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And the AVG popup-there is no way to close it.I am using Kmeleon browser.
AVG.I am getting popups warning that they are going to discontinue service for AVG 7.5.And I think you have to pay to get AVG 8.Is this correct?
Wow!He did that?
Yes,I agree.And I admit I am not sure what the disagreement is about.Is it because TS mentioned the competition and gave them credibility?I think it does us good to be reminded that the general perception is that LTC has plenty of competition.I am not sure if it is relevent here but ,for my own amusement,I posted on a medical forum about how beneficial LTC was going to be for the proceedure.I got a reply from a "medical doctor" saying LTC was just a rehash of something that has been around for 40 years.And a reply from a "patient" who said glues worked just fine on her body so what was the use of LTC?We could all go ballistic with the wrongness of that but it wouldnt change the general perception.LTC is going to have to prove itself in action.And I am betting it will.
What do you mean "make all of you angry"?Hardly anybody is angry.Did you know that long ago Jagman pissed off a few people and we voted wether or not to ban him.A lot of lurkers here voted to keep him.I am confident those same lurkers will be dissappointed if you feel you cannot post your opinions.
Oh come on JS!There is no need to be realistic.That is completely uncalled for here!
Excerpt from that site.
Author: MB Smith
Hi! In February I had a
tummy tuck. It has left me with extensive scars. I am
African American with other small keloid scars. I was
told I could have a revision done followed by
radiation applied to the incision. Even then there is
a possibility it will not help with the scaring
(keloid). I have done some research and I would like
to know if laser tissue welding (instead of stitches)
will help reduce my chance of the scaring(keloid) from
reoccurring. When I talk to the local
doctors they do not know what I am talking about when
I refer to laser tissue welding or suture-less
techniques. Is this not common in the US?
Please help any advise would help.
Answer: Hi, Smith!
We are not sure about radiation application to the incision.
However, we are experienced in suture-less techniques. Our clinic has the necessary equipment, operative treatment but also using some advanced therapy. Is it possible to send us your picture of scars? (My pers. e-mail: vtl2006@ukr.net)
Ha, you obviously still think this stock is trending up.
Geez,oil at $117 and PTCH cant get a bid.
To me this confirms that CTUM made a big mistake having anything to do with Waste Management.They regarded CTUM as a competitor and probably sabotaged the operation.And I am wondering if they stole any technology.........
Joe,it probably makes no difference ,but I have heard that ISRG make their profit from the clip on disposable tools and not from the robots.Sort of like the printer manufacturers making their profit from the cartriges.
Re Bob Brinker.As I recall,his last prognostication was that the S&P was going to 1600 this year and 1400 was a buying opportunity.It is looking likely,to me,that he is going to be wrong.
Bakken Trend update - 25 times more oil than previous estimate
By Tim Wood
11 Apr 2008 at 12:28 PM
It's official, the Bakken Formation has a lot more oil than was previously thought. It's only a tenth of the original estimates, but remember that the overall estimates of 200 billion barrels did not refer to recoverable oil, only the total estimated extent.
For background on the Bakken, see our report from earlier this week.
The USGS says there is "3.0 to 4.3 billion barrels of undiscovered, technically recoverable oil." The 1995 estimate pegged the reserve at 151 million barrels of oil. The original estimate faced imminent embarrassment given that the The Elm Coulee field in Montana has produced around 65 million barrels since its discovery in 2000. It is estimated that Elm Coulee will eventually produce 270 million barrels before it is exhausted.
The USGS says the increased estimate is justified by "new geologic models... advances in drilling and production technologies, and recent oil discoveries.
Is 4 billion barrels of oil a big deal? Absolutely. Consider that:
*
It increases US crude oil reserves by 19%, or an additional 2.4 years of annual domestic production.
*
The Bakken Formation estimate is larger than all other current USGS oil assessments of the lower 48 states and is the largest "continuous" oil accumulation ever assessed by the USGS.
*
It represents a potential profit of $260 billion assuming production costs of $40/bbl and an oil price of $105.
*
It does not account for what lies on the Canadian side of the border.
Investors must now acclimatise themselves to a new lexicon of names that companies will use to pump up their stock prices - the five Five continuous assessment units (AU) now associated with this news: the Elm Coulee-Billings Nose AU, the Central Basin-Poplar Dome AU, the Nesson-Little Knife Structural AU, the Eastern Expulsion Threshold AU, and the Northwest Expulsion Threshold AU.
And the evidence is in that investors are going big. Saskatchewan is doing a roaring trade in land sales related to the Bakken formation and the Shaunavon oil patch. The best land prices are being fetched on Bakken plays just north of the US border, near the towns of Stoughton and Lampman in Saskatchewan.
You can bet that prices will continue to increase when the next land auction takes place this coming June. And with Montana land owners in Richland County and Fallon County minting a fortune in recent years, you can also bet that rural North Dakota is not going to suffer a real estate crisis for some time. Last year North Dakota saw a 52% increase in the number of wells drilled.
The Great Falls Tribune does a nice job of distilling some of the geology and production basics:
"About two-thirds of the Bakken Formation's acreage is in western North Dakota, where the oil is trapped in a thin layer of porous dolomite rock wedged between two layers of hard shale nearly two miles beneath the surface. The dolomite ranges between 8 and 14 feet thick throughout most of northeastern Montana. Oil companies drill down to this thin layer, then drill horizontal legs several thousand feet long to recover oil from the porous rock. They also use pressurized fluid and sand to break pores in the rock and hold them open while the oil is recovered."
It is estimated that the cost per well is $5 million, which translates into a production cost of up to $50/bbl. Not exactly cheap and it raises the risks for late investors. However, what a bonus for the oil services industry.
I agree.It is impossible to understand that deal so far.My wish is that they cancell it.
What is wrong with Genco?It should be similar price to First Majestic.Where are the cockroaches?I cant see what the problem is.
Genco Reports Results for 2007
Wednesday April 9, 4:26 pm ET
VANCOUVER, BRITISH COLUMBIA--(Marketwire - April 9, 2008) - Genco Resources Ltd. (TSX:GGC - News) today announced results for the financial year ended December 31, 2007. Genco had another successful year reporting an operating profit from its Mexican silver mining operations of $132,618.
The following table contains selected highlights from Genco's consolidated income statement and consolidated balance sheet for the financial years ended December 31, 2007 and December 31, 2006.
------------------------------------------------------------------------
December 31,
2007 2006
---------- ----------
C$ C$
Total revenue 6,212,545 8,568,324
Operating profit 132,618 2,967,581
General & administrative costs (4,085,402) (1,824,602)
Income (loss) before other items (3,952,784) 1,142,979
Other income (expense) (1,785,583) (2,635,371)
Net income (loss) (5,738,367) (1,492,392)
Net income (loss) per-share (0.16) (0.05)
Total assets 46,022,662 22,445,075
------------------------------------------------------------------------
Revenues in 2007 fell as a result of several factors including the mining of lower grade ore as part of the surface test mining program conducted during the first four months of the year, producing fewer silver and gold ounces, a direct result of higher metal prices allowing for a lower cut-off grade. Increased staffing and activities related to Genco's planned mine expansion contributed to the increase in general and administrative costs.
The following table highlights production achievements during the last two fiscal years.
------------------------------------------------------------------------
2007 2006
Tonnes milled 59,342 53,873
Silver equivalent ounces 572,788 777,710
Silver ounces 304,368 532,506
Gold ounces 5,177 4,705
Silver equivalent grade (grams/tonne) 358 501
Average realized silver price (US$) 13.39 11.54
Average realized gold price (US$) 694.39 601.70
Gold$/Silver$ equivalency factor 51.84 52.12
------------------------------------------------------------------------
At La Guitarra Mine, the total tonnes milled increased 10% while average silver equivalent grade fell from 501 grams per tonne ("g/t") in 2006 to 358 g/t in 2007. This drop in grade was a result of several factors including: the surface test mining during the first four months of the year; lower economic cut-off grade; a drop in the average silver grade; and the limited introduction of lower cost underground bulk mining methods allowing for the economic mining of lower grade ores. Genco believes the value of cost and recovery information gained during test mining operations and the introduction of lower cost mining methods compensates for any short term drop in metal production.
Management's commitment to controlling costs in a difficult inflationary environment has continued. The table below summarizes Genco's mining costs in US dollars for the past two financial years on a cost per silver equivalent ounce basis.
--------------------------------------------------------------
2007 2006
(US$) (US$)
Cash operating cost 6.12 5.26
Total cash cost 6.62 5.61
Total production cost 8.36 6.53
--------------------------------------------------------------
Total 2007 production costs were higher than 2006 as lower production costs at La Guitarra Mine were offset by increased third party smelting and refining costs.
During 2007, Genco continued with aggressive exploration and development programs at La Guitarra Mine. Genco remains focused on the completion of a Feasibility Study in mid 2008, significant expansion of La Guitarra Mine and the continued growth of reserves and resources in the Temascaltepec Mining District of Mexico.
See attached balance sheet and income statement for details. Full financial statements are available on SEDAR at http://www.sedar.com and on Genco's website at www.gencoresources.com.
GENCO RESOURCES LTD.
Umm.........is your chart upside down ?
OT.Do your search here
http://www.elitetrader.com/
My guess is that it is not the escalating cost of projects because the escalating cost of oil has that covered.The article posted by Joe projected an oil price of $160 quite soon.
Joe,anyone,care to opine why the Canadian oilsand juniors are not flying?
Well I could tell you but it would be illegal to do it and I have never done it.Honestly.
Can you trust anything you read? The answer is NO. Check. Check. Check. Remember I told you about my friend Michael Marcus who enjoys spoofing the media. On April he issued a fake press release about Panasonic using plasma screens in its cell phones. The press picked up Michael's garbage. This morning Michael emails me:
In Google, type Panasonic plasma, and then click on news, and you should see links for websites around the world who fell for my fake news.
Many of the writers were professional enough to embellish the story with opinions and added information that demonstrated their expertise, but I got only ONE call for verification, and I told him it was a spoof.
There's an unfortunate trend in contemporary journalism, particularly in online journalism, to reporting by repetition and even reporting by robots.
Press releases are "read" by robots, that in turn re-publish them for human beings and other robots to read.
Sometimes human beings do read the press releases, but they do little or none of the traditional fact checking that was once an important part of journalism. In many media outlets, there is an automatic assumption of accuracy and honesty that allows almost anything to get published and widely permeated.
If "news" arrives in the proper format, with authentic language, it is almost always believed and is not likely to be challenged by journalists who are in a hurry to publish faster than their peers.
Bakken oil formation has industry gushing
Bruce Johnstone, Saskatchewan News Network
Published: Monday, December 10, 2007
Saskatchewan could be sitting on 25 billion to 100 billion barrels of sweet, light crude oil in the Bakken formation in the southeast part of the province, according to industry and government estimates.
By comparison, the heavy oil resource in west-central Saskatchewan, which is considered to have great potential for future production, is estimated to be 25 billion barrels of oil in place.
The huge potential of the Bakken play has industry and government officials gushing with superlatives.
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"We're excited about it," said Ed Dancsok of Saskatchewan Energy and Resources. "It's probably the biggest oil find in Saskatchewan since the 1950s."
"The Bakken is the hottest play in Western Canada," said Trent Stangl, manager of marketing and investor relations for Crescent Point Energy Trust of Calgary, one of the top three players in the Bakken in Saskatchewan.
Gregg Smith, vice-president of Canadian operations for Petrobank Energy and Resources, another Calgary company with a large land position in southeastern Saskatchewan, goes one further. "It's fair to say, the Bakken play is the hottest play in North America," Smith said.
What has government and industry observers so excited is the sheer magnitude of the Bakken formation, which is found in the Williston Basin underlying much of North Dakota, eastern Montana, southeastern Saskatchewan and southwestern Manitoba.
The Bakken is a geological formation of siltstone and sandstone about 300 metres below the Mississippian formation, where most Saskatchewan light oil production comes from. Bakken wells tend to be highly productive (200 barrels a day or more), producing sweet, light crude oil with 41 degree gravity, basically the highest grade of crude oil you can find anywhere.
While relatively new in Canada, Bakken exploration has been underway in the U.S. since 2000 and has increased dramatically in recent years. According to the U.S. Geological Survey, the Bakken formation could contain a mind-boggling 413 billion barrels of oil in place.
Exactly how much of that Bakken oil in place is in Saskatchewan is a matter of some conjecture.
Fifteen years ago, the then-department of Energy and Mines estimated there was roughly 100 billion barrels of oil in the Bakken formation throughout the entire Williston Basin.
Dancsok, who co-authored the 1991 study, said the prevailing view in the geoscience community at the time was "the potential of the Bakken was immense, but the price of oil in 1991 was not such that people wanted to risk (exploration and development dollars)."
Dancsok estimated roughly 25 per cent of the Williston Basin, which covers some 200,000 square miles (518,000 square kilometres) is located in Saskatchewan. Based on that simple arithmetic, the estimate of Bakken oil in the province could range anywhere from 25 billion barrels to 100 billion barrels of oil in place.
Of course, geology isn't that simple.
"Whether the Bakken is evenly distributed throughout the basin is one question," Dancsok said. "It is deeper in North Dakota. But is the distribution of Bakken oil equal in Saskatchewan to North Dakota or Montana? That's a big question mark."
Smith says it's difficult to estimate how much oil is in the Bakken formation in Saskatchewan, but suggests that three to four billion barrels of oil could be in place in the area (22 townships) where Petrobank and other companies, like Crescent Point and Tristar, are active.
"This is very much a resource play," Smith said. "There will be other Bakken discoveries. This play will expand."
Romlis if you do visit the prague event I am sure board members would be interested in hearing about anything you learn.Especially if you are able to observe how much interest LTC is getting.
But if you are short of time there maybe you could "front up" at the LTC booth ,tell them you are a shareholder and ask "hows it going?".
We currently do not have sufficient funds to pay our anticipated general operating and corporate expenses for the remainder of the fiscal year and we intent to try to raise funds but there is no assurance that we will be able to raise adequate capital.
Over the remainder of the fiscal year, we plan to raise funds through the sale of our common stock, through loans or convertible debentures. There is no guarantee that we will be successful in arranging the required financing.
Unless we raise funds through the sale of our common stock or through loans, we cannot further explore or develop our properties or pay our anticipated general operating and corporate expenses. There is no assurance that we will be able to raise adequate capital.
Our future success will be materially dependent upon our ability to satisfy additional financing requirements. We are reviewing our options to raise equity capital. It is unlikely that we will begin to realize any revenue in the next twelve months. In order to raise funds, we have held and will continue to conduct negotiations with various investors. We cannot predict whether these negotiations will result in additional investment income for us.
Funding for our operations may not be available under favorable terms, if at all. If adequate funds are not available, we may not be able to continue as a going concern or we may be required to curtail our operations significantly or to obtain funds by entering into arrangements with collaborative partners or others that may require us to relinquish rights that we would not otherwise relinquish.
On or about April 12, 2006, we entered into certain financing transactions with AJW Partners, LLC; AJW Offshore, Ltd.; AJW Qualified Partners, LLC; and New Millennium Capital Partners II, LLC. In connection with those transactions we delivered to those parties certain secured convertible promissory notes. The next interest payments pursuant to those notes are due May 2008. We currently have sufficient funds to pay those interest payments. The secured convertible notes are secured by all of our assets and property. As such, if we default on the secured convertible notes, we could be forced to forfeit all of our assets and property to the noteholders.
On or about January 31, 2008 we exchanged for interest due to New Millennium Capital
Partners II, LLC, AJW Partners, LLC and AJW Master Fund, LTD in the amount of $117,947 Interest Rate debenture notes in the same amount due January 31, 2011 at the rate of 2%. These notes are secured by all of our assets, and are payable quarterly and are
convertible into shares of our common stock at the rate of the Applicable Percentage multiplied by the Market Price which is defined as the average of the lowest three trading prices for the common stock during the 20 day period prior to conversion. The Applicable Percentage is 50%. Any amount of principal or interest on the notes which is not paid when due shall bear interest at 15%.
OUR PLAN OF OPERATIONS FOR NEXT 12 MONTHS
We are an exploration stage company and we do not have any proven or probable reserves on any of our properties.
Arizona Property
We held a 60% interest in the Lucky Boy Prospect, which comprises 14 mineral claims and an 80 acre State Lease located in Gila County, Arizona. Handley Minerals Inc. ("Handley") holds the other 40% interest. The Lucky Boy Prospect is subject to a 3% yellow cake royalty. The Lucky Boy Prospect is situated 13 miles SSW of Globe, Arizona.
On January 29, 2008, we reached an agreement with Rodinia Minerals Inc. ("Rodinia") to dispose of our right to earn an additional 10% for each $100,000 we spent on the Lucky Boy Prospect. By was of this agreement Rodinia also backed-in for 40% interest of our 60% interest in the Lucky Boy Prospect. This leaves us with a total of 36% undivided right, title and interest in and to the Lucky Boy Prospect and gives Rodinia a total acquisition of 24% interest. In consideration, Rodinia agreed to pay the balance of $125,000 owing by us for exploration costs on the project. As part of this agreement, we also received a refund of $9,797 from reclamation bonds and expects the balance of the bonds outstanding, totaling $13,362, to be refunded.
We also hold a 100% interest in an additional 12 lode claims, the Get Lucky Claims, which are located in the same vicinity as the Lucky Boy Prospect. They are also situated 13 miles SSW of Globe, Arizona. We will be exploring for uranium on the Lucky Boy Prospect and the Get Lucky Claims if we commence a work program
In August 2007, we paid $3,250 to the BLM in claims fee to maintain the Lucky Boy Prospect.
We currently do not have the funds to pay for a work program on this property, however Rodinia is obligated to spend $400,000 on the work program while we pay nothing and our interest does not change. Once Rodina spends $400,000 on a work program, then we may enter into a joint venture agreement to continue development the property, at which point we would be responsible for 36% of all exploration and development costs. If we do not come to a contractual agreement with Rodina after they spend $400,000 on a work program, then neither party has the right to perform any further work on the property. Currently, if we do not pay further costs and we will not lose our existing interest, except for $1,170 (which represents out 36% of the total $3,250 in claim fees) for the claim maintenance fees payable to the BLM in August 2008. However if we receive adequate financing we do intend on utilizing them on a work program on the Lucky Boy Prospect. Handley will remain the operator on the property.
A full geological and geochemical report has been prepared and contains the results along with a recommendation for definition drilling which would test to determine the resources of the strike land. The progress report on the geological, radiometric and geochemical investigation and summary of drilling results on the Lucky Boy Prospect also details the results from the Plan of Operations that was completed during the last quarter of 2006. The Plan of Operations included a 25-hole drilling program intended to define economic uranium mineralization. After several months of compiling all the data from various sources it has been determined that a strike length of several hundred feet with a thickness of approximately 5 to 10 feet with intercepted grades of .1% U or greater warrants us to submit a further Plan of Operation to the various state and government agencies for further drilling and to consider small-scale mining. This will include potentially putting the probable and proven
Thanks for that.My Dell 8200 laptop says it has intel inside, otherwise I dont know who made the motherboard.I downloaded AIDA32 but it wouldnt install.I think the message was that microsoft had reserved the space where it wanted to go.Lol.
Can anyone recommend a free program that will display my puters temperature ?
Canada
Please buy our dirty oil
Mar 13th 2008 | OTTAWA
From The Economist print edition
A new American law could limit oil-sands production in Alberta
CANADIANS like to think that although they are the junior partner in their trade relations with the United States, the 174 billion barrels of proven reserves in the oil sands of Alberta provide a powerful ace up their sleeve in any dealings with their energy-hungry neighbour. That belief has now been shaken by an American law that appears to prohibit American government agencies from buying crude produced in the oil sands of the western province.
The Energy Independence and Security Act 2007 did not set out to discriminate against Canada, America's biggest supplier of oil. But that is the effect of banning federal agencies from buying alternative or synthetic fuel, including that from non-conventional sources, if their production and use result in more greenhouse gases than conventional oil. Transforming Alberta's tarry muck into a barrel of oil is an energy-intensive process that produces about three times the emissions of a barrel of conventional light sweet crude.
Having woken belatedly to the danger, the Canadian government is now scrambling to secure an exception. Michael Wilson, Canada's ambassador in Washington, has written to America's secretary of defence, Robert Gates (whose department is a big purchaser of Canadian oil), stressing American dependence on Canadian oil, electricity, natural gas and uranium imports, and noting that some of the biggest players in the Alberta oil patch are American companies. Mr Wilson added plaintively that both George Bush and his energy secretary, Samuel Bodman, have publicly welcomed expanded oil-sands production, given the increased contribution to American energy security.
John Baird, the Canadian environment minister, referred this week to the American move when he unveiled new proposals to reduce industrial emissions in Canada, including the oil sands, by 20% by 2020. Big states like California were making similar pronouncements, he told reporters. The oil sands were an important national resource, but had to be expanded in an environmentally friendly way.
The fear in Canada is that the American purchasing restrictions, which at present apply only to federal agencies, is the start of a wholesale shift to greener as well as more protectionist policies under a Congress and potentially a White House controlled by the Democrats. With energy exports, mainly from Alberta, driving the Canadian economy, this is not a happy thought for Canadians.
Yet environmentalists point out that Canada is now paying for its own foot-dragging at the federal level on green initiatives. Having signed the Kyoto agreement under a previous Liberal government, Canada did little to stop its emissions rising. They are now almost 35% above the Kyoto target. And although Mr Baird likes to describe his plan as tough, it will not bring Canada into line with Kyoto. The rules for the oil sands, now the fastest growing source of greenhouse gases, have yet to be finalised and will not come into force until 2010. Furthermore, they rely on carbon capture, a promising but unproven technology.
The vagueness of the proposed federal rules did not stop the premier of Alberta, Ed Stelmach, from giving a defiant warning that he will stand up for the interests of Albertans (read oil industry) and will be examining the constitution to ensure that the federal government's proposed plan does not intrude on provincial jurisdiction. His province has one of the weakest environmental regimes in Canada.
Although the Canadian embassy says that there has been no official response to Mr Wilson's letter, there are reports of talks going on in Washington aimed at addressing Canada's concerns. But even if a deal is reached with the outgoing Bush administration, any exception for Canada may be short-lived if green-tinged Democrats take the White House in November.
New 'green' oilsands rules costly post 2012
Posted: March 11, 2008, 8:40 AM by David Pett
Energy
Oilsands projects beyond 2012 will likely face higher costs, given new rules announced by the federal government regarding its Green legislation.
UBS analyst Andrew Potter said in a note to clients that the key change to the legislation is that projects on-stream after 2012 will face mandated CO2 Sequestration & Storage (CSS). Mr. Potter added that projects on-stream before 2012 appear unaffected by the recent changes.
CSS would reduce or eliminate investor concerns with oil sands pollution, the analyst wrote. "However, the cost is potentially high,"
For example, he said a mandated 25% intensity reduction accomplished through CSS at a cost of $65 per tonne would imply an incremental $1.50 per barrel in cost. He added any mandated CSS beyond this level would result in significant net asset value (NAV) reduction.
He said investors will likely react negatively to the news but told clients that stock valuations generally reflect no value for projects coming on-stream later than 2009.
"With oil prices remaining well above street forecasts we are still more likely to see oil sands NAV estimates increase substantially over the next year even when incorporating these added costs."
New 'green' oilsands rules costly post 2012
Posted: March 11, 2008, 8:40 AM by David Pett
Energy
Oilsands projects beyond 2012 will likely face higher costs, given new rules announced by the federal government regarding its Green legislation.
UBS analyst Andrew Potter said in a note to clients that the key change to the legislation is that projects on-stream after 2012 will face mandated CO2 Sequestration & Storage (CSS). Mr. Potter added that projects on-stream before 2012 appear unaffected by the recent changes.
CSS would reduce or eliminate investor concerns with oil sands pollution, the analyst wrote. "However, the cost is potentially high,"
For example, he said a mandated 25% intensity reduction accomplished through CSS at a cost of $65 per tonne would imply an incremental $1.50 per barrel in cost. He added any mandated CSS beyond this level would result in significant net asset value (NAV) reduction.
He said investors will likely react negatively to the news but told clients that stock valuations generally reflect no value for projects coming on-stream later than 2009.
"With oil prices remaining well above street forecasts we are still more likely to see oil sands NAV estimates increase substantially over the next year even when incorporating these added costs."
Is this what is crippling oilsands prices?
Tough new green plan targets oil sands
Regulations, which also apply to coal-fired power plants, would force future projects to store greenhouse-gas emissions underground
BRIAN LAGHI
Monday, March 10, 2008
OTTAWA — Ottawa will unveil new climate-change regulations this week that would force new oil sands projects and coal-fired electricity plants to capture and store the bulk of their greenhouse gases rather than spew them into the air.
The new rules are part of Environment Minister John Baird's plan to regulate 17 key industrial sectors, which include manufacturers of pulp and paper, cement and chemicals, as well as producers of mineral products like steel, aluminum and iron ore, among others.
“There's no doubt we're asking a lot of industry and a lot of Canadians but we believe Canadians are up to the challenge,” Mr. Baird said Sunday.
Mr. Baird said Canada cannot meet its targets of reducing greenhouse gases if it does not compel capture and storage of the substances in the two key industries of coal-fired electricity and oil sands. Oil sands production alone is expected to create 25 per cent of Canada's carbon-dioxide emissions by 2020, up from the current level of about 18 per cent.
“There's just no future for dirty coal,” said Mr. Baird. “... The second big issue is the oil sands and we will not be able to make our targets for 2050, let alone 2020, unless we mandate carbon capture and storage of all the oil sands projects.”
Oh be still my beating heart!
I am a bag holder with this one.
Yes I think that is what it means.So that guy has a clue about something that might possibly develop but we have no way to find out what people like him are thinking.I am thinking they know something we dont.
How much $ does POGI get for those 2.5mil shares?
Oh sure.Its easy to get insider info.Just pick up the phone.
The suspense is killing me.Something is happening with this one but no one knows anything.
Nordic Oil and Gas Acquires Four Well Bores in Lloydminster; Expects to Have Wells on Production Soon
Thursday March 6, 11:35 am ET
WINNIPEG, March 6 /CNW/ - Donald Benson, Chairman and Chief Executive Officer of Nordic Oil and Gas Ltd. ("Nordic" or, the "Company"), today announced that the Company has acquired four well bores located on leases on its lands in Lloydminster, Alberta. The well bores were about to be abandoned as the vendor had lost the mineral rights to the properties.
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The Company plans to install pumps and tanks at each well bore location and will do everything in its power to have these wells on production over the next 30 to 60 days. Of particular note is the fact that the wells were drilled over the past 10 years or so.
"Another operator, who owns land adjoining ours, followed a similar approach to what we are undertaking, and today those lands are producing 80 barrels of oil per day from those well bores," Mr. Benson stated.
Furthermore, the acquisition of these wells bores by Nordic will result in the Company saving in the area of $750,000 to $800,000 - the cost that would be associated with the drilling of four new wells in Lloydminster.
In addition, the Company is also currently in the midst of surveying four other locations in Lloydminster with the intent of commencing drilling as soon as possible. When completed, the Company anticipates that it will then have eight wells on production in Lloydminster.
In other news, Mr. Benson also stated today several photos of the Company's recently acquired compression facility at Joffre, Alberta are being added to the Nordic website - www.nordicoilandgas.com.
About Nordic Oil and Gas Ltd.
Nordic Oil and Gas Ltd. is a junior oil and gas company engaged in the exploration and development of oil, natural gas and Coal Bed Methane in Alberta and Saskatchewan. The Corporation is listed on the TSX Venture Exchange and trades under the symbol NOG.
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8 Kilos Silver per Tonne at Urique
By Darryl Kelley
Feb, 28th
Yale Resources Ltd (YLL TSX.V) has recently announced the discovery of a new mineralized zone at their Urique Project, a 29,000 hectare property in Sierra Madre gold belt in Mexico.
This most recently identified zone, El Rosario, is located east of the town of Urique and comprises multiple historic mines and prospects that exploited a system of high grade veins. Formal mining of this area ended in the late 1920's and consisted of several hundred metres of underground workings on three levels. These historic workings are all within a zone of strongly silicified andesite host rocks that measures approximately 100 metres wide and over 400 metres long. The zone is open at depth and along strike sampling has yielded significant values of as much as 10.6 g/t gold and 8,290.0 g/t (or 241.5 ounces per ton) silver from 10-40 centimetre wide veins. There were also two veins that returned assays greater than 3,000 g/t silver and a half dozen other veins grading greater than 1,000 g/t silver. And there are more that went unsampled. Of note for the technical types is that these veins consistently have elevated gold grades, which is significant as several mineralizing systems in the district that have similar gold grades at surface have been proven to have better continuity at depth. Sampling within the altered andesite has yielded gold and silver values of as much as 0.2 to 0.3 g/t gold and 5.0 to 41.0 g/t silver suggesting that the El Rosario area has the potential to host a bulk tonnage open pittable resource.
“What we’ve identified there now is a target that’s over 400 m long and 100 m wide. We’re dealing with silicified andesites in which we see discrete veins coming up through it, you’ve got stringers, stockwork, and some of the sampling of the individual veins are yielding up to 8 kilos per tonne of silver. We’re getting some shockingly high values”, said Mr. Foreman, P.Geo., president of Yale Resources.
Numerous plus-one million ounce gold deposits have been discovered in this 300 km long region of southwestern Chihuahua: including Mulatos (Alamos Gold), Dolores (Minefinders), Ocampo (Gammon Lake), as well as the El Sauzal mine (Goldcorp). The Urique Project is located only 10 km from the El Sauzal mine.
The El Sauzal mine entered production in 2004 and was scheduled to produce 170,000 ounces in 2005. As of Dec. 31, 2005, the mine has proven and probable reserves of 15,821,000 tonnes grading 3.29 g/t gold (for a total of 1,673,000 ounces) and measured and indicated resources of 20,529,000 tonnes grading 2.73 g/t gold (for a total of 1,802,000 ounces)
As if having a successful exploration program in a district scale project isn’t enough, Yale is also building an asset at it’s wholly owned La Verde Project in Sonora.
Having just returned from a field trip to the La Verde Grande mine, the crown jewel in Yale’s La Verde project, Mr. Foreman showed us pictures of management team members underground in the old workings. Oxidized copper on the surfaces of the adit imparts a blue-green tinge to the ambient light generated from the flash. The walls are literally covered from top to bottom with copper oxidization.
“They were mining high grade copper from here”, explains Mr. Foreman. “This was being mined in the early 1900’s. They were hand sorting high grade ore that they were chasing. And I’m confident that they only exploited a small portion of the deposit”
Yale recently announced an addition to its La Verde project - the La Cobriza claim. "This ground is a very important addition to the La Verde Project as there are several geological and structural trends that have been identified that cross the La Cobriza property,” said Mr. Foreman. “Yale now has control over all of the significant known mineralization in the vicinity of the La Verde Grande Mine and we will be able to fully take advantage of having unencumbered access to test the multi-million tonne potential of the property."
A sampling program by the Consejo de Recursos Minerales on La Cobriza in 1982 showed that there is skarn mineralization irregularly distributed over a strike length greater than 500 metres. Twenty five widely spaced chip channel samples from the various historic workings throughout this area ranged from 0.28 to 5.45 % copper, 0.15 to 8.60 % zinc, 3.90 to 578.00 g/t silver and 0.1 to 11.1 g/t gold (note: these samples are included for reference only as they are historical in nature due to them being collected before the creation of NI 43-101).
“So we’re advancing well on all fronts,” Mr. Foreman concluded. “We’ll see trenching and sample results from the Carol property, which are visually interesting, I’m told; drilling at Urique; and we’re looking forward to results of sampling at La Cobriza and elsewhere at La Verde. So we have lots of news coming.”
You can learn more about Yale Resources at their web site at http://www.yaleresources.com.
ScienceDaily (Jan. 21, 2008) — Natural gas distributed throughout the Marcellus black shale in northern Appalachia could conservatively boost proven U.S. reserves by trillions of cubic feet if gas production companies employ horizontal drilling techniques, according to a Penn State and State University of New York, Fredonia, team.
"The value of this science could increment the net worth of U.S. energy resources by a trillion dollars, plus or minus billions," says Terry Engelder, professor of geosciences, at Penn State.
The Marcellus shale runs from the southern tier of New York, through the western portion of Pennsylvania into the eastern half of Ohio and through West Virginia. In Pennsylvania, the formation extends from the Appalachian plateau into the western valley and ridge. This area has produced natural gas for years, but the Marcellus shale, a deep layer of rock, is officially identified as holding a relatively small amount of proven or potential reserves. However, many gas production companies are now interested in the Marcellus.
Engelder, working with Gary Lash, professor of geoscience, SUNY Fredonia, has conservatively estimated that the Marcellus shale contains 168 trillion cubic feet of natural gas in place and optimistically suggests that the amounts could be as high as 516 trillion cubic feet.
"Conservatively, we generally only consider 10 percent of gas in place as a potential resource," says Engelder. "The key, of course, is that the Marcellus is more easily produced by horizontal drilling across fractures, and until recently, gas production companies seemed unaware of the presence of the natural fractures necessary for magnifying the success of horizontal drilling in the Marcellus."
The U.S. currently produces roughly 30 trillion cubic feet of gas a year, and these numbers are dropping. According to Engelder, the technology exists to recover 50 trillion cubic feet of gas from the Marcellus, thus keeping the U.S. production up. If this recovery is realized, the Marcellus reservoir would be considered a Super Giant gas field.
Engelder, who has studied this area of the U.S. for most of his career and began looking into fractures under a National Science Foundation grant 25 years ago, has identified and mapped natural fractures in the Marcellus shale. He and Lash will present some of their recent work at the 2008 American Association of Petroleum Geologists Annual Convention and Exhibition this spring.
The researchers look at the patterns of fractures in the shale and determine which are important for gas production. Fractures that correlate with the folding of the ridge and valley system are less common in black shale. However, because of their orientation, the fractures that formed prior to the folding will release gas if the wells cross the fracture zones.
These fractures, referred to as J1 fractures by Engelder and Lash, run as slices from the northeast to the southwest in the Marcellus shale and are fairly close together. While a vertical well may cross one of these fractures and other less productive fractures, a horizontally drilled well aimed to the north northwest will cross a series of very productive J1 fractures.
"It takes $800,000 to drill a vertical well in the Marcellus, but it takes $3 million to drill a horizontal well," says Engelder.
Companies that drill gas wells need to be certain that horizontal drilling will produce the gas they expect and the work by Engelder and Lash suggests that it will.
"We know that the Marcellus shale appears as an outcrop near Batavia, N.Y., east of Buffalo," says Engelder. "And we can see the fractures in the Marcellus in the exposed sections of the ridge and valley areas to the southeast. Because we see them going through the folded areas, we know they were there before the folding. If it happened earlier, then we know they have to be in the intervening basin as well."
The natural fractures in the Marcellus shale are the key to recovering large amounts of gas. As heavily organic sediments were laid down 365 million years ago, the black shale of the Marcellus formed. As the organic material decayed and degraded, methane and other components of natural gas formed and dispersed through the pores in the rock. About 300 million years ago, the pressure of the gas caused fractures to form in the shale. It was not until 280 million years ago that the eastern portion of Pennsylvania was pushed into the folding of the ridge and valley province that makes up that area. Gas that occurs in pockets underground is considered a conventional reservoir; gas that is distributed throughout the rock, like the Marcellus, is called an unconventional reservoir.
The Penn State-Fredonia approach is not restricted to production of the Marcellus shale, but can be applied to any gas-bearing shale with this type of fracture. Because the approach begins with a vertical well and then drills horizontally in the direction that will crosscut the productive fractures, old vertical wells can be reused.
"We can go back to wells that are already drilled and played out, and then drill horizontal from there," says Engelder. "Reusing old wells has both economic and environmental value."
Engelder and Lash are principals in Appalachian Fracture Systems Inc., a consulting firm.
Adapted from mate
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