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FORM 10-K
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
[x] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 1996
Commission File number 33-51630:
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CHIEFTAIN INTERNATIONAL FUNDING CORP.
-------------------------------------
(Exact name of registrant as specified in its charter)
NEVADA 98-0127391
- -------------------------------------------------------------- ------------------------------------
(State or other jurisdiction of incorporation or organization) (I.R.S. Employer Identification No.)
-----------------------
1201 TORONTO DOMINION TOWER, EDMONTON CENTRE,
EDMONTON, ALBERTA, CANADA T5J 2Z1
- ----------------------------------------------------- -------------
(Address of Registrant's principal executive offices) (Postal Code)
Registrant's telephone number, including area code: (403) 425-1950
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
Title of each class Name of each exchange on which registered
- ------------------- -----------------------------------------
$1.8125 Convertible Redeemable Preferred Stock......... American Stock Exchange
SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT: None
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes x No
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CHIEFTAIN INTERNATIONAL FUNDING CORP.
1996 FORM 10-K ANNUAL REPORT
Table of Contents
PART I
Page
Item 1. Business ............................................ 3
Employees ........................................... 3
Item 2. Properties .......................................... 3
Item 3. Legal Proceedings ................................... 3
Item 4. Submission of Matters to a Vote of Security Holders.. 3
PART II
Item 5. Market for the Registrant's Securities and
Related Stockholder Matters ..................... 4
Item 6. Selected Financial Data ............................. 5
Item 7. Management's Discussion and Analysis of Financial
Condition and Results of Operations ............. 5
Item 8. Financial Statements and Supplementary Data ......... 6
Item 9. Changes in and Disagreements with Accountants on
Accounting and Financial Disclosure ............. 6
PART III
Item 10. Directors and Executive Officers .................... 6
Item 11. Executive Compensation .............................. 8
Item 12. Security Ownership of Certain Beneficial Owners
and Management .................................. 8
Item 13. Certain Relationships and Related Transactions ...... 9
PART IV
Item 14. Exhibits and Reports on Form 8-K .................... 9
Signatures .......................................................... 16
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PART I
ITEM 1. BUSINESS
Chieftain International Funding Corp. ("Funding Corp." or the "Company") is
a Nevada subsidiary of Chieftain International (U.S.) Inc. ("Chieftain
U.S."), a Nevada corporation which is, in turn, a wholly-owned subsidiary of
Chieftain International, Inc., an Alberta, Canada corporation. The primary
purpose of Funding Corp. is to finance business operations of Chieftain U.S.
On each of August 28, 1992 and November 5, 1992, Funding Corp. issued 100,000
common shares to Chieftain U.S. for total cash proceeds of $15.0 million.
Funding Corp. commenced operations on November 6, 1992 with the initial public
offering of 2,400,000 $1.8125 Convertible Redeemable Preferred Shares
("Preferred Shares"). An additional 326,700 Preferred Shares were issued
pursuant to the underwriter's exercise of an over-allotment option. Proceeds of
the issuance of Preferred Shares, net of offering costs of $4.7 million, were
$63.4 million. The Preferred Shares are redeemable at the option of the Company
at $26.0069 per share during 1997 declining to $25.00 per share after December
31, 2001 plus accumulated and unpaid dividends.
On November 6, 1992, Funding Corp. purchased 2,840,000 $1.8125 Redeemable Class
B Preferred Shares of Chieftain U.S., its parent company, at $25.00 per share,
and subsequently purchased an additional 300,000 of such shares to hold a total
of 3,140,000 such shares. Funding Corp. receives quarterly dividends on such
shares at the annual rate of $1.8125 per share. The shares are redeemable at
the option of the issuer at $26.0069 per share during 1997 declining to $25.00
during 2002 and thereafter.
Since December 31, 1992, Funding Corp. has, from time to time, purchased
short-term notes, payable by Chieftain U.S., with funds in excess of working
capital requirements. Such notes bear interest at competitive money market
rates.
Chieftain U.S. is engaged in the acquisition of gas and oil reserves through
purchase and through exploration and development and in gas and oil production
and sales in the United States. Its principal properties are located in the
U.S. federal waters of the Gulf of Mexico and in southeast Utah. Chieftain U.S.
has working interests in additional properties in the Gulf of Mexico region.
Onshore in the United States, in addition to the interests in Utah and the Gulf
of Mexico region, Chieftain U.S. holds minor interests in developed and
undeveloped acreage in the Rocky Mountain and Williston Basin areas and in
Pennsylvania. Reference is made to the information describing United States
properties and operations in the Form 40-F Annual Report of Chieftain
International, Inc. for the year ended December 31, 1996, which is attached as
Exhibit 28 hereto.
EMPLOYEES
At December 31, 1996, Funding Corp. had no employees. Management services are
provided by Chieftain International, Inc.
ITEM 2. PROPERTIES
Funding Corp. owns no physical properties. Its assets consist of investments in
and advances to Chieftain U.S., its parent company.
ITEM 3. LEGAL PROCEEDINGS
Funding Corp. is not a party to any material legal proceeding.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matters were submitted to a vote of security holders of the Company during
the fourth quarter of 1996.
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PART II
ITEM 5. MARKET FOR THE REGISTRANT'S SECURITIES AND RELATED STOCKHOLDER MATTERS
The high and low prices of the Chieftain International Funding Corp. $1.8125
Convertible Redeemable Preferred Shares (the "Preferred Shares") during each
quarter since December 31, 1994 are shown below.
Price History of Chieftain International Funding Corp. $1.8125
Convertible Redeemable Preferred Shares on the American Stock Exchange
(U.S. dollars) High Low
------------------------------------------------------
1995
First quarter 23.00 19.88
Second quarter 24.25 22.13
Third quarter 25.50 22.63
Fourth quarter 27.50 23.25
1996
First quarter 27.25 25.13
Second quarter 27.63 25.00
Third quarter 29.63 26.00
Fourth quarter 33.00 27.75
1997
January 32.50 29.38
February 31.75 27.50
March 1 to March 19 29.25 27.25
All of the Company's issued common shares are owned by its parent, Chieftain
International (U.S.) Inc. The Preferred Shares were held by 61 shareholders of
record on December 31, 1996.
The Company has made timely payment of quarterly dividends on the Preferred
Shares, amounting to $0.453125 per share, for each quarter since the shares were
issued in 1992.
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ITEM 6. SELECTED FINANCIAL DATA
The selected financial data for each of the three years in the period ended
December 31, 1996 has been derived from the financial statements of Funding
Corp. and should be read in conjunction with such financial statements and the
related notes.
Year ended December 31,
------------------------------
Chieftain International Funding Corp. 1996 1995 1994
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(US% in thousands, except shares and
per share amounts)
INCOME STATEMENT DATA:
Revenue ..................................... $ 5,826 $ 5,792 $ 5,736
General and administrative expenses ......... 46 44 44
Income before dividends on preferred shares . 5,748 5,748 5,692
Dividends on preferred shares ............... 4,942 4,942 4,942
Net income applicable to common shares ...... 806 806 750
Earnings per common share:
Net income applicable to common shares .. 4.03 4.03 3.75
Number of common shares outstanding ......... 200,000 200,000 200,000
OTHER DATA:
Cash provided from operating activities ..... $ 993 $ 617 $ 748
BALANCE SHEET DATA (at end of period):
Working capital ............................. $ 3,106 $ 2,300 $ 1,494
Total assets ................................ $ 81,610 $ 82,040 $ 80,000
Preferred shares issued ..................... $ 63,403 $ 63,403 $ 63,403
Common shareholder's equity ................. $ 18,203 $ 17,398 $ 16,592
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
Funding Corp., a special purpose subsidiary of Chieftain International (U.S.)
Inc., was formed in 1992 for the primary purpose of financing the U.S. business
operations of its parent.
ANALYSIS OF OPERATING RESULTS
Funding Corp.'s income is derived from dividends on preferred shares and
interest on short-term notes, all of which are issued by its parent company,
Chieftain International (U.S.) Inc.
Dividends received on 3,140,000 redeemable Class B preferred shares amounted to
$5,691,250 in each of the years 1996 and 1995. In addition to such dividend
income, interest of $134,272 and $100,690 in 1996 and 1995, respectively, was
earned on short-term investments.
Dividend income is expected to remain the same for 1997 while interest income is
expected to increase, reflecting the larger amount of short-term investments
held.
Dividends in the amount of $4,942,144 were paid in 1996, unchanged from 1995.
CAPITAL RESOURCES AND LIQUIDITY
Funding Corp. is dependent upon the dividend income from its investment in
preferred shares of its parent company to provide funds for payment of
dividends on its publicly-held preferred shares.
Funds provided from operations increased to $992,999 in 1996 compared with
$617,234 in 1995. Most of these funds were invested in short-term notes issued
and payable by the parent company. Cash balances at December 31, 1996 and 1995
were $80,857 and $96,248 respectively.
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The following financial statements of Chieftain International Funding Corp. are
included in Part IV of this report.
Auditors' Report
Balance Sheet as at December 31, 1996 and 1995
Statement of Income and Retained Earnings for the years ended
December 31, 1996, 1995 and 1994
Statement of Changes in Financial Position for the years ended
December 31, 1996, 1995 and 1994
Notes to Financial Statements
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
There have been no disagreements between Funding Corp. and Funding Corp.'s
auditors on accounting or financial disclosure matters.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS
The Board of Directors of the Company consists of not less than three nor more
than ten directors. The number of directors within these limits is fixed from
time to time by resolution of the Board of Directors and is currently seven.
Directors are elected annually by the common stockholder to hold office until
the close of the next ensuing annual meeting.
Information is presented below with respect to the directors of the Company.
The information includes age as of the date hereof, present position with the
Company and other business experience during the past five years. All of the
directors of the Company have served as such since the Company's formation in
November, 1992 and all are also directors of Chieftain International (U.S.)
Inc., the immediate parent of the Company and Chieftain International, Inc.,
the ultimate parent of the Company. Also presented is information with respect
to their ownership of securities of the Company and its ultimate parent, and
the ownership of such securities by the directors and executive officers as a
group. A director need not be a shareholder of the Company.
SHARES BENEFICIALLY OWNED AND PERCENT OF CLASS(1)
AS AT FEBRUARY 28, 1997
-------------------------------------------------
COMMON SHARES PREFERRED SHARES
OF OF
CHIEFTAIN INTERNATIONAL INC. CHIEFTAIN FUNDING(2)
---------------------------- --------------------
HUGH J. KELLY, 71, Director,
Corporate Director and
Energy Consultant.(3) ....... 24,333(4) -- 10,000 --
JOHN E. MAYBIN, 72, Director,
Corporate Director and
Consultant. ................. 24,333(4) -- -- --
STANLEY A. MILNER, A.O.E.,
LL.D., 68, Director,
President and Chief Executive
Officer of Chieftain
International Inc.(5) ....... 649,996(6) 4.63% 39,000 1.43%
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SHARES BENEFICIALLY OWNED AND PERCENT OF CLASS(1)
AS AT FEBRUARY 28, 1997
-------------------------------------------------
COMMON SHARES PREFERRED SHARES
OF OF
CHIEFTAIN INTERNATIONAL INC. CHIEFTAIN FUNDING(2)
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DAVID E. MITCHELL, O.C., 70
Chairman of the Board,
Chairman of Alberta
Energy Company Ltd.(7)....... 33,333(4) -- -- --
LOUIS G. MUNIN, 63, Director,
Corporate Director and
Financial Consultant.(8)..... 27,333(4) -- 2,000 --
ESTHER S. ONDRACK, 56, Director,
Senior Vice President and
Secretary of Chieftain
International, Inc.(9)........ 90,770(10) -- -- --
STUART T. PEELER, 67, Director,
Corporate Director and
Petroleum Industry
Consultant.(11).............. 26,933(12) -- 21,500 --
DIRECTORS AND EXECUTIVE
OFFICERS AS A GROUP.......... 1,075,558(13) 7.67% 77,875 2.86%
(1) Percentages of less than one are omitted.
(2) Each $1.8125 Convertible Redeemable Preferred Share of Chieftain
International Funding Corp. is convertible into 1.25 Common Shares of
Chieftain International, Inc.
(3) Mr. Kelly retired as President and Chief Executive Officer of Ocean
Drilling & Exploration Company in 1989. He is a director of Baroid
Corporation, Central Louisiana Electric Co. Inc.. Hibernia National Bank
and Tidewater Inc.
(4) Includes options, exercisable within 60 days, to purchase 23,333 shares.
(5) Mr. Milner was President and Chief Executive Officer of Chieftain
Development Co. Ltd. from the time of its incorporation in 1964 until 1988.
He is a director of Canadian Pacific Limited.
(6) Includes options, exercisable within 60 days, to purchase 90,000 shares.
(7) Mr. Mitchell retired as President and Chief Executive Officer of Alberta
Energy Company Ltd. on December 30, 1993. He is a director of Continental
Airlines, Inc. and Lafarge Corporation.
(8) Mr. Munin retired as Executive Vice President and Chief Financial Officer
of Lafarge Corporation in 1989. He is a director of Lafarge Canada Inc. and
Walden Residential Properties, Inc.
(9) Mrs. Ondrack was formerly Senior Vice President, Administration and
Secretary of Chieftain Development Co. Ltd.
(10) Includes options, exercisable within 60 days, to purchase 69,166 shares.
(11) Mr. Peeler retired as Chairman of the Board and Chief Executive Officer of
Statex Petroleum, Inc. in 1989. He is a director of Calmat Co. and
Homestake Mining Company.
(12) Includes options, exercisable within 60 days, to purchase 19,433 shares.
(13) Includes options, exercisable within 60 days, to purchase 422,763 shares.
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EXECUTIVE OFFICERS
The following table lists the name and age of each Executive Officer and all
positions and offices with the Company held by each such person. The officers
are appointed each year at the directors' meeting immediately following the
annual meeting of the shareholder. The next such meeting will be held on May 15,
1997.
NAME AGE POSITION/OFFICE
- ---- --- ---------------
S.A. Milner, A.O.E., LL.D. 68 Director, President and Chief Executive Officer
S.C. Hurley 47 Senior Vice President and Chief Operating Officer
E.L. Hahn 59 Senior Vice President, Finance and Treasurer
E.S. Ondrack 56 Director, Senior Vice President and Secretary
R.A. McDougall 61 Vice President, Land
S.J. Milner 39 Vice President, Drilling and Production
R.J. Stefure 49 Controller
With the following exceptions all of the officers have held positions as
officers of the Company since its incorporation in 1992 and each officer
presently holds and has held for more than five years positions as officers of
Chieftain International, Inc. and Chieftain International (U.S.) Inc., the
former, in each case, being his or her principal occupation. Mr. Hurley joined
Chieftain in September, 1995 prior to which time he was the Vice President
Exploration of a U.S.-based integrated oil company. S.J. Milner and R.J. Stefure
were appointed officers of the Company in June, 1995 and prior thereto held
management positions with the Company and its immediate and ultimate parents.
There are no family relationships between any executive officer, director, or
person nominated or chosen to become a director or executive officer except
between S.A. Milner and D.E. Mitchell, O.C. who are first cousins and between
S.A. Milner and S.J. Milner who are father and son.
ITEM 11. EXECUTIVE COMPENSATION
The directors and officers, including the chief executive officer, receive no
compensation in their capacities as directors and officers of Funding Corp. All
of the officers are employees of Chieftain International Inc., (sometimes herein
referred to as "Chieftain Canada") and as such they receive remuneration from
Chieftain Canada based on their positions with Chieftain Canada.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The following table shows the share ownership in the voting securities of the
Company of each person or company beneficially owning, or exercising control or
direction over, more than five per cent of the outstanding shares of the
Company.
CLASS OF NUMBER OF SHARES PERCENT OF
NAME AND ADDRESS OF BENEFICIAL OWNER SHARES BENEFICIALLY OWNED CLASS OWNED
- ------------------------------------ -------- ------------------ -----------
Chieftain International (U.S.) Inc.
1201 Toronto Dominion Tower
Edmonton Centre
Edmonton, Alberta, Canada
T5J 2Z1 Common 200,000 100%
Information with respect to shares beneficially owned in the registrant and its
ultimate parent, Chieftain International, Inc., by directors and executive
officers of the Company, is presented in Item 10, "Directors and Executive
Officers".
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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Under the terms of an informal understanding between the Company and Chieftain
Canada, Chieftain Canada provides management services as required to enable the
Company to carry on its business.
Chieftain Canada has unconditionally guaranteed certain obligations of the
Company with respect to the Preferred Shares. The Preferred Shares are
redeemable, at the option of the Company, at $26.0069 per share during 1997,
declining to $25.00 per share after December 31, 2001 plus accumulated and
unpaid dividends. Each Preferred Share has a liquidation preference of $25.00
and is convertible at any time into 1.25 common shares of Chieftain Canada at
the option of the holder. Reference is made to Exhibits 4(a), "Form of
Certificate of Designation of Preferred Stock of Funding Corp.", and 4(b),
"Form of Subordinated Guarantee Agreement of Chieftain International, Inc.".
PART IV
ITEM 14. EXHIBITS AND REPORTS ON FORM 8-K
The following is a listing of the financial statements which are included in
this Form 10-K report.
FINANCIAL STATEMENTS
Reference is made to the list of financial statements on page 6 of this report.
EXHIBITS
Reference is made to the Index to Exhibits on page 17 of this report.
REPORTS ON FORM 8-K
The registrant filed no reports on Form 8-K during the fourth quarter of the
year ended December 31, 1996.
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AUDITORS' REPORT
To the Shareholders of
Chieftain International Funding Corp.
We have audited the balance sheets of Chieftain International Funding Corp. as
at December 31, 1996 and 1995 and the statements of income and retained
earnings and changes in financial position for each of the years in the
three-year period ended December 31, 1996. These financial statements are the
responsibility of the Company's management. Our responsibility is to express an
opinion on these financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. 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.
In our opinion, these financial statements present fairly, in all material
respects, the financial position of the Company as at December 31, 1996 and
1995 and the results of its operations and the changes in its financial
position for each of the years in the three-year period ended December 31, 1996
in accordance with generally accepted accounting principles.
PRICE WATERHOUSE
Chartered Accountants
Edmonton, Alberta
February 4, 1997
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CHIEFTAIN INTERNATIONAL FUNDING CORP.
(a subsidiary of Chieftain International (U.S.) Inc.)
BALANCE SHEET
December 31, 1996 1995
- ---------------------------------------------------------------------------
(U.S.$)
ASSETS
Current assets:
Cash $ 80,857 $ 96,248
Dividend receivable -- 1,422,813
Due from affiliated companies 3,029,427 2,021,037
----------------------------------
3,110,284 3,540,098
Investment in preferred shares of
Chieftain International (U.S.) Inc.
at cost (Note 2) 78,500,000 78,500,000
----------------------------------
$81,610,284 $82,040,098
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LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities:
Accounts payable and accrued $ 4,100 $ 4,075
Dividend payable -- 1,235,536
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4,100 1,239,611
Preferred shares issued (Note 3) 63,402,903 63,402,903
Common shareholder's equity:
Share capital (Note 4)
Authorized
10,000,000 common shares,
par value $0.01 each
Issued
200,000 common shares 2,000 2,000
Additional paid in capital 14,998,000 14,998,000
Retained earnings 3,203,281 2,397,584
----------------------------------
18,203,281 17,397,584
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$81,610,284 $82,040,098
----------------------------------
APPROVED BY THE BOARD
/s/ S.A. Milner Director
- -----------------------
/s/ L.G. Munin Director
- -----------------------
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CHIEFTAIN INTERNATIONAL FUNDING CORP.
STATEMENT OF INCOME AND RETAINED EARNINGS
Year ended December 31, 1996 1995 1994
- ---------------------------------------------------------------------------------------------------
(U.S.$)
Revenue:
Dividends $ 5,691,250 $ 5,691,250 $ 5,691,250
Interest 134,272 100,690 45,172
-----------------------------------------------------------
5,825,522 5,791,940 5,736,422
General and administrative expenses 46,081 44,260 44,687
-----------------------------------------------------------
Income before income taxes and
dividends on preferred shares 5,779,441 5,747,680 5,691,735
Income taxes (Note 5) 31,600 -- --
-----------------------------------------------------------
Income before dividends on
preferred shares 5,747,841 5,747,680 5,691,735
Dividends on preferred shares (4,942,144) (4,942,144) (4,942,144)
-----------------------------------------------------------
Net income applicable to common shares 805,697 805,536 749,591
Retained earnings, beginning of period 2,397,584 1,592,048 842,457
-----------------------------------------------------------
Retained earnings, end of period $ 3,203,281 $ 2,397,584 $ 1,592,048
-----------------------------------------------------------
Net income per common share $ 4.03 $ 4.03 $ 3.75
-----------------------------------------------------------
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CHIEFTAIN INTERNATIONAL FUNDING CORP.
STATEMENT OF CHANGES IN FINANCIAL POSITION
Year ended December 31, 1996 1995 1994
- ---------------------------------------------------------------------------------------------------------
(U.S.$)
Operating activities:
Net income applicable to common shares $ 805,697 $ 805,536 $ 749,591
Change in non-cash working capital
Dividend receivable 1,422,813 (1,422,813) --
Current liabilities (1,235,511) 1,234,511 (1,600)
---------------------------------------------------------
992,999 617,234 747,991
Investing activities:
Advances to affiliated companies (1,008,390) (563,638) (713,932)
---------------------------------------------------------
Change in cash (15,391) 53,596 34,059
Cash, beginning of year 96,248 42,652 8,593
---------------------------------------------------------
Cash, end of year $ 80,857 $ 96,248 $ 42,652
---------------------------------------------------------
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CHIEFTAIN INTERNATIONAL FUNDING CORP.
NOTES TO FINANCIAL STATEMENTS
December 31, 1996, 1995 and 1994
Funding Corp., a special purpose subsidiary of Chieftain International (U.S.)
Inc., was formed in 1992 for the primary purpose of financing the U.S. business
operations of its parent. Funding Corp.'s income is derived from dividends on
preferred shares and interest on short-term notes, all of which are issued by
its parent company, Chieftain International (U.S.) Inc. The financial statements
are expressed in United States currency since the assets and operations of
Funding Corp. are denominated in United States dollars.
1. SUMMARY OF SIGNIFICANT POLICIES
ACCOUNTING POLICIES
The financial statements of Funding Corp. are prepared in conformity with
Canadian generally accepted accounting principles. The preparation of financial
statements in conformity with generally accepted accounting principles requires
management to make informed judgements and estimates in preparation of these
financial statements. Actual results may differ from those estimates. Material
differences between Canadian principles and those of the U.S. which affect
Funding Corp. are specifically referred to in these Notes to Financial
Statements.
INCOME TAXES
Funding Corp. and its parent file corporate income tax returns on a consolidated
basis. As a result, income taxes payable have been offset by the parent
company's tax losses and are reflected in the amount due from the parent
company.
Funding Corp. follows the tax allocation method of accounting for the tax effect
of all timing differences between taxable income and accounting income.
United States accounting principles require corporations to account for
deferred income taxes using the liability method. The effect on the Company of
the application of such method is not material.
2. INVESTMENT IN PREFERRED SHARES OF PARENT
On November 6, 1992, Funding Corp. purchased 2,840,000 $1.8125 Redeemable Class
B Preferred Shares at $25.00 per share of Chieftain International (U.S.) Inc.,
its parent company. Subsequent to that date, Funding Corp. purchased an
additional 300,000 of such shares to hold a total of 3,140,000 shares. The
shares pay quarterly dividends at the annual rate of $1.8125 per share. The
shares are redeemable at the option of the issuer at $26.0069 during 1997
declining to $25.00 during 2002 and thereafter.
3. PREFERRED SHARES
The Articles of Funding Corp. authorize the issue of a maximum of 10,000,000
preferred shares with a par value $1.00 each.
On November 6, 1992, Funding Corp. sold 2,400,000 shares of $1.8125 convertible
redeemable preferred stock at $25.00 per share through an underwritten public
offering in the United States. On December 2, 1992, Funding Corp. sold an
additional 326,700 preferred shares pursuant to an over-allotment option
granted to the underwriters, resulting in a total issuance of 2,726,700 shares.
Proceeds of the issuance of preferred shares, net of offering costs of $4.7
million, were $63.4 million. The preferred shares are redeemable, at the option
of Funding Corp., at $26.0069 per share during 1997, declining to $25.00 per
share after
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December 31, 2001 plus accumulated and unpaid dividends. Each preferred share
has a liquidation preference of $25.00 and is convertible at any time at the
option of the holder into 1.25 common shares of Chieftain International, Inc.
(the ultimate parent company). Chieftain International, Inc. has guaranteed
certain obligations of Funding Corp. with respect to the preferred shares.
Canadian generally accepted accounting principles require the disclosure of the
fair value of a financial instrument of this nature and define the fair value as
the amount at which the instrument could be exchanged in a current transaction
between willing parties. The estimated fair value of Funding Corp.'s preferred
shares at December 31, 1996 is $88,617,750, which is the market value of the
securities into which these shares are convertible, and $68,849,175 at December
31, 1995 which is the market value of these preferred shares.
4. SHARE CAPITAL
On August 28, 1992, Funding Corp. issued 100,000 common shares, par value $0.01
each, for net cash proceeds of $1,000 and, on November 5, 1992 issued 100,000
common shares, par value $0.01 each, to its parent for net cash proceeds of
$14,999,000.
5. INCOME TAXES
The actual tax rate differed from the expected tax rate for the following
reason:
Year ended December 31, 1996 1995 1994
---------------------------------------------------------------------------------------------------------------
Expected percentage 35.8% 35.5% 35.5%
Deduct the effect of dividends from the parent received by
the company on a "tax-free" basis 35.3 35.5 35.5
---------------------------------------
Actual percentage of income tax expense on pre-tax income 0.5% 0.0% 0.0%
---------------------------------------
6. TRANSACTIONS WITH AFFILIATES
All dividend and interest income of Funding Corp. is received from Chieftain
International (U.S.) Inc. Certain administrative services are provided to
Funding Corp. by Chieftain International, Inc.
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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 to be signed on its
behalf by the undersigned, thereunto duly authorized.
CHIEFTAIN INTERNATIONAL FUNDING CORP.
by: /s/ STANLEY A. MILNER by: /s/ EDWARD L. HAHN
-------------------------------- ------------------------------
Stanley A. Milner, A.O.E., LL.D. Edward L. Hahn
President and Senior Vice President, Finance
Chief Executive Officer and Treasurer
Dated: March 20, 1997
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
registrant and in the capacities and on the date indicated.
/s/ D.E. MITCHELL Chairman of the Board and March 20, 1997
- ------------------------------- Director
D.E. Mitchell, O.C.
/s/ S.A. MILNER President, Chief Executive March 20, 1997
- ------------------------------- Officer and Director
S.A. Milner, A.O.E., LL.D.
/s/ H.J. KELLY Director March 20, 1997
- -------------------------------
H.J. Kelly
/s/ J.E. MAYBIN Director March 20, 1997
- -------------------------------
J.E. Maybin
/s/ L.G. MUNIN Director March 20, 1997
- -------------------------------
L.G. Munin
/s/ E.S. ONDRACK Director March 20, 1997
- -------------------------------
E.S. Ondrack
/s/ S.T. PEELER Director March 20, 1997
- -------------------------------
S.T. Peeler
/s/ E.L. HAHN Senior Vice President, March 20, 1997
- ------------------------------- Finance and Treasurer
E.L. Hahn
/s/ R.J. STEFURE Controller March 20, 1997
- -------------------------------
R.J. Stefure
16
17
Index to Exhibits
Exhibit
Number Exhibit
- -------- -------
**3(e) Articles of Incorporation of Funding Corp.
**3(f) Amended Articles of Incorporation of Funding Corp.
**3(g) Bylaws of Funding Corp.
**4(a) Form of Certificate of Designation of Preferred Stock of Funding Corp.
**4(b) Form of Subordinated Guarantee Agreement of Chieftain International, Inc.
****28 Form 40-F of Chieftain International, Inc. for the year ended December 31, 1996.
** Previously filed as an exhibit to the Registration Statement of the
registrant on Form S-1/S-3, File No. 33-51630.
**** Filed herewith.
17
18
EXHIBIT 28
19
Page 1 of 37
FORM 40-F
U.S. SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
/ / REGISTRATION STATEMENT PURSUANT TO SECTION 12 OF THE SECURITIES
EXCHANGE ACT OF 1934
OR
/x/ ANNUAL REPORT PURSUANT TO SECTION 13(a) OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 1996
Commission File number 1-10216:
- -------------------------------
CHIEFTAIN INTERNATIONAL INC.
-----------------------------------------------------
(Exact name of Registrant as specified in its charter)
ALBERTA, CANADA NOT APPLICABLE
- ----------------------------------------------------------------- ------------------------------------
(Province or other jurisdiction of incorporation or organization) (I.R.S. Employer Identification No.)
1311
--------------------------------------------------------
(Primary Standard Industrial Classification Code Number)
1201 TORONTO DOMINION TOWER, EDMONTON CENTRE,
EDMONTON, ALBERTA, CANADA T5J 2Z1 Telephone (403) 425-1950
---------------------------------------------------------------------------------------
(Address (including zip code) and telephone number (including area code) of Registrant)
-----------------------
JOHN L. ROACH, INC., 4150 LINCOLN PLAZA, 500 NORTH AKARD,
DALLAS, TEXAS 75021 TELEPHONE (214) 922-9850
- -------------------------------------------------------------------------------------------------------------------------
(Name, address (including zip code) and telephone number (including area code) of agent for service in the United States)
SECURITIES REGISTERED OR TO BE REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
Title of each class Name of each exchange on which registered
- ------------------- -----------------------------------------
Common Shares, no par value American Stock Exchange. The Toronto Stock Exchange.
The Alberta Stock Exchange
Securities registered pursuant to Section 12(g) of the Act: None
Securities for which there is a reporting obligation pursuant to Section 15(d)
of the Act: None
For annual reports, indicate by check mark the information filed with this
Form:
/x/ Annual information form /x/ Audited annual financial statements
The number of shares outstanding of the Registrant's common stock as of
December 31, 1996 was 13,591,763.
Indicate by check mark whether the Registrant by filing the information
contained in this Form is also thereby furnishing the information to the
Commission pursuant to Rule 12g3-2(b) under the Securities Exchange Act of 1934
(the "Exchange Act"). If "Yes" is marked, indicate the file number assigned to
the Registrant in connection with such Rule.
Yes 82- No x
------ ----- -----
Indicate by check mark whether the Registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Exchange Act during the
preceding 12 months (or for such shorter period that the Registrant was required
to file such reports) and (2) has been subject to such filing requirements for
the past 90 days.
Yes x No
------ -----
20
Page 2 of 37
FORM 40-F TABLE OF CONTENTS
Form 40-F
Sequential
Page No.
----------
1. Annual Information Form of Chieftain International, Inc. dated March 20, 1997
including Management's Discussion and Analysis of Financial Condition and
Results of Operations for 1996. See Exhibit A .............................. 3
2. Consolidated Financial Statements for the fiscal years ended December 31, 1996
and 1995, including Management's Report, Auditors' Report and Notes to
Consolidated Financial Statements including U.S. GAAP reconciliation ....... 18
3. Consent of Independent Accountants ........................................... 29
4. Consent of Independent Engineers ............................................. 30
5. Undertaking .................................................................. 31
6. Signatures ................................................................... 31
Exhibit A. Management's Discussion and Analysis of Financial Condition and
Results of Operations ................................................. 32
21
Page 3 of 37
[CHIEFTAIN LOGO]
ANNUAL INFORMATION FORM
MARCH 20, 1997
22
Page 4 of 37
TABLE OF CONTENTS
Page
----
Glossary ................................................................................... 3
Currency Exchange Rates .................................................................... 4
Incorporation .............................................................................. 4
Corporate Structure ........................................................................ 4
Business and Property ...................................................................... 5
Selected Consolidated Financial and Operating Data ......................................... 14
Summary of Quarterly Financial Information ................................................. 15
Management's Discussion and Analysis of Financial Condition and Results of Operations ...... 15
Directors and Officers ..................................................................... 16
Dividend Policy ............................................................................ 17
Market for Securities ...................................................................... 17
Additional Information ..................................................................... 17
2
23
Page 5 of 37
GLOSSARY
THE FOLLOWING ARE DEFINED TERMS USED HEREIN:
barrel (bbl) means 34.972 Imperial gallons or 42 U.S. gallons.
bcf means 1,000,000,000 cubic feet.
bcfe means 1,000,000,000 cubic feet of gas equivalent.
bpd means barrels per day.
developed acreage refers to the number of acres assignable to productive wells.
development wells are wells drilled within the proved area of a gas or oil
reservoir to the depth of a stratigraphic horizon known to be productive.
dry wells means wells found to be incapable of producing either gas or oil in
sufficient quantities to justify completion as gas or oil wells.
exploratory wells are wells drilled to find and produce gas or oil in an
unproved area, to find a new reservoir in a field previously found to be
productive of gas or oil in another reservoir, or to extend a known reservoir.
gas means natural gas. Natural gas reserves are reported at a base pressure of
14.65 psia and a base temperature of 60 degrees Fahrenheit.
gas equivalent is determined by using the approximate energy equivalent ratio
of 6 mcf of gas to 1 bbl of oil and liquids.
gross acres means the total number of acres in which an interest is owned by
Chieftain.
gross wells means the total number of wells in which an interest is owned by
Chieftain.
liquids means natural gas liquids.
mbbls means 1,000 barrels.
mcf means 1,000 cubic feet.
mcf/d means 1,000 cubic feet per day.
mmcf means 1,000,000 cubic feet.
mmcf/d means 1,000,000 cubic feet per day.
mmcfe means 1,000,000 cubic feet of gas equivalent.
net acres refers to the sum of the fractional interests owned in gross acres.
net wells refers to the sum of the fractional interests owned in gross wells.
ngls means natural gas liquids.
non-producing wells are wells which are capable of, but are not, producing.
oil or oil and liquids means crude oil and natural gas liquids.
probable reserves are those reserves which geological and engineering data
demonstrate to be potentially recoverable, but where some element of risk or
insufficient data prevent classification as proved.
proved developed producing reserves are those reserves which are expected to
be produced from existing completion intervals now open for production in
existing wells.
proved developed non-producing reserves are (1) those reserves expected to be
produced from existing completion intervals in existing wells, but due to
pending pipeline connections or other mechanical or contractual requirements
hydrocarbon sales have not yet commenced, and (2) other non-producing reserves
which exist behind the casing of existing wells, or at minor depths below the
present bottom of such wells, which are expected to be produced through these
wells in the predictable future, where the cost of making such oil and gas
available for production should be relatively small compared to the cost of a
new well.
proved reserves are the estimated quantities of natural gas, crude oil and
natural gas liquids which geological and engineering data demonstrate with
reasonable certainty to be recoverable in future years from known reservoirs
under existing economic and operating conditions. Proved reserves are limited to
those quantities of gas and oil which can be expected, with little doubt, to be
recoverable commercially at current prices and costs under existing regulatory
practices and with existing conventional equipment and operating methods.
proved undeveloped reserves are those reserves which are expected to be
recovered from new wells on undrilled acreage or from existing wells where a
relatively major expenditure is required for recompletion. Proved reserves on
undrilled acreage are limited to those drilling units offsetting productive
units that are reasonably certain of production when drilled.
undeveloped acreage is acreage on which wells have not been drilled or completed
to a point that would permit the production of commercial quantities of gas and
oil regardless of whether or not such acreage contains proved reserves.
working interest refers to the net interest held by Chieftain in an oil or gas
lease or other disposition which interest bears its proportionate share of the
costs of exploration, development and operations and any royalties or other
production burdens.
3
24
Page 6 of 37
CURRENCY EXCHANGE RATES
Chieftain's accounts are maintained in United States dollars. All dollar amounts
herein are stated in United States dollars except where otherwise indicated.
The following table sets forth the rates of exchange for Canadian dollars per
U.S.$1.00 in effect at the end of the following periods and the average rates
of exchange during such periods, based on the Bank of Canada average noon spot
rate of exchange.
Year 1996 1995 1994
---------------------------------------------------------------------------------------------------------------
Rate at end of year.............................................. $1.3696 $1.3640 $1.4028
Average rate for the year........................................ $1.3636 $1.3726 $1.3659
On March 19, 1997, the Bank of Canada noon spot rate of exchange was U.S.$1.00
= Cdn.$1.3785.
INCORPORATION
Incorporated under the Business Corporations Act (Alberta), Chieftain
International, Inc. (the "Company" and together with its subsidiaries
"Chieftain") commenced operations in April, 1989 upon completion of its initial
public offering.
The head and principal office of the Company is located at 1201 Toronto
Dominion Tower, Edmonton Centre, 10205 - 101 Street, Edmonton, Alberta, Canada,
T5J 2Z1 (Telephone: 403-425-1950).
Chieftain conducts its business directly and through wholly owned subsidiaries
as described below.
CORPORATE STRUCTURE
The following is the corporate structure of Chieftain International, Inc. and
its subsidiaries and their jurisdictions of incorporation.
[FIGURE 1]
Each of the subsidiaries is 100% owned by its parent except for (i) Chieftain
International (U.S.) Inc. which is owned as to 100% of its issued common stock
and Series A Preferred stock by the Company and as to 100% of its issued Series
B Preferred stock by Chieftain International Funding Corp. and (ii) Chieftain
International Funding Corp. which is owned as to 100% of its issued common
stock by Chieftain International (U.S.) Inc. and as to 100% of its issued
$1.8125 Convertible Redeemable Preferred stock by the public.
4
25
Page 7 of 37
BUSINESS AND PROPERTY
BUSINESS
Chieftain is engaged in gas and oil exploration and production, primarily in
the United States and also in the U.K. sector of the North Sea. In addition,
Chieftain is participating in an exploration venture in Libya.
In the United States, Chieftain's principal producing properties are located in
the U.S. federal waters of the Gulf of Mexico and in southeast Utah. Chieftain
has interests in exploration acreage in the Gulf of Mexico region, primarily
offshore and also in Texas. Minor interests are held onshore in other areas of
the United States.
PRINCIPAL PROPERTIES
Chieftain's principal gas producing properties are located in U.S. federal
waters in the Gulf of Mexico and in the U.K. sector of the North Sea. Its
principal oil producing properties are located in the Four Corners area of
southeast Utah.
UNITED STATES GULF OF MEXICO AREA -- OFFSHORE
Chieftain concentrates its exploration and development activities in, and
devotes substantial managerial and financial resources to, the offshore Gulf of
Mexico area which accounted for most of Chieftain's gas production in 1996.
Activity in this area during 1996 was primarily devoted to developing reserves
and increasing production. Thirteen exploratory wells were drilled, of which 6
were successful, and 13 development wells were drilled, of which 11 were
successful.
Substantial additions were made to Chieftain's acreage position in
the Gulf of Mexico during 1996. Interests in 35 federal leases and five state
leases were acquired at competitive sales and interests in two blocks were
acquired through joint venture operations. Holdings in the offshore Gulf of
Mexico amounted to 606,581 gross (211,388 net) acres at year-end compared to
476,896 gross (134,968 net) acres at December 31, 1995. Ongoing acquisition of
3-D seismic data will continue to guide the Company's exploration efforts.
WESTERN GULF
MATAGORDA ISLAND. Chieftain has working interests averaging 35% in eight blocks
covering 45,000 gross acres. Gas fields on Blocks 604 and 589 have been major
sources of production since 1989. Ten productive gas wells on these blocks,
connected to a production facility on Block 604, accounted for average 1996
production of 9.7 mmcf/d, net of royalties. A redevelopment program has
commenced with a successful exploratory well, on Block 589, drilled into a
fault block separate from the main producing area. This well commenced
production in the fourth quarter of 1996 at a rate, net to Chieftain, of 4.1
mmcf/d. Additional prospects along this trend, which extends into Block 604,
have been identified and are being evaluated for drilling in 1997. Chieftain
also has working interests of approximately 25% in producing acreage on Blocks
633/634 and 704/709. Chieftain's share of production from six wells on these
blocks aggregated approximately 6.3 mmcf/d, net of royalties, during 1996. A
horizontal drilling program on Blocks 633/634 resulted in two successful wells
which commenced production subsequent to year-end at 4.3 mmcf/d net to
Chieftain. Exploratory drilling is planned for Blocks 604,633,634,666,673 and
704 during 1997.
MUSTANG ISLAND. Chieftain has working interests averaging 39% in five blocks
covering 28,350 gross acres. A well on Block 785, in which Chieftain has a 27.5%
working interest, was successfully recompleted. Exploratory prospects have been
identified utilizing 3-D seismic data on Blocks 783 and 784, in which Chieftain
has 50% working interests, and drilling is proposed for 1997. Chieftain's gas
production from its Mustang Island interests averaged 6.0 mmcf/d, net of
royalties, in 1996.
5
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Page 8 of 37
HIGH ISLAND. Chieftain increased its interest to 50% and participated in
drilling two successful gas wells on Block 207. One of the wells commenced
production during the fourth quarter. The other well was drilled into a
separate prospect where further delineation drilling is planned. On Block 134,
Chieftain increased its interest from 12.5% to 50% and drilled a successful gas
well from which production commenced in September. Production from the High
Island area averaged 6.3 mmcf/d and 105 bpd of oil and ngls, net of royalties.
In Texas state waters, Chieftain participated with a 50% interest in the
acquisition of five leases covering 3,700 gross acres.
HIGH ISLAND SOUTH ADDITION. Seven exploratory leases covering 40,320 gross
acres were acquired during 1996. Chieftain plans to participate with a 50%
interest in exploratory wells on Blocks A-510, A-526, A-527, A-541, A-566 and
A-567 during 1997.
CENTRAL GULF
WEST CAMERON. Two successful gas wells, in which Chieftain participated with
a 25% interest, were drilled on Blocks 192 and 193 during 1996. Exploratory
drilling is planned for Block 300 in which Chieftain has a 60% interest.
EAST CAMERON. Chieftain holds interests averaging 30% in 12 blocks covering
54,000 gross acres in this area, including Blocks 349,350 and 356, where
significant oil and gas discoveries have been made. A successful 1996 well
established additional reserves on Blocks 349 and 356. A production platform is
scheduled to be installed during the second quarter of 1997 and production is
expected to commence in the third quarter. Three-D seismic data has been
acquired and is being used to evaluate other blocks in which Chieftain has
interests in the area. Exploratory wells are planned for Blocks 329 and 355 in
which Chieftain has interests of 33% and 25%, respectively.
VERMILION. A successful gas well was drilled on Block 23, in which Chieftain has
a 25% interest. A second successful well was drilling at year-end and
production is scheduled to commence from this block in 1997.
SOUTH MARSH ISLAND. Chieftain has interests ranging from 18.75% to 50% in three
blocks covering 13,000 gross acres and will participate with a 50% interest in
an exploratory well on Block 39.
EUGENE ISLAND. Exploratory drilling has been proposed for Block 189 in which
Chieftain has a 75% working interest. An additional exploratory location has
been proposed on Block 85 where Chieftain has a 25% interest.
GRAND ISLE. An exploratory well is planned for the first quarter of 1997 on
Chieftain-operated Block 77 in which a 50% working interest is held.
SOUTH PASS. Chieftain operates and has a 44.4% working interest in 2,500 gross
acres in the south half of Block 37 on which there are currently 8 producing
wells. Three wells, in which Chieftain's interests range from 61.5% to 72.2%,
were drilled in 1995 and commenced production in 1996. Chieftain's share of
1996 production from the south half averaged 184 bpd and 1.4 mmcf/d, net of
royalties. In the north half of the block, on which 6 producing wells are
located. Chieftain's share of 1996 production averaged 0.5 mmcf/d and 66 bpd,
net of royalties.
EASTERN GULF
MOBILE BAY/VIOSCA KNOLL. Chieftain has interests averaging 35% in 13 offshore
blocks, 8 of which were producing at year-end. A production platform was
installed on Viosca Knoll Block 124, in which Chieftain has a 25% interest, and
production is expected to commence in early 1997. Pipeline facilities are
planned to connect Viosca Knoll Blocks 213 and 256 and an exploratory well is
planned for Block 301, to the south of Block 124. Proposals are under discussion
for the drilling of a well to test a deep Norphlet prospect on Mobile Bay Blocks
913/914 in which Chieftain holds interests of 50% and 25%, respectively
6
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Page 9 of 37
MAIN PASS. Chieftain has an average interest of 15.6% in a total of 14 blocks
in the Main Pass area, covering 58,000 gross acres. In 1996, 6 wells were
drilled, production facilities were installed and production commenced from
production units located on Blocks 225 and 223. The processing facilities have
total capacity of 200 mmcf/d. Chieftain has a 7% interest in the Block 225
production unit which includes portions of Blocks 224, 248 and 249. The unit
began producing in March, 1996, averaging 5.5 mmcf/d of gas and 66 bpd of ngls
(net of royalties) in the fourth quarter of 1996, net to Chieftain. Production
commenced in August, 1996 from the Block 223 area which includes Block 222.
Chieftain has a 10% interest in these blocks, which produced 2.4 mmcf/d of gas
and 56 bpd of ngls, net of royalties, to Chieftain's interest in the fourth
quarter of 1996. During 1996, Chieftain participated with an interest of 20% in
a gas discovery on Block 217 and 10% in a gas discovery outside of the
production unit on Block 225. Production is expected to commence from these
discoveries in 1998. Further exploratory drilling is planned for Block 225,
Block 213 where Chieftain has a 20% interest and the southern half of Block 250
where Chieftain's interest is 7.5%.
MISSISSIPPI CANYON. Chieftain has a 33% interest in Blocks 29, 30 and 74 which
cover 17,280 gross acres in the deep water "Flex" trend. A 3-D seismic
evaluation is planned for 1997.
UNITED STATES GULF OF MEXICO AREA - ONSHORE
In Texas, Chieftain holds a 25% interest in 13,357 gross acres in Kenedy
County where exploratory drilling is scheduled for 1997.
ANETH/RATHERFORD AREA, UTAH
In the Four Corners area of southeast Utah, Chieftain has interests of 13.4%
and 21.4%, respectively, in the 18,000 gross acre Aneth and the 13,000 gross
acre Ratherford oil production units. During 1996, 17 multilateral horizontal
oil wells were drilled from existing vertical wellbores in the Aneth Unit and
five were drilled in the Ratherford Unit. These are long-life light oil fields
which have been producing, using waterflood techniques, for many years. At
year-end, there were 167 producing wells (22.3 net to Chieftain) in the Aneth
Unit and 111 producing wells (23.7 net to Chieftain) in the Ratherford Unit.
Chieftain's share of production from Aneth and Ratherford averaged 1,468 bpd,
net of royalties, during 1996.
NORTH SEA
Chieftain has interests averaging 17.2% in 74,000 acres in the British sector,
of which 46,553 gross (8,270 net) acres are in the Galahad/Mordred area.
Chieftain's interests in the Galahad and Mordred gas fields, which are located
on Blocks 48/12a and 48/13b, are 17.8% and 5.3%, respectively. The Galahad
Field has been producing since November, 1995, and in 1996 a well was drilled
from the Galahad Platform into the Mordred structure to the south. Mordred
production commenced in the fourth quarter of 1996. Production from both fields
is processed through the Galahad Platform which has a capacity of 120 mmcf/d.
Chieftain's combined share of production from the two fields averaged 9 mmcf/d
during 1996 and increased to an average of 12.6 mmcf/d during the fourth
quarter. Interruptions in production, related to the drilling of the Mordred
well and to the modification of computerized production control equipment,
coincided with a period of weak gas prices in the British sector of the North
Sea. The price received by Chieftain averaged US$0.86 per mcf during the first
half of 1996 and increased to US$1.90 in December, 1996. North of Galahad, a
3-D seismic program has confirmed an exploration project which is being
considered for future drilling.
Farther north in the U.K. sector, on the southern flank of the Forties High, a
3-D seismic program is scheduled for the spring of 1997 over Blocks 21/14a and
21/14b in which Chieftain has interests of 10% and 22.5% respectively. The
Company's current North Sea production is not subject to royalties.
7
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Page 10 of 37
LIBYA
Chieftain is participating in the exploration of concessions covering 3.9
million gross acres in the eastern portion of Libya's Sirte Basin. The project
is led by Fina Exploration Libya B.V., a wholly-owned subsidiary of Petrofina
S.A. of Belgium. Under the terms of the joint venture agreement, Chieftain will
earn a 7.5% interest in the acreage. The program commitment requires 8,500
kilometers of seismic and 12 exploratory wells. Drilling commenced in mid-1993.
The seismic commitment has essentially been met and 10 exploratory wells and
one appraisal well have been drilled.
During 1996, evaluation continued on Block 5, the "U-Block" of Concession 171,
which is within five miles of the prolific Intisar oil fields. Additional
seismic data has been integrated into an evaluation of the discovery area.
Three of the five wells drilled on this block were tested at gross rates
ranging from 2,200 to 2,800 bpd. These discoveries are within six miles of
export pipeline facilities. No further drilling was carried out during 1996.
The operator is preparing an application for a long-term production test of
three of the wells. Commencement of this production may occur in the fourth
quarter of 1997. Chieftain has not booked any reserves for Libya.
ACREAGE
The following table summarizes the developed and undeveloped acreage held by
Chieftain as at December 31, 1996. Where applicable, interests which are not
working interests (none of which is material) have been converted to working
interest equivalents.
Developed Acres Undeveloped Acres
Area Gross Net Gross Net
-------------------------------------------------------------------------------------------------------
United States
Offshore Gulf of Mexico
Louisiana................................. 20,471 6,357 294,709 92,888
Texas..................................... 13,134 3,665 273,095 106,508
Texas State............................... 300 22 4,872 1,948
--------------------------------------------------------
Total Offshore Gulf of Mexico............... 33,905 10,044 572,676 201,344
--------------------------------------------------------
Onshore
Louisiana................................. 573 72 58 6
Mississippi............................... -- -- 357 11
Montana................................... -- -- 3,240 3,240
North Dakota.............................. 997 227 3,345 188
Pennsylvania.............................. 324 36 --
Texas..................................... -- -- 13,357 3,339
Utah...................................... 29,860 4,895 5,173 1,136
--------------------------------------------------------
Total Onshore 31,754 5,230 25,530 7,920
--------------------------------------------------------
Total United States.......................... 65,659 15,274 598,206 209,264
--------------------------------------------------------
United Kingdom
North Sea.................................. 5,003 889 68,990 11,842
--------------------------------------------------------
Libya
Sirte Basin................................ -- -- 3,888,550 291,641
--------------------------------------------------------
Total, all areas............................. 70,662 16,163 4,555,746 512,747
--------------------------------------------------------
Chieftain's developed and undeveloped acreage in all areas covered 4,626,408
gross (528,910 net) acres at December 31, 1996.
The undeveloped acreage has not been independently evaluated. The cost to
Chieftain thereof is approximately $33 million.
8
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Page 11 of 37
GAS AND OIL CAPITAL EXPENDITURES
The following table summarizes Chieftain's net capital expenditures for the
years ended December 31, 1996 and 1995.
Year ended December 31, 1996 1995
- --------------------------------------------------------------------------------
(US$ in thousands)
Property acquisition costs:
United States ..................................... $13,954 $ 2,873
United Kingdom .................................... 722 842
Other foreign ..................................... 68 87
------------------------
14,744 3,802
------------------------
Purchase of producing properties:
United States ..................................... 2,077 54,678
------------------------
Sale of producing properties:
United States ..................................... (1,040) (21)
------------------------
Exploration costs:
United States ..................................... 17,453 13,837
United Kingdom .................................... -- 2
Other foreign ..................................... 434 2,255
------------------------
17,887 16,094
------------------------
Development costs:
United States ..................................... 22,131 15,206
United Kingdom .................................... 1,874 10,743
------------------------
24,005 25,949
------------------------
$57,673 $100,502
------------------------
DRILLING ACTIVITY
The following table summarizes the results of Chieftain's drilling activities
during the years ended December 31, 1996 and 1995.
EXPLORATORY WELLS -- Year ended December 31, 1996 1995
GROSS NET Gross Net
- ------------------------------------------------------------------------------------------------------------
Gas ................................................. 6 1.47 6 0.83
Oil ................................................. -- -- 1 0.08
Oil/Gas ............................................. 1 0.25 3 1.95
Evaluating .......................................... -- -- -- --
Drilling at end of year ............................. -- -- 1 0.25
Abandoned ........................................... 8 2.26 14 3.04
----------------------------------------------------
15 3.98 25 6.15
----------------------------------------------------
DEVELOPMENT WELLS -- Year ended December 31, 1996 1995
GROSS NET Gross Net
- ------------------------------------------------------------------------------------------------------------
Gas ................................................. 8 2.00 2 0.58
Oil ................................................. 20 3.00 19 3.20
Oil/Gas ............................................. -- -- -- --
Evaluating .......................................... -- -- -- --
Drilling at end of year ............................. 5 0.80 3 0.40
Abandoned ........................................... 2 0.67 1 0.35
----------------------------------------------------
35 6.47 25 4.53
----------------------------------------------------
9
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Page 12 of 37
WELLS
Chieftain's gas and oil wells as at December 31, 1996 are listed in the
following table. Any interests which are not working interests (none of which
is material) have been converted to working interest equivalents.
Gas Wells Oil Wells
Producing Non-producing Producing Non-producing
Gross Net Gross Net Gross Net Gross Net
---------------------------------------------------------------------------------------------------------------------
North Dakota............... -- -- -- -- 2 0.47 -- --
Pennsylvania............... 5 0.93 -- -- -- -- -- --
Utah....................... -- -- -- -- 278 46.05 -- --
Louisiana.................. 1 0.13 -- -- -- -- -- --
U.S. Gulf of Mexico........ 84 19.81 -- -- 15 4.27 -- --
United Kingdom............. 3 0.41 -- -- -- -- -- --
---------------------------------------------------------------------------------------
93 21.28 -- -- 295 50.79 -- --
---------------------------------------------------------------------------------------
In addition, Chieftain has interests in three (0.23 net) suspended oil wells and
one appraisal well in Libya where the feasibility of development is being
evaluated.
RESERVES
GAS AND OIL RESERVES as at December 31, 1996 Natural Gas (bcf) Oil and ngls (mbbls)
Before After Before After
Royalties Royalties Royalties Royalties
--------------------------------------------------------------------------------------------------------------------
Proved reserves:
Developed producing -- U.S..................... 53.4 43.0 9,175.9 8,138.0
Developed producing -- U.K..................... 23.4 23.4 50.6 50.6
Developed non-producing -- U.S................. 25.2 20.6 255.4 207.8
Undeveloped -- U.S............................. 48.6 39.8 1,087.5 907.1
------------------------------------------------------------------
Total proved reserves............................ 150.6 126.8 10,569.4 9,303.5
------------------------------------------------------------------
Probable reserves -- U.S......................... 32.3 26.3 2,830.7 2,448.9
-- U.K......................... 3.1 3.1 6.5 6.5
------------------------------------------------------------------
Total probable reserves.......................... 35.4 29.4 2,837.2 2,455.4
------------------------------------------------------------------
Total proved and probable reserves............... 186.0 156.2 13,406.6 11,758.9
------------------------------------------------------------------
10
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Page 13 of 37
RESERVES RECONCILIATION
The following table's provides a summary of the changes in proved and probable
reserves which occurred in 1996.
Natural Gas (bcf) Oil and Ngls (mbbls)
PROVED RESERVES Before Royalties After Royalties Before Royalties After Royalties
- -----------------------------------------------------------------------------------------------------------------------------------
December 31, 1995 .............................. 149.9 126.7 9,602.3 8,451.5
Revision of previous estimates ................. (2.6) (2.6) 752.6 664.0
Purchases of producing properties .............. 6.5 5.2 21.2 17.4
Sale of producing properties ................... (0.4) (0.3) (24.2) (18.2)
Extensions, discoveries and other additions .... 23.5 19.7 1,074.3 922.5
Production ..................................... (26.3) (21.9) (856.8) (733.7)
---------------------------------------------------------------------------------
DECEMBER 31, 1996 .............................. 150.6 126.8 10,569.4 9,303.5
---------------------------------------------------------------------------------
Natural Gas (bcf) Oil and Ngls (mbbls)
PROBABLE RESERVES Before Royalties After Royalties Before Royalties After Royalties
- -----------------------------------------------------------------------------------------------------------------------------------
December 31, 1995 .............................. 43.2 36.8 1,006.6 836.1
Revision of previous estimates ................. (16.0) (14.3) 1,431.0 1,284.1
Purchases of producing properties .............. -- -- -- --
Sale of producing properties ................... (0.4) (0.3) (23.8) (17.8)
Extensions, discoveries and other additions .... 8.6 7.2 423.4 353.0
Production ..................................... -- -- -- --
---------------------------------------------------------------------------------
DECEMBER 31, 1996 .............................. 35.4 29.4 2,837.2 2,455.4
---------------------------------------------------------------------------------
PRODUCTION
Chieftain's net production of gas and oil (computed after royalty deductions
but before production taxes) for the years ended December 31, 1996 and 1995 is
listed below. Also listed are average sales prices and average production costs
during such periods.
Year ended December 31, 1996 1995
- ------------------------------------------------------------------------
Total Net Production:
Gas (mmcf) ................................ 21,894.1 10,753.7
Oil and liquids (mbbls) ................... 733.7 599.6
Gas and equivalent (mmcfe) ................ 26,296.3 14,351.3
Average Daily Net Production:
Gas (mmcf) ................................ 59.8 29.5
Oil and liquids (bbls)* ................... 2,005 1,643
Gas equivalent (mmcfe) .................... 71.8 39.3
Average Sales Price:
Gas (per mcf) ............................. $ 2.09 $ 1.54
Oil and liquids (per bbl) ................. $20.99 $16.94
Average Production Cost:
Gas (per mcf) ............................. $ 0.25 $ 0.35
Oil and liquids (per bbl) ................. $ 6.57 $ 7.31
* Oil comprised approximately 87% of the oil and liquids production over the
periods shown.
11
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Page 14 of 37
MARKETING
Most of Chieftain's gas reserves are located in the Gulf of Mexico area of the
United States, where ready deliverability of gas through numerous large
capacity pipelines and auxiliary feeder pipelines provides flexibility in
marketing Chieftain's gas reserves in the U.S. spot market. Gas prices in the
U.S. and in the U.K. North Sea are largely determined by competitive market
forces.
Most of the gas produced by Chieftain has been marketed since 1989 by Highland
Energy Company, an aggregator for several U.S. gas producers, at prices based
on spot market prices. Highland Energy Company has also represented Chieftain
in relation to the marketing of Chieftain's U.K. gas production.
Oil is produced by Chieftain primarily from the Aneth and Ratherford Units in
the Four Corners area of Utah. The quantity and quality of the oil produced has
allowed Chieftain to enter into sales contracts, based on locally posted
prices, under which a premium over such prices is received. Since 1989, all
such oil has been sold under successive term contracts to a regional refiner.
Most of Chieftain's Gulf of Mexico oil and ngls production is marketed by
Highland Energy Company.
Chieftain believes that alternative marketing arrangements would be readily
available for its gas, oil and liquids although no assurance can be given that
any alternative would not be less advantageous to Chieftain.
COMPETITION
There is competition in all aspects of the gas and oil industry, particularly
with respect to the marketing and sale of natural gas in the North American
market. There is also competition for desirable exploratory, development and
acquisition prospects and for investment capital. Chieftain's competitors
include the major integrated oil companies as well as numerous independent gas
and oil companies, integrated gas production and transmission companies and
other producers and marketers of energy sources and fuels.
ENVIRONMENTAL REGULATION
Various laws and regulations covering the discharge of materials into the
environment, or otherwise relating to the protection of the environment, may
affect Chieftain's operations and costs. At present, Chieftain believes that
its properties are being operated in compliance with applicable environmental
laws and regulations. Chieftain does not anticipate that it will be required in
the foreseeable future to expand amounts that are material, in relation to its
total capital expenditures program and to customary industry experience, by
reason of environmental laws and regulations, but it is unable to predict the
ultimate cost of compliance.
U.S. offshore oil and gas operations are subject to regulations of the United
States Department of the Interior which currently imposes absolute liability
upon the lessee under a federal lease for the cost of pollution clean-up
resulting from the lessee's operations, and could subject the lessee to
possible liability for pollution damages. In the event of a serious incident of
pollution, a lessee under a federal lease may be required to suspend or cease
operations in the affected area.
In the U.K., deposits of substances or articles at sea from offshore oil and
gas operations are subject to the licensing control of the Ministry of
Agriculture, Fisheries and Food. The breach of a license will result in
criminal liability and possible civil liability for the cost of any resulting
pollution clean-up. In the event of a serious incident of pollution, the
Ministry may vary or revoke a license.
REGULATION AND POLITICAL RISK
The gas and oil business is regulated by certain federal, state and local laws
and regulations relating to the development, marketing and transmission of gas
and oil, as well as taxation, environmental and safety matters.
12
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Page 15 of 37
International gas and oil operations, such as Chieftain's operations in the
United Kingdom and Libya, may also be subject to various regulatory, political
and economic factors. Political developments (especially in the Middle East)
and the decisions of OPEC (the Organization of Petroleum Exporting Countries)
can particularly affect world oil supply and oil prices. There is no assurance
that laws and regulations enacted in the future will not adversely affect
Chieftain's exploration for, or its production and marketing of, gas and oil.
CONCENTRATION OF GAS PRODUCTION
Most of Chieftain's gas reserves and production are located offshore in the
U.S. Gulf of Mexico and could be adversely affected by natural disasters or
market conditions affecting this area.
DEVELOPMENT OF ADDITIONAL RESERVES
Chieftain's future success, as is generally the case in the industry, depends
on its ability to find or acquire additional gas and oil reserves that are
economically recoverable. Except to the extent that Chieftain conducts
successful exploration or development activities or acquires properties
containing proved reserves, Chieftain's proved reserves will generally decline
as reserves are produced. There can be no assurance that Chieftain will be able
to discover additional commercial quantities of gas and oil or continue to
acquire additional proved properties.
EXPLORATION AND PRODUCTION RISKS
Gas and oil exploration involves a high degree of risk, which even a
combination of experience, knowledge and careful evaluation may not be able to
overcome. Chieftain's operations are subject to all of the risks normally
incident to the operation and development of gas and oil properties and the
drilling of gas and oil wells, including blowouts, cratering and fires and
encountering unexpected formations or pressures, which could result in personal
injury, loss of life and damage to property of Chieftain and others. Offshore
operations are subject to a variety of special operating risks, such as
hurricanes or other adverse weather conditions, more extensive governmental
regulation, including certain regulations that may, in certain circumstances,
impose absolute liability for pollution damage, and interruption or termination
by government authorities based upon environmental or other considerations. In
accordance with customary industry practice, Chieftain may not be fully insured
against these risks, nor may all such risks be insurable.
PRICE UNCERTAINTY
There is uncertainty as to the prices at which gas and oil produced by
Chieftain may be sold, and it is possible that under some market conditions the
production of gas and oil from some of Chieftain's properties may not be
commercially feasible. The availability of a ready market for gas and oil as
produced and the price obtained for such gas and oil depend upon numerous
factors beyond the control of Chieftain, including market considerations, the
proximity and capacity of gas and oil pipelines and processing equipment and
governmental regulation. In recent years, markets for gas in the United States
have been characterized by periods of oversupply relative to demand. There have
been significant fluctuations in prices for both gas and oil in recent years
and there can be no assurance that prices for gas or oil would not decrease in
the future.
EMPLOYEES
At December 31, 1996, Chieftain had 37 full-time equivalent employees, 10 of
whom were engaged as consultants to Chieftain prior to September 1, 1996. In
addition, Chieftain engages the services of consultants as required.
13
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Page 16 of 37
SELECTED CONSOLIDATED FINANCIAL AND OPERATING DATA
CHIEFTAIN INTERNATIONAL, INC. AND SUBSIDIARIES
Year ended December 31, 1996 1995 1994 1993 1992
- -----------------------------------------------------------------------------------------------------------------------
(US$ in thousands, except shares, per share amounts and operating data)
INCOME STATEMENT DATA:
Revenue ....................................... $ 63,099 $ 31,071 $ 34,876 $ 43,270 $ 34,258
Direct expenses ............................... 10,707 8,181 7,443 7,149 6,089
Production taxes .............................. 1,513 1,382 1,396 1,305 1,790
General and administrative expenses ........... 3,972 3,346 3,402 2,921 2,948
Depletion and depreciation(1).................. 30,920 18,779 21,527 23,855 21,142
Additional depletion(2) ....................... - - 15,434 - -
Income (loss) from operations, before dividends
on preferred shares of a subsidiary ......... 9,784 (775) (9,528) 4,883 1,192
Dividends on preferred shares of a subsidiary . 4,942 4,942 4,942 4,942 755
Net income (loss) applicable to common shares(1) 4,842 (5,717) (14,470) (59) 437
Net income (loss) per common share(1) ........ 0.37 (0.54) (1.32) (0.01) 0.04
Weighted average number of common
shares outstanding ......................... 13,065,414 10,633,142 10,986,116 10,991,045 9,749,795
OTHER DATA:
Cash flow from operations ..................... $ 41,841 $ 13,186 $ 17,647 $ 26,894 $ 22,601
Net gas and oil capital expenditures .......... $ 57,673 $ 100,502 $ 28,059 $ 28,779 $ 25,052
BALANCE SHEET DATA (at end of period):
Working capital ............................... $ 42,854 $ 11,216 $ 103,225 $ 115,065 $ 117,117
Total assets(1) ............................... $ 263,279 $ 201,552 $ 208,516 $ 226,738 $ 225,050
Long-term debt ................................ - - - - -
Shareholders' equity(1) ....................... $ 180,719 $ 127,131 $ 137,351 $ 152,754 $ 152,742
OPERATING DATA:
Average Daily Net Production:
Gas (mmcf) .................................. 59.8 29.5 28.4 40.0 34.0
Oil and liquids (bbls) ..................... 2,005 1,643 1,631 1,576 1,545
Gas equivalent (mmcfe) ...................... 71.8 39.3 38.2 49.5 43.3
Average Sales Price:
Gas (per mmcf) .............................. $ 2.09 $ 1.54 $ 1.97 $ 2.05 $ 1.76
Oil and liquids (per bbl) ................... 20.99 16.94 15.86 16.68 19.15
Average Production Cost:
Gas (per mcf) ............................... $ 0.25 $ 0.35 $ 0.34 $ 0.23 $ 0.19
Oil and liquids (per bbl) ................... 6.57 7.31 6.79 6.56 7.68
Notes:
(1) Reference is made to Note 8 of the Notes to Consolidated Financial
Statements which describes the impact of United States accounting
principles.
(2) This amount reflects write-downs in the carrying value of U.S. and
Peruvian gas and oil properties in 1994 in accordance with full cost
accounting rules under Canadian GAAP.
14
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Page 17 of 37
SUMMARY OF QUARTERLY FINANCIAL INFORMATION
Per
Quarter Ended Revenue Income (loss) Common Share
- ----------------------------------------------------------------------
(US$ in thousands except per share amounts)
MARCH 31, 1996 $ 13,057 $ (157) $ (0.01)
JUNE 30, 1996 14,941 1,019 0.08
SEPTEMBER 30, 1996 14,610 693 0.05
DECEMBER 31, 1996 20,491 3,287 0.25
MARCH 31, 1995 $ 6,558 $ (1,290) $ (0.12)
JUNE 30, 1995 6,862 (960) (0.09)
SEPTEMBER 30, 1995 7,015 (1,740) (0.16)
DECEMBER 31, 1995 10,636 (1,727) (0.17)
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITIONS AND RESULTS OF
OPERATIONS
Reference is made to the section entitled "Management's Discussion and Analysis"
on pages 20 and 21 of the 1996 Annual Report, which sections are incorporated
herein by reference.
15
36
Page 18 of 37
DIRECTORS AND OFFICERS
The name, municipality of residence, position held with the Company and
principal occupation of each of the directors and officers are set forth below:
NAME AND POSITION HELD WITH THE COMPANY AND
MUNICIPALITY OF RESIDENCE DURATION THEREOF PRINCIPAL OCCUPATION
David E. Mitchell, O.C.(1) Chairman of the Board of Directors Chairman of the Board of Directors,
Calgary, Alberta since February, 1989 Alberta Energy Company Ltd.
Stanley A. Milner, A.O.E., LL.D. President and Chief Executive Officer President and Chief Executive Officer
Edmonton, Alberta and Director of the Company
Stephen C. Hurley Senior Vice President and Chief Officer of the Company
Dallas, Texas Operating Officer
Edward L. Hahn Senior Vice President, Finance and Officer of the Company
Edmonton, Alberta Treasurer
Esther S. Ondrack Senior Vice President and Secretary and Officer of the Company
Edmonton, Alberta Director
Roger A. McDougall Vice President, Land Officer of the Company
Edmonton, Alberta
S. Jay Milner Vice President, Drilling and Production Officer of the Company
Edmonton, Alberta
Ronald J. Stefure Controller Officer of the Company
Edmonton, Alberta
Hugh J. Kelly Director since July, 1989 Corporate Director and Energy
Mandeville, Louisiana Consultant
John E. Maybin(1) Director since June, 1991 Corporate Director and Consultant
Calgary, Alberta
Louis G. Munin(1) Director since February, 1989 Corporate Director and Financial
Dallas, Texas Consultant
Stuart T. Peeler(1) Director since February, 1989 Corporate Director and Petroleum
Tucson, Arizona Industry Consultant
(1) Member of the Audit Committee. The Company has no executive committee.
Except as otherwise noted, all of the officers of the Company have held
positions as officers of the Company since its inception. Prior thereto, all of
them, other than Mr. Mitchell and Mr. Hurley, served in similar capacities with
Chieftain Development Co. Ltd. Mr. Mitchell was President and Chief Executive
Officer of Alberta Energy Company Ltd. from 1975 until December 1993. Mr.
Hurley joined the Company in September, 1995. He was previously the Vice
President Exploration of a U.S.-based integrated oil company. Mr. Kelly was
President and Chief Executive Officer of Ocean Drilling & Exploration Company
until 1989. Mr. Maybin has been a corporate director and consultant since 1985.
Mr. Munin was Executive Vice President and Chief Financial Officer of Lafarge
Corporation until February 1988. Mr. Peeler was Chairman of the Board and Chief
Executive Officer of Statex Petroleum, Inc. until January, 1989. S.J. Milner
and R.J. Stefure were appointed officers of the Company in June, 1995 and prior
thereto held management positions with the Company.
Terms of office of directors will expire at the time of Annual Meetings as
follows: 1997 - Mr. Maybin and Mrs. Ondrack; 1998 - Messrs. Milner and
Mitchell; 1999 - Messrs. Kelly, Munin and Peeler.
As at December 31, 1996 the directors and officers of the Company, as a group,
beneficially owned, directly or indirectly, or exercised control or direction
over, approximately 4.8% of the outstanding common shares.
16
37
Page 19 of 37
DIVIDEND POLICY
The Company has not paid any dividends on its common shares and at the present
time it is not the Company's policy to declare regular dividends on the common
shares. This policy is under periodic review by the Board of Directors and is
subject to change at any time depending on the earnings, financial condition and
capital requirements of the Company. Dividends may be paid on the common shares
provided that all dividends on the preferred shares of Chieftain International
Funding Corp. have been paid.
MARKET FOR SECURITIES
The common shares of the Company are traded on the Toronto, American and
Alberta stock exchanges under the symbol CID. The preferred shares of Chieftain
International Funding Corp. are traded on the American Stock Exchange.
ADDITIONAL INFORMATION
Additional information, including executive compensation and options to
purchase securities, is contained in the Company's Information Circular dated
March 20, 1997 which relates to the Annual Meeting of Shareholders to be held
on May 15, 1997. Additional financial information is provided in the
Company's comparative consolidated financial statements for the year ended
December 31, 1996.
The Company undertakes to provide to any person or company, upon request to the
Secretary of the Company:
(a) when the securities of the Company are in the course of a distribution
pursuant to a short form prospectus or a preliminary short form
prospectus has been filed in respect of a proposed distribution of its
securities:
(i) one copy of the latest Annual Information Form together with one
copy of any document, or the pertinent pages of any
document,incorporated therein by reference;
(ii) one copy of the comparative financial statements of the Company
for the Company's most recently completed financial year in
respect of which such financial statements have been issued,
together with the report of the auditors thereon, Management's
Discussion and Analysis contained in the Annual Report of the
Company, if applicable, and one copy of any interim financial
statements of the Company subsequent to the filing of the annual
financial statements;
(iii) one copy of the Information Circular or comparable document of
the Company in respect of the most recent annual meeting of
shareholders of the Company, if applicable, which involved the
election of directors; and
(iv) one copy of any other documents which are incorporated by
reference into the preliminary short form prospectus or the
short form prospectus; or
(b) at any time the documents referred to in subclauses (a)(i), (ii) and
(iii) above, provided that the Company may require the payment of a
reasonable charge from such a person or company who is not a security
holder of the Company where the documents are furnished under this
Clause (b).
For additional copies of this Annual Information Form or any of the materials
listed in the preceding paragraphs, please contact:
Secretary
Chieftain International, Inc.
1201 Toronto Dominion Tower, Edmonton Centre
Edmonton, Alberta, Canada
T5J 2Z1
17
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Page 20 of 37
MANAGEMENT'S REPORT
February 4, 1997
The annual and quarterly consolidated financial statements of the Company have
been prepared by management in accordance with Canadian generally accepted
accounting principles. The financial information contained elsewhere in this
annual report is consistent with the consolidated financial statements in all
material respects.
The Company maintains systems of accounting and internal controls to provide
reasonable assurance that its financial information is reliable and accurate,
and that its assets are adequately safeguarded. Where necessary, management has
made informed judgments and estimates in the preparation of the financial
statements.
Independent auditors, appointed by the shareholders, have examined the
consolidated financial statements. The Audit Committee of the Board of Directors
meets periodically with management and the independent auditors to review audit,
internal control, accounting policy and financial reporting matters.
The annual consolidated financial statements are approved by the Board of
Directors on the recommendation of the Audit Committee.
S.A. Milner E.L. Hahn
President and Senior Vice President,
Chief Executive Officer Finance and Treasurer
AUDITORS' REPORT
To the Shareholders of Chieftain International, Inc.
We have audited the consolidated balance sheets of Chieftain International, Inc.
as at December 31, 1996 and 1995 and the consolidated statements of income and
retained earnings (deficit) and changes in financial position for each of the
years in the three-year period ended December 31, 1996. These financial
statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with generally accepted auditing
standards. 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.
In our opinion, these consolidated financial statements present fairly, in all
material respects, the financial position of the Company as at December 31, 1996
and 1995 and the results of its operations and the changes in its financial
position for each of the years in the three-year period ended December 31, 1996
in accordance with generally accepted accounting principles.
Chartered Accountants
Edmonton, Alberta
February 4, 1997
22
39
Page 21 of 37
CONSOLIDATED BALANCE SHEET
Chieftain International, Inc. and Subsidiary Companies
(Full Cost Method of Accounting)
as at December 31, 1996 1995
- -------------------------------------------------------------------------
(US$ in thousands)
ASSETS
Current assets:
Cash and short-term deposits $ 42,449 $ 10,575
Accounts receivable 11,199 8,263
Other 293 492
--------- --------
53,941 19,330
--------- --------
Capital assets, at cost:
Natural resource properties including
exploration and development thereon 390,354 332,681
Land and buildings 200 200
Other equipment 1,589 1,402
--------- ---------
392,143 334,283
Less: accumulated depletion
and amortization 188,254 157,334
--------- ---------
203,889 176,949
-------- ---------
Deferred income taxes 5,449 5,273
--------- ---------
$ 263,279 $ 201,552
--------- ---------
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities:
Accounts payable and accrued $ 11,087 $ 6,878
Dividend payable - 1,236
--------- ---------
11,087 8,114
--------- ---------
Deferred income taxes 8,070 2,904
Preferred shares of a subsidiary (Note 2) 63,403 63,403
Shareholders' equity (Note 3):
Share capital-
Authorized - an unlimited number of -
First preferred shares
Second preferred shares
Common shares
Issued-
13,591,763 common shares
(1995 - 10,546,100) 192,381 143,635
Contributed surplus 645 645
Deficit (12,307) (17,149)
--------- ---------
180,719 127,131
--------- ---------
$ 263,279 $ 201,552
--------- ---------
Approved by the Board
- ------------------------ ------------------------
S.A. Milner, Director L.G. Munin, Director
23
40
Page 22 of 37
CONSOLIDATED STATEMENT OF INCOME AND RETAINED EARNINGS (DEFICIT)
Chieftain International, Inc. and Subsidiary Companies
Year ended December 31, 1996 1995 1994
- -----------------------------------------------------------------------------------------------------------
(US$ in thousands except shares and per share amounts)
Production revenue $ 72,838 $ 31,733 $ 35,960
Less: Royalties 12,226 5,058 5,841
-------------------------------------------
Production revenue, net of royalties 60,612 26,675 30,119
Interest and other 2,487 4,396 4,757
-------------------------------------------
63,099 31,071 34,876
-------------------------------------------
Direct expenses 10,707 8,181 7,443
Production taxes 1,513 1,382 1,396
General and administrative expenses 3,972 3,346 3,402
Depletion and amortization 30,920 18,779 21,527
Additional depletion (Note 1(d)):
U.S. properties -- -- 9,834
Peruvian properties -- -- 5,600
-------------------------------------------
47,112 31,688 49,202
-------------------------------------------
Income (loss) before income taxes and dividends on
preferred shares of a subsidiary 15,987 (617) (14,326)
Income taxes (recovery) (Note 4):
Current 124 34 46
Deferred 6,079 124 (4,844)
-------------------------------------------
6,203 158 (4,798)
-------------------------------------------
Income (loss) before dividends on preferred shares
of a subsidiary 9,784 (775) (9,528)
Dividends paid on preferred shares of a subsidiary 4,942 4,942 4,942
-------------------------------------------
Net income (loss) applicable to common shares 4,842 (5,717) (14,470)
Retained earnings (deficit), beginning of year (17,149) (11,432) 3,038
-------------------------------------------
Deficit, end of year $ (12,307) $ (17,149) $ (11,432)
-------------------------------------------
Net income (loss) per common share (Note 5) $ 0.37 $ (0.54) $ (1.32)
-------------------------------------------
Weighted average number of common shares
outstanding (Note 5) 13,065,414 10,633,142 10,986,116
-------------------------------------------
24
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Page 23 of 37
CONSOLIDATED STATEMENT OF CHANGES IN FINANCIAL POSITION
Chieftain International, Inc. and Subsidiary Companies
Year ended December 31, 1996 1995 1994
- -------------------------------------------------------------------------------
(US$ in thousands except per share amounts)
Operating activities:
Net income (loss) applicable to common
shares $ 4,842 $ (5,717) $(14,470)
Items not requiring funds:
Depletion and amortization 30,920 18,779 36,961
Deferred income taxes 6,079 124 (4,844)
--------------------------------
Cash flow from operations 41,841 13,186 17,647
Change in non-cash operating working capital
Accounts receivable (2,936) (2,879) 892
Other current assets 199 (112) 92
Accounts payable and accrued (901) 921 392
Dividend payable (1,236) 1,236 --
--------------------------------
36,967 12,352 19,023
--------------------------------
Financing activities:
Issue of common shares 50,097 40 --
Financing costs (2,440) -- --
Purchase of common shares for cancellation -- (4,543) (933)
--------------------------------
47,657 (4,503) (933)
--------------------------------
Investing activities:
Purchase of producing gas and oil
properties (2,077) (54,678) (113)
Lease acquisition, exploration and
development costs (56,636) (45,824) (27,946)
Sale of producing properties 1,040 -- --
--------------------------------
(57,673) (100,502) (28,059)
Purchase of other capital assets (187) (190) (495)
Change in investing accounts payable
and accrued 5,110 1,267 (193)
--------------------------------
(52,750) (99,425) (28,747)
--------------------------------
Change in cash and short-term deposits 31,874 (91,576) (10,657)
Cash and short-term deposits, beginning
of year 10,575 102,151 112,808
--------------------------------
Cash and short-term deposits, end of year $ 42,449 $ 10,575 $102,151
--------------------------------
Cash flow from operations per common share:
Basic $ 3.20 $ 1.24 $ 1.61
--------------------------------
Fully diluted $ 2.73 $ 1.21 $ 1.53
--------------------------------
25
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Page 24 of 37
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (December 31, 1996, 1995 and 1994)
Chieftain International, Inc. and Subsidiary Companies
The Company is engaged in gas and oil exploration, development and production
primarily in the United States and also in the U.K. sector of the North Sea and
in Libya. The Consolidated Financial Statements are expressed in United States
currency since most of the Company's assets and operations are denominated in
U.S. Dollars.
1. Summary of Significant Accounting Policies:
(a) Accounting principles --
The Company's financial statements are prepared in conformity with
Canadian generally accepted accounting principles. The preparation of
financial statements in conformity with generally accepted accounting
principles requires management to make informed judgements and
estimates in preparation of these financial statements. Actual results
may differ from those estimates. Material differences between Canadian
principles and those of the U.S., which affect the Company, are
specifically referred to in these Notes to Consolidated Financial
Statements. Note 8 details the effect of such differences on earnings
and balance sheet accounts.
(b) Principles of consolidation --
The Consolidated Financial Statements include the accounts of the
Company and its subsidiary companies, all of which are wholly-owned
except for Chieftain International Funding Corp., a U.S. subsidiary
which in 1992 issued 2,726,700 preferred shares to the public. These
preferred shares are convertible into common shares of Chieftain
International Inc.
Acquisitions of all subsidiaries and businesses have been accounted
for by the purchase method and accordingly only income or losses since
date of acquisition are included in the Consolidated Statement of
Income.
(c) Foreign currency translation --
Canadian and other foreign currency amounts have been translated into
U.S. currency on the following bases: monetary assets and liabilities
at the year-end rates of exchange; non-monetary assets and liabilities
at historical exchange rates; and revenue and expenses at monthly
average exchange rates during the year. Translation gains or losses
are reflected in the Consolidated Statement of Income.
(d) Natural resource properties --
The Company accounts for gas and oil properties in accordance with
Canadian guidelines on full cost accounting. Under this method, all
costs associated with the acquisition, exploration and development of
gas and oil properties are capitalized in cost centers on a
country-by-country basis. Depletion is calculated using the
unit-of-production method based on gross proved reserves before
royalties and combines oil and natural gas on an energy equivalent
basis. Future well abandonment and site restoration costs are included
in the calculation of depletion expense.
A ceiling test is applied to ensure that capitalized costs do not
exceed estimated future net revenues less certain costs. There is
uncertainty as to the prices at which gas and oil produced by the
Company may be sold. The application of such ceiling test on U.S.
property carrying costs at December 31, 1994 based on average prices
received by the Company during the year, $1.97 for natural gas and
$15.86 for oil and natural gas liquids ("ngls"), resulted in a
write-down of $6,431,000, after providing for tax recoveries of
$3,403,000. A write-down of $10,996,000, after providing for tax
recoveries of $5,817,000 would have been required had December 31,
1994 prices, $1.62 for natural gas and $16.50 for oil and ngls, been
used. A write-down of $3,120,000, after providing for tax recoveries
of $2,480,000, was taken to eliminate all costs incurred in Peru to
December 31, 1994.
General and administrative costs relating directly to exploration and
development activities have been capitalized as follows:
Year ended December 31, 1996 1995 1994
- ----------------------------------------------------------------------------
(in thousands)
Lease acquisition costs $ 837 $ 538 $ 469
Exploration costs 1,547 1,909 1,638
Development costs 1,254 928 525
--------------------------------------
$3,638 $3,375 $2,632
--------------------------------------
26
43
Page 25 of 37
The following weighted average field prices were used in the
determination of the Company's U.S. reserves:
As at December 31, 1996 1995 1994
--------------------------------------------------------------------
Oil -- per barrel $ 24.29 $ 18.71 $ 16.64
---------------------------------------
Ngls -- per barrel $ 21.66 $ 16.64 $ 15.09
---------------------------------------
Oil & ngls -- per barrel $ 24.03 $ 18.48 $ 16.50
---------------------------------------
Natural gas -- per thousand
cubic feet ("mcf") $ 3.43 $ 2.06 $ 1.62
---------------------------------------
Depletion rates per physical unit of U.S. production are as follows:
Natural Gas Crude Oil & Ngls
(per mcf) (per barrel)
----------------------------------------------------------------
Year ended December 31, 1994 $ 1.28 $ 7.65
---------------------------
Year ended December 31, 1995 $ 1.10 $ 6.57
---------------------------
Year ended December 31, 1996 $ 1.03 $ 6.16
---------------------------
A field price of $2.04 (1995 -- $0.86, 1994 -- $2.25) per thousand
cubic feet was used in the determination of the Company's U.K. natural
gas reserves. The depletion rate per physical unit of U.K. production
was $0.56 per mcf for the year ended December 31, 1996 (1995 --
$0.53).
(e) Land, buildings and other equipment -- Amortization is provided as
follows:
Rate per annum Method
-------------------------------------------------------------------
Buildings 5% Straight--line
Furniture, office equipment and
leasehold improvements 10--20% Straight--line
Expenditures for renewals and betterments which materially increase
the estimated useful life of buildings and equipment are capitalized;
expenditures for repairs and maintenance are charged to income. Costs
and accumulated amortization of assets retired or sold are removed
from the asset and related accumulated amortization accounts; losses
and gains thereon are included in the Consolidated Statement of Income
as depletion and amortization.
(f) Income taxes --
The Company follows the tax allocation method of accounting for the
tax effect of all timing differences between taxable income and
accounting income. Thus, provision is made currently for taxes
deferred as a result of claiming for tax purposes deductions in excess
of amounts charged to income in the books, principally natural
resource lease acquisition costs, intangible exploration, development
and drilling costs and costs of tangible capital assets.
United States accounting principles require corporations to account
for deferred income taxes by the liability method. The effect on the
Company of the application of such method is not material.
2. PREFERRED SHARES OF A SUBSIDIARY:
Chieftain International Funding Corp. ("Funding"), a subsidiary of
Chieftain International (U.S.) Inc., sold 2,726,700 shares of $1.8125
cumulative convertible redeemable preferred shares at $25.00 per share
through a 1992 public offering in the United States. The preferred shares
are redeemable, at the option of Funding, at $26.0069 per share during
1997, declining to $25.00 per share after December 31, 2001 plus
accumulated and unpaid dividends. Each preferred share has a liquidation
preference of $25.00 and is convertible at any time into 1.25 Common Shares
of Chieftain International, Inc. at the option of the holder. Chieftain
International, Inc. has guaranteed certain obligations of Funding with
respect to the preferred shares.
27
44
Page 26 of 37
3. SHAREHOLDERS' EQUITY:
(a) Common Shares -
Year ended December 31, 1996 1995 1994
---------------------------------------------------------------------------------------------------------------------
(dollars in thousands) Number Share Number Share Number Share
of Capital of Capital of Capital
Shares Account Shares Account Shares Account
----------------------------------------------------------------------------------------------------------------------
Balance, beginning of year 10,546,100 $ 143,635 10,912,100 $ 148,621 10,992,500 $ 149,716
Shares issued for cash 2,970,000 47,654* - - - -
Share options exercised 75,663 1,092 3,000 40 - -
Shares purchased and cancelled - - (369,000) (5,026) (80,400) (1,095)
-------------------------------------------------------------------------------------------
Balance, end of year 13,591,763 $ 192,381 10,546,100 $ 143,635 10,912,100 $ 148,621
-------------------------------------------------------------------------------------------
* Reduced by costs of issue of $2,440, less related deferred taxes of
$1,089.
In the first quarter of 1996, the Company sold 2,970,000 common
shares, through a public offering in the United States and Canada at
$16.50 per share (C$22.75).
Alberta Energy Company Ltd. which at December 31, 1993 owned 21.6% of
the issued common shares of the Company, sold all such shares in a
1994 secondary public offering.
(b) Common Shares reserved -
At December 31, 1996 a total of 1,226,003 (1995 - 1,046,250; 1994 -
895,000) of the authorized but unissued common shares of the Company
were reserved for issuance under the Share Option Plan. See Note
3(d). The Company has reserved 3,408,375 common shares for issuance
pursuant to the conversion provisions of the preferred shares of a
subsidiary. See Note 2.
(c) Contributed Surplus -
During 1995, the Company purchased for cancellation 369,000 (1994 -
80,400) common shares pursuant to a normal-course issuer bid.
Contributed surplus is created out of the excess of original net issue
price over purchase price.
(d) Share Option Plan (the "Plan") -
The Plan, as amended on March 15, 1996, provides for the granting of
options to employees, directors and consultants to purchase common
shares of the Company. In 1996, the number of shares reserved for
issuance under the plan was increased by 255,416 (1995 - 154,250, 1994
- 400,000). Each option expires not later than ten years from the date
it was granted. The exercise of options granted under the Plan is
contingent upon continued service except that options which are
exercisable may be exercised after termination of service under
certain conditions. Options granted are exercisable as to one-third of
the granted amount on or after each of the first three anniversaries
of the date of grant or over such longer period as may be determined
by the directors. Exercisability of options accelerates in certain
events. The option price for shares in respect of which an option is
granted under the Plan is not less than the market price on the date
of grant. Prior to 1992, the Company granted certain options at 90% of
the market price on the date of grant.
At December 31, 1996 the following options were outstanding to 46
participants in the Plan:
Option Price Year of
Shares Per Share Expiry
-------------------------------------------------------
152,500 $13.50 1999
19,000 14.50 - 16.10 1999
70,000 19.00 2001
1,000 16.25 2002
34,000 20.12 - 20.87 2003
247,102 15.38 2004
370,651 13.63 - 15.63 2005
15,000 23.75 2006
28
45
Page 27 of 37
The following is a summary of activity related to the share option
plan for the years ended December 31, 1996, 1995 and 1994.
Number Market Value at
of Minimum Option Price Date Granted
Shares Per Share Total Per Share Total
--------------------------------------------------------------------------------------------------------------
Outstanding December 31, 1993 329,750 $13.50-20.87 $ 5,136,125 $13.50-20.87 $ 5,188,925
Year ended December 31, 1994
Granted 277,500 15.38 4,267,950 15.38 4,267,950
--------- ----------- -----------
Outstanding December 31, 1994 607,250 9,404,075 9,456,875
Year ended December 31, 1995
Granted 384,000 13.63-15.63 5,365,420 13.63-15.63 5,365,420
Exercised (3,000) 13.50 (40,500) 13.50 (40,500)
Forfeited (8,000) 15.38 (123,040) 15.38 (123,040)
--------- ----------- -----------
Outstanding December 31, 1995 980,250 14,605,955 14,658,755
Year ended December 31, 1996
Granted 15,000 23.75 356,250 23.75 356,250
Exercised (75,663) 13.50-16.25 (1,075,572) 13.50-16.25 (1,097,972)
Forfeited (10,334) 13.63-20.12 (159,079) 13.63-20.12 (159,079)
--------- ----------- -----------
Outstanding December 31, 1996 909,253 $ 13,727,554 $ 13,757,954
--------- ----------- -----------
Exercisable at December 31, 1994 305,083 13.50-20.87 $ 4,627,292
--------- -----------
Exercisable at December 31, 1995 404,583 13.50-20.87 $ 6,227,813
--------- -----------
Exercisable at December 31, 1996 558,319 13.50-20.87 $ 8,548,461
--------- -----------
4. INCOME TAX EXPENSE:
Income tax expense is made up of the following components:
Year ended December 31 1996 1995 1994
--------------------------------------------------------------------------------------------------------------------------
(in thousands) Canada U.S. Canada U.S. Canada U.S.
--------------------------------------------------------------------------------------------------------------------------
Income (loss) before income taxes and dividends
on preferred shares of a subsidiary $ 1,461 $ 14,526 $ (324) $ (293) $ (5,794) $ (8,532)
--------------------------------------------------------------------------
Income taxes (recovery)
Current 124 - 34 - 41 5
Deferred 912 5,167 292 (168) (1,826) (3,018)
--------------------------------------------------------------------------
$ 1,036 $ 5,167 $ 326 $ (168) $(1,785) $ (3,013)
--------------------------------------------------------------------------
Deferred income tax expense results from timing differences between the
recognition of expenses for tax and financial statement purposes as
explained in Note 1(f). The sources of these differences are as follows:
Year ended December 31 1996 1995 1994
--------------------------------------------------------------------------------------------------------------------------
(in thousands) Canada U.S. Canada U.S. Canada U.S.
--------------------------------------------------------------------------------------------------------------------------
Amortization of natural resource properties $ 805 $ 5,898 $ 1,289 $ 6,567 $ (2,117) $ (780)
Amortization of buildings and equipment 3 340 136 11 26 (5)
Financing costs 348 - 129 - 209 -
Tax loss carry forward (230) (1,143) (1,206) (6,746) (20) (2,302)
Other (14) 72 (56) - 76 69
--------------------------------------------------------------------------
$ 912 $ 5,167 $ 292 $ (168) $(1,826) $ (3,018)
--------------------------------------------------------------------------
29
46
Page 28 of 37
The actual tax rate differs from the expected tax rate for the following
reasons:
Year ended December 31, 1996 1995 1994
- --------------------------------------------------------------------------------
Expected percentage on pre-tax income (loss)
(combined Canadian federal and
provincial rate) 44.6 % 44.6 % 44.3 %
Add (deduct) the effect of:
Lower income tax rate on earnings of
U.S. subsidiary (7.9) (7.4) (5.3)
Effects of Canadian income taxes on
exchange (gain) loss that eliminates
upon consolidation (0.3) (63.8) (3.0)
Other 2.4 1.0 (2.5)
--------------------------------
Actual percentage of income tax on
pre-tax income (loss) 38.8 % (25.6)% 33.5 %
--------------------------------
5. NET INCOME (LOSS) PER COMMON SHARE:
Net income (loss) per common share is computed by dividing net income
(loss) applicable to common shares by the weighted average number of common
shares outstanding during each year.
In the calculation of fully diluted earnings per share, consideration is
given to potentially dilutive share options and convertible preferred
shares issued by a subsidiary. This calculation produced no dilutive effect
for 1996, 1995 and 1994 and is therefore not shown.
6. PENSION COSTS AND OBLIGATIONS:
The Company contributed $103,455, $73,230 and $81,053 for 1996, 1995 and
1994, respectively, to defined contribution plans. Under a supplementary
retirement plan established in 1991, defined costs of $127,358, $97,299 and
$127,356 for 1996, 1995 and 1994, respectively, and the related liability
are recorded in the accounts but are not currently funded.
The Company has established no other retirement benefit plans.
7. SEGMENT INFORMATION:
1996 1995 1994
- --------------------------------------------------------------------------------
(in thousands)
INDUSTRY SEGMENTS--
The Company operates in one industry segment.
GEOGRAPHIC SEGMENTS--
Revenue:
United States $ 56,827 $ 26,674 $ 30,339
United Kingdom 4,155 552 --
Corporate and other 2,117 3,845 4,537
--------------------------------
$ 63,099 $ 31,071 $ 34,876
--------------------------------
Income (loss) before income taxes and
dividends on preferred shares of a
subsidiary
United States $ 14,173 $ (3,461) $ (9,127)
United Kingdom 1,102 129 --
Corporate and other 761 2,983 583
Libya (30) (43) (121)
Peru (19) (225) (5,661)
--------------------------------
$ 15,987 $ (617) $(14,326)
--------------------------------
Identifiable assets:
United States $185,974 $159,564 $ 84,380
United Kingdom 18,613 17,048 6,011
Other foreign 13,322 13,107 11,234
Corporate and other 45,370 11,833 106,891
--------------------------------
$263,279 $201,552 $208,516
--------------------------------
30
47
Page 29 of 37
8. UNITED STATES ACCOUNTING PRINCIPLES:
U.S. Full cost accounting rules differ materially from the Canadian full
cost accounting guidelines followed by the Company. The U.S. rules require
an impairment test to be conducted quarterly whereas the Canadian
guidelines require this test only at year-end. In determining the
limitation on carrying values, U.S. rules require the discounting of future
net revenues at 10%; Canadian guidelines use undiscounted future net
revenues and require the deduction of estimated future administrative
costs. During 1995 and 1994 an impairment adjustment would have been
required under U.S. accounting rules. The quarterly test required by U.S.
accounting rules, using a December 31 U.K. gas price of $0.86 per mcf in
1995 and December 31 U.S. gas and oil prices of $1.62 per mcf and $16.50
per bbl in 1994 to determine future net revenues, would have resulted in a
write-down of U.K. property carrying costs of $3.8 million, after providing
for tax recoveries of $2.9 million, at December 31, 1995 and a write-down
of U.S. property carrying costs of $8.3 million, after providing for tax
recoveries of $4.4 million, at December 31, 1994. Under Canadian guidelines
the test resulted in a write-down of U.S. property carrying costs at
December 31, 1994 of $6.4 million, after providing for tax recoveries of
$3.4 million.
The effect on the Consolidated Balance Sheet of the differences between
Canadian and U.S. accounting principles is as follows:
Year ended December 31, 1996 1995
- -----------------------------------------------------------------------------------------------------------------------------
(in thousands) Under U.S. Under U.S.
Increase Accounting Increase Accounting
As Reported (Decrease) Principles As Reported (Decrease) Principles
- -----------------------------------------------------------------------------------------------------------------------------
Net capital assets $ 203,889 $ (21,219) $ 182,670 $ 176,949 $ (23,600) $ 153,349
Deferred tax - asset $ 5,449 $ (460) $ 4,989 $ 5,273 $ 5,727 $ 11,000
Deferred tax - liability $ 8,070 $ (8,070) $ - $ 2,904 $ (2,904) $ -
Retained earnings (deficit) $ (12,307) $ (13,609) $ (25,916) $ (17,149) $ (14,969) $ (32,118)
The effect on consolidated earnings of these differences is summarized as
follows:
Year ended December 31, 1996 1995 1994
- ---------------------------------------------------------------------------------------------------------------------------
(in thousands except share amounts)
Net income (loss) applicable to common shares as reported $ 4,842 $ (5,717) $ (14,470)
Additional depletion - (6,740) (2,811)
-------------------------------------------
4,842 (12,457) (17,281)
Reduction in depletion expense 2,381 2,775 3,836
Reduction (increase) in deferred tax provision (1,021) 1,820 (265)
-------------------------------------------
Net income (loss) applicable to common shares under U.S.
accounting principles $ 6,202 $ (7,862) $ (13,710)
-------------------------------------------
Basic and fully diluted earnings (loss) per common share and common
share equivalents under U.S. accounting principles $ 0.46 $ (0.74) $ (1.25)
------------------------------------------
Weighted average number of common shares and common share
equivalents outstanding 13,446,684 10,633,142 10,986,116
------------------------------------------
Earnings per common share and common share equivalents were computed by
dividing net income (loss) applicable to common shares by the weighted
average number of shares and common share equivalents, if dilutive,
outstanding during the year. Common share equivalents consist of share
options assuming all share options are exercised using the treasury stock
method.
The Company applies APB opinion 25 and related interpretations in
accounting for share option transactions. Accordingly, no compensation cost
is recognized in the accounts. Effective for 1996, U.S. accounting
principles require disclosure of the impact on earnings and earnings per
share of the value of options granted after 1994 calculated in accordance
with FAS 123. Such impact, calculated using the Black-Scholes option
pricing model, applying risk-free interest rates of 6.51% for 1996 and
6.40% for 1995 and assuming ten year expected option lives, no dividend
yields and expected volatilities of 24% for both years on a weighted
average basis, would amount to a net of tax charge to income (loss) of
$872,000 (1995 - $270,000). After reflecting this charge, pro forma net
income (loss) applicable to common shares under U.S. accounting principles
would be $5,330,000 (1995 - $(8,132,000)) and pro forma basic and fully
diluted earnings (loss) per common share and common share equivalent under
U.S. accounting principles would be $0.40 (1995 - $(0.76)). These effects
are not necessarily indicative of those to be expected in future years.
31
48
Page 30 of 37
Deferred tax liabilities (assets) are comprised of the following:
As at December 31, 1996 1995
------------------------------------------------------------
(in thousands)
Deferred tax liabilities
Depletion and amortization $ 16,064 $ 9,124
-------------------------
Deferred tax assets
Depletion and amortization (3,735) (4,694)
Financing costs (965) (213)
Loss carryforwards (16,092) (12,853)
Other (261) (2,364)
-------------------------
(21,053) (20,124)
-------------------------
Net deferred tax (assets) $ (4,989) $(11,000)
-------------------------
At December 31, 1996 the Company's U.S. net operating losses were
$37,558,000 of which $6,119,000, $2,835,000, $6,139,000, $18,007,000 and
$4,458,000 expire in the years 2005, 2007, 2009, 2010 and 2011,
respectively. Canadian net operating losses were $5,908,000 of which
$241,000, $1,021,000, $8,000 and $4,638,000 expire in the years 1998, 1999,
2000 and 2003 respectively. The Company is of the opinion that the tax
benefit of these losses will be realized.
Provisions for deferred income taxes were as follows:
Year ended December 31, 1996 1995 1994
-------------------------------------------------------------------------------
(in thousands)
U.S. Federal and State $ 5,861 $ 567 $ (2,753)
Canada 1,239 (2,263) (1,826)
--------------------------------------------
$ 7,100 $ (1,696) $ (4,579)
--------------------------------------------
The provision for income taxes differs from the amount of income tax
determined by applying the Canadian statutory rate to pre-tax income before
dividends paid on preferred shares of a subsidiary, as a result of the
following:
Year ended December 31, 1996 1995 1994
-------------------------------------------------------------------------------
(in thousands)
Tax at statutory Canadian rate
44.6%; 1995 - 44.6%; 1994 - 44.3% $ 8,196 $ (2,043) $ (5,892)
Lower income tax rate on earnings
of U.S. subsidiaries (1,428) (150) 577
Effects of Canadian income taxes
on exchange (gain) loss that
eliminates upon consolidation (56) 394 431
Other 512 137 351
--------------------------------------------
Tax at effective rate $ 7,224 $ (1,662) $ (4,533)
--------------------------------------------
Cash payments for income taxes for the years 1996, 1995 and 1994 were
$26,000, $44,000 and $49,000, respectively.
32
49
Page 31 of 37
UNDERTAKING
Registrant undertakes to make available, in person or by telephone,
representatives to respond to inquiries made by the Commission staff, and to
furnish promptly, when requested to do so by the Commission staff, information
relating to: the securities registered pursuant to Form 40-F; the securities in
relation to which the obligation to file an annual report on Form 40-F arises;
or transactions in said securities.
SIGNATURES
Pursuant to the requirements of the Exchange Act, the Registrant Chieftain
International, Inc. certifies that it meets all of the requirements for filing
on Form 40-F. The Registrant duly caused this annual report to be signed on its
behalf by the undersigned, thereunto duly authorized.
Registrant
CHIEFTAIN INTERNATIONAL, INC.
By: /s/ E.L. HAHN
---------------------
Name: E.L. Hahn
Title: Senior Vice President, Finance and Treasurer
Date: March 20, 1997
4
50
[PRICE WATERHOUSE LOGO]
Page 32 of 37
CONSENT OF INDEPENDENT CHARTERED ACCOUNTANTS
We hereby consent to the inclusion in the Annual Report of Form 40-F of our
report dated February 4, 1997 on the consolidated financial statements of
Chieftain International, Inc. for the year ended December 31, 1996.
/s/ Price Waterhouse
- ------------------------------------------
Chartered Accountants
Edmonton, Alberta, Canada
March 20, 1997
51
[NETHERLAND, SEWELL LETTERHEAD]
Page 33 of 37
CONSENT OF INDEPENDENT PETROLEUM ENGINEERS AND GEOLOGISTS
We hereby consent to the references to our firm in the Annual Report of
Chieftain International, Inc. on Form 40-F for the fiscal year ended December
31, 1996, filed with the Securities and Exchange Commission in Washington, D.C.
pursuant to the Securities Exchange Act of 1934.
NETHERLAND, SEWELL & ASSOCIATES, INC.
By: Frederic D. Sewell
-------------------------------------
Frederic D. Sewell
President
Dallas, Texas
March 20, 1997
52
EXHIBIT A
53
Page 34 of 37
MANAGEMENT'S DISCUSSION AND ANALYSIS
To be read in conjunction with the 1996 audited consolidated financial
statements.
(Comparisons are with 1995 amounts unless otherwise stated)
The Company produces and sells natural gas and oil acquired through exploration
and development or through the purchase of producing properties. Producing
reserves are located in the United States in the Gulf of Mexico and Utah and in
the British sector of the North Sea. Exploration is conducted in these areas
and in Libya. In August 1995, the Company completed the acquisition of 50% of
the interests held by Santa Fe Minerals, Inc. and affiliates ("SFM") in 57
offshore Gulf of Mexico blocks, significantly increasing reserves, production
and exploration acreage in this area.
The Company's reporting currency is the U.S. dollar.
ANALYSIS OF OPERATING RESULTS
The 130% increase in production revenue resulted from a 36% increase in average
price received for natural gas to $2.09 per mcf, a 24% increase in average oil
price received to $20.99 per b, a 102% increase in natural gas production
volume to 26 bcf and a 24% increase in oil production volume to 857,000 b. A
$0.10 per mcf change in the average natural gas price received in 1996 would
have resulted in a change in gross revenue, cash flow and pre-tax income of
$2.2 million. A $1.00 per barrel change in oil price would have resulted in a
change in gross revenue of approximately $0.7 million and a change in cash flow
and pre-tax income of a slightly lesser amount.
PRODUCTION, PRICING AND MARKETING
During 1996, Chieftain produced 26.3 bcf of gas, more than double the 13.0 bcf
produced the year before. Production averaged 71.8 mmcfd compared to 35.5 mmcfd
in 1995. Production in the Gulf of Mexico, which accounted for 87.5% of total
gas production, averaged 62.1 mmcfd and the North Sea contributed 9.0 mmcfd. At
year-end, our exit rates of production were 73.6 mmcfd from the Gulf and 13.4
mmcfd from the North Sea for a total of 87.0 mmcfd. The emphasis placed on
development activities during the last two years will continue to have a
positive effect on production throughout 1997.
The prices Chieftain received for Gulf of Mexico gas production were strong
during the first half of 1996, weakened during the summer months, and then rose
dramatically during the fall and early winter. Prices have risen steadily from
$1.34 per mcf (Texas Eastern Transmission gas price) in August 1995 when
Chieftain purchased a 50% interest in 57 Gulf blocks, including 76.3 bcf
of proved gas reserves, from Santa Fe Minerals, Inc. (SFM). North Sea prices
were weak during much of 1996, although they showed considerable strength
toward year-end. Chieftain's average U.S. gas price was $2.21 per mcf and the
U.K. average was $1.23 per mcf, for an overall weighted average of $2.09 per
mcf. The Company's U.K. production is free of royalties. Prices in both markets
remained strong in early 1997.
In the marketing of its gas production, Chieftain aims to capture the highest
prices possible on a daily basis from a variety of buyers in the Gulf coast
area. During 1996, we sold a majority of our volumes at the higher spot prices.
Chieftain produced 712,000 b of oil and 145,000 b of ngls, for a total of
857,000 b during 1996, an increase of 24% over total production of 693,000 b in
the prior year. Oil and ngls production averaged 2,340 bd, compared to 1,900 bd
in 1995. The Company's exit rate of production was 2,680 bd. We received an
average price of $20.99 per b, a 24% increase over 1995. In the last decade,
only in the year of the Iraqi invasion of Kuwait in 1990, were oil prices
higher. While 72% of our oil and ngls production comes from southeastern Utah,
the South Pass and Main Pass fields in the Gulf of Mexico also contributed to
the increase. We are optimistic about our oil production outlook for 1997, and
expect increases from Utah and the Gulf to continue.
The Company anticipates that 1997 natural gas and oil production volumes will
increase from 1996 levels as a result of the further development of producing
and non-producing properties in the Gulf of Mexico.
54
Page 35 of 37
Interest income from investment of working capital declined 45% to $2.1 million,
the result of a 14% decrease in investment yield and a 36% decline in average
amount invested. Such investments, in short-term certificates guaranteed by a
major Canadian bank, attach minimum risk.
Direct expenses increased 31% from 1995, resulting from the August 31, 1995
acquisition of producing properties from SFM and the November, 1995 commencement
of production from the Galahad field in the U.K. North Sea. Direct costs are
expected to continue at these higher levels in 1997.
Depletion and amortization expense increased 65%, the net result of an 8%
decline in depletion rate to $0.98 per mcfe and an 83% increase in production
volumes. Estimated costs of well abandonment and site restoration are included
in depletable costs.
CAPITAL RESOURCES AND LIQUIDITY
The following table summarizes cash provided from operating, financing and
investing activities for each of the past two years.
SOURCE AND USE OF CASH ($ in thousands)
Year ended December 31, 1996 1995
- ----------------------------------------------------
Cash provided from (used in ):
Operating activities $ 36,967 $ 12,352
Financing activities 47,657 (4,503)
Investing activities (52,750) (99,425)
-------------------------
Increase (decrease) in cash $ 31,874 $(91,576)
-------------------------
Cash generated from operating activities increased 199%, primarily as a result
of higher operating revenue.
Financing activities provided $46.6 million, net of issue costs, through the
sale of 2.97 million common shares at $16.50 per share in the first quarter of
1996. The exercise of employee stock options, primarily during the fourth
quarter, provided an additional $1.1 million.
Cash used in investing activities decreased 47% to $52.8 million in 1996.
Purchase of producing properties, net of sales, amounted to only $1.0 million
during 1996 compared with $54.7 million in 1995. Cash used in exploration and
development activities increased $7.0 million or 16% in 1996. Approximately 94%
of these expenditures were incurred on U.S. properties. The Company participated
in the purchase, with an average interest of 47%, of 40 offshore Gulf of Mexico
federal and state lease blocks in 1996 covering 186,000 acres resulting in a 57%
increase in net Gulf of Mexico acreage held. During 1996, the Company
participated in the drilling of 50 wells comprising 49 in the U.S. and one in
the U.K. North Sea.
The December 31, 1996 cash balance of $42.4 million was up $31.9 million from a
year earlier, primarily the result of the issuance of common shares described
above. The Company is debt free and has substantial borrowing capacity. Most of
the anticipated capital expenditure budget for 1997 is expected to be funded by
operating cash flow.
OUTLOOK
Increasing demand for natural gas in the U.S. resulted in substantial price
increases in 1996, encouraging increased exploration and development activity
and resulting in high levels of demand for drilling rigs and related services.
The Company expects to drill a number of potentially significant exploratory
prospects during 1997 and to continue development of presently producing
properties.
Development of gas production in several offshore Gulf of Mexico areas is
expected to provide increased cash flow from operations in 1997.
Capital expenditures in 1997 are expected to approximate $75.0 million of which
approximately 90% will be in the U.S.