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To: Crocodile who wrote (9128)2/19/1998 9:26:00 AM
From: Kerm Yerman  Respond to of 15196
 
MARKET ACTIVITY/TRADING NOTES FOR DAY ENDING WEDNESDAY, FEBRUARY 18, 1998 (2)

TOP STORY

Shortage Looms in Worldwide Oil Supplies

Experts Say Production of Conventional Oil Will Decline Within 10 Years; Reported Growth in Oil Reserves Since 1980 is "Illusion"


Contrary to most oil industry forecasts, global production of conventional oil will most likely begin to decline within ten years, possibly resulting in radical increases in oil prices, according to an article published in the March issue of Scientific American.

The authors, respected geologists and oil industry consultants Colin J. Campbell and Jean H. Laherrere, explain why the flow of conventional oil -- the cheap, easily recovered crude that currently supplies about 95 percent of the world demand for oil -- will peak and then drop off permanently before 2010. Unless demand for oil falls or substitutes are found, the industrial world's dependence on Middle Eastern oil will again increase dramatically. That could lead to price shocks similar to those seen in the 1970s, the authors warn.

This provocative article leads off Scientific American's 19-page special report on oil production and technology, ''Preventing the Next Oil Crunch.'' As the report makes clear, the world is not on the verge of running out of oil altogether. By a variety of technologies detailed here, it is possible to tap unconventional sources for oil that have traditionally been ignored as too costly or difficult to reach. The challenge is whether those technologies can be developed in time to prevent a crisis from the decline of conventional oil.

According to Campbell and Laherrere's analysis, the oil industry has already discovered about 90 percent of the roughly 1.8 trillion barrels of conventional oil that the earth contained. Almost half that endowment is now gone, and geological constraints will soon force production to slow, even as the demand for oil continues to rise rapidly.

Campbell and Laherrere have each worked in the oil industry for more than 40 years. Campbell served as chief geologist for Ecuador with Amoco, while Laherrere supervised exploration techniques worldwide for the French oil company Total. Both men are currently associated with Petroconsultants in Geneva.

Their article points out numerous flaws in the statistics usually used to track oil reserves. According to most industry reports, world oil reserves have marched steadily upward over the past 20 years and will continue to do so. Even the U.S. Energy Information Administration has projected that oil production will continue to rise unhindered for decades, increasing by nearly two-thirds by 2020.

Such growth is an illusion produced by inconsistent definitions of reserves, by improper accounting of revised estimates, and by suspiciously large reserve increases reported by OPEC member nations in the late 1980s, the authors contend. Among their findings:

Countries of the former Soviet Union often report wildly optimistic estimates of ''proved'' reserves that are only ten percent likely to be met. Subsequent official accounts of world reserves often fail to correct such inconsistencies.

Revisions in oilfield estimates are commonly treated as though they were newly discovered fields, rather than as mere corrections. If revisions are properly backdated to the year in which the oil field was actually discovered, the true trend becomes visible.

Oil companies have drained more oil than they discovered during each of the past 20 years.

About 80 percent of the oil produced today flows from fields that were found before 1973, the great majority of which are declining.

Why aren't the oil industry and governments more alarmed about this situation?

Many observers pin hopes on expected technological advances. Also, economists point out that the world contains enormous caches of unconventional oil -- heavy oil in Venezuela and tar sands and shale deposits in Canada and Russia -- that can substitute for conventional oil. But the authors think that the industry will be ''hard- pressed for time and money need to ramp up production of unconventional oil quickly enough.''

However, Campbell and Laherrere say that with substantial preparation, the transition to the post-oil economy need not be traumatic. ''Safer nuclear power, cheaper renewable energy and oil conservation programs could all help postpone the inevitable decline of conventional oil,'' they write. They suggest that if advanced methods of producing liquid fuels from natural gas can be made profitable and scaled up quickly, gas could become the next source of transportation fuels -- a prospect that is also explored in the magazine's special report.

Other articles in Scientific American's special report on oil production and technology include a survey of the methods now used to extract oil trapped in Canadian oil sands, as well as innovations in underground imaging, steerable drills and deep water oil production.

Scientific American reaches more than three million globally by subscription, on newsstands, and on the Web at www.sciam.com. Published in New York City by Scientific American, Inc., the magazine won the 1997 National Magazine Award for Single Topic Issue.

FEATURE STORY

Here's an interesting article that one may want to keep abreast of.

WAITING FOR FUNDING
Proflex Pipe Corp. Plans $12 Million, 260-Job Plant

Edmonton Sun

Edmonton-based ProFlex Pipe Corp. said yesterday it's planning to build a $12-million manufacturing plant in Alberta, creating 260 jobs.

But it won't pick a location or start digging until funding is secured.

"There is a billion-dollar market for our product in North America, and we want a healthy share of it," said ProFlex president Don Wolfe, in a release.

The Edmonton-based company makes a flexible composite pipe for the oil and gas sector.

The patented pipe is in demand because, unlike steel, it is corrosion resistant and is flexible enough to be wound onto a big reel for transportation, the company said.

"This is the pressure pipe for the 21st century," said Wolfe.

"We project that within 10 years, flexible, continuous pipe made from composites and plastics will replace at least 30% of the steel pipelines used in the oil industry."

To date, ProFlex has installed its product - made at a small test facility - in over 300 locations for about 30 oil producers throughout Western Canada since 1994, "without a single failure," the release said.

The company's next step is to raise the money for the proposed plant. The six-year-old company, which has 40 shareholders, also plans to go public in the near future, the release says. Wolfe couldn't be reached for comment yesterday.

FEATURE STORY

Alberta Energy's Thrust In '98: Gas, Gas and Gas

The Financial Post

Alberta Energy Co. Ltd.'s strategy to grow by the drill bit paid off last year as the company said yesterday its earnings soared to $200 million ($1.73 a fully diluted share) from $68 million in 1996 (65›).

When non-recurring items are excluded for both years, earnings jumped 81% - to $96 million - from $53 million.

"In challenging times, relative strengths become more evident and more important," said president and chief executive Gwyn Morgan.

"Our large, concentrated land and reserve base enable us to dominate in our operating areas. AEC will continue to own a large interest in Syncrude. We also have a unique growing midstream business."

Cash flow from operations was $544.7 million for the year, up from $411.9 million.

Revenue (net of royalties) was $1.72 billion, up from $1.12 billion in 1996.

Last year's net earnings include proceeds from the spinoff through an initial public offering of AEC Pipelines LP, and adjustments to the value of pipelines and international assets. Combined, they contributed $104 million.

Net earnings for 1996 included a $15-million non-recurring gain from selling AEC's forest products business.

AEC has outlined an $800-million capital spending program for this year. Half has been earmarked for natural gas exploration, production, storage and transportation.

"We expect natural gas prices to recover more rapidly than oil prices," as additional pipeline capacity opens a continental energy market for Canadian producers, Morgan said.

"Our growth thrust for 1998 and 1999 will be gas, gas and gas."

The company estimates its cash flow increases $22 million for every 10› increase in the price of a thousand cubic feet of gas.

AEC produced 575 million cubic feet of natural gas daily in 1997, up from 515 million in 1996. Oil and liquids production was 58,940 barrels daily, up from 53,155 b/d.

Its successful exploration program resulted in conventional reserve additions of 1.2 trillion cubic feet equivalent in 1997. Reserve additions were 682 billion cubic feet equivalent in 1996.

FEATURE STORY

Rigel Energy Asset Sale Trims Output

The Financial Post

An asset sale by Rigel Energy Corp. produced a pretax writedown of $37.8 million, pulled it into the red and dragged down its 1997 oil production, the company said yesterday.

It lost $23.9 million (43› a share) on net revenue of $215.3 million after taking a hit on the sale of properties in southwestern Saskatchewan. In 1996, it earned $2.4 million (4›) on revenue of $211.9 million.

Cash flow for the year was $133 million ($2.36), down marginally from $134.7 million ($2.40) in 1996.

The writedown hurt fourth-quarter earnings, which plunged to a loss of $26.1 million (46›) on revenue of $65.9 million, compared with profit of $2.5 million (4›) from revenue of $56.1 million in the year-ago period. Cash flow improved 13.5% to $40.1 million (71›).

Finding and onstream costs were $10.48 a barrel of oil equivalent.

Aliza Fan, an analyst with John Herold Inc. in Stamford, Conn., said those costs were above expectations for the industry of $6 to $8 a BOE. She said Rigel has good properties and interesting exploration plays that might make it attractive to producers looking for an acquisition.

The potential of the firm's North Sea play north of Scotland is one reason for David Stenason's "buy" recommendation. The analyst at Gordon Capital Corp. in Montreal has a 12-month target of $14.

"If they come in with a big discovery in the North Sea, it could make their finding and development costs come way down in 1998," he said.



To: Crocodile who wrote (9128)2/19/1998 9:36:00 AM
From: Kerm Yerman  Respond to of 15196
 
MARKET ACTIVITY/TRADING NOTES FOR DAY ENDING WEDNESDAY, FEBRUARY 18, 1998 (3)

FEATURE STORY

Husky To Take Over Saskatchewan Upgrader
Province Selling Stake In Lloydminster

The Globe & Mail

Saskatchewan Premier Roy Romanow will announce today that Calgary-based Husky Oil Ltd. will become the sole owner of the $1.6-billion Lloydminster heavy oil upgrader, which is currently equally owned by Husky and the NDP government.

Mr. Romanow will appear this morning at a news conference in Saskatoon with Husky chief executive officer John Lau to reveal that the Saskatchewan government is selling its 50-per-cent stake to Husky, government sources said yesterday.

The upgrader, which transforms molasses-like heavy oil into synthetic light crude, is one of numerous Husky properties in the Lloydminster region, which straddles the Alberta-Saskatchewan border.

Dwain Lingenfelter, Saskatchewan's cabinet minister in charge of Crown Investments Corp., is also scheduled to take part in today's announcement.

Husky, controlled by Hong Kong billionaire Li Ka-shing, has switched into expansion mode after staging a financial turnaround across its various holdings, including the upgrader.

Progressive Conservative governments in Ottawa, Alberta and Saskatchewan announced the Lloydminster plant's construction with Husky shortly before the 1988 federal election.

Ottawa and Alberta walked away from the controversial upgrader in 1994.

Prime Minister Jean Chr‚tien's Liberal government inherited the project and went on to write off $516-million of Ottawa's $558-million investment.

Alberta took a hit of $391-million on its $423-million of project funding, leaving it, like Ottawa, with about 8 cents on the dollar.

However, Saskatchewan decided to stick with the upgrader for at least a few years and valued the megaproject on its books at $204-million, or more than 60 per cent of its $333-million investment.

One NDP government source in Regina said the Saskatchewan government will be receiving considerably more than book value for its 50-per-cent stake.

The Romanow administration began studying the advantages and disadvantages of selling its stake in the upgrader a year ago.

A widespread provincial program of fiscal restraint had prompted the Romanow government to take steps to unload its interest in the megaproject.

Opened in late 1992, the upgrader cost $1.6-billion to build as it soaked up more than $1-billion in subsidies from three governments.

But the project began turning things around in 1996, when it posted an estimated $16-million profit.

Profit last year and in recent months will be much larger than before as heavy oil prices have fallen about 45 per cent in the past four months, industry observers have said.

The move by privately owned Husky to take over the Lloydminster plant is part of the company's ambitious plans to boost its Canadian presence.

Husky is controlled by Hutchison Whampoa Ltd. and the Li family. Hutchison Whampoa, a Hong Kong-based publicly traded company whose major shareholder is the Li family, owns 49 per cent of Husky.

Mr. Li -- one of Hong Kong's most powerful businessmen -- and his family own another 46 per cent of Husky, while Canadian Imperial Bank of Commerce holds a 5-per-cent stake.

FEATURE STORY

Oil Industry Defends Its Retail Pricing

The Financial Post

Consumers will pay more for gasoline if governments impose pricing laws, the Canadian Petroleum Products Institute said yesterday.

The group said "political initiatives" that could lead to regulated retail prices are being looked at in Quebec, New Brunswick and at the federal level. The moves are in response to recurring complaints about price gouging and big companies "conspiring" to drive smaller retailers out of business.

"An open, fair, competitive market works in the best interest of the consumer," said Brendan Hawley, vice-president of public affairs for the group, which represents Canada's integrated oil companies and large independent marketers.

A recent study by Calgary-based consultant Michael Ervin said average pump prices have been in a long-term decline. The study, funded by the industry and Ottawa, found prices fell 4› a litre, excluding taxes, between 1986 and 1995, or by 10› a litre in inflation-adjusted dollars.

The average gas station in Toronto pumps more than five million litres a year and needs a margin of 3› a litre, the study found. In smaller markets, gas stations sell fewer than one million litres a year, requiring a margin of 12›.

"Consistently, there is an inverse relationship between the pump price and the outlet volume. The more you sell, the cheaper the gas," Ervin said.

Gasoline retailers are only now earning respectable returns, after years of restructuring that reduced the number of gas stations, refineries and overall costs by $2.5 billion, said Hawley.

Last year, Canada's four integrated oil companies reported record results from refining and marketing because of strong demand. They are also reaping the benefits of expanding revenue from car washes and convenience stores.

"We have taken a lot of cost out of the system. Consumers have benefitted from that," Hawley said.

OIL & GAS REVIEW

NYMEX

Crude Oil


Crude oil futures rose sharply Wednesday, recovering losses made a day earlier on the New York Mercantile Exchange, on market talk Saudi Arabia may propose that it and fellow OPEC countries cut daily output in a move to boost prices that have fallen to four-year lows.

March light sweet crude oil settled up $0.59 to $16.25.

Saudi Arabia's oil minister, Ali bin Irahim al-Naimi, said that country, the largest exporting member of the Organization of Petroleum Exporting Countries, was "deeply worried" about falling oil prices and urged all producers to coordinate efforts to halt the decline. Oil prices have fallen nearly 20 percent, to the lowest since April 1994, since November.

Futures prices rose further on unconfirmed reports the Saudis were considering seeking a cut in OPEC quotas if widespread cheating by other members is reduced. OPEC on Jan. 1 boosted daily output by nearly 10% at a time when many of its members were already cheating by well exceeding their quotas and as Asian nations that had seen growing demand fell deeper into the grips of economic problems.

Natural Gas

Natural gas futures, boosted by strong technical buying, ended up sharply Wednesday in an active session, then on ACCESS traded on either side of unchanged after neutral weekly inventory data.

March jumped 7.2 cents to close at $2.238 per million British thermal units, then on ACCESS traded betweem $2.22 and $2.249 shortly after the AGA report. April settled 7.6 cents higher at $2.283. Other months ended up by 3.2 to 6.5 cents.

"The AGAs were definitely neutral, but there's still no weather ahead, and the year-on-year surplus is bearish," said one East Coast trader, noting stocks were well-above last year.

AGA said Wednesday that U.S. gas stocks fell last week by 93 bcf, about in line with Reuter poll estimates in the 95-100 bcf range. Overall stocks climbed to 298 bcf, or 26 percent, over year-ago levels.

Most agreed today's rally was primarily technical, noting March tested and held support in the $2.15 area three times in two days.

But even those who viewed as bearish the growing stock surplus and mild weather questioned how cash could still be holding 15 cents over index if fundamentals were so negative.

Forecasts still call for mostly above-normal U.S. temperatures into next week, with levels in the Midwest climbing to as much as 25 degrees F above normal for the period. Eastern temperatures should average between normal to 15 degrees F above normal into next week.

Chart traders agreed there was decent March support in the $2.15 area. A close below that level would likely lead to a test of next support in the $2.03 area.

Key resistance was seen at the $2.32-2.35 gap. Above the gap, major selling should emerge at the prominent high of $2.435 and then in the $2.50 area. In the cash Wednesday, Gulf Coast quotes were little changed in the mid-teens. Midcon pipes also held fairly steady in the $2.06-2.11 range. Traders said a big buyer at the Chicago city-gate helped muscle prices there into the low-$2.20s, up several cents on the day. New York was flat on the day in the high-$2.30s.

The NYMEX 12-month Henry Hub strip rose 5.5 cents to $2.409. NYMEX said an estimated 62,934 Hub contracts traded, up sharply from Tuesday's revised tally of 41,147.

CANADA SPOT GAS

Canadian spot natural gas prices remained steady in Alberta on Wednesday as storage withdrawals continued at low volumes amid fears over next year's supply, traders said.

"People are concerned over supply for the November '98 gas year," a Calgary-based marketer said. "Nobody's selling their storage positions -- only about 500 (million cubic feet) a day has come out (of Alberta facilities) over the past few days."

He noted a general concern in Alberta that producers would be hard pressed to pump enough supply to fill 1.1 billion cubic feet a day of new pipeline capacity out of the province coming on stream in November and, at the same time, arrest production declines.

Spot gas at the AECO storage hub in Alberta was discussed at C$1.61/1.63 per gigajoule, up about a cent from Tuesday and down about four cents from last week. March and March-October terms were quoted in the C$1.64/1.67 range, giving storage holders little impetus to sell their positions into the spot market.

Prices in Alberta were remaining strong despite continued warm temperatures in the region.

At the borders, spot gas at the Huntingdon, British Columbia-Sumas, Wash. export point were talked at about US$1.20 per million British thermal units, unchanged from Tuesday and last Wednesday.

In the east, Niagara gas was quoted in the low US$2.30s, about even with Tuesday and down about three cents from last week.

U.S. SPOT GAS

U.S. spot natural gas prices, shrugging off storage concerns and revised forecasts for more mild weather, mostly stayed little changed Wednesday in moderate trade, underpinned by decent gains in NYMEX futures.

"The cash was down early, then chased NYMEX higher," said one Midwest trader.

But with the year-on-year stock surplus again likely to grow after tonight's weekly inventory report and no cold weather on the horizon, few saw much more upside near-term.

Swing gas at Henry Hub, the NYMEX delivery point in Louisiana, was quoted today between $2.15 and $2.22 per mmBtu, with most deals done in the $2.20 area, up one cent on the day and still about 15 cents over index.

Forecasts still call for mostly above-normal U.S. temperatures into next week, with levels in the Midwest climbing to as much as 25 degrees F above normal for the period. Eastern temperatures should average between normal to 15 degrees F above normal into next week.

A Reuters poll showed most expected a weekly AGA stock draw in the 95-100 bcf range when the data are released later today. For the same week last year, stocks declined 147 bcf, meaning a draw today in the expected range would increase the year-on-year surplus to about 280 bcf.

In the Midcontinent, prices held fairly steady in the $2.06-2.11 area, about 15 cents over Feb indices. But a big buyer at the Chicago city-gate helped muscle prices there into the low-$2.20s, up several cents on the day.

South Texas gas, helped by firmer western prices, firmed a penny to $2.06-2.11. West Texas gas on El Paso Permian gained four or five cents to the $2.05 area.

In the East, New York city gate prices were unchanged in the high-$2.30s, while Appalachian prices on Columbia eased slightly but were still in the mid-to-high $2.20s.



To: Crocodile who wrote (9128)2/19/1998 10:15:00 AM
From: Kerm Yerman  Respond to of 15196
 
MARKET ACTIVITY/TRADING NOTES FOR DAY ENDING WEDNESDAY, FEBRUARY 18, 1998 (4)

COMMENTARY

Crude Oil


Sustained low prices?? That appears to be the case. NYMEX crude oil has settled in to a narrow trading range of $15.50-$16.50, with no major price rise in the near future. The Iraq situation has not scared the market, warm North American weather is expected to impact prices further, and the impact of Asia is yet to be seen (but is certainly not a bullish unknown). The technical picture is still negative in both the short term and medium term, with no signs of a near term change in trend. Buyers should be doing all they can to lock in prices at these levels. Sellers should be looking at curve lock related products (to lock in the contango in the forward curve).

Natural Gas

The technicals were correct again! It would appear that most of the recent run up in prices (into the $2.40's) was due to short covering and profit taking. Longer term (3-5 years), there is concern that reserves will not be replaced and at that time we could see $3-$4 ga once again. But even taking into account increased volatility due to increased commodity fund activity. in the near term $1.75-$2.50 seems appropriate.

Alberta prices have soften from their recent highs, with near term prices expected to remain quite firm. Concern over the lack of field receipts remains a bullish factor, and if we continue to see big draws from storage, prices could see a further $0.15-0.20 of gains. Lack of field receipts has been impacting prices more than the effects of warmer than normal weather in the province.

OIL & GAS REFERENCES

Charts


oilworld.com

oilworld.com

NYMEX Reference:

quotewatch.com

MARKET ACTIVITY

INDEXES


The Toronto Stock Exchange 300 Composite Index slipped 0.2% or 16.25 to 6944.21. Can't blame the shortcoming on the oil groups yesterday. They didn't perform well, but was in line with the 300. The Oil & Gas Composite Index also slipped 0.2% or 14.33 to 6221.85. The sub-components were mixed. The Integrated Oils gained 0.3% or 29.73 to 8895.24. The Oil & Gas Producers fell 0.3% or 17.21 to 5392.95. The Oil & Gas Services Index was again hit hard, falling 1.7% or 45.92 to 2661.26. It doesn't seem to far back in time when the TSE 300 & O&G Composite were neck to neck. The now 600+ spread between the two is discouraging

INDEX CHARTS

TSE 300.......... canoe.quote.com

O&G Composite. chart.canada-stockwatch.com

Integrated Oil's.... chart.canada-stockwatch.com

O&G Producers.. chart.canada-stockwatch.com

O&G Services..... chart.canada-stockwatch.com

NEW PHLX OIL SERVICE SECTOR

bigcharts.com.

lonestar.texas.net

MOST ACTIVES

Kerms Top21, Spec15, Serv9 companies are in bold print

Gentry Resources, Canadian Natural Resources, Talisman Energy, Petro-Canada, Anderson Exploration, Gulf Canada Resources, Alberta Energy, Tarragon Oil & Gas, Ranger Oil, Northrock Resources, Poco Petreoleums and Renaissance Energy were among the top 50 most active traded issues on the TSE.

Net gainers included Seven Seas Petroleum (U) $1.90 to $27.40, Crestar Energy $1.75 to $21.25 and Pioneer Natural Resources Canada $1.50 to $32.00.

Percentage gainers included Black Rock Ventures 14.3% to $1.20, TriGas Exploration 13.8% to $3.30, Crestar Energy 9.0% to $21.25, Seven Seas Petroleum (U) 7.5% to $27.40, Pan East Petroleum 6.7% to $1.60, Newstar Energy 6.5% to $4.25 and Windsor Energy 5.5% to $5.80.

On the downside, Remington Energy fell $1.40 to $15.35, Chieftain International $1.00 to $31.00, Denbury Resources $0.90 to $25.25, Ulster Petroleums $0.70 to $11.50, Tarragon Oil & Gas $0.60 to $8.60 and Kappa Energy $0.53 to $1.77.

Percentage losers included Kappa Energy 23.0% to $1.77, Neutrino Resources 11.2% to $1.35, Westfort Energy 10.8% to $1.41, Rider Resources 9.8% to $3.61, Profco Resources 8.7% to $0.95, Remington Energy 8.4% to $15.35, Richland Petroleum 8.1% to $3.40, Black Sea Energy 7.4% to $1.25, Tarragon Oil & Gas 6.5% to $8.60, Bellator Exploration 5.8% to $1.30, United TriStar 5.8% to $0.98, Ulster Petroleums 5.7% to $11.50, Founders Energy 5.7% to $0.99 and Abacan Resources 5.4% to $2.82.

No new 52-week highs

Bow Valley Energy, Founders Energy, Kappa Energy, Remington Energy, Southward Energy and Tarragon Oil & Gas reached new 52-week lows.

There were no service companies among the top 50 mst active traded issues on the TSE.

Service companies were absent from the listing of top net gainers and percentage gainers.

On the downside, Ensign Resource Service fell $1.70 to $27.55, American Eco $0.65 to $16.50, Tesco $0.65 to $19.45 and Canadian Fracmaster $0.50 to $18.50.

Percentage losers included Ensign Resource Service, down5.8%.

There were no new 52-week highs.

Anadime Corp. reached a new 52-week low.

Over on the Alberta Stock Exchange Raptor Capital, Doreal Energy, HEGCO Canada, AltaPacific Capital, Bearcat Exploration, Rock Capital, Hampton Court, Red Sea Oil, Green River Petroleum, Dalton Resources, Stampede Oils, Storm Energy, Parkcrest Exploration, Colt Energy and Bolt Energy were among the top 30 most active traded issues.

Net gainers included Hawk Oil B $0.60 to $1.75, BW Technologies $0.35 to $4.05, Hawk Oil A $0.20 to $1.10, Doreal Energy $0.18 to $2.28, Rock Capital $0.18 to $0.95, Meota Resources $0.15 to $1.25, Tier One Energy $0.15 to $2.00, Jett Investment $0.12 to $1.05, Corridor Resources $0.10 to $1.20, Progress Energy $0.10 to $2.60, Bolt Energy $0.09 to $0.69, Hampton Court $0.08 to $2.53, Scimitar Hydrocarbons $$0.08 to $0.45 and DeTECH $0.07 to $0.83.

Percentage gainers included Hawk Oil B 52.2% to $1.75, Q Energy 26.9% to $0.33, Endeavor Resources 25.0% to $0.25, Rock Capital 23.4% to $0.95, Hawk Oil A 22.2% to $1.10, Scimitar Hydrocarbons 21.6% to $0.45, Bolt Energy 15.0% to $0.69, Meota Resources 13.6% to $1.25 and Jett Investment 12.9% to $1.05.

On the downside, Progress Energy B fell $0.50 to $4.00, Arrival Energy $0.40 to $1.60, Solid Resources $0.25 to $6.70, HEGCO Canada $0.20 to $2.90, BriAlto Energy $0.15 to $0.70, Red Sea Oil $0.15 to $2.80, Alma Oil & Gas $0.10 to $0.45, Del Mar Energy $0.10 to $0.50, Destiny Resource Service $0.10 to $2.95, Palmetta Resource $0.10 to $0.95, Rapidfire Resources $0.09 to $0.16 and Airgen A $0.08 to $0.57.

Percentage losers included Rapidfire Resources 36.0% to $0.16, Rockport Energy 21.4% to $0.22, Aspin Energy 20.0% to $0.20, Arrival Energy 20.0% to $1.60, Ramarro Resources 18.8% to $0.26, Alma Oil & Gas 18.2% to $0.45, BriAlto Energy 17.6% to $0.70, Del Mar Energy 16.7% to $0.50, Barra Resources 14.3% to $0.30, Tappit Resources 13.9% to $0.31, PanOil Resources 12.5% to $0.35, Airgen A 12.3% to $0.57, Progress Energy B 11.1% to $4.00 and Cascade Oil & Gas 10.0% to $0.45.

Doreal Energy, Green River Petroleum, Hawk Oil B and Rock Capital were among 52-week highs.

Green Maple Energy, OTATCO, Progress Energy B and WWB Oil & Gas reached new 52-week lows.

EXCHANGE INFORMATION

Falcon Well Services Ltd. (FWSL/CDN) announced that the company has been advised by the Canadian Dealing Network Inc. that the quotation of the common shares of Falcon has been approved. Quotation of Falcon's common shares on the CDN's system under the symbol "FWSL" will be available starting Wednesday, February 18, 1998.

Falcon Well Services Ltd. is a Calgary-based oil and gas well servicing company, performing recompletions, perforations, and other types of service requirements for existing oil and gas wells. It also has the capacity to drill both horizontal and vertical wells. Falcon's services are presently utilized in the oil and gas producing areas of Western Canada and the company is contemplating expanding internationally.

As of the date of this press release, there are outstanding 28,376,627 Common Shares and 75,136 Preference Shares of the Capital Stock of Falcon.

ANALYSTS - FUND MGR.'S - BUY - HOLD - SELL - MISC.

Zargon Oil & Gas (ZAR, $3.00) F& D Costs Better Than Expected

Zargon has completed its reserve report for 1997 which shows finding and development costs of approximately $6.00 per barrel on a proven basis. These results are excellent in comparison to the Company's peers and impressive given the weakness in the sector. Investors are not currently paying a premium for Zargon as the preliminary NAV calculation is roughly $3.00 per share. Zargon is rated as a Buy.

Symmetry Resources (SYO, $1.34) Pools Acreage With Amber Energy

Symmetry has finalized an agreement with Amber (AMB, $14.50) and a First Nations group to pool acreage and increase the Company's undeveloped land position. Symmetry will now have 5000 acres of undeveloped land in the Dawson area compared to 1900 acres prior to this agreement. This additional land adds another two years of drilling for Symmetry. Symmetry shares are rated as a Buy with a target price of $1.70.

Chieftan International (CID, $32.00) 1997 CFPS Better Than Expected

Chieftan reported fully-diluted 1997 CFPS of US$3.06, slightly higher than the estimate of US$2.98. 1998 CFPS estimate is US$3.80 and it generates a $33.00 target price for the Company's shares. Based on this target price, Chieftan is rated as a Hold, however watch a few exciting exploration plays that the Company is drilling in the Gulf of Mexico. Chieftan presently has five rigs drilling and there are three wells that have "company maker" potential. .



To: Crocodile who wrote (9128)2/19/1998 10:32:00 AM
From: Kerm Yerman  Respond to of 15196
 
MARKET ACTIVITY/TRADING NOTES FOR DAY ENDING WEDNESDAY, FEBRUARY 18, 1998 (5)

KERMS TOP 21 - SPEC 15 - SERV 9 COMPANIES IN THE NEWS,

Alberta Energy Company Ltd. (AEC/TSE) reported record Cash Flow From Operations of $544.7 million in 1997, up 32 percent. Fully diluted Cash Flow Per Share was $4.67, up 22 percent. Cash Flow is the key financial performance indicator for the oil and gas industry.

The Company also reported 1997 Net Earnings of $200 million, or $1.73 on a fully diluted, per-share basis. Net Earnings this year include non-recurring items totaling $104 million, associated with the initial public offering of AEC Pipelines, L.P. and adjustments to the book value of the Company's pipelines and international exploration and production assets. The prior year's Net Earnings of $68 million also included a $15 million non-recurring gain related to the sale of the Company's Forest Products business.

''Excluding non-recurring items, AEC's Net Earnings in 1997 were $96 million, or 81 percent higher than the comparable $53 million in 1996,'' said Gwyn Morgan, President and Chief Executive Officer.

AEC's revenues, net of royalties, increased to $1.7 billion from $1.1billion.

''AEC has achieved record operating and financial performance while our capital programs have created growth in underlying asset value. In the last two years, AEC has invested more than $3 billion and our balance sheet ha remained very strong, giving the Company the muscle and flexibility to continue to pursue our broad range of investment opportunities at a time of weakening commodity prices,'' said Mr. Morgan.

AEC invested a total of $984 million during 1997, representing 181% of Cash Flow from Operations. Despite this significant investment program, the Company maintained its strong financial ratios, with long-term debt increasing less than $50 million. Net corporate debt-to-equity improved to 29:71. The exploration and production segment continued with a healthy 20:80 debt-to-equity ratio. The net debt-to-cash flow ratio of the exploration and production segment remained low at 1.1 times.

As well, with the successful closure of the Express project financing on February 6 1998, the Company extended the average term to maturity of its debt to 7.4 years. With over 75 percent of its debt at fixed rates, the Company is shielded from interest rate fluctuations and the average interest rate on borrowing is 6.7 percent.

$800 million capital program for 1998

''We expect natural gas prices to recover more rapidly than oil prices. Consequently, our growth thrust for 1998 and 1999 will be gas, gas and gas. Additional gas export pipeline capacity to the U.S. later this year will provide a continental energy market for Canadian gas producers. AEC's position as a major natural gas producer will help the Company benefit substantially from that recovery. We intend to invest half of our $800 million capital budget on natural gas exploration, production, storage and transportation to put us in the strongest possible position to respond to these new market opportunities,'' said Mr. Morgan. He added that AEC's cash flow rises $22 million for every ten-cent increase per thousand cubic feet in price, excluding additional revenues from expected 1999 sales growth.

Building Value for Growth

AEC earlier reported 1997 operating results which were highlighted by the following:

- Conventional Reserves additions of 1.2 trillion cubic feet equivalent, which is 28 percent of AEC's conventional reserve base and larger than the individual reserves base of the vast majority of companies in the Canadian oil and gas industry;

- Reserve additions replaced 1997 production by 362 percent, further extending the Company's Reserve Life Indices -- natural gas to 17 years and conventional liquids to 11 years;

- Drilling of 477 wells, with an average working interest of 82 percent and success rate of 89 percent;

- Land in Western Canada increased 1.9 million net acres, to total 6.1 million, third largest in Canada; plus 3.0 million internationally for a total 1997 year-end exploration land base of 9.1 million acres;

- Sales of produced gas of 575 million cubic feet per day (MMcf/d), and liquids of 58,940 barrels per day. Gas production was 588 MMcf/d, with 13 MMcf/d placed in storage;

- The AECO C Hub gas storage and trading facility achieved record throughput, and progress was made in developing California's first independent storage facility and trading Hub.

- The new Express oil pipeline was commissioned and AEC Pipelines completed the issuance of one of Canada's first pipeline limited partnerships.

Improving Cost Performance

The Company also achieved important cost performance improvements:

- Reducing conventional Exploration and Production general & administrative costs per barrel of oil equivalent by 33 percent;

- Reducing Finding and Development costs by 11 percent, on a proven and probable basis, to $5.81 per barrel of oil equivalent including land assembly costs of $1.54 per barrel of oil equivalent;

- These cost reductions were achieved at a time of industry wide increases in land, supply and service costs.

''In challenging times, relative strengths become more evident and more important. AEC's vision is to build a Company with a solid foundation of capable people and long-life reserves, and to be a leader in grassroots exploration. Our large, concentrated land and reserves base enable us to dominate in our operating areas. AEC will continue to own a large interest in Syncrude. We also have a unique growing midstream business. This vision is underpinned by a very solid balance sheet. As 1998 progresses, we believe the fundamental value, performance and growth potential will become even better recognized by investors,'' said Mr. Morgan.

Focused and growing, Alberta Energy Company Ltd. is one of Canada's largest oil and gas exploration and production companies. Profitable midstream investments in pipeline transportation, as well as natural gas storage and gas liquids processing provide an additional solid income base. AEC's current stock market value exceeds C$ 3.4 billion. Common Shares trade on the Toronto and Montreal Stock Exchanges (AEC) and the New York Stock Exchange (AOG).

Thunder Energy Inc. (THY - TSE) announced 1997 year end reserves as determined by its independent engineering consultants, Sproule Associates Limited.

Total additions for the year were 2.4 million barrels of oil and ngl's and 29.6 BCF of gas. Seventy eight percent of 1997 additions were achieved with the drill bit with the balance coming from acquisitions. On a barrel of oil equivalent basis 1997 year end reserves have increased 449 percent over 1996 reserves.

During the year Thunder drilled a total of 36 wells (16 net) resulting in 21 gas wells (9.2 net), 11 oil wells (5.2 net), 1 service well (0.5 net) and 3 dry holes (1.1 net). Seventeen of these wells were drilled in the fourth quarter.

Total capital expenditures in 1997 are estimated at $19.3 million. For the year Thunder's finding and development costs were $4.69 per BOE on a proven basis and $3.63 on a proven plus probable basis. Thunder's three year average finding and development costs are $4.80 per BOE and $3.77 per BOE on a proven and proven plus probable basis respectively.

For complete information with table data, see Message 3465234

Badger Daylighting Inc., (BAD/TSE) reported its audited financial results for the year ended November 30, 1997. Net income for the year ended November 30, 1997 was $2.2 million as compared to $0.6 million in 1996, an increase of 267%. Revenues for 1997 were $26.1 million, an increase of more than 400% over 1996. 1997 earnings per share increased by 70% over 1996 to $0.17.

Commenting on the results, Ken Rose, President and CEO of Badger remarked, ''We are pleased to report, for the second consecutive year, record revenues and earnings for Badger. During 1997, the operations of the Bomega division were successfully integrated and the Corporation achieved several growth milestones, including the acquisition of Hewlett Shoring Systems, Ltd., the acquisition of Delta Oilfield Construction (''Delta'') and the licensing of Baseline Technologies, Inc.'s Pipeline Information Control System. Badger is now well positioned to provide a fully integrated service to the pipeline and utility sectors. We expect net income to increase substantially in 1998 as Delta operations are integrated and Badger expands into pipeline integrity and repair services utilizing Baseline's software system. The consolidation of Badger's operations into one facility late in 1997 will further improve profit margins in 1998 by increasing efficiency and reducing overhead costs.''

Mr. Rose further commented, ''During 1997 we added 21 hydrovac units and 1 environmental unit to the fleet, bringing the total number of operating units to 42 as at November 30, 1997. Utilization rates for our operating units exceeded 74% for the year. All divisions are currently operating at full capacity.

Badger Daylighting Inc. is a Red Deer, Alberta based vertically integrated industrial technology company providing various services and equipment to the oil and gas, pipeline and utilities industries. The Corporation specializes in ''daylighting'' underground structures and trenching using a patented hydrovacing process that is safer than typical excavation systems. ''Daylighting'' is a term used in the industry to describe the removal of the soil cover to allow for visual observation of an underground structure. A hydrovac excavating system is one which simultaneously uses water under high pressure to remove soil cover and a vacuum system to suck up the debris. In addition to hydrovac services, Badger provides a complementary suite of products and services to its customers including small inch pipeline facilities and construction, pipeline anomaly locating, line locating, shoring, environmental services and designing and, manufacturing industrial equipment.

For full report with table data, see Message 3462814

Crestar Energy Inc. (CRS/ TSE & ME) announced that it has completed the issue of 5.25 million common shares at $22.25 per share, for aggregate gross proceeds of $116.8 million, to a syndicate co-led by RBC Dominion Securities Inc. and Nesbitt Burns Inc.

The net proceeds from the offering of common shares will be used initially to reduce Crestar's bank indebtedness until required for the Company's exploration and development activities in 1998.

Crestar Energy is a senior Canadian producer of crude oil, natural gas and natural gas liquids.

KERMS WATCHLIST OF COMPANIES IN THE NEWS

Rigel Energy Corporation (RJL/TSE) reported results for the twelve months and quarter ended December 31, 1997. The Corporation recorded substantial gains of 43 percent in cash flow and 18 percent in production during the fourth quarter over the previous three-month period. The Corporation successfully replaced in excess of 250 percent of its 1997 production, adding 29.4 million barrels of oil equivalent on a proved plus half-probable basis. Cash flow for the twelve months ended December 31, 1997 decreased by one percent compared to the previous year, primarily as a result of lower production, which was affected by asset sales late in 1996 and higher operating costs. A net loss of $23.9 million was reported for the year, due to a loss provision associated with an asset sale that will be closed subsequent to the 1997 year-end.

Commenting on the results, Don West, President and CEO of Rigel said, ''the past year resulted in major changes in the direction of the Corporation. We successfully established a production base in the UK with the asset acquisition at MacCulloch and have drilled the first of at least two appraisal wells as a follow-up to the potentially significant discovery in the Moray Firth (Blake) area made earlier in 1997. We also consolidated our position in our core area, the Peace River Arch, with an acquisition of producing properties at Sinclair. The Moose Mountain project is moving forward with the granting of the approval to build a 25-kilometre pipeline that will allow for an extended production test to determine development plans for the area. However, operating activities and short-term production objectives have not met expectations, and as a result, an extensive reorganization of the exploration and development function into business units was undertaken late in 1997. We believe that these independent units can better respondto the challenges and opportunities facing our Corporation and industry.''

Financial Review

Revenue, net of royalties, for the twelve months ended December 31, 1997 increased to $215.3 million from $211.9 recorded in 1996. Increased revenue from natural gas prices more than offset lower oil and natural gas production. Funds generated from operations decreased marginally to $133.0 million, or $2.36 per share, from $134.7 million, or $2.40 per share, reported the previous year. Strong demand for industry services during 1997 contributed to an increase of $7.2 million in operating costs over the twelve-month period in 1996 and represented a significant portion of the decline in cash flow. In the UK, costs associated with leasing production facilities for the MacCulloch field will continue to be reflected in higher average operating costs during 1998, but will decline over the production life of the field. The effect of these costs on the netbacks for UK oil production is mitigated by the absence of royalties on new production. Primarily as a result of asset sales in southwest Saskatchewan to be completed subsequent to year-end 1997, the Corporation recorded a net loss of $23.9 million, or $0.43 per share, compared to net income of $2.4 million, or $0.04 per share in 1996. The sale resulted in a one time pre-tax write down of $37.8 million. Proceeds of approximately $35 million will be applied to debt reduction in 1998.

Revenue, net of royalties, in the fourth quarter increased by 38 percent compared to the third quarter as a result of both oil and natural gas production gains and higher natural gas prices. Cash flow rose to $40.1 million versus $28.1 million during the third quarter -- a 43 percent improvement.

Operations Review

Exploration and Development

Capital expenditures, including acquisitions net of dispositions, during 1997 totaled $309.2 million compared to $349.5 million in 1996 including the Inverness corporate acquisition of $256.9 million. Exploration in the UK and the MacCulloch acquisition resulted in expenditures of $151.7 million, or nearly half of total 1997 expenditures.

During the period, the Corporation participated in the drilling of 167 wells (excluding nine service wells and seven stratigraphic tests), resulting in 49 oil wells and 52 gas wells. This total for 1997 compares to 188 wells drilled in 1996, of which 55 were cased for oil production and 54 wells for natural gas. Drilling in the fourth quarter totaled 46, which resulted in the casing of 34 wells for production. Based on proved and half-probable reserves, additions (net of revisions and dispositions) totaled 29.4 million barrels of oil equivalent, or 252 percent of 1997 production, at a finding and on-stream cost of $10.48 per barrel of oil equivalent.

The winter program in northern Alberta is targeting natural gas from a number of potentially significant Slave Point prospects and is expected to add to production during the second quarter. At Burmis, located in the Alberta foothills, a well targeting high deliverability natural gas is expected to reach total depth in March. Additional drilling is under consideration pending results from the initial well.

Approval has been received to build a pipeline connecting Moose Mountain to Jumping Pound that will allow extended production testing of two oil wells beginning in September. Construction will begin on critical crossings prior to breakup with completion of the 25-kilometre line in the summer. Initial test rates are expected to be approximately 1,900 barrels of total liquids per day.

Operations in the Acme area of south central Alberta continue to expand with first quarter production expected to reach approximately 1,300 barrels per day following the completion of recently drilled wells. At least eight new prospects generated from newly completed three-dimensional seismic are proposed for 1998. Construction of a central oil battery with initial capacity of 1,600 barrels per day will be completed in June.

In the UK, evaluation of the first appraisal well offsetting the discovery well 13/24b drilled last year in the Moray Firth has been completed. Information regarding the well will not be released at this time due to competitive reasons. Further appraisal drilling is expected during the first half of 1998. Approximately 90 kilometres east, Rigel is also participating in an additional prospect located in block 21/6b that began drilling in mid-February. The Corporation will earn a 30 percent interest in the prospect, which is estimated to take approximately 35 days to drill and evaluate. Three additional prospects will be drilled through the remainder of the year.

Production and Pricing

Crude oil and condensate production during 1997 totaled 15,463 barrels per day compared to 16,352 barrels per day during the previous year. Approximately 1,100 barrels per day of this decline is attributable to sales completed late in 1996. Prices received for crude oil and condensate averaged $25.27 per barrel for the period compared to $26.07 per barrel recorded in 1996. Crude oil hedging contributed approximately $0.14 per barrel to the price received during the twelve-month period. Production for the fourth quarter averaged 18,479 barrels per day, with the addition of sales from MacCulloch, at a price of $24.81 per barrel.

Natural gas sales to December 31, 1997 averaged 148.0 million cubic feet per day compared to 156.2 million cubic feet per day recorded for 1996. Production was adversely affected by the sale of 12 million cubic feet per day late in 1996. As a result of a 25 percent improvement in average natural gas prices to $2.03 per thousand cubic feet from $1.62 per thousand cubic feet the previous year, revenue from natural gas sales increased by 19 percent. The addition of Sinclair production in November helped boost fourth quarter over third quarter production by approximately 10 percent to average 157.5 million cubic feet per day at a price of $2.18 per thousand cubic feet.

Natural gas liquids production declined to 1,635 barrels per day compared to 1,877 barrels per day recorded in 1996. The average price increased marginally to $16.33 per barrel from $16.10 per barrel received in the previous year.

Outlook

World events, including the recent financial upheaval in Asia, continue to impact commodity prices, which emphasizes the need to establish long-term objectives able to withstand the volatility of unpredictable revenues. Two years ago, Rigel began initiatives to reallocate corporate resources to manage the changes shaping our business. To this end, Rigel achieved significant progress over the past year in establishing an operating base in the UK. That effort will continue in 1998 with expectations of a drilling program consisting of six to eight wells.

However, the necessity of maintaining a strong Canadian based operation is paramount in our efforts towards international expansion. With this resolve, Rigel has reenergized its focus on the Western Canadian Basin, and with an aggressive program planned for 1998, expects to deliver significant growth in the coming year.

For full report with table data, see Message 3462567



To: Crocodile who wrote (9128)2/19/1998 10:56:00 AM
From: Kerm Yerman  Respond to of 15196
 
MARKET ACTIVITY/TRADING NOTES FOR DAY ENDING WEDNESDAY, FEBRUARY 18, 1998 (6)

KERMS WATCHLIST OF COMPANIES IN THE NEWS, con't

Canrise Resources Ltd. (CRE/TSE) announced its unaudited financial and operating results for the fourth quarter and 1997 fiscal year. Total revenue amounted to $8,012,000 compared to $3,930,000 in 1996. Cash flow was $4,592,000 ($0.27/share) versus $2,228,000 ($0.18/share) last year. Production averaged 3,501boe/d compared to 1754 boe/d in 1996.

For full detailed report with table data, see Message 3466374

Summit Resources Limited (SUI/TSE) reported their 1997 financial and operating results. Activity levels in the Western Canadian Sedimentary Basin were at an all time high in 1997, resulting in the drilling of 16,500 wells. Shortages in equipment, trained field personnel and professional staff resulted in delays and escalated costs impacting performance throughout the sector. The industry's heightened interest in heavy oil projects resulted in the heavy oil differential widening significantly, impacting netbacks for heavy oil producers. Summit's blend of higher quality crude oil, with an average API exceeding 35 degrees, mitigated this alarming,but not surprising, spread in the differential.

During 1997 Summit participated directly in 77 wells and farmed-out 7 wells to industry partners. Twenty-three per cent of Summit's participation wells were exploratory where the Company posted a 50 per cent success rate, and the remaining 77 per cent were development where the Company achieved an 81 per cent successrate. This drilling activity resulted in 42 oil wells (17.5 net) and 19 gas wells (13.9 net), with an average well depth of 1,700 meters.

Summit's 1997 BOE production increased to 12,362 BOE's per day which was within 3 per cent of budgeted production volumes forecast at the beginning of 1997. Oil and liquids production increased from 5,707 BOE's per day in 1996 to 6,145 BOE's per day in 1997, while natural gas production increased to 62.2 MMcf/d from 60.1 MMcf/d the previous year. Summit's 1997 average natural gas price of $2.06 per Mcf (1996 - $1.70 per Mcf) continues to rank in the top quartile for the industry. Summit's blend of natural gas contracts and higher than average BTU content contributed to Summit's premium pricing for its natural gas production. While natural gas prices firmed in 1997, crude oil prices declined by 6 per cent, with WTI prices averaging US$20.61 in 1997 compared to US$22.00 in 1996. As a result, Summit's 1997 realized crude oil price averaged $23.89 per barrel compared with 1996 realized prices of $25.49 per barrel.

During 1997 Summit expanded its production base in core areas through a combination of successful property acquisitions, asset rationalizations and an active drilling program which resulted in total expenditures of $88 million. Seventy-two per cent of the $65 million invested in oil and gas exploration and development activities was allocated to Canadian operations, with the remaining 28 per cent invested to expand Summit's light oil exploration and development activities in the U.S. portion of the Williston Basin.

Strategic property acquisitions completed in 1997 totaled $75 million and included an expansion of the Company's oil production base through the acquisition of producing assets in the Williston Basin and in Rabbit Hills, Montana, while an acquisition at Fox Creek, Alberta offset a portion of the Company's natural gas and liquids divestitures. As part of Summit's rationalization program in 1997, dispositions of non-core assets totaling $51 million were concluded, including dispositions at Sturgeon Lake, Dunvegan, Manir, Pine Creek and Hays in Alberta, and Viewfield and Cantal in Saskatchewan.

Summit's year-end 1997 long-term debt totaled $125 million, including $17.6 million incurred by the Company to finance its investment in Fort Chicago Energy Partners L.P. which is the largest owner of interest in the Alliance Pipeline projects. Excluding the debt associated with this investment, Summit's 1997 debt to cash flow ratio equates to 2.1:1.

Increased production levels in 1997 resulted in petroleum and natural gas revenues increasing to $101 million, an 11 per cent increase from the $91 million posted in 1996. Cash flow for the year increased to $51 million ($1.51 per share) compared to $50 million ($1.46 per share) in 1996. 1997 cash flow was impacted by higher operating costs due to increased production volumes from Summit's U.S. production which were converted to Canadian dollars, excess natural gas transportation commitments which have since been mitigated, and generally higher operating costs throughout the industry. Cash flow in the fourth quarter of 1997 totaled $13.8 million ($0.41/share) based on average oil and liquids production of 6,365 barrels per day ($22.65/bbl) and average natural gas production of 67.7 MMcf/d ($2.14/Mcf).

Under Generally Accepted Accounting Principles (GAAP) the Company is required to evaluate the carrying value of its assets in each country against the future cash flows its proven reserves will generate at constant prices over their economic life. In performing the "ceiling test" the Company has the option to either use average commodity prices for the year or prices in effect at the end of the year. In Canada future net revenues are considerably higher than the carrying costs of the reserves. Using average oil prices for 1997 (US$20.61 WTI) Summit's proven reserves in the United States satisfies the ceiling test requirements under GAAP. However, using year-end constant prices of US$17.68, a ceiling test deficiency resulted for the Company's U.S. cost centre. In light of the soft crude oil prices that currently exist and the expectation that soft prices are likely to continue in 1998 due to the decreased demand in south-east Asia and OPEC's decision to increase production output, the Company has elected to use the more conservative year-end oil price in its ceiling test calculation. This calculation, together with the Company's decision to write-off certain land and seismic costs on U.S. properties evaluated by the Company, results in Summit recording a net loss of $31 million in 1997, which includes a $34.5 million write-down on the Company's U.S. cost centre.

Summit's drilling and acquisition programs during the year added proven reserves of 11.7 million BOE's and 14.5 million BOE's of proven and probable reserves. Given the favourable market conditions during 1997, Summit disposed of some of its non-strategic properties, thereby reducing proven reserves by 5 million BOE's (6.6 million BOE's proven plus probable) while netting the Company proceeds in excess of $10.00 per BOE on a proven basis. Reserve revisions to prior years evaluations accounted for a reduction of 0.6 million proven BOE's and 2.3 million proven plus probable BOE's. The Company's total crude oil and liquids reserves increased to 20.1 million barrels, including 14.6 million barrels proven, while natural gas reserves totaled 185 Bcf, including 147.4 Bcf proven. The Company's U.S. reserves increased by over 300 per cent to 8.4 million BOE's, including 6.3 million barrels of proven reserves.

Summit has established a $40 million capital program for exploration and development activities in 1998, including drilling, facilities, land and geophysics. Sixty-eight per cent of this total has been allocated to the drilling of 70 wells, including 23 exploration projects and 47 development wells. Fifty-seven per cent of the Company's drilling and facilities capital has been allocated to natural gas and the remainder to crude oil. Forty wells are planned in Canada to expand the Company's natural gas and light oil production base, and 30 wells are planned in the U.S., mostly located in the Williston Basin, to expand the Company's crude oil production base.

1998 production volumes are projected to increase 13 per cent to 14,000 BOE's per day, comprising 6,700 barrels of oil and liquids per day and 73 MMcf/d of natural gas. Using budget parameters of US$18.50 per barrel for oil and $1.75 per MMcf/d (plus $0.15 per Mcf for settlement of an outstanding gas contract), Summit anticipates cash flow for 1998 of $48 million or $1.45 per share.

OTHER COMPANIES IN THE NEWS

Saxon Petroleum Inc. (SXN/TSE) reported net income for year ended December 31, 1997 of $61,542 ($0.00 per share) compared to $358,993 ($0.00 per share) for the year ended December 31, 1996. Cash flow for this same period was $9,276,105 or $0.06 per fully diluted share versus $6,360,280 or $0.05 per fully diluted share in the 1996. The results for 1997 include a charge of $1.0 million for costs associated with the share evaluation and enhancement process. If these costs are excluded, the net income would be $0.6 million ($0.00 per share) and cash flow would be $10.3 million ($0.07 per share).

Production volumes in 1997 averaged 2,868 barrels of oil equivalent per day (BOE/D) for a 53 percent increase over the corresponding period in 1996. Exit rates for production in December 1997 were 3,220 BOE/D compared to 2,440 BOE/D in December 1996. In addition to increased production, Saxon improved its netbacks to $12.84 per BOE in 1997 versus $11.76 per BOE in 1996.

Saxon continued the development of its Bigoray operations and devoted the majority of its capital expenditures of $49.9 million to this field. Saxon is currently expanding its waterflood to remove production restrictions from certain wells in Bigoray. Expenditures were also made in Kaybob South, increasing natural gas production for that area. In addition, further Kaybob South gas will be tied-in in early 1998 after the completion of a pipeline extension by the partner in the area.

The Board of Directors is continuing to review several alternatives with respect to the share value enhancement program which was announced in August 1997. Included in this evaluation is the scope of the 1998 capital expenditure program and in this regard an announcement will be forthcoming in the near future.

For full report with table data, see Message 3464954

Backer Petroleum Corp. (BCM/TSE) reported that three wells completed in 1996 and 1997 at its Darwin, Alberta, property commenced production on February 13, 1998, at a rate of 8.0 MMCF per day of raw gas.

Backer's 30% share of the natural gas production is 2.4 MMCF per day.

Construction of the natural gas processing facility has just been completed on the gas property located 60 miles north of Peace River, Alberta. The plant will handle 10 MMCF per day.

Backer's 1997 year end sales volume of 600 barrels of oil equivalent ("BOE") per day will increase to over 800 BOE per day, and Backer's net cash flow will increase by over $60,000 per month, based on recent oil and gas prices.

Four additional wells in which Backer holds a 30% Working Interest are in progress in the Darwin Area. These include one well drilled and completed as a potential gas well which will be production tested during the next three weeks and which earned three sections of land; one well which has had casing set with completion work underway which earned an additional three sections of land; one water disposal well to handle water recovered from the natural gas processing plant, and one location anticipated to spud within the next two weeks. Depending upon results, the new gas wells may also be tied in for production before spring break-up.

With the completion of the earning phase of the multi-well program initiated in 1996, Backer owns an 18% to 50% Working Interest in 32 sections, over 20,000 gross acres of land, in the Darwin Area. Drilling can only be conducted during the winter freeze-up season in this area. Consequently, an additional three or four wells to further develop the Darwin property will be drilled in the 1998-99 winter drilling season, and should provide additional natural gas throughput within the 10 MMCF per day capacity of the processing facility already in place.

HEGCO Canada, Inc. (HEG/ASE) reported an update on progress within the Company's Oklahoma operations. As indicated in a previous release, a general status report on Oklahoma is as follows:

1) The Nemaha No. 1 - Has been flow tested from the lower Arbuckle zone at a daily rate of 139 BO plus approximately 110,000 cubic feet of gas per day. The well will be hooked up, and all surface equipment installed, within the next two days. Management has encountered substantial pay zones above the productive Arbuckle interval, and as a result, is now considering twinning the well for two prolific sections of Wilcox.

2) The Guame No. 2-98 - Company will begin flow testing from the lower Arbuckle zone this week. As with the Nemaha No. 1, the well will be hooked up, and all surface equipment installed, within the next two to three days. Management has encountered substantial pay zones above the productive Arbuckle interval, and as a result, is now considering twinning the well for two prolific sections of Wilcox.

The Alberta No. 3 has been drilled and is awaiting completion. Testing will begin after completion operations are done on the Guame No. 2-98 well. During drilling, several good oil shows were observed over several known pay intervals.

Drilling is underway on the Meier No. 2 well, located in the NE Garber Field. The Company expects to be at total depth within 20 days. This well is being drilled to develop infield gas pay. The exploratory objectives will include drilling deeper than the pay objective to test and evaluate the deeper Arbuckle and Wilcox series.

HEGCO Canada, Inc., is an oil and gas production, servicing and drilling company with operations in Oklahoma and Arkansas.

Burner Exploration Ltd. (BXP/ASE) reports that it has participated for 25 % in the successful horizontal sidetrack of a liquids rich gas well in the Hamburg area of northwest Alberta. The well is tied-in and currently onstream. The Company has also participated for 25 % in the 8-19-64-3W6 well drilled in the Lator area of west central Alberta which has been cased awaiting further production testing. This well is the first well in a three well program that will earn the Company an interest in 62 sections of land in the Lator area.

With the addition of the Hamburg well, Burner's net production is currently 6.7 mmcf/d of gas and 150 bbls/d of oil and liquids.

Storm Energy Inc. reported record results for the year ended December 31, 1997. Revenue was $13,791,968 compared to $2,656,570 of a year ago. Cash flow was $7,054,046 (fd-$0.122/share) compared to $1,348,081 (fd-$0.047/share) last year. Production averaged 1527 boe/d versus 378 boe/d in 1996. The company exited the year with a production rate of 2350 boe/d.

For more information and table data, see Message 3466134

Calvalley Petroleum Inc. (CVI.A/MSE) today announced its participation as a fifty percent (50%) working interest partner in a drilling and seismic joint venture arrangement in the Battle Creek area of S.W. Saskatchewan. This contiguous block of 16 sections (10,240 acres) of petroleum and natural gas rights is located 30 miles S.E. of the city of Medicine Hat, is accessible on a year round basis, and is in close proximity to pipelines and facilities.

Calvalley, as the designated managing-operator intends that the initial exploration well will be drilled within the next 30-45 days to a depth of approximately 1300 meters, where it is anticipated that significant natural gas reserves will be encountered in the Second White Specks Formation (850m) and oil production from the Shaunavon Zone (1300m).

Calvalley Petroleum Inc. is a Calgary-based oil and gas exploration and development Company whose shares are traded on the Montreal Exchange.

BelAir Energy Corporation (BGY/ASE) announced today that the Company has closed the purchase of various working interests in producing oil and gas properties and undeveloped lands for $625,000.

The acquisition adds 47 boepd of production to BelAir's current production of 400 boepd and adds 600 MMcf of proven producing natural gas reserves and 46 Mbbl of proven producing oil and NGL reserves to BelAir's reserve base.

The acquired producing properties in Fenn West, Viking Kinsella and Wainwright complement BelAir's existing production in central Alberta and expands the Company's production base into east central Alberta.

According to President Vic Luhowy, ''This acquisition completes the first phase of our strategy to build a solid base of long life producing reserves and cash flow. This base is the foundation of BelAir's future growth. The next phase will be to build on the Company's undeveloped land base and to make strategic acquisitions with development potential.''

Midas Resources Ltd. (MDS/TSE) reported its sixth successful Hackett gas well in the Gadsby area. Midas has a 43.75 percent working interest in the well, which flowed 4.6 million cubic feet per day on drill stem test. The flow rate from the Hackett sandstone indicates the well has an absolute open flow potential of 40 million cubic feet. Midas plans to have the well on stream by the beginning of April at a rate of 4 million cubic feet per day, since the well is located within one half mile of Midas' existing gas gathering system. The gas is being marketed to Pan-Alberta Gas.

Midas has varying working interests in 13 Hackett sand gas wells in the Gadsby, Hackett and Fenn-Big Valley areas and interests in 26,500 gross (9,000 net) acres. The majority of Midas' 1998 capital budget will be spent in this focus area.

Best Pacific Resources Ltd. (BPG/ASE) reported 1997 year-end proven plus half probable reserves of 7,017 thousand barrels of oil equivalent (mboe). Best Pacific added to its reserve base in 1997 with commendable finding and development costs of $4.97 per boe based on the addition of 3,114 mboe of proven plus half probable reserves over the year. Proven reserve additions accounted for 2,654 mboe of this increase, bringing total proven reserves at December 31, 1997 to 5,692 mboe.

To date in 1998, Best Pacific has participated in two new gas wells in Alberta and two dual leg horizontal oil wells in southeast Saskatchewan, with one similar horizontal well to immediately follow. In addition a gas well in the Farrell Lake area has been put on production at a net rate of 22 boepd. Best Pacific has also completed a recently drilled oil well at its Michel property and is currently evaluating this new pool discovery. The Company's total current production is approximately 2,100 boepd.

Thus far in 1998, the Company has entered into 8 separate agreements primarily consolidating interests in its core areas and disposing of non-core assets.

Best Pacific Resources Ltd. is also pleased to announce the recent appointment of Mr. Vincent Cheung, M.Eng., P.Eng., as Vice President of Production. Mr. Cheung has 22 years of experience in reservoir engineering and production and asset management in Western Canada and abroad, and is a valuable addition to the Company's management team.

A complete summary of 1997 year-end reserves with table data is at
Message 3464620



To: Crocodile who wrote (9128)2/19/1998 11:06:00 AM
From: Kerm Yerman  Respond to of 15196
 
MARKET ACTIVITY/TRADING NOTES FOR DAY ENDING WEDNESDAY, FEBRUARY 18, 1998 (7)

INTERNATIONAL COMPANIES IN THE NEWS

Gulf Indonesia Resources Limited (GRL/NYSE) made significant strides and achievements throughout 1997. In short, a public offering of 28 per cent of the company in September, sizable exploration successes and the acquisition of Clyde Petroleum Plc's producing assets in Indonesia have expanded operations and realized value for the Company beyond what could have been envisioned a year ago. Gulf Indonesia's assets provide a tremendous base for future expansion, and the Company looks forward to extending its 36-year history in the area into the next millenium.

Operational highlights for 1997 include:

- Crude oil sales volumes increased 62 per cent to 22,500 barrels per day as a result of the Clyde assets acquisition.

- Proved crude oil and natural gas reserves increased 40 per cent to 168 million barrels of oil equivalent, primarily from Gulf discoveries, but also as a result of the acquisition. This equates to a production replacement rate of over 500 per cent for the year.

- The acquisition of Clyde Petroleum (Kakap) for $105 million added 22.6 million barrels of oil equivalent gross proved reserves and 8,700 barrels to daily production.

- In February, project financing was obtained from a consortium of lenders for the Corridor Block Gas Project. Gulf's share of the limited recourse loan totaled $270 million of which $150 million was drawn by year end, reflecting the significant progress made in construction of the field facilities.

- Drilling successes announced in the second quarter included delineation drilling on the Corridor Block resulting in confirmation of a large extension of the Sumpal structure; the first discovery well on the 100 per cent Gulf held Tungkal PSC, which showed both oil and natural gas; and an oil discovery made on the currently producing Kakap PSC.

- Two new natural gas discoveries were added to the 1996 Bungkal discovery on the South Jambi 'B' PSC adjacent to the Corridor Block, providing additional reserves with the potential to be developed as another Corridor-size project.

- The promising Halilintar well, spudded near year end, is the deepest well Gulf has ever drilled in Indonesia; results are expected early in the second quarter of 1998.

Gulf Indonesia's 1997 operating revenue was generated primarily from crude oil sales from production at the Kakap and Corridor Blocks. Net oil revenue of $117 million for the year was 54 per cent higher than in 1996, primarily due to production from the acquired Kakap PSC. This was offset slightly by a lower average oil price received of $19.12 versus $20.09 per barrel in 1996.

Cash generated from operations of $73.9 million increased approximately 74 per cent over 1996, due mostly to the impact of the Kakap acquisition. Earnings of $8.3 million were approximately $1 million lowe than in 1996, mainly due to the extensive drilling program and associated dry hole costs that offset the benefits from higher production.

Capital expenditures and exploration expenses of $268 million in 199 reflected a much higher level of investment activity compared to $52 million in 1996. Capital expenditures included construction and drilling costs associated with the Corridor Project of approximately $178 million; 89 per cent of the project facilities and 59 per cent of the drilling were completed by year end. Drilling activity also increased significantly, resulting in six discoveries during the year including Mengoepeh, Tetangga and Rayun. The exploration drilling success rate exceeded 50 per cent. Gulf Indonesia also announced a discovery at Bungin in January 1998.

In September, the Company completed a public offering of 28 per cent of its outstanding shares (the remainder of the shares are held by Gulf Canada Resources Limited). The Company actively trades on the New York Stock Exchange under the symbol GRL and is actively pursuing a listing on the Jakarta Stock Exchange. At the time of the initial public offering, the stock sold for $19.50 per share, creating a recognized value for the Company of $1.7 billion. From this transaction, the Company netted approximately $100 million (after inter-company repayments and a dividend to Gulf Canada) that can be applied to the 1998 capital budget.

For much greater detail and review of properties, along with tables of data, see Message 3470274

Primeline Energy (VSE/PEH) provided further details of the reserve estimates in its news release dated February 16, 1998.

The estimates in the release were based on the result of a post well evaluation which was conducted by Primeline's own technical team in conjunction with Quad Consulting Ltd., a United Kingdom-based resource consulting firm involved in oil and gas exploration and development worldwide.

Management's post well evaluation utilized the data collected during drilling and testing the Vicky-1 (LS36-1-1) well including electric log data, drill stem test data, analytical data of the samples collected from the well and geophysical data. The structural closure has been re-interpreted/re-mapped in detail incorporating the well results. The reserve estimates were calculated probabilistically in order to not overstate the situation but at the same time not overlook the potential. The discovery is the first in the area and is located 100 km from the coast of China, 140 km from Wenzhou, a major city in South East China, in Zhejiang Province. However, this is a ''frontier discovery'' so the hydrocarbons discovered cannot be assigned as either ''proved'' or ''probable'' as defined in Canada's National Policy Statement 2-B at this early stage.

The ''most likely recoverable reserve'' of 660 billion cubic feet (bcf) of gas quoted was calculated by Primeline according to normal industry practice from the reservoir which was clearly demonstrated by the well data of Vicky-1 (LS36-1-1). The final reserve calculation will, however, require future appraisal drilling before the overall development program can be established.

The ''potential recoverable resource of over 4 trillion cubic feet (tcf) of gas'' describes the potential resources in the identified adjacent prospects within a 20 km radius to the Vicky-1 discovery if these prospects are successfully drilled. These prospects have geological similarities to the Vicky-1 discovery as indicated by seismic mapping and inversion processing.

As previously announced, Primeline intends to supplement its initial evaluation with a 3D seismic survey this spring before commencing with the drilling of appraisal wells in the locations identified following processing of the 3D seismic data. Once the results are obtained from one or more appraisal wells, there will be sufficient data for Primeline to commission an independent reserve report in accordance with National Policy Statement 2-B.

Primeline owns a 75 percent interest in Block 32/32, a 6,000 square km (1.5 million acres) concession block in the East China Sea. Primeline is exclusively focused on oil and gas exploration and upstream business opportunities in China.

Ram Petroleums Ltd. RPL.A/TSE) announced that it has been informed by Schlumberger that the logistical problem with the logging unit has been resolved. The unit is scheduled to be on the AIRU-1 location on February 25, 1998. The AIRU-1 well is a 6,193' indicated oil discovery in the 130,000 hectare (321,000 acre) Rio Putumayo Association Contract in southern Colombia in which Ram has a 100% working interest.

In view of the delay resulting from this logistical problem and the resulting risk of collapse of shales in an uncased hole, Ram ran and cemented 7'' casing yesterday. Ram will be working closely with Schlumberger to optimize the information that will be obtained from cased hole logs.

Del Mar Energy Inc. (DEM/ASE) reported the successful completion of the side track of its Mora 3 Well in the 5,034 acre Mora Block located offshore on the East Coast of Trinidad. Del Mar owns an indirect partial interest in a company Mora Oil Ventures Ltd. (''Mora Oil'') a Trinidad company with an offshore oil and gas license in Trinidad called the Mora Block.

The Mora 3 Well penetrated 200 feet of oil pay in the C-35 sand. Production and reservoir testing will be implemented over the next week to establish a stabilized production rate. In the first 20 hours, the Mora 3 Well tested at 600 BOPD at 18/64'' choke and 380 BOPD at 16/64'' choke. For comparative purposes, the Galeota Ridge 4 discovery well in the C-35 sand tested at 605 BOPD at 20/64'' choke and 3,108 BOPD at 44/64'' choke. The Mora 3 Well is producing the C-35 sand for the first time.

Del Mar, through its ownership in Mora Oil, plans to undertake further development and exploration activities on the Mora block in 1998 to further increase production.

Del Mar is currently evaluating several other onshore and offshore oil and gas projects in Trinidad as part of its strategic alliance agreement with Dr. Krishna Persad and Mr. Darcy Carr, two well respected oil strategists based in Trinidad.

Kyrgoil Corporation (KGO/TSE) announced continued increases to volumes of refinery production for Kyrgyz Petroleum Company, the Corporation's joint venture in the Kyrgyz Republic.

From the Kyrgyz Republic, Mr. Roth indicated that in the fourth quarter of 1997 gross average daily refinery production increased to 3,127 barrels per day (bpd) from 2,542 bpd refined in the third quarter and 1,572 bpd refined in the first half of the year. These gross figures include the crude oil supplied to the refinery by Kyrgyzneftegaz, the Republic's national oil company. KPC earns 25% of the Kyrgyzneftegaz volumes refined as a processing fee.

Net to the KPC joint venture, fourth quarter refinery production increased to 2,470 bpd from the 1,433 bpd reported for the third quarter and the 660 bpd reported for the first half of 1997. All of the refined petroleum products produced have been sold in the domestic Kyrgyz market.

Kyrgoil also announced that Mr. Ray Cej will be resigning as Chairman of the Corporation effective February 28, 1998 to pursue another opportunity. The Corporation wishes to acknowledge the significant contribution that Mr. Cej has made to the Corporation and wishes him success in his new endeavors.

Kyrgoil's corporate focus continues to be on increasing refinery production volumes, increasing operating cash flow and completing the required technical work to develop the upstream assets prior to commencing a development drilling program in the exclusive licensed areas held by KPC.

Kyrgoil Corporation is a Canadian-based public company. Its operations in the Kyrgyz Republic are conducted through Kyrgyz Petroleum Company, an integrated oil company formed and owned equally by Kyrgoil and Kyrgyzneftegaz.

Kappa Energy Company Inc. (KAP/TSE) announces its decision to abandon the Al Hijera-2 exploratory well in Yemen. Interpretation of electric logs run in the well showed the target reservoir sandstones to be water bearing.

Kappa will continue its 1998 exploration program with the Nabors 217 drilling rig moving to Kappa's second exploratory location, South Ma'ber-1 which is located approximately 20 kilometers west of the Al Hijera location. The Company anticipates this well will spud in approximately 2 weeks.

Kappa plans to drill a total of six or seven wells during 1998. Drilling in Colombia is expected to commence late in the second quarter with a well in the Cucuana block in the Upper Magdalena Valley. The Colombian drilling program will continue throughout 1998.

Kappa Energy Company Inc. is a Calgary based international oil and gas company with current exploration operations in Colombia, Egypt and the Republic of Yemen.

Lateral Vector Resources Inc. (LVR/TSE) announced that its Shareholders have approved a resolution which provides the company's board of directors with the discretion to consolidate the shares of the corporation on the basis of one newly issued common share in exchange for ten common shares or such lesser number of common shares as the directors may approve. A total of 99% of all ballots cast at the special meeting voted in favour of the consolidation which now enables the Company to pursue a listing on a US stock exchange.

LVR believes a listing on a US exchange is desirable for the followin reasons:

1. Approximately 25% of LVR's outstanding share capital is held by US residents;
2. The Company believes there is the potential to expand the shareholder base in the U.S.; and
3. The company is already an SEC registrant and filer in the US.

The Shareholders approved a two-year time period, within which the Company can effect the consolidation. The exact timing of the consolidation and pursuit of a listing will be at the discretion of the board but will be scheduled to coincide with other corporate developments in order to maximize shareholder value. The directors of LVR may elect not to act on or carry out the consolidation withoutfurther approval of the shareholders at any time prior to effecting the consolidation. The details of the consolidation are subject to the approval of The Toronto Stock Exchange. The Company intends to maintain its listing on The Toronto Stock Exchange.

Lateral Vector Resources Inc. is a Canadian resource company with head office in Saskatchewan. The Corporation specializes in international oil projects.



To: Crocodile who wrote (9128)2/19/1998 11:19:00 AM
From: Kerm Yerman  Read Replies (7) | Respond to of 15196
 
MARKET ACTIVITY/TRADING NOTES FOR DAY ENDING WEDNESDAY, FEBRUARY 18, 1998 (8)

SERVICE SECTOR NEWS

Venture Seismic Ltd. (VSEIF/NASDAQ) announced it has entered into a revised letter of intent to acquire 100 percent of the outstanding capital stock of Continental Holdings Ltd. ("Continental"), for consideration of 2,080,000 Common Shares of Venture Seismic Ltd. ("Venture") and payments in cash of an aggregate of $1.5 million. All amounts which follow are in U.S. dollars

Pending closing of the acquisition, Venture has agreed to advance $4 million to Continental to equip a second marine seismic vessel, which advance is subject to an equity conversion provision should closing not occur. The letter of intent also includes provision for employment agreements with the existing management of Continental.

Continental is a privately held marine seismic data acquisition company, based on Calgary, which currently operates one marine seismic vessel capable of performing both 2D and 3D seismic surveys. Continental has completed seismic surveys in the Persian Gulf, the North Sea, the Falkland Islands area, the Mediterranean and off the coasts of West Africa and Norway. According to financial information supplied by Continental, audited revenue for its year ended Dec. 31, 1996 and $8.6 million and net income, adjusted for normalized owner/management compensation, was approximately $600,000. For the nine months ended Sept. 30, 1997 Continental recognized revenue of approximately $7.1 million and unaudited net income of approximately $1.6 million. Certain financial information relating to Continental is included in Venture's Annual Report on Form 10-KSB as filed with the Securities and Exchange Commission on Dec. 24, 1997.

Brian Kozun, president & CEO of Venture stated "The amended letter of intent allows Venture to proceed with the announced acquisition while providing Venture the flexibility to use a portion of its existing cash resources to equip a second marine vessel, which Continental estimates will be operational by July 1998."

The Continental acquisition is subject to a number of conditions, any of which may not occur, including execution of a definitive purchase and sale agreement, receipt of requisite shareholder, regulatory and/or third party approvals and completion of due diligence. The companies anticipate entering into a definitive agreement upon completion of due diligence and closing upon receipt of the requisite approvals.

Venture Seismic Ltd. is traded on the Nasdaq National Market and is engaged primarily in the acquisition of land and wetlands seismic data for use in the exploration for and development and field management of oil and gas reserves. The Company utilizes both traditional two-dimensional ("2D") and more technologically advanced three-dimensional ("3D") seismic data technology to acquire data on possible oil and gas reserves for its customers, which range from junior exploration companies to fully-integrated multi-national corporations. Venture's subsidiaries include Boone Geophysical, Inc., a Texas based company engaged in the acquisition of land and wetlands seismic data in the Southern United States, and Hydrokinetic Surveys of Canada Inc., a company based in Western Canada which provides shallow marine airgun and survey services.

Also see Kerms top 221 - spec 15 - serv 9 and watchlist companies in the news.

PIPELINE NEWS

NOVA Gas Transmission Ltd. Record Natural Gas Volume
Message 3466215

EARNINGS REPORTS

Badger Daylighting Inc., (BAD/TSE) See kerms top 21 - Spec 15 - Serv 9 companies in the news.

Rigel Energy Corp. (RJL/TSE) See Kerms watchlist of companies in the news.

Summit Resources Limited (SUI/TSE) See Kerms watchlist of companies in the news.

Saxon Petroleum Inc. (SXN/TSE) See other companies in the news.

Burner Exploration Ltd. (BXP/ASE) See other comanies in the news.

Canrise Resources Ltd. (CRE/TSE) See other companies in the news.

Alberta Energy Comapny Ltd. (AEC/TSE) See Kerms top 21 - spec15 - serv 9 companies in the news

Gulf Indonesia Resources Limited (GRL/NYSE) See international companies in the news

FINANCIAL

Rock Capital Corporation (RCK/ASE) announced that it has completed the previously announced private placement of 2,195,000 common shares at a price of $0.31 per share.

The Corporation intends to use a portion of this private placement to finance the acquisition of a 62.5 % interest in three oil wells located in the Roncott area of Saskatchewan from Black Canyon Resources Inc. for total consideration of $500,000. An independent engineering report suggests that the property on which the wells are located has proven producing reserves before royalties of 185,000 barrels of oil with daily production in the order of 29 barrels of oil per day. This acquisition is anticipated to close on Friday, February 20, 1998.

Crestar Energy Inc. (CRS/ TSE & ME) See Kerms top 21 - spec 15 - serv 9 companies in the news.

Newstar Resources Inc. (NER/TSE - NASDAQ/NERIF) announced that it has negotiated a U.S.$50 million senior revolving credit facility with a major Houston based energy lender. Message 3466196

DIVIDENDS

Akita Drilling Ltd.'s (AKT/TSE) Board of Directors approved the payment of a quarterly dividend to shareholders. AKITA Drilling Ltd, declared an ordinary cash dividend of six cents ($0.06) per share on the outstanding Class A Non-Voting and Class B Common shares of the Corporation with a Record Date as at the close of business on March 20, 1998 and a payment date of April 1, 1998.

MISC.

Energy Communications Inc. will hold their second Saskatchewan Oil and Gas Investment Forum. This session features three dynamic oil and gas companies who will provide you with a time efficient insight into their

inherent investment opportunities. All are demonstrating rapid growth and share appreciation and will benefit from stronger commodity prices.

The executives of the participating companies will each give a brief, visually supported presentation on their corporate strategy and on the projected growth of their respective corporations. These firms have collectively budgeted for over $44 million in capital expenditures for the 1998 fiscal year.

Sufficient time will be provided in an informal environment to meet with, and direct questions to the participating company executives after the luncheon.

We encourage all to extend this invitation to your clients or other interested investors.

Call 403-266-7209 to register or fax your name, company name, address and phone number to 1-800-832-8281

There is no charge for this function.

Please choose one of the following venues:

Saskatoon: Wednesday, Feb. 18th, 1998
Radisson Hotel Saskatchewan
11:30 - 1:00 P.M.

Regina: Thursday, Feb. 19th, 1998
Hotel Saskatchewan, Radisson Plaza
11:30 - 1:00 P.M.

The presenting companies are:

OPAL ENERGY INC.
TSE Symbol - OPE
Oil & Liquids: 1,300 BOPD
Gas: 8.12 MMCFD
Areas of Exploration and Production
Oil: Freemont, Epping (Sask)
Gas: Gilby, Clive, Atlee

PURCELL ENERGY LTD.
TSE Symbol - PEL
Daily Production Rates
Oil & Liquids: 720 BOPD
Gas: 7.8 MMCFD
Areas of Exploration and Production
Primarily Alberta & Saskatchewan

BEAU CANADA EXPLORATION LTD.
TSE & ME Symbol - BAU
Daily Production Rates
Oil & Liquids: 9,700 BOPD
Gas: 70.0 MMCFD
Areas of Exploration and Production:
BC, Alberta and Saskatchewan


Please make note of this. The Financial Post may be thinking of eliminating columns from their internet site. Send them a short e-mail message telling them that you hope dropping of the columns is only temporary. Here is the address: Executive Producer. Email: swickens@canoe.ca

These columns provided quite a little of information related to the Canadian Oils.

END - END



To: Crocodile who wrote (9128)2/20/1998 1:05:00 AM
From: Crocodile  Read Replies (7) | Respond to of 15196
 
MARKET ACTIVITY/TRADING NOTES FOR DAY ENDING THURSDAY, FEBRUARY 19, 1998 (1)

Friday, February 20, 1998

Blue chips tumbled as Wall Street took a breather after six successive days of gains. Bay Street posted losses for a third day as investors sold companies that have outperformed so far this year

The Dow Jones industrial average fell 75.48 points, or 0.9%, to 8375.58.
ÿ
The Nasdaq composite index rose 11.28 points, or 0.7%, to 1727.01 on the back of strong gains by technology stocks.
ÿ
The Standard & Poor's 500 composite index fell 3.78 points, or 0.4%, to 1028.28.
ÿ
Trading volume was moderate, with about 587 million shares changing hands on the New York Stock Exchange, down from about 610.9 million shares traded on Wednesday.
ÿ
Traders said they were little surprised by the Dow's pullback after its string of six straight records.
ÿ
They said there could be heightened volatility today because of the "double witching" expiration of individual and index options.
ÿ
Technology stocks rallied, inspired by earnings-related gains in Dell Computer Corp.
ÿ
"There's a divergence in the market created by Dell," said Warren Epstein, director trading at Richard Rosenblatt.
ÿ
Dell shares (dell/nasdaq) climbed US$9 9/16 to US$1223 1/84 after the direct computer seller reported more than a 50% increase in fourth-quarter earnings and set a two-for-one stock split.
ÿ
Other computer-related stocks rose on the news, including semiconductor maker Intel Corp., which was upgraded to "strong buy" from "market perform" by brokerage house Bankers Trust Alex. Brown. Intel shares (intc/nasdaq) gained US$35 1/88 to US$90 9/16.
ÿ
Among shares pulling back were drug maker Merck & Co. (mrk/nyse), which fell US$2 to US$1221 1/84. The stock retreated after posting big gains this week on investor optimism that its new asthma pill would gain U.S. marketing approval soon.
ÿ
Canadian stocks fell for a third day, led by Canadian Imperial Bank of Commerce and other major banks as investors sold shares that have outperformed the broader market this year.
ÿ
The Toronto Stock Exchange 300 composite index fell 57.95 points, or 0.8%, to 6886.26 - the first time the benchmark index had slipped below the 6900 level in six trading sessions.
ÿ
About 116.7 million shares changed hands, up from 113.5 million shares traded Wednesday.
ÿ
CIBC shares (CM/Tse) slipped $1.90 to $43.55, Bank of Nova Scotia (bns/tse) slid $1.25 to $33.90.
ÿ
"Investors are reacting to analysts' comments that banks have reached reasonable prices," said Jim Muir, a senior vice-president with AGF Trust Co. "Short-term players look at any excuse to take money out."
ÿ
Alcan Aluminium Ltd., which accounts for 1.8% of the TSE 300, lost ground after it said it will construct a 375,000-tonne capacity aluminum smelter in Alma, Que., at a cost of US$1.6 billion.
ÿ
Alcan shares (al/tse) fell $1.65 to $42.50.
ÿ
Some investors questioned Alcan's decision to increase its aluminum-making production by 19% when the industry is already plagued by idle capacity, analysts said.
ÿ
Energy issues were mixed as investors found value after a 6.7% decline in the subgroup this year.
ÿ
Gulf Canada Resources Ltd. (gou/tse) gained 5› to $7.10, Tarragon Oil & Gas Ltd. (tn/tse) climbed 25› to $8.85 while Talisman Energy Inc. (tlm/tse) fell 55› to $39.70.
ÿ
Air Canada was the most active issue on the TSE. The shares (ac/tse) fell 75› to $13.60 on volume of 5.4 million shares.
ÿ
While Air Canada recorded a fourth-quarter profit of 59› a share, compared with a year-earlier loss of 14› a share, a $115-million tax gain offset unexpectedly high costs to maintain aircraft. Excluding the gain, some analysts said the results were worse than expected.
ÿ
Other Canadian markets closed lower.
ÿ
The Montreal Exchange portfolio fell 42.77 points, or 1.2%, to 3551.18.
ÿ
The Vancouver Stock Exchange fell 2.48 points, or 0.4%, to 628.14.

For a scorecard of trading activity on all Canadian Stock Exchanges, go to:
quote.yahoo.com .

REFERENCE: Canadian Market Summary
canoe2.canoe.ca

Major international markets ended mostly lower.
ÿ
London: The FT-SE 100 index edged 4.9 points lower to close at 5718.5.
ÿ
Frankfurt: Germany's blue-chip Dax index ended below the key 4600 level, after hitting another record high in early trade. The Dax closed at 4582.4, down 46.43 points or 1%.
ÿ
Tokyo: Japanese stocks ended flat after a rally on hopes for a large supplementary budget for the next fiscal year dwindled. The 225-share Nikkei average closed at 16,616.48, up 2.59 points.
ÿ
Hong Kong: A strong budget-related rally fizzled, with the Hang Seng index ending at 10,581.27, down 89.68 points or 0.8%.
ÿ
Sydney: The Australian stock market gave up earlier gains to end flat. The all ordinaries index closed at 2658.8, down 2.4 points.

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

Central banks expected to control inflation

TORONTO (CP) - Stern central bankers, poised to choke off inflation at the earliest signs, are helping to keep interest rates low and promote economic growth in North America and Europe, a financial expert with Canada Trust said Thursday.
ÿ
Vigilant central bank policies and G-7 leaders are also bringing pressure on Asian countries to stabilize financial systems and restore investor confidence, said Steve Saldanha, an economist with Canada's largest trust company.
ÿ
He's optimistic Asian policymakers - especially in Japan, the world's second largest economy - will co-operate.

Although the Asian crisis has shaken economies and frightened investors, Saldanha said signs suggest the region's troubles will be contained. "The world is not falling apart, it's not becoming unhinged. The environment for investors is still relatively favorable."
ÿ
Central bankers have become so intolerant of inflation that they're launching pre-emptive strikes - boosting interest rates moderately in mere anticipation of inflation, Saldanha told a news conference. That's helping to keep any threat of inflation - which erodes earning power - at bay. ÿ"There are bumps along the way (but) the trend is unmistakable. If inflation is going to be low, we can expect a low interest rate environment ... because of tough central bank policy."
ÿ
Expect domestic growth to run as high as 3.5 per cent this year, topping the G-7, with American growth under three per cent, he predicted. Saldanha's economic predictions have been cut by half a point because of the Asian problems.
ÿ
And Canadian employment, now just under nine per cent, should fall close to eight per cent this year, while Americans are enjoying their lowest jobless rates in 25 years, he predicts.
ÿ
"We have a strong domestic economy, our major trading partner is relatively healthy, which should lead Canada to grow in a 3- to 3.5 per cent range over the next 12 months."
ÿ
Canada Trust's predictions are in line with most other economic forecasts.
ÿ
Meanwhile, revolutions in technology have been another key force in boosting corporate earnings and equity markets while improving workers' pay, said Saldanha.
ÿ
Companies willing to invest in new equipment and restructuring can maintain profitability, he said.
ÿ
That has heightened worker insecurity. Despite nearly seven years of solid growth in the U.S. economy, workers remain fearful because they know an emphasis on profitability makes them expendable.
ÿ
But that insecurity keeps a lid on wage demands, Saldanha argued. Unrest over high unemployment has created growing problems in parts of Europe, where he predicts moderate growth of between 2 and 2.5 per cent. Germany, the world's third-biggest economy, has a jobless rate of 12.6 per cent and is facing ugly clashes between thousands of unemployed and police.
ÿ
Some experts fear its troubles could have wider global implications than what has happened in Japan. ÿBut Canada Trust says European stock markets are doing well and remain good investments because companies are restructuring to boost profits.

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

Trade surplus revives C$ - By DAVID THOMAS - Economics Reporter The Financial Post

Growth in Canada's exports outpaces imports in December; higher than expected trade surplus could narrow current account deficit. The C$ jumped sharply yesterday after Statistics Canada released figures showing Canada's trade surplus unexpectedly widened by one-third in
December.
ÿ
The trading surplus rose to $1.74 billion from a revised $1.3 billion in November, as exports continued to grow after spending most of 1997 in the shadow of an import boom. Exports were up 3.9%, while imports rose 2.2%.
ÿ
The wider than expected surplus led economists to conclude the current account deficit, which ballooned last year, may have bottomed out.
ÿ
That view was shared by currency traders, who bid the C$ up sharply after the figures were released in the morning. The C$ traded as high as US70.42› before closing at US70.37›, up US0.56›. It bottomed out at US68.25› Jan. 29.

"These numbers are definitely positive for the exchange rate," said Randall

"These numbers are definitely positive for the exchange rate," said Randall Powley, senior economist at Scotia Capital Markets. [Canadian dollar]
ÿ
The current account deficit hit an annualized level of $25.5 billion in the third quarter and economists had forecast it would exceed $30 billion for the full year. Fourth-quarter numbers are scheduled for release March 2.
ÿ
The current account includes the trade balance in goods, which was released yesterday, plus trade in services and investment flows. A currency tends to drop in value when the current account swells, because the country is forced to borrow more abroad to finance its balance of payments.
ÿ
"The much-feared widening in the current account deficit to over $30 billion does not seem to have materialized," said Sherry Cooper, chief economist at Nesbitt Burns Inc. "It probably consolidated [at] around $25 billion."
ÿ
Bank of Montreal also revised its current account forecast to a deficit of $25 billion from $30 billion. CIBC Wood Gundy Securities Inc. economists dropped their estimate by several billion dollars to an even more bullish $23 billion.
ÿ
Other economists said the turnaround might take a bit longer and the current account deficit will still surpass $30 billion before showing some improvement later this year.
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"The bad news isn't completely over," cautioned Powley, who forecasts a deficit of "at least $29 billion."

Andrew Pyle, an economist with ABN Amro Bank Canada, said December's performance "will not be enough to prevent a widening in the current account to at least $30 billion."
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As for the trade figures, exports gained on a huge 13.9% gain in the auto sector, some of which was the result of a temporary backlog after shipping delays in November, Statistics Canada reported. "Some manufacturers delayed exports of new models in November to allow time for additional quality checks," it said.
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Forestry, the worst performing of the economy's major sectors, had a 1.5% drop in exports. On the import side, crude oil shipments boosted energy products to a 22.1% gain.
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Exports totalled $26.7 billion in December, $77.8 billion in the fourth quarter and $301.3 billion for the year. Imports hit $24.9 billion in December, $74 billion in the quarter and $278.2 billion for the year. All numbers were records.
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There was a swing toward higher export versus import growth at the end of the year.

In the fourth quarter, exports rose 2.8% while imports were up 4.2%. In all of 1997, imports were up 16.1% while exports gained 7.4%. Imports have been soaring on a strong appetite among businesses for machinery and equipment.
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A slowdown in equipment investment is expected to lend improvement to the trade and current account balances this year.
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In the U.S., trade figures released yesterday showed the trade deficit widened to US$10.8 billion in December. Goods exports rose 1.9% but were outpaced by a 4.1% gain in imports.
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Bruce Steinberg, chief economist at Merrill Lynch & Co., said a drop in exports to emerging markets in Asia has not turned up in the figures.
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The region's weakness will take a larger bite out of U.S. exports in the months ahead, causing trade to "deteriorate substantially in the upcoming quarter," he said.

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Thursday, February 19, 1998

Asia worries dominate Rubin's G7 agenda

WASHINGTON (Reuters) - Treasury Secretary Robert Rubin Thursday geared up for a meeting of the Group of Seven finance ministers this weekend by reminding both Japan and Indonesia of the urgent need for major economic reforms.
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He told reporters that the economic turmoil that has ravaged much of Asiawill dominate the talks at the gathering in London of economic leaders from the world's top industrial nations.
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Noting that the crisis in Asia cannot be resolved unless major industrial nations boost their own economies, Rubin signaled the G7 would put renewed pressure on Japan to do more to boost domestic demand and prevent its faltering economy from falling into a recession.
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"Although the key to recovery lies with the Asian nations, strong growth in the G7 is also necessary for a successful resolution," Rubin said, adding Japan had "an especially crucial role" to play.
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"If Japan were on a strong economic track led by domestic demand-led growth, it would be a larger market for Asian goods, a source of greater bank credit and other capital flows, and a wellspring of confidence for the region," Rubin said.
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The G7 is made up of Britain, Canada, France, Germany, Italy, Japan and the United States.
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Even though he reminded Europe that the Continent's own problem with high unemployment required a strong commitment to economic change, Rubin said he expected his counterparts from the region to back his message to Tokyo.
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"I suspect their analysis is not going to be very different from our own," he said.
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Rubin declined to comment directly on market speculation the Indonesian government was willing to compromise on President Suharto's wish to establish a currency board, a rigid system criticized by the U.S. government and the International Monetary Fund for the risks it poses to financial stability.
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"There is a path to recovery and that path lies in the implementation of an effective reform program," he said.
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A senior Treasury official told reporters separately that establishing a currency board would provide "no silver bullets" for Jakarta's woes, which he said the U.S. administration was monitoring closely.
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Rubin said a solid commitment to follow through on reforms in distressed Asian countries was vital. "Only when sound policies are pursued will confidence, capital and growth return to these nations," he said.
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He added there would be discussion about proposed short-term trade credits to struggling Asian countries that he said could speed a return of growth in the region.
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He also renewed a call for Congress to approve funding for the IMF and for a special supplementary borrowing arrangement, saying the IMF was vital in leading multilateral efforts to prevent the current Asian economic crisis from spreading and to deal with future such global threats.
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He said the administration had "made a lot of progress" on its bid to win congressional backing but said there was still "a very large challenge ahead of us."
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The IMF has put together international rescue packages totaling more than $100 billion for the three hardest-hit countries in Asia -- Indonesia, Thailand and South Korea.
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Part of the G7 meeting will focus on a broader effort to revamp "international financial architecture" -- making the private sector, including banks, share the burden when crises arise, strengthening financial systems and imposing tougher rules for disclosure of financial information, Rubin said.
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The G7 ministers will be joined by representatives from Russia on Sunday for a separate discussion of employment issues in the global economy.

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Japan posts first deficit with Asia in eight years

TOKYO, Feb 19 (Reuters) - Japan posted its first monthly trade deficit with Asia in eight years on Thursday, as economic turmoil and depreciated currencies sapped demand for Japanese exports in countries like South Korea, Thailand and Indonesia.
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While Japan's customs-cleared trade surplus with the world showed a conspicuous rise in January to 381.50 billion yen ($3.02 billion), the Finance Ministry said the country recorded a 34.26 billion yen ($271 million) deficit with Asia.
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It was the first deficit with the region since January 1990, as exports to the region slid nine percent from a year earlier.
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Final trade balance figures for last year, which are being revised, will not be published until later this month, the ministry said.
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Economists said that while New Year's holidays always mean an export slowdown in January and helped pushed the Asia trade balance into deficit, exports to the region were clearly on a downward trend and would continue to slide.
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"From here on, we will see marked drops in Japan's trade surplus with Asia, not only because exports will keep falling, but also because we will have growth in imports from the region," said Teruyuki Morinaga, an economist at the Industrial Bank of Japan.
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Asian economies were still too traumatised to embark on a full-fledged export drive, but would eventually get there, he added.
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The Finance Ministry said, however, that it was difficult to predict the direction of Japan's trade with Asia.
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"As Asian nations recover their price competitiveness in global markets with the depreciation of their currencies, Japanese exports to them of materials needed to make finished goods may increase," a ministry official said. Bleak prospects for Japanese exports to Asia mean Japanese manufacturers will concentrate on exports to the United States and Europe, economists said.
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Japan's trade surplus with the United States rose 66 percent in January from a year earlier to 493.85 billion yen ($3.91 billion) and the surplus with Europe doubled to 186.42 billion yen ($1.47 billion).
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Within Asia, exports to South Korea suffered most, plunging 42 percent from a year earlier against a two percent increase in imports, sending Japan's trade balance with South Korea into a 3.39 billion yen ($26.9 million) deficit.
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Exports to Thailand also dived, falling 35 percent and halving Japan's trade surplus with the country to 1.69 billion yen ($13.4 million). Imports from Thailand fell 4.3 percent.
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For Indonesia and Malaysia, Japanese exports fell 18 percent and 16 percent respectively.
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And while economists said imports from countries that had devalued their currencies would look weaker in yen terms, key imports from these countries -- oil for Indonesia and lumber for Malaysia -- took a beating. Imports from Indonesia dropped 16 percent while those from Malaysia fell 18 percent.
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Japan recorded a 91.75 billion yen ($728 million) trade deficit with Indonesia and a 18.27 billion yen ($145 million) deficit with Malaysia.
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Within the region, the Taiwanese economy appeared comparatively healthy. Japan's trade surplus with Taiwan jumped 54 percent from a year earlier as exports rose 16 percent against an eight percent fall in imports.
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