1
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
[ X ] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 1998.
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
Commission file number 0-29344
INDO-PACIFIC ENERGY LTD.
(Exact name of Registrant as specified in its charter)
Yukon Territory, Canada Not Applicable
(State or Jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
1200-1090 West Pender Street
Vancouver, British Columbia
Canada, V6E 2N7
(Address of Principal Executive Offices, including Postal Code)
Registrant's telephone number, (604) 682-6496
Securities to be registered pursuant to Section 12(b) of the Act:
Title of each class Name of each exchange on which registered
NONE
Securities to be registered pursuant to Section 12(g) of the Act:
Title of each class
Common Stock
Indicate by check mark if disclosure of delinquent filers pursuant to
Item 405 of Regulation S-K is not contained herein, and will not be
contained, to the best of the Registrant's knowledge, in definitive
proxy or information statements incorporated by reference in Part III
of this Form 10-K or any amendments to this Form 10-K: [ ]
As of December 31, 1998 the Registrant has outstanding 28,262,398
shares of common stock without par value.
2
Documents Incorporated by Reference
1. Form 10 Registration Statement filed with the Securities and
Exchange Commission on April 8, 1998, and all exhibits thereto.
2. Amendment No. 1 to the Form 10 Registration Statement filed with
the Securities and Exchange Commission on August 21, 1998, and all
exhibits thereto.
3. Amendment No. 2 to the Form 10 Registration Statement filed with
the Securities and Exchange Commission on November 16, 1998, and
all exhibits thereto.
4. Form 10-Q for the third quarter filed with the Securities and
Exchange Commission on November 5, 1998, and all exhibits thereto.
5. Form 10-Q for the third quarter filed with the Securities and
Exchange Commission on August 14, 1998, and all exhibits thereto.
6. Form 10-Q for the third quarter filed with the Securities and
Exchange Commission on June 19, 1998, and all exhibits thereto.
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PART I
ITEM 1. BUSINESS
General
The Registrant is an oil and gas exploration company based in
Vancouver, British Columbia, Canada with interests in the Austral-
Pacific region in hydrocarbon properties described in Item 2. The
Registrant is to a lesser extent involved in the development and
production of hydrocarbons. The majority of the Registrant's properties
are in the exploration stage. Total production revenue for the year
ended December 31, 1998 was $234,168. The Registrant's focus is on the
acquisition, exploration and development of properties in the Austral-
Pacific region.
Corporate History and Structure
The Registrant was incorporated on July 31, 1979 under the name
Pryme Energy Resources Ltd. under the Company Act (British Columbia,
Canada). On March 21, 1980 the Registrant became a reporting or
distributing company in British Columbia with the issuance of a receipt
for its initial prospectus offering. The business of the Registrant was
not successful and the Registrant was reorganized. On August 23, 1985
the name was changed to Newjay Resources Ltd. and a consolidation of
its common shares on a 2.5 old for one new basis occurred. The business
of the Registrant was the exploration for hydrocarbons in Alberta,
California and Texas. The business of the Registrant was not successful
and the Registrant was again reorganized. The Registrant applied to be,
and was deemed, inactive by the Vancouver Stock Exchange on February
26, 1993 and subsequently completed a reorganization satisfactory to
the Vancouver Stock Exchange and was removed from inactive status on
April 25, 1994. On August 25, 1993 the name of the Registrant was
changed to Consolidated Newjay Resources Ltd. and a consolidation of
its common shares on a 3.5 old for one new basis occurred. The
Registrant did not commence any business after these events until 1996.
In April 1995, control of the Registrant was acquired by Mr. Alex
Guidi, who is currently a member of the board of directors, chairman
and the promoter of the Registrant. On May 9, 1995 the name of the
Registrant was changed to its current name. A subdivision of its common
shares on a 1.5 new for one old basis occurred on April 15, 1996 and a
further subdivision of its common shares on a two new for one old basis
on May 31, 1996 occurred. The Registrant began to acquire its current
hydrocarbon assets in 1996.
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The common shares of the Registrant commenced trading in January,
1996 on the Bulletin Board operated by the National Association of
Securities Dealers, Inc.(the "Bulletin Board")and trades under the
symbol "INDX". Trading in the common shares of the Registrant was
halted by the Vancouver Stock Exchange on September 12, 1996 and the
Registrant voluntarily delisted from the Vancouver Stock Exchange on
September 13, 1996.
On September 25, 1997, the Registrant was continued from being a
corporation subsisting under the Company Act (British Columbia) to a
corporation subsisting under the Business Corporations Act (Yukon). The
Registrant maintains its head office in Vancouver, British Columbia and
an exploration office in Wellington, New Zealand.
From 1996 to 1999, the Registrant acquired interests in petroleum
exploration licences and permits in New Zealand, Australia and Papua
New Guinea. The Registrant also acquired the outstanding shares of
Ngatoro Energy Limited [formerly, Minora Energy (New Zealand) Limited]
and entered into an agreement with China National Oil and Gas
Exploration and Development Corporation for a Technical Study contract
in the Nanling and Wuwei basins, Anhui province, China. The exploration
of certain of the petroleum interests commenced in 1996. The Registrant
continued to acquire and explore petroleum interests.
The Registrant's operations are conducted through its wholly-owned
subsidiaries, as described below:
Indo-Pacific Energy Ltd.
Source Rock Holdings Limited - Indo Overseas Exploration
Limited (B.C.)
Indo-Pacific Energy (NZ) Limited - Indo-Pacific Energy (PNG)
Ltd.
- Indo-Pacific Energy Pty.
Ltd. (Aust.)
Ngatoro Energy Limited PEP 38716 Limited
Unless the context indicates otherwise, the "Registrant" will
refer to Indo-Pacific Energy Ltd. and its subsidiaries.
The Registrant has financed the revival and conduct of its
business by the issuance of common shares and other securities by way
of private placement.
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All monetary amounts contained in this Statement are, unless
otherwise indicated, expressed in United States dollars. On December
31, 1998 the closing rate for Canadian dollars was US$1.00 for
CDN$1.5333. Rates of exchange are obtained from the Bank of Canada
and believed by the Registrant to approximate closely the rates
certified for customs purposes by the Federal Reserve Bank in New
York. See Item 6. Selected Financial Data - Exchange Rates.
Plan of Operations
The Registrant has committed to carry out, or plans to carry out
the following work by the following dates:
Total Work
Permit Anticipated
Obligation to Before
December 31, December 31,
Property Description of Work Permit 1999 ($US) 1999 (US$)
Developed
PMP 38148 Ngatoro 1 work over $ Nil $ 16,000
Ngatoro 6 work over Nil 3,000
Purchase production equipment Nil 7,000
Undeveloped
PEP 38328 Seismic Collection Nil $ 26,000
Seismic collection Nil 34,000
Administration and
geologic studies Nil 11,000
PEP 38330 Seismic Collection Nil 80,000
Administration and
geologic studies Nil 9,000
PEP 38332 Seismic collection Nil 14,000
Seismic collection Nil 36,000
Administration and
geologic studies Nil 11,000
PEP 38335 Seismic collection 10,000 10,000
Administration and
geologic studies Nil 1,000
PEP 38339 Seismic collection Nil 52,000
Administration and
geologic studies 7,000 7,000
PEP 38256 120 miles of 2D seismic
collection under contract
to AMG
Administration and
geologic studies Nil 13,000
PEP 38706 Drill Kupara North well 112,000 112,000
PEP 38716 Drill Huinga-1 well 273,000 273,000
PEP 38720 Drill Mt. Messenger well [1] 460,000 460,000
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PEP 38723 Seismic Collection 63,000 63,000
AC/P19 Purchase of 25 square miles
of Onnia 3D seismic data 246,000 246,000
Administration and
geologic studies Nil 17,000
Vic/P39 Administration and
geologic studies Nil 26,000
300 miles of seismic
collection [2] 184,000 184,000
PPL 192 30 miles of 2D seismic
collection 210,000 210,000
China Contract negotiation 48,000 48,000
----------- -----------
TOTAL $ 1,613,000 $ 1,969,000
[1] The depth of this well has not been determined and may vary
materially.
[2] Permit may be surrendered.
Acquisition, Exploration and Development Expenditures.
The Registrant has incurred expenditures of $1,182,655 to December
31, 1996, $1,064,976 in the year ended December 31, 1997 and $1,901,030
in the year ended December 31, 1998 in the acquisition, exploration and
development of petroleum properties.
Employees and Consultants
The Registrant employs ten people in its Vancouver office and five
people in its Wellington office. The persons employed in the Vancouver
office are the chairman and nine others occupied with office
management, reception, shareholder relations and communications and
legal and accounting matters. The persons employed in the Wellington
office are the president and chief executive officer and four persons
occupied with joint venture accounting, office management and New
Zealand, Australian and PNG corporate affairs.
Hydrocarbon Tenures in New Zealand, Australia, Papua New Guinea and
China.
In New Zealand a prospecting licence is a form of tenure held
under the Petroleum Act 1937, the predecessor legislation to the Crown
Minerals Act of 1991 and is, as the tenure expires, replaced by the
exploration permit under the later legislation. In New Zealand, permits
are granted for specified minerals to the first applicant for that
mineral in a specific area and generally prescribe work to be performed
over the term of the permit. In most cases, permits contain a work
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program approved by the Minister of Energy. Prospecting permits are
limited forms of tenure granted under the Crown Minerals Act of 1991
for two years on conditions the Minister of Energy considers
appropriate. The Registrant does not hold any prospecting permits.
Under the Crown Minerals Act of 1991, the exploration permit, which
replaced the prospecting licence, grants the right to explore a
specified mineral for a term of five years and may be extended for up
to ten years on conditions the Minister of Energy considers
appropriate. If the holder of an exploration permit discovers a deposit
or occurrence to which the exploration permit relates and satisfies the
Minister of Energy that the results of exploration justify granting a
mining permit, the holder may, on application before the expiry of the
exploration permit, obtain a mining permit for up to 40 years for such
part of the land as the deposit or occurrence relates and exchange the
exploration permit for such part of the land. Changes to the conditions
prescribed in a permit may be made by application to the Minister of
Energy of the holder of a permit is in substantial compliance with the
conditions of the permit. The Crown Minerals Act of 1991 also provides
for the revocation of a permit if the Minister of Energy has reason to
believe that the holder of the permit is contravening, or not making
reasonable efforts to comply with, the Crown Minerals Act or the
conditions of the permit and the Minister of Energy is satisfied that
the holder of a permit has failed to comply with a notice to rectify
the contravention or non-compliance. Any transfer or other dealing with
a permit is subject to the consent of the Minister of Energy on such
conditions as he considers appropriate and an application for consent
is made within three months of the date of the agreement. A transfer or
lease of a permit with respect to petroleum has no effect until a
notice of the transfer has been lodged with the Secretary of Commerce
and the Minister of Energy has given his consent. Otherwise, the
transfer or other dealing has no effect. The Minister of Energy may
also direct that any petroleum products be refined or processed in New
Zealand. The Minister of Energy also has the jurisdiction to unitize
producing permits. Finally, the Crown Minerals Act of 1991 provides
procedures for the resolution of conflict with other forms of land
tenure.
In Australia, the Petroleum (Submerged Lands) Act 1967 governs
permits lying further offshore than three miles form the coast. Coastal
waters and lands are within state jurisdiction. The Australian permits
of the Registrant are granted and regulated under the Petroleum
(Submerged Lands) Act 1967. This statute provides for four types of
permits, exploration permits, retention leases, production licences and
pipeline licences. An exploration permit provides the exclusive right
to undertake seismic surveys and drilling in a defined area. Permits
are awarded by a work program bidding system or a cash bidding system
over acreage released each year by the Commonwealth. Work program
permits are issued for an initial term of six years with an unlimited
number of five year renewals. At each renewal, 50% of the permit area
must be relinquished. On discovering petroleum, a holder must notify
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the authority. If commercial, the holder may apply for a production
licence. Production licences are issued for 21 years and may be renewed
for a further 21 years. If the holder makes a non-commercial discovery
which has a reasonable chance of becoming commercial within the next 15
years, a retention lease may be granted. Retention leases are issued
for terms of five years with renewal periods of five years. A pipeline
licence is usually granted at the same time as a production licence.
In Papua New Guinea, the Petroleum Act provides for four different
types of licence, petroleum prospecting licences ("PPL") for
exploration, which is the form of tenure held by the Registrant,
petroleum development licences ("PDL") for petroleum developments,
petroleum retention licences ("PRL") for gas reserves which are
considered sub-economic and pipeline licences. A PPL is granted for a
term of six years with one five year extension permitted. At the end of
the first term, the holder must relinquish 50% of the initial size of
the permit, less the area of any PRLs on extension. A PPL usually
contains a work program which is submitted to, and approved by, the
Minister for Petroleum and Energy. Appropriate variations to a work
program may be approved by the Minister at any time during the third to
sixth years of a PPL. The State has the option to acquire a 22.5%
interest in any petroleum development. Where it does so, a two percent
interest is held for the benefit of the landowners in the project area.
The price payable by the State is 22.5% of sunk costs, including the
allowable exploration expenditure of the project. Orogen Minerals
Limited ("Orogen"), a publicly listed company 51% owned by the State,
has an option to acquire up to a 20.5% interest in future petroleum
projects out of the State's entitlement of 22.5%. If Orogen does not
exercise its option, the permit holder is obliged to carry the State's
acquisition of its 22.5% interest and all development costs. This
carried interest is repaid with a commercial rate of interest out of
petroleum production attributable to the State's share. If Orogen
exercises its option, the cost of the carried interest is paid
immediately. A PDL is granted for an initial term of 25 years with one
20 year extension. A PRL is granted for an initial term of five years
with two five year extensions. A pipeline licence is granted for a term
of 25 years with one 20 year extension. Assignments of, and dealings
in, all types of petroleum licences are permitted, subject to the
Minister's consent. Any assignment or dealing without such consent is
void. Before drilling an exploration well, the permit holder and the
State generally enter into a production agreement that sets out
additional conditions applying to operations, the procedures which will
lead to a development and the terms on which the state will acquire its
equity interest in a development.
In November 1998, the PNG parliament passed the Oil and Gas Act
1998 which, when proclaimed, will repeal the Petroleum Act. This is
anticipated before March 31, 1999. The material changes effected by the
Oil and Gas 1998 are (1) for new projects, the royalty benefit equal to
the royalty paid by a licensee, which is currently two percent of the
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well head value, less tax, which is currently five per cent, is to be
shared among the project area landowners, local level government and
provincial governments; (2) the carried interest of two percent in a
project held for local landowners is to be provided free to the area
landowners and local government(s); (3) licensing of petroleum
processing facilities is required; (4) third party access arrangements
must be adopted where a pipeline is strategic; (5) social mapping and
landowner identification studies must be carried out by licensees; (6)
the State's entitlement to its 22.5% interest and all development costs
is enshrined in law; (7) provincial governments may form a national gas
corporation to acquire on commercial terms interests in gas projects;
(8) extended well testing may be carried on with the State's consent;
and (9) development forums must be held before the development of a
project.
In China, the Registrant is negotiating with the China National
Petroleum Corporation the next stage of its operation. The terms and
conditions of operation and property tenure cannot at this time be
determined. Discussions are based on the February 1994 China National
Petroleum Corporation model contract, but it is not clear at this time
if the Registrant will enter into a geophysical service agreement, a
drilling services agreement or a production sharing contract or the
extent to which terms and conditions of the model agreement will be
modified during the course of negotiation with the China National
Petroleum Corporation.
Environmental Regulation in New Zealand, Australia, PNG and China
New Zealand
Since 1990, the government of New Zealand has developed a
comprehensive statutory regime dealing with the effect of development
on the environment. Depending on the location of the petroleum
interest, different laws apply where petroleum exploration and
development is concerned. On land and in waters within twelve miles of
the coast, the Resource Management Act 1991 controls users of natural
and physical resources with a view to managing resource usage in ways
that will not compromise future utilization. Previous legislation in
New Zealand prescribed what activities could, or could not, be carried
on. The Resource Management Act 1991 places the emphasis on assessment
of the effect the proposed activity will have will, or might, have on
the environment with a view to promoting sustainable management.
Under the Resource Management Act 1991, most of the responsibility
for managing resources and their use is given to local authorities.
Regional and district councils establish their own rules and standards
for environmental effect assessments and required degrees of
consultation. Both regional and district councils must produce and
continuously update planning schemes for their jurisdictions. These
schemes may limit industries to designated areas, depending on the
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environmental or social effects. The right to take from, and discharge
into, waterways for industrial purposes requires approval from various
regional catchment authorities, which may require maintenance of water
quality standards.
Resource consents authorize the use or development of a natural or
physical resource or permit an activity to be conducted which may
affect the environment. Under the Resource Management Act 1991 there
are five types of resource consents: land use consent, subdivision
consent, water permits, discharge permits and coastal permits. Certain
applications require public notice and allow public involvement in the
assessment process. Adverse decisions made by a regional or district
council may be appealed the Environmental Court.
Petroleum exploration and development outside of twelve miles from
the coast comes under the Maritime Transport Act 1994 administered by
the Maritime Safety Authority. The Registrant holds no licenses or
permits that fall under the jurisdiction of this authority.
Australia
In Australia, for permit areas lying further offshore than three
miles from the coast, the federal Commonwealth is involved in pollution
control through a number of government departments. Pollution control
laws are administered by federal and state government departments and
commissions. These entities enforce a variety of statutes and
regulations relating to air, water and noise pollution. There is an
increasingly significant emphasis on pollution control and breaches of
legislation attract severe penalties.
Papua New Guinea
In Papua New Guinea, the Environmental Planning Act, the
Environmental Contaminants Act, the Water Resources Act and the
Conservation Areas Act are the four main statutes relating to
environmental regulation of the exploration for, and development and
production of, hydrocarbons.
The Environmental Planning Act requires the preparation of an
environmental plan and prescribes the procedures for submitting, and
obtaining the approval for, a prospecting development license. The
Environmental Contaminants Act regulates the prevention and control of
environmental contamination and provides for other aspects of
environmental protection. The Water Resources Act regulates water use
in all of Papua New Guinea. To use water in the exploration for, or
development and production of, hydrocarbons a permit is required under
this statute. The Conservation Areas Act regulates preservation of the
environment and of natural cultural sites and areas. If the exploration
for, or development and production of, hydrocarbons is to occur in such
a site or area, a permit is required under this statute from the
Minister of the Environment.
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China
Environmental regulation in China does not exist on a national
level. Individual projects are monitored by the State and the standard
of environmental regulation depends on each case.
Year 2000 Compliance
The Registrant is currently conducting a review of its computer
systems to identify the systems that could be affected by the "Year
2000" issue. The Year 2000 problem is the result of computer programs
being written using two digits rather than four to define the
applicable year. Any of the Registrant's programs that have time-
sensitive software may recognize a date using '00' as the year 1900
rather than the year 2000. This could result in a major system failure
or miscalculations. Based upon the Registrant's current review of its
systems, the Registrant does not believe that the Year 2000 problem
will pose a material operations problem for the Registrant. The
Registrant's computer software providers have assured the Registrant
that all of the Registrant's software is or will be Year 2000 compliant
(i.e. will function properly in the year 2000 and beyond). Because the
Registrant believes that it has no material internal Year 2000
problems, the Registrant has not expended and does not expect to expend
a significant amount of funds to address Year 2000 issues. It is the
Registrant's policy to continue to review its suppliers' Year 2000
compliance and require assurance of Year 2000 compliance from new
suppliers; however, such monitoring does not involve a significant cost
to the Registrant. The Registrant's sole source of oil & gas sales
revenue is from its 5% interest in Petroleum Mining Permit ("PMP")
38148 (See ITEM 2 "PROPERTIES"). With regard to the Registrant's
interest in PMP 38148, the Registrant is dependent on Fletcher
Challenge Energy Limited ("Fletcher") for the delivery and payment of
the Registrant's oil and natural gas revenues. Fletcher is in turn
dependent on various third parties for delivery and payment. The
Registrant will request written assurances from Fletcher that it has
examined their own Year 2000 issues. However, as of the date of this
report, the Registrant has not requested such an assurance. It should
be emphasized that no assurance can be given at this time that Fletcher
is or will be Year 2000 compliant. In the event that Fletcher was to
have a material Year 2000 problem, the Registrant believes that the
foreseeable consequences would be a temporary delay in revenue
collection caused by an interruption in computerized billing and
collecting which may have a short term impact on the Registrant's
revenues. As yet, the Registrant does not have any contingency plan to
address this possibility.
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Risk Factors
The common shares of the Registrant must be considered a
speculative investment due to a number of factors. The purchase of the
common shares involves a number of significant risk factors. Purchasers
of common shares should consider the following:
1. No History of Operations and Reliance on Expertise of Certain
Persons. The Registrant has no history of operations and is dependent
on the management by its president and, in the acquisition, exploration
and development of petroleum properties, and on the advice of
consulting geologists retained by the Registrant from time to time. The
current president of the Registrant is experienced in the acquisition,
exploration and development of petroleum properties in New Zealand and
other Asian countries, particularly China, Papua New Guinea and
Australia. Should the current president leave the Registrant, the
Registrant may have difficulty in finding a person of comparable
education and experience to manage the business of the Registrant.
2. Limited Financial Resources. The Registrant has limited
financial resources and, if the business is not profitable, may not be
able to raise sufficient funds to sustain, continue or expand its
business. The Registrant currently has limited revenues and relies
principally on the issuance of common shares to raise funds to finance
the business of the Registrant. There is no assurance that market
conditions will continue to permit the Registrant to raise funds if
required.
3. Competition with Other Companies. Other companies with
greater financial resources or expertise are in competition with the
Registrant. The Registrant must compete with such companies in bidding
for the acquisition of petroleum interests from various state
authorities, in purchasing or leasing equipment necessary to explore
for, develop and produce hydrocarbons and in obtaining the services of
personnel in the exploration for, and development and production of,
hydrocarbons. While the Registrant has acquired various rights to
explore, there is no assurance that personnel and equipment will be
available to carry out the programs planned by the Registrant.
4. Failure to Locate Commercial Quantities of Hydrocarbons and
Geological Risks. There is no assurance that commercial quantities of
hydrocarbons will be discovered and prices for hydrocarbons may vary,
rendering any deposit discovered uneconomic. In addition, even if
hydrocarbons are discovered, the costs of extraction and delivering the
hydrocarbons to market may render any deposit found uneconomic.
Geological conditions are variable and unpredictable. Even if
production is commenced from a well, the production will inevitably
decline and may be affected or terminated by changes in geological
conditions that cannot be foreseen or remedied by the Registrant.
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5. Fluctuation of Oil and Gas Prices. Prices for oil and gas may
fluctuate widely from time to time depending on international demand,
production and other factors which cannot be foreseen by the
Registrant. A decline in price may render a discovery uneconomic. The
recent Asian financial market crisis has reduced demand for petroleum
products in the Asia-Pacific region, but production, if any, from the
Registrant's properties that might be sold to countries affected by the
recent Asian financial market crisis would, even for a discovery made
in 1998, take some years to develop and would be sold under financial
conditions that cannot be determined.
6. Governmental Laws and Local Conditions. Claims of aboriginal
peoples in Australia or New Zealand may adversely affect the rights or
operations of the Registrant. There is no assurance that governmental
regulation will not vary, including regulations relating to prices,
royalties, allowable production, environmental matters, import and
export of hydrocarbons and protection of water resources and
agricultural lands. The Registrant is subject to numerous foreign
governmental regulations that relate directly and indirectly to its
operations including title to the petroleum interests acquired by the
Registrant, production, marketing and sale of hydrocarbons, taxation,
environmental matters, restriction on the withdrawal of capital from a
country in which the Registrant is operating and other factors. There
is no assurance that the laws relating to the ownership of petroleum
interests and the operation of the business of the Registrant in the
jurisdictions in which it currently operates will not change in a
manner that may materially and adversely affect the business of the
Registrant. In particular, the Registrant is of the view that the laws
of China and to a lesser extent those of Papua New Guinea relating to
the business of the Registrant may be unable to be determined or may
change with little or no notice or the Registrant may be subject to
unofficial or local policies that materially and adversely affect the
business of the Registrant. There is, however, no assurance that the
laws of any jurisdiction in which the Registrant carries on business
may not change in a manner that materially and adversely affects the
business of the Registrant.
7. Environmental Risks. The Registrant is subject to laws and
regulations that control the discharge of materials into the
environment, require removal and cleanup in certain circumstances,
require the proper handling and disposal of waste materials or
otherwise relate to the protection of the environment. In operating and
owning petroleum interests, the Registrant may be liable for damages
and the costs of removing hydrocarbon spills for which it is held
responsible. Laws relating to the protection of the environment have in
many jurisdictions become more stringent in recent years and may, in
certain circumstances, impose strict liability, rendering the
Registrant liable for environmental damage without regard to negligence
of fault on the part of the Registrant. Such laws and regulations may
expose the Registrant to liability for the conduct of, or conditions
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caused by, others or for acts of the Registrant that were in compliance
with all applicable law at the time such acts were performed. The
application of these requirements or the adoption of new requirements
could have a material adverse effect on the business of the Registrant.
The Registrant believes that it has conducted its business in
substantial compliance with all applicable environmental laws and
regulations.
8. Indemnities may be Unenforceable or Uncollectable. The
operating agreements with participants in a property provide for the
indemnification of the Registrant as operator. There is no assurance
that such indemnification will be enforceable or that a participant
will be financially able in all circumstances to comply with its
indemnification obligations, or that the Registrant will be able to
obtain such indemnification agreements in the future.
9. Possible Lack of or Inadequacy of Insurance. The Registrant
maintains insurance against certain public liability, operational and
environmental risks, but there is no assurance that an event causing
loss will be covered by such insurance, that such insurance will
continue to be available to, or carried by, the Registrant or, if
available and carried, that such insurance will be adequate to cover
the Registrant's liability.
10. No Assurance of Earnings or Dividends and Taxation of
Dividends. The Registrant has no history of earnings and there is no
assurance that the business of the Company will be profitable and, even
if the business of the Registrant is profitable, there is no assurance
the board of directors will declare dividends on common shares. The
register of members of the Registrant discloses that the majority of
the shares of the Registrant are held of record by persons resident in
the United States of America. If the Registrant should declare a
dividend, a withholding tax of five percent is payable in Canada on
payment of a dividend to a corporate resident of the United States of
America holding more than ten per cent of the shares of the Registrant
and 15% to all other residents of the United States.
11. Marketing of Petroleum Products. The availability of
products sold, or to be sold, by the Registrant may be restricted or
rendered unavailable due to factors beyond the control of the
Registrant, such as change in laws in the jurisdictions in which the
properties of the Registrant are located, changes in the source of
supply in foreign countries, prohibition on use due to testing and
licencing requirements and in certain areas of the world civil disorder
or governmental confiscation without compensation. The Registrant is
in the early stages of the exploration of its properties and does not
sell petroleum production in countries affected by the current Asian
financial market crisis. Even if discoveries in commercial quantities
are made by the Registrant, development of a discovery may take a
number of years and financial conditions at that time cannot be
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determined. The Registrant holds its cash reserves in US dollars but
incurs the majority of its expenses in Australian and New Zealand
dollars, which have declined relative to the US dollar, and, if
anything, has benefitted from the Asian financial crises with the
recent rise of the US dollar relative to currencies of countries in the
Asia-Pacific region.
12. Activities of Management. The management of the Registrant
and the growth of the Registrant's business depends on certain key
individuals who may not be easily replaced if they should leave the
Registrant; and persons in management have other business interests
which may result in them devoting, from time to time, some of their
time to such other interests.
13. Inadequacy of Public Market. There is no assurance that the
public market for the common shares of the Registrant will be
maintained or that the holder of common shares will be able in all
circumstances to sell such shares in the quantity and at the price
desired by such holder.
14. Restrictions in Applicable Securities Laws. Applicable
securities laws may restrict the transfer of common shares and if an
exemption is not available to a holder wishing to sell, the shares may
not be transferred.
15. Loss of Investment. An investment in common shares of the
Registrant should only be made by persons who can afford a complete
loss of their investment and there is no assurance that the common
shares of the Registrant will increase in value from the amount at
which a member acquired common shares of the Registrant.
16. Risk Inherent in Exploration. Most of the properties of the
Registrant are at the exploration stage and, except for petroleum
mining permit 38148, without known, commercial reserves of oil or gas.
Oil and gas exploration and development involves a high degree of risk
and few properties which are explored are ultimately developed into
producing and profitable properties.
17. Common Management. The acquisition, exploration and
development of hydrocarbon permits and licences by the Registrant is
carried on, in a number of cases, with companies that have common or
connected management or the same principal shareholder.
18. Consequences of Failure to Satisfy Prescribed Permit or
License Terms and Conditions. In all cases, the terms and conditions
of the permit or license granting the right to the Registrant, or the
party from which the Registrant acquired, or agreed to acquire,
directly or indirectly, the right to explore for, and develop,
hydrocarbons prescribe a work program and the date or dates before
which such work program must be done. Varying circumstances, including
16
the financial resources available to the Registrant, availability of
required equipment, expertise of the management of the Registrant and
other matters relating to the Registrant, reliance on third party
operators of permits and licenses or circumstances beyond the control
or influence of the Registrant may result in the failure to satisfy the
terms and conditions of a permit or license and result in the complete
loss of the interest in the permit or license without compensation to
the Registrant. Such terms and conditions may, in certain cases, be
renegotiated with applicable regulatory authorities, but there is no
assurance that if a term or condition of a license or permit that is
required to be satisfied will not, or has not been met and may result
in the loss of the interest in such permit or license that such term or
condition will be renegotiated with the applicable authority.
19. Defeasance of Title. The possibility exists that title to
one or more properties of the Registrant may be lost due to an omission
in the claim of title. The Registrant does not maintain title
insurance.
GLOSSARY
Currency and Measurement All currency amounts in this Statement
are stated in United States dollars
unless otherwise indicated.
Currency and Measurement All currency amounts are stated in
Canadian dollars unless otherwise
indicated. See Item 6. Selected
Financial Data - Exchange Rates.
Metric and Imperial Units Conversion from metric units into
imperial equivalents is as follows:
Metric Units Imperial Units
hectare 2.471 acres
meter (m) 3.281 feet
kilometer (km) 0.621 miles (3,281 feet)
Geologic Time
Name of Era Name of Period Number of Years Before
Present (Millions)
Quaternary Holocene 0 to 0.4
Pleistocene 0.4 to 1.8
17
Tertiary Pliocene 1.8 to 5.0
Miocene 5.0 to 24
Oligocene 24 to 38
Eocene 38 to 56
Paleocene 56 to 66
Mesozoic Cretaceous 66 to 140
Jurassic 140 to 200
Triassic 200 to 250
Paleozoic Permian 250 to 290
Carboniferous 290 to 365
Devonian 365 to 405
Silurian 405 to 425
Ordovician 425 to 500
Cambrian 500 to 570
Precambrian Precambrian > 570
Other Geologic Expressions
Anticline A geologic structure in which the
sedimentary strata are folded to form an
arch or dome.
Appraisal Well A well drilled after an existing
discovery well to determine the extent
of the resources of the field.
Basin A segment of the crust of the Earth in
which thick layers of sediments have
accumulated over a long period of time.
Carried Interest An equity percentage in a permit or
license where the owner is entitled to a
stated percentage of the proceeds
received from the sale of hydrocarbons
but is not liable to for exploration,
development or operating costs.
Condensate Hydrocarbons associated with natural gas
which are liquid under surface
conditions but gaseous in a reservoir
before extraction.
Depletion The reduction in petroleum reserves due
to production.
Development The phase in which a proven oil or gas
field is brought into production by
drilling and completing production wells
and the wells, in most cases, are
connected to the petroleum gathering
system.
18
Diapirism The upwards movement through the
subsurface of discrete masses of
plastically deforming rocks, as in salt
and bentonitic mudstone as occurred in
the East Coast Basin situation)
Discovery The location by drilling of a well of an
accumulation of gas, condensate or oil
reserves, the size of which may be
estimated but not precisely quantified
and which may or may not be commercially
economic, depending on a number of
factors.
Dry Hole A well drilled without finding
commercially economic quantities of
hydrocarbons.
Exploration Well A well drilled in a prospect without
knowledge of the underlying sedimentary
rock or the contents of the underlying
rock.
Farm In or Farm Out A common form of agreement between or
among petroleum companies where the
holder of the petroleum interest agrees
to assign all or part of an interest in
the ownership to another party that is
willing to fund agreed exploration
activities which may be more or less
than the proportionate interest assigned
to such other party.
Fault A fracture in a rock or rock formation
along which there has been an observable
amount of displacement.
Field An area that is producing, or has been
proven to be capable of producing,
hyrdocarbons.
Formation A reference to a group of rocks of the
same age extending over a substantial
area of a basin.
Frontier Exploration Exploration in an area that has seen
little previous exploration but offers
the potential for the discovery of large
reserves of hydrocarbons.
19
Geology The science relating to the history and
development of the Earth.
Graben A fault bounded downthrown region,
typically infilled by a thickened
sedimentary rock section.
High A feature which sits shallower than its
surroundings.
Horst A fault bounded high.
Hydrocarbon The general term for oil, gas,
condensate and other petroleum products.
Lead An inferred geological feature or
structural pattern which on further
investigation may be upgraded to a
prospect.
Participating Interest or
Working Interest An equity interest, compared with a
royalty interest, in an oil and gas
property whereby the participating
interest holder pays its proportionate
or agreed percentage share of
development and operating costs and
receives its proportionate share of the
proceeds of hydrocarbon sales after
deduction of royalties due on gross
income.
Pay Zone The stratum or strata of sedimentary
rock in which oil or gas is found.
Permit or License An area that is granted for a prescribed
period of time for exploration,
development or production under specific
contractual or legislative conditions.
Pipeline A system of interconnected pipes that
gather and transport hydrocarbons from a
well or field to a processing plant or
to a facility that is built to take the
hydrocarbons for further transport, such
as a gas liquifaction plant.
Play A combination of geologic features that
have the potential for the accumulation
of hydrocarbons.
20
Prospect A potential hydrocarbon trap which has
been confirmed by geological and
geophysical studies to warrant the
drilling of an exploration well.
Reservoir A porous and permeable sedimentary rock
formation containing adequate pore space
in the rock to provide storage space for
oil, gas or water.
Royalty The entitlement to a stated or
determinable percentage of the proceeds
received from the sale of hydrocarbons
calculated as prescribed in applicable
legislation or in the agreement
reserving the royalty to the owner of
the royalty.
Seal An impervious sedimentary rock formation
overlying a reservoir that prevents the
further migration of hydrocarbons.
Seep The natural flow of oil or gas to the
Earth's surface from a formation or
through cracks and faults indicating
that a formation containing hydrocarbons
may be located somewhere nearby.
Seismic A geophysical technique using low
frequency sound waves to determine the
subsurface structure of sedimentary
rocks.
Show The detectable presence of hydrocarbons
during the drilling of a well.
Source Rock Sedimentary rock, usually fine-grained
shale rich in organic matter, the
geologic conditions, including
conditions of temperature, pressure and
time, and history of which is favourable
for the formation of hydrocarbons.
Top Seal A rock formation through which
hydrocarbons cannot move which lies
above a trap and below which
hydrocarbons accumulate to form a pool.
21
Trap A geological structure in which
hydrocarbons build up to form an oil,
condensate or gas field.
ITEM 2. PROPERTIES
General
The following is a discussion of the development of the business
of the Registrant between January 1, 1996 and December 31, 1998. For a
discussion of intended operations to December 31, 1999 see Item 1.
Business - Plan of Operations.
Except for PMP 38148, New Zealand, the properties of the
Registrant are in the exploration stage. The assessment of the
potential of the properties of the Registrant to contain petroleum
reserves involves, among other things, a consideration of discoveries
made by third parties on properties adjacent to, or, depending on
circumstances, in the area of, the properties of the Registrant.
Geological conditions are, however, unpredictable. The discovery of
reserves on properties adjacent to, or in the area of, properties of
the Registrant is no assurance that commercially recoverable reserves
of oil and gas will be discovered on the Registrant's properties. See
Item 1. Business - Risk Factors.
The formation of geological conditions for the generation,
entrapment and location of hydrocarbons depends on a number of
unpredictable factors. First, any system of sedimentary strata must
contain a source of hydrocarbons. Secondly, the source rocks must have
been buried in order for conditions favourable to the production of
hydrocarbons to prevail and the hydrocarbons must have been expelled
from the source formations. With expulsion, the hydrocarbons will
migrate and strata into which the hydrocarbons migrate must be
conducive to both the collection of the hydrocarbons in the strata and
the sealing of the hydrocarbons within the strata in which they
collect. Geological conditions are extremely varied and unpredictable.
See Item 1. Business - Risk Factors.
For definitions of technical terms used in the description of
properties, see the Glossary of Industry Terms at the end of Item 1.
Business.
The following properties are discussed in Item 2:
22
Working
Property Location Interest
PEP 38330 East Coast Basin, New Zealand 34.0% [2]
PPL 38312/
PEP 38335 East Coast Basin, New Zealand 10.0% [1]
PEP 38328 East Coast Basin, New Zealand 40.0% [2]
PEP 38332 East Coast Basin, New Zealand 42.5% [2]
PMP 38148 Taranaki Basin, New Zealand 5.0%
PEP 38706 Taranaki Basin, New Zealand 7.75%
PEP 38716 Taranaki Basin, New Zealand 19.8%
PEP 38720 Taranaki Basin, New Zealand 50.0% [2]
PEP 38723 Taranaki Basin, New Zealand 40.0% [2]
PEP 38339 On and offshore Clarence
Basin, New Zealand 50.0% [2][4]
PEP 38256 Canterbury Basin, New Zealand 35.0% [2][3]
AC/P19 Offshore Timor Sea, Australia 65.0% [2][5]
VIC/P39 Offshore Bass Strait, Australia 33.0% [2][6]
WA 199-P Offshore Timor Sea, Australia 5.0%
PPL 192 Onshore Papua New Guinea Foreland 40.0% [2]
China Production Sharing Contract
under negotiation for Nanling
and Wuwei Basins 50.0% [2]
[1] PPL 38312, in which the Registrant had a 10.5% participating
interest, expired in November, 1997. PEP 38335 was granted on
November 29, 1998 covering the same area and the Registrant has a
10.0% working interest.
[2] Operated by the Registrant. See Item 13 - Certain Relationships
and Related Transactions.
[3] At July 31, 1998 the Registrant held a participating interest of
50.0%. AMG Oil Ltd. gave notice on August 4, 1998 of the
acquisition of a 15.0% participating from the Registrant and could
elect before December 4, 1998 to acquire a further 25%
participating interest from the Registrant on certain conditions.
By agreement dated December 3, 1998 AMG Oil has until the earlier
of October 31, 1999 or the date of delivery by AMG Oil to the
Registrant and Trans-Orient Petroleum Ltd. that AMG Oil has
completed the collection and interpretation of sufficient seismic
data to identify a drilling prospect area. See Item 13 - Certain
Relationships and Related Transactions.
[4] Permit was granted November 26, 1998.
[5] Subject to a five percent carried interest that may vary in
certain circumstances.
23
[6] Subject to a five percent carried interest that may vary in
certain circumstances.
Oil discovered in New Zealand may be sold locally to any of Shell
(NZ), Todd Petroleum, Fletcher Challenge and others. The sale of gas
discovered in New Zealand requires the negotiation of contracts and the
installation of compression and transport facilities. The national grid
gas pipeline system crosses all three of the Registrant's East Coast
Basin permits and various oil and gas pipelines lie across or near the
Registrant's Taranaki Basin permits. Oil discovered in offshore
Australia may be sold internationally. The sale of gas discovered in
offshore Australia will depend, among other things, on the ease of
laying a pipeline to markets on land or having sufficient quantities to
remote transportation facilities. Gas or oil discovered in China can be
sold locally and oil can be exported.
East Coast Basin, North Island, New Zealand
The most significant 1998 development in the East Coast Basin was
not on the Registrant's permits, but has a material effect on the
potential for the discovery of hydrocarbons on the Registrant's permits.
The Westech/Enerco venture on PEP 38329, the permit situated
immediately north of the Registrant's PEP 38328 and immediately west of
the Registrant's PEP 38335, drilled the Kauhauroa-1 well which was
reported as flowing dry gas at a sustained rate of 11.5 million cubic
feet per day, with a surface flow pressure of 2,100 psi, from Miocene
sandstones at a 4,000 foot depth over a 60 hour test period. Their
second exploration well, Awatere-1 was also a gas discovery; and gas
shows' were observed in all seven of the exploration wells of their
1998 drilling campaign. A three well appraisal drilling program on the
Kauhauroa structure commenced in the first quarter 1999 and might
define reserves of several hundred billion cubic feet of gas. Statutory
consents for a pipeline to link the discovery to the national pipeline
grid have been applied for. The discovery demonstrates that the East
Coast Basin can have economically recoverable reserves of gas and may
become the second producing basin in New Zealand after the Taranaki
Basin. Miocene sandstones are known to underly most of the East Coast
Basin and are reservoir objectives elsewhere. Unlike PEP 38329, the
Company's East Coast Basin permits enclose sizeable industries, port
cities and key gas pipelines of the national transport grid, making
discoveries more easily developable than in the more remote terrain of
PEP 38329.
Petroleum Exploration Permit PEP 38330 (34%)
PEP 38330 was granted on July 1, 1996. The other participants are
Mosaic Oil NL (33%) and NWE (ZOCA 96-16) Pty. Ltd. (33%). The
Registrant is the operator. The permit area is 1,077,000 acres (1,683
square miles). The permit term is for five years, renewable for a
further five years over 50% of the permit area. Any production permits
24
granted will be for a term of up to 40 years from the date of issue.
The Crown in right of New Zealand has reserved a royalty of the greater
of five percent of net sales revenue from the sale of petroleum
products or 20% of accounting profits.
The participants have fulfilled all work requirements of the
permit to July 1, 1999, which has included acquisition of 60 miles of
new seismic data, reprocessing of existing seismic data, and remapping
of the permit. By July 1, 1999 the participants are required to commit
to acquire an additional 15 miles of seismic data, and by July 1, 2000
to commit to drill an exploration well before July 1, 2001 . Subject
to the commitment to do so, the participants are required to drill an
exploration well before July 1, 2001 and submit another program of
exploration for approval.
The main focus of exploration is on the Pauariki Anticline and the
Arataha Dome, two large structures with potential to reservoir sizeable
reserves of hydrocarbons. Several other leads are also identified.
An operating agreement is being negotiated. Before execution of an
operating agreement, the participants proceed in accordance with
standard local industry conventions.
For work planned to be done before December 31, 1999 on PEP 38330
and its estimated cost, see Item 1. Business Plan of Operations.
Petroleum Exploration Permit PEP 38335 (10.0%) [covering the same area
as the lapsed Petroleum Prospecting License PPL 38312, (10.5%)], East
Coast Basin, North Island.
PPL 38312 was granted in 1992 to Asia Pacific Oil Sdn. Bhd. of
Malaysia. In August 1997 the Registrant earned a participating interest
of 10.5% in the license by funding 10.5 percent of the costs of
drilling the Waitaria-1 well. The other participants were Asia Pacific
Oil Sdn. Bhd. (64.5%), Northern Oil Ltd. (2.5%), Everest Oil Co. Ltd.
(12.5%) and Trans-Orient Petroleum Ltd. (10.0%). Asia Pacific Oil Sdn.
Bhd. was the operator. The license area was about 90,000 acres. The
license expired in November 1997.
Before the license expired, the participants drilled the Waitaria-
1 well to a depth of 1,344 meters (~4,400 feet) which encountered high
gas levels, but was abandoned due to engineering problems encountered
while drilling before the target Tunanui Sandstones were reached.
PEP 38335 was granted on November 29, 1998 for an initial term of
five years, renewable over 50% of the permit area at the end of the
five years. The participants are Asia Pacific Oil Sdn. Bhd. (45.0%),
Everest Energy Inc. (30.0%), the Registrant (10.0%) and Trans-Orient
25
Petroleum Ltd. (15.0%). Everest Energy Ltd. is the operator. Any
production permits granted will be for a term of up to 40 years from
the date of issue. The Crown in right of New Zealand reserved a royalty
of the greater of five per cent of net sales revenue from the sale of
petroleum products or 20% of accounting profits.
The conditions of PEP 38335 require the participants to review the
geology of the area incorporating the results of the 1997 Waitara-1
well and collect 12 miles of seismic data before November 29, 1999.
Before November 29, 2000 an exploration well may be drilled to test to
the Tunanui Formation at a depth of about 1,800 meters (~6,000 feet).
If the permit is not then surrendered, the participants are to submit
before November 29, 2001 a work program for the remainder of the term
of the permit for the approval of the Minister.
An operating agreement is being negotiated. Before execution of an
operating agreement, the participants proceed in accordance with
standard local industry conventions.
For work planned to be done before December 31, 1999 on PEP 38335
and its estimated cost, see Item 1. Business Plan of Operations.
Petroleum Exploration Permit PEP 38328 (40.0%)
After the withdrawal in 1998 of two participants, the participants
in the permit are the Registrant (40.0%), Trans-Orient Petroleum Ltd.
(22.5%) and Boral Energy Resources Limited (37.5%). The Registrant is
the operator. The permit area is 785,000 acres (1,226 square miles).
The permit is for five years from July 1, 1996, renewable for a further
five years over 50% of the licence area. Any production permits granted
will be for a term of up to 40 years from the date of issue. The Crown
in right of New Zealand reserved a royalty of the greater of five per
cent of net sales revenue from the sale of petroleum products or 20% of
accounting profits.
The conditions of the first year of the permit were satisfied by
drilling the Kereru-1 well in 1996 which recorded some gas shows, but
was plugged and abandoned without testing.
Since drilling that well, approximately 200 miles of new seismic
data has been collected, and over 200 miles of existing seismic data
reprocessed, and a variety of field geological studies completed. A
number of exploration leads and prospects have been identified, of
which the Whakatu Prospect, a large fault anticline situated on the
Heretaunga Plains near to the city of Hastings, is now being considered
for drilling in mid-1999.
26
An operating agreement is being negotiated. Before execution of an
operating agreement, the participants proceed in accordance with local
industry conventions. Among other things, the operating agreement will
provide that a participant may not sell, assign, transfer, mortgage,
pledge, charge, encumber, lease, sub-lease, declare itself trustee of
or otherwise dispose of or create a charge or encumbrance over all or
part of its participating interest except to a "related body corporate"
as that expression is defined in the Companies Act (NZ) if that related
body corporate holds the participating interest for at least one year
without either the consent of the other participants or offering the
participating interest proposed to be dealt with to the other
participants.
For work planned to be done before December 31, 1999 on PEP 38328
and its estimated cost, see Item 1. Business Plan of Operations.
Petroleum Exploration Permit PEP 38332 (42.5%)
PPL 38332 was granted on June 24, 1997. The other participants are
Boral Energy Resources Limited. (37.5%) and Trans-Orient Petroleum Ltd.
(20%). The Registrant is the operator. The permit area is situated
immediately south of PEP 38328 and is 1,012,000 acres (1,581 square
miles) in area. The permit term is for five years, renewable for a
further five years over 50% of the licence area. Any production permits
granted will be for a term of up to 40 years from the date of issue.
The Crown in right of New Zealand has reserved a royalty of the greater
of five per cent of net sales revenue from the sale of petroleum
products or 20% of accounting profits.
Approximately 75 miles of new seismic data has been acquired, and
over 100 miles of existing seismic data reprocessed, and a variety of
field geological studies completed. A number of exploration leads and
prospects have been identified, of which the best defined is the Boar
Hill Prospect, which may be considered for drilling in late 1999.
An operating agreement is being negotiated. Before execution of an
operating agreement, the participants proceed in accordance with local
industry conventions. Among other things, the operating agreement will
provide that a participant may not sell, assign, transfer, mortgage,
pledge, charge, encumber, lease, sub-lease, declare itself trustee of
or otherwise dispose of or create a charge or encumbrance over all or
part of its participating interest except to a "related body corporate"
as that expression is defined in the Companies Act (NZ) if that related
body corporate holds the participating interest for at least one year
without either the consent of the other participants or offering the
participating interest proposed to be dealt with to the other
participants.
For work planned to be done before December 31, 1999 on PEP 38332
and its estimated cost, see Item 1. Business Plan of Operations.
27
New Zealand, Onshore Canterbury Basin, South Island
Petroleum Exploration Permit 38256 (35.0%)
The Canterbury Basin is located both onshore and offshore in the
area surrounding Christchurch, on the east coast of the South Island.
The total area of the Canterbury Basin is about twelve million acres
with the 2,760,120 acre (4,312.7 square miles) PEP 38256 covering most
of the onshore area. The sediments in the Canterbury Basin range in age
from Early Cretaceous to Quaternary.
PEP 38256 was granted on August 25, 1997 to the Registrant and to
Trans-Orient Petroleum Ltd. The Registrant and Trans-Orient Petroleum
Ltd. agreed to assign an interest of 20% to AMG Oil Ltd. (formerly
Trans New Zealand Oil Company) and an interest of 10% to Gondwana
Energy Ltd. This transaction was cancelled January 31, 1998.
The Registrant is the operator. The permit term is for five years,
but at the end of the third year of the permit the participants must
relinquish at least 50% of the permit area. Any production permits
granted will be for a term of up to 40 years from the date of issue.
The Crown in right of New Zealand has reserved a royalty of the greater
of five per cent of net sales revenue from the sale of petroleum
products or 20% of accounting profits.
By November 25, 1998 the participants were required to locate and
analyse petroleum seeps within the permit area, model existing gravity
data and acquire new gravity data, collect and interpret a minimum of
ten magnetotelluric stations, process existing seismic data and
complete surface geological work. The participants are required by
August 25, 1999 to collect, process and interpret 80 kilometres of new
seismic data. If the permit is not surrendered, by February 25, 2000
the participants are required to acquire, process and interpret 120
kilometres of new seismic data. If the permit is not then surrendered,
the participants are required by August 25, 2000 to drill an
exploration well to the lesser of 1200 metres or the economic basement.
The participants have acquired in excess of 250 miles of new seismic in
the permit, and scanned and reprocessed existing seismic, and defined
several major exploration leads.
The Registrant and Trans-Orient Petroleum Ltd. by agreement dated
June 25, 1998 optioned up to 80% of the permit to AMG Oil Ltd. In
August AMG earned 30% of the permit by paying the cost of a 120 mile
seismic survey. To earn an additional 50%, AMG was required to elect
before December 4, 1998 to pay the cost of any additional seismic
required to define two drilling prospects and to pay the dry hole costs
of drilling two wells to a maximum of about US$2,100,000. By agreement
dated December 3, 1998 the date for exercise of the drilling option was
28
extended to the earlier of October 31, 1999 or the date of delivery by
AMG to the Registrant and Trans-Orient Petroleum Ltd. that AMG has
completed the collection and interpretation of sufficient seismic data
to identify a drilling prospect within PEP 38256. AMG is maintaining
the option by funding ongoing costs including an independent evaluation
of the permit by the Geology Department of the University of
Canterbury.
AMG sold 1,000,000 shares for US$0.25 per share to each of the
Registrant and Trans-Orient Petroleum Ltd. and granted to each an
option to acquire 1,000,000 shares for US$0.50 per share before the
earlier of July 31, 2000 or thirty business days after AMG ceased to
have a right to earn an interest in, or to hold an interest in, PEP
38256. The Registrant partially exercised its option to acquire 800,000
shares on March 1, 1999. Trans-Orient Petroleum Ltd. partially
exercised its option to acquire 400,000 shares on March 1, 1999.
An operating agreement dated June 24, 1998 governs the working
relationship of the parties. Among other things, the operating
agreement provides that a participant may not sell, assign, transfer,
mortgage, pledge, charge, encumber, lease, sub-lease, declare itself
trustee of or otherwise dispose of or create a charge or encumbrance
over all or part of its participating interest except to a "related
body corporate" as that expression is defined in the Companies Act (NZ)
if that related body corporate holds the participating interest for at
least one year without either the consent of the other participants or
offering the participating interest proposed to be dealt with to the
other participants.
For work planned to be done before December 31, 1999 on PEP 38256
and its estimated cost, see Item 1. Business Plan of Operations.
Petroleum Exploration Permit PEP 38339, Cook Strait (50.0%)
PEP 38339 was granted on November 26, 1998 to the Registrant and
Trans-Orient Petroleum Ltd. The permit area encompasses onshore
portions of the South Island and offshore portions of Cook Strait lying
between the North and South Islands. The Registrant is the operator.
The permit area is about 814,771 acres (1,273 square miles)and the
term of the permit is five years, renewable for a further five years
over 50% of the permit area. Any production permits granted will be for
a term of up to 40 years from the date of issue. The Crown in right of
New Zealand reserved a royalty of the greater of five per cent of net
sales revenue from the sale of petroleum products or 20% of accounting
profits.
29
Before February 26, 2000 the participants are required to
reprocess available seismic data and collect additional gravimetric
data, conduct rock sampling and evaluate the database to define the
basin structure and identify prospects and leads for further
evaluation. Before November 26, 2000, the participants are to collect
and interpret a minimum of 12 miles of onshore seismic data and 30
miles of offshore seismic data. Any additional seismic data required to
identify a drilling prospect is to be collected by May 26, 2001 and a
well is to be drilled before November 26, 2001. A work program for the
remainder of the permit is then to be submitted for approval.
The permit encloses the southern part of a Miocene-Pliocene basin
formed in response to movement along the Alpine Fault and associated
plate boundary faults. The thick, sedimentary section provides the
potential for hydrocarbon generation and reservoir development, while
the limited offshore seismic base shows evidence of large scale
structuring. The basin has formed in a manner analogous to the Los
Angeles basin in California. No wells have been drilled and there is no
onshore seismic data. However, surface geological mapping has
identified the Blind River Anticline as a focus of exploration. Several
oil and gas seeps along the southern margin of the basin indicate
hydrocarbon generation.
There is no operating agreement under which work on PEP 38339 is
conducted although the participants conduct operations in accordance
with local industry conventions.
For work planned to be done before December 31, 1999 on PEP 38339
and its estimated cost, see Item 1. Business Plan of Operations.
New Zealand, Onshore Taranaki Basin, North Island
The Taranaki Basin is located on the west coast of the North
Island. The sediments in the Taranaki Basin range in age from Late
Cretaceous to the Quaternary and encompass a depth of some 25,000 feet
with complex structure and geology. Compression across the eastern
portion of the Basin during the early Miocene period created a thrusted
fold belt up to ten miles wide, which contains the McKee, Tariki,
Ahuroa and Waihapa-Ngaere fields. Further west in the onshore region
are the fault bounded Kapuni, Ngatoro and Kaimiro fields. All these
fields are currently in production.
Petroleum Mining Permit PMP 38148 (5.0%)
Effective September 1, 1996 the Registrant bought the outstanding
shares of Minora Energy (New Zealand) Limited for AUS$575,000
(CDN$478,755, US$348,790). The name of the company was changed to
Ngatoro Energy Limited. Ngatoro Energy Limited owns a five percent
participating interest and revenue interest in petroleum mining permit
38148, which has six producing oil wells and one producing gas well.
30
The permit area is 9,400 acres. The permit expires on December 23,
2010. Production is from turbidite sandstones of the Mount Messenger
Formation at depths of 1,500 metres to 2,000 metres. The other
participants are New Zealand Oil & Gas Ltd. (35.43%) and Fletcher
Challenge Energy Taranaki Ltd. (59.57%). New Zealand Oil & Gas Ltd. is
the operator. The Crown in right of New Zealand has reserved a royalty
of the greater of five per cent of net sales revenue from the sale of
petroleum products or 20% of accounting profits.
Oil and gas production and sales revenue from September 1996 to
September 30, 1998 is:
Oil Oil Gas Sales Gas
Year Sales (bbl) Revenue (US$) ( 000 scf) Revenue (US$)
1996 [1] 8,206 $163,388 - [2] -
1997 26,556 487,941 - [2] -
1998 20,628 224,921 27,688 9,247
[1] For the months September to December, inclusive.
[2] To August 1998 gas was flared.
The Registrant entered into an oil sales contract dated November
9, 1997 with Fletcher Challenge Energy Taranaki Limited and a gas sales
contract dated February 18, 1998 with Fletcher Challenge Energy
Limited. Under the oil sales contract, the Registrant sells its share
of production from the field at the monthly average of the mean of the
Asian Petroleum Price Index published in Hong Kong. The agreement may
be terminated on 30 days' notice on the occurrence of certain events.
Gas sales began in the third quarter of 1998. The gas sales contract
provides for the sale by the Registrant and other participants from the
wells on the Ngatoro-1 site and from the Ngatoro-3 gas well of up to
ten petajoules of gas, with a price increase after production of the
first four petajoules. Reasonable efforts are to be made to deliver up
to one petajoule a year. Fletcher Challenge has the option to purchase
any gas production from other Ngatoro wells, but gas from the Ngatoro-2,
- - - - - - - - - - - - - - - -9 and 11 wells is currently flared due to remoteness from
production facilities.
A workover of the Ngatoro-2 oil well was suspended in May, 1998
with the intention of carrying out a complete rehabilitation of the
well after drilling of the Ngatoro-9 development well. In the third
quarter of 1998, the Ngatoro-9 and 11 oil wells were completed and a
workover of the Ngatoro-2 oil well, shut in since December, 1997, was
completed and the well recommenced production. Ngatoro field oil
production is about 1,100 barrels a day.
Drilling two wells early in 1999 to test separate oil prospects,
G0880 and BS780, is under consideration. A water injection well is
planned to increase recovery from the Ngatoro-1 oil well pool.
31
For work planned to be done before December 31, 1999 on PMP 38148
and its estimated cost, see Item 1. Business Plan of Operations.
Petroleum Prospecting Licence PPL 38706 (7.75%)
PPL 38706 and PMP 38148 are situated onshore in the north central
part of the Taranaki Basin, and cover a total area of approximately
40,000 acres. The area is immediately to the south of PEP 38720.
PPL 38706 expired on July 31, 1998, but a retention licence
covering about 5,800 acres of PPL 38706 area was granted in August
1998. The retention licence expires July 31, 2001 and requires the
participants to drill a well before that date. Should a discovery be
made, the participants may apply for a petroleum mining permit over the
extent of the discovery for a term of up to 40 years. The licence is
operated by Fletcher Challenge Energy Ltd. which holds a 92.25% working
interest in the licence. The Crown in right of New Zealand has reserved
a royalty of the greater of five per cent of net sales revenue from the
sale of petroleum products or 20% of accounting profits.
Fletcher Challenge operates the adjoining permit PML 38138. The
Registrant does not have a participating interest in PML 38138. In May
1998, the Tariki-2C well was drilled on PML 38138 about 200 metres from
the border with PPL 38706. The Registrant made a contribution to the
cost of the well entitling it to data from the well, which is being
refunded because the Tariki-2C well was a commercial success. The oil
reserves discovered in the Tikorangi Limestone Formation by the Tariki-
2C well may extend into PPL 38706.
The location and trajectory of a well on PPL 38706 is being
determined and is scheduled to be drilled in 1999.
For work planned to be done before December 31, 1999 on PEP 38706
and its estimated cost, see Item 1. Business Plan of Operations.
Petroleum Exploration Permit PEP 38716 (19.8%)
PEP 38716 is situated in the eastern margin of the onshore
Taranaki Basin and covers an area of approximately 67,000 acres. It is
located adjacent to the Waihapa-Ngaere oil and gas field. The gathering
station for the Waihapa-Ngaere oil and gas field is located within a
few miles of the boundary of PEP 38716. The area consists of gently
rolling hills with rural agriculture being the main activity.
Previous exploration of PEP 38716 has resulted in the collection
of several hundred miles of seismic data, and the drilling of several
wells, all of which had oil shows, with Wingrove-1 being a sub
commercial oil discovery.
32
The Crown Prospect is located in the northern part of PEP 38716,
and is to be drilled by the Huinga-1 well in the second quarter 1999.
The main target horizons in the Crown Prospect are the Tikorangi
limestones, at an estimated depth near 9,000 feet and the Tariki
sandstones below about 11,500 feet, while Kapuni Group sandstones are
expected to be encountered below 12,500 feet. The Crown Prospect is
interpreted as a thrust block anticline, somewhat similar in geological
style and size to the nearby Waihapa oil field.
South of the Crown Prospect lies the Oru Prospect which targets
the Miocene sandstones of the Mount Messenger Formation at depths of
less than 5,000 feet. This is considered to be a secondary target
within the permit area. The Waihapa-8 well, drilled on the very edge of
the Oru structure, flow tested oil from the target sandstones at rates
in excess of 750 barrels per day. Oru Prospect is a potential future
drilling target.
A participating interest of 38.4% in PEP 38716 was acquired by the
Registrant on January 30, 1996. On application, the effective date was
changed to April 10, 1996. A participating interest of six percent was
assigned to Durum Energy Corp. By agreement effective July 1, 1997 with
Australian Worldwide Exploration NL, the participants assigned a 25%
participating interest to Australian Worldwide in consideration that
Australian Worldwide pay the first NZ$2,000,000 of the costs of
drilling an exploration well to earn a 25% interest. After giving
effect to this assignment, the other participants are Durum Energy
Corp. (4.0%), Marabella Enterprises Ltd. (39.6%), Euro-Pacific Energy
Pty. Ltd. (6.6%) and Australian Worldwide Exploration NL (25.0%).
Marabella Enterprises Limited, a subsidiary of Bligh Oil & Minerals NL,
is the operator.
By an agreement dated November 6, 1997, Marabella Enterprises Ltd.
agreed to sell a 15% participating interest to Antrim Energy Ltd. for
US$225,000. The Registrant agreed to participate in one-third of this.
After giving effect to this assignment, the participants are the
Registrant (19.8%), Durum Cons. Energy Corp. (4.0%), Marabella
Enterprises Ltd. (29.6%), Euro-Pacific Energy Pty. Ltd. (6.6%),
Australian Worldwide Exploration NL (25.0%) and Antrim Energy Ltd.
(15%).
The permit term is for five years, renewable for a further five
years over 50% of the licence area. Any production permits granted will
be for a term of up to 40 years from the date of issue. The Crown in
right of New Zealand has reserved a royalty of the greater of five
percent of net sales revenue from the sale of petroleum products or 20%
of accounting profits.
33
The conditions of the permit were amended on January 14, 1999. The
participants are required before June 14, 2000 to process and interpret
250 kilometres of existing seismic data utilising PMPS/DMO techniques
as appropriate, acquire, reprocess and interpret 30 kilometres of new
seismic data and acquire aeromagnetic data sufficient to support 3D
modelling. These work programs have been completed. The participants
are required by June 30, 2000 to drill on exploration well to a minimum
depth of 2,500 metres, or to an approved objective or depth unless
geological or engineering constraints encountered whilst drilling make
this unreasonable. The permit is then to be surrendered or a further
work program submitted for the approval of the Minister.
For work planned to be done before December 31, 1999 on PEP 38716
and its estimated cost, see Item 1. Business Plan of Operations.
Petroleum Exploration Permit PEP 38720 (50.0%)
A participating interest of 50.0% in PEP 38720 was acquired by the
Registrant on September 2, 1996. The other participant is Trans-Orient
Petroleum Ltd. The Registrant is the operator.
The permit is approximately 6,322 acres (9.8 square miles) in area
and the term of the permit is five years, renewable for a further five
years over 50% of the permit area. Any production permits granted will
be for a term of up to 40 years from the date of issue. The Crown in
right of New Zealand reserved a royalty of the greater of five per cent
of net sales revenue from the sale of petroleum products or 20% of
accounting profits.
Before September 2, 1997 the participants were obligated to
reprocess a minimum of 100 miles of existing seismic data, undertake
modeling of the seismic data to investigate reservoir distribution,
undertake a reservoir engineering review of flow-tested off-set wells
to investigate likely productivity potential within the permit area and
either commit to drill one exploration well before September 2, 1999 or
commit to collect, process and interpret a minimum of 15 km of new
seismic data before March 2, 1999. The Registrants have completed this
work. If an exploration well is drilled, a program for further
exploration must then be submitted for approval. If further seismic
work is done, the participants must commit by March 2, 1999 to drill an
exploration well before September 2, 1999 or relinquish the permit. The
March 2, 1999 date is being re-negotiated to later in 1999.
In the first half of 1997, the participants completed 38 km of
seismic survey. This confirmed the Waitoriki Prospect as a sizable gas-
condensate drilling target within the Kapuni formation at depths below
3,500 metres. Sandstones of the Mount Messenger Formation are also oil
discovery objectives at depths between 1,500 and 2,000 metres.
34
For work planned to be done before December 31, 1999 on PEP 38720
and its estimated cost, see Item 1. Business Plan of Operations.
Petroleum Exploration Permit PEP 38723 (40%)
PEP 38723 was granted on October 30, 1997. The other participants
are Trans-Orient Petroleum Ltd. (40.0%) and Gondwana Energy Ltd.
(20.0%). The Registrant is the operator. The permit area is 19,783
acres (30.9 square miles) in area. The permit term is for five years,
renewable for a further five years over 50% of the licence area. Any
production permits granted will be for a term of up to 40 years from
the date of issue. The Crown in right of New Zealand has reserved a
royalty of the greater of five per cent of net sales revenue from the
sale of petroleum products or 20% of accounting profits.
By January 30, 1999, the participants were required to reprocess
a minimum of 50 km of seismic data, re-evaluate prospects and leads,
review relevant existing wells to identify a potential Mount Messenger
sand play and develop a sand distribution model in conjunction with the
seismic interpretation, identify and high grade leads for further
seismic acquisition and either make a firm commitment to continue the
work program or surrender the permit. This has been done. By April 30,
2000 the participants must collect a minimum of six square km of 3D
seismic data, or 2D swathe coverage of equivalent detail, interpret the
new data and identify and consider drilling targets. If the
participants continue, by October 30, 2000 they must drill an
exploration well to a minimum depth of 1600 metres unless geological or
engineering constraints encountered while drilling make this
unreasonable and either submit a satisfactory work program for the
remainder of the permit term or surrender the permit.
An operating agreement dated June 24, 1998 governs the working
relationship of the parties. Among other things, the operating
agreement provides that a participant may not sell, assign, transfer,
mortgage, pledge, charge, encumber, lease, sub-lease, declare itself
trustee of or otherwise dispose of or create a charge or encumbrance
over all or part of its participating interest except to a "related
body corporate" as that expression is defined in the Companies Act (NZ)
if that related body corporate holds the participating interest for at
least one year without either the consent of the other participants or
offering the participating interest proposed to be dealt with to the
other participants.
35
Exploration of the general area has resulted in the discovery of
the nearby McKee, Tariki, Ahuroa, Kaimiro and Ngatoro fields. PEP 38723
is underlain by a Late Cretaceous to Pliocene sequence of sedimentary
rocks, in which all the essential elements for oil and gas entrapment
are demonstrated by the surrounding oil and gas fields. The principal
target formation on PEP 38723 is the Mount Messenger sandstones. There
is, however, much regional variation within this formation given its
deposition as toe and slope fans. Experience from the nearby Ngatoro
wells indicates that there may be as little as 1000 metres of lateral
continuity in such sandstones. Definition of drilling targets requires
well control, strong seismic anomalies and evidence of geologic
structural closure.
For work planned to be done before December 31, 1999 on PEP 38723
and its estimated cost, see Item 1. Business Plan of Operations.
AUSTRALIA
Offshore Petroleum Exploration Permit Ashmore Cartier AC/P19, Timor Sea
(65.0%)
A participating interest of 65.0% was acquired by the Registrant
in AC/P19 in May, 1997. The other participant is Mosaic Oil NL (35.0%).
The Registrant is the operator.
The permit comprises some 364,500 acres (570 square miles) and
encompasses the Cartier Trough and parts of the Ashmore Platform. The
permit has a term of six years. In the first three years of the permit,
the participants are required to carry out a program of seismic
reprocessing and acquisition, including the collection of 400 km of
seismic data, with an estimated cost of $246,000.
By an agreement dated August 12, 1997 the participants granted a
five percent carried interest to Lonman Pty. Ltd. The Registrant is
initially carrying 3.25%. If the participants farmout an interest to
drill the first well on the permit, the carried interest will become
five percent of the percentage interest that is free carried through
the farmout. The carried interest may be converted to a participating
interest before the commencement of commercial production. The carried
interest may be assigned after being first offered to the participants.
During August 1998, Veritas DGC acquired 65 miles of new 2D data
for the Registrant; in a detailed infilling of the existing seismic
grid over the Corvus Prospect and the adjacent, much larger but more
uncertain Aquila Lead; features the Registrant had identified in the
western part of the permit. This seismic has confirmed the existence of
the Corvus Prospect, which is mapped as a fault bounded high block with
trapping potential at the Plover Formation level, the producer
formation in the 100 million barrel Jabiru oil field, located on a
similar type and sized fault block about 20 miles southeast of AC/P 19
36
It is planned to acquire about 25 square miles of 3D seismic in the
eastern part of the permit, by purchasing part of the Onnia' 3D
speculative seismic survey acquired in 1998.
During the coming year, the Registrant will continue its
evaluation of 2D and 3D seismic and well data, in order to establish
and rank prospects and leads in the permit. No well is required to be
drilled, under the permit terms for another two years, which gives the
Company ample time in which to arrange the funding of an exploration
well. During this time, the ongoing drilling activity in surrounding
permits is likely to markedly enhance the value of the Registrant's
permit.
This Vulcan Graben area of the Timor Sea is an ongoing focus of
oil exploration, with many of the world's major explorers including
Shell, Chevron and Mobil actively involved. Many wells are committed to
be drilled in licenses surrounding AC/P 19 in the next few years, while
the recent acquisition of large scale 3D seismic surveys over much of
the area is likely to bring about identification of many new targets.
For work planned to be done before December 31, 1999 on AC/P19 and
its estimated cost, see Item 1. Business Plan of Operations.
Offshore Gippsland Basin, Bass Strait Permit VIC/P-39 (33.33%)
A participating interest of 33% was acquired by the Registrant in
VIC/P-39 on July 31 1997. The other participants are Mosaic Oil NL
(34%) and Euro-Pacific Energy Pty. Ltd. (33%). Mosaic Oil NL is the
operator.
The permit comprises some 541,250 acres (845 square miles). The
permit has a term of six years. The permit provides for certain minimum
work requirements. In the first year, the participants must reprocess
certain seismic data. In the second year, a 500 km seismic survey must
be completed. In the third year, an exploration well must be drilled.
The work requirements for the balance of the permit are not mandatory.
The estimated cost for the first three years is $5,600,000. Further
seismic interpretation, seismic data collection and drilling is
prescribed.
By an agreement dated August 12, 1997 the participants granted a
five percent carried interest to Lonman Pty. Ltd. The Registrant is
initially carrying 1 2/3%. If the participants farmout an interest to
drill the first well on the permit, the carried interest will become
five percent of the percentage interest that is free carried through
farmout. The carried interest may be converted to a participating
interest before the commencement of commercial production. The carried
interest may be assigned after being first offered to the participants.
37
The Registrant and the other participants have completed a
detailed PSDM (pre stack depth migration) reprocessing of data from
within this license.
The PSDM study involved application of a computer processing
technology which was unavailable to previous explorers of this area,
and provided much improved depth resolution of geological structure.
However, this has demonstrated that likely oil traps in the Latrobe
Formation, which is the regional hydrocarbon producer, are too small to
merit drilling. Arrangement is being made to relinquish the license.
Offshore Exploration Permit WA-199-P, Western Australia (5.0%
relinquished in 1998)
Pursuant to an agreement dated September 15, 1997 with Boral
Energy Resources Limited, a participating interest of five percent is
to be acquired by the Registrant in WA-199-P in consideration that the
Registrant pay the lesser of 10% of the dry hole costs of drilling the
Kittiwake-1 well or $636,000. The other participants are Boral Energy
Resources Limited (24.869%), which is the operator, Petroz NL
(11.392%), TAP Oil NL (10.0%), Asisun Pty. Ltd. (10.027%) and Santos
(BOL) Pty Ltd. (38.712%)
The Kittiwake-1 well was drilled in April and May 1998. The Plover
Sands, which were the main target of the well, were encountered at a
depth near 8,800 feet, and were present down to the 9,400 foot level.
Electric log evaluation showed there are no significant hydrocarbons in
the reservoir. Accordingly, the decision was taken to plug and abandon
the Kittiwake-1 well. The permit was relinquished.
PAPUA NEW GUINEA
Petroleum Prospecting Licence PPL 192 (40.0%)
A participating interest of 80% in PPL 192 was acquired by the
Registrant in January 1997. The Registrant assigned a 20% participating
interest to each of Trans-Orient Petroleum Ltd. and Durum Cons. Energy
Corp. The remaining participant is Mosaic Oil Niugini Pty. Ltd. (20%).
The Registrant is the operator.
PPL 192 grants the exclusive right to explore for petroleum for an
initial six year term commencing January 28, 1997, extendable for a
further five year term over 50% of the original area, and the exclusive
right to enter into a production agreement upon a discovery. A
production agreement provides the right to produce any oil and gas
discovered for a period of up to 30 years from discovery, subject to a
maximum 22.5% participating interest that can be acquired by the
Government of Papua New Guinea and a two per cent participating
interest that can be acquired by local landowners. See Item 2
Hydrocarbon tenures in New Zealand, Australia, Papua New Guinea and
China for proposed legislative changes.
38
PPL 192 comprises some 1,200,000 acres (1,875 square miles)
located in the foreland of the Papuan Basin, immediately south of the
Highlands fold belt. The main targets of interest are the Kamu
Prospect, the Douglas Lead and the area surrounding the Langia gas
discovery. The licence requires the participants to reprocess seismic
and other data in the first year of the licence at a cost of $100,000
and in the second year of the licence to spend $100,000 on an area
review and an analysis of gas development in a "Kamu" type gas
discovery. This has been done. If work proceeds in the licence area, 50
km of seismic work are required in the third year of the licence and
drilling of an exploration well is required in the fourth year of the
licence.
The participants have carried out a program of geological work,
licence administration and seismic data collection and, intend to
proceed to the second stage of the work program. The Registrant's
portion of budgeted costs is $210,000.
PPL 192 lies across the Strickland River in Western Province,
Papua New Guinea. The area is covered by forests and is relatively
flat. The area is sparsely populated and the lack of roads leaves the
principal mode of transport as the Strickland River.
The Registrant has applied for other interests in Papua New
Guinea.
For work planned to be done before December 31, 1999 on PPL 192
and its estimated cost, see Item 1. Business Plan of Operations.
CHINA
Technical Study Area, Nanling and Wuwei Basins, Anhui Province, China
(50%)
During 1996 and 1997, working under a Joint Technical Study
Agreement with China National Oil and Gas Exploration and Development
Corporation, the Registrant and its other participant, Moondance Energy
Ltd., completed an initial technical review of this 2,500,000 acre area
and identified the Hongzhuang Prospect in the Nanling basin, the
Longtangwan Prospect in the Wuwei basin and several other prospects and
leads of geological types similar to those which have provided oil and
gas discoveries elsewhere in China. Since completion of the Technical
Study in 1997, negotiations have been ongoing with Sinopec (China
Petrochemical Corporation) to finalise a PSC (Production Sharing
Contract) over the area. In meetings in Beijing and Shaobo during
January, 1999 most of the basic terms of a PSC were agreed, and the
Company secured a six month period in which to finalise outstanding
points and to confirm its joint venture's commitment to the terms of the
PSC.
39
The basins are situated immediately north and south of the Yangtze
River in south-eastern Anhui Province and cover approximately 2.5
million acres (3,900 square miles). The shipbuilding center of Wuhu, a
trading hub and deep-water river port, is located in the eastern part
of the Wuwei Basin. It has a population of about 600,000 and is the
last deep water port on the Yangtze River, accommodating ships of up to
10,000 tons year round. Shanghai is some 180 miles downstream.
ITEM 3. LEGAL PROCEEDINGS
There are no material legal proceedings to which the Registrant is
subject or which are anticipated or threatened.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.
There were no matters submitted for the vote of security holders
in the fourth quarter of the year.
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER
MATTERS.
The shares of the Registrant traded on the Vancouver Stock
Exchange ("VSE") in Vancouver, British Columbia, Canada to September
12, 1996. Since January, 1996 the shares of the Registrant have traded
and continue to trade on the OTC Bulletin Board under the symbol
"INDX". Summary trading by quarter, adjusted for the 1996 stock
subdivisions, for the three most recent calendar years ending December
31, 1998:
VSE and Bulletin Board
(in United States dollars unless otherwise indicated)
Year and
Quarter[1] High[1] Low[1] Close[1] Trading Volume[1]
1996
First Quarter CDN$2.75 CDN$0.97 CDN$2.67 6,100,851
Second Quarter CDN$7.80 CDN$2.71 CDN$5.80 28,021,277
Third Quarter[2] 10.25 3.00 5.75 9,214,099
Fourth Quarter 7.75 1.75 3.13 8,341,500
40
1997
First Quarter 4.031 0.30 2.25 10,075,800
Second Quarter 4.437 2.13 4.312 5,675,200
Third Quarter 6.562 3.50 3.656 10,199,200
Fourth Quarter 3.75 1.25 2.438 6,399,900
1998
First Quarter 3.563 2.406 2.844 3,609,500
Second Quarter 3.000 1.492 1.719 3,985,000
Third Quarter 1.813 0.563 0.969 4,191,100
Fourth Quarter 1.031 0.6875 0.4375 4,228,600
[1] Volume adjusted for 1.5 for one share subdivision on April 15,
1996 and two for one share subdivision on May 31, 1996.
[2] To September 12, 1996 on the VSE and thereafter only on the
Bulletin Board.
Recent Sales of Unregistered Securities (Stock, Warrants & Options).
Rights to Acquire Common Shares on Exercise of Options
The names, holdings, exercise price and expiry date of outstanding
options to acquire common shares of the Registrant are as follows:
Name Number of Shares Exercise Expiration
Under Option [1] Price Date
David Bennett[2][3] 200,000 $2.50 10/30/00
Jennifer Bennett[2] 50,000 2.50 03/25/99
Alex Guidi[3] 500,000 2.50 10/30/00
Brad Holland[3] 300,000 2.50 05/13/00
Mark Katsumata 6,000 3.00 05/12/99
Jennifer Muzzin 5,000 3.125 05/22/99
Paul Townson 5,000 3.125 05/22/99
[1] In the year ended December 31, 1998, no options to acquire shares
were exercised.
[2] Transferred to the DJ and JM Bennett Family Trust on receipt of
regulatory approval on June 22, 1998.
[3] Term extended pursuant to agreements dated May 7, 1998.
41
Rights to Acquire Common Shares on Exercise of Warrants
The names, holdings, exercise price and expiry date of outstanding
warrants to purchase common shares of the Registrant are as follows:
Number of
Share Purchase Expiration
Name Warrants Price Date
Tracy Godoy[3] 160,000 CDN$3.485 05/27/99
Alex Guidi[3] 494,000 CDN$3.485 05/27/99
Peter Loretto[1][2][3] 146,000 CDN$3.485 05/27/99
1,000,000 07/03/00
Tanya Loretto[3] 150,000 CDN$3.485 05/27/99
[1] In the year ended December 31, 1998, no warrants to acquire shares
were exercised.
[2] By an agreement dated June 2, 1997, Mr. Loretto purchased
1,000,000 units for $1.80 per unit. Each unit is comprised of one
common share and one non-transferable share purchase warrant. Each
share purchase warrant entitles the holder to purchase a common
share for $1.90 before July 4, 1998, for $2.00 from July 4, 1998
to July 3, 1999 and for $2.10 from July 4, 1999 to July 3, 2000.
[3] Term extended by agreements dated May 8, 1998.
All proceeds from the sale thereof was and will be used for
working capital.
As at December 1998 there were 28,262,398 shares outstanding. At
December 31, 1998 there were 125 shareholders of record resident in
Canada holding 8,758,392 shares and 115 shareholders of record resident
in the United States holding 19,318,967 shares.
No cash dividends have been declared by the Registrant nor are any
intended to be declared. The Registrant is not subject to any legal
restrictions respecting the payment of dividends (except that they may
not be paid to render the Registrant insolvent). Dividend policy will
be based on the Registrant's cash resources and needs and it is
anticipated that all available cash will be needed for property
development for the foreseeable future.
The Registrant believes that its market price is a reflection of
actual sales and purchases. OTC BB quotations may reflect interdealer
prices, without retail markup, markdown or commission and may not
necessarily reflect actual transactions.
42
SEC Rule 15g.
The Company's Units are covered by Section 15g of the Securities
Act of 1933, as amended that imposes additional sales practice
requirements on broker/dealers who sell such securities to persons
other than established customers and accredited investors (generally
institutions with assets in excess of $5,000,000 or individuals with
net worth in excess of $1,000,000 or annual income exceeding $200,000
or $300,000 jointly with their spouses). For transactions covered by
the Rule, the broker/dealer must make a special suitability
determination for the purchase and have received the purchaser's
written agreement to the transaction prior to the sale. Consequently,
the Rule may affect the ability of broker/dealers to sell the Company's
securities and also may affect the ability of purchasers in this
offering to sell their shares in the secondary market.
Section 15g also imposes additional sales practice requirements on
broker/dealers who sell penny securities. These rules require a one
page summary of certain essential items. The items include the risk of
investing in penny stocks in both public offerings and secondary
marketing; terms important to in understanding of the function of the
penny stock market, such as "bid" and "offer" quotes, a dealers
"spread" and broker/dealer compensation; the broker/dealer
compensation, the broker/dealers duties to its customers, including the
disclosures required by any other penny stock disclosure rules; the
customers rights and remedies in causes of fraud in penny stock
transactions; and, the NASD's toll free telephone number and the
central number of the North American Administrators Association, for
information on the disciplinary history of broker/dealers and their
associated persons.
ITEM 6. SELECTED FINANCIAL DATA
The following constitutes selected financial data for the
Registrant prepared in accordance with United States generally accepted
accounting principles for the last five completed financial periods.
The information, expressed in United States dollars unless otherwise
indicated, must be read in conjunction with the more detailed financial
information contained in the accompanying audited financial statements.
43
1998 1997 1996 1995[1] 1995[2]
Current assets $10,547,114 $10,872,800 $ 9,597,265 $ 1,024,635 $ 575,210
Pet. & Gas 2,819,946 1,929,839 1,113,928 60,438 10,320
Prop. & Equip 134,076 115,244 34,933 6,150 -
Incorp costs - - - 867 867
Total assets 13,501,136 12,917,883 10,746,126 1,092,090 586,397
Share capital 18,253,992 18,376,476 15,512,578 4,993,739 4,397,920
Deficit (6,471,552) (5,591,864) (4,853,487) (3,968,214) (3,824,570)
Cum. comp.
adjustment 1,561,800 87,567 - - -
Gross rev. 684,765 870,059 426,432 38,980 25,768
Net (loss) (879,688) (738,377) (885,273) (143,644) (50,706)
Other comp.
income 1,474,233 87,567 - - -
Comp. income
(loss) 594,545 (650,810) (885,273) (143,644) (50,706)
Net Loss per Share (0.03) (0.03) (0.04) (0.01) (0.01)
[1] For the eleven month period ended December 31, 1995.
[2] For the year ended January 31, 1995.
Exchange Rates
On December 31, 1998 the buying rate for Canadian dollars was
US$1.00: Cdn$l.5333. The following table sets out the buying rate for
Canadian dollars for the period indicated. Rates of exchange are
obtained from the Bank of Canada and believed by the Registrant to
approximate closely the rates certified for customs purposes by the
Federal Reserve Bank in New York.
1994 1995 1996 1997 1998
Year End 1.4018 1.3640 1.3706 1.4305 1.5333
Average 1.3659 1.3726 1.3636 1.3844 1.4831
High [1] 1.4065 1.4243 1.3855 1.4393 1.5795
Low [1] 1.3109 1.3303 1.3295 1.3365 1.4082
[1] The high and low buying rate figures are selected from daily high
and low figures.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS
Summary
The Registrant is in the exploration and evaluation stage on its
oil and gas properties and hence has not yet achieved profitability or
break even cash flow. The Registrant has experienced losses in each
fiscal period reported on. Its main source of capital currently is the
issuance of equity securities, which has a dilutive effect on the
Registrant's shareholders. Total losses incurred from incorporation to
December 31, 1998 were $6,471,552. The level of future operations may
be limited by the availability of capital resources, the sources of
44
which are not predictable. The results of operations should be largely
measured by the success of the extent and quality of oil and gas
discovered as a result of exploration programs. The sales value of any
oil and gas discovered by the Registrant will be largely dependent on
factors beyond the Registrant's control such as the market value of the
hydrocarbons produced.
The business of the Registrant was inactive during the 1995 fiscal
year. The Registrant commenced the operation of its current business in
1996. The efforts of management have been directed towards the
acquisition of petroleum interests and the commencement of exploration
programs on the interests acquired. The Registrant is also the operator
on certain of the interests acquired and to that end has established an
exploration office in Wellington, New Zealand. The acquisitions made by
the Registrant between January 1, 1996 and December 31, 1998 are
described under Item 2 - Properties.
Operating Revenue
Effective September 1, 1996 the Registrant bought the outstanding
shares of Minora Energy (New Zealand) Limited for Aus$575,000
(Cdn$478,755, US$348,790). The name of the company was changed to
Ngatoro Energy Limited. Ngatoro Energy Limited owns a five per cent
participating interest and revenue interest in petroleum mining permit
PMP 38148, which has six producing oil wells, four producing gas wells
and two shut-in gas and oil wells.
Annual production revenue was US$234,168 (Cdn$347,411) compared
with gross 1997 production revenue of US$487,941 (Cdn$675,603). The
decrease is attributable to a change in average oil sale price of
US$18.37 per barrel to US$10.90 per barrel and a change in production
volume from 26,556 barrels to 20,628 barrels. This was offset to a
minor degree by commencement of gas sales in the second half of
US$9,247 (Cdn$13,719) with gas production averaging 0.14 million cubic
feet a day in August and September.
Costs and Expenses
In the year ended December 31, 1998 the Registrant incurred
expenses in the acquisition, exploration and development of petroleum
interests of $1,901,030. The amount incurred in the acquisition,
exploration and development of petroleum interests for the year ended
December 31, 1997 was $1,064,976. The increase represents the
acquisition of additional petroleum interests by the Registrant and
development and implementation exploration programs.
Depletion and amortization expense for the year ended December 31,
1998 was $148,875 and for the year ended December 31, 1997 was $97,827.
45
General and administrative expenses for the year ended December
31, 1998 were $510,384 and for the year ended December 31, 1997 were
$1,236,759.
Interest Expense
The Registrant finances its business primarily from the issuance
of common shares and secondarily from the receipt of petroleum revenues
from its interest in the Ngatoro oil field, New Zealand. The Registrant
has not effected any borrowing and has consequently not incurred any
interest expense.
Interest Income
Interest income for the year ended December 31, 1998 was $450,597
and for the year ended December 31, 1997 was $382,118.
Liquidity
The Registrant has maintained an appropriate liquidity level to
fund its expenditure programs in the past and has no reason to conclude
that this will not continue for fiscal 1999. The Registrant is
satisfied with its ability to access capital markets through private
placements, public offerings, and convertible securities in order to
preserve liquidity levels. The Registrant will utilize joint venture
arrangements to reduce its exposure on exploration and development
programs.
Other than the replacement of escrow shares in 1998, there were no
material issuances of shares to finance the operations of the
Registrant.
In the fiscal year ended December 31, 1997 the Registrant
completed a Canadian private placement of 1,000,000 units for $1.80 per
unit. Each unit is comprised of one common share and one non-
transferable share purchase warrant. Each share purchase warrant
entitles the holder to purchase a common share for $1.90 before July 4,
1998, for $2.00 from July 4, 1998 to July 3, 1999 and for $2.10 from
July 4, 1999 to July 3, 2000. The Registrant issued 279,000 common
shares to directors, senior officers and employees pursuant to the
exercise of incentive stock options for gross proceeds of $652,151. The
Registrant also issued 50,000 common shares on exercise of warrants for
proceeds of $125,667.
As of December 31, 1998 the Registrant had $10,390,218 in working
capital as compared with $10,827,096 as of December 31, 1997.
46
Capital Resources
The Registrant's capital resources are comprised primarily of
private investors, including members of management, who are either
existing contacts of the Registrant's management or who come to the
attention of the Registrant through brokers, financial institutions and
other intermediaries. The Registrant's management is of the view that
conventional banking is unavailable to resource companies which are in
the exploration stage. The Registrant's access to capital is always
dependent upon general financial market conditions, especially those
which pertain to venture capital situations such as oil and gas
exploration companies. The Registrant's capital resources have not
changed in 1998 nor are they anticipated to change materially in 1999.
The amount that the Company has spent on acquisitions vs.
exploration and development over the past two years is:
Acquisition: Nil
Exploration and development: $2,966,000
The amount that the Company intends to spend in 1999 on
acquisitions vs. exploration and development is:
Acquisition: Nil
Exploration and development: $1,969,000
See Item 1. Business Plan of Operations.
It is management's intention to acquire, explore and develop oil
and gas properties in the Asia Pacific region. Material capital
commitments to December 31, 1999 are described in Item 1. Business -
Plan of Operations.
The Registrant has no other anticipated capital expenditures of a
material amount. However, the Registrant intends to acquire additional
petroleum interests which may give rise to further capital
expenditures.
The Registrant has no agreements with management, investors,
shareholders or anyone else respecting additional financing at this
time. Because of the nature of the Registrant's business, there are no
trends in the nature of its capital resources which could be considered
predictable. To date, the Registrant's capital resources have consisted
solely of the issuance of common shares pursuant to either public
distributions, private placements or the exercise of convertible
securities.
47
Results of Operations
The Registrant is an exploration company. The Registrant's primary
focus as of December 31, 1998 is the investigation and acquisition of
oil and gas properties. The Registrant's policy is to acquire interests
and where possible, minimize its risk exposure by farming out or joint
venturing these interests to other industry participants.
The Registrant's current property focus is on the acquisition and
exploration of properties primarily in the Austral Pacific region with
the objective of establishing a solid cash flow base and participating
in high potential exploration blocks in under explored countries with
attractive fiscal regimes.
Revenues for the year ended December 31, 1998 were $684,765
compared with $870,059 for the year ended December 31, 1997. The
Registrant's expenses for the year ended December 31, 1998 were
$1,564,453 and unrealized gains were $1,474,233 resulting in a per
share book loss of $(0.03) compared with $1,608,436 and an unrealized
gain of $87,567 resulting in a per share book loss of $(0.03) for the
year ended December 31, 1997.
Effective September 1, 1996 the Registrant bought the outstanding
shares of Minora Energy (New Zealand) Limited for Aus$575,000
(Cdn$478,755, US$348,790). The name of the company was changed to
Ngatoro Energy Limited. This acquisition provided the Registrant with
oil and gas revenues of $163,388 for the year ended December 31, 1996,
$487,941 for the year ended December 31,1997 and $234,168 for the year
ended December 31, 1998. During the year ended December 31, 1998
interest income increased to $450,597 compared to $382,118 for the year
ended December 31, 1997. This is due to additional cash of $2,577,818
provided by the issuance of common shares through private placements
and exercise of stock options and warrants during the year ended
December 31, 1997 and higher interest rates during the year.
48
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
The Registrant operates in the international crude oil, refined
product, natural gas and natural gas liquids markets and is exposed to
fluctuations in hydrocarbon prices, foreign currency rates, and
interest rates that can affect the revenues and cost of operating,
investing and financing. The Registrant has not established any
policies to protect against the foregoing risks.
Commodity Price Risk
The Registrant's policy is to generally be exposed to market
pricing for commodity purchases and sales. The Company has not taken
any steps to protect against the fluctuating market price of oil or
gas.
Foreign Currency Risk
The Registrant has foreign currency exchange rate risk resulting
from operations in overseas countries in the south Pacific and Canada.
The Registrant does not hedge its exposure to currency rate changes,
although it may choose to selectively hedge exposure to foreign
currency exchange rate risk. The Company, however, has no policies
relating to the foregoing.
Interest Rate Risk
The Registrant believes that it has no material interest rate risk
to manage.
ITEM 8. FINANCIAL STATEMENTS.
AUDITORS' REPORT F-1
CONSOLIDATED BALANCE SHEETS F-2
CONSOLIDATED STATEMENTS OF LOSS
AND COMPREHENSIVE INCOME (Loss) F-3
CONSOLIDATED STATEMENTS OF CASH FLOWS F-4
CONSOLIDATED STATEMENTS OF CHANGES
IN STOCKHOLDERS' EQUITY F-5
NOTES TO THE CONSOLIDATED
FINANCIAL STATEMENTS F-6 - F-31
SUPPLEMENTARY INFORMATION S-1 - S-4
49
AUDITORS' REPORT
To the Shareholders of Indo-Pacific Energy Ltd.
We have audited the consolidated balance sheets of Indo-Pacific Energy
Ltd. as at December 31, 1998 and 1997 and the related consolidated
statements of loss and comprehensive income (loss), cash flows and
changes in stockholders' equity for the years ended December 31, 1998,
1997 and 1996. These consolidated financial statements are the
responsibility of the Company's management. Our responsibility is to
express an opinion on these consolidated financial statements based on
our audits.
We conducted our audits in accordance with generally accepted auditing
standards in the United States. Those standards require that we plan
and perform an audit to obtain reasonable assurance whether the
financial statements are free of material misstatement. An audit
includes examining, on a test basis, evidence supporting the amounts
and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made
by management, as well as evaluating the overall financial statement
presentation. We believe that our audits provide a reasonable basis
for our opinion.
In our opinion, these consolidated financial statements referred to
above present fairly, in all material respects, the financial position
of the Company as at December 31, 1998 and 1997 and the results of its
operations, cash flows and changes in stockholders' equity for the years
ended December 31, 1998, 1997 and 1996 in conformity with generally
accepted accounting principles in the United States.
/s/ SADOVNICK TELFORD + SKOV
CHARTERED ACCOUNTANTS
Vancouver, British Columbia
Canada
February 20, 1999
F-1
50
INDO-PACIFIC ENERGY LTD.
Consolidated Balance Sheets
(Expressed in United States Dollars)
As at December 31, 1998 1997
Assets
Current
Cash and short-term deposits $ 8,194,849 $ 10,255,407
Accounts receivable 102,194 134,474
Marketable securities (Note 3) 2,194,875 321,077
Due from related parties (Note 8) 46,161 152,373
Prepaid expenses and deposits 9,035 9,469
------------ ------------
10,547,114 10,872,800
Petroleum and natural gas
properties (Note 4) 2,819,946 1,929,839
Property and equipment (Note 5) 134,076 115,244
------------ ------------
Total Assets $ 13,501,136 $ 12,917,883
Liabilities
Current
Accounts payable and accrued
liabilities $ 156,896 $ 45,704
------------ ------------
Total Liabilities 156,896 45,704
------------ ------------
Stockholders' Equity
Common stock, no par value (Note 6);
100,000,000 shares authorized;
Issued and outstanding at December 31,
1998 and 1997: 28,262,398 shares 18,253,992 18,376,476
Accumulated deficit (6,471,552) (5,591,864)
Accumulated other
comprehensive income 1,561,800 87,567
------------ ------------
Total Stockholders' Equity 13,344,240 12,872,179
------------ ------------
Total Liabilities and
Stockholders' Equity $ 13,501,136 $ 12,917,883
============ ============
Approved by the Directors:
/s/ David Bennett /s/ Alex Guidi
Director Director
F-2
51
INDO-PACIFIC ENERGY LTD.
Consolidated Statements of Loss and Comprehensive Income (Loss)
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 1997 1996
Revenues
Petroleum and natural gas sales $ 234,168 $ 487,941 $ 163,388
Interest income 450,597 382,118 263,044
---------- ----------- -----------
684,765 870,059 426,432
Cost of Sales
---------- ----------- -----------
Production costs 129,781 67,593 19,338
Royalties 10,269 44,209 19,067
Amortization and depletion 148,875 97,827 98,258
Write-off of petroleum and natural
gas properties (Note 4) 765,144 162,048 37,653
---------- ----------- -----------
1,054,069 371,677 174,316
---------- ----------- -----------
(369,304) 498,382 252,116
---------- ----------- -----------
Expenses
General and administrative
(Schedule) 510,384 1,236,759 1,137,389
---------- ----------- -----------
Net loss for the year (879,688) (738,377) (885,273)
Other comprehensive income:
Unrealized gain on marketable
securities 1,474,233 87,567 -
---------- ----------- -----------
Comprehensive income
(loss) for the year $ 594,545 $ (650,810) $ (885,273)
========== =========== ===========
Basic and diluted loss
per share (Note 7) $ (0.03) $ (0.03) $ (0.04)
========== =========== ===========
F-3
52
INDO-PACIFIC ENERGY LTD.
Consolidated Statements of Cash Flows
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 1997 1996
Operating Activities
Net loss for the year $ (879,688) $ (738,377) $ (885,273)
Adjustments to reconcile net loss to
cash applied to operating activities:
Amortization and depletion 148,875 97,827 98,258
Compensation expense (recovery) (129,000) 286,080 694,630
Write-off of petroleum and natural
gas properties (Note 4) 765,144 162,048 37,653
Write-off of incorporation costs - - 867
Changes in non-cash working capital:
Accounts receivable 32,280 8,361 (119,416)
Due from related parties 106,212 (157,821) 5,448
Prepaid expenses and deposits 434 2,003 14,099
Accounts payable and
accrued liabilities 111,192 (35,479) 14,618
---------- ----------- ----------
Net cash provided by (used in)
operating activities 155,449 (375,358) (139,116)
---------- ----------- ----------
Financing Activities
Common shares issued for cash 6,516 2,577,818 9,824,209
---------- ----------- ----------
Net cash provided by financing activities 6,516 2,577,818 9,824,209
---------- ----------- ----------
Investing Activities
Purchase of marketable securities (399,565) (233,510) -
Petroleum and natural gas properties (1,901,030) (1,064,976) (1,182,655)
Proceeds from sale of license interest 150,000 - -
Property and equipment (71,928) (91,121) (35,529)
---------- ----------- ----------
Net cash used in investing activities (2,222,523) (1,389,607) (1,218,184)
---------- ----------- ----------
Net increase (decrease) in cash (2,060,558) 812,853 8,466,909
Cash position - Beginning of year 10,255,407 9,442,554 975,645
---------- ----------- ----------
Cash position - End of year $8,194,849 $10,255,407 $9,442,554
========== =========== ==========
F-4
53
INDO-PACIFIC ENERGY LTD.
Consolidated Statements of Changes in Stockholders' Equity (Expressed
in United States Dollars)
For the Years Ended December 31, 1998, 1997 and 1996
Common Stock Accumulated
Shares Amount Deficit
Balance at December 31, 1995 22,514,398 $ 4,993,739 $ (3,968,214)
Common stock issued for
private placements 1,000,000 2,209,260 -
Common stock issued for
exercise of stock options 3,419,000 7,614,949 -
Net compensation expense
from stock options - 694,630 -
Net loss during the year - - (885,273)
---------- ----------- ------------
Balance at December 31, 1996 26,933,398 $15,512,578 $ (4,853,487)
Common stock issued for
private placements 1,000,000 1,800,000 -
Common stock issued for
exercise of stock options 279,000 652,151 -
Common stock issued for
exercise of warrants 50,000 125,667 -
Net compensation expense
from stock options - 286,080 -
Net loss during the year - - (738,377)
Unrealized gain on marketable
securities - - -
---------- ----------- ------------
Balance at December 31, 1997 28,262,398 $18,376,476 $ (5,591,864)
Common stock issued for
private placements 1,406,250 9,774 -
Cancellation of previously
issued common stock (1,406,250) (3,258) -
Net compensation recovery
from stock options - (129,000) -
Net loss during the year - - (879,688)
Unrealized gain on marketable
securities - - -
---------- ----------- ------------
Balance at December 31, 1998 28,262,398 $18,253,992 $ (6,471,552)
========== =========== ============
F-5a
54
INDO-PACIFIC ENERGY LTD.
Consolidated Statements of Changes in Stockholders' Equity (Expressed
in United States Dollars)
For the Years Ended December 31, 1998, 1997 and 1996
Accumlated
Other Total
Comprehensive Stockholders'
Income Equity
Balance at December 31, 1995 $ - $ 1,025,525
Common stock issued for
private placements - 2,209,260
Common stock issued for
exercise of stock options - 7,614,949
Net compensation expense
from stock options - 694,630
Net loss during the year - (885,273)
----------- ------------
Balance at December 31, 1996 $ - $ 10,659,091
Common stock issued for
private placements - 1,800,000
Common stock issued for
exercise of stock options - 652,151
Common stock issued for
exercise of warrants - 125,667
Net compensation expense
from stock options - 286,080
Net loss during the year - (738,377)
Unrealized gain on marketable
securities 87,567 87,567
----------- ------------
Balance at December 31, 1997 $ 87,567 $ 12,872,179
Common stock issued for
private placements - 9,774
Cancellation of previously
issued common stock - (3,258)
Net compensation recovery
from stock options - (129,000)
Net loss during the year - (879,688)
Unrealized gain on marketable
securities 1,474,233 1,474,233
----------- ------------
Balance at December 31, 1998 $ 1,561,800 $ 13,344,240
=========== ============
F-5b
55
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 1 - NATURE OF OPERATIONS
The Company was incorporated under the Company Act (British Columbia)
and continued its jurisdiction of incorporation to the Yukon Territory
under the Business Corporations Act (Yukon). Its major activity is the
acquisition, exploration and development of petroleum and natural gas
properties.
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
a) Basis of Consolidation
These consolidated financial statements include the accounts of
Indo-Pacific Energy Ltd. and its wholly-owned subsidiaries, Indo
Overseas Exploration Ltd., Indo-Pacific Energy Pty. Ltd., Indo-
Pacific Energy (PNG) Limited, and Source Rock Holdings Limited and
its wholly-owned subsidiaries, Indo-Pacific Energy (NZ) Limited,
Ngatoro Energy Limited, and PEP 38716 Limited.
b) Joint Operations
Substantially all of the Company's activities relate to the
exploration for and production of petroleum and natural gas which
are conducted jointly with other companies and accordingly, the
accounts reflect only the Company's proportionate interest in
these activities.
c) Cash and Short-Term Deposits
Cash and short-term deposits include Government treasury bills and
Bankers' Acceptance with maturities no longer than 90 days,
together with accrued interest.
d) Petroleum and Natural Gas Properties
The Company follows the full cost method of accounting for
petroleum and natural gas operations whereby all costs associated
with the acquisition of, exploration for and development of
petroleum and natural gas reserves are capitalized in cost centers
on a country-by-country basis. Such costs include property
acquisition costs, geological and geophysical studies, carrying
charges on non-producing properties, costs of drilling both
productive and non-productive wells, and overhead expenses
directly related to these activities.
F-6
56
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
Depletion is calculated for producing properties by using the
unit-of-production method based on proved reserves, before
royalties, as determined by management of the Company or
independent consultants. Sales of oil and gas properties are
accounted for as adjustments of capitalized costs, without any
gain or loss recognized, unless such adjustments significantly
alter the relationship between capitalized costs and proved
reserves of oil and gas attributable to a cost center. Costs of
abandoned oil and gas properties are accounted for as adjustments
of capitalized costs and written off to expense.
A ceiling test is applied to each cost center by comparing the net
capitalized costs to the present value of the estimated future net
revenues from production of proved reserves discounted by 10%, net
of the effects of future costs to develop and produce the proved
reserves, plus the costs of unproved properties net of impairment,
and less the effects of income taxes. Any excess capitalized
costs are written off to expense.
Unproved properties are assessed for impairment on an annual basis
by applying factors that rely on historical experience. In
general, the Company may write-off any unproved property under one
or more of the following conditions:
i) there are no firm plans for further drilling on the unproved
property;
ii) negative results were obtained from studies of the unproved
property;
iii) negative results were obtained from studies conducted in the
vicinity of the unproved property; or
iv) the remaining term of the unproved property does not allow
sufficient time for further studies or drilling.
Additionally, the Company has implemented the requirements of
Statement of Financial Accounting Standards No. 121: Accounting
for the Impairment of Long-Lived Assets and for Long-Lived Assets
to be Disposed Of. In evaluating the recoverability of the
Company's long-lived assets, management evaluated the current fair
market value and expected future cash flows attributable to its
long-lived assets and concluded that no impairment of value had
occurred as of December 31, 1998 or 1997.
F-7
57
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
e) Property and Equipment
Property and equipment are recorded at cost and amortized over
their estimated useful lives on a declining-balance basis as
follows:
Office equipment 20% to 30%
Automobile 30%
For each fiscal year in which property and equipment are acquired,
management deems each acquisition to occur midway through the
fiscal year and accordingly, the amortization recorded is
restricted to one-half of the normal rate. Amortization is not
recorded in the year of disposal.
f) Translation of Foreign Currencies
The Company's foreign operations are of an integrated nature and
accordingly, the remeasurement method of foreign currency
translation is used for conversion into United States dollars, as
follows:
Revenues and expenses arising from foreign currency transactions
are translated into United States dollars at the average rate for
the year. Monetary assets and liabilities are translated into
United States dollars at the rates prevailing on the balance sheet
date. Other assets and liabilities are translated into United
States dollars at the rates prevailing on the transaction dates.
Exchange gains and losses are recorded as income or expense in the
year in which they occur.
g) Use of Estimates
The preparation of financial statements in conformity with
generally accepted accounting principles requires the Company's
management to make estimates and assumptions that affect the
reported amounts of assets and liabilities and disclosures of
contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenues and expenses
during the reporting year. Actual results could differ from these
estimates.
F-8
58
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
h) Financial Instruments and Financial Risk
i) Fair value of financial instruments
The Company's financial instruments consist of current assets and
current liabilities. The fair values of the current assets and
liabilities approximate the carrying amounts due to the short-term
nature of these instruments.
ii) Credit risk
The Company is subject to credit risk through short-term
investments. Short-term cash investments are placed in short
duration corporate and government debt securities with well-
capitalized financial institutions. By policy, the Company limits
the amount of credit exposure in any one type of investment
instrument.
i) Accounting Pronouncements Recently Issued
The Financial Accounting Standards Board ("FASB") issued Statement
of Financial Accounting Standards No. 128: Earnings per Share
("SFAS 128"), effective for fiscal periods ending after December
15, 1997 and requiring restatement of all prior period earnings
per share data. SFAS 128 replaces the presentation of primary
earnings per share ("EPS") with a presentation of both basic and
diluted EPS for all entities with complex capital structures.
Basic EPS excludes dilutive securities and is computed by dividing
income available to common shareholders by the weighted-average
number of common shares outstanding for the period. Diluted EPS
reflects the potential dilution that could occur if dilutive
securities were converted into common shares and is computed
similarly to fully diluted EPS pursuant to previous accounting
pronouncements. SFAS 128 applies equally to loss per share
presentations.
The FASB issued Statement of Financial Accounting Standards No.
130: Reporting Comprehensive Income ("SFAS 130"), effective for
fiscal periods beginning after December 15, 1997 and requiring
restatement of all comparative financial statements disclosed.
SFAS 130 requires that all items required to be recognized under
accounting standards as components of comprehensive income be
reported as part of the basic financial statements.
59
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
i) Accounting Pronouncements Recently Issued
The FASB issued Statement of Financial Accounting Standards No.
131: Disclosures about Segments of an Enterprise and Related
Information ("SFAS 131"), effective for fiscal periods beginning
after December 15, 1997 and requiring restatement of all
comparative financial statements disclosed. SFAS 131 establishes
standards for reporting information about operating segments in
annual financial statements and requires selected information
about operating segments in interim financial reports. The
Company does not expect adoption of this new standard to have a
material effect on its financial reporting.
NOTE 3 - MARKETABLE SECURITIES
Marketable securities are comprised of 517,020 shares of Trans-Orient
Petroleum Ltd., acquired at a cost of $383,075 and 1,000,000 shares of
AMG Oil Ltd., subject to resale restrictions, acquired at a cost of
$250,000. At December 31, 1998, the market value of these shares were
$694,875 and $1,500,000 (December 31, 1997 $321,077 and Nil)
respectively. Trans-Orient Petroleum Ltd. and AMG Oil Ltd. (formerly
Trans New Zealand Oil Company) are public companies with directors,
officers and principal shareholders in common with the Company.
Refer to Note 8
F-10
60
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES
Petroleum and natural gas properties are comprised as follows:
1998 1997
Accumulated
Amortization Net Book Net Book
Cost and Depletion Value Value
Proved:
New Zealand
PMP 38148
Ngatoro Oil Field $ 691,766 $ 274,331 $ 417,435 $ 315,150
----------- --------- ----------- -----------
Total Proved 691,766 274,331 417,435 315,150
----------- --------- ----------- -----------
Unproved:
New Zealand
PEP 38256 29,920 - 29,920 -
PEP 38328 645,836 - 645,836 398,443
PEP 38330 194,286 - 194,286 109,219
PEP 38332 194,961 - 194,961 41,054
PEP 38335 3,829 - 3,829 -
PEP 38339 4,270 - 4,270 -
PPL 38706 79,038 - 79,038 14,897
PEP 38716 370,781 - 370,781 333,459
PEP 38720 208,335 - 208,335 176,960
PEP 38723 17,957 - 17,957 -
New Licenses 29,322 - 29,322 25,899
Australia
AC/P19 183,073 - 183,073 50,254
VIC/P39 - - - 20,976
WA-199-P - - - 1,165
People's Republic of China
Nanling-Wuwei Blocks 311,442 - 311,442 324,851
Papua New Guinea
PPL 192 125,677 - 125,677 117,512
New Licenses 3,784 - 3,784 -
----------- --------- ----------- -----------
Total Unproved 2,402,511 - 2,402,511 1,614,689
----------- --------- ----------- -----------
$ 3,094,277 $ 274,331 $ 2,819,946 $ 1,929,839
=========== ========= =========== ===========
F-11
61
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
NEW ZEALAND
Unless otherwise indicated, petroleum exploration permits granted in
New Zealand provide for the exclusive right to explore for petroleum
for an initial term of five years, renewable for a further five years
over one-half of the original area. The participants are allowed to
exceed the committed work programs for the permits or apply for
extensions or reductions of such work programs for any particular year.
Any production permits granted will be for a term of up to 40 years
from the date of issue. The New Zealand government has reserved a
royalty of the greater of 5% of net sales revenue or 20% of accounting
profits from the sale of petroleum products.
a) PEP 38256
The Company has a 35% participating interest in, and is the
operator of, Petroleum Exploration Permit 38256 ("PEP 38256")
commencing August 25, 1997. At least one-half of the original
area must be relinquished by August 25, 2000. The other
participants in PEP 38256 are Trans-Orient Petroleum Ltd. (35%)
and AMG Oil Ltd. (30%).
The Company and the other participants have completed the work
program required for the first two and a half years which included
modelling existing gravity data, acquiring new gravity and
magnetotelluric data, reprocessing existing seismic data, and
acquiring, processing and interpreting 200 kilometers of new
seismic data. The remaining work program requires the
participants to commit by February 25, 2000 to drill one
exploration well prior to August 25, 2000, or surrender the
permit.
By an agreement dated June 25, 1998, AMG Oil Ltd. ("AMG") acquired
a right to earn up to an 80% participating interest in PEP 38256
from Trans-Orient Petroleum Ltd. ("Trans-Orient") and the Company.
In July 1998, AMG earned a 30% participating interest in PEP 38256
by funding all of the costs of acquiring, processing and
interpreting 200 kilometers of new seismic data. AMG has the right
to earn an additional 50% participating interest by funding all of
the costs of drilling two exploration wells including any further
seismic data required prior to drilling.
F-12
62
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
PEP 38256 is in good standing with respect to its work
commitments. The committed work program for the 1999 fiscal year
has been fulfilled.
Refer to Note 8
b) PEP 38328
The Company has a 40% participating interest in, and is the
operator of, Petroleum Exploration Permit 38328 ("PEP 38328")
commencing July 1, 1996. The other participants in PEP 38328 are
Boral Energy Resources Limited (37.5%) and Trans-Orient Petroleum
Ltd. (22.5%).
The Company and the other participants have completed the work
program required for the first four years which included drilling
the Kereru-1 exploration well, subsequently plugged and abandoned,
acquiring and processing approximately 250 kilometers of new
seismic data, reprocessing approximately 350 kilometers of
existing seismic data, conducting geological field studies,
synthesizing and interpreting all relevant geological and
geotechnical data, completing a review report, and acquiring
further seismic data to detail prospects for drilling. The
remaining work program requires the participants to commit by July
1, 2000 to drill one exploration well prior to July 1, 2001, or
surrender the permit.
Trans-Orient Petroleum Ltd. ("Trans-Orient") acquired a 10%
participating interest in PEP 38328 from the Company by funding
20% of the costs of drilling the Kereru-1 exploration well. By an
agreement dated September 15, 1997, Trans-Orient acquired a
further 10% participating interest in PEP 38328 from the Company
by funding additional costs incurred subsequent to the Kereru-1
exploration well. The consideration received by the Company was
467,020 common shares of Trans-Orient at $0.50 per share. As a
result of certain participants withdrawing from PEP 38328, the
participating interests of the remaining participants were
adjusted on a pro rata basis.
PEP 38328 is in good standing with respect to its work
commitments. The committed work program for the 1999 fiscal year
has been fulfilled.
Refer to Note 3 and 8
63
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
c) PEP 38330
The Company has a 34% participating interest in, and is the
operator of, Petroleum Exploration Permit 38330 ("PEP 38330")
commencing July 1, 1996. The other participants in PEP 38330 are
NWE (ZOCA 96-16) Pty. Ltd. (formerly Moondance Energy Pty. Ltd.)
(33%) and Mosaic Oil N.L. (33%).
The Company and the other participants have completed the work
program required for the first three years which included
reprocessing and interpreting a minimum of 80 kilometers of
existing seismic data and acquiring, processing and interpreting
a minimum of 72 kilometers of new seismic data. The remaining
work program requires the participants to complete the following:
(i) subject to commitment prior to July 1, 1999, acquire, process
and interpret a minimum of 25 kilometers of new seismic data
and commit prior to July 1, 2000 to drill an exploration
well, or surrender the permit; and
(ii) subject to commitment prior to July 1, 2000, drill one
exploration well prior to July 1, 2001, or surrender the
permit.
PEP 38330 is in good standing with respect to its work
commitments. The committed work program for the 1999 fiscal year
has been fulfilled.
d) PEP 38332
The Company has a 42.5% participating interest in, and is the
operator of, Petroleum Exploration Permit 38332 ("PEP 38332")
commencing June 24, 1997. The other participants in PEP 38332 are
Boral Energy Resources Ltd. (37.5%) and Trans-Orient Petroleum
Ltd. (20%).
The Company and the other participants have completed the work
program required for the first two and a half years which included
reprocessing a minimum of 100 kilometers of existing seismic data,
acquiring a minimum of 75 kilometers of new seismic data, and
undertaking photogeologic and field geological mapping. The
remaining work program requires the participants to commit by
December 24, 1999 to drill one exploration well prior to June 24,
2000, or surrender the permit.
F-14
64
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
PEP 38332 is in good standing with respect to its work
commitments. The committed work program for the 1999 fiscal year
has been fulfilled.
Refer to Note 8
e) PEP 38335
The Company has a 10% participating interest in Petroleum
Exploration Permit 38335 ("PEP 38335") commencing November 29,
1998. PEP 38335 covers the same area as Petroleum Prospecting
License 38312 which expired in November 1997. The other
participants in PEP 38335 are Asia Pacific Oil Sdn. Bhd. (45%),
Everest Energy Inc. (30%), as the operator, and Trans-Orient
Petroleum Ltd. (15%).
The Company and the other participants are required to complete a
work program as follows:
(i) prior to November 29, 1999, complete a geological review of
PEP 38335 while incorporating the results of the Waitaria-1
exploration well drilled in August 1997, acquire 20
kilometers of new 2D seismic data or equivalent 3D seismic
data, and either commit to complete the next stage of the
work program detailed below in (ii) or surrender the permit;
(ii) prior to November 29, 2000, drill one exploration well and
either commit to complete the next stage of the work program
detailed below in (iii) or surrender the permit; and
(iii) prior to November 29, 2001, evaluate the results of the
exploration well drilled during the second year and either
commit to a satisfactory work program for the remainder of
the permit term or surrender the permit.
PEP 38335 is in good standing with respect to its work
commitments. The Company's committed work program for the 1999
fiscal year requires an estimated $10,000 of exploration
expenditures to be incurred.
Refer to Note 8
F-15
65
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
f) PEP 38339
The Company has a 50% participating interest in, and is the
operator of, Petroleum Exploration Permit 38339 ("PEP 38339")
commencing November 26, 1998. The other participant in PEP 38339
is Trans-Orient Petroleum Ltd. (50%).
The Company and the other participant are required to complete a
work program as follows:
(i) prior to February 26, 2000, reprocess existing seismic data,
acquire a minimum of 50 new gravity stations to produce
revised gravity maps and models, perform geochemical
evaluations, identify prospects and leads for further
evaluation and either commit to complete the next stage of
the work program detailed below in (ii) or surrender the
permit;
(ii) prior to November 26, 2000, acquire, process and interpret a
minimum of 20 kilometers of onshore seismic data and 50
kilometers of offshore seismic data and either commit to
complete the next stage of the work program detailed below in
(iii) or surrender the permit;
(iii) prior to May 26, 2001, acquire, process and interpret
additional seismic data necessary to detail an onshore or
offshore prospect and either commit to complete the next
stage of the work program detailed below in (iv) or surrender
the permit; and
(iv) prior to November 26, 2001, drill one onshore or offshore
exploration well and either commit to a satisfactory work
program for the remainder of the permit term or surrender the
permit.
PEP 38339 is in good standing with respect to its work
commitments. The Company's committed work program for the 1999
fiscal year requires an estimated $7,000 of exploration
expenditures to be incurred.
Refer to Note 8
F-16
66
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
g) PMP 38148 Ngatoro Oil Field
By an agreement dated December 4, 1996 and effective September 1,
1996, the Company acquired a 5% participating interest in
Petroleum Mining Permit 38148 ("Ngatoro Oil Field") and in the
surrounding Petroleum Prospecting License 38706 through the
purchase of Ngatoro Energy Limited for $575,000 in Australian
funds. The New Zealand government has reserved a royalty of the
greater of 5% of net sales revenue or 20% of accounting profits
from the sale of petroleum products which amounts to $10,269
(NZ$19,147) for the 1998 fiscal year. All obligatory work
commitments have been completed.
The Ngatoro Oil Field includes seven producing oil and/or gas
wells.
PMP 38148 is in good standing with respect to its work
commitments. The committed work program for the 1999 fiscal year
has been fulfilled.
h) PPL 38706
The Company has a 7.75% participating interest in Petroleum
Prospecting License 38706 ("PPL 38706"). Fletcher Challenge
Energy Ltd., as the operator, holds the remaining 92.25% interest
in PPL 38706. Royalties payable and production permit grants for
PPL 38706 are subject to the same conditions as petroleum
exploration permits.
In August 1998, the Company and the other participant were granted
an extension for PPL 38706 over a portion of the original area and
are required to complete a work program as follows:
(i) prior to July 31, 1999, incorporate the results of the
Tariki-2C exploration well drilled in May 1998, reprocess
300 kilometers of existing 2D seismic data, acquire, process
and interpret 20 kilometers of infill 2D seismic data and
either commit to complete the next stage of the work program
detailed below in (ii) or surrender the permit;
(ii) prior to July 31, 2000, drill and test one exploration well;
and
(iii) prior to July 31, 2001, evaluate the results of the
exploration well drilled during the second year and submit a
Mining License Application.
67
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
PPL 38706 is in good standing with respect to its work
commitments. The Company's committed work program for the 1999
fiscal year requires an estimated $112,000 of exploration
expenditures to be incurred.
i) PEP 38716
The Company has a 19.8% participating interest in Petroleum
Exploration Permit 38716 ("PEP 38716") commencing January 30,
1996. The other participants in PEP 38716 are Marabella
Enterprises Ltd. (29.6%), as the operator, Australian Worldwide
Exploration N.L. (25%), Antrim Oil and Gas Limited (15%), Euro-
Pacific Energy Pty. Ltd. (6.6%), and Durum Cons. Energy Corp.
(4%).
The Company and the other participants have completed the work
program required for the three years which included reprocessing
and interpreting a minimum of 250 kilometers of existing seismic
data, acquiring, processing and interpreting 30 kilometers of new
seismic data, acquiring aeromagnetic data, and committing to drill
one exploration well prior to June 30, 1999.
By an agreement effective July 30, 1998 with Antrim Oil and Gas
Limited ("Antrim"), the Company and one other participant agreed
to assign a 15% participating interest in PEP 38716 to Antrim for
a total amount of $450,000. The Company received $150,000 for
assigning a 5% participating interest in PEP 38716 to Antrim.
By an agreement effective July 1, 1997 with Australian Worldwide
Exploration N.L. ("Australian Worldwide"), the participants agreed
to assign a 25% participating interest in PEP 38716 to Australian
Worldwide in consideration for funding 50% of the estimated dry
hole costs of drilling an exploration well.
PEP 38716 is in good standing with respect to its work
commitments. The Company's committed work program for the 1999
fiscal year requires an estimated $273,000 of exploration
expenditures to be incurred.
Refer to Note 8
F-18
68
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
j) PEP 38720
The Company has a 50% participating interest in, and is the
operator of, Petroleum Exploration Permit 38720 ("PEP 38720")
commencing September 2, 1996. The other participant in PEP 38720
is Trans-Orient Petroleum Ltd. (50%).
The Company and the other participant have completed the work
program required for the first two and a half years which included
reprocessing and interpreting a minimum of 100 kilometers of
seismic data, seismic modelling, reservoir engineering and
petrophysical reviews, and acquiring a minimum of 15 kilometers of
new seismic data. The remaining work program requires the
participants to commit by March 2, 1999 to drill one exploration
well prior to September 2, 1999 and either commit to a
satisfactory work program for the remainder of the permit term or
surrender the permit. The participants have applied to have the
commitment deadline extended to July 19, 1999.
PEP 38720 is in good standing with respect to its work
commitments. The Company's committed work program for the 1999
fiscal year requires an estimated $460,000 of exploration
expenditures to be incurred.
Refer to Note 8
k) PEP 38723
The Company has a 40% participating interest in, and is the
operator of, Petroleum Exploration Permit 38723 ("PEP 38723")
commencing October 30, 1997. The other participants in PEP 38723
are Trans-Orient Petroleum Ltd. (40%) and Gondwana Energy, Ltd.
(20%).
The Company and the other participants have completed the work
program required to January 30, 1999 which included reprocessing
and interpreting a minimum of 50 kilometers of seismic data. The
remaining work program requires the participants to collect a
minimum of six kilometers of 3D seismic data or equivalent 2D
swathe coverage prior to April 30, 2000 and either commit by April
30, 2000 to drill an exploration well by October 30, 2000 or
surrender the permit.
F-19
69
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
PEP 38723 is in good standing with respect to its work
commitments. The Company's committed work program for the 1999
fiscal year requires an estimated $63,000 of exploration
expenditures to be incurred.
Refer to Note 8
AUSTRALIA
Offshore exploration permits granted in Australia provide for the
exclusive right to explore for petroleum for an initial term of six
years, renewable for an unlimited number of five-year terms over one-
half of the remaining area at each renewal. The participants are
allowed to exceed the committed work programs for the permits or apply
for extensions or reductions of such work programs for any particular
year. Any production permits granted will be for a term of 21 years
from the date of issue, renewable for a further 21 years. In addition
to general Australian taxation provisions, most offshore permits,
including all of the Company's Australian permits, are subject to
Petroleum Resource Rent Taxation at the rate of 40% on a project's net
income after deduction of allowable project and exploration
expenditures, with undeducted exploration expenditures compounded
forward at the Long-term Bank Rate ("LTBR") plus 15% and project
expenditures at LTBR plus 5%.
l) AC/P19
The Company has a 65% participating interest in, and is the
operator of, Ashmore-Cartier Permit 19 ("AC/P19") commencing May
30, 1997. The other participant in AC/P19 is Mosaic Oil N.L.
(35%). A third party has the right to acquire a 5% participating
interest in AC/P19.
The Company and the other participant have completed the work
program required for the first two years which included mapping,
seismic data analysis, and delineating prospects and leads. The
remaining work program requires the participants to complete the
following:
(i) prior to May 30, 2000, conduct a 300 kilometer 2D or 70
square kilometer 3D seismic grid;
(ii) prior to May 30, 2001, acquire, process and interpret
additional seismic data;
70
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
(iii) prior to May 30, 2002, drill one exploration well; and
(iv) prior to May 30, 2003, reinterpret and evaluate results.
The participants have the right to withdraw from AC/P19 at the end
of each year's work program starting in the third year.
AC/P19 is in good standing with respect to its work commitments.
The Company's committed work program for the 1999 fiscal year
requires an estimated $246,000 of exploration expenditures to be
incurred.
m) VIC/P39
The Company has a 33% participating interest in Victoria/P39
("VIC/P39") commencing July 31, 1997. The other participants in
VIC/P39 are Mosaic Oil N.L. (34%), as the operator, and Euro-
Pacific Energy Pty. Ltd. (33%). A third party has the right to
acquire a 5% participating interest in VIC/P39.
The Company and the other participants are required to complete a
work program as follows:
(i) prior to July 31, 1999, acquire, process and interpret 500
kilometers of 2D seismic data;
(ii) prior to July 31, 2000, drill one exploration well;
(iii) prior to July 31, 2001, collate and reprocess seismic data;
(iv) prior to July 31, 2002, acquire, process and interpret a
further 500 kilometers of 2D seismic data; and
(v) prior to July 31, 2003, drill a second exploration well.
The participants have the right to withdraw from VIC/P39 at the
end of each year's work program starting in the third year.
VIC/P39 is in good standing with respect to its work commitments.
However, due to negative results obtained from studies of VIC/P39,
the participants are currently renegotiating the license
obligations with the possibility of surrendering the license.
Accordingly, the Company has written off VIC/P39 in its entirety.
F-21
71
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
The Company's committed work program for the 1999 fiscal year
requires an estimated $184,000 of exploration expenditures to be
incurred.
n) WA-199-P
By an agreement effective September 15, 1997 with Boral Energy
Resources Limited, the Company acquired a 5% participating
interest in Permit Western Australia-199-P ("WA-199-P") by funding
10% of the costs of drilling the Kittiwake-1 exploration well in
March 1998 to a maximum of $850,000 in Australian funds. The
other participants in WA-199-P are Boral Energy Resources Limited
(24.869%), as the operator, Santos (BOL) Pty. Ltd. (38.712%),
Petroz NL (11.392%), Asisun Pty. Ltd. (10.027%) and TAP Oil NL
(10%).
Due to the negative result of the Kittiwake-1 exploration well,
the participants surrendered the license in September 1998.
Accordingly, the Company has written off WA-199-P in its entirety.
PEOPLE'S REPUBLIC OF CHINA
o) Nanling-Wuwei Blocks
By a Joint Study Agreement dated March 18, 1996 with China
National Oil and Gas Exploration and Development Corp. ("CNODC"),
the Company has a 50% participating interest to study the Nanling
and Wuwei Blocks ("the Blocks"). The other participant in the
Blocks is Moondance Energy Limited (50%).
A detailed technical evaluation of the Blocks, including seismic
data reprocessing and remapping, investigating field geology, and
conducting an economic evaluation, was completed by June 30, 1997
after which the Joint Study Agreement expired.
The Company has the exclusive right to obtain partners to enter
into a Production Sharing Contract by July 1999.
The Company's committed work program for the 1999 fiscal year
requires an estimated $48,000 of exploration expenditures to be
incurred.
F-22
72
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 4 - PETROLEUM AND NATURAL GAS PROPERTIES (continued)
PAPUA NEW GUINEA
p) PPL 192
The Company has a 40% participating interest in, and is the
operator of, Petroleum Prospecting License No. 192 ("PPL 192").
PPL 192 grants the exclusive right to explore for petroleum for an
initial term of six years commencing January 28, 1997, extendable
for a further five years over one-half of the original area, and
the right to enter into a Petroleum Agreement upon a discovery.
The Petroleum Agreement provides the right to produce any oil and
gas discovered for a period of up to 30 years from discovery,
subject to a maximum 22.5% participating interest that can be
acquired by the Government of Papua New Guinea and a 2%
participating interest that can be acquired by local landowners.
The other participants in PPL 192 are Trans-Orient Petroleum Ltd.
(20%), Durum Cons. Energy Corp. (20%) and Mosaic Oil N.L. (20%).
The Company and the other participants have completed the work
program required for the first two years which included
reprocessing and interpreting a minimum of 200 kilometers of
existing seismic data, conducting field and environmental reviews
and engineering and economic analyses, and producing a prospect
and lead ranking report. The remaining work program requires the
participants to complete the following:
(i) prior to January 28, 2000, complete a work program which
includes acquiring, processing and interpreting 50 kilometers
of new seismic data;
(ii) prior to January 28, 2001, drill one exploration well. In
addition, the participants must commit to a minimum work
program prior to November 28, 2000 for the fifth and sixth
years, or surrender the permit;
(iii) prior to January 28, 2002, complete a work program which
includes acquiring 400 kilometers of new 2D or equivalent 3D
seismic data; and
(iv) prior to January 28, 2003, drill a second exploration well.
PPL 192 is in good standing with respect to its work commitments.
The Company's committed work program for the 1999 fiscal year
requires an estimated $210,000 of exploration expenditures to be
incurred.
Refer to Note 8
73
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 5 - PROPERTY AND EQUIPMENT
Property and equipment are comprised as follows:
1998 1997
Accumulated Net Book Net Book
Cost Amortization Value Value
Office equipment $ 181,603 $ 47,527 $ 134,076 $ 113,973
Automobile 5,043 5,043 - 1,271
--------- -------- --------- ---------
$ 186,646 $ 52,570 $ 134,076 $ 115,244
========= ======== ========= =========
NOTE 6 CAPITAL STOCK
a) Authorized and Issued Share Capital
The authorized share capital of the Company is 100,000,000 shares
of common stock without par value. At December 31, 1998 and 1997,
there were 28,262,398 shares of common stock issued and
outstanding.
b) Incentive Stock Options
The Company applies Accounting Principles Board Opinion No. 25:
Accounting for Stock Issued to Employees ("APB 25") to account for
all stock options granted. Further, Statement of Financial
Accounting Standards No. 123: Accounting for Stock-Based
Compensation ("SFAS 123") requires additional disclosure to
reflect the results of the Company had it elected to follow SFAS
123.
SFAS 123 requires a fair value based method of accounting for
stock options using the Black-Scholes option pricing model and
other existing models. These models were developed for use in
estimating the fair value of traded options and require the input
of and are highly sensitive to subjective assumptions including
the expected stock price volatility. The stock options granted by
the Company have characteristics significantly different from
those of traded options. In the opinion of management, the
existing models do not provide a reliable single measure of the
fair value of stock options granted by the Company.
F-24
74
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 6 - CAPITAL STOCK
In accordance with SFAS 123, the following is a summary of the
changes in the Company's stock options for the 1998, 1997, and 1996
fiscal years:
1998 1997 1996
Weighted Weighted Weighted
Average Average Average
Number Exercise Number Exercise Number Exercise
Fixed Options of Shares Price of Shares Price of Shares Price
Balance at
beginning
of year 2,098,000 $2.50 1,949,000 $4.05 912,000 $0.26
Granted - - 570,000 $2.52 5,161,000 $3.23
Exercised - - (279,000) $2.34 (3,419,000) $2.23
Expired/
cancelled (1,032,000) $2.50 (142,000) $0.60 (705,000) $3.21
---------- ----- --------- ----- ---------- -----
Outstanding and
exercisable at
end of year 1,066,000 $2.51 2,098,000 $2.50 1,949,000 $4.05
========= ===== ========= ===== ========== =====
Weighted-average fair
value of options granted
during the year $ - $1.16 $1.52
----- ----- -----
There were no stock options granted during the 1998 fiscal year thus no
weighted-average fair value has been assigned. The weighted-average
fair values for stock options granted during the 1997 and 1996 fiscal
years were estimated at the date of grant using a Black-Scholes option
pricing model with the following weighted-average assumptions: risk-
free interest rates of 6.23% for 1997 and 5.58% for 1996; volatility
factors of the expected market price of the Company's common stock of
0.66 for 1997 and 1.08 for 1996; no expected dividends; and option
lives of 1.64 years for 1997 and 0.72 for 1996. Certain stock options
granted during the 1997 and 1996 fiscal years to purchase a total of
1,632,000 shares exercisable at a weighted-average price of $2.93 per
share have been excluded from the fair value calculations as these
stock options were subsequently cancelled or expired without exercise.
The following is a summary of the Company's net loss and basic and
diluted loss per share as reported and pro forma as if the fair value
based method of accounting defined in SFAS 123 had been applied for the
1998, 1997, and 1996 fiscal years:
F-25
75
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 6 - CAPITAL STOCK (continued)
1998 1997 1996
As Pro As Pro As Pro
Reported Forma Reported Forma Reported Forma
Net loss
for the
year $(879,688) $(1,008,688) $(738,377) $(1,346,697) $(885,273) $(6,310,509)
========= =========== ========= =========== ========= ===========
Basic and
diluted
loss per
share $ (0.03) $ (0.04) $ (0.03) $ (0.05) $ (0.04) $ (0.26)
-------- ----------- --------- ----------- -------- -----------
The following incentive stock options are outstanding at December
31, 1998:
Number of Shares Price per Share Expiry Date
50,000 $ 2.50 March 25, 1999
6,000 $ 3.00 May 12, 1999
10,000 $ 3.125 May 22, 1999
300,000 $ 2.50 May 13, 2000
700,000 $ 2.50 October 30, 2000
During the 1998 fiscal year, stock options to purchase 832,000
shares exercisable at a price of $2.50 per share until May 13,
1998 were amended to 300,000 shares exercisable at a price of
$2.50 per share until May 13, 2000 and stock options to purchase
700,000 shares exercisable at a price of $2.50 per share until
October 30, 1998 were extended to October 30, 2000. Additionally,
stock options to purchase 500,000 shares exercisable at a price of
$2.50 per share until March 25, 1999 were cancelled.
During the 1997 fiscal year, stock options to purchase 1,082,000
shares exercisable at a price of Cdn$5.33 per share until May 13,
1998 were amended to 1,082,000 shares exercisable at a price of
$2.50 per share until May 13, 1998 and stock options to purchase
700,000 shares exercisable at a price of $5.13 per share until
October 30, 1998 were amended to 700,000 shares exercisable at a
price of $2.50 per share until October 30, 1998. Additionally,
stock options to purchase 142,000 shares exercisable at a price of
Cdn$0.84 per share until December 31, 1997 expired.
F-26
76
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 6 - CAPITAL STOCK (continued)
c) Share Purchase Warrants
The following share purchase warrants are outstanding at December
31, 1998:
Number of Shares Price per Share Expiry Date
950,000 Cdn$3.485 May 27, 1999
1,000,000 $2.00/$2.10 July 3, 1999/2000
During the 1998 fiscal year, share purchase warrants to acquire
950,000 shares exercisable at a price of Cdn$3.485 until May 27,
1998 were extended to May 27, 1999.
d) Escrow Shares
During the 1998 fiscal year, 1,406,250 shares at a price of
Cdn$0.003, subject to escrow restrictions, were cancelled. To
replace these cancelled escrow shares, 1,406,250 shares at a price
of Cdn$.01 per share were issued by private placements.
NOTE 7 LOSS PER SHARE
The Financial Accounting Standards Board ("FASB") issued Statement of
Financial Accounting Standards No. 128: Earnings per Share ("SFAS 128")
effective for fiscal periods ending after December 15, 1997 and
requiring restatement of all prior period earnings per share data.
SFAS 128 replaces the presentation of primary earnings per share
("EPS") with a presentation of both basic and diluted EPS for all
entities with complex capital structures including a reconciliation of
each numerator and denominator. Basic EPS excludes dilutive securities
and is computed by dividing income available to common stockholders by
the weighted-average number of common shares outstanding for the year.
Diluted EPS reflects the potential dilution that could occur if
dilutive securities were converted into common stock and is computed
similarly to fully-diluted EPS pursuant to previous accounting
pronouncements. Shares held in escrow are excluded from the weighted-
average number of common stock outstanding until the shares are
released for trading. SFAS 128 applies equally to loss per share
presentations.
F-27
77
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 7 - LOSS PER SHARE (continued)
A reconciliation of the numerators and denominators of the basic and
diluted loss per share calculations follows:
1998 1997 1996
Basic and Diluted Loss per
Share Computation
Numerator, net loss
for the year $ (879,688) $ (738,377) $ (885,273)
---------- ---------- ----------
Denominator:
Weighted-average number of
common shares outstanding 27,861,713 26,176,186 23,873,549
---------- ---------- ----------
Basic and diluted
loss per share $ (0.03) $ (0.03) $ (0.04)
---------- ---------- ----------
For the years ended December 31, 1998, 1997 and 1996, stock options and
warrants have not been included in the computation of diluted loss per
share. The inclusion of these securities would be antidilutive as net
losses were incurred for these years.
NOTE 8 - RELATED PARTY TRANSACTIONS
The following are related party transactions not disclosed elsewhere in
these financial statements.
a) Due from Related Companies
As at December 31, 1998, the Company is owed a total amount of
$46,161 (December 31, 1997 - $152,373) by certain public companies
with directors, officers and principal shareholders in common with
the Company.
b) Consulting and Management Agreements
The Company is of the view that the amounts incurred for services
provided by related parties approximates what the Company would
incur to non-arms length parties for the same services.
During the 1998 fiscal year, the Company paid $57,123 (1997 fiscal
year - $132,214) in consulting fees and $19,480 (1997 fiscal year
Nil) in rent to the President of the Company.
F-28
78
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 8 - RELATED PARTY TRANSACTIONS (continued)
During the 1997 fiscal year, a consulting agreement between the
Company and a private company owned by a former director of the
Company was cancelled. A total of $12,820 was paid by the Company
during the 1997 fiscal year.
c) Petroleum and Natural Gas Properties
Certain participants of petroleum and natural gas properties have
directors, officers and principal shareholders in common with the
Company. These participants are Trans-Orient Petroleum Ltd.,
Durum Cons. Energy Corp. (formerly Durum Energy Corp.), AMG Oil
Ltd. (formerly Trans New Zealand Oil Company), and Gondwana
Energy, Ltd.
Refer to Note 4
d) Private Placement and Stock Option
By an agreement dated June 25, 1998, the Company purchased
1,000,000 shares of AMG Oil Ltd. at a price of $0.25 per share and
was granted a stock option to purchase a further 1,000,000 shares
of AMG Oil Ltd. at a price of $0.50 per share expiring on July 31,
2000. AMG Oil Ltd. (formerly Trans New Zealand Oil Company) is a
public company with directors, officers and principal shareholders
in common with the Company.
Refer to Note 3
NOTE 9 - INCOME TAXES
There are no income taxes payable for the 1998 and 1997 fiscal years.
The Company has approximately Cdn$1.6 million (1997 - Cdn$1.5 million)
of resource and other unused tax pools to offset future taxable income
derived in Canada. In addition, the Company has non-capital losses of
Cdn$1,130,900 available for future deductions from taxable income
derived in Canada, which expire as follows:
F-29
79
INDO-PACIFIC ENERGY LTD.
Notes to the Consolidated Financial Statements
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
NOTE 9 - INCOME TAXES (continued)
2000 Cdn$ 10,071
2001 52,731
2002 251,664
2003 662,559
2004 153,875
--------------
Cdn$ 1,130,900
--------------
The Company also has losses and deductions of approximately NZ$6.4
million (1997 - NZ$3.5 million) available to offset future taxable
income in New Zealand, Australia, Papua New Guinea and People's
Republic of China.
The benefits of these excess resource tax pools and non-capital loss
carryforwards have not been recognized in these financial statements as
there is sufficient uncertainty regarding the realizability of such
benefits. Additionally, it is expected that any income tax effects
arising from the realization of accumulated other comprehensive income
will be offset by application of these excess resource tax pools and
non-capital loss carryforwards.
NOTE 10 - COMPARATIVE FIGURES
Certain comparative figures have been reclassified to conform to the
current year's presentation.
NOTE 11 - SUBSEQUENT EVENT
The Company has a 40% participating interest in, and is the operator
of, an application for a Petroleum Prospecting License No. 215 ("PPL
215") over an area adjacent to PPL 192. The other participants in the
PPL 215 are Trans-Orient Petroleum Ltd. (40%) and Mosaic Oil N.L.
(20%). In January 1999, PPL 215 was offered by the Papua New Guinea
government and awaits formal acceptance by the participants, upon which
PPL 215 will be awarded to the Company and the other participants of
the application.
F-30
80
INDO-PACIFIC ENERGY LTD.
Consolidated Schedule of General and Administrative Expenses
(Expressed in United States Dollars)
For the Years Ended December 31, 1998 and 1997
For the Years Ended December 31, 1998 1997 1996
GENERAL AND ADMINISTRATIVE
EXPENSES
Accounting and audit $ 43,576 $ 54,165 $ 11,776
Compensation expense (recovery) (129,000) 286,080 694,630
Consulting fees (Note 8) 44,081 150,298 27,346
Corporate relations and development 57,938 71,548 51,964
Directors' fees - - 734
Filing and transfer agency fees 11,413 9,803 28,360
Foreign exchange loss 14,771 239,713 56,437
Legal fees 113,101 61,395 39,503
Management fees - - 11,591
Office and miscellaneous 127,988 68,614 75,188
Printing 109,453 104,901 65,710
Rent 70,132 33,791 9,205
Telephone 51,176 23,005 24,968
Travel 54,470 101,567 15,594
Wages and benefits 64,922 31,879 23,516
Write-off of incorporation costs - - 867
Recovery of general and
administrative expenses (123,637) - -
--------- ----------- -----------
$ 510,384 $ 1,236,759 $ 1,137,389
========= =========== ===========
F-31
81
SUPPLEMENTARY INFORMATION ON OIL AND GAS PRODUCING ACTIVITIES
(EXPRESSED IN UNITED STATES DOLLARS)
DECEMBER 31,1998
(Unaudited - Prepared by Management)
S-1
82
INDO-PACIFIC ENERGY LTD.
SUPPLEMENTARY INFORMATION ON OIL AND GAS PRODUCING ACTIVITIES
(EXPRESSED IN UNITED STATES DOLLARS)
AS AT DECEMBER 31,1998
(Unaudited - Prepared by Management)
PROVED PETROLEUM AND NATURAL GAS RESERVE QUANTITIES
December 31, December 31, December
31,
1998 1997 1996
PETROLEUM RESERVES
Proved developed reserves, end of period
Oil (barrels) 90,000 110,500 70,000
Gas (billion cubic feet) 0.13 0,17 0,17
Proved reserves, end of period
Oil (barrels) 90,000 110,500 145,000
Gas (billion cubic feet) 0,13 0.40 0.40
All petroleum and natural gas reserves are located in New Zealand.
Petroleum and natural gas reserves cannot be measured exactly. Reserve
estimates are based on many factors related to reservoir performance
which require evaluation by engineers interpreting available data, as
well as price, costs and other economic factors. The reliability of
these estimates at any point in time depends on both the quality and
quantity of the technical and economic data, the production performance
of the reservoirs as well as extensive engineering judgement.
Consequently, reserve estimates are subject to revision as additional
data becomes available during the producing life of a reservoir. When
a commercial reservoir is discovered, proved reserves are initially
determined based on only limited data from the first well or wells.
Further drilling may better define the extent of the reservoir and
additional production performance, well tests and engineering studies
will likely improve the reliability of the estimate.
Proved developed reserves are reserves that can be expected to be
recovered through existing wells with existing equipment and operating
methods. Proved reserves are reserves which geological and engineering
data demonstrate with reasonable certainty to be recoverable in future
years from known reserves under existing economic and operating
conditions. Reserves are considered proved if economic producibility
is supported by either production or conclusive formation tests.
S-2
83
INDO-PACIFIC ENERGY LTD.
SUPPLEMENTARY INFORMATION ON OIL AND GAS PRODUCING ACTIVITIES
(EXPRESSED IN UNITED STATES DOLLARS)
AS AT DECEMBER 31,1998
(Unaudited - Prepared by Management)
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS RELATING TO
PROVED OIL AND GAS RESERVES
December 31, December 31, December 31,
1998 1997 1996
Future cash inflows $1,222,000 $1,493,878 $ 850,040
Future production and
development costs to
abandonment at December
31, 2003 644,500 639,322 314,576
Future income taxes - - -
---------- ---------- ---------
577,500 854,556 535,464
Discount at 10% annual
rate for estimated timing
of cash flows 117,000 169,983 54,025
---------- ---------- ---------
$ 460,500 $ 684,573 $ 481,439
========== ========== =========
Undiscounted future net cash flows from proved producing oil and
natural gas reserves is largely based on information provided by
in-house reserve calculations. A discount factor of 10% was applied to
estimated future cash flows to compute the estimated present value of
proved oil and natural gas reserves. This valuation procedure does not
necessarily result in an estimate of the fair market value of the
Company's oil and natural gas properties.
There has been no provision for income taxes, as the Company has
resource and other unused tax pools to offset future taxable income,
The only change in the standardized measure of future cash flows from
production has been due to the purchase of Ngatoro Energy Limited
(formerly Minora Energy (New Zealand) Limited), a company whose sole
asset was a 5% interest in the producing Ngatoro oil field. This is the
only interest the Company holds in a proven oil property. The
standardized measure calculation for the property, at December 31,
1998, was $460,500 as compared to the Net Book Value of $417,435.
S-3
84
INDO-PACIFIC ENERGY LTD.
RESULTS OF OPERATIONS FOR PRODUCING ACTIVITIES
(EXPRESSED IN UNITED STATES DOLLARS)
FOR THE YEAR ENDED DECEMBER 31,1998
(Unaudited - Prepared by Management)
New
Total Zealand
REVENUES
Petroleum and natural gas $ 234,168 $ 234,168
--------- ---------
Amortization and depletion 148,875 148,875
Production costs 129,781 129,781
Royalties 10,269 10,269
Write-down of petroleum properties 836,532 245
--------- ---------
1,125,457 289,170
--------- ---------
RESULTS OF OPERATIONS FROM PRODUCING ACTIVITIES
(excluding corporate overhead and
interest costs) (891,289) (55,002)
-------- ---------
LICENCE SALES
Revenue 150,000 150,000
Cost associated with interest sold (78,612) (78,612)
-------- ---------
Net increase from sales of licence interest 71,388 71,388
-------- ---------
Total $(819,901)$ 16,386
========= =========
S-4
85
ITEM 9.
There have been no disagreements on accounting and financial
disclosures during the last three fiscal years to the date of this
annual report.
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS
The names, municipality of residence, age and position held of the
directors and officers of the Registrant are as follows:
Name Age Position Held
Dr. David Bennett[1] 53 President, Chief Executive Officer
and Director
Ronald Bertuzzi[1][2] 62 Director
Alex P. Guidi 40 Chairman of the Board
and Director
Brad J. Holland (1) 42 Director
Mark Katsumata 33 Secretary
[1] Member of audit committee.
[2] Appointed on March 31, 1998.
Dr. David Bennett has been a member of the board of directors and
an officer since October, 1996. Dr. Bennett received a Bachelor of Arts
(Natural Sciences) from Cambridge University in 1968 and a Master of
Science in Exploration Geophysics from the University of Leeds in 1969.
In 1973, Dr. Bennett received his doctorate in Geophysics from the
Australian National University and from 1973 to 1975 conducted post-
doctoral research at the University of Texas (Dallas). From 1975 to
1977, Dr. Bennett was a post-doctoral fellow and lecturer at the
University of Wellington, New Zealand. From 1977 to 1982, Dr. Bennett
was employed by the Department of Scientific and Industrial Research,
Government of New Zealand and from 1982 to 1994 was employed as
geophysicist, exploration manager and finally general manager by New
Zealand Oil and Gas Ltd. Dr. Bennett was an independent consultant from
1994 to 1996 when he joined the Registrant and other associated
companies. Dr. Bennett has been the president and a member of the board
of directors of the Registrant since October, 1996. Since November,
1996, Dr. Bennett has been a member of the board of directors, and
since April, 1997 the president, of Trans-Orient Petroleum Ltd., since
April, 1997 a member of the board of directors and president of Durum
Cons. Energy Corp. and since June 25, 1998 a member of the board of
directors of AMG Oil Ltd.
86
Mr. Bertuzzi was a member of the board of directors from October
2, 1992 to October 30, 1996 and was appointed on March 31, 1998 to fill
the vacancy resulting from the passing of Mr. John Holland. Mr.
Bertuzzi received a Bachelor of Arts from the University of British
Columbia in 1965 and has worked in the medical sales and product
development industries since that time. Mr. Bertuzzi is a member of the
board of directors of several companies, including AMG Oil Ltd., of
which he is president, and Gondwana Energy, Ltd., of which he is a
member of the Board of Directors.
Mr. Alex Guidi has been a member of the board of directors and an
officer since October, 1996. Mr. Guidi has been involved in public
markets since 1985 and since 1989 in the oil and gas sector. Mr. Guidi
has organized and financed several oil and gas companies. Mr. Guidi has
been chairman of the board and a member of the board of directors of
the Registrant since October, 1996. From July, 1988 to December, 1995,
Mr. Guidi was a member of the board of directors of Trans-Orient
Petroleum Ltd. and was elected a member of the board of directors on
January 28, 1998 and chairman on April 22, 1998. From December, 1990 to
May, 1996, Mr. Guidi was a member of the board of directors of Durum
Cons. Energy Corp. and was president from August, 1992 to May, 1996.
From August 6, 1997 Mr. Guidi has been a member of the board of
directors of AMG Oil Ltd.
Mr. Brad Holland was a member of the board of directors from May
1996 to February 1997, an officer from February 1997 to October 15,
1997 and was appointed a member of the board on October 15, 1997. Mr.
Holland received a Bachelor of Science in Chemical Engineering from the
University of Alberta in 1979. Mr. Holland was initially employed for
two years by John Holland Consultants Ltd. in property valuation,
production management, evaluation and financing for production
acquisition. From 1982 to 1988, Mr. Holland was employed by Canadian
Western Natural Gas, a natural gas utility. From 1988 to 1992, Mr.
Holland was employed as a senior project engineer with Nova Corp. where
he was responsible for the design and construction of large diameter
pipeline projects. Since 1992, Mr. Holland has been employed by ARAMCO
in Saudi Arabia in the construction of pipelines.
Mr. Mark Katsumata was a director and officer from December, 1994
to November, 1995 and an officer from November, 1995 to February, 1997.
Mr. Katsumata was appointed Secretary on October 15, 1997. Mr.
Katsumata is a certified general accountant who was in public practice
from 1990 to 1994 in Vancouver, B.C. In 1994 Mr. Katsumata joined the
Registrant. Mr. Katsumata is also the secretary of Trans-Orient
Petroleum Ltd., Durum Cons. Energy Corp., AMG Oil Ltd. and Gondwana
Energy, Ltd.
87
All directors have a term of office expiring at the next annual
general meeting of the Registrant to be scheduled in June 1999 unless
re-elected or unless a director's office is earlier vacated in
accordance with the by-laws of the Registrant or the provisions of the
Business Corporations Act (Yukon). All officers have a term of office
lasting until their removal or replacement by the board of directors.
Consultants
The principal consultants engaged by the Registrant are Mr. Alan
Hart, Dr. Bruce Morris, Mr. Roger Brand, Mr. David Francis, Mr. Carey
Mills and Mr. Tian Xitai.
Mr. Hart holds graduate degrees in geology from the University of
Texas and has 23 years of industry experience. Mr. Hart worked on
petroleum projects for Hunt Oil Company and later with Atlantic
Richfield International in North and West Africa, Central America,
Southeast Asia, Australia and New Zealand. Mr. Hart served for six
years as exploration manager of Arco International's Jakarta-based
companies which, during his tenure, added one trillion cubic feet of
gas and 156 million barrels of oil to the reserve base.
Dr. Morris trained and lectured as a sedimentologist at University
of Victoria (New Zealand). Over the last nine years, he has been
involved in remote oilfield operations in Papua New Guinea, and with
exploration in the Taranaki and East Coast Basin of New Zealand. Dr.
Morris has also worked as a well site geologist for Exxon in the
Gippsland Basin, Australia.
Mr. Brand has over 20 years experience in the oil industry. After
graduating from Oxford University (United Kingdom) in 1974, he worked
for British Petroleum as a geologist in the North Sea and onshore
United Kingdom. Following a move to New Zealand in 1982, Mr. Brand
served as Chief Geologist for New Zealand Oil and Gas Ltd. for three
years. Since 1986, he has conducted a variety of exploration
assessments and prospect valuations for major and minor oil companies
based in New Zealand, Australia and Papua New Guinea. His main
interests lie in the definition of hydrocarbon plays in New Zealand's
Taranaki Basin.
Mr. Francis is a highly experienced field geologist with over 15
years specialist activity in New Zealand's East Coast Basin. He has
completed numerous scientific papers and company reports detailing East
Coast petroleum geology.
Mr. Mills provides the group with a broad range of capabilities.
Before joining the Registrant, Mr. Mills worked as a petrophysisist for
Exxon on the West Tuna Field in the Gippsland Basin, Australia, on the
Moran discovery in Papua New Guinea and had other responsibilities.
88
Mr Tian Xi Tai brings expertise in seismic field acquisition and
data processing, and provides interpretation and liaison services on
the Nanling-Wuwei project. A geophysicist with a Master of Science from
Stanford University (California), Mr. Tian has worked for such
companies as Fletcher Challenge Energy Ltd. and China National
Petroleum Corporation.
Indemnification of Directors and Officers
Except with respect to an action by the Registrant to obtain a
judgment, the constating documents of the Registrant provide for the
indemnification of any director, officer, employee or agent of the
Registrant if the person acted honestly and in good faith with a view
to the best interests of the Registrant and, with respect to any
criminal action or administrative proceeding, had reasonable grounds
to believe that his action was lawful. The Registrant has not,
however, entered into any agreement with a director and officer
providing for the grant of a covenant of indemnity by the Registrant
pursuant to this provision in the constating documents of the
Registrant.
With respect to an action to obtain a judgment, the Registrant is
required under the Business Corporations Act (Yukon) before performing
its obligation to indemnify to obtain the approval of the Supreme Court
(Yukon) of the indemnity and any payment to be made in connection with
the indemnity.
To date, no agreements to contractually provide indemnities have
been executed and delivered.
Indemnification of Directors and Officers
Except with respect to an action by the Registrant to obtain a
judgment, the constating documents of the Registrant provide for the
indemnification of any director, officer, employee or agent of the
Registrant if the person acted honestly and in good faith with a view
to the best interests of the Registrant and, with respect to any
criminal action or administrative proceeding, had reasonable grounds
to believe that his action was lawful. The Registrant has not,
however, entered into any agreement with a director and officer
providing for the grant of a covenant of indemnity by the Registrant
pursuant to this provision in the constating documents of the
Registrant.
With respect to an action to obtain a judgment, the Registrant is
required under the Business Corporations Act (Yukon) before performing
its obligation to indemnify to obtain the approval of the Supreme Court
(Yukon) of the indemnity and any payment to be made in connection with
the indemnity.
89
To date, no agreements to contractually provide indemnities have
been executed and delivered.
Compliance with Section 16(a) of the Securities Exchange Act of 1934.
Section 16(a) of the Securities and Exchange Act of 1934 requires
officers, directors and persons who own more than ten percent of a
registered class of a company's equity securities to file initial
reports of beneficial ownership and to report changes in ownership of
those securities with the Securities and Exchange Commission. They are
also required to furnish the Company with copies of all Section 16(a)
forms they file. To the Company's knowledge, based solely on review of
the copies of Forms 3, 4 and 5 furnished to the Company or written
representations that no other transactions were required, the Company
has determined that the pertinent officers, directors and principal
shareholders have complied with all applicable Section 16(a)
requirements during fiscal 1998.
ITEM 11. EXECUTIVE COMPENSATION
The following table sets forth the aggregate compensation paid by
the Company for services rendered during the period indicated:
SUMMARY COMPENSATION TABLE
Long Term Compensation
Annual Compensation Awards Payouts
(a) (b) (c) (d) (e) (f) (g) (h) (i)
Name Other Restricted LTIP All
and Annual Stock Pay- Other
Principal $ $ Compen Awards Options/ Outs Compen
Position Year Salary Bonus sation($) $ SAR's(#) ($) sation$
December 31
David Bennett
President 1998 $ -0- $0 $ 57,123 $ 560,936[1] 0 $0 $0
CEO and 1997 $ -0- $0 $132,214 $ 0 200,000 $0 $0
Director 1996 $ -0- $0 $ 79,992 $ 0 200,000 $0 $0
Ronald Bertuzzi
Director 1998 $ -0- $0 $0 $ 0 0 $0 $0
1997 $ -0- $0 $0 $ 0 0 $0 $0
1996 $ -0- $0 $0 $ 0 600,000 $0 $0
Alex P.
Guidi
Director 1998 $ -0- $0 $0 $2,944,914[1] 0 $0 $0
1997 $ -0- $0 $0 $ 0 500,000 $0 $0
1996 $ -0- $0 $0 $ 0 500,000 $0 $0
Brad J.
Holland 1998 $ -0- $0 $0 $ 0 0 $0 $0
Director 1997 $ -0- $0 $0 $ 0 1,082,000 $0 $0
1996 $ -0- $0 $0 $ 0 1,122,000 $0 $0
90
Mark
Katsumata
Secretary1998 $ -0- $0 $0 $ 0 0 $0 $0
1997 $ -0- $0 $0 $ 0 10,000 $0 $0
1996 $ -0- $0 $0 $ 0 0 $0 $0
[1] In fiscal 1998, 1,406,250 shares held in escrow and previously
issued for CDN$4,688 in 1994 were cancelled. International
Resource Management Corporation, a private company wholly-owned by
Alex Guidi, held 1,361,250 of these shares with the remaining
45,000 shares held by two former directors. To replace the
cancelled shares, 1,406,250 shares for total proceeds of
CDN$14,063 were reallocated through private placements to
International Resource Management Corporation as to 1,181,250
shares and to the DJ and JM Bennett Family Trust as to 225,000
shares.
Cash Compensation.
During the year ended December 31, 1998 the Registrant had two
executive officers: David Bennett, president and chief executive
officer and Alex Guidi, chairman of the board. The aggregate cash
compensation paid or payable by the Registrant and its subsidiaries to
its executive officers during the year ended December 31, 1998 was
$57,123 all of which was compensation paid to Dr. Bennett.
During the year ended December 31, 1997 the Registrant had two
executive officers: David Bennett, president and chief executive
officer and Alex Guidi, chairman of the board. The aggregate cash
compensation paid or payable by the Registrant and its subsidiaries to
its executive officers during the year ended December 31, 1997 was
$132,214 all of which was compensation paid to Dr. Bennett.
During the year ended December 31, 1996 the Registrant had three
executive officers: David Bennett, president and chief executive
officer; Alex Guidi, chairman of the board; and John Holland, a former
president and chief executive officer. The aggregate cash compensation
paid or payable by the Registrant and its subsidiaries to its executive
officers during the year ending December 31, 1996 was $80,092.
Compensation of Directors.
The Company's Board of Directors unanimously resolved that members
receive no compensation for their services, however, they are
reimbursed for travel expenses incurred in serving on the Board of
Directors.
No other cash compensation, including salaries, fees, commissions,
and bonuses, was paid or is to be paid to the directors and officers of
the Registrant for services rendered for the financial years ended
December 31, 1998 or 1997, nor was any remuneration paid to the
Registrant's directors in their capacity as such.
91
No profit sharing, pension or retirement benefit plans have been
instituted by the Registrant and none are proposed at this time. There
are no arrangements for payments on termination of any member of
management in the event of a change of control.
Aggregated Option/SAR Exercises and Fiscal 1998 Year-End Option/SAR
Value Table.
The following table sets forth certain information with respect to
each exercise of stock options and SARs during fiscal 1998 by each of
the Named Executive Officers, and the fiscal 1998 year-end value of
unexercised options and SARs. The dollar values are calculated by
determining the difference between the exercise or base price of the
options and the fair market value of the underlying stock at the time
of exercise and at fiscal year-end if unexercised, respectively. The
unexercised options, some of which may be exercisable, have not been
exercised and it is possible they might never be exercised. Actual
gains realized, if any, on stock option exercises and common stock
holdings are dependent on the future performance and value of the
Common Stock and overall stock market conditions. There can be no
assurance that the projected gains and values shown in this Table will
be realized.
AGGREGATED OPTION/SAR EXERCISES IN FISCAL 1998
AND OPTION/SAR VALUES AT DECEMBER 31, 1998
Number of Securities Value of Unexercised
Underlying Unexercised In-the-Money at FY-End
Options/SARs Options/SARs (#) at FY-END ($)
Shares Dollar
Acquired Value Exercisable/ Exercisable/
Name on Exercise(#) Realized Unexercisable Unexercisable
______________________________________________________________________________
David
Bennett 0 0 200,000 N/A
Alex
Guidi 0 0 500,000 N/A
Brad
Holland 0 0 300,000 N/A
Mark
Katsumata 0 0 6,000 N/A
92
Long-Term Incentive Plan Awards.
The Company does not have any formalized long-term incentive
plans, excluding restricted stock, stock option and SAR plans, which
provide compensation intended to serve as incentive for performance to
occur over a period longer than one fiscal year, whether such
performance is measured by reference to financial performance of the
Company or an affiliate, the Company's stock price, or any other
measure.
There were no directors' or senior officers' options exercised in
the year ended December 31, 1998. The aggregate value of directors' and
senior officers' options exercised below the market price of the shares
at the time of exercise for the year ended December 31, 1997 was
$570,660 and for the year ended December 31, 1996 was $2,365,008. These
benefits are calculated as the difference between the market price and
option exercise price on the date of exercise. Actual proceeds of the
disposition will usually vary from the date of the exercise to the date
of actual disposition of such shares.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
MANAGEMENT.
Beneficial Holders of More Than Five Percent of Outstanding Shares
The following schedule sets forth the Common Stock ownership of
each person known by the Company to be the beneficial owner of five
percent or more of the Company's Common Stock, each director,
individual, and all officers and directors of the Company as a group.
Each person has sole voting and investment power with respect to the
shares of Common Stock shown, and all ownership is of record and
beneficial.
Name and address Number of Percent
of owner Shares Position of Class
David Bennett[1] 225,000 President, CEO 0.80%
Karori, Wellington and Director
New Zealand
Ronald Bertuzzi 1,790 Director 0.01%
Vancouver, BC
Canada
Alex Guidi 5,724,076 Chairman of Board 20.25%
Vancouver, BC
Canada
93
Brad Holland 0 Director 0.00%
Dhahran, Saudi Arabia
Mark Katsumata 4,000 Secretary 0.01%
Surrey, BC
Canada
ALL OFFICERS AND 5,954,866 21.07%
DIRECTORS AS A
GROUP (5 persons)
[1] By an agreement dated April 15, 1998 the DJ and JM Bennett Family
Trust purchased 225,000 shares at Cdn$0.01 per share, subject to
release on board approval from time to time.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
No director or senior officer, and no associate or affiliate of
the foregoing persons, and no insider has, or has had any material
interest, direct or indirect, in any transactions, or in any proposed
transaction which in either such case has materially affected or will
materially affect the Registrant or its predecessors except as
disclosed herein.
Mr. Alex Guidi is a member of the board of directors, the
chairman, principal shareholder and the promoter of the Registrant. Mr.
Guidi is the chairman, a member of the board of directors, principal
shareholder and the promoter of Tran-Orient Petroleum Ltd. Mr. Guidi is
a shareholder of Durum but is by private agreement not involved in
business of Durum until the earlier of delisting of trading of the
shares of the Registrant through the facilities of the Vancouver Stock
Exchange, agreement of the Vancouver Stock Exchange or April 15, 2000.
Mr. Guidi is a member of the member of the board of directors, the
principal shareholder and the promoter of AMG. Mr. Guidi is the
principal shareholder and promoter of GEL. See below regarding
shareholdings and options, warrants and rights to acquire shares
beneficially held by Mr. Guidi.
Dr. David Bennett is the president, chief executive officer and a
member of the boards of directors of the Registrant, Indo and Durum.
Dr. Bennett is a member of the board of directors of AMG. Dr. Bennett
is a member of the various boards of directors and an officer of Trans-
Orient, Durum and AMG.
Mr. Ronald Bertuzzi is a member of the boards of directors of Indo
and AMG and is president of AMG. Mr. Bertuzzi is also a member of the
board of directors of Gondwana Energy Ltd.
94
Mr. Mark Katsumata is the secretary and controller of the
Registrant, Indo and Durum. Mr. Katsumata is the secretary, treasurer
and controller of AMG and Gondawna.
At December 31, 1998, Mr. Guidi beneficially held 9,621,400 common
shares of the Trans-Orient of a total outstanding of 28,794,060 common
shares (33.4% undiluted) and held rights to acquire an additional
6,800,000 common shares at various prices. At December 31, 1998, Mr.
Guidi beneficially held 5,724,076 common shares of the Registrant of a
total outstanding of 28,262,398 common shares (20.3% undiluted) and
held rights to acquire an additional 994,000 common shares at various
prices. At December 31, 1998, Mr. Guidi beneficially held 200,000
common shares of Durum of a total outstanding of 1,908,381 common
shares (10.5% undiluted). At December 31, 1998 Mr. Guidi beneficially
held 4,491,000 common shares of AMG of a total outstanding of
13,000,000 common shares (34.5% undiluted). At December 31, 1998 Mr.
Guidi beneficially held 1,000,000 common shares of GEL of a total
outstanding of 2,100,000 common shares (47.6% undiluted).
The related transactions in the year ended December 31, 1998 are:
(a) the Registrant sold to Trans-Orient Petroleum Ltd. a ten
percent interest in PEP 38328 and on December 10, 1997 Trans-
Orient Petroleum issued to the Registrant 467,020 shares for
US$0.50 per share in consideration that a subsidiary of Indo
incurred costs in connection with work done on PEP 38328;
(b) by an agreement dated January 31, 1998 AMG voided an agreement
to acquire interests in PEP 38256 from the Registrant and Trans-Orient;
(c) by agreements dated April 15, 1998, International Resources
Management Corporation, owned by Alex Guidi and former directors
surrendered shares to the Registrant and received common shares in
return;
(d) by an agreement dated June 25, 1998 the Registrant granted a
subsidiary of AMG an option to earn a 15% participating interest
in PEP 38256 exercisable by paying for the costs of a 120 mile
seismic program and granted the right to elect to earn a further
25% participating interest paying for any additional seismic to
define two drilling prospects and for the costs of drilling two
exploration wells;
(e) by agreement dated June 25, 1998 the Registrant purchased
1,000,000 shares of AMG for US$0.25 per share;
95
(f) by an agreement dated June 25, 1998 the Registrant was granted
an option to acquire 1,000,000 shares for US$0.50 per share before
the earlier of July 31, 2000 or thirty business days after AMG
ceased to have a right to earn an interest in, or to hold an
interest in, PEP 38256;
(g) by an agreement dated June 25, 1998 the Registrant entered
into with a subsidiary of Trans-Orient an operating agreement
relating to PEP 38256;
(h) by an agreement dated June 25, 1998 the Registrant entered
into with subsidiaries of Trans-Orient and AMG an operating
agreement relating to PEP 38723;
(i) on November 26, 1998 the Registrant and a subsidiary of Trans-
Orient were granted participating interests of 50.0% each in PEP
38339; and
(j) on November 29, 1998 the Registrant and a subsidiary of Trans-
Orient were granted participating interests of 15.0% and 10.0%
respectively in PEP 38335; and
(k) by agreement dated December 3, 1998 the agreement of June 25,
1998 was amended to provide AMG has until the earlier of October
31, 1999 or the date of delivery by AMG to the Registrant and Indo
that AMG has completed the collection and interpretation of
sufficient seismic data to identify a drilling prospect within PEP
38256.
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM
8-K
All schedules are omitted because they are not applicable or the
required information is included in the financial statements or notes
thereto.
B. Reports on Form 8-K
During the 1998 fiscal year the Company filed no reports on Form
8-K.
C. Index to Exhibits
The following Exhibits are filed herewith:
Exhibit
Number Document Description
27 Financial Data Schedule
96 SIGNATURES
Pursuant to the requirements of section 13 or 15(d) of the Securities
Exchange Act of 1934, the Registrant has duly caused this report and
any amendment thereto to be signed on its behalf by the undersigned,
thereunto duly authorized.
INDO-PACIFIC ENERGY LTD.
By: /s/ Alex Guidi
Alex Guidi, Chairman
March 23, 1999
Pursuant to the requirements of section 13 or 15(d) of the Securities
Exchange Act of 1934, the Registrant has duly caused this report and
any amendment thereto to be signed on its behalf by the undersigned,
thereunto duly authorized.
INDO-PACIFIC ENERGY LTD.
By: /s/ David Bennett
Dr. David Bennett, President & Chief Executive Officer
March 16, 1999
KNOW ALL MEN BY THESE PRESENTS, that each person whose signature
appears below constitutes and appoints Dr. David Bennett as true and
lawful attorney, with full power of substitution, for him and in his
name, place and stead, in any and all capacities, to sign any and all
amendments to this registration statement, and to file the same,
therewith, with the Securities and Exchange Commission, and to make any
and all state securities law or blue sky filings, granting unto said
attorney-in-fact and agent, full power and authority to do and perform
each and every act and thing requisite or necessary to be done in or
about the premises, as fully to all intents and purposes as he might or
could do in person, hereby ratifying and confirming all that said
attorney-in-fact and agent, or any substitute or substitutes, may
lawfully do or cause to be done by virtue hereof.
Pursuant to the requirements of the Securities Exchange Act of
1934, the Form 10-K Annual Report and any amendment thereto has been
signed by the following persons in the capacities and on the dates
indicated.
Name Title Date
/s/ David Bennett
Dr. David Bennett President, Chief Executive Officer 3/16/99
and member of the Board of Directors
/s/ Ronald Bertuzzi
Ronald Bertuzzi Director 3/23/99
/s/ Alex Guidi
Alex Guidi Chairman of the Board of Directors 3/23/99
/s/ Mark Katsumata
Mark Katsumata Secretary 3/23/99
97
An annual report has been forwarded to securities holders in each of
the period covered by this report and for the previous five calendar
years ended December 31, 1998; and if any annual report or proxy
material is furnished to security holders in connection with the annual
meeting of stockholders to be held in 1999, a copy of such annual
report or proxy materials will be forwarded to the Commission when it
is forwarded to security holders.