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Gold/Mining/Energy : KERM'S KORNER -- Ignore unavailable to you. Want to Upgrade?


To: Kerm Yerman who wrote (9191)2/23/1998 7:29:00 PM
From: Arnie  Respond to of 15196
 
EARNINGS / Rider Resources Inc. reports 1997 results

NET INCOME GROWS BY 187%

Rider's net income for 1997 increased to $1,224,000 ($0.45 per
share) compared to $427,000 ($0.18 per share) in 1996. Revenues for 1997
totalled $4,472,000, an increase of 78% over 1996 revenues of $2,511,000.
(See table)

CASH FLOW INCREASES BY 112%

Cash flow for the year increased to $2,682,000 ($0.98 per share) from
$1,267,000 ($0.55 per share) in 1996.

PROVEN OIL AND GAS RESERVES EXPAND BY 75%

Rider's proven reserves, as of January 1, 1998 increased to 2,640 MBOE
from 1,507 MBOE at the end of 1996. Total proven plus probable reserves
increased to 3,785 MBOE from 2,495 MBOE at December 31, 1996. The company has
replaced its 1997 production by 8 times on the basis of proven reserves only.
Finding and development costs for 1997 were $3.67 per BOE for proven reserves
and $3.27 per BOE for proven plus probable reserves.

1997 production of oil and gas averaged 454 barrels of oil equivalent per
day (1996 - 280 BOED).

HIGHLIGHTS
----------
Earnings Cash Cash Flow
Earnings(x) Per Share Flow(x) Per Share Revenue(x)
----------- --------- ------- --------- ----------
Fiscal YTD 1997 $ 1,224 $ 0.45 $ 2,682 $ 0.98 $ 4,472
1996 $ 427 $ 0.18 $ 1,267 $ 0.55 $ 2,511
1995 $ 139 $ 0.06 $ 757 $ 0.35 $ 1,941

(x) thousands

Rider's Class A shares are listed on the Toronto Stock Exchange under the
symbol ''RRI.A''.



To: Kerm Yerman who wrote (9191)2/23/1998 7:37:00 PM
From: Arnie  Respond to of 15196
 
GENERAL INTEREST / NEB submits Study on Trans Quebec & Maritimes

CALGARY, Feb. 23 /CNW/ - The National Energy Board (''NEB'') on Friday,
20 February submitted to the federal Minister of Environment and to the
Canadian Environmental Assessment Agency (the ''Agency'') a copy of its
Comprehensive Study Report (''CSR''), which was prepared in accordance with
the Canadian Environmental Assessment Act, with respect to Trans Qu‚bec &
Maritimes Pipeline Inc.'s (''TQM'') application to construct a natural gas
pipeline from Lachenaie, Quebec to East Hereford, Quebec near the New
Hampshire border, where the proposed pipeline would connect with the Portland
Natural Gas Transmission System (''PNGTS''). The project is known as the
''PNGTS Extension''. The report was submitted on behalf of the NEB and the
Canadian Coast Guard, Fisheries and Ocean Canada.

The NEB concluded that the PNGTS Extension project is not likely to
cause significant adverse environmental effects, provided that the mitigative
measures identified during the public hearing are implemented and enforced.
The Board indicated that, should it find that the PNGTS Extension is required
by public convenience and necessity, a series of environmental conditions
would be included in the certificate.

The CSR results from a public hearing that the NEB held from 17 November
to 17 December 1997 in Montreal and Magog, Quebec to consider the PNGTS
Extension. The hearing was also used as a forum for public participation in
the comprehensive study of the project.

The following steps will occur prior to the NEB making a decision on the
PNGTS Extension project:

- the Agency will issue the CSR for public review and comment; and
- the Minister of Environment will take a course of action after taking
into consideration the CSR and any comments filed.

TQM applied for approval to construct a 213.2-kilometre (132.2-mile)
pipeline from Lachenaie to the Canada/U.S. border near East Hereford. TQM
also requested approval to install, for the first year of operation, a 7.0
megawatt electric motor driven compressor unit at Lachenaie and two meter
stations, one at Waterloo and one at East Hereford. In the second year of
operation, TQM proposes to install an additional 3.2 megawatt electric motor
driven compressor unit at East Hereford and one gas aftercooler unit at
Lachenaie. The estimated cost of the project is $270 million with a planned
in-service date of 1 November 1998.

Beginning 1 November 1998, 4.3 million cubic metres (152.2 million cubic
feet) per day of natural gas would be delivered at East Hereford to supply
markets in the U.S. Northeast and 1.0 million cubic metres (33.7 million cubic
feet) per day would be delivered at Waterloo to supply markets in the Eastern
Townships of Quebec. In the second year of operation the deliveries would
increase to 5.9 million cubic metres (210.0 million cubic feet) per day for
East Hereford and to 1.4 million cubic metres (48.7 million cubic feet) per
day for Waterloo.



To: Kerm Yerman who wrote (9191)2/23/1998 7:39:00 PM
From: Arnie  Respond to of 15196
 
PIPELINES / ATCO Ltd. reports 1997 Results

CALGARY, Feb. 23 /CNW/ - The ATCO Group reported earnings attributable to
Class I and Class II shares for the year ended December 31, 1997 of $81.2
million ($2.68 per share) on revenues of $2,045.1 million. Comparative
figures for 1996 were earnings of $80.1 million ($2.63 per share) on revenues
of $1,934.1 million. 1996 earnings included a gain of $6.8 million ($0.22 per
share) from the sale of ATCOR.

Cash flow from operations for the year ended December 31, 1997 was $410.6
million compared to $383.3 million in 1996.

The 1997 earnings reflect strong performance by all of the Corporation's
units and were achieved despite temperatures that were 18.7% warmer than 1996
in the main service areas of the Corporation's natural gas utility operations.
Other significant factors impacting 1997 results were lower financing costs
and increased sales in the Corporation's electric power operations.

Earnings attributable to Class I and Class II Shares for the three
months ended December 31, 1997 were $20.7 million ($0.69 per share) on
revenues of $544.6 million compared with $18.5 million ($0.61 per share) on
revenues of $546.6 million in the previous year.

Cash flow from operations for the three months ended December 31, 1997
was $112.0 million compared to $101.0 million in 1996.

The Board of Directors declared a first quarter dividend of 17.0 cents
per Class I and Class II shares, up from 14.0 cents in each of the previous
four quarters. The dividend is payable March 31, 1998 to shareholders of
record on March 16, 1998.

The ATCO Group of Companies is engaged in electric power generation,
transmission and distribution; natural gas gathering, processing,
transmission, storage and distribution; workforce housing and technical
facilities management.



To: Kerm Yerman who wrote (9191)2/23/1998 7:40:00 PM
From: Arnie  Respond to of 15196
 
DIVIDEND / ATCO Ltd

CALGARY, Feb. 23 /CNW/ - On February 23, 1998, the Board of Directors of
ATCO Ltd. declared the following quarterly dividends:

TSE Stock Dividend Record Payment
Shares Symbol per Share ($) Date (1998) Date (1998)
---------- ----------- --------------- ------------- -------------

Class I
Non-Voting ACO.X 0.17 Mar 16 Mar 31
Class II
Voting ACO.Y 0.17 Mar 16 Mar 31

ATCO LTD.

P.J. House
Vice-President, Corporate Secretary



To: Kerm Yerman who wrote (9191)2/23/1998 7:44:00 PM
From: Arnie  Respond to of 15196
 
ENERGY TRUSTS / Gas Management Income Fund signs Management Agreement

TSE Symbol: GIF.UN

TORONTO, Feb. 23 /CNW/ - Gas Management Income Fund today reported its
subsidiary, Alliance Gas Management Inc. of Markham, has signed an energy
management agreement with Duke Energy Marketing LP which will see Duke manage
the supply, storage and transportation of natural gas on behalf of Alliance.

Duke Energy Marketing LP is a joint venture between Duke Energy Corp and
Mobil Oil Canada.

''This represents an important addition to our operations,'' said Paul
Woods, President and CEO of Alliance. ''With Duke, we now have full access to
buying long term gas and have the support to manage our portfolio of gas
supply as efficiently as possible.''

The five-year agreement allows Alliance flexibility on such key gas
supply issues as when to buy gas, which largely determines price.

Another significant feature of the agreement is Duke's management of the
gas transportation and storage requirements of Alliance.

The agreement positions Alliance for anticipated regulatory changes which
will allow gas wholesalers to manage the transportation and storage of natural
gas on behalf of their customers, providing an opportunity to significantly
increase wholesaler revenue base. Gas transportation and storage are currently
the domain of the utilities and represent approximately one third of the
average residential gas bill.

''This agreement enables us to more economically lock-in future gas
supply costs and we expect this will result in considerable savings for our
customers in the form of still lower gas prices,'' said Woods. ''On top of
this, Alliance, Alliance's customers and Duke will share any profits generated
by the efficient management of Alliance's gas transportation and storage, to
deliver better value to both Alliance customers and Gas Management
unitholders.

''This agreement with Alliance Gas Management represents a significant
expansion of our business,'' said Alfred Sorensen, President of Duke Energy
Marketing. ''We are extremely pleased to win this mandate to act as Energy
Manager for Alliance Gas.''

Consumers Gas and Union Gas are seeking Ontario Energy Board approval to
exit the merchant functions as early as mid-1999, as these operations are not
included in their rate base and do not contribute to their overall level of
profit.

Duke Energy Corp is a global energy company with more than $20 billion in
assets. Duke Energy companies provide electric service to approximately two
million customers; operate pipelines that deliver 12% of the natural gas
consumed in the United States; and are leading marketers of electricity,
natural gas and natural gas liquids. Globally, the companies develop, own and
operate energy facilities and provide engineering, management, operating and
environmental services.

Gas Management Income Fund provides unitholders with regular income and
the potential for growth through its ownership of the common shares, preferred
shares and notes of Alliance Gas Management Inc., a leading Canadian
wholesaler of natural gas to residential and small commercial users.
Established in 1991, Alliance Gas provides approximately 500,000 Canadian
customer equivalents (residential and commercial users) with access to savings
and stable price natural gas contracts. Gas Management Income Fund units are
traded on The Toronto Stock Exchange under the symbol GIF.UN. The Fund is
eligible for RRSPs, RRIFs and DPSPs.



To: Kerm Yerman who wrote (9191)2/23/1998 7:47:00 PM
From: Arnie  Respond to of 15196
 
CORP. / Black Sea Energy announces an Expanded Management Team

CALGARY, Feb. 23 /CNW/ - Robert M. Friedland, Chairman, announced today
that an expanded management team headed by newly-appointed President and Chief
Executive Officer Barry W. Harrison has been named to direct the future of
Black Sea Energy.

Mr. Friedland also announced that while he will remain as a director, he
will step down as Chairman of the Board. Clint A. Hussin, former Black Sea
President and CEO, will replace Mr. Friedland as chairman. All appointments
are effective immediately.

''Black Sea is a maturing company'', said Mr. Friedland. ''Since going
public last June, it has acquired significant new land holdings and increased
daily production from the Tura Petroleum joint venture to approximately 8,850
barrels per day. The new appointments strengthen the management team and give
it the expertise needed to combine operating profitability with the ability to
pursue opportunities for future growth.''

An experienced oil and gas executive, Mr. Harrison has held many senior
management positions in the oil and gas industry including President and CEO
of Mark Resources Inc. and its predecessor Blue Sky Oil and Gas Ltd, as well
as President and CEO of Quest Oil and Gas Inc. He currently serves on the
board of directors of PanCanadian Petroleum Ltd. and Wawanesa Mutual Insurance
Co. ''Mr. Harrison's proven leadership and his knowledge of Canadian markets
will help Black Sea move forward,'' Mr. Friedland said.

Mr. Hussin's leadership in Black Sea's acquisition of three
fully-operational Russian projects are the foundation of the company's current
success. As chairman, he will devote significantly more time to the Russian
operations and explore opportunities for further expansion.

Mr. Burrows joins Black Sea after a successful career as a senior partner
with Deloitte & Touche Chartered Accountants, where he has served as Managing
Partner of the Calgary office and was responsible for serving many of that
firm's domestic and foreign oil and gas clients.

Black Sea Energy is a Canadian company focused exclusively on the
initiation, rehabilitation, exploration and development of major oil
properties in Russia. With Russian partners, the company is actively involved
in two exploration and development projects, Tura Petroleum and Radonezh
Petroleum in Western Siberia and one production rehabilitation project. Kuban
Technologies in the Krasnodar region of Southern Russia.

Black Sea Energy's common shares trade on the Toronto Stock Exchange
under the symbol BSX.



To: Kerm Yerman who wrote (9191)2/23/1998 7:52:00 PM
From: Arnie  Respond to of 15196
 
ENERGY TRUSTS / Gas Management Income Fund reports 1997 Results

TSE Symbol: GIF.UN

TORONTO, Feb. 23 /CNW/ - Gas Management Income Fund, a trust with
interests in Canadian natural gas wholesaling, today reported its financial
results - and the performance of its underlying business, Alliance Gas
Management Inc.- for the fourth quarter and fiscal year ended December 31,
1997.

Gas Management Income Fund distributed $1.30 per unit in 1997, including
32.6 cents per unit in the fourth quarter.

As expected, cash flow rebounded in the fourth quarter reflecting both
the implementation of Agent Billing & Collection (ABC) Service and the
contribution of acquisitions made during 1997. After accounting for long term
debt retirement and a deposit on customer contract acquisitions, cash flow per
unit in the fourth quarter was 54 cents. This included 39 cents which was
attributable to Alliance's existing customer base and 15 cents generated from
contracts purchased from Priority Gas Marketing Inc. of Toronto. Gas
Management was therefore able to fund its fourth quarter distribution entirely
from operations.

For the 12 months, operating cash flow contributed $5.6 million or 94
cents per unit, while $2.4 million or 36 cents per unit came from a guarantee
established at the time of the Fund's initial public offering.

''Alliance is one of the largest natural gas wholesalers in Ontario ando
we're only beginning to see the positive impact of our leading market
position,'' said Paul Woods, President and CEO of Alliance Gas Management.
''We will continue to benefit from the implementation of ABC service over the
next year.''

Alliance doubled its customer base to approximately 500,000 customer
equivalents (a standard industry term to measure residential and commercial
users) in 1997. Woods said this ''underscores the value of our natural gas
wholesaling services in Ontario and two key strategic acquisitions we made
during the year.

''Based on our new-found size, and the fact that ABC service, a new
industry pricing mechanism, allows us to offer our customers our Price
Protection Programs, we believe operating margins and cash flow will improve
this year.''

ABC service was mandated by the Ontario Energy Board and slated for
introduction at the beginning of 1997, but was not fully rolled out until the
third quarter. This delay was the major impediment Alliance faced in
generating expected margins in 1997.

''Despite these delays, we managed to convert 28% or 140,000 customer
equivalents to Stable Price programs during the third and fourth quarters,''
said Woods, ''which exceeded our 135,000 customer target. Alliance is
forecasting the conversion of 50% of our customer base by the end of 1998.
Joining the Alliance Stable Price program means residential customers can lock
in their natural gas prices for up to five years, thereby protecting
themselves from price volatility, while ensuring their natural gas supply.''

Gas Management Income Fund's sales for fiscal 1997 were $75.3 million,
and $30.4 million in the fourth quarter compared to $16.1 million in the third
quarter. Sales growth was due to higher natural gas volumes attributable to
Alliance's enlarged customer base. The Fund's results for 1996 include only
the results of operations for the 12-day period from the completion of its
public offering on December 18 to December 31, 1996. As such, year over year
results are not comparable.

Gross margin for 1997 was $11.9 million or 16% of sales. Gross margin
improved to $5.2 million or 17% of sales in the fourth quarter compared to
$1.8 million or 11.3% of sales in the previous quarter. The improvement was
due to approximately 100,000 customer equivalents flowing on ABC service at
year end versus 13,000 at the end of the third quarter.

Gas Management Income Fund provides unitholders with regular income and
the potential for growth through ownership of the common shares, preferred
shares and notes of Alliance Gas Management Inc., a leading Canadian
wholesalers of natural gas to residential and small commercial users.
Established in 1991, Alliance provides approximately 500,000 Canadian customer
equivalents (residential and commercial users) with access to stable price
natural gas contracts. Gas Management Income Fund units are traded on The
Toronto Stock Exchange under the symbol GIF.UN. The Fund is eligible for
RRSPs, RRIFs and DPSPs.



To: Kerm Yerman who wrote (9191)2/23/1998 7:56:00 PM
From: Arnie  Respond to of 15196
 
SERVICE SECTOR / Computalog Ltd reports 1997 Results

(Thousands of Canadian Dollars except per share data)

1997 OPERATING RESULTS

Computalog Ltd. of Calgary, Alberta, announced today that for the year
ended December 31, 1997, it generated a net income of $19,726 ($1.49 per share
on a fully diluted basis) from revenues of $223,056. Cash flow from
operations totalled $38,117.

Further details and a comparison to 1996, are provided as follows:
<<

1997 1996
---- ----
Revenue $ 223,056 $ 147,945

Expenses
Operating 140,992 98,814
Selling, general & administration 22,308 16,257
Depreciation & amortization 16,036 10,797
Research & development 6,784 5,936
Loss (gain) on foreign exchange (989) (195)
Interest 2,801 626
--------- ---------
Net income from operations before
taxes and minority interest $ 35,124 $ 15,710

Income taxes 15,415 5,126
--------- ---------

Net income before minority interest $ 19,709 $ 10,584

Minority interest (17) (74)
--------- ---------
--------- ---------
Net Income $ 19,726 $ 10,658
--------- ---------

Earnings per share
Basic $ 1.73 $ 1.22
Fully diluted $ 1.49 $ 0.84

Cash flow from operations $ 38,117 $ 22,419
>>

During 1997, Computalog experienced revenue increases in all three of its
geographic segments. The increase in the Company's Canadian revenue was
primarily the result of the increase in drilling activity and the inclusion of
a full twelve months of revenue from the acquisition of Norjet Geotechnologies
Inc., which occurred on March 7, 1996. The western Canadian average drilling
rig count increased by 148, or 46%, and the number of well completions
increased by 3,140, or 32%, in 1997 compared to 1996. Canadian operations
comprised 64% of the Company's total revenue for the period, as compared to
65% during 1996.

The remainder of the Company's revenue is derived from the United States
and international markets. These two geographic areas contributed 21% and 15%
of the total revenue of Computalog, respectively, in 1997 compared to 18% and
17%, respectively, in 1996.

The increase in revenue in the United States primarily occurred in the
Company's wireline and directional drilling activities. The increase in
wireline services revenue occurred primarily as a result of the acquisition
strategy followed by Computalog during 1997. Through this effort, the Company
increased the size of its wireline operations from four stations operating 31
units in three states to 21 stations operating 70 wireline units in eight
states. Activity increases in the Gulf Coast region of Louisiana and in Texas
also had a positive impact on revenues. The Company's directional drilling
service experienced increased revenue as a consequence of recording a full
yearŠs revenue from The Bob Fournet Company, which was acquired in May 1996.
Revenue from wireline product sales in North America also increased as
independent wireline companies increased their purchases of products as the
demand for their services increased during the year.

The increase in revenue from international sales was the result of the
Company's success in obtaining directional drilling contracts outside North
America and the continued expansion of the Company's wireline operations in
Venezuela and, through a 49% interest in a joint venture to provide wireline
services, in Argentina. These revenue increases were offset by lower product
sales to international markets. Although South American wireline revenues are
increasing, the Venezuelan market has suffered a reduction in activity which
has been attributed to the reorganization of the state-owned oil company. The
Company believes that this reorganization will continue to effect revenues in
1998.

The increase in operating expenses in 1997 was consistent with the
increase in revenue although fixed cost efficiencies were gained through the
higher levels of activity experienced during the year. During 1997, revenues
increased 51% and operating expenses increased 43%. Operating expenses are
approximately 64% of operating revenues during 1997 as compared to 67% during
1996. In preparation for new segmented reporting standards the Company has
more closely defined operating, selling, general and administrative, and
research and development expenses. Certain comparative figures have therefore
been reclassified to conform with the current year's presentation.

In 1997, selling, general and administrative expenses increased by $6.1
million, or 37%, to $22.3 million. These expenses represented 10% of revenue
in 1997 compared to 11% of revenue in 1996. During 1997, the Company
increased its sales and administration efforts in the United States to take
advantage of Computalog's expanding operation. Selling, general and
administration costs increased in Canada as a result of increased activity and
the initiation of a financial accounting and information system replacement
project. Internationally, the Company focused its efforts to complement the
expansion of services into Venezuela and Argentina.

In 1997, depreciation and amortization expenses increased $5.2 million,
or 49%, to $16.0 million as compared to 1996. This increase was due to the
amortization of goodwill acquired of $1.6 million, the depreciation on assets
acquired through acquisitions and on new asset additions of $2.9 million,
lower gains from the disposal of certain assets of $0.5 million and asset
writeoffs during 1997 of $0.2 million.
$2.2 million as the
Company maintained higher average bank borrowings during the first half of
1997 as compared to 1996. During August of 1997, Computalog completed the
private placement of U.S. $35 million in unsecured senior notes which bear
interest at 7.78% payable semi-annually. The notes have an average term of
6.08 years and require annual principal repayments of U.S. $7.0 million
commencing on September 1, 2001. The funds from this borrowing were used
primarily to repay bank debt, fund business acquisitions and purchase new
capital assets for market expansion and new international ventures. Excess
cash balances were held in United States dollars and were invested in low risk
short term deposits of less than 90 days. During January 1998, United States
dollar denominated short term deposits held by the parent company were
converted into Canadian Dollars.

Cash flow from operations before working capital changes totalled $38.1
million in 1997, an increase of $15.7 million, or 70%, from 1996. Working
capital changes resulted in a source of cash totalling $0.7 million in 1997.
In 1996, working capital used additional funds of $11.3 million. The funds
provided by working capital during 1997 were a result of higher accrued
liabilities offset by increased accounts receivable resulting from increased
revenues.

Computalog provides wellbore knowledge and solutions through its electric
wireline and directional drilling services. These services enable oil and gas
producers to manage risk and maximize production. The Company's common shares
trade on the Toronto Stock Exchange under the symbol CGH and on the Nasdaq
National Market. under the symbol CLTDF.

Certain statements included in this news release may constitute
''forward-looking statements'' within the meaning of the U.S. Private
Securities Litigation Reform Act of 1995. Such forward-looking statements
involve known and unknown risks, uncertainties and other factors that may
cause the actual results, performance or achievements of the Company, or
industry results, to be materially different from any future results,
performance or achievements expressed or implied by such forward-looking
statements.



To: Kerm Yerman who wrote (9191)2/23/1998 8:04:00 PM
From: Arnie  Respond to of 15196
 
EARNINGS / Niko Resources reports 1st 9 months results

Niko Resources Ltd. (ASE - NKO) announced its financial results for the three
and nine months ended December 31, 1997.

During the three months ended December 31, 1997 operating revenue increased
to $971,000 compared to $447,000 in 1996. Cash flow from operations rose to
$510,000 or $0.025 per share compared to $292,000 or $ 0.015 per share in
1996. The Company earned $234,000 or $0.011 per share compared to $260,000 or
$0.013 per share in 1996.

For the nine months ended December 31, 1997 revenue was $2,097,000 compared
to $892,000 in 1996. Cash flow from operations was $1,106,000 or $0.054 per
share compared to $353,000 or $ 0.022 per share in 1996. Net income was
$497,000 or $0.024 per share compared to net income of $270,000 or $0.010 per
share in 1996.

For further information please contact:

Niko Resources Ltd. (403) 262-1020
Edward Sampson, Executive Chairman or Paul Wright, Vice President Finance.



To: Kerm Yerman who wrote (9191)2/23/1998 8:06:00 PM
From: Arnie  Read Replies (7) | Respond to of 15196
 
FIELD ACTIVITIES / CityView Energy Corp updates Drilling


Capital Structure:
Fully Diluted: 12,607,068
Float: 5,522,049

MMC Exploration & Production (Philippines) Pte Ltd has been advised by the
operator ARCO Philippines Inc, that Hippo Well No. 1- at 0600 hours 23
February 1998 was at 940 metres (3082 feet) depth and running 20 inch casing.

MMC Exploration & Production (Philippines) Pte Ltd is owned 51% by MMC
Exploration and Production BV and 49% by CityView Energy Corporation
Limited's wholly owned subsidiary Western Resources N.L.

Yours faithfully

(Signed)

A P WOODS
Company Secretary/Chief Financial Officer

For further information contact
Australia - CityView Energy North America - Zoya Financial

Chris Vander Boom Steve Basra/Jasbir Gill
Tel: 011-61-89-474-1333 Tel: 416-214-2368
Fax: 011-61-89-474-5997 Fax: 416-214-2771
cityviewenergy.com emailjazz@wwonline.com



To: Kerm Yerman who wrote (9191)2/23/1998 8:28:00 PM
From: Arnie  Respond to of 15196
 
FIELD ACTIVITIES / Vision 2000 Exploration updates Pine Creek

Vision 2000 Exploration Ltd. (VNN.A: ASE) is pleased to announce that two
wells are scheduled to be drilled prior to breakup on company held lands in
the Pine Creek area of northern Alberta.

Vision 2000 has entered into a Farmout Agreement with an industry partner
covering two sections of land in which the company holds a 50% working
interest. Vision 2000 will retain a net 7.5% gross overriding royalty in the
test well convertible to a 25% working interest after payout and retain a 25%
working interest in the undrilled Farmout lands. A twenty (20) section Area
of Mutual Interest ("AMI") has been established surrounding the Farmout lands
in which Vision 2000 will retain a 25% working interest.

Vision 2000 will also participate with a 7% working interest in the deepening
of a currently suspended well targeting the deeper gas potential in the area.

Both of these developments fit the corporation's objectives to maximize
shareholder value by focusing its exploration efforts at the present time on
gas plays which have the potential to add significantly to the company's
reserve base.



To: Kerm Yerman who wrote (9191)2/23/1998 8:52:00 PM
From: Arnie  Respond to of 15196
 
FIELD ACTIVITIES / GHP Exploration commences Operations in Texas


GHP Exploration Corporation (CDN:GHPX.U) announced today that drilling
operations have begun on the Winfield Ranch 17 No. 1-E well located on the
Company's South Fort Stockton prospect in the highly productive Delaware
Basin of West Texas (News-July 9, 1997). The well is being drilled under a
"turnkey" contract and will take approximately nine months to reach total
depth. The Company has a 10% working interest in the prospect.

The primary objective is the Lower Ordovician Ellenburger Formation at a
depth of 26,000 feet. The prospect was identified by interpretation of a 1996
high quality 3-D seismic survey covering 40 square miles. The prospect is on
trend and in-between Gomez field (cumulative production of 4.7 trillion cubic
feet of gas (TCFG)) and Puckett field (cumulative production of 3.8 TCFG).
Additionally, the prospect is immediately south of the McComb field which has
estimated recoverable reserves of 160 billion cubic feet of gas. The 3-D
seismic interpretation over the prospect leasehold indicates that there are
multiple large structural closures which present several drilling
opportunities on the prospect acreage.

GHP engages in the exploration for and development and production of crude
oil and natural gas in the United States and Internationally with operations
and interests in acreage in the Gulf of Mexico, West Texas, Egypt and in
Tunisia. The Company currently has 17.7 million common shares outstanding.



To: Kerm Yerman who wrote (9191)2/23/1998 8:55:00 PM
From: Arnie  Respond to of 15196
 
FIELD ACTIVITIES / Nevis Petroleum signs Agreement with Suncor Energy


Nevis petroleum corporation (the "Corporation") a junior capital pool company
announced today that it has signed a Purchase and Sale Agreement with Suncor
Energy Inc. The Purchase and Sale Agreement contemplates the acquisition of
an 18% working interest in the Boundary Lake South Triassic "C" oil Unit, in
Northwest Alberta. This arm's length transaction is proposed to be the
Corporation's Major Transaction, as contemplated by Alberta Securities
Commission Policy 4.11 entitled, Junior Capital Pool Offerings ("Policy
4.11") and Circular No. 7 of The Alberta Stock Exchange ("Circular No. 7").

Pursuant to the Purchase and Sale Agreement, the Corporation would be
required to make a payment of $ 793,000.00, which will be financed by a
combination of cash from the treasury and a production loan from a Canadian
Chartered Bank.

In addition, and in conjunction with the Corporation's Major Transaction, the
Corporation intends to complete a private placement of approximately
1,300,000 common shares to be issued at 0.25 per share.

The property yielded an estimated net average production of 21 barrels per
day in 1997. Proven developed producing and undiscounted probable oil
reserves net to the Corporation before royalties are estimated to be 103,900
barrels. The probable oil reserves after discounting by 50% for risk are
estimated to be 19,300 barrels.

For further information, please contact:

W. (Bill) Barclay,
President & Chief Executive Officer
of the Corporation
at (403) 237-5155.



To: Kerm Yerman who wrote (9191)2/23/1998 11:11:00 PM
From: Arnie  Respond to of 15196
 
ENERGY TRUSTS / Enerplus Resource Fund replaces 157% of Production

CALGARY, Feb. 23 /CNW/ - Enerplus Resources Fund is pleased to announce
that it has closed the last of a series of fourth quarter 1997 acquisitions
for a total consideration of $21.2 million.

During 1997, Enerplus focused its acquisition and development activities
on natural gas properties adding 24.8 billion cubic feet (''bcf'') of proven
and 4.2 bcf of probable net natural gas reserves during the year, representing
77% of net 1997 reserves additions. Enerplus replaced 157% of its 1997
production at an average cost of $4.67 per barrel of oil equivalent net of
property dispositions. The Fund has consistently fully replaced its production
in each of the last 5 years and has done so at replacement costs below $5.00
per barrel of oil equivalent (''BOE'') each year.

The Fund's largest 1997 acquisition, which closed on February 17, 1998,
consisted of various working interests and royalty interests in the Medicine
Hat area of Alberta. The property currently produces 3.9 million cubic feet
of natural gas per day net to Enerplus and has added 1.17 million BOE of
proven and 0.39 million BOE of probable reserves to the Fund. The total
consideration paid in this transaction was $8.13 million, or $5.22 per BOE,
and the remaining economic reserve life of the property is over 28 years.

Other acquisitions completed by the Fund in the fourth quarter included
natural gas producing properties in the Harmattan Elkton Unit, Wembley,
Hotchkiss, Fox Valley, Bantry and Buck Lake areas, as well as oil producing
properties in Luseland, Hayter and Medicine River. During the first nine
months of 1997, the Fund had been a net seller of assets as over $13 million
in non-core properties were disposed of at favorable prices.

As a result of 1997 acquisition and development activities, Enerplus
Resources Fund has increased its year end total proven and probable reserves
base by 4.5% over 1996 levels and has increased its year end Reserve Life
Index from 12.5 years in 1996 to 13.0 years in 1997.