UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
------
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2000, or
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the transition period from ___________to______________
Commission File Number: 000-24881
-------
Pennaco Energy, Inc.
(Exact name of registrant as specified in its charter)
DELAWARE 88-0384598
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
1050 17th Street, Suite 700
Denver, Colorado 80265-2076
(Address of principal executive offices) (Zip Code)
(303) 629-6700
(Registrant's telephone number, including area code)
Indicate by check mark whether the registrant (1) filed all reports required to
be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during
the preceding twelve (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 ninety (90) days.
Yes /X/ No / /
As of July 31, 2000, the registrant had 19,563,536 shares of Common Stock
outstanding.
PENNACO ENERGY, INC.
INDEX
Page
Number
--------
PART I. FINANCIAL INFORMATION.......................................... 3
Item 1. Financial Statements........................................... 3
Balance Sheet as of
June 30, 2000 and December 31, 1999............................ 3
Statement of Operations for the three months and six months
ended June 30, 2000 and 1999................................... 4
Statement of Cash Flows for the six months
ended June 30, 2000 and 1999................................... 5
Notes to Financial Statements.................................. 6
Item 2. Management's Discussion and Analysis of Financial
Condition and Results of Operations............................ 9
Item 3. Quantitative and Qualitative Disclosures about Market Risk..... 14
PART II. OTHER INFORMATION.............................................. 15
Item 4. Submission of Matters to a Vote of Security Holders............ 15
Item 6. Exhibits and Reports on Form 8-K............................... 15
SIGNATURES........................................................................ 16
2
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
PENNACO ENERGY, INC.
BALANCE SHEET
(unaudited)
June 30, December 31,
2000 1999
-------- ------------
(in thousands)
ASSETS
------
Current assets:
Cash and cash equivalents..................................................................... $ 1,646 $ 2,908
Accounts receivable:
Gas sales.................................................................................. 5,496 1,649
Joint interest owners and other............................................................ 8,540 3,562
Inventory..................................................................................... 2,900 1,715
Prepaid expenses and other current assets..................................................... 516 467
-------- -------
Total current assets.................................................................. 19,098 10,301
-------- -------
Property and equipment, at cost:
Natural gas properties, using the successful efforts method of accounting..................... 98,267 49,349
Other property and equipment.................................................................. 1,107 772
-------- -------
99,374 50,121
Less accumulated depletion, depreciation and amortization..................................... (2,887) (873)
-------- -------
Net property and equipment................................................................. 96,487 49,248
-------- -------
Other assets.................................................................................... 621 108
-------- -------
$116,206 $59,657
======== =======
LIABILITIES AND STOCKHOLDERS' EQUITY
------------------------------------
Current liabilities:
Accounts payable:
Gas sales.................................................................................. $ 1,259 $ 696
Trade and other............................................................................ 11,702 7,530
Accrued ad valorem and severance taxes........................................................ 1,087 313
Other accrued liabilities..................................................................... 2,376 1,347
-------- -------
Total current liabilities............................................................. 16,424 9,886
-------- -------
Long-term debt.................................................................................. 45,325 -
-------- -------
Deferred income taxes........................................................................... 1,986 810
-------- -------
Commitments.....................................................................................
Stockholders' equity:
Common stock, $.001 par value (Authorized 50,000,000 shares; issued and
outstanding 19,503,000 shares at June 30, 2000 and 18,813,000 shares at
December 31, 1999)........................................................................... 20 19
Additional paid-in capital.................................................................... 49,567 48,241
Retained earnings............................................................................. 2,884 701
-------- -------
Total stockholders' equity............................................................ 52,471 48,961
-------- -------
$116,206 $59,657
======== =======
See accompanying notes to financial statements.
3
PENNACO ENERGY, INC.
STATEMENT OF OPERATIONS
(unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
---------------------- ---------------------
2000 1999 2000 1999
------- ------- ------- -------
(in thousands, except per share amounts)
Revenue:
Natural gas revenue..................................... $11,451 $ 628 $17,650 $ 628
------- ------- ------- -------
Total revenue...................................... 11,451 628 17,650 628
------- ------- ------- -------
Operating expenses:
Lease operating......................................... 1,884 170 3,124 170
Gathering, compression and transportation............... 2,779 316 4,970 316
Production taxes........................................ 755 52 1,132 52
Exploration............................................. 280 57 497 108
Depletion, depreciation and amortization................ 1,192 118 2,014 148
General and administrative.............................. 1,323 1,380 2,607 2,425
------- ------- ------- -------
Total expenses..................................... 8,213 2,093 14,344 3,219
------- ------- ------- -------
Income (loss) from operations............................. 3,238 (1,465) 3,306 (2,591)
------- ------- ------- -------
Other income:
Interest income......................................... 18 130 53 239
Gain on sale of properties.............................. - 485 - 12,431
------- ------- ------- -------
Total other income................................. 18 615 53 12,670
------- ------- ------- -------
Income (loss) before income taxes......................... 3,256 (850) 3,359 10,079
Income tax benefit (expense).............................. (1,140) 304 (1,176) (3,612)
------- ------- ------- -------
Net income (loss)....................................... $ 2,116 $ (546) $ 2,183 $ 6,467
======= ======= ======= =======
Earnings (loss) per share:
Basic................................................... $ .11 $ (.04) $ .11 $ .43
======= ======= ======= =======
Diluted................................................. $ .10 $ (.04) $ .10 $ .37
======= ======= ======= =======
Weighted average common shares outstanding:
Basic................................................... 19,380 15,153 19,145 15,048
======= ======= ======= =======
Diluted................................................. 21,786 15,153 21,382 17,369
======= ======= ======= =======
See accompanying notes to financial statements.
4
PENNACO ENERGY, INC.
STATEMENT OF CASH FLOWS
(unaudited)
Six Months Ended
June 30,
------------------------------
2000 1999
-------- --------
(in thousands)
Cash flows from operating activities:
Net income..................................................................... $ 2,183 $ 6,467
Adjustments to reconcile net income to net cash provided by (used in)
operating activities:
Gain on sale of properties................................................... - (12,431)
Depletion, depreciation and amortization...................................... 2,014 148
Stock option compensation..................................................... - 11
Deferred income tax expense................................................... 1,176 1,874
Changes in operating assets and liabilities:
Increase in accounts receivable............................................. (8,825) (1,253)
Increase in inventory....................................................... (1,185) (460)
(Increase) decrease in prepaid expenses and other current assets............ (49) 60
Increase in other assets.................................................... (513) -
Increase in accounts payable and accrued liabilities........................ 6,538 997
-------- --------
Net cash provided by (used in) operating activities 1,339 (4,587)
-------- --------
Cash flows from investing activities:
Capital expenditures................................................................ (49,253) (11,546)
Proceeds from sale of properties.................................................... - 20,058
-------- --------
Net cash provided by (used in) investing activities......................... (49,253) 8,512
-------- --------
Cash flows from financing activities:
Borrowing of long-term debt......................................................... 53,490 -
Payments of long-term debt.......................................................... (8,165) -
Repayment of bridge loan............................................................ - (5,600)
Proceeds from exercise of stock options and warrants................................ 1,327 787
Other, net........................................................................ - (21)
-------- --------
Net cash provided by (used in) financing activities......................... 46,652 (4,834)
-------- --------
Net decrease in cash and cash equivalents............................................ (1,262) (909)
Cash and cash equivalents at beginning of period..................................... 2,908 5,623
-------- --------
Cash and cash equivalents at end of period........................................... $ 1,646 $ 4,714
======== ========
Supplemental disclosures of cash flow information:
Cash paid for interest.............................................................. $ 370 $ -
======== ========
Cash paid for income taxes.......................................................... $ - $ 528
======== ========
See accompanying notes to financial statements.
5
PENNACO ENERGY, INC.
June 30, 2000
Notes to Financial Statements
(unaudited)
(1) ORGANIZATION AND BASIS OF PRESENTATION
Pennaco Energy, Inc. (the "Company") is an independent exploration and
production company. The Company's current operations are completely focused on
the acquisition, exploration, development and production of natural gas from
coal bed methane properties located in the Powder River Basin in northeastern
Wyoming and southeastern Montana. The Company was incorporated on January 26,
1998 under the laws of the state of Nevada and in 2000 reincorporated in
Delaware. The Company is headquartered in Denver, Colorado.
From its inception through March 31, 1999 the Company's activities were
limited to organizational activities, prospect development activities,
acquisition of leases and option rights, and commencement of its drilling
program. In April 1999 the Company began producing gas from certain of its gas
properties in the Gillette Area of Wyoming.
The accompanying financial statements are unaudited; however, in the
opinion of management, the accompanying financial statements reflect all
adjustments, consisting of normal recurring adjustments, necessary to present
fairly the Company's financial position as of June 30, 2000, and the results of
its operations for the three-month and six-month periods ended June 30, 2000 and
1999. The accounting policies followed by the Company are included in Note 1 to
the Financial Statements in the Company's Annual Report on Form 10-KSB for the
year ended to December 31, 1999. These financial statements should be read in
conjunction with the Form 10-KSB.
The Company's financial results are affected when prices for natural gas
fluctuate. Such effects can be significant. To manage the risks related to
commodity prices and to reduce the impact of fluctuations in prices, the Company
may enter into long-term sales contracts and hedging contracts. In order to
implement its hedging strategy, the Company enters into energy swaps and uses
other financial instruments. The Company uses the hedge or deferral method of
accounting for these activities and as a result, gains and losses on the related
instruments are generally offset by similar changes in the realized prices of
the commodities.
(2) OIL AND GAS ACTIVITIES
The Company follows the successful efforts method of accounting for its oil
and gas activities. Accordingly, costs associated with acquiring, drilling and
equipping successful exploratory wells are capitalized. Geological and
geophysical costs, delay and surface rentals, and drilling costs of unsuccessful
exploratory wells and pilot drilling projects are charged
6
Pennaco Energy, Inc.
Notes to Financial Statements
(continued)
to expense as incurred. Costs of drilling development wells, both successful
and unsuccessful, are capitalized. Upon the sale or retirement of oil and gas
properties, the cost thereof and the accumulated depreciation and depletion are
removed from the accounts and any gain or loss is recorded to operations. Upon
the sale of a partial interest in an unproved property, the proceeds are treated
as a recovery of cost. If the proceeds exceed the carrying amount of the
property, a gain is recognized. Depletion of capitalized acquisition,
exploration and development costs is computed on the units-of-production method
by individual fields as the related proved reserves are produced.
Capitalized costs of unproved properties are assessed periodically and a
provision for impairment is recorded, if necessary, through a charge to
operations. During the three months and six months ended June 30, 2000, the
Company capitalized interest of $796,000 and $937,000, respectively which was
incurred to carry unproved properties that are under development. No interest
was capitalized during the three months and six months ended June 30, 1999.
Proved oil and gas properties are assessed for impairment on a field-by-
field basis. If the net capitalized costs of proved oil and gas properties
exceeds the estimated undiscounted future net cash flows from the property, a
provision for impairment is recorded to reduce the carrying value of the
property to its estimated fair value.
The Company's natural gas revenues are reported net of transportation
expenses incurred on gas delivered and sold downstream of the Company's typical
point of sale, which is currently at Glenrock, Wyoming.
(3) EARNINGS (LOSS) PER SHARE
The following table sets forth the computation of basic and diluted
earnings (loss) per share:
Three Months Ended Six Months Ended
June 30, June 30,
---------------------- ----------------------
2000 1999 2000 1999
------- ------- ------- -------
(in thousands, except per share amounts)
Numerator for basic and diluted earnings (loss) per share--
Net income (loss)................................................ $ 2,116 $ (546) $ 2,183 $ 6,467
======= ======= ======= =======
Denominator for basic earnings (loss) per share--
Weighted average shares-basic.................................... 19,380 15,153 19,145 15,048
Effect of dilutive securities:
Stock options................................................ 2,345 - 2,181 1,878
Warrants..................................................... 61 - 56 443
------- ------- ------- -------
Denominator for diluted earnings (loss) per share--
Adjusted weighted average shares-diluted....................... 21,786 15,153 21,382 17,369
======= ======= ======= =======
Basic earnings (loss) per share..................................... $ .11 $ (.04) $ .11 $ .43
======= ======= ======= =======
Diluted earnings (loss) per share................................... $ .10 $ (.04) $ .10 $ .37
======= ======= ======= =======
7
Pennaco Energy, Inc.
Notes to Financial Statements
(continued)
Potentially dilutive common shares attributable to outstanding options and
warrants to purchase 3,000 and 4,501,000 common shares were excluded from the
calculation of diluted earnings (loss) per share for the three months ended June
30, 2000 and 1999 respectively, and 21,000 and 93,000 common shares were
excluded from such calculation for the six months ended June 30, 2000 and 1999,
respectively, as their effect was antidilutive.
(4) LONG-TERM DEBT
On July 23, 1999 the Company entered into a revolving line of credit with
US Bank National Association ("USB") which provided for loans of up to
$25,000,000 with an initial borrowing base of $10,000,000. The borrowing base
was subsequently increased to $14,000,000 and then further increased to
$20,000,000 in September 1999. Based upon the Company's reserves at January 1,
2000, the credit facility was increased to provide for loans of up to
$75,000,000 limited to a borrowing base, as determined by USB, of $40,000,000
through September 30, 2000, with the capacity for expansion as the Company's
reserve base expands further. In April 2000, the borrowing base was increased
to $60,000,000. The credit facility is secured by mortgages on substantially
all of the Company's properties. The credit facility provides for a revolving
period ending on June 30, 2001, after which the loan is to be repaid over 48
months. The credit facility contains certain covenants, including restrictions
on indebtedness, requirements with respect to working capital and tangible net
worth. Interest is payable at a variable rate based on LIBOR or the prime rate.
(5) PUT OPTION
In June 2000 the Company purchased a "put option" which establishes a floor
price of $3.10 per MMBtu (CIG Rocky Mountain price) for approximately 3.2 Bcf of
production from August 1, 2000 through December 31, 2000, or approximately 26%
of the Company's expected production for the second half of 2000. This put
option contract places no limit on the upside price for the Company's gas
production. The Company will charge its natural gas revenues the $421,000 cost
of the put option over the period the hedged production is produced. Natural
gas revenues will also be charged with any proceeds received by the Company upon
exercise of the put option.
8
PENNACO ENERGY, INC.
Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operations
General
-------
This Quarterly Report on Form 10-Q includes "forward-looking
statements" within the meaning of Section 27A of the Securities Act and Section
21E of the Securities Exchange Act of 1934, as amended (the "Exchange Act"). All
statements other than statements of historical fact included in this Form 10-Q,
including without limitation statements regarding planned capital expenditures,
the Company's financial position, business strategy and other plans and
objectives for future operations, are forward-looking statements. Although the
Company believes that the expectations reflected in such forward-looking
statements are reasonable, it can give no assurance that such expectations will
prove to have been correct. A number of risks and uncertainties could cause
actual results to differ materially from these statements, including, without
limitation, fluctuations in the price of natural gas, the success rate of
drilling efforts, expected production levels, operating expenses, capital
expenditures, completion of gathering and pipeline projects and availability of
equipment and personnel, as well as other risk factors described from time to
time in the Company's documents and reports filed with the SEC. All subsequent
written and oral forward-looking statements attributable to the Company or
persons acting on its behalf are expressly qualified in their entirety by such
factors.
The Company is an independent energy company entirely focused on the
acquisition, exploration, development, and production of natural gas from coal
bed methane properties located in the Powder River Basin of northeastern Wyoming
and southeastern Montana. The Company is one of the largest holders of oil and
gas leases covering coal bed methane properties in the Powder River Basin.
As of July 31, 2000, the Company owned oil and gas lease rights with
respect to approximately 809,100 gross acres and 394,600 net acres in the Powder
River Basin. Of these amounts, 663,100 gross acres and 282,800 net acres
represent the Company's portion of the leasehold interests contained in an area
of mutual interest, or AMI, shared with CMS Oil and Gas Company, a wholly owned
subsidiary of CMS Energy Corporation.
Pennaco acquired 41,600 net acres of undeveloped CBM leases in the six
months ended June 30, 2000 at a cost of $16.1 million or an average of $387 per
acre. Over 50% of the acquired leases are located in the Company's new House
Creek Project in the Gillette Area, outside of the Pennaco/CMS AMI. Over 50% of
the leases are on fee and state acreage and the balance is on federal acreage.
Pennaco also acquired 36 CBM wellbores and surface facilities in the House Creek
Project, at a cost of approximately $2.7 million.
9
Pennaco Energy, Inc.
Management's Discussion and Analysis of Financial
Condition and Results of Operations
(continued)
On November 15, 1998, the Company initiated its drilling program and had
drilled 1,107 gross (804 net) wells by July 31, 2000. The Company has drilled
and operates 628 gross (548 net) wells in the Gillette Area with an average 87%
working interest, 37 gross (37 net) wells in the Felix Project in the Northern
Fairway Area with a 100% working interest and 167 gross (82 net) wells in the
AMI with an average 49% working interest. The Company has also participated in
275 gross (137 net) wells drilled and operated by CMS in the AMI with an average
50% working interest net to Pennaco. The Company plans to drill a total of 550
net wells during 2000 with expected drilling costs of approximately $35,000,000.
The Company has drilled 350 of these net wells through July 31, 2000. The number
of locations actually drilled will depend on future operating results,
availability of capital, and the Company's ability to obtain the requisite
regulatory approvals from state and federal agencies.
As of July 31, 2000, the Company's gross gas production totaled 86 MMcf per
day from two primary areas - the Company's Gillette Area and the Pennaco/CMS
AMI. In the Gillette Area, production was 78 MMcf per day (66 MMcf per day net
to the Company's average 85% working interest) from 468 wells that have been
hooked up to date, which is an average of 165 Mcf per day per well. Another 56
wells in the Gillette Area are connected and dewatering, but not yet producing
gas. In the Pennaco/CMS AMI, production was 8 MMcf per day (4 MMcf per day net
to the Company's average 50% working interest) from 76 producing wells, which is
an average of 107 Mcf per day per well.
Combined, the Company's net working interest production is 70 MMcf per day
or 52 MMcf per day net after royalty and fuel usage. Since early November 1999,
the Company's net working interest gas production has increased by 250% from 20
MMcf per day to 70 MMcf per day and the number of producing wells has increased
from 122 to 544 wells. The Company has an additional 282 wells that are
connected to gathering systems and dewatering but not yet producing gas and 266
wells that are in the process of being connected to gathering and water handling
systems.
RESULTS OF OPERATIONS
---------------------
The Company had net income of $2,116,000 and $2,183,000 for the three
months and six months ended June 30, 2000, respectively. This compares to a net
loss of $546,000 for the three months ended June 30, 1999 and to a net income of
$6,467,000 for the six months ended June 30, 1999. Net income for the six months
ended June 30, 1999 includes a gain on the sale of properties in connection with
the CMS Transaction of $12,431,000. The Company had income from operations of
$3,238,000 and $3,306,000 for the three months and six months ended June 30,
2000. This compares to a loss from operations of $1,465,000 and $2,591,000 for
the same periods in 1999. The Company's first gas sales occurred in late April
1999.
10
Pennaco Energy, Inc.
Management's Discussion and Analysis of Financial
Condition and Results of Operations
(continued)
As reflected in the unaudited quarterly statement of operations data and
summary production, price and cost data shown below, the Company's operating
activities for the three months ended June 30, 2000, have grown significantly
over the past four quarters.
Three Months Ended
-----------------------------------------------------------------------------
(in thousands, except per share amounts)
June 30, September 30, December 31, March 31, June 30,
1999 1999 1999 2000 2000
---- ---- ---- ---- ----
STATEMENT OF OPERATIONS DATA:
Revenue:
Natural gas revenue......................... $ 628 $ 1,121 $ 2,801 $ 6,199 $11,451
------- ------- ------- ------- -------
Total revenue............................ 628 1,121 2,801 6,199 11,451
------- ------- ------- ------- -------
Operating expenses:
Lease operating............................. 170 287 500 1,240 1,884
Gathering, compression and transportation... 316 502 1,153 2,191 2,779
Production taxes............................ 52 70 162 377 755
Exploration................................. 57 286 324 217 280
Depletion, depreciation and amortization.... 118 196 467 822 1,192
General and administrative.................. 1,380 1,315 1,497 1,284 1,323
------- ------- ------- ------- -------
Total expenses........................... 2,093 2,656 4,103 6,131 8,213
------- ------- ------- ------- -------
Income (loss) from operations ................ (1,465) (1,535) (1,302) 68 3,238
------- ------- ------- ------- -------
Other income (expense):
Interest income............................. 130 23 108 35 18
Interest expense............................ - (62) - - -
Gain on sale of properties.................. 485 - 168 - -
------- ------- ------- ------- -------
Total other income (expense)............. 615 (39) 276 35 18
------- ------- ------- ------- -------
Income (loss) before income taxes............. (850) (1,574) (1,026) 103 3,256
Income tax benefit (expense).................. 304 563 444 (36) (1,140)
------- ------- ------- ------- -------
Net income (loss)............................. $ (546) $(1,011) $ (582) $ 67 $ 2,116
======= ======= ======= ======= =======
Earnings (loss) per share:
Basic....................................... $ (.04) $ (.07) $ (.03) $ .00 $.11
======= ======= ======= ======= =======
Diluted..................................... $ (.04) $ (.07) $ (.03) $ .00 $.10
======= ======= ======= ======= =======
Weighted average common shares outstanding:
Basic....................................... 15,153 15,291 17,989 18,910 19,380
======= ======= ======= ======= =======
Diluted..................................... 15,153 15,291 17,989 21,209 21,786
======= ======= ======= ======= =======
SUMMARY PRODUCTION, PRICE AND COST DATA:
Natural gas sales volume for period (MMcf)............... 398 743 1,604 3,145 4,055
Average daily natural gas sales volume (MMcf)............ 4 8 17 35 45
Average realized gas price (per Mcf)..................... $ 1.58 $ 1.51 $ 1.75 $ 1.97 $ 2.82
Lease operating expense (per Mcf)........................ $ 0.43 $ 0.39 $ 0.31 $ 0.39 $ 0.46
Gathering, compression and transportation (per Mcf)...... $ 0.79 $ 0.68 $ 0.72 $ 0.70 $ 0.69
Depletion, depreciation and amortization (per Mcf)....... $ 0.30 $ 0.26 $ 0.29 $ 0.26 $ 0.29
11
Pennaco Energy, Inc.
Management's Discussion and Analysis of Financial
Condition and Results of Operations
(continued)
The Company's natural gas revenues have increased quarter-to-quarter due to
the increased volume of gas sales resulting from the Company's increase in the
number of producing wells and the increase in the sales price received by the
Company for its natural gas. The Company had net gas sales during the second
quarter 2000 of 4.1 billion cubic feet (Bcf), or 45 million cubic feet (MMcf)
per day, an elevenfold increase over the 4 MMcf per day of gas sales in the
comparable prior year period and a 29% increase over the 35 MMcf per day of net
gas sales in the first quarter 2000. The quarterly average realized gas price
for the second quarter 2000 was $2.82 per thousand cubic feet (Mcf), a 79%
increase over the $1.58 per Mcf realized in the prior year period and a 43%
increase over the $1.97 realized in the first quarter 2000.
With respect to operating expenses, a comparison of the second quarter 2000
to the first quarter 2000 is more meaningful than to the prior year period since
the Company's first gas sales did not occur until late April 1999. Lease
operating expense was $0.46 per Mcf for the second quarter 2000 as compared to
$0.39 for the first quarter 2000. The Company realized an increase of $0.07 per
Mcf in lease operating expense between these periods, primarily due to the
continued heavy use of portable, diesel-fired generators to produce electricity
for the Company's downhole water pumps. Lease operating expense per Mcf is
expected to decrease over the next several quarters as the Company connects a
larger proportion of its producing wells to the local electric power grid.
Gathering, compression and transportation expense was $0.69 per Mcf in the
second quarter 2000 compared to $0.70 in the first quarter 2000. Production
taxes increased to $0.19 per Mcf in the second quarter 2000 compared to $0.12
per Mcf in the first quarter 2000, principally as a result of the increase in
the average realized gas price. Depreciation, depletion and amortization was
$0.29 per Mcf for the second quarter 2000, compared to $0.26 per Mcf for the
first quarter 2000, primarily due to higher capital costs for water handling
operations.
With respect to gas production, revenues and expenses, a comparison of the
six months ended June 30, 2000, to the prior year is not meaningful since the
Company's first gas sales did not occur until late April 1999.
LIQUIDITY AND CAPITAL RESOURCES
-------------------------------
The Company had capital expenditures of approximately $49,253,000 during
the six months ended June 30, 2000, including $18,840,000 for leasehold
acquisitions and for the purchase of 36 CBM wellbores, $18,085,000 for drilling
activities, $11,992,000 for water discharge, power and pipeline facilities, and
$336,000 for other property and equipment. A portion of the water discharge,
power and pipeline facilities are associated not only with wells drilled in 1999
and 2000, but also with future wells to be drilled over the next two years
throughout the Gillette Area and the Northern Fairway Area. Such capital
expenditures were financed by a combination of bank borrowings and cash flow
from operations.
12
Pennaco Energy, Inc.
Management's Discussion and Analysis of Financial
Condition and Results of Operations
(continued)
The Company's capital spending budget for 2000 is currently $55,000,000.
Preliminarily, the Company plans to increase the capital spending budget to at
least $70,000,000, pending approval of the Board of Directors, to accommodate
the acquisition of additional leases and the acceleration of the Company's
drilling program. The Company plans to finance the year 2000 budget through a
combination of cash flow from operations and bank borrowings. The Company plans
to spend a total of $20,000,000 on lease acquisitions which will add to near-
term drilling inventory and $50,000,000 to drill at least 550 net wells and to
construct water discharge facilities. Of these 550 net wells, 350 were drilled
as of June 30, 2000. The wells will be a combination of joint Pennaco/CMS wells
drilled in the AMI and Pennaco wells drilled primarily in its Gillette Area.
On July 23, 1999 the Company entered into a revolving line of credit with
US Bank National Association. US Bank increased the Company's borrowing base to
$60,000,000 on April 5, 2000, under the existing $75,000,000 credit facility, as
a result of the Company's successful drilling and production activities since
December 31, 1999. The Company's bank debt totaled $46,532,000 as of July 31,
2000.
Should the Company's cash flow from operations or availability under its
revolving credit agreement be insufficient to satisfy its planned capital
expenditure requirements, there can be no assurance that additional debt or
equity financing will be available to meet these requirements.
In June 1998, the Financial Accounting Standards Board issued Statement of
Financial Accounting Standards No. 133, Accounting for Derivative Instruments
and Hedging Activities (Statement No. 133), effective beginning with the first
quarter of fiscal years beginning after June 30, 2000. Statement No. 133
establishes accounting and reporting standards for derivative instruments,
including certain derivative instruments embedded in other contracts, and for
hedging activities. The Company has not determined the impact Statement No. 133
will have on its financial statements and believes that such determination will
not be meaningful until closer to the date of initial adoption.
13
Pennaco Energy, Inc.
Management's Discussion and Analysis of Financial
Condition and Results of Operations
(continued)
Item 3. Quantitative and Qualitative Disclosures about Market Risk
The Company is exposed to market risk, including the effects of adverse
changes in commodity prices and interest rates as discussed below.
Commodity Price Risk
The Company's financial results are affected when prices for natural gas
fluctuate. Such effects can be significant. To manage the risks related to
commodity prices and to reduce the impact of fluctuations in prices, the Company
may from time to time enter into long-term sales and hedging contracts. Under
its hedging strategy, the Company may enter into energy swaps or use other
financial instruments. The Company uses the hedge or deferral method of
accounting for these activities and, as a result, gains and losses on the
related instruments are generally offset by similar changes in the realized
prices of the commodities.
During June 2000, the Company purchased a "put option" which establishes
a floor price of $3.10 per MMBtu (CIG Rocky Mountain price) for approximately
3.2 Bcf of production from August 1, 2000 through December 31, 2000, or
approximately 26% of the Company's expected gas production for the second half
of 2000. The Company currently has no other hedges in place at this time, and
does not expect to enter into any fixed price sales contracts that would limit
the upside gas price for its production.
Interest Rate Risk
The Company's credit facility is secured by mortgages on substantially
all of the Company's properties. The credit facility provides for a revolving
period ending on June 30, 2001, after which the loan is to be repaid over 48
months. The credit facility contains certain covenants, including restrictions
on indebtedness, requirements with respect to working capital and tangible net
worth. Interest is payable at a variable rate based on LIBOR or the prime rate.
The Company's exposure to changes in interest rates results from such borrowing
with floating interest rates. At the present time, the Company has no financial
instruments in place to manage the long-term impact of changes in interest
rates.
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PART II. OTHER INFORMATION
Item 4. Submission of Matters to a Vote of Security Holders
The Company held its annual meeting of stockholders in Denver, Colorado
on May 16, 2000. The following sets forth matters submitted to a vote of the
stockholders:
(a) Kurt M. Petersen was elected to the Board of Directors as stated in the
Company's Proxy Statement dated April 14, 2000, for a term expiring at
the 2003 Annual Meeting or until his successor has been elected and
qualified. Mr. Petersen was elected by a vote of 16,401,595 shares,
being more than a majority of the outstanding shares of Common Stock,
with 211,486 shares abstaining.
(b) The stockholders approved a proposal to change Pennaco's state of
incorporation from Nevada to Delaware, through a merger of the Company
into its wholly-owned subsidiary, and all of the effects of a
reincorporation, including (a) the conversion of the Company's
outstanding securities into corresponding securities of the surviving
corporation and (b) certain amendments to the Company's Articles of
Incorporation necessary to conform to Delaware corporate law, as
described in the Company's Proxy Statement by a vote of 11,999,471
shares, being more than a majority of the shares of Common Stock
present, in person or by proxy, at the annual meeting and entitled to
vote with 242,026 shares voted against, 10,179 shares abstaining.
(c) The stockholders approved an amendment to the Company's 1998 Stock
Option and Incentive Plan, as amended, to increase the number of shares
of the Company's Common Stock reserved for issuance thereunder from
4,500,000 shares to 5,500,000 shares by a vote of 9,998,664 shares,
being more than a majority of the shares of Common Stock present, in
person or by proxy, at the annual meeting and entitled to vote, with
2,216,008 shares voted against, 37,004 shares abstaining.
(d) The stockholders ratified the appointment of KPMG LLP to audit the
financial statements of the Company and its subsidiaries for the year
ending December 31, 2000, by a vote of 16,582,477 shares, being more
than a majority of the shares of Common Stock present, in person or by
proxy, at the annual meeting and entitled to vote, with 22,600 shares
voted against, 8,004 shares abstaining.
Item 6. Exhibits and Reports on Form 8-K
(a) Exhibits
27 Financial Data Schedule
(b) Reports on Form 8-K.
No reports on Form 8-K were filed during the three months ended June 30,
2000.
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SIGNATURES
Pursuant to the requirements 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.
PENNACO ENERGY, INC.
July 31, 2000 By: /s/ Paul M. Rady
---------------------------------
Paul M. Rady, President and Chief
Executive Officer
July 31, 2000 By: /s/ Glen C. Warren, Jr.
----------------------------------
Glen C. Warren, Jr., Executive Vice President
and Chief Financial Officer
(Principal Financial and Accounting Officer)
July 31, 2000 By: /s/ Charles E. Brammeier
----------------------------------
Charles E. Brammeier, Controller
16