if I was Mattel or Hasbro, I would buy the whole company.. offer 60 % over todays close ( that is $ 14.08 per share ) And own the Entire LF company. for $ 960 Million $$$..
At the cheap price LF is tonight someone will shortly.. don
this article from Dickinson paper today. I wonder if WBI ( division of MDU) will use this on their proposed NG pipeline???
BISMARCK — A Duluth, Minn., energy company announced Wednesday it plans to create an energy corridor that could efficiently transport oil and natural gas produced in North Dakota and reduce natural gas flaring.
ALLETE, an energy company that has a 465-mile electrical transmission line from central North Dakota to Duluth, said it plans to work with other energy companies to locate pipelines along its existing right-of-way.
ALLETE officials made the announcement from the North Dakota Capitol on Wednesday with Gov. Jack Dalrymple and members of the EmPower North Dakota Commission.
No specific projects have been proposed, but the energy corridor could accommodate several pipelines for transporting oil or natural gas, as well as wastewater and carbon sequest-ered from fossil fuel.
Pipeline companies have to obtain right-of-way from private landowners. The idea is that locating pipelines adjacent to the transmission line would be more efficient and less disruptive to landowners than establishing several different rights-of-way.
“We think it can bring a certain amount of efficiency and ease landowner fatigue here in North Dakota,” said ALLETE President, Chairman and CEO Alan Hodnik.
Dalrymple thanked company officials for their “tremendous vision” and said he hopes the corridor will help the state meet its goal of reducing natural gas flaring.
“I would like to see this corridor become part of the achievement of a large natural gas pipeline from the Bakken region to the east,” Dalrymple said. “I think the odds of that taking place are greatly enhanced by this concept.”
ALLETE has a 250-kilovolt line, purchased in 2009, that transmits electricity from the lignite-fired Young Generation Station in Center and the nearby Bison Wind Energy Center to Duluth. The company is working to extend its right-of-way 60 miles to the west to the Bakken region.
I would support a $ .05 cent Annual dividend. this would also open the stock up to Mutual funds who have to have a dividend to hold in their fund.. This would cost the company less then $ 3.4 Million per year.
Make It payable in Feb, or March.. don
the AP is reporting today in dickinson paper. don
BISMARCK — Two North Dakota State University researchers who have predicted that an influx of oil field workers will continue to boost the state's population now want to know more about those workers.
Nancy Hodur and Dean Bangsund, researchers with NDSU's Agribusiness and Applied Economics Department, announced during the Bakken Construction Summit in Bismarck on Wednesday that they plan to study workforce characteristics to complement their previous study on projected population, investment and job numbers in the western Oil Patch.
The number of people employed directly by the oil industry is expected to peak at between 45,000 and 60,000 in 2020 and slowly taper off to about 38,000 permanent workers in 25 years, according to Hodur and Bangsund's earlier study.
The researchers now plan to conduct personal interviews and use focus groups and written surveys, starting early next year. They want to find out where workers are from, where they're living and where they would like to live, how old they are, if they're married and if they have children.
Hodur said she and Bangsund hope they will be able to provide builders with insight into the type of housing workers want. The study's findings might reveal a disconnect between what types of housing is in demand and what is being built, she said.
Hodur said it also is unknown whether workers want to live in larger communities where spouses can go shopping and golfing, and whether they want to commute to their jobs or live close to work.
“No one has asked the industry,” she said.
The study is expected to take about a year.
this is the first part,. google the subject for complete article.
It's a climate puzzle that has vexed scientists for more than a decade and added fuel to the arguments of those who insist man-made global warming is a myth.
Since just before the start of the 21st century, the Earth's average global surface temperature has failed to rise despite soaring levels of heat-trapping greenhouse gases and years of dire warnings from environmental advocates.
Now, as scientists with the Intergovernmental Panel on Climate Change gather in Sweden this week to approve portions of the IPCC's fifth assessment report, they are finding themselves pressured to explain this glaring discrepancy.
The panel, a United Nations creation that shared the 2007 Nobel Peace Prize with Al Gore, hopes to brief world leaders on the current state of climate science in a clear, unified voice. However, experts inside and outside the process say members probably will engage in heated debate over the causes and significance of the so-called global warming hiatus.
"It's contentious," said IPCC panelist Shang-Ping Xie, a professor of climate science at the Scripps Institution of Oceanography at UC San Diego. "The stakes have been raised by various people, especially the skeptics."
Though scientists don't have any firm answers, they do have multiple theories. Xie has argued that the hiatus is the result of heat absorption by the Pacific Ocean — a little-understood, naturally occurring process that repeats itself every few decades. Xie and his colleagues presented the idea in a study published last month in the prestigious journal Nature.
In a report available online ( goggle ) ( Bakken shale production will surprise Wall Street, Goldman Sachs says)
Goldman has a chart of the future production from the bakken . in 2015 they are projecting the Daily production to be 1.5 Million BOPD . in 2020 at a peak , 2 Million BOPD..
ND today is a little over 850,000 BOPD . Think of all the NG that will have to be Processed in NEW NG processing plants and placed in pipelines to be shipped somewhere.... don
there also were 9 different wells in 4 fields, ( Heart river, New Hradec, Sanish, Stanley ) that are on the Confidential list but producing Oil. These 9 wells had Runs ( oil Sold ) in august that amounted to 85,221 BO.
When you add the produced ( actual ) 341,590 BO and the Runs from the confidential wells , you have 425,560..
Fidelity also sold 200,943 Mcft of NG, of this NG total 78,525 came out of the Cedar Creek field ( Pierre shale) this field is located approx. 15 miles South of Marmarth ND, in the very SW corner of ND. The other 122,418 Mcft of Sold NG came as associated NG from oil production.
I Do not know how much was NG was flared, cause the 9 wells on confidential did not report the NG not sold, or flared .And I did not track the difference in the other reported wells.. don
Google this subject, it is a article appearing in todays Duluth herald.. don
this article available from Bismarck trib. don
November 03, 2013 12:15 pm • By KENT THIESSE, Farm Management Analyst, and Vice President, MinnStar Bank
Parts of the upper Midwest are experiencing temporary shortages of propane (LP) gas to dry the corn that is currently being harvested.
Propane inventories are very tight at many of the terminals in southern Minnesota, resulting in limited availability to local cooperatives, and ultimately to farm operators, in some areas. The tight propane situation is being monitored very closely by the Minnesota Grain and Feed Association (MGFA), which represents most of the grain elevators in the state.
According to the MGFA, the propane shortage problem is more severe in southern Minnesota, due to the high amount of corn currently being harvested at this time. Some propane terminals have no free-stock gallons of propane available, while other terminals are only loading two or three trucks of LP per hour.
A large commercial corn dryer at a grain elevator that is drying corn at full capacity will utilize a semi load of propane in about four hours. For many cooperatives, income from commercial grain drying, along with propane sales to farm operators, is a big part of their income for a given year.
Some cooperatives are attempting to get propane supplies from other states, such as Kansas and Nebraska, to meet their propane needs; however, the added transportation costs for the LP gas will be passed on to the farmers purchasing the drying gas.
Minnesota Gov. Dayton has issued an executive order to temporarily relax daily hour restrictions on truckers transporting propane gas, in order to transport the needed LP supplies more quickly, but this will still not address supply shortages.
The shortages of propane gas for corn drying comes at the same time that LP demand is increasing for 2013 home heating needs, which is also earlier this year due to the extended cool weather pattern in October.
Another method, demonstrated by the utility American Electric Power in recent years at its Mountaineer plant in West Virginia, is to burn coal conventionally and use an ammonia process to grab the carbon dioxide out of the flue gas. And if coal is burned in nearly pure oxygen, the flue gases are nearly pure carbon dioxide.
In the last few days, Ms. McCarthy has referred to several early-stage carbon capture projects as a sign that industry can build the needed equipment. In testimony on Wednesday before the House Energy and Power Subcommittee, Ms. McCarthy cited four such projects. She told reporters on Friday that the draft rule was based on “technologies that are already entering the market and being constructed in plants today.” But the four she referred to in the committee hearing ranged from under construction to planned. None of them would sequester the carbon dioxide, and all would sell it.
The closest to opening is the Southern Company’s Kemper County plant in Mississippi, which will convert coal to gases and then filter out some of the carbon dioxide, reducing emissions by about 65 percent.
But the plant, at $5 billion, is $1 billion over budget. Southern Company said in a statement on Friday that the plant’s economics were peculiar to its location, and not a national model. Its captured carbon will be sold for use in the oil fields, where it helps force more oil to the surface.
But most power plants are not in areas where they can sell their carbon dioxide.
Revis W. James, director of the Energy Technology Assessment Center at the Electric Power Research Institute, said that before a technology could be considered commercially demonstrated, “you’d need Kemper to be operational and a couple more Kempers, and have the kinks worked out.”
Carbon capture and sequestration, he said, was unlikely to be competitive unless natural gas prices increased by 100 to 150 percent and the construction of nuclear plants was ruled out.
WASHINGTON — The Obama administration’s potentially pathbreaking proposal for carbon emission limits on new power plants will face political and legal challenges from opponents who argue that the technology needed has not been close to being proven as the law requires.
The draft rule was announced on Friday at the National Press Club by Gina McCarthy, the administrator of the Environmental Protection Agency. But to protect industries from pie-in-the-sky requirements, current law limits what rules the agency can make.
E.P.A. rules sometimes demand technological advancements, but the goals that the agency establishes have to be met by techniques that existing law describes as “adequately demonstrated.”
The proposal would limit new gas-fired power plants to 1,000 pounds of carbon dioxide emissions per megawatt-hour and new coal plants to 1,100 pounds of carbon dioxide. Industry officials say the average advanced coal plant currently emits about 1,800 pounds of carbon dioxide per megawatt-hour. A megawatt-hour is a little more than a typical American household uses in a month.
Once the rule is in place, new plants would be required to capture carbon dioxide from the smokestacks and “sequester” it underground. Officials said the regulation could be completed by the fall of 2014.
But, utilities say, laws governing underground disposal were not written with carbon dioxide in mind, and sequestration is in a legal quagmire.
Three systems of carbon capture are in various stages of development. The most common is to convert coal into a mixture of hydrogen, carbon monoxide — which in this context is a fuel, not a pollutant — and carbon dioxide, and to recover the carbon dioxide at two different stages.
you can google the Utah oil and gas and find this info if you want, but i wanted to know what the well/production numbers were for Fidelity / The last month of listed production is August of 2013. Fidelity has a total of 21 listed wells. 3 are listed as Temp abandoned, 5 are listed as Shut in, and 13 are producing oil.
The 13 producers had a total of 362 production days , 10 had 31 production days and the other 3 was at 18,16 and again 18 days.. this makes a average of 27.8 production days for the month. The producing wells averaged 233 BO per production day. or a Grand total of 84,497 BO. the 3 major wells produced for 31 days each and Produced 37,182 BO, 14,316 BO and 13,508 BO total. the other 2 major producers were at 6688 BO in 31 days and 5734 BO in 18 production days.. The balance of the wells were marginal producers.. don
from todays Dickinson paper, Fidelity has property in Stark county that has the Tyler formation under it.. don
Marathon Oil is the first company to try modern horizontal fracking in the Tyler Formation after spudding a well in northeastern Slope County this month.
If successful, Marathon could be the first of many companies to drill that way in the Tyler, a geologically complex formation beneath the southwest part of the state that is viewed by many as the Bakken’s little brother. The formation has produced oil from vertical drilling in the past, but most of the oil that can be caught that way has been tapped by now.
Though it doesn’t have all the potential of the Bakken, the Tyler is similar geologically, which allows Marathon to use Bakken techniques there. The company plans to target the limestone layer between two organic-rich shales, Department of Mineral Resources Director Lynn Helms said.
Marathon is approved to drill a total of four wells in a part of the Tyler containing organic-rich limestone layers that average 5.5 percent “total organic carbon,” said state subsurface geologist Timothy Nesheim.
“Organic-rich rock intervals generate oil and gas, and rocks with greater than 4 percent TOC are typically considered excellent quality in the oil and gas industry,” he said.
The Tyler will vary across North Dakota more than the Bakken does, which means companies would likely have to use more diverse techniques to produce oil.
Germany, Europe’s biggest energy market, is in its largest new-build program for hard coal stations since 1998. Ten new plants with a combined capacity of 7,985 megawatts are scheduled to start producing in the next two years, according to information from German grid regulator Bundesnetzagentur and operators.
“Unabated coal represents the single biggest threat to climate stability,” U.K. Climate Change Minister Gregory Barker said today in an interview. While “it’s imperative” to scale up renewables and energy efficiency, “in the next two decades it is gas that offers the most immediate and economic replacement to coal,” he said, describing the fuel as a “stepping stone” to a lower-carbon future.
The global energy mix “has to tilt much more to non-fossil sources” if climate change is to be curbed, U.S. Special Envoy for Climate Change Todd Stern told reporters today in Warsaw. Carbon capture and storage can help reduce emissions from coal-fired power generation, he said.
“The world runs significantly on fossil fuels right now, and that’s not going to change overnight,” Stern said.
Either way, coal companies should expect tighter government regulation, growing difficulties to secure financing and falling public acceptance for new projects, Figueres said.
“The coal industry faces a business continuation risk that you cannot afford to ignore,” she said. Companies should instead diversify into renewable-energy projects to reduce risk, she said.
Bruce in his blog today has put this article up.. don
North Dakota amended state law on flaring:
House Bill No. 1134 maintains North Dakota's one year flaring grace period, but upon the expiration of the grace period, increased the permitted activities to include a compression collection system that intakes at least seventy-five percent (75.00%) of the gas and natural gas liquids volume for beneficial consumption by various means. This provision also includes any well equipped with other value-added processes as approved by the North Dakota Industrial Commission, which reduces the volume or intensity of the flair by more than sixty percent (60.00%). Additionally, if the gas is collected and/or used by one of these optional systems, the gas is granted an exemption from gross production taxation for a period of two (2) years and thirty (30) days from the time of first production.
I mention this because of this observation regarding the October NDIC hearing dockets: there were only two cases in which an operator asked for permission to continue flaring at max crude oil production. Generally, there are many, many more cases. For example, on the June, 2013, agenda, there were 34 cases in which operators asked flaring be allowed past the "grace period." There have been other months in which there were few or no cases regarding flaring, but with all the activity in the Bakken this past summer, one would think there would be more requests for flaring