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   Gold/Mining/EnergyOil & Gas Exploration & Production Co.'s

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To: Celtictrader who wrote (102)4/11/2009 11:42:48 AM
From: Celtictrader
   of 112
Maybe Not,just found this article!
Natural gas prices tumble almost 75%

COLUMBUS - The 60 million American homes that rely on natural gas for heat can expect substantially lower bills next winter, thanks to a glut in supply and the weak economy.

Just as distributors start to lock in contracts for the coming winter, natural gas prices have fallen almost 75 percent. Not all of that will show up as savings on heating bills, but it should mean noticeable savings.

New technology this decade has unlocked massive reserves of natural gas in North America, and the sudden jump in supply has collided with a recession, the worst since World War II, that has sapped demand.

The result has been a collapse even more dramatic than the drop in oil prices.

Natural gas futures ended this week at $3.61 per 1,000 cubic feet, down from a July peak of $13.69. That's a decline of 74 percent, compared with a decline of 64 percent in oil prices over the same period.

Households have yet to see those huge drops reflected in their heating bills because the companies that buy and distribute natural gas in bulk are still passing on the premium prices they paid last summer.
But lower rates are almost certainly coming. Distributors already are signing contracts for next winter that lock in today's low rates.

A 75 percent decline in the price of natural gas does not mean the heating bill will decline by that much. On average, the price of gas makes up about two-thirds of the bill with transportation, taxes, and other expenses covering the remaining costs. Americans spent about $60 billion on natural gas for heat this past winter.

Distributors don't profit from the price of gas. They typically make money from getting the gas to your home. If they want to charge more, they need approval of state regulators.

In some places, natural gas bills are already way down. The average bill this month for customers of Columbia Gas of Ohio will be $101.54, the lowest in five years and down 26 percent from a year ago.

The government's Energy Information Association says the volume of gas in storage around the country, a staggering 1.67 trillion cubic feet, is 35 percent more than it was last year.

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To: Ed Ajootian who wrote (99)4/16/2009 12:12:08 PM
From: Celtictrader
   of 112
Hi Ed,do you have any favorite Beaten down Natural gas plays?Bloomberg this morning talking about natural gas is used by only 150,000 cars & trucks in the USA while Worldwide it is used by about 10 Million. 1 MCF of gas = about 7 gallons of diesel i believe.Looks like a pretty good time to start buying up some beaten natural gas co? Thanks & good luck Jerry

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To: Celtictrader who wrote (104)4/16/2009 10:03:47 PM
From: Ed Ajootian
   of 112
Jerry, I'm not really looking very closely at natgas companies right now because I believe the pain of low commodity prices is not over yet. One company I have in mind to look at more closely if/when the future looks brighter is GMX Resources (GMXR). They have a large exposure to the Haynesville Shale, a very hot play right now. Another company I would look at would be Double Eagle (DBLE).

BTW, I don't really check this board any more, so I suggest you post any further thoughts/questions on the Boom Boom Room board, see Subject 50987 . I check that board regularly and you will find that there are a lot of astute posters there.

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To: Ed Ajootian who wrote (105)4/17/2009 1:46:34 PM
From: Celtictrader
   of 112
Thanks Ed,will do. I see GMXR having a nice day today! Good Luck

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From: Ed Ajootian12/6/2009 1:45:17 PM
1 Recommendation   of 112
Denbury Sharpens Enhanced Oil Recovery Focus
Copyright © 2009 Energy Intelligence Group, Inc.
Friday, December 4, 2009

Dallas-based Denbury Resources is expanding further into the carbon dioxide-based enhanced oil recovery (EOR) business and disposing of its largest remaining natural gas assets.

Denbury said on Thursday it will pay $430.7 million in cash and stock to privately held Wapiti Energy for a 95% stake in the old Conroe oil field north of Houston.

The cash will come from the proceeds of a $210 million sale of Denbury's remaining Barnett Shale gas assets in North Texas to Talon Oil & Gas, another private company that purchased 60% of the Barnett properties earlier this year (OD May14,p7).

The two transactions will get Denbury almost completely out of the natural gas business, even after factoring in the recently announced $4.5 billion purchase of Encore Acquisition (OD Nov.3,p1).

Denbury is currently in the process of acquiring Fort Worth-based Encore which focuses on enhanced oil recovery and unconventional oil, such as the Bakken Shale play of North Dakota. Encore does have a few small natural gas holdings.

Denbury is representative of an emerging trend, especially among independent producers, but also some majors, to focus more on North American oil which currently offers much higher margins.

Current Nymex futures prices have oil and natural gas at a 17:1 price ratio, compared to the historical ratio of 10:1. The multiple had been as high as 30:1 earlier this year.

"We believe that taken together, these two transactions further enhance our core strategy, assets and focus," said Denbury Chief Executive Phil Rykhoek.

"We are acquiring an asset with an estimated 125 million barrels of upside potential in exchange for an asset that we believe has far less potential," he added.

Rykhoek described the Conroe field as the "single largest potential tertiary flood on our list of desired Gulf Coast properties."

Denbury has been expanding from its original base in Mississippi into the Upper Texas Gulf Coast through the acquisition of an assortment of old oil fields. It is currently constructing the Green Pipeline to transport naturally occurring occurring carbon dioxide from an underground source to the region.

The company also is looking at opportunities to capture carbon dioxide from industrial emissions for use in enhanced oil recovery projects in the Gulf Coast area.

Developing the Conroe field as an enhanced recovery project will not be cheap, however. Denbury said it will invest $750 million to $1 billion to recover an additional 125 million bbl of oil from the field, including construction of an 80-mile connection to the Green Pipeline.

In addition, Denbury believes it can recover another 20 million barrels of oil equivalent of conventional reserves from the property.

The Conroe field, located about five miles northwest of the town of Conroe and 40 miles north of Houston, was discovered in 1931 by wildcatter George W. Strake.

As was often the case, development of a find of this magnitude was beyond Strake's means, so he brought in the Humble Oil & Refining Co. -- one of Exxon Mobil's predecessor companies -- as his partner.

Other drillers had interests in the field, and it became a test case for the Texas Railroad Commission as the agency sought to implement newly passed production regulations in the 1930s. Eventually the field was unitized under a single operator, initially Humble, which later became part of Exxon.

According to Texas Railroad Commission figures, the Conroe field has already yielded more than 750 million bbl of oil over a lifetime of nearly eight decades.

Barbara Shook, Houston

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To: Ed Ajootian who wrote (107)11/19/2010 12:02:08 AM
From: DipNoid
   of 112
Be on the look out. TRDY is a clean debt free shell and we expect to see an O&G company R/M into it between now and Monday AH. (.017)

Could be big. A Stan Larson is controling this

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From: JakeStraw3/30/2011 11:26:16 AM
   of 112
Neal Dingmann: Genuine Energy Growth Still Lives in E&Ps
March 30, 2011

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From: demersal7/15/2011 9:00:45 AM
   of 112
POTG exploration-stage company, not healthy, almost no cash in the bank, being actively promoted/pumped:

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From: Ed Ajootian8/23/2013 8:10:15 PM
   of 112
Adena Field Project

In two transactions in May and December 2011, Black Raven bought the wells, equipment and acreage known as the Adena Field Project. Our Adena Field Project is located in Morgan County in Northeast Colorado, where we owned a 100% working interest in 18,760 gross acres as of June 30, 2013. Our acreage position covers the vast majority of Adena Field, which is the third largest oil field in the history of Colorado according to the Colorado Oil and Gas Conservation Commission, behind Rangely Field and Wattenberg Field. Adena Field has cumulatively produced 75 million barrels of oil and 125 billion cubic feet of natural gas. Almost all of our leased acreage in this project is currently held-by-production (see “Glossary” on page [•] for definition of held-by-production). Nearly all of the producing wells in Adena Field were temporarily abandoned or shut-in during the secondary recovery phase in the mid-1980’s when oil prices collapsed, and only a small number of wells have been produced since that time.

As of July 31, 2013, our Adena Field Project was producing approximately 250 gross barrels of oil equivalent (68% oil) per day from 8 J-S and 7 D-Sand wells at a depth of approximately 5,500 feet. Approximately 127 wells are currently shut-in or temporarily abandoned in our Adena Field Project, of which we have initially identified approximately 60 wells to be re-activated in the J-Sand formation and 20 wells to be re-completed in the D-sand formation. Our producing J-Sand wells currently average approximately 11 barrels of oil per day and our most recent D-Sand re-completion achieved an initial peak production rate of approximately 100 barrels of oil per day before stabilizing at a rate of approximately 30 barrels of oil per day. Re-completions and re-activations are expected to cost approximately $200,000 per well. In addition, Black Raven initiated a secondary water flood project in an isolated D-Sand oil pool during the first quarter of 2013. This water flood project is expected to significantly increase our oil production with initial response expected during the fourth quarter of 2013.

Our working interest in our Adena Field Project is subject to a 30% reversionary working interest that will be assigned to an unrelated third party, subject to the terms and conditions of such agreement, after payout of all acquisition, operating, development, and financing costs (including interest), plus interest at a rate of 13% per annum on all amounts paid by us on or with respect to the Carlyle Note agreement. The payout balance associated with this reversionary working interest was estimated to be approximately $28 million as of June 30, 2013.

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From: Steve2436/7/2015 11:53:50 AM
   of 112
I`m new at this site but I hope it`s ok to give my recomendation?

It`s a company called African Petroleum Corporation Limited, APCL.

It`s traded at the Oslo Axess in Norway.

This company is a significant net acreage holder in West Africa, holding ten licenses, six of them close to where several discoveries have been made in recent years, including significant discoveries during 2014 by Total in Côte d’Ivoire and Cairn Energy in Senegal.

This might be the next hot-spot region in oil development. The new CEO, Stuart Lake, has this amazing track record, having drilled above 300 wells with 85% hit-rate.

Today`s Market Cap is about $45M, it can easily be ten times this in a year with a commercial discovery..

About 20% of the shareholders are US investors.

According to CFO Stephen West, there will be made farm out announcements by H1 this year. A completed farm out transaction provides a huge upside potential, a commercial discovery should deliver further material upside.

Please take a look, ask me if you have any questions!

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