath, Dickinson, t12/67; cum 793K 11/18;
- 4353, 115/PA, Conoco, D-H-S Unit 42, Heath, Dickinson, t12/67; cum 1 million 11/11;
- 4437, 32, C12 Energy: North Dakota LLC/Cline, Dickinson-Heath-Sand Unit 18, Heath, Dickinson, s7/68, t9/68, 467K 8/16;
- 4653, PA/90, C12 Energy: North Dakota LLC/Cline, Dickinson-Heath-Sand Unit 13, Heath, Dickinson, t6/69; cum 1.0 mill 11/11
- 4762, 205, C12 Energy: North Dakota LLC/Cline, Dickinson-Heath-Sand Unit 04, Heath, Dickinson, t10/69; cum 886K 11/18;
- 4770, 336, Cline, D-H-S Unit 38, Heath, Dickinson, s9/69, t10/69; cum 1.48 million 9/16;
- 4971, 422/AB, Howie 11X2, Rocky Ridge, Heath, t1/71; cum 782K 8/14;
- 4831, 663, Cline, Dickinson-heath-Sand Unit 06, Heath, Dickinson, t1/70; cum 1.83 mill 7/15;
- 4842, 48/PNA, Conoco, D-H-S Unit 12, Heath, Dickinson, s12/69, t2/70; cum 416K 11/11
- 4905, 188/PA, Cline, Dickinson-Heath-Sand Unit 02, Heath, Dickinson, t6/70; cum 364K 11/11
- 5500, 378/PNA, South Heart Company, George 1-29, t12/74; cum 487K 11/91;
- 7230, 347, Whiting, Kostelecky 1-29, t11/79; cum 697K 11/18;
- 7995, 76, Encore, Beatric Ridl 13-13, Tyler, Dickinson, t5/81; cum 246K 11/18;
- 8527, 257/PA, Omimex, Fritz A 1-R, Rocky Ridge, Heath, t6/71; 42 years; cum 712K 6/14;
- 9869, PA/20, JN Exploration, Privratsky 1, a Heath well, t11/82; cum 614K bbls 6/98;
- 9706, 571, New Millennium Resources (orig CENEX), Decker 1-32, Bell field, Tyler, t8/82, 829K 4/21; spudded 1982; 37 years of production;
- 9759, 779, Scout Energy / Cline, Dickinson-Heath-Sand Unit 64, Heath, Dickinson, s11/82, t12/82; cum 809K 4/21; went off line as of middle 1/19; back on line 6/19; not much production after coming back on line;
Winnepegosis
- 10073, PA/1,265/IAW, Sequel Energy,Skarderud 10-7, Winnipegosis (also targeted the Red River and the Duperow); t8/83; cum 1.4 million bbls 3/17; still producing after almost 30 years;
- 10480, PA/455/AB, Sequel Energy, Skarderud 22-7, Winnipegosis; t2/84; cum 610K 5/13; A, but on-line one day/month;
- 11450, PA/312/IA/AB, Cobra/Enduro Operating/Sequel Energy, Skarderud 33-7, Winnipegosis; Temple; t7/85; cum 506K 1/13; taken off-line late last year;
Bakken Pool: multi-well pads
- 20210, 803, CLR, Whitman 2-34H, Oakdale, Bakken, s1/11; t9/11; cum 1.834725 million bbls 7/25; 24 stages; 2.4 million lbs; middle Bakken; runs south; 4-section spacing; one well on an Eco-Pad; 12K/month as of 5/16; off-line as of 8/16; see this post; back on line 8/18; producing 10K/month as of 5/19; off line as of 4/22; cum 1.789484 million bbls 3/22; cum 1.802786 million bbls; cum 1.834725 million bbls 7/25;
- Whiting's Skaar Federal wells in Twin Valley;
- Dozens of "monster wells" in the Sanish oil field;
- 95% of the Wayzetta wells in the Parshall oil field would make the monster well list; (Wayzetta wells might not be posted below)
- The Austin wells in Parshall oil field: mostly short laterals; after five years production, still producing 3,000 to 5,000 bbls per month; Parshall oil wells drilled in 2006 / 2007
- EOG's Riverview wells in Clarks Creek
- Kennedy-Miles drilling unit in Dimmick Lake
- 1779, PA/301, P & P Producing, Harvey Hopkins A 3, t5/58; cum 1.123 million bbls 11/87; a vertical well; Spanish/Antelope;
- ****16059, 729, Petro-Hunt, USA 2D-3-1H, Charlson field, t10/06; cum 1.870044 million bbls 10/21; still producing 6,000 bbls/month, 11/19; update at this post; off line 5/20; remains off line 6/20; two days in 7/20; to be lengthened; confidential noted 11/20; still confidential but now producing again after being lengthened; update here; update here; cum 1.870044 million bbls 10/21; re-entry; cum 1.945212 million bbls 5/22; cum 1.966330 million bbls 10/22; cum 1.980221 6/23; cum 2.000011 1/24; hits 2 million bbls crude oil cumulative; 2.005 million bbls 4/24; cum 2.014984 million bbls 9/24; cum 2.020875 million bbls 11/24;
- ****16424, 700, Petro-Hunt, USA 11B-2-2H, Charlson, t7/07; cum 673K 4/20; off line 5/20; remains off line 12/20; two days in 7/20; significant decline beginning 4/20; cum 805K 10/21; see this post; cum 1.002055 million bbls 5/22; see recent production here; cum 1.105512 million bbls 10/22; producing 20,000 bbls/month; see this update; cum 1.191588 6/23; 1.269 million bbls 4/24; cum 1.296699 million bbls 9/24; cum 1.311227 million bbls 11/24;
- 16457, 922, EOG, C & B 1-31H, Parshall, t5/07; cum 471K 11/20; went inactive 1/15; active as of 10/15; needs to be re-fracked (1/19); still only 150 bbls/month 7/19; offline 3/20; 31 days in 7/20 but very little production; remains off line 8/21; remains off line 5/22; back on line 6/22; cum 476K 1/24; cum 477K 3/24; cum 478K 11/24;
- 16461, 1,487, EOG, Patten 1-02H, Parshall, t3/07; cum 551K 12/20; offline 4/20; back on line, 6/20; cum 558K 9/21; off line much of 10/21; cum 559K 5/22; cum 574K 1/24;
- 16469, A/AB/IA/1,267, EOG, Herbert 1-26H, Parshall, t12/07; cum 583K 3/20; only 2 bbls of oil in 3/20; off line, 3/20; remains off line 12/20; remains off line 9/21; back on line 4/22; but not remarkable; cum 585K 5/22; cum 588K 1/24;
- 16483, A/IA/870, EOG, Zacher 1-24H, Parshall, t6/07; cum 628K 12/20; off line 5/20; back on line 7/20; off line 2/21; remains off line 8/21; back on line, 9/21; cum 629K 10/21; offline 1/23; remains off line 3/24; back on line; cum 632K 8/24;
- *****16484, A/AB/IA/1,670, EOG, Wenco 1-30H, Parshall, t9/07; cum 497K 10/20; -- needs to be re-fracked; went off line 1/20; back on ine 2/20; small production; off line 11/20; remains off line 9/21; back on line 8/22; very little production; cum 499K 1/24; cum 500K 11/24;
- 16497, A/AB/IA/1,675, EOG, Hoff 1-10H, Parshall t6/07; cum 488K 3/20; -- needs to be re-fracked; went off line 1/20; remains off line 9/21; back on line 8/22; cum 489K 2/23; off line again, 6/24; cum 491K 11/24
- 16532, PA/TA/1,285, EOG, N&D 1-05H, Parshall, t7/07; cum 472K 3/18; came off-line 10/17; TA noted 3/19;
- 16543, A/IA/1,015, EOG, Florence 1-04H, Parshall, t7/07; cum 540K 10/21; only 11 days, 4/20; cum 547K 1/24;
- 16577, A/IA/571, EOG, Alan 1-06H, Parshall, t1/08; cum 608K 10/21; cum 609K 3/22; cum 617K 1/24;
- 16578, A/AB/IA/817, EOG, Risan 1-34H, Parshall, t9/07; cum 477K 3/19 -- needs to be re-fracked; went off line 3/19; remains off line 4/20; back on line 9/22; cum 479K 10/22; cum 496K 11/24;
- 16780, 2,247, Whiting, Liffrig 11-27H, Sanish, t1/08; cum 683K 12/20; cum 695K 10/21; went off line 7/21 (did not go off line); see this note; cum 700K 5/22; cum 725K 1/24; 740K 2/25;
- 16845, 1,418, Slawson, Pathfinder 1-9H, t7/08; cum 635K 7/19; remains off line 4/20; back on line 4/21; see this note; cum 644K 10/21; cum 652K 5/22; cum 675K 1/24;
- 16902, 2,192, Whiting, Lacey 11-1H, Sanish, t7/08; cum 521K 12/20; one of the few wells that did not go off line, 5/20; just went off line 7/21; cum 522K 6/21; see this post; off line 8/21; remains off line 10/21; cum 540K 5/22; cum 586K 3/24;
- 16930, 1,407, Murex, Rick Clair 25-36H, Stanley, t3/08; cum 600K 10/21; 639K 2/25;
- 16961, 1,064, EOG, Wayzetta 8-11H, Parshall, cum 605K 6/20; off line 5/20; returns, 6/20; off line 7/20; remains off line 11/20; cum 611K 8/21; minimal production 8/21 - 9/21; off line 4/22; cum 613K 10/22; cum 618K 8/24;
- ****16963, 423, Petro-Hunt, USA 35D-1-1H, Charlson, t12/08; cum 812K 12/20; off line as of 7/19; remains off line 1/20; back on line 3/20; see this post; recent production here; big jump in production 3/20; off li1e 1/21; huge production jump, 3/21; another great month of production; cum 890K 9/21; cum 926K 5/22; cum 948K 10/22; cum 996K 1/24; see this post; cum 1.003557 million bbls, 4/24;
- 16965, 1,109, EOG, Hauge 1-01H, Parshall, a short lateral t6/09; cum 605K 12/20; off line 5/20; returned to production, 6/20; off line 1/21; back on line, 3/21; cum 611K 9/21; cum 615K 5/22; cum 622K 3/24;
- 16977, AI/AB/2,625, Whiting, Lee State 44-16H, Parshall, t5/08; cum 623K 12/20; 624K 6/21; see this post; cum 625K 9/21; cum 625K 5/22; was off line 9/21; came back on line 5/22; struggling; last production, 1/23; cum 626K 1/23; off line since 1/23; remains off line 11/24;
- 16991, A/AB/IA/1,383, EOG, Wayzetta 9-03H, Parshall
field; short lateral, s4/08; producing 5,000 bbls 1/13; inactive since 5/13; back on status 7/13; no production since 11/13; back on status as of 6/14; t7/08; cum 834K 12/20; only 4 days in 5/16; 0 days in 6/16; full months beginning in 8/16; candidate for re-frack based on current production (4/18); pretty much off-line since 4/18; struggling; back to steady, but low, production as of 2018; cum 835K 6/21; went off line 7/21; remains off line, 9/21; remains off line 5/22; back on line; cum 837K 1/24; cum 837K 3/24;
- 16997, IA/AB/IA/1,520, EOG, Van Hook 1-13H, t6/08; cum 608K 3/20; placed on inactive status in 4/13; appears to be pumping again in 7/13; producing as of 7/13; again, off-line, 10/14; again, off-line as of 11/14; back on status as of 9/15; only 14 days over two months, 5/16 and 6/16; only 17 days 11/16; candidate for a re-frack, 4/18 based on low production; only 22 days, 4/20; remains off line 12/20; remains off line 8/21; remains off line 5/22; still off line 1/24; still off line 11/24; cum 608K 4/20; back on line; producing almost nothing;
- 17023, A/IA/2,669, Whiting, Braaflat 11-11H, t5/08; cum 834K 2/21; huge bump in production without explanation back in 2012; just went off line; see this post; cum 843K 9/21; went off line 2/22; cum 848K 1/22; cum 858K 5/08; cum 861K 3/24; 870K 2/25
- 17028, A/IA/2,207, EOG, Wayzetta 14-02H, Parshall, t10/08; cum 669K 11/20; only five days in 11/18; full month as of 12/18; subtle jump in production, 1/20; off line 12/20; back on line 10/21; off line; cum 676K 10/23; cum 676K 3/24;
- 17030, 1,967, EOG, Skaar 7-10H, Parshall, t6/08; cum 850K 12/20; slight bump in production after neighboring well fracked; cum 854K 9/21; offline for one month, 2/23; cum 859K 1/23; cum 861K 1/24;
- 17032, 1,934, Whiting, Litttlefield 11-29H, Sanish, t7/08; cum 473K 12/20; cum 481K 9/21; cum 507K 11/24;
- *******17035, A/A/IA/2,016, Whiting, Kannianen 11-4H, Sanish, t8/08; cum 897K 9/21; interesting production profile; see this note; cum 900K 2/22; off line; back on line, cum 907K 1/24; cum 908K 3/24; cum 910K 8/24; cum 913K 7/25;
- 17061, AB/664, CLR, Whitman 11-34H, Oakdale, t6/08; cum 498K 12/20; returned to production, 7/20; cum 504K 9/21; cum 586K 10/22; huge jump in production; see this post; cum 587K 3/24;
- 17072, 2,843, Whiting, Stenseth Trust 11-5H, Sanish, t7/08; cum 755K 2/21; off line as of 8/19; remains off line 10/19; neighboring wells have been fracked; back on line as of 11/19; cum 775K 9/21; see this note; cum 816K 2/25;
- 17080, 2,096, Whiting, Niemi 44-22H, Sanish, t10/09; cum 551K 12/20; cum 563K 9/21; see this note; off line since 2/22, not back on line, 6/25; small production;
- 17081, 3,311, Whiting, Kinnoin 11-14H, Sanish, t10/08; cum 792K 12/20; cum 798K 6/21; see this post; went off line 6/21; remains off line 8/21; back on line 8/22; cum 810K 2/23; cum 823K 3/24;
- 17086, AB/560, Grayson Mill/Ovintive/Newfield, Jorgenson 1-15H, t11/08; cum 357K 10/20; off line as of 3/18; remains off line 5/19; just came back on line 7/19; off line again, 11/20; back on line 5/21; cum 363K 9/21; struggling; cum 372K 8/24; off line;
- 17092, AB/3,027, Whiting, Behr 11-34H, Sanish; s4/08; produced 500,725 bbls in 591 days; inactive Jan/Feb 2015; now back on status 3/15; cum 1.118594 million bbls 11/20; off line as of 7/19; remains off line 1/20; back on line 3/20; cum 1.128761 million bbls 9/21; see this post; 3/22; cum 1.134137 million bbls;
- *****17113, 3,030, XTO/Denbury, Charlson Federal 14X-35H, Charlson, t10/08; cum 882K 3/21; F; subtle jump in production; cum 890K 6/21; still F; cum 891K 9/21; still F; cum 921K 10/22; F; 933K 6/23; cum 951K 1/24; see this post; cum 956K 3/24; still F; cum 875K 11/24; F; cum 898K 7/25; huge one time jump in production 11/25; cum 1.03 million bbls 4/26;
- 17120, 2,051, EOG, Austin 10-34H, t8/08; cum 1.065342 11/20; inactive as of 4/16; active as of 7/16; bump in production late 2016 for no apparent reason; see update here; still producing 3,000 bbls/month (12/18); producing 3,000 bbls/month (2/21); cum 1.087020 million bbls 9/21; only nine days in 9/21; cum 1.150132 million bbls; coming off line 4/25;
- **********17122, 581, EOG, Austin 23-32H, t8/09; cum 694K 11/20; off line as of 8/18; back on line as of 10/18 with a little bit of a jump in production; off line 5/20; returned to production, 6/20; cum 705K 9/21; cum 730K 7/24; off line; back on line; cum 734K 12/24; cum 741K 4/25;
- **********17127, 1,714, EOG, Wayzetta 11-08H, t11/08; cum 793K 2/21; off line 5/20; returned to production, 6/20; cum 798K 9/21; cum 823K 2/23; cum 865K 10/24; recent small jump in production; cum 868K 11/24; cum 875K 4/25;
- 17158, 4,184, Whiting, Richardson
Federal 11-9H, Sanish, t10/08; F; cum 995K 10/21; see this post; cum 1.000125 million bbls 6/22; just came off line 7/22; cum 1.002338 6/23; update here; cum 1.015069K 3/24;
- 17147, 2,101, XTO, HBU Boucher 41X-21, Hofflund, t4/09; F; cum 992K 10/21; jump in production; cum 1.030890 million bbls 19/22; see this note; huge well; cum 1.051301 million bbls 2/23;
- 17152, 937, EOG, Wazyetta 15-05H, Parshall, t7/09; cum 675K 11/20; -- needs to be refracked; off line 5/20; back on line 7/20; but lousy production; cum 676K 8/21; off line 8/21; some production, 9/21; off line, struggling, 7/22; continues to struggle; cum 678K 10/24; still struggling; 7/25;
- 17222, 1,769, EOG, Austin 18-21H, Parshall, t9/08; cum 1.010488 million bbls 11/20; inactive as of 2/16; back on status as of 6/16; off line 5/20; back on line 7/20; see this post; cum 1.024526 million bbls 9/21; steady but low production, cum 1.040969 million bbls 10/24;
- 17263, 3,124, Chandler James 25-36H, s7/08, produced 500,234 bbls in 484 days; still producing 2,000 bbls/month; t10/08; cum 1.179732 million bbls 11/20; cum 1.199738 million bbls 8/21; nice production; cm 1.242709 million bbls 10/24;
- *****17280, A, EOG, Van Hook 5-11H, s10/08; cum 670K 11/20; 3 stages; 500K sand; see this post; off line 4/20; remains off line 2/21; back on line, 3/21; cum 676K 9/21; cum 687K 2/24; off line for over a year; came back on line 6/25;
- 17287, 1,137, EOG, Austin 22-31H, Parshall, t10/08, off-line? only 1 - 5 days for the past three months (8/15 - 11/15); full months as of 12/15; cum 915K 3/20; needs to be re-fracked; off line 4/20; remains off line 2/21; back on 3/21; cum 917K 8/21; off line 6/21; remains off line 9/21; back on line; cum 924K 10/22; cum 925K 2/23; low production; cum 927K 10/24;
- 17303, 1,676, Slawson, Whitmore 1-6H, Parshall, single section, t8/08; cum 544K 11/20; see this note; off line 4/20; back on line 9/20; cum 552K 9/21; cum 569K 10/24;
- 17354, 2,205, Slawson, Whitmore 1-7H, Parshall, t10/08; cum 686K 4/20; off-line as of 8/18; see this post; back on line as of 12/18; off line 2/21; back on line, F, cum 698K 9/21; see this post; cum 698K 9/21; cum 735K 3/24; still, F; cum 738K 10/24;
- 17379, AB/1,971, Hunt, Karbowski 1-22H, Parshall, t3/09; cum 567K 3/21; cum 570K 9/21; struggling, 6/22;
- 17391, A/IA/2,400, Whiting, Littlefield 11-7H, Sanish, t9/08; cum 751K 3/21; cum 757K 9/21; see this post; off line 7/22; cum 777K 10/24; cum 778K 12/24;
- 17478, 238, EOG, Wayzetta 20-17H, Parshall, t9/09; cum 489K 4/20; only sixteen days, 4/20; off line 5/20; remains off line 11/20; back on line 4/21; cum 490K 5/21; see this post; cum 493K 9/21; cum 505K 10/22; cum 525K 10/24;
- 17510, 2,027, Windsor, Weflen 1-4H, Parshall, t7/09; cum 750K 11/20; needs to be re-fracked; cum 761K 9/21; cum 792K 10/24; small but significant jump in production 10/24; a workover?
- 17575, 3,260, Whiting, Niemitalo 11-35H, Sanish, t2/09; cum 696K 11/20; off line as of 7/19; remains off line, 10/19; back on line 11/19; see this post; cum 708K 9/21; cum 724K 10/24;
- 17612, A/AB/IA/4,345, Whiting, Maki 11-27H, Sanish, t10/09; cum 882K 11/19; off line 12/19; remains off line 12/20; remains off line 10/22; cum 886K 2/23; cum 906K 10/24; cum 910K 7/25;
- 17613, 690, EOG, Van Hook 2-24H, Van Hook, t7/09; cum 583K 11/20; finally returned to production, 7/21; cum 584K 9/21;
- 17614, 1,595, EOG, Austin 20-29H, Parshall, t9/09; cum 854K 11/20; off line as of 5/18; back on line as of 11/18; see this post; off line 5/20; back on line 6/20; cum 864K 9/21; see this note;
- 17619, AB/A/IA/1,571, EOG, Van Hook 6-14H, Van Hook, t12/08; cum 669K 11/20; only nine days, 4/20; off line 5/21; remains off line 9/21;
- 17700, A/IA/3,405, Whiting, Rigel State 11-16H, Sanish, t4/09; cum 670K 11/20; cum 679K 9/21; see this post; cum 725K 4/25;
- 17872, IA/1,814, WLL, Littlefield 12-34H, Sanish, 18 stages; 2.3 million lbs, t5/10; cum 720K 12/19; offline for 2.5 months in early 2015; intermittent production as of 12/19; remains off line 5/201; back on line 6/21; but very little production; back on line 6/21; cum 725K 9/21;
- 17907, IA/2,138, Whiting, Patten 44-3H, Sanish, t3/10; cum 732K 11/20; cum 741K 9/21; see this post; off line 7/22;
- 17912, 2,581, Whiting, Sorenson 11-3H, Sanish, t2/10; cum 892K 11/20; went off line as of 4/19; remains off line 10/19; back on line 11/19; cum 910K 9/21; see this post; back on line; cum 925K 2/23; cum 929K 1/24; cum 931K 12/24; cum 934K 4/26;
- 17917, 1,782, Whiting, Olson Federal 42-8H, Sanish, t5/10; cum 628K 11/20; cum 633K 9/21; off line 7/22;
- 18040, A/IA/993, MRO, Arvid Bangen USA 31-18H, t8/10; cum 689K 1/21; huge jump in production; see this post; off line 5/20; off line 2/21; remains off line 8/21; back on line 6/22;
- *** 18077, A/AB/IA/1,773, Whiting, Kannianen 11-5H, t9/09; cum 497K 2/21; cum 500K 6/21; cum 501K 8/21; off line since 9/21; back on line 6/25;
- 18104, 1,113, Hess, BB-State A-151-95-1615H-1, Blue Buttes, t11/09; cum 501K 11/20; off line most of 4/19; remains off line 12/19; intermittent, small production 10/19; struggling? remains off line 1/20 -- now listed as IA; back on line as of 4/20; back on line 5/20; recent production here; cum 518K 6/21; off line 7/21; remains off line 9/21; back on line 11/21; jump in production; see this note;
- 18109, 2,409, Whiting, Tollefson 44-10H, Sanish, t9/09; cum 683K 11/20; off line as of 5/19; remains off line 10/19; back on line 11/19; cum 688K 6/21; cum 690K 9/21; off line 9/22; back on line, 700K 12/24;
- 18159, 754, CLR, Rollefstad 1-3H, Antelope, t9/09; cum 595K 11/20; was off line 6/19; came back on line 7/19; off line 5/20; back on line 10/20; cum 620K 9/21; cum 726K 4/25;
- 18171, A/IA/572, EOG, Lucille 22-06H, Parshall, t9/09, cum 782K 11/20; off line 5/20; back on line 6/20; cum 789K 9/21; off line 8/22; back on line; cum 807K 12/24; cum 810K 4/25;
- ***18193, PA/TA/1,666, Lime Rock Resources/OXY USA, Martin 34-31H, t10/09; cum 320K 3/15; not much production since May, 2014; is off-line; inactive; a sundry form dated 3/31/14 says that 12.28 tons of contaminated soil was removed; another well is being added to the pad; the existing tank battery and berm will be removed to ensure adequate cleanup and a new lined dike will be installed to accommodate the dual well pad; nothing since 9/14; TA as of 6/16; the new well on this pad is #28037, Lime Rock Resources, Martin 6-31-30H-144-96, t6/14; cum 104K 11/19 API: 33-025-02505; it was fracked 6/10-12/14;
- 18200, 1,658, Whiting/Kraken/Kaiser-Francis/Fidelity, Kinnoin 24-13H,
Sanish field, t9/10; cum 718K 11/20; off line as of 8/18; back on line as of 10/18; off line as of 12/19;back on line 1/20 -- for three days; minimal production; nice production as of 3/20; cum 734K 5/21; cum 750K 9/21; cum 837K 12/24;
- 18209, 1,380, Murex, Thomas Patrick 1-12H, Sanish, t11/09; cum 665K 11/20; cum 681K 9/21; cum 755K 4/25;
- 18213, 3,308, Whiting, Platt 44-28H, Sanish, t12/09; cum 577K 11/20; cum 581K 6/21; off line 7/21; remains off line 9/21; back on line 9/22; see this note;
- 18224, 1,099, CLR, Hendrickson 1-36H, t12/09; cum 768K 11/20; had a huge jump in 2018; off line 10/19; remains off line 1/20; back on line 4/20; only six days, 5/20; cum 789K 9/21; cum 842K 12/24;
- 18275, 1,020, CLR, Hawkinson 1-22H, t2/10; cum 730K 11/20; off line 5/20; back on line 7/20; cum 739K 9/21; cum 753K 2/23;
- 18278, 2,894, Whiting, Rigel State 12-16H, t1/10; cum 652K 11/20; cum 666K 9/21; just went off line; remains off line 10/22; back on line; cum 716K 12/24;
- 18298, 3,422, Whiting, Kannianen 44-33H, Sanish, t1/10; cum 712K 11/20; off line as of 4/19; remains off line 1/20; back on line 4/20; cum 721K 9/21; off line 3/22; remains off line 10/22;
- 18309, 1,306, Slawson, Banshee 2-1H, t12/09; cum 536K 11/20; only one day, 4/20; five days, 5/20; cum 543K 9/21; off line 4/22; back on line, 10/22; cum 548K 10/22;
- 18341, 567, Enerplus/Bruin/HRC, Fort Berthold 147-94-1A-12-1H, t10/11; cum 670K 4/20; recently off-line, 8/18; back on line, 11/18; only two days, 4/20; off line 5/20; back on line 9/20; cum 686K 9/21; cum 692K 10/22;
- 18408, PA/AB/TA/1,945, Amber Renee 25-36H, Sanish; one mile to the west of the Chandler James; t2/10; F ; 822K 8/14 -- 661K in about two years; no pump; still 9K/month 1/13; IA 1/14; still inactive 10/15; the most recent sundry form shows this well is scheduled for a "re-drill"; TA as of 3/16; cum 822K 3/16; no change since 9/18;
- 18409, 2,404, Whiting, Kinnoin 21-14H, Sanish, t3/10; cum 645K 2/21; cum 649K 6/21; off line 7/21; cum 653K 10/22;
- 18424, 2,409, Lime Rock Resources/OXY USA/Anschutz, Kenneth Stroh 1-12-1H-143-97; t9/10; cum 679K 9/21; cum 694K 10/22;
- 18481, 2,672, Whiting, Niemitalo 12-35H, Sanish, t5/10; cum 628K 2/21; off line since 7/19; back on line 11/19; cum 648K 9/21; cum 675K 10/22;
- 18504, A/IA/2,195, EOG, Van Hook 7-23H, Van Hook, t5/10; cum 614K 9/21; off line 6/22; remains off line 10/22; back on line; cum 625K 4/25;
- 18507, IA/AB/IA/1,946, WLL, Lahti 24-22H, Sanish, Bakken, t6/10; cum 570K 4/20; off line 3/20; back on line 11/21 for four months; off line 4/22; remains off line 10/22;
- 18549, 1,114, Whiting, Littlefield 21-7H, Sanish, t7/10; cum 661K 9/21; off line for summer months, 2022; cum 671K 10/22;
- 18610, 877, Lime Rock Resources/OXY USA, Harry Stroh 1-8-5H-143-96, Fayette, t10/11; cum 589K 8/21; only 22 days, 4/20; cum 590K 9/21; cum 598K 10/22; 614K 2/25;
- 18635, 2,591, WLL, Littlefield 21-12H, Sanish, Bakken, t8/10; cum 619K 3/21; production slowed to less than 5 days/month since 9/19; nice production in 2020; cum 628K 9/21; off line 5/22;
- 18711, A/IA/4,126, WLL, Fladeland 12-10H, Sanish, Bakken, t7/10; cum 510K 10/19; recently off line; back on line 7/19; off line 11/19; remains off line 2/20; back on line 12/20; cum 519K 9/21; cum 534K 10/22;
- 18735, 1,936, WPX, State of ND 10-3H, Van Hook, t4/11; cum 633K 9/21; cum 654K 10/22;
- 18825, 951, EOG, Van Hook 8-36H, Van Hook, t7/10; cum 642K 3/21; only 23 days, 4/20; remains off line 5/20; back online 9/20; cum 647K 9/21; off line during spring of 2022; cum 651K 10/22; cum 656K 3/24;
- 18859, 680, CLR, Carson Peak 3-35H, Oakdale, Bakken, t5/11; cum 836K 3/21; huge jump in production, 4/19; stand-alone post here; only 7 days, 2/21; cum 854K 9/21; cum 886K 10/22;
- 18861, 759, CLR, Carson Peak 2-35H, Oakdale, Bakken; t5/11 cum 738K 3/21; off line as of 10/18; still offline, 10/19; back on line 11/19; nice production; off line, 5/20; back on line 7/20; off line 1/21; intermitten production, on line 5/21; cum 741K 9/21; cum 745K 10/22;
- 18876, 3,023, Whiting, Rohde 14-6XH, Sanish, t8/10; cum 523K 9/21; off line 5/22;
- 18896, A/IA/4,438, Grayson Mill/Equinor/BEXP, Clifford Bakke 26-35 1H, Alger, t10/10; cum 614K 9/21; off linnee as of 1/22; cum 638K 3/24;
- 18922, 472, WPX, Skunk Creek 1-12H, South Fork, t6/11; cum 625K 3/21; off line 11/18; back on line 2/19; jump in production; off line 1/20; back on line for three months; off line 5/20; cum 632K 9/21; cum 646K 10/22;
- 18924, 1,361, Slawson, Vixen Federal 1-19-30H, t2/11; cum 574K 3/21; off line as of 9/18; back on line as of 9/19; only six days, 4/20; four days, 5/20; cum 589K 9/21; off line 5/22;
- 18943, 2,169, Whiting, Locken 14-9XH, Sanish, t10/10; cum 591K 9/21; off ine 4/20; remains off line 5/20; back on line 6/20; cum 591K 9/21; off line 6/22;
- 18970, 1,106, Slawson, Pike Federal 1-3-2H, Van Hook, t9/10; cum 544K 9/20; huge jump in production, 1/18; only seven days in 4/20; six days, 5/20; remains off line 11/20; back on line for 12 days, 3/21; cum 555K 9/21; cum 584K 10/22;
- 18973, AB/IA/2,579, Oasis/QEP, State 1-16/21H, Blue Buttes, t3/11; cum 691K 3/21; this well is tracked here; taken off-line 1/17 -- neighboring wells being fracked? back on-line 3/17; down to 500 bbls, 10/19; off lie 1/21; remains offline 9/21; remains off line 10/22;
- 18977, A/TA/AB/IAW/469, Hunt, Halliday 1-11-2H 1, Wolf Bay, t11/10; cum 544K 7/19; went off-line 8/18; back on line 12/18; off line as of 7/19; one day of minimal production 10/19; off line 3/21; one day minimal production 2/20; AB noted 3/21; TA noted 10/22;
- 19246, 1,425, WPX/Zenergy, Wells 32-29H/Dakota-3 Wells 32-29H, Reunion Bay, Bakken; t3/11; cum 617K 9/21; cum 625K 10/22; back on line; cum 562K 12/24;
- 19255, 718, Slawson, Muskrat Federal 1-28-33H, Van Hook, t1/11; cum 608K 3/21; off line 11/19; back on line; see this post; only six days in each 4/20 and 5/20; remains off line 9/21; cum 614K 9/21; off line much of 2021; back on line 2/22; a big well; cum 660K 10/22;
- 19285, 2,325, BR, Rising Sun 11-1MB-3NH, Clear Creek, t7/11; cum 341K 3/21; 4-section; 21 stages; 2.3 million lbs proppants (both on low end of
what is often seen in the Bakken); off line as of 11/19; remains off line 4/20; one day, 9/20, no longer IA; was off line for about a year; cum 361K 9/21; cum 384K 11/22;
- 19296, 2,388, SHD Oil & Gas, Golden 22-31H, Deep Water Creek Bay, 62 stages, 15 million lbs sand, spacing ICO, F-->AL (3/21), t3/15; cum 814K 3/21; a singleton; still producing 5,000 bbls 11/19; only fourteen days, 4/20; remains off line 8/20; back on line for 5 days, 9/20; comes back strong, 10/20; offline to install a pump; cum 828K 9/21; cum 874K 11/22;
- 19323, 2,521, Oasis/QEP/Helis, Thompson 1-29/32H, Grail, t8/11; cum 584K 3/21; back on status for five days 4/15; back on status since then; less than 30 days each month starting 11/15; looks like back to normal as of 4/16; at 1,500 bbls 9/18; down to 500 bbls, 10/19; off line 5/20; back on line 8/20; cum 586K 9/21; cum 587K 11/22;
- 19768, 261, WPX, Arikara 15-22HC, Reunion Bay, Bakken, t12/11; cum 725K 8/21; F; re-fracked 1/18; cum 727K 9/21; cum 749K 11/22; cum 769K 3/24; F; cum 780K 12/24;
- 19802, PA/AB/1,215, EOG, Liberty LR 18-14H, Van Hook, Bakken, t10/11; cum 394K 3/21; off line 5/20; back on line 6/20; off line 12/20; back on line 2/21; cum 398K 9/21; cum 402K 11/22;
- 19946, 1,474, Oasis, Spratley 5494 34-13H, Alkali Creek, Bakken, t11/11; cum 690K 3/21; huge jump in production, 2/18; only nine days, 4/20; only ten days, 5/20; cum 700K 9/21; cum 724K 11/22; 746K 3/24;
- 20088, 1,390, Enerplus/Bruin/HRC/Petro-Hunt, Fort Berthold 151-94-34C-27-1H, Sanish, s10/11; t1/12; cum 610K 8/21; but off line as of 10/19; back on line 11/19; cum 610K 9/21; cum 616K 11/22;
- 20170, 2,939, Grayson Mill/Newfield, Moberg Federal 149-95-29-32-2H, Bear Den, t5/12; cum 513K 3/21; a jump in production, 5/18; off line as of 8/19; remains off line 1/20; back on line 2/20; see this post; cum 522K 9/21; cum 534K 11/22; cum 536K 2/23; cum 550K 12/24;
- 20210, 803, CLR, Whitman 2-34H, Oakdale, Bakken, s1/11; t9/11; AL; cum 1.760230 million bbls 3/21; 24 stages; 2.4 million lbs;
middle Bakken; runs south; 4 section spacing; this is an incredible
well; still 19,000 bbls in October, 2015; off-line all of 8/16; back
on-line; sundry form says valve on LACT line was cracked open; small oil
spill; resolved; off-line as of 9/17; neighboring well in section was re-refracked; taken off line 12/18; back on line 2/19; jump in production to10K in 3/19; now at 5,000 bbls/month; 8/19; cum 1.78 million bbls 9/21; cum 1.796364 million bbls 11/22;
- 20342, 1,430, Petro-Hunt, USA 153-95-4B-9-1H, t11/11; Charlson; cum 1.168581 million bbls 3/21; 25 stages; 3.1 million lbs proppant; went IA 1/14; still inactive as of 6/14; back on line September, 2014; tracked here; off line as of 10/18; update here; also, here; on line as of 12/18; still producing 10,000 bbls/month; off line 5/20; cum 1.195451 million bbls 9/21;
- 20451, IA/3,502, Whiting, Nesheim 11-24XH, Sanish, Bakken, t7/11; cum 471K 6/21; back online 5/21; cum 473K 9/21; remains off line 2/25;
- 20505, 2,868, Whiting, Brown 41-28XH, Sanish, ICO, t3/12; cum 410K 2/20; needs to be re-fracked; off line 3/20; remains off line 3/21; back on line 6/21; cum 415K 9/21; cum 425K 3/22; just went off line; 449K/2/25;
- 20513, 2,365, EOG, Riverview 3-3130H, Clarks Creek, more information here, t3/13; cum 764K 3/21; off line as of 3/19; back on line for two days, 719; huge jump in production, 8/19; off line, 4/20; remains off line 5/20; back on line 11/20; cum 766K 9/21; cum 767K 7/22; cum 769K 11/22;
- 20589, A/AB/IA/4,815, Whiting, Tarpon Federal 21-4H, said to have a 7,000 boepd IP; record middle Bakken (as of Feb, 2012); Twin Valley, 30 stages; 2 million lbs sand/mesh ; s8/11; t10/11; cum 635K 3/21; needs to be re-fracked; off line as of 7/19; remains off line 4/20; back on line 11/20? cum 638K 9/21; cum 644K 7/22; cum 646K 11/22; cum 646K 2/23;
- 20591, 2,656, Oasis/QEP/Helis, Jones 4-15/22H, Blue Buttes, Bakken, t4/12; cum 666K 3/21; off line as of 8/19; on line as of 9/19; cum 675K 9/21; cum 690K 7/22; cum 699K 11/22; cum 707K 3/23;
- *****20738, 1,496, Hess, HA-Mogen-152-95-0805H-2, Hawkeye; t12/11; cum 675K 3/21; note -- 250K and not even a full year; off line as of 1/19; back on line 2/19; no jump in production; cum 681K 9/21; cum 693K 7/22; cum 696K 10/22; off line 11/22; see this note; cum 396K 9/22; off line; 700K 6/23;
- 20780, 2,190, Oasis/QEP, Henderson 1-28/33H, Grail, t6/12; cum 594K 3/21; cum 605K 9/21; cum 619K 7/22; cum 625K 11/22; cum 630K 3/23;
- 21406, 1,355, EOG, Liberty 25-0107H, Parshall, t4/13; cum 492K 8/21; off line 5/20; back on linne 6/21; cum 493K 9/21; cum 512K 7/22; cum 518K 11/22; cum 521K 3/23;
- 21488, 1,357, CLR, Antelope 3-23H, four sections; Elm Tree, Bakken, t8/12; cum 723K 3/21; off line 11/19; remains off line 1/20; only two days, 2/20; off line 5/20; back on line 7/20; cum 733K 9/21; cum 742K 7/22; cum 744K 11/22; cum 746K 3/23;
- 21521, 1,521, Oasis/QEP, Dailey 4-12/13H, Spotted Horn, t3/12; cum 439K 3/21; no production since 12/14; 1 day of production 7/15; 2 days of production 8/15; back on status as of 10/15; no production 10/16; on-line 6 days 11/16; looks back to normal as of 2/17; jump in production back in 7/18; since 7/18, erratic production; produced 5/19; no production 6/19; back on line as of 5/19; low production since then; cum 440K 8/21; off line 9/21; back on line for a couple of days; offline; cumm 441K 1/22; sporadic since then;
- 21564, 2,288, Oasis/QEP, Levang Federal 14-21/16H, Blue Buttes, t8/12; cum 692K 3/21; very erratic production since 12/18; was off line 2/19 - 6/19; back on line 6/19; cum 696K 9/21; cum 702K 7/22; cum 703K 11/22; cum 705K 3/23;
- 22361, 4,971, Whiting, Tarpon Federal 21-4-3H, Twin Valley, Middle Bakken "C" facies well; t12/12; cum 604K 3/21; -- ready to be re-fracked; cum 606K 9/21; cum 607K 7/22; cum 608K 11/22; cuum 608K 3/23;
- 22484, 2,946, EOG, Hawkeye 102-2501H,
Clarks Creek, Bakken, Three Forks; 3 standup sections, 1920 acres; TD = 25,451 feet; producing, first short month at
17,147 bbls, January, 2013; t1/13; cum 621K 3/21; extended long lateral (3 sections long); only 22 days, 4/20; off line 5/20; back on line 6/20; cum 628K 9/21; cum 638K 7/22; cum 642K 11/22; cum 646K 3/23;
- 22485, 1,926, EOG, Hawkeye 01-2501H,
Clarks Creek, Bakken, middle Bakken; producing, first short month at
17,721 bbls, January, 2013; TD = 25,827 feet; 3 stand-up sections, 1920 acres; extended long lateral (3 sections long); t1/13; cum 707K 3/21; off line 3/20; remains off line 4/20; back on line 7/20; cum 713K 9/21; cum 727K 7/22; cum 733K 11/22; cum 736K 3/23;
- 22486, 2,421, EOG, Hawkeye 100-2501H, Clarks Creek (see stand-alone post); 3-section spacing (1,920 acres); will this be a long lateral (9,000 feet) or a much-talked-about-seldom-seen-super-long lateral (14,000 feet)? I'm betting the latter. If accurate, a huge "thank you" to a reader. This well is NORTHEAST of Watford City. [Turned out to be 25,101 feet long. Yes, a super-long lateral, almost 3 sections long.] Did Lynn Helms misspeak or was he misquoted in The Bismarck Tribune when he said there was a gusher NORTHWEST of Watford City? If there is still another gusher NORTHWEST of Watford City that is better than this well, we are talking some big wells in the Bakken, Three Forks; 47 stages; 14 million lbs of sand, 1920-acre spacing unit; t9/12; cum 809K 3/21; remains off line 10/19; back on line 10/19; off line as of 11/19; remains off line 4/20; back on line 7/20; 823K 9/21; cum 839K 7/22; cum 844K 11/22; cum 848K 2/23; cum 849K 3/23; cum 862K 3/24; 874K 7/25;
- ***22487, 67 (no typo), EOG, Hawkeye 02-2501H, Clarks Creek, t12/13; cum 889K 3/21; went offline 6/19; 3-section spacing; 1,741 acres in the spacing unit; sister well to the well announced earlier with 200,000 bbls in less than 5 months; another 15,000-ft horizontal; trip gas over 4,000 units; remains off line 7/19; back on line 8/19; off line 11/19; remains off line 4/20; back on line 10/20; see this post; cum 909K 9/21; cum 934K 7/22; cum 942K 11/22; cum 948K 2/23; cum 949K 3/23; cum 968K 1/24; 971K 3/24; cum 996K 4/26;
- 22921, 60, EOG, Liberty 106-0107H, Parshall, t5/13; cum 599K 3/21; off line 5/20; back on line 6/20; cum 610K 9/21; cum 623K 7/22; cum 626K 11/22; cum 627K 12/22; off line.
- ***24337, 2,519, EOG, Hawkeye 3-2413H, 28 stages; 10 million lbs sand, t5/13; cum 852K 3/21; huge well; great production continues, 10/19; only 22 days, 4/20; off line 5/20; cum 868K 9/21; cum 900K 7/22; cum 914K 11/22; cum 918K 2/23; cum 921K 3/23; cum 945K 1/24; cum 950K 3/24;
- ******24666, A/AB/1,913, EOG, Van Hook 126-2523H, Van Hook, t7/13; cum 777K 3/21; nice production continues; see this post; only 17 days, 4/20; off line 5/20; cum 784K 9/21; cum 786K 12/21; off lnie; 1/22; cum 787K 11/22; cum 787K 2/23; cum 788K 3/23;
- 24667, A/IA/1,173, EOG, Van Hook 19-2523H, Parshall, t7/13, cum 597K 3/21; only one day production in July, 2015; since then, full up; 50 stages, 10 million lbs; only 14 days, 4/20; off line 5/20; remains off line 9/20; back to A and back on line 10/20; sporadic production; cum 602K 9/21; cum 608K 7/22; cum 611K 11/22; cum 612K 3/23; cum 616K 4/25;
- 25093, A/IA/745, EOG, Wayzetta 150-159H, 52 stages, 14 million lb, t8/13; cum 814K 3/21; only 14 days, 8/19; only 9 days, 4/20; offline 5/20; back to active and back on line 11/20; cum 823K 9/21; cum 832K 7/22; cum 840K 11/22; cum 844K 3/23; cum 865K 4/24; cum 873K 4/25;
- 25164, 768, Whiting, Hauge 41-3H, t5/13; cum 417K 3/21; went off line 4/19; remains off line 8/19; back on line 9/19; cum 433K 9/21; cum 454K 7/22; cum 461K 11/22; cum 468K 3/23; cum 496K 4/25;
- 25336, 2,129, EOG, Wayzetta 137-2226H, Parshall (215,000 bbls in less than five full months), 54 stages; 17 million lbs of sand; t9/13; cum 781K 3/21; off line 3/20; remains off line 5/20; back on line 6/20; cum 792K 9/21; cum 817K 7/22; cum 824K 11/22; cum 831K 3/23; cum 846K 4/24; cum 862K 4/25;
- ******* 25374, 1,414, EOG, Austin 39-3204H, 1920-acre spacing, Parshall, 60 stages, 14.6 million lbs, 1920 acres, t9/13; cum 1.131520 million bbls 4/21; according to FracFocus, fracked from 7/6/2013 to 8/8/2013; went off-line as of 9/18; F; back on line as of 11/18; still flowing at 5,000 bbls/month, 10/19; off line 5/20; back online 6/20; struggling, 6/21; struggling earlier but looks like it is doing well as of 7/21; cum 1.139663 million bbls 9/21; cum 1.162822 million bbls 7/22; flowing at 2200 bbls/month; cum 1.170394 million bbls 11/22; cum 1.1175125 million bbls 2/23; cum 1.176256 million bbls 3/23; cum 1.195773 million bbls 3/24; cum 1.209841 million bbls 4/25;
- 25646, 607, EOG, Wayzetta 30-3230H, t11/13; cum 815K 3/21; off line 3/20; remains off line 4/20; remains off line 5/20; back on line 8/20; cum 824K 9/21; cum 837K 7/22; cum 842K 11/22; cum 846K 3/23; cum 869K 4/25;
- 25647, 110, EOG, Wayzetta 31-3230H, t10/13; cum 818K 3/21; off line 5/20; back on line 10/20; cum 824K 9/21; cum 840K 7/22; cum 845K 11/22; cum 848K 3/23; cum 860K 4/24; cum 868K 4/25;
- 26028, IA/1,142, EOG, Wayzetta 41-2117H, t12/13; cum 837K 12/20; remains off line 9/20; back on line 10/20; off line 12/20; remains off line 4/21; back on line 6/21; cum 839K 9/21; cum 846K 4/22; went off line 4/22; cum 849K 11/22; cum 851K 3/23; cum 854K 2/24;
- 26737, 3,374,
Enerplus, Ribbon 152-94-18B-19H,
Sanish, again, much of the paperwork
says "Bakken," and the target was clearly the middle Bakken (middle
Bakken "C") but the scout ticket says the Sanish pool; 42 days (316
hours) of
drilling; 42 stages; 10.0 million lbs sand; t4/14; cum 60K 3/21; in 5/19, full month but only 88 bbs of oil; cum 666K 9/21; cum 674K 7/22; cum 677K 11/22; cum 681K 3/23; cum 690K 8/24; cum 697K 4/25;
- 26989, 2,357, Enerplus, Rattle 152-94-18B-19H, Sanish, t6/15; cum 427K 3/21; off line 3/20; remains off line 5/20; back on line 6/20; cum 429K 4/20; cum 435K 9/21; cum 444K 7/22; cum 447K 11/22; cum 450K 3/23; cum 465K 4/25;
- 27521, 5,002, Whiting, Flatland Federal 11-4HR, Twin Valley, MB about 42 feet thick; 94 stages; 4 million lbs sand/ceramic; t10/14; cum 504K 9/21; cum 513K 5/22; cum 517K 11/22; cum 519K 3/23; cum 543K 4/25;
- 27564, 1,235, CLR, Holstein Federal 2-25H, Elm Tree, 40 stages, 4 million lbs, t2/15; cum 806K 3/21; GL; off line as of 11/19; remains off line 2/20; back on line 3/20; offline 5/20; back online 7/20; cum 826K 9/21; cum 850K 7/22; cum 857K 11/22; cum 864K 3/23; cum 885K 8/24; cum 890K 4/25;
- 28590, 1,258, WPX, Victor Elk 32-29HB, Reunion Bay; t1/15; cum 450K 4/21; see this post; cum 461K 9/21; cum 479K 7/22; cum 483K 11/22; cum 489K 3/23; cum 504K 8/24; cum 507K 4/25;
- 1509, AB/IA/248, CRL/Prima, Kate Hopkins 1, Antelope field; Sanish; spacing: 160 acres; t12/57; cum 607K 7/20; slowing down significantly; every other month with no production; then as of 10/16 began producing 300 bbls/month every month; up to 500 bbls as of 5/18; cum 607K 12/23, but essentially reporting a few bbls every quarter; no production since 1/24;
- 1987, AB/IA/A/AB/IA/150, CLR/Pan American/Prima, Woodrow Star "A" 1, Antelope field; Sanish; t10/58; cum 1.105586 million bbls 12/18; a vertical well; went off line 1/19; back on line 7/21; cum 1.106121 million bbls 9/21; cum 1.109317 million bbls 4/24; cum 1.109820 bbls 6/24;
- ****16963, A/IA/423, Petro-Hunt, USA 35D-1-1H, Charlson Three Forks, t12/08; cum 812K 1/21; NOTE: this is a 640-drilling unit; this is a dual lateral; it's quite a story; off line again, 5/20; remains off line 6/20; last sundry form received in 2012; nothing to explain recent production; cum 890K 9/21; cum 953K 11/22; cum 977K 6/23; cum 996K 1/24; see this post; 1.003557 million bbls 4/24; cum 1.028518 million bbls 4/25;
- 17974, 1,068, BR, Shenandoah 34-36H, t6/09; cum 582K 1/21; off line 6/20; back on line 9/20; cum 589K 9/21; cum 600K 11/22; cum 616K 4/24; cum 627K 4/25;
- 18012, 3,304, Ovintiv/Newfield, Sand Creek Federal 1-23H, t2/11; cum 442K 1/21; struggling; cum 445K 9/21; cum 450K 11/22; cum 458K 4/24; cum 463K 4/25;
- 19296, 2,388, SHD Oil & Gas, LLC, Golden 22-31H, Deep Water Creek Bay, Three Forks Bench 1, 62 stages; 15.3 million lbs, TD = 27,141 feet; seam 215 feet thick (top of TF to top of Nisku); target zone = 10 feet thick; gas maxed out gas equipment at 9,998 units; t3/15; cum 818K 4/21; off line 5/20; remains off line 6/20; back on line 9/20; cum 828K 9/21; cum 874K 11/22; cum 936K 4/24; cum 975K 4/25;
- 19321,1,274, MRO, Danks USA 11-3H, Antelope, Sanish, 8/11; cum 651K 1/21; remains off line 6/20; back on line 8/20; cum 664K 9/21; cum 677K 11/22; cum 686K 4/24; cum 689K 4/25;
- 20526, 2,446, Whiting, Smith 34-12TFH, Park oil field; the company says this is a record TFS well; production run; s6/11; t9/11; cum 441K 9/21; cum 458K 4/24; cum 462K 4/25;
- 20640, 2,597, Grayson Mill/Equinor/BEXP, Irgens 27-34 2TFH, East Fork field, Three Forks, s4/11; t9/11; cum 323K 1/21; BEXP says this was their record well; does not even compare to #20526 (above); cum 336K 9/21; cum 349K 11/22; cum 357K 4/24; cum 361K 4/25;
- 20504, 2,696, Pronghorn Federal 21-13TFH, first half month of production, 14K bbls; first full month, 28K, 1/12; t12/11; cum 325K 1/21; taken off-line September, 2014; only 10 days 11/14; cum 332K 9/21; cum 346K 4/24; cum 350K 4/25;
- 21488, 1,357, CLR, Antelope 3-23H, Elm Tree, Three Forks, 29 stages, 2.8 million lbs, t8/12; cum 719K 1/21; off line 11/19; remains off line 12/19; returned to production; off line 5/20; remains off line 6/20; back on line 7/20; cum 733K 9/21; cum 744K 11/22; cum 752K 4/24; cum 757K 4/25;
- 22486, A/IA/2,421, EOG, Hawkeye 100-2501H, Clarks Creek (see stand-alone post);
3-section spacing (1,920 acres); t9/12; cum 804K 1/21; super long lateral (15,000 ft); Three Forks well; off line as of 4/19; back on line as of 10/19; cum 823K 9/21; cum 844K 11/22; cum 863K 4/24; cum 872K 4/24;
- 26737, 3,374,
Enerplus, Ribbon 152-94-18B-19H, Sanish, again, much of the paperwork
says "Bakken," and the target was clearly the middle Bakken (middle Bakken "C") but the scout ticket says the Sanish pool; 42 days (316 hours) of
drilling; 42 stages; 10.0 million lbs sand; t4/14; cum 658K 1/21; remains off line 6/20; back on line 9/20; cum 666K 9/21; cum 688K 4/24; cum 697K 4/25;
- 26988, 2,842, Enerplus, Bull 152-94-18B-19H-TF, Sanish, t6/15; cum 585K 9/21; cum 644K 4/24; cum 677K 4/25;
- 26990, 3,102, Enerplus, Hognose 152-94-18B-19H-TF, Sanish, specifically Three Forks 2nd bench, three laterals; 60 days (533 hours) drilling, 41 stages; 9.7 million lbs sand; t4/14; cum 596K 9/21; look at production profile in 1/16; cum 607K 11/22; cum 618K 4/24; cum 625K 4/25;
- 27520, 6,002, Whiting, Flatland Federal 11-4TFH, TF1, Twin Valley, up to 9,900 gas units; 97 stages; 4.2 million lbs sand/ceramic; t10/14; cum 691K 9/21; cum 702K 7/22; cum 718K 4/24; cum 723K 4/25;
- 27522, 4,207, Whiting, Flatland Federal 11-4TFHU, 4 sections, TF2, in excess of 9,500 gas units, Twin Valley, F, t10/14; cum 608K 9/21; remains off line 6/20; back on line 7/20; cum 634K 8/22; F; cum 638K 11/22; still flowing, no pump; cum 664K 4/24; cum 677K 4/25;
- *****27587, 2,188, Softshell 152-94-33C-28H TF, 1280 acres, 39 stages, 9.3 million lbs, t11/14; cum 826K 1/21; plus 333,000 boe natural gas 11/18; no explanation why this well is reporting only one day of production each month since 10/19; in 11/19, 6,300 bbls on one day, doesn't make sense; starting 11/20, back to full months (30 - 31 days); cum 857K 9/21; back to reporting full months; cum 887K 7/22; cum 925K 1/24; 929K 3/24; 931K 4/24; cum 947K 4/25;
- 30286, A/AB/1,974, EOG, Riverview 102-32H, 320-acre spacing; short lateral; 87K first full month of production, 7/15; remains off line 6/20; back on line 7/20; t6/15; cum 685K 9/21; 706K 9/22; cum 706: 4/25;
- 31060, A/IA/3,473, MRO, Heather USA 13-35TFH, 44 stages, 12 million lbs, t5/16; cum 429K 8/21; off line 8/21; cum 460K 4/24; cum 479K 4/25;
- 31061, IA/2,942, MRO, Juanita USA 13-35H, Antelope/Sanish, 13 days; percent in drilling target: 76% -- ouch, 40 stages; 11.99 million lbs; t7/16; cum 449K 10/19; cum 488K 8/21; off line 6/20; profile update here; back on line 8/20; off line 8/21; cum 514K 2/24; off line again; cum 530K 4/25;
- 32975, 9,166, MRO, Jerome USA 12-23TFH, Reunion Bay, t9/18; cum 474K 3/21; TD: 23,722 feet; permit: Three Forks B2; stimulation:
Three Forks B1; 56 stages; 11.4 million pounds proppant; sundry form
dated September 4, 2017, name change and target changed from second
bench to first bench; cum 588K 9/21; cum 690K 4/24; cum 716K 4/25;
Three Forks
Second Bench
Second Bench
See "third generation fracks."
Pronghorn- 28055, 1,754, Whiting, Smith Federal 41-13PH, Park, Three Forks B1, 17 stages, 1.6 million lbs, s10/10; t5/15; cum 304K 1/21; remains off line 6/20; back on line 9/20; cum 326K 9/21; 362K 4/24; cum 368K 4/25;
- 28056, 2,282, Whiting, Smith Federal 44-12PH, Park, Three Forks B1, s10/14; t4/15; cum 461K 1/21; cum 472K 9/21; cum 494K 4/24; cum 497K 4/25;
- 20526, 2,446, Whiting, Smith 34-12TFH, Park, t9/11; cum 441K 9/21; cum 458K 4/24; cum 462K 4/25;
- 20504, 2,696, Whiting, Pronghorn Federal 21-13TFH, Park, t12/11; cum 317K 6/20; cum 332K 9/21; cum 346K 4/24; cum 350K 4/25;
- 27691, 2,683, Whitng, Pronghorn Federal 11-13PH, Park, t11/14; cum 348K 6/20; cum 362K 9/21; cum 379K 4/24; cum 382K 4/25;
- 23419, A/IA/1,556, Whiting, Hecker 11-18PH, Bell, t11/12; cum 353K 1/21; remains off line 6/20; back on line 8/20; cum 356K 9/21; cum 364K 4/24; cum 362K 4/25;
- 23420, IA/1,861, Whiting, Frank 14-77PH, Bell, t11/12; cum 440K 1/21; coming back on line, 9/21? cum 441K 9/21; cum 456K 4/24; cum 460K 1/25;
- 19444, 3,106, Whiting, Hecker 21-18TFH, Bell, t3/11; cum 441K 1/21; cum 443K 9/21; cum 446K 11/22; cum 450K 4/24; cum 452K 4/25;
- 20828, 2,456, Whiting, Frank 34-7TFH, Bell, t1/12; cum 454K 1/21; remains off line 6/20; back on line 7/20; cum 458K 9/21; cum 467K 4/24; cum 470K 4/25;
- 21269, 372, WPX, Skunk Creek 23-14 HC, Mandaree, t3/12; cum 479K 1/21; remains off line 6/20; back on line 8/20; cum 487K 9/21; cum 497K 11/22; cum 501K 6/23; cum 511K 4/25;
- 20323, IA/3,325, BR, Midnight Run 11-1MBH, Union Center, t12/11; cum 369 3/20; poor producer after 1/15; most recent sundry form dated November, 2012; now doing well, 12/16; off line as of 6/19; remains off line 10/19; returned to production but off line for quite some time; remains off line 6/20; intermittent; back on line 8/21 but still a poor producer; cum 377K 11/22; cum 383K 8/24;
- 19690, 2,884, BR, Mazama 44-21H, Westberg, Bakken, t7/12; cum 431K 6/20; cum 457K 9/21; cum 572K 12/24; off line but now back on line 4/25;
- 19764, 3,249, Grayson Mill/Equinor/Statoil/BEXP, Vachal 3-34 1H, Alger, Bakken, t5/11; cum 428K 4/21; cum 440 K 9/21; cum 450K 11/22; cum 475K 4/24;
- 20079, IA/2,760, Whiting, Obrigewitch 21-16TFH, Bell, t2/12; cum 386K 6/20; cum 391K 9/21; cum 392K 9/21;
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