SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-QSB
|X| QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
or
|_| TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE
ACT OF 1934
FOR THE QUARTER ENDED SEPTEMBER 30, 1996
Commission File Number 0-6580
PEASE OIL AND GAS COMPANY
(Name of small business issuer as specified in its charter)
Nevada 87-0285520
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification Number)
751 Horizon Court, Suite 203
Grand Junction, Colorado 81506
(Address of principal executive offices) (Zip code)
(970) 245-5917
(Issuer's telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
(None)
Securities registered pursuant to Section 12(g) of the Act:
Common Stock (Par Value $.10 Per Share) Series A Cumulative Convertible
Preferred Stock (Par Value $0.01 Per Share)
Title of Class
Indicate by check mark whether the issuer (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Exchange Act during the past
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
As of November 1, 1996 the issuer had 7,316,207 shares of its $0.10
par value Common Stock and 202,688 shares of its $0.01 par value Series A
Cumulative Convertible Preferred Stock issued and outstanding. As of November
1, 1996 the aggregate market value of the common stock held by non-affiliates
was $13,741,328. This calculation is based upon the closing sale price of
$2.1875 per share on November 1, 1996.
<PAGE>
TABLE OF CONTENTS
PAGE
NUMBER
PART I - Financial Information
Item 1. Financial Statements
Consolidated Balance Sheets 3-4
September 30, 1996 (unaudited)
and December 31, 1995
Consolidated Statements of Operations 5-6
For the Three Months
Ended September 30, 1996
(unaudited) and 1995 (unaudited)
Consolidated Statements of Operations 7-8
For the Nine Months Ended September 30, 1996
(unaudited) and 1995 (unaudited)
Consolidated Statements of Cash Flows 9-10
For the Nine Months Ended September 30, 1996
(unaudited) and 1995 (unaudited)
Notes to Consolidated Financial Statements 11-12
Item 2. Management's Discussion and Analysis of 13-27
Financial Condition and
Results of Operations
Part II - Other Information 28-30
Part III - Signatures 31
<PAGE>
PART 1 - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
PEASE OIL AND GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
September 30, December 31,
1996 1995
(unaudited)
CURRENT ASSETS:
Cash and equivalents .......................... $ 855,149 $ 677,275
Trade receivables ............................. 386,961 963,315
Inventory ..................................... 433,852 532,289
Prepaid expenses and other .................... 108,711 77,844
Common stock subscription receivable .......... -- 68,750
Total current assets ................... 1,784,673 2,319,473
OIL AND GAS PROPERTIES, at cost
(successful efforts method):
Undeveloped properties ........................ 377,606 377,606
Well-in-progress .............................. 851,164 --
Developed properties .......................... 9,046,711 9,149,516
Total oil and gas properties ........... 10,275,481 9,527,122
Less accumulated depreciation,
depletion and impairment ..................... (3,815,182) (3,608,917)
Net oil and gas properties ............. 6,460,299 5,918,205
PROPERTY, PLANT AND EQUIPMENT, at cost:
Gas plant ..................................... 4,099,285 4,095,227
Service equipment and rolling-stock ........... 869,757 855,025
Land, buildings and office equipment .......... 446,833 529,703
Total property, plant and equipment .... 5,415,875 5,479,955
Less accumulated depreciation ................. (1,273,904) (1,034,731)
Net property, plant and equipment ...... 4,141,971 4,445,224
ASSETS HELD FOR SALE ........................... -- 92,432
OTHER ASSETS:
Deferred debt issuance costs, net ............. 919,667 --
Non-compete agreements, net ................... 318,177 352,674
Other ......................................... 273,218 311,718
Total other assets ..................... 1,236,062 664,392
TOTAL ASSETS ................................... $ 13,898,005 $ 13,439,726
<PAGE>
PEASE OIL AND GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET (continued)
September 30, December 31,
1996 1995
(unaudited)
CURRENT LIABILITIES:
Current maturities of long-term debt .......... $ 58,885 $ 1,100,474
Accounts payable, trade:
Natural gas purchases ....................... 23,771 899,878
Other ....................................... 184,352 272,689
Accrued production taxes ...................... 242,717 303,287
Other accrued expenses ........................ 195,342 243,325
Total current liabilities .............. 705,067 2,819,653
LONG-TERM LIABILITIES:
Long-term debt, less current
maturities:
Convertible Debenture ....................... 3,415,000 --
Related parties ............................. 352,808 338,741
Other ....................................... 28,164 884,418
Accrued production taxes and other ............ 283,538 379,652
Total long-term liabilities ............ 4,079,510 1,602,811
STOCKHOLDERS' EQUITY:
Preferred Stock, par value $ .01 per
share, 2,000,000 shares authorized,
202,688 shares of Series A Cumulative
Convertible Preferred Stock issued and
outstanding, (liquidation preference
of $2,432,256 at September 30, 1996 .......... 2,027 2,027
Common Stock, par value $.10 per share,
25,000,000 shares authorized, 7,316,207
and 7,180,804 shares issued and outstanding,
respectively ................................. 731,621 718,081
Additional paid-in capital .................... 17,152,681 16,560,194
Accumulated deficit ........................... (8,772,901) (8,263,040)
Total stockholders' equity ............. 9,113,428 9,017,262
TOTAL LIABILITIES AND STOCKHOLDERS'
EQUITY ....................................... $ 13,898,005 $ 13,439,726
4
<PAGE>
PEASE OIL AND GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited)
For The Three Months
Ended September 30,
1996 1995
REVENUE:
Natural gas marketing and trading ............. $ -- $ 464,954
Oil and gas sales ............................. 594,730 514,043
Gas plant processing .......................... 175,389 351,369
Oil field services and supply ................. 163,477 220,591
Well administration and other income .......... 36,896 23,470
Total revenue ......................... 970,492 1,574,427
OPERATING COSTS AND EXPENSES:
Natural gas marketing and trading ............. -- 394,918
Oil and gas production ........................ 304,506 341,767
Gas plant processing .......................... 108,618 334,569
Oil field services and supply ................. 175,748 407,056
General and administrative .................... 345,926 270,344
Depreciation, depletion and
amortization ................................. 259,264 276,674
Dry hole, plugging and abandonment
of oil and gas properties .................... 79,453 --
Restructuring charges ......................... -- 33,573
Total operating costs and expenses ..... 1,273,515 2,058,901
LOSS FROM OPERATIONS ........................... (303,023) (484,474)
OTHER INCOME (EXPENSES):
Interest expense .............................. (137,128) (77,058)
(Loss)gain on sale of assets .................. (24,362) 34,227
Total other expenses, net .............. (161,490) (42,831)
LOSS BEFORE INCOME TAXES ....................... (464,513) (527,305)
INCOME TAXES
Current income tax benefit (expense) ......... -- (20,912)
Deferred income tax benefit .................. -- 181,900
Total income taxes ..................... -- 160,988
NET LOSS ....................................... $ (464,513) $ (366,317)
PEASE OIL AND GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited)
(continued)
For The Three Months
Ended September 30,
1996 1995
NET LOSS ..................................... $ (464,513) $ (366,317)
PREFERRED STOCK DIVIDENDS:
Declared .................................... -- --
In arrears .................................. (50,672) (50,672)
Total preferred stock dividends ...... (50,672) (50,672)
NET LOSS APPLICABLE TO COMMON
STOCKHOLDERS ................................ $ (515,185) $ (416,989)
NET LOSS PER COMMON SHARE .................... $ (0.07) $ (0.06)
WEIGHTED AVERAGE NUMBER OF COMMON
SHARES OUTSTANDING .......................... 7,310,000 7,018,000
6
<PAGE>
PEASE OIL AND GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited)
For The Nine Months
Ended September 30,
1996 1995
REVENUE:
Natural gas marketing and trading ....... $ 2,048,565 $ 2,510,474
Oil and gas sales ....................... 1,846,708 1,991,078
Gas plant processing .................... 531,069 918,571
Oil field services and supply ........... 469,612 1,144,155
Well administration and other income .... 102,468 71,196
Total revenue .................... 4,998,422 6,635,474
OPERATING COSTS AND EXPENSES:
Natural gas marketing and trading ....... 1,745,446 2,196,488
Oil and gas production .................. 952,060 1,242,359
Gas plant processing .................... 360,626 793,064
Oil field services and supply 416,425 1,245,566
General and administrative .............. 913,694 851,112
Depreciation, depletion and
amortization ........................... 807,583 971,880
Dry hole plugging and abandonment
of oil and gas properties .............. 79,762 5,291
Restructuring charges ................... -- 113,292
Total operating costs and expenses 5,275,596 7,419,052
LOSS FROM OPERATIONS ..................... (277,174) (783,578)
OTHER INCOME (EXPENSES):
Interest expense ........................ (266,383) (238,443)
(Loss) gain on sale of assets ........... (7,713) 85,681
Total other expenses, net ........ (274,096) (152,762)
LOSS BEFORE INCOME TAXES ................. (551,270) (936,340)
INCOME TAXES
Current income tax benefit (expense) .... 41,409 (20,912)
Deferred income tax benefit ............. -- 323,000
Total income taxes ............... 41,409 302,088
NET LOSS ................................. $ (509,861) $ (634,252)
<PAGE>
PEASE OIL AND GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited)
(continued)
For The Nine Months
Ended September 30,
1996 1995
NET LOSS ..................................... $ (509,861) $ (634,252)
PREFERRED STOCK DIVIDENDS:
Declared .................................... -- --
In arrears .................................. (152,016) (152,016)
Converted in tender offer ................... -- (117,000)
Total preferred stock dividends ...... (152,016) (269,016)
Loss before non-cash inducement ............. (661,877) (903,268)
Non-cash inducement in tender offer ......... -- (1,523,906)
NET LOSS APPLICABLE TO COMMON
STOCKHOLDERS ................................ $ (661,877) $(2,427,174)
NET LOSS PER COMMON SHARE
Before non-cash inducement .................. $ (0.09) $ (0.16)
Non-cash inducement ......................... -- (0.26)
Net loss per common share ............ $ (0.09) $ (0.42)
WEIGHTED AVERAGE NUMBER OF COMMON SHARES
OUTSTANDING ............................... 7,254,000 5,820,000
<PAGE>
PEASE OIL AND GAS COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited)
For The Nine Months
Ended September 30,
1996 1995
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss ...................................... $ (509,861) $ (634,252)
Adjustments to reconcile net loss
to net cash provided by
operating activities:
Provision for depreciation
and depletion ............................ 773,086 899,880
Amortization of deferred debt issuance
costs and intangible assets .......... 113,936 86,429
Provision for bad debts .................... 21,497 15,078
Deferred income taxes ...................... -- (323,000)
Loss (gain) on sale of property and
equipment ................................ 7,713 (85,681)
Issuance of stock for services ............. 61,027 86,242
Other ...................................... (40,007) --
Changes in operating assets
and liabilities:
(Increase) decrease in:
Trade receivables ........................... 554,857 847,243
Inventory ................................... 98,437 217,872
Prepaid expenses and other assets ........... (32,367) 11,652
Increase (decrease) in:
Accounts payable ............................ (964,444) (625,180)
Accrued expenses ............................ (190,600) (267,646)
Net cash (used in) provided by
operating activities ...................... (106,726) 228,637
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures for property
and equipment ................................ (1,072,942) (313,374)
Proceeds from sale of property, plant
and equipment ................................ 145,740 529,444
Investments in Certificate of Deposit ......... --
Proceeds from redemption of
certificate of deposit ...................... 40,000 34,500
Net cash (used in) provided by
investing activities ...................... (887,202) 250,570
<PAGE>
PEASE OIL AND GAS COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
For The Nine Months
Ended September 30,
1996 1995
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term debt ................ 3,415,000 --
Repayment of long-term debt ................. (1,787,842) (688,636)
Net proceeds from issuance of
Common Stock ............................... 68,750 220,188
Debt issuance costs ......................... (524,106) --
Net cash (used in) provided by
financing activities .................... 1,171,802 (468,448)
INCREASE (DECREASE) IN CASH AND
EQUIVALENTS ............................... 177,874 10,759
CASH AND EQUIVALENTS, beginning
of period ................................. 677,275 532,916
CASH AND EQUIVALENTS, end of period .......... $ 855,149 $ 543,675
SUPPLEMENTAL DISCLOSURE OF CASH FLOW
INFORMATION:
Cash paid for interest ..................... $ 134,123 $ 211,936
Cash paid for income taxes ................. $ -- $ 20,912
SUPPLEMENTAL DISCLOSURE OF NON-CASH
INVESTING AND FINANCING ACTIVITIES:
Estimated fair value of warrants
granted and capitalized as
debt issuance costs ......................... $ 475,000 $ --
Conversion of long-term debt into
common stock ................................ $ 70,000 $ --
Issuance of stock for services ............... $ 61,027 $ 86,242
Acquisition of oil and gas
properties for stock ........................ $ -- $ 59,922
Long-term debt incurred
for purchase of vehicles .................... $ -- $ 24,992
<PAGE>
PEASE OIL AND GAS COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 - Basis of Presentation:
The accompanying unaudited condensed consolidated financial statements
have been prepared in accordance with generally accepted accounting
principles for interim financial information. They do not include all
information and notes required by generally accepted accounting
principles for complete financial statements. However, except as
disclosed herein, there has been no material change in the information
disclosed in the notes to consolidated financial statements included in
the Annual Report on Form 10-KSB of Pease Oil and Gas Company (the
Company) for the year ended December 31, 1995. In the opinion of
Management, all adjustments (consisting of normal recurring accruals)
considered necessary for a fair presentation have been included.
Operating results for the periods presented are not necessarily
indicative of the results that may be expected for the full year.
The accounting policies followed by the Company are set forth in Note 1
to the Company's financial statements in Form 10-KSB for the year ended
December 31, 1995. It is suggested that these financial statements be
read in conjunction with the financial statements and notes included in
the Form 10-KSB.
Note 2 - Private Placement:
In April 1996, the Company initiated a private placement to sell up to
$5,000,000 of collateralized convertible debentures in the form of
"Units". The private placement is more thoroughly discussed later in
Managements Discussion and Analysis under the caption Liquidity and
Capital Resources.
Note 3 - Deferred Debt Issuance Costs:
In connection with the warrants issued to Beta Capital Group, Inc. in
March 1996 to purchase one million shares of the Company's common stock
at $ .75 per share, (which are more fully described in the Annual Report
on Form 10-KSB), the Company recorded the estimated fair value of the
warrants of $200,000 as a debt issuance cost. In connection with the
private placement discussed in Note 2, the Company will issue warrants
giving the holder the right to purchase a total of 1,707,500 shares of
common stock for $1.25 per share. These warrants are attached to the
convertible debentures sold through September 30, 1996. As of September
30, 1996 the Company recorded the estimated fair value of the warrants of
$275,000 as a debt issuance cost. The debt issuance costs are being
amortized over the term of the convertible debentures discussed in Note
2. The estimated fair value of the warrants was determined under the
valuation methodology prescribed in Statement of Financial Accounting
Standards No. 123 and the consensus reached in issue No. 96-3 of the
<PAGE>
PEASE OIL AND GAS COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Emerging Issues Task Force.
In addition, all other direct costs incurred in connection with the
private placement have been capitalized and are being amortized over the
term of the convertible debentures.
Note 4 - Income Taxes:
The total income tax expense or benefit differs from the amount that
would be provided by applying the statutory U.S. Federal income tax rate
to income or loss before taxes primarily due to the utilization of net
operating loss carryforwards, tax credit carryforwards, and percentage
depletion carryforwards.
A deferred income tax benefit is not recorded in the 1996 financial
statements since the Company provided a valuation allowance for the net
operating loss carryforwards generated in 1996.
The income tax benefit of $41,509 recorded in 1996 is related to a net
operating loss carry back that was filed with the Internal Revenue
Service in March 1996.
Note 5 - Reclassifications:
Certain reclassifications have been made to the 1995 financial statements
to conform to the presentation in 1996. The reclassifications had no
effect on the 1995 net loss.
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS
SELECTED FINANCIAL DATA
<TABLE>
<CAPTION>
Statement of Operations Data: ..........................................................................For the Three Months
Ended September 30,
1996 1995
Natural gas marketing and trading ................................................................$ -- $ 464,954
Oil and gas sales ................................................................................ 594,730 514,043
Gas plant processing revenue ..................................................................... 175,389 351,369
Total revenue .................................................................................... 970,492 1,574,427
Net loss ...................................................................................... (464,513) (366,317)
Preferred Stock Dividends:
Declared ....................................................................................... -- --
In arrears ................................................................................... (50,672) (50,672)
Net loss applicable
to common stockholders ........................................................................$ (515,185) $ (416,989)
Per Share Data:
Net loss per common share ........................................................................$ (0.07) $ (0.06)
Cash dividends declared per
common share ...................................................................................$ -- $ --
For the Nine Months
Ended September 30,
1996 1995
Natural gas marketing and trading ................................................................$ 2,048,565 $ 2,510,474
Oil and gas sales ................................................................................ 1,846,708 1,991,078
Gas plant processing revenue ..................................................................... 531,069 918,571
Total revenue .................................................................................... 4,998,422 6,635,474
Net loss ....................................................................................... (509,861) (634,252)
Preferred stock dividends:
Declared ....................................................................................... -- --
In arrears ..................................................................................... (152,016) (152,016)
Converted in tender offer ...................................................................... -- (117,000)
Non-cash inducement charge to
convert preferred stock to
common stock ................................................................................... -- (1,523,906)
Net loss applicable
<S> <C> <C>
to common stockholders .........................................................................$ (661,877) $(2,427,174)
</TABLE>
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
<TABLE>
<CAPTION>
Per Share Data: For the Nine Months
Ended September 30,
1996 1995
Before non-cash inducement charge .......................................................... (0.09) (0.16)
Effect of non-cash inducement charge ....................................................... -- (0.26)
Net loss per
common share ...................................................................... $ (0.09) $ (0.42)
Cash dividends declared per common share$ .................................................. -- $ --
Balance Sheet Data: ........................................................................ As of
9/30/96 12/31/95
Working capital (deficit) .................................................................. $ 1,079,606 $ (500,180)
<S> <C> <C>
Total assets ............................................................................... $ 13,898,005 $ 13,439,726
Long-term liabilities ...................................................................... $ 4,079,510 $ 1,602,811
Stockholder's equity ....................................................................... $ 9,113,428 $ 9,017,262
</TABLE>
Liquidity and Capital Resources
At September 30, 1996, the Company's cash balance was $855,149 with a
positive working capital position of $1,079,606, compared to a cash
balance of $677,275 and a working capital deficit of $500,180 at December
31, 1995. The significant improvement in the Company's working capital
position is directly related to: a) the proceeds received from the
private placement of convertible debentures that is discussed more
thoroughly later in this section; and b) the repayment of the entire
balance of outstanding debt with Colorado National Bank (of which
$944,644 was classified as a current liability at December 31, 1995).
The change in the Company's cash balance is summarized as follows:
Cash balance at December 31, 1995 ........................ $ 677,275
Cash used in operating activities ........................ (106,726)
Capital expenditures ..................................... (1,072,942)
Proceeds from the sale of property
and equipment .......................................... 145,740
Redemption of certificate of deposit ..................... 40,000
Payments on long-term debt ............................... (1,787,842)
Net proceeds from issuance of
convertible debt ....................................... 2,890,894
Proceeds from common stock
subscription receivable ................................ 68,750
Cash balance at September 30, 1996 ....................... $ 855,149
The success of the Company is largely dependent on its ability to raise
additional debt or equity capital to fund future drilling and development
activities. Since the acquisition of Skaer Enterprises Inc. ("Skaer")in
August of 1993, the Company has suffered from undercapitalization,
lacking the necessary funds to properly exploit the assets acquired from
Skaer or explore other opportunities outside of its existing asset base.
Therefore, management has diligently pursued various avenues in search of
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
a strategic partner, or partners, to facilitate the Company's growth.
As a result of these efforts, in March 1996, the Company entered into a
consulting agreement with Beta Capital Group, Inc. ("Beta"). Beta is
located in Newport Beach, California and specializes in emerging
companies that have both capital needs and market support requirements.
Steve Antry, Beta's President, is from a third generation oil and gas
background, was an officer of Benton Oil and Gas between 1989 and 1992
and marketed Swift Energy's Income Funds between 1987 and 1989. The
Company joined forces with Beta in an effort to raise significant debt
and/or equity capital.
For instance, in April 1996 the Company initiated a private placement to
sell up to $5,000,000 of collateralized convertible debentures in the
form of "Units". Each Unit consists of one $50,000 five-year 10%
collaterized convertible debenture and warrants to purchase 25,000 shares
of the Company's common stock at $1.25 per share. As of September 30,
1996, the Company had sold approximately 68 units generating net proceeds
of $2,890,894. In November 1996 the offering was completed and the
Company was successful in selling the entire $5,000,000 generating net
cash proceeds of $4,300,000. The debentures will be collaterized by a
first priority interest in certain oil and gas properties owned and
operated by the Company. The debentures will be convertible, at the
holders option, into the Company's common stock for $3.00 per share and
may be redeemed by the Company, in whole or in part, beginning at a
premium of 110% of the original principal amount and are subject to
adjustment beginning on April 25, 1999. Interest on the debentures is
payable quarterly commencing on September 30, 1996 and the entire
principal balance will be due on April 15, 2001. The warrants will be
exercisable commencing on August 1, 1996 and will expire on July 31,
2001. The Company will be entitled to call the warrants at any time
commencing 90 days after issuance at a price of $0.10 per warrant. The
Company has agreed to use its best efforts to register for resale: (1)
the shares of common stock into which the debentures may be converted;
(2) the warrants; and (3) the shares of common stock issuable upon
exercise of the warrants by including such securities in a registration
statement on an appropriate form filed with the United States Securities
and Exchange Commission within 60 days of terminating the private
placement.
Through September 30, 1996, the net proceeds generated from the private
placement were used to: a) pay off the entire balance of the outstanding
debt with Colorado National Bank; b) fund the drilling of one horizontal
well in Loveland Field, Colorado (which is discussed later in this
section under the caption Capital Resources); c) fund the cost of
participating in a deep wildcat well in South Louisiana (this well was
dry and is discussed more thoroughly in the Results of Operations section
under the caption Dry Holes, Plugging and Abandonment); and d) general
working capital needs. The remaining proceeds generated from these
efforts will be used for general working capital needs, and/or drilling
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
and development activities.
The completion of the private placement has significantly improved the
health of the Company's balance sheet and provided the funds necessary to
pursue additional drilling development activities on a limited basis. In
order to provide a means for even further growth and opportunities, the
capital raising discussed above is only the first of a series of
financing's the Company is contemplating to seek out with Beta's
assistance. Should future capital raising efforts be successful, the
Company intends to pursue a strategic course of action to diversify its
assets outside of the Rocky Mountain region. For instance, during the
past several months, the Company has been working on a relationship with
National Energy Group, Inc. ("NEG"), another publicly held Company
headquartered in Dallas, Texas, and Sandefer Oil & Gas, Inc., a group of
geologists and geophysicists that work closely with NEG whose sole
purpose is to generate Gulf Coast, South Louisiana, and other lucrative
prospects, negotiating the possibility of participating in several of
their drilling prospects and development activities. As a result of
these efforts, the Company elected to participate in a deep wildcat well
in South Louisiana that was drilled in August 1996 (unfortunately this
well was dry and is discussed more thoroughly in the Results of
Operations section under the caption Dry Holes, Plugging and Abandonment)
and has committed to participate in an additional natural gas prospect
in Jefferson Davis Parish, Louisiana that is scheduled to commence
drilling activities in December 1996. In addition, the Company has
reached an informal agreement with NEG to participate in an additional 8
to 10 projects over the next 12 to 18 months. This informal agreement
for the additional projects is subject to several contingencies
including, but not limited to, successfully negotiating and executing
formal agreements to participate, due diligence on the specific projects
and raising the necessary capital to fund the participations.
Management of the Company believes the current working capital position
and its current cash flows will support continued operations for at least
12 months (exclusive of drilling and development activities). Beyond
that, the success of the Company is and will be dependent on: a) its
ability to successfully generate additional debt and/or equity financing
to invest in additional oil and gas drilling and development activities;
and b) the ultimate success of those activities.
Capital Expenditures
During the first nine months of 1996, the Company capitalized and
invested $1,072,942 in property and equipment as follows:
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
Oil and Gas Properties:
Horizontal drilling (well-in-process) .................... $ 851,164
Perforating and fracing 3 wells
in Loveland Field ....................................... 95,473
Workovers of existing properties ......................... 96,487
Total Oil and Gas properties ...................... 1,043,124
Service Equipment and Rolling Stock ........................ 18,645
Office Equipment ........................................... 7,115
Gas Plant facility ......................................... 4,058
$1,072,942
As of September 30, 1996, the Company was in process of completing the
first "double-stacked" horizontal well in Colorado. A "double-stacked"
horizontal well consists of drilling two separate horizontal wells, or
legs, in two separate geologic formations from a single well bore. This
technology has been used extensively in the Austin Chalk Formation in
Texas and Pease Oil and Gas Company is the first to bring this technology
to Colorado. The drilling rig was released on July 22, 1996 and the
first production was attempted in August 1996. After a few days of
initial production, the well experienced several mechanical problems
down-hole. The Company is currently attempting to correct these problems
but at this time it is uncertain whether or not the well will be
commercially productive.
RESULTS OF OPERATIONS
Overview
The Company's largest source of operating income is from the sale of
produced oil, gas, and natural gas liquids. Therefore, the level of the
Company's revenues and earnings are affected by prices at which natural
gas, oil and natural gas liquids are sold. As a result, the Company's
operating results for any prior period are not necessarily indicative of
future operating results because of the fluctuations in natural gas, oil
and natural gas liquid prices and the lack of predictability of those
fluctuations as well as changes in production levels.
Early in 1995, the Company initiated a corporate restructuring that
focused on: eliminating areas of its business that were losing money;
reducing operating costs; increasing efficiencies; and generating funds
for working capital. These initiatives included but were not limited to:
1) Downsizing of the Company's oil field service and supply operations.
As is more fully discussed later in this section under their
respective captions, the Company's oil field service and oil field
supply operating margins have been historically low and even
unprofitable. The burden of these low margins or operating losses
have been compounded with the risks inherent in these operations,
the capital investment required to maintain and operate, and the
uncertainty of the future prospects in light of the overall decrease
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
in natural gas prices and drilling activity. Downsizing these
operations is not expected to have a material negative effect on the
Company's overall results of operations.
2) Closing the administrative office in Denver, Colorado which
eliminated annual payroll costs associated with its accounting and
administrative staff of approximately $140,000. The Company also
expects savings of an additional $60,000 annually from costs
duplicated as a result of the Company maintaining two administrative
offices (such as rent, telephone, insurance and office supplies).
Prior to the restructuring initiatives discussed above, the Company also
addressed one of the single largest cash demands burdening the Company -
the preferred stock dividend. In light of the Company's continuing
operating losses, deteriorating working capital position, and belief that
the Company's primary lender would not approve a payment thereon, the
Company's Board of Directors voted in December 1994 to not declare the
quarterly cash dividend to holders of the Company's Series A Cumulative
Convertible Preferred Stock ("Preferred Stock") for the fourth quarter of
1994. In March 1995, the Board of Directors voted to suspend payment on
any future Preferred Stock dividends indefinitely. However, pursuant to
the terms underlying the Preferred Stock, dividends will continue to
accrue on an monthly basis. Dividends paid in the future, if any, on the
Preferred stock will be contingent on many factors, including but not
limited to, whether or not a dividend can be justified through the cash
flow and earnings generated from future operations.
Since the future payment of Preferred Stock dividends was so uncertain,
and the Company wanted to preserve its working capital, in January 1995,
the Company extended a tender offer to the Preferred stockholders. On
February 28, 1995, the Company completed the tender offer to its
Preferred Stockholders whereby the holders of the Company's Preferred
Stock were given the opportunity to convert each share of Preferred Stock
and all then accrued and undeclared dividends (including the full
dividend for the quarters ended December 31, 1995 and March 31, 1995)
into 4.5 shares of the Company's Common Stock and warrants to purchase
2.625 shares of Common Stock at $5.00 per share through December 31, 1996
and $6.00 per share through August 13, 1998, (the date the warrants
expire). As a result of the tender offer 933,492 shares of the Preferred
stock converted into 4,200,716 shares of the Company's Common Stock and
warrants to purchase 2,450,417 shares of Common stock. In addition,
21,600 shares of Preferred Stock converted into 56,739 shares of Common
Stock prior to the tender offer. Accordingly, as of September 30, 1996
there remains 202,688 shares of Preferred Stock outstanding. These
events substantially changed the capital structure of the Company and
alleviated the burden of approximately 83% of Preferred Stock dividends.
These restructuring initiatives consolidated and focused the Company's
operations such that it is operating very efficiently today. The
consideration of the restructuring is an important component when
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
comparing the results of operations between the two periods presented.
Total Revenue
Total Revenue from all operations was as follows:
<TABLE>
<CAPTION>
For the Three Months Ended September 30,
1996 1995
Amount % Amount %
Natural gas marketing
and trading .................................................................. $ -- -% $ 464,954 30%
Oil and gas sales ....................................................................... 594,730 61% 514,043 33%
Gas plant processing .................................................................... 175,389 18% 351,369 22%
Oil field services
and supply ............................................................................ 163,477 17% 220,591 14%
Well administration
and other income ...................................................................... 36,896 4% 23,470 1%
Total revenue ................................................................ $ 970,492 100% $1,574,427 100%
For the Nine Months Ended September 30,
1996 1995
Amount % Amount %
Natural gas marketing
and trading ...........................................................................$2,048,565 41% $2,510,474 38%
Oil and gas sales ....................................................................... 1,846,708 37% 1,991,078 30%
Gas plant processing .................................................................... 531,069 11% 918,571 14%
Oil field services/supply ............................................................... 469,612 9% 1,144,155 17%
Well admin. & other ..................................................................... 102,468 2% 71,196 1%
<S> <C> <C> <C> <C>
Total revenue ................................................................$4,998,422 100% 6,635,474 100%
</TABLE>
The decrease in total revenue is a result of the Company: a) losing its
natural gas marketing and trading revenues effective July 1, 1996; b) not
processing any third party gas through its gas plant facility in 1996; c)
a decrease in oil and gas production; and d) a loss of revenue resulting
from the Company's downsizing of its service and supply operations.
These circumstances, along with any known trends or changes that effect
revenue on a line-by-line basis, are discussed in the following
paragraphs under their respective captions.
Natural Gas Marketing and Trading
The Company had a "take-or-pay" contract with Public Service Company of
Colorado ("PSCo") which called for PSCo to purchase from the Company a
minimum of 2.92 billion cubic feet ("BCF") of natural gas annually. The
price paid the Company by PSCo was based on the Colorado Interstate Gas
Commission's "spot" price, plus a fixed price bonus. The natural gas
marketing and trading activities represent natural gas that was purchased
from third parties and sold to PSCo under the terms of the contract.
Operating statistics for the Company's Marketing and Trading Activities
for the periods presented are as follows:
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
<TABLE>
<CAPTION>
Ended September 30,
1996 1995
Total Volume Sold (Mcf) .............................................................. -- 354,937
Average Price ........................................................................ $ -- $ 1.31
Total Revenue ............................................................... $ -- $ 464,954
Costs ................................................................................ -- (394,918)
Gross Margin ................................................................ $ -- $ 70,036
For the Nine Months
Ended September 30,
1996 1995
Total Volume Sold (Mcf) .............................................................. 1,223,756 1,728,621
Average Price ........................................................................ $ 1.67 $ 1.45
Total Revenue ............................................................... $ 2,048,565 $ 2,510,474
<S> <C> <C>
Costs ................................................................................ (1,745,446) (2,196,488)
Gross Margin ................................................................ $ 303,119 $ 243,950
</TABLE>
The contract with PSCo expired on June 30, 1996. Historically, the price
paid by PSCo under that contract was at a premium above the market and
therefore allowed for the marketing and trading activities. Although the
Company has been negotiating with PSCo to renew the contract, no formal
agreement has been reached as of the date of this report. Consequently,
no marketing and trading revenues have been generated subsequent to June
30, 1996. With the increasing competition fostering within all phases of
the natural gas industry, it is unlikely that the contract will be
renewed at an above market premium, if at all, and the Company's
Marketing and Trading activities will probably disappear. Since the
gross margin represents the net cash flow and income generated from this
activity, the loss of this premium contract price will have a material
and negative impact on the Company's future operations.
Oil and Gas
Operating statistics for oil and gas production for the periods presented
are as follows:
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
<TABLE>
<CAPTION>
For the Three Months
Ended September 30,
1996 1995
Production:
Oil (bbls) ......................................................................... 23,600 24,900
Gas (Mcf) .......................................................................... 98,700 111,100
BOE (6:1) .......................................................................... 40,000 43,400
Average Collected Price:
Oil (per bbl) ...................................................................... $ 21.10 $ 15.95
Gas (per Mcf) ...................................................................... $ 0.98 $ 1.05
Per BOE (6:1) ...................................................................... $ 14.85 $ 11.84
Gross Margin:
Revenue ............................................................................ $ 594,730 $ 514,043
Operating costs .................................................................... (304,506) (341,767)
Gross Margin ..................................................................... $ 290,224 $ 172,276
Gross Margin Percent ............................................................. 49% 34%
For the Three Months
Ended September 30,
1996 1995
Average Production Costs per
BOE before DD&A ........................................................................... $ 7.60 $ 7.87
DD&A per BOE ................................................................................ 3.59 3.46
Total Costs of Production
per BOE .......................................................................... $ 11.19 $ 11.33
Change in oil and gas revenue
attributed to:
Production ......................................................................... $ ( 33,930)
Price .............................................................................. 114,617
80,687
For the Nine Months
Ended September 30,
1996 1995
Production:
Oil (bbls) ......................................................................... 76,500 92,000
Gas (Mcf) .......................................................................... 316,500 356,000
BOE (6:1) .......................................................................... 129,300 151,300
Average Collected Price:
Oil (per bbl) ...................................................................... $ 19.48 $ 16.89
Gas (per Mcf) ...................................................................... $ 1.12 $ 1.23
Per BOE (6:1) ...................................................................... $ 14.28 $ 13.16
Gross Margin:
<S> <C> <C>
Revenue ............................................................................ $ 1,846,708 $ 1,991,078
Operating costs .................................................................... (952,060) (1,242,359)
Gross Margin ..................................................................... $ 894,648 $ 748,719
Gross Margin Percent ............................................................. 48% 38%
</TABLE>
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
Average Production Costs per
BOE before DD&A ........................... $ 7.36 $ 8.21
DD&A per BOE ................................ 3.54 3.60
Total Costs of Production
per BOE .......................... $ 10.90 $ 11.81
Change in oil and gas revenue
attributed to:
Production ......................... $ (309,655)
Price .............................. 165,285
(144,370)
Most of the decrease in oil and gas revenue and the corresponding costs
were caused by a decrease in production which can be attributed to the
following: 1) the sale of several marginal, uneconomic, or nonstrategic
oil and gas properties in 1995 and 1996 (see divested production table
below); and 2) to a much lesser extent the natural decline inherent of
oil and gas wells. Both these circumstances were offset to a certain
extent by an increase in price.
The production included on the above tables and associated with the wells
sold during 1995 and 1996 is as follows:
For the Three Months For the Nine Months
Ended September 30, Ended September 30,
Divested Production 1996 1995 1996 1995
Oil (bbls) - 1,400 2,400 14,000
Gas (Mcf) - 300 - -
BOE (6:1) - 1,500 2,400 14,000
Gas Plant Processing Revenues
This category accounts for the natural gas processed and the natural gas
liquids extracted and sold by the Gas Plant facility.
Operating statistics for the periods presented are as follows:
For the Three Months
Ended September 30,
1996 1995
Production: ........................................ Volumes Volumes
Natural Gas Processed (Mcf)
From Company owned wells ................ 89,200 79,200
Third party gas ......................... -- 28,500
Total gas processed .............. 89,200 107,700
B-G Mix (gallons) ....................... 224,000 419,900
Propane (gallons) ....................... 166,600 300,400
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
Gross Margin: ......................................... Amount Amount
Revenue .................................$ 175,389 $ 351,369
Costs ................................... (108,618) (334,569)
Gross Margin ............$ 66,771 $ 16,800
Gross Margin Percent .... 38% 5%
For the Nine Months
Ended September 30,
1996 1995
Production: ......................................... Volumes Volumes
Natural Gas Processed (Mcf)
From Company owned wells ................. 274,700 260,300
Third party gas .......................... -- 73,500
Total gas processed ............... 274,700 333,800
B-G Mix (gallons) ............................ 685,300 1,093,500
Propane (gallons) ............................ 515,700 852,300
Gross Margin: ......................................... Amount Amount
Revenue ................................. $ 531,069 $ 918,571
Costs ................................... (360,626) (793,064)
Gross Margin .................... $ 170,443 $ 125,507
Gross Margin Percent ............ 32% 14%
Costs associated with the Gas Plant operations consist of both semi-fixed
and variable costs. The semi-fixed costs consist of direct payroll,
utilities, operating supplies, general and administrative costs, and
other items necessary in the day-to-day operations. The semi-fixed costs
average approximately $435,000 annually and are not expected to change
significantly regardless of the volume processed by the Gas Plant. The
variable costs consist primarily of purchased gas, plant fuel and shrink,
lubricants, repair and maintenance, and costs of gas marketing and
buying. These costs are generally a direct function of the volume
processed by the Gas Plant and are expected to either increase or
decrease proportionately with the corresponding plant production. The
costs in 1995 increased both in amount and as a percentage of revenue,
when compared to 1996, as a result of the Company purchasing and
processing third party gas between February 1995 and September 1995.
Currently, the gas processed by the Gas Plant facility is from wells the
Company owned. Accordingly, the costs, as a percentage of revenue, have
decreased in 1996.
The decrease in processing volumes and revenue during 1996 as compared to
the same periods in 1995, can be substantially attributed to the Company
purchased and processed third party gas between February 1995 and
September 1995. In October 1995 the Company stopped processing third
party gas to correct some operational problems. The operational problems
have been corrected and the plant is now running more efficiently and
effectively than it has in the past. However, with the increased
competition to process natural gas and the historically low gas prices
prevalent in the Rocky Mountain Region, the Company has not been able to
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
purchase third party gas at an economical rate. These factors along with
the declining rig count in the DJ Basin where the gas plant facility is
located, and the increasing competitive environment in the natural gas
market, it is uncertain at this time if the Company will be able to
compete with other gas plants and purchasers of natural gas in its market
area. Accordingly, it cannot be determined at this time when, or if, the
Company will process any additional third party gas.
As stated above, the Company currently processes natural gas exclusively
from wells owned or operated by the Company. Given the extremely
competitive environment in the DJ Basin where the gas plant facility is
located, management is exploring the possibility of increasing the
Company's net cash flow by entering into a gas processing agreement with
a third party. Under this scenario, the current operations at the gas
plant facility would be shut down and the gas currently processed by the
plant would be sold to a third party. Although no formal decision has
been made, this possibility is being disclosed since such a decision may
ultimately impact the carrying value of the gas plant facility under
Statement of Financial Accounting Standards No. 121, "Accounting for the
Impairment of Long-Lived Assets." As of September 30, 1996 the net
carrying value of the gas plant facility was approximately $3.4 million.
It is not certain at this time if a decision of this nature will
ultimately be made, and if so, if that decision would ultimate impact the
carrying value of the gas plant facility. However, should a
determination be made in the future that the carrying value of the gas
plant facility will not be realized, a non-cash impairment charge may
need to be recognized as prescribed under SFAS No. 121, which could have
a material negative impact on the Company's future results of operations
and balance sheet.
Oil Field Services and Oil Field Supply
Operating statistics for the Company's oil field service and supply
operations for the periods presented are as follows:
<TABLE>
Service and Supply Operations
For the Three Months Ended September 30,
1996 1995
<CAPTION>
Revenue .................................................................................... $ 163,477 $ 220,591
Costs ...................................................................................... (175,748) (407,056)
Net Operating
Income (Loss) ............................................................................ $ (12,271) $ (186,465)
Service and Supply Operations
For the Nine Months Ended September 30,
1996 1995
Revenue .................................................................................... $ 469,612 $ 1,114,155
<S> <C> <C>
Costs ...................................................................................... (416,425) (1,245,566)
Net Operating
Income (Loss) ............................................................................ $ 53,187 $ (101,411)
</TABLE>
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
The decrease in revenue from the service and supply operations is
directly related to the restructuring initiatives conducted in 1995. A
summary of the restructuring for both operations is discussed in the
following paragraphs.
Service Operations
Historically, the Company's service business has operated out of two
locations - Loveland and Sterling Colorado. The services provided
included: servicing rigs, vacuum trucks, roustabout services, and hot
oiling services. The operations serviced both the Company's needs and
those of third parties. The restructuring was focused on reducing the
service rig, vacuum truck, and roustabout operations to a point where the
Company can service its own needs efficiently and at the lowest possible
cost, while performing only limited services for third parties. Any
services of this type to third parties will be limited to those
circumstances when the equipment and man power is not needed in the
Company's operations. The Company did retain its hot oiler fleet
(consisting of three trucks) and intends to continue providing this
service to third parties on a full time basis.
Supply Operations
Historically, the Company's supply business has operated out of two
locations - Loveland and Sterling, Colorado. The restructuring was
focused on consolidating the operations to one location (Loveland,
Colorado), eliminating duplicate costs and ultimately reducing the amount
of inventory.
Although management expects total revenues from the service and supply
operations to decrease approximately 50% on an annual basis, and
therefore generate approximately $600,000 to $700,000 annually, it is not
expected to have a material negative effect on the Company's overall
results of operations in light of the historically low margins.
Well Administration and Other Income
This revenue primarily represents the revenue generated by the Company
for operating oil and gas properties. There has been no significant
change in the average monthly revenue between 1996 and 1995 and
Management does not expect any significant change in the future.
General and Administrative Expenses
Although many of the costs included in general and administrative costs
decreased during the periods presented as a result of the restructuring
instituted in 1995, total general and administrative costs increased as
a result of the consulting contract entered into with Beta in March 1996.
Fees and reimbursed expenses incurred by the Company in connection with
Beta's contract were $86,895 and $166,811 for the three months ended
September 30, 1996 and the nine months ended September 30, 1996,
respectively.
<PAGE>
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS, continued
Depreciation, Depletion and Amortization
Depreciation, Depletion and Amortization ("DD&A") for the periods
presented by cost center consisted of the following:
<TABLE>
For the Three Months
Ended September 30,
<CAPTION>
1996 1995
Oil and Gas Properties ............................................................................... $143,691 $150,132
Gas Plant Operations ................................................................................. 60,188 60,503
Service and Supply Operations ........................................................................ 34,420 31,213
Furniture and Fixtures ............................................................................... 9,465 10,826
Non-Compete Agreements ............................................................................... 11,500 24,000
<S> <C> <C>
Total .............................................................................................. $259,264 $276,974
For the Nine Months
Ended September 30,
1996 1995
Oil and Gas Properties ............................................................................... $458,060 $544,804
Gas Plant Operations ................................................................................. 180,401 178,021
Service and Supply Operations ........................................................................ 101,648 142,807
Furniture and Fixtures ............................................................................... 32,977 34,248
Non-Compete Agreements ............................................................................... 34,497 72,000
Total .............................................................................................. $807,583 $971,880
</TABLE>
As previously disclosed in this section under the caption Oil and Gas,
DD&A per BOE for oil and gas properties has remained relatively constant
for the periods presented. The decrease in DD&A for the Service and
Supply Operations for the nine months ends September 30, 1996 can be
attributed to the disposition of the corresponding assets during the
restructuring of the Service and Supply operations. The decrease in the
amortization of the Non-compete Agreements is because one agreement with
an original cost basis of $100,000, which was being amortized over a 24
month period, became fully amortized in 1995.
Dry Hole, Plugging and Abandonment
Reflective of the Company's determination to diversify its assets outside
of the Rocky Mountain Region, in August 1996 the Company elected to
participate in a deep wildcat prospect in South Louisiana with National
Energy Group, Inc. The well was drilled in excess of 14,000 feet and the
logs indicated some excellent shows. Unfortunately it appears the
targeted formation either did not receive a hydrocarbon charge or it had
passed through the formation. Accordingly the well was plugged and
abandoned. The Company's cost for this dry hole was $75,000.
The remaining costs in 1996 as well as all the costs in 1995 relate to
plugging and abandonment of a few depleted wells in the Rocky Mountain
Region.
<PAGE>
Restructuring Charges
The restructuring charges in 1995 were directly related to the
initiatives in 1995 as previously discussed. Those costs consisted
primarily of severance pay, relocation costs and a loss on the
abandonment of the administrative office lease in Denver, Colorado.
Interest Expense
The higher interest expense for the periods presented is reflective of
the increase in the average long-term debt outstanding during those
periods. The increase in long-term debt is attributable to the
convertible debentures sold by the Company pursuant to the private
placement initiated in April 1996 and previously discussed under the
caption Liquidity and Capital Resources.
(Loss) Gain on Sale of Assets
The gain on sale of assets in 1995 is primarily related to the sale of
oil field service equipment in connection with the Company's
restructuring initiatives and the sale of various oil and gas properties.
The loss on sale of assets in 1996 is primarily related to the sale of
certain oil and gas properties and the abandonment of obsolete or
unusable furniture and fixtures.
<PAGE>
PART II - OTHER INFORMATION
Item 1. Legal Proceedings
The Company may from time to time be involved in various claims,
lawsuits, disputes with third parties, actions involving allegations of
discrimination, or breach of contract incidental to the operation of its
business. The Company is not currently involved in any such incidental
litigation or any other legal proceedings which it believes could have a
material adverse effect on its financial condition or results of
operations.
Item 2. Changes in Securities
(a) There is no information reportable under this item for the period
covered by this report.
(b) No rights evidenced by any class of registered securities have been
materially limited or qualified by the issuance or modification of
any other class of securities.
Item 3. Defaults Upon Senior Securities
(a) There has been no material default in the payment of principal,
interest, or any other material default, with respect to any
indebtedness of the small business issuer during the period covered
by this report.
(b) In December 1994, the Board of Directors elected to forgo the
declaration of the regular quarterly dividend for the Company's
Series A Cumulative Convertible Preferred Stock for the fourth
quarter of 1994. In March 1995, the Board of Directors elected to
suspend the Preferred Stock dividend indefinitely. However, the
dividends continue to accrue on a monthly basis and are cumulative.
Accordingly, as of September 30, 1996, dividends in arrears
aggregate $405,376 or $2.00 per share.
Item 4. Submission of Matters to a Vote of Security Holders
The Company's Annual Meeting of Stockholders was held at the Ramada Inn,
2790 Crossroads Boulevard, Grand Junction, Colorado 81506, on Saturday,
August 10, 1996, at 10:00 a.m., Mountain Daylight Time. The matters
submitted to a vote of the Company's security holders as well as the
results of the votes cast are as follows:
I. Matters Voted Upon by Holders of Common Stock
(1) The election of two Class C directors to serve on the
Company's Board of Directors totaling nine directors. A
summary of the votes cast are as follows:
<PAGE>
Votes Received
In Favor of Votes Withheld
% of % of
Number Shares Number Shares
Willard H. Pease, Jr. 6,078,091 83.25% 55,104 .75%
William F. Warnick 6,072,523 83.71% 60,672 .83%
As a result of the voting, Willard H. Pease, Jr. and William F.
Warnick were elected as Class C Directors to serve in that
capacity until the Annual Meeting of Stockholders in 1999.
(2) A proposal to approve the Company's 1996 Employee
Stock Option Plan. A summary of the votes cast are as
follows:
Shares % of
Vote Voted Shares
In Favor of 5,932,640 81.25%
Against 125,098 1.71%
Withheld 57,888 .79%
Not Voted 17,569 .24%
As a result of the voting, the stockholders of the Company
ratified, approved and adopted the 1996 Employee Stock Option
Plan.
II. Matters Voted Upon by Holders of Preferred Stock
(1) The election of two directors to represent the holders
of Preferred Stock on the Company's Board of Directors
totaling nine directors. A summary of the votes cast are as
follows:
<TABLE>
<CAPTION>
Votes Received Votes
In Favor of Withheld Votes Abstained
% of % of % of
Nominee .................................................... Number shares Number shares Number shares
Jack Alexander ............................................. 18,625 9.19% 14,200 7.01% 30,155 14.88
Steve Antry ................................................ 24,400 12.03% 8,425 4.16% 30,155 14.88
<S> <C> <C> <C> <C> <C> <C>
Leroy Smith ................................................ 20,625 10.17% 12.200 6.02% 30,155 14.88
Clemons F. Walker .......................................... 1,600 .79% 31,225 15.41% 30,155 14.88
</TABLE>
As a result of the votes, Steve Antry and Leroy Smith received
at least a plurality of the votes cast and shall serve on the
Company's Board of Directors representing the Preferred
Stockholders until such time all past due dividends have been
paid or until re-elected or replaced at the next Annual
Meeting of the Company's stockholders in 1997.
III. Matters Voted Upon by Holders of Common Stock and Preferred
Stock
(1) A proposal to amend the Certificate of Designation of
Series A Cumulative Convertible Preferred Stock to change the
event which triggers automatic conversion of the Preferred
Stock into Common Stock, to lower the price for converting
Preferred Stock into Common Stock and Warrants, and to state
the exercise price of the Warrants. A summary of the votes
cast are as follows:
<TABLE>
Votes Received Votes
In Favor of Votes Against Withheld Votes Abstained
<CAPTION>
Stock ............................ % of % of % of # of
Class ............................ Number shrs Number shrs Number shrs Number shrs
Common
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Stk ............................. 3,089,934 42% 53,350 .7% 88,246 1% 2,901,665 40%
Prefd ............................
Stk ............................. 43,880 22% 6,100 3% 600 .3% 12,400 6%
</TABLE>
Since at least a majority of Common shares outstanding and at
least two-thirds of the Preferred shares outstanding did not
vote in favor of the proposed change in the Certificate of
Designation of Series A Cumulative Convertible Preferred
Stock, the motion DID NOT pass.
Item 5. Other Information
There is no information reportable under this item for the period covered
by this report.
Item 6. Exhibits and Reports on Form 8-K
(a) There are no exhibits filed as part of this report.
(b) There were no reports on Form 8-K filed during the quarter ended
September 30, 1996.
<PAGE>
SIGNATURES
In accordance with Section 13 or 15 (d) of the Exchange Act, the
Registrant caused this report to be signed on its behalf by the
undersigned, thereunto duly authorized.
PEASE OIL AND GAS COMPANY
Date: November 13, 1996 By: /s/ Willard H. Pease, Jr.
Willard H. Pease, Jr.
President and Chief
Executive Officer
Date: November 13, 1996 By: /s/ Patrick J. Duncan
Patrick J. Duncan
Chief Financial Officer and
Principal Accounting Officer
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