UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
|
|
|
þ
|
|
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
|
FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2008.
OR
|
|
|
o
|
|
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE
|
ACT OF 1934 FOR THE TRANSITION PERIOD FROM
TO
.
COMMISSION FILE NO. 1-32533
CRUSADER ENERGY GROUP INC.
(Exact name of registrant as specified in its charter)
|
|
|
Nevada
|
|
88-0349241
|
(State or other jurisdiction of
incorporation or organization)
|
|
(I.R.S. Employer
Identification No.)
|
4747 Gaillardia Parkway
Oklahoma City, Oklahoma 73142
(Address of principal executive offices, including zip code)
(405) 285-7555
(Registrants telephone number, including area code)
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by
Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for
such shorter period that the registrant was required to file such reports) and (2) has been subject
to such filing requirements for the past 90 days.
Yes
þ
No
o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer,
a non-accelerated filer, or a smaller reporting company.
See the definitions of large
accelerated filer, accelerated filer and smaller reporting company in Rule 12b-2 of the Exchange Act. (Check one):
|
|
|
|
|
|
|
Large accelerated filer
o
|
|
Accelerated filer
o
|
|
Non-accelerated filer
o
(Do not check if a smaller reporting company)
|
|
Smaller reporting company
þ
|
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the
Exchange Act).
Yes
o
No
þ
At November 6, 2008, the number of outstanding shares of the issuers common stock was 198,564,958.
CRUSADER ENERGY GROUP, INC.
INDEX TO QUARTERLY REPORT ON FORM 10-Q
FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2008
AVAILABLE INFORMATION
Crusader makes available free of charge on or through its Internet Web site its annual report
on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and all amendments to
such reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act
of 1934 as soon as reasonably practicable after such material has been electronically filed with,
or furnished to, the Securities and Exchange Commission (SEC). The companys Internet address is
http://www.crusaderenergy
.com and such filings are also available at the SECs Web site,
http://www.sec.gov
. Crusader also posts on its Internet Web site under the heading, Investor
Information, other materials of general interest to investors including any current investor
meeting information or Crusader conference or analyst presentations.
FACTORS AFFECTING FORWARD-LOOKING STATEMENTS
This report contains forward-looking statements within the meaning of the Federal securities
laws and regulations. Forward-looking statements are estimates and predictions by management about
the future outcome of events and conditions that could affect Crusaders business, financial
condition and results of operations. We use words such as, will, should, could, plans,
expects, likely, anticipates, intends, believes, estimates, may, and other words of
similar expression to indicate forward-looking statements.
There is no assurance that the estimates and predictions contained in our forward-looking
statements will occur or be achieved as predicted. Any number of factors could cause actual
results to differ materially from those referred to in a forward-looking statement, including
drilling risks, operating hazards and other uncertainties inherent in the exploration for, and
development and production of, oil and natural gas; volatility in oil and natural gas prices,
including the adverse impact of lower prices on the amount of our cash flow available to meet
capital expenditures, our ability to borrow and raise capital and on the values attributed to our
proven reserves; drilling and operating risks in the unconventional shales and other reservoirs in
which we operate, including uncertainties in interpreting engineering, reservoir and reserve data;
the availability of technical personnel and drilling equipment; the timing and installation of
processing and treatment facilities, third-party pipelines and other transportation facilities and
equipment; changes in interest rates; and increasing production costs and other expenses.
Further information on risks and uncertainties affecting our business is described under Risk
Factors in this report and are also available in our reports filed with the Securities and Exchange
Commission (SEC) which are incorporated by this reference as though fully set forth herein. We
undertake no obligation to publicly update or revise any forward-looking statement.
2
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements.
Crusader Energy Group Inc.
CONSOLIDATED BALANCE SHEETS (see Note 1)
|
|
|
|
|
|
|
|
|
|
|
(Unaudited)
|
|
|
|
|
|
|
September 30,
|
|
|
December 31,
|
|
|
|
2008
|
|
|
2007
|
|
ASSETS
|
|
|
|
|
|
|
|
|
CURRENT ASSETS
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$
|
27,637,842
|
|
|
$
|
7,941,663
|
|
Accounts receivable:
|
|
|
|
|
|
|
|
|
Accrued oil and gas production revenue
|
|
|
18,095,835
|
|
|
|
7,581,187
|
|
Joint interest billings
|
|
|
23,545,280
|
|
|
|
14,045,470
|
|
Other
|
|
|
456,132
|
|
|
|
770,584
|
|
Prepaid expenses and other assets
|
|
|
4,816,657
|
|
|
|
126,450
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
74,551,746
|
|
|
|
30,465,354
|
|
OIL AND GAS PROPERTIES AT COST, net, based on
full cost accounting ($181,309,360 and $12,558,796
excluded from amortization at 2008 and 2007,
respectively)
|
|
|
652,790,008
|
|
|
|
243,560,456
|
|
Derivative financial instruments
|
|
|
2,337,651
|
|
|
|
|
|
Other assets
|
|
|
20,298,926
|
|
|
|
5,199,199
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
749,978,331
|
|
|
$
|
279,225,009
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND MEMBERS/STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
CURRENT LIABILITIES
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
$
|
14,692,198
|
|
|
$
|
11,856,699
|
|
Accrued liabilities
|
|
|
22,987,939
|
|
|
|
5,934,262
|
|
Derivative financial instruments
|
|
|
13,989
|
|
|
|
1,775,617
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
37,694,126
|
|
|
|
19,566,578
|
|
|
|
|
|
|
|
|
|
|
LONG-TERM LIABILITIES
|
|
|
|
|
|
|
|
|
Asset retirement obligations
|
|
|
1,151,419
|
|
|
|
718,316
|
|
Derivative financial instruments
|
|
|
|
|
|
|
403,883
|
|
Other
|
|
|
|
|
|
|
215,778
|
|
Deferred income taxes
|
|
|
49,223,602
|
|
|
|
|
|
Notes payable
|
|
|
237,770,833
|
|
|
|
67,000,000
|
|
|
|
|
|
|
|
|
Total long-term liabilities
|
|
|
288,145,854
|
|
|
|
68,337,977
|
|
COMMITMENTS AND CONTINGENCIES (Note 9)
|
|
|
|
|
|
|
|
|
MEMBERS EQUITY
|
|
|
|
|
|
|
191,320,454
|
|
STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
Common stock, $.01 par value, 500,000,000
authorized; 198,564,958 shares issued and
outstanding at September 30, 2008
|
|
|
1,985,650
|
|
|
|
|
|
Additional paid-in capital
|
|
|
523,198,521
|
|
|
|
|
|
Accumulated deficit
|
|
|
(101,045,820
|
)
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders Equity
|
|
|
424,138,351
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
749,978,331
|
|
|
$
|
279,225,009
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of these statements.
3
Crusader Energy Group Inc.
CONSOLIDATED STATEMENT OF OPERATIONS (see Note 1)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Unaudited)
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
OPERATING REVENUES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas sales
|
|
$
|
19,461,726
|
|
|
$
|
5,236,783
|
|
|
$
|
40,291,425
|
|
|
$
|
14,789,573
|
|
Oil sales
|
|
|
13,682,006
|
|
|
|
5,508,222
|
|
|
|
35,337,557
|
|
|
|
12,127,594
|
|
Other
|
|
|
368,873
|
|
|
|
271,747
|
|
|
|
1,097,661
|
|
|
|
614,319
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating revenue
|
|
|
33,512,605
|
|
|
|
11,016,752
|
|
|
|
76,726,643
|
|
|
|
27,531,486
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OPERATING COSTS AND EXPENSES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating
|
|
|
3,176,995
|
|
|
|
1,102,303
|
|
|
|
6,227,443
|
|
|
|
2,347,783
|
|
Production taxes
|
|
|
2,531,769
|
|
|
|
763,536
|
|
|
|
5,303,388
|
|
|
|
1,766,532
|
|
General and administrative
|
|
|
3,227,305
|
|
|
|
952,426
|
|
|
|
113,599,183
|
|
|
|
2,715,870
|
|
Depreciation, depletion and amortization
|
|
|
10,885,522
|
|
|
|
4,523,575
|
|
|
|
22,392,645
|
|
|
|
11,809,640
|
|
Accretion of asset retirement obligations
|
|
|
20,637
|
|
|
|
21,471
|
|
|
|
48,181
|
|
|
|
32,823
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs and expenses
|
|
|
19,842,228
|
|
|
|
7,363,311
|
|
|
|
147,570,840
|
|
|
|
18,672,648
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
13,670,377
|
|
|
|
3,653,441
|
|
|
|
(70,844,197
|
)
|
|
|
8,858,838
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OTHER (EXPENSE) INCOME
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(8,283,932
|
)
|
|
|
(862,468
|
)
|
|
|
(11,384,422
|
)
|
|
|
(1,797,650
|
)
|
Interest income and other
|
|
|
480,469
|
|
|
|
24,862
|
|
|
|
603,926
|
|
|
|
68,182
|
|
Risk management
|
|
|
19,008,980
|
|
|
|
832,160
|
|
|
|
(1,197,988
|
)
|
|
|
115,030
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other (expenses) income
|
|
|
11,205,517
|
|
|
|
(5,446
|
)
|
|
|
(11,978,484
|
)
|
|
|
(1,614,438
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before income taxes
|
|
|
24,875,894
|
|
|
|
3,647,995
|
|
|
|
(82,822,681
|
)
|
|
|
7,244,400
|
|
|
Income tax expense
|
|
|
8,456,038
|
|
|
|
|
|
|
|
20,282,862
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET INCOME (LOSS)
|
|
$
|
16,419,856
|
|
|
$
|
3,647,995
|
|
|
$
|
(103,105,543
|
)
|
|
$
|
7,244,400
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EARNINGS (LOSS) PER SHARE
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and Diluted
|
|
$
|
0.08
|
|
|
|
|
|
|
$
|
(0.77
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
WEIGHTED AVERAGE SHARES OUTSTANDING
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
198,194,958
|
|
|
|
|
|
|
|
134,469,036
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
209,973,306
|
|
|
|
|
|
|
|
134,469,036
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
PRO FORMA INFORMATION (NOTE 2)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Historical income (loss) from operations
before income taxes
|
|
|
|
|
|
$
|
3,647,995
|
|
|
|
|
|
|
$
|
7,244,400
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma provision (benefit) for income taxes
|
|
|
|
|
|
|
1,419,070
|
|
|
|
|
|
|
|
2,818,072
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income (loss)
|
|
|
|
|
|
$
|
2,228,925
|
|
|
|
|
|
|
$
|
4,426,328
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
PRO FORMA EARNINGS PER SHARE
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and Diluted
|
|
|
|
|
|
$
|
0.02
|
|
|
|
|
|
|
$
|
0.04
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
WEIGHTED AVERAGE SHARES OUTSTANDING
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and Diluted
|
|
|
|
|
|
|
100,100,000
|
|
|
|
|
|
|
|
100,100,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of these statements.
4
Crusader Energy Group Inc.
Consolidated Statement of Members/Stockholders Equity (see Note 1)
(Unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common Stock
|
|
|
Additional
|
|
|
|
|
|
|
Total
|
|
|
|
Members
|
|
|
Number of
|
|
|
$.01 Par
|
|
|
Paid In
|
|
|
Accumulated
|
|
|
Stockholders
|
|
|
|
Equity
|
|
|
Shares
|
|
|
Value
|
|
|
Capital
|
|
|
Deficit
|
|
|
Equity
|
|
Balance as of January 1, 2008
|
|
$
|
191,320,454
|
|
|
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
191,320,454
|
|
Net loss through June 25, 2008
|
|
|
(2,059,723
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(2,059,723
|
)
|
Effect of business combination with Westside Energy Corp.
|
|
|
(189,260,731
|
)
|
|
|
198,194,958
|
|
|
|
1,981,950
|
|
|
|
412,204,785
|
|
|
|
|
|
|
|
224,926,004
|
|
Stock compensation
|
|
|
|
|
|
|
370,000
|
|
|
|
3,700
|
|
|
|
110,993,736
|
|
|
|
|
|
|
|
110,997,436
|
|
Net loss, June 26, 2008 through September 30, 2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(101,045,820
|
)
|
|
|
(101,045,820
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of September 30, 2008
|
|
$
|
|
|
|
|
198,564,958
|
|
|
$
|
1,985,650
|
|
|
$
|
523,198,521
|
|
|
$
|
(101,045,820
|
)
|
|
$
|
424,138,351
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of these statements.
5
Crusader Energy Group Inc.
CONSOLIDATED STATEMENT OF CASH FLOWS (see Note 1)
|
|
|
|
|
|
|
|
|
|
|
(Unaudited)
|
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
|
2008
|
|
|
2007
|
|
Cash flows from operating activities
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
(103,105,543
|
)
|
|
$
|
7,244,400
|
|
Adjustments to reconcile net income (loss) to net cash
provided by operating activities, net of effect of
business combinations:
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization
|
|
|
22,392,645
|
|
|
|
11,809,640
|
|
Accretion of asset retirement obligations
|
|
|
48,181
|
|
|
|
32,823
|
|
Amortization of loan costs
|
|
|
1,337,556
|
|
|
|
11,796
|
|
Amortization of loan discount
|
|
|
520,833
|
|
|
|
|
|
Deferred income taxes
|
|
|
20,282,862
|
|
|
|
|
|
Stock compensation
|
|
|
106,860,370
|
|
|
|
|
|
Change in assets and liabilities
(Increase) decrease in
Accounts receivable
|
|
|
(5,643,913
|
)
|
|
|
(5,914,097
|
)
|
Derivative financial instruments
|
|
|
(3,153,638
|
)
|
|
|
2,535,426
|
|
Prepaid assets and other
|
|
|
(5,055,685
|
)
|
|
|
(254,919
|
)
|
Increase (decrease) in
Accounts payable, accrued liabilities and other
|
|
|
(16,724,092
|
)
|
|
|
(124,344
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
17,759,576
|
|
|
|
15,340,725
|
|
|
|
|
|
|
|
|
|
|
Cash flows used in investing activities
|
|
|
|
|
|
|
|
|
Acquisitions of businesses, net of cash acquired
|
|
|
1,660,233
|
|
|
|
|
|
Proceeds from sale of oil and gas property
|
|
|
250,000
|
|
|
|
|
|
Oil and gas property costs
|
|
|
(137,629,827
|
)
|
|
|
(53,039,505
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(135,719,594
|
)
|
|
|
(53,039,505
|
)
|
|
|
|
|
|
|
|
|
|
Cash flows from financing activities
|
|
|
|
|
|
|
|
|
Payment of loan costs
|
|
|
(5,634,250
|
)
|
|
|
(291,957
|
)
|
Payments on debt borrowings
|
|
|
(157,209,553
|
)
|
|
|
|
|
Proceeds from debt borrowings
|
|
|
300,500,000
|
|
|
|
38,750,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
137,656,197
|
|
|
|
38,458,043
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET INCREASE IN CASH AND
CASH EQUIVALENTS
|
|
|
19,696,179
|
|
|
|
759,263
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at beginning of period
|
|
|
7,941,663
|
|
|
|
5,122,383
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of period
|
|
$
|
27,637,842
|
|
|
$
|
5,881,646
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid during period for interest
|
|
$
|
4,440,859
|
|
|
$
|
1,233,000
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of these statements.
6
Crusader Energy Group Inc.
CONSOLIDATED STATEMENT OF CASH FLOWS CONTINUED
(Unaudited)
Noncash investing and financing activities
:
During 2008 and 2007, the Company recorded a net asset and related liability of $384,922 and
$252,732 associated with the asset retirement obligations on oil and gas properties (see Note 6).
The amounts recorded in 2008 included $238,380 assumed in the business acquisitions (see Note 1).
At September 30, 2008 and 2007, accounts payable and accrued liabilities consisted of $28,624,829
and $14,802,511 related to oil and gas acquisition and development costs, respectively.
On June 26, 2008, in conjunction with the business acquisitions (see Note 1), the estimated fair
market values of the assets acquired and liabilities assumed were as follows:
|
|
|
|
|
Estimated fair value of assets acquired:
|
|
|
|
|
Current assets
|
|
$
|
38,426,589
|
|
Oil and gas properties
|
|
|
297,651,522
|
|
Other long-term assets
|
|
|
3,434,576
|
|
|
|
|
|
Total fair value of assets
|
|
|
339,512,687
|
|
Liabilities:
|
|
|
|
|
Current liabilities
|
|
|
46,186,108
|
|
Note payable
|
|
|
34,650,225
|
|
Deferred income taxes, net
|
|
|
28,728,695
|
|
Other long-term liabilities
|
|
|
318,428
|
|
|
|
|
|
Net value of assets acquired
|
|
$
|
229,629,231
|
|
|
|
|
|
The accompanying notes are an integral part of these statements.
7
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 1: Nature of Operations and Acquisition of Businesses
Knight Energy Group, LLC (Knight) was formed on August 29, 2006, and its major operations
consist of the exploration for and acquisition, production, and sale of crude oil and natural gas
with an area of concentration in Oklahoma and Texas. On December 31, 2007, Westside Energy
Corporation (Westside), a public company traded on the American Stock Exchange, entered into a
definitive agreement to combine with several affiliated privately-held entities, including
Knight, Knight Energy Group II, LLC (Knight II), RCH Upland Acquisition, LLC (RCH), Hawk
Energy Fund I, LLC (Hawk) and other entities acquired (consisting of Knight Energy Management,
LLC, Crusader Energy Group, LLC and Crusader Management Corporation) (with Knight II, Hawk, RCH
and the other entities acquired collectively referred to as the Crusader Entities). On June 26,
2008, the business combination contemplated by the contribution agreement (the Westside
Transaction) was completed and Westside changed its name to Crusader Energy Group Inc.
(Crusader or the Company). For accounting purposes, the Westside Transaction was treated as
a reverse acquisition with Knight as the acquirer and Westside and the Crusader Entities as the
acquired parties, as described more fully below. As such, the historical financial statements
of Crusader are Knights historical financial statements. The acquisitions have been accounted
for using the purchase method and the results of operations for Westside and Crusader Entities
are included subsequent to June 26, 2008. The accompanying financial statements include the
Companys accounts and the accounts of its wholly owned subsidiaries. All intercompany accounts
and transactions have been eliminated in consolidation.
The aggregate purchase price paid by Knight in the Westside Transaction was approximately
$229,629,000, consisting of unregistered common stock (valued at the closing price ($2.27) of
Westside common stock on January 2, 2008, the announcement date of the Westside Transaction),
cash and warrants assumed (see table below). The operations of the acquired entities consist
of the exploration for and acquisition, production and sale of crude oil and natural gas with an
area of concentration in Oklahoma and Texas. Knight completed the business combinations for the
following reasons:
|
|
|
additional opportunities to exploit its horizontal drilling expertise;
|
|
|
|
|
attractive acreage in areas such as the Barnett Shale in the Fort Worth Basin, Bakken
Shale in the Williston Basin and various shale plays in the Permian Basin;
|
|
|
|
|
expected synergies (elimination of Westside general and administrative expenses and
Knight II management fee);
|
|
|
|
|
appealing route to becoming a publicly traded company; and
|
|
|
|
|
enhanced access to public markets to execute its business strategy.
|
8
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 1: Nature of Operations and Acquisition of Businesses Continued
The preliminary allocation of the purchase price and the estimated fair market values of the
assets acquired and liabilities assumed are subject to modification and are shown below. The
purchase price allocation is preliminary because certain items, such as the determination of the
final tax bases and the fair value of certain assets and liabilities as of the acquisition date,
have not been completed.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Preliminary calculation and allocation of
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other
|
|
|
purchase price:
|
|
Westside
|
|
Knight II
|
|
Hawk
|
|
RCH
|
|
Entities
|
|
Total
|
|
|
|
Shares of common stock issued
|
|
|
26,471,274
|
|
|
|
53,223,684
|
|
|
|
14,700,000
|
|
|
|
3,700,000
|
|
|
|
|
|
|
|
98,094,958
|
|
Westside closing stock price
|
|
$
|
2.27
|
|
|
$
|
2.27
|
|
|
$
|
2.27
|
|
|
$
|
2.27
|
|
|
$
|
2.27
|
|
|
$
|
2.27
|
|
|
|
|
Fair value of common stock issued
|
|
$
|
60,089,792
|
|
|
$
|
120,817,763
|
|
|
$
|
33,369,000
|
|
|
$
|
8,399,000
|
|
|
$
|
|
|
|
$
|
222,675,555
|
|
Plus cash consideration
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
501,000
|
|
|
|
501,000
|
|
Plus merger cost
|
|
|
1,133,986
|
|
|
|
2,280,015
|
|
|
|
629,724
|
|
|
|
158,502
|
|
|
|
|
|
|
|
4,202,227
|
|
Plus warrants assumed
|
|
|
2,250,449
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,250,449
|
|
|
|
|
Total purchase price
|
|
|
63,474,227
|
|
|
|
123,097,778
|
|
|
|
33,998,724
|
|
|
|
8,557,502
|
|
|
|
501,000
|
|
|
|
229,629,231
|
|
Plus fair value of liabilities assumed:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current liabilities
|
|
|
5,673,233
|
|
|
|
31,340,279
|
|
|
|
9,101,959
|
|
|
|
70,637
|
|
|
|
|
|
|
|
46,186,108
|
|
Note payable
|
|
|
34,650,225
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
34,650,225
|
|
Deferred income taxes
|
|
|
13,686,849
|
|
|
|
326,551
|
|
|
|
11,083,779
|
|
|
|
3,631,516
|
|
|
|
|
|
|
|
28,728,695
|
|
Other long-term liabilities
|
|
|
146,660
|
|
|
|
44,823
|
|
|
|
97,945
|
|
|
|
29,000
|
|
|
|
|
|
|
|
318,428
|
|
|
|
|
Total purchase price plus liabilities assumed
|
|
$
|
117,631,194
|
|
|
$
|
154,809,431
|
|
|
$
|
54,282,407
|
|
|
$
|
12,288,655
|
|
|
$
|
501,000
|
|
|
$
|
339,512,687
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair value of assets acquired:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current assets
|
|
$
|
3,968,529
|
|
|
$
|
29,129,104
|
|
|
$
|
4,290,981
|
|
|
$
|
1,037,975
|
|
|
$
|
|
|
|
$
|
38,426,589
|
|
Oil and gas properties
|
|
|
113,647,665
|
|
|
|
122,836,424
|
|
|
|
49,916,753
|
|
|
|
11,250,680
|
|
|
|
|
|
|
|
297,651,522
|
|
Other long-term assets
|
|
|
15,000
|
|
|
|
2,843,903
|
|
|
|
74,673
|
|
|
|
|
|
|
|
501,000
|
|
|
|
3,434,576
|
|
|
|
|
Total fair value of assets acquired
|
|
$
|
117,631,194
|
|
|
$
|
154,809,431
|
|
|
$
|
54,282,407
|
|
|
$
|
12,288,655
|
|
|
$
|
501,000
|
|
|
$
|
339,512,687
|
|
|
|
|
9
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 1: Nature of Operations and Acquisition of Businesses Continued
The following summary presents unaudited pro forma consolidated results of operations for the
three and nine months ended September 30, 2008 and 2007, respectively, as if the acquisitions
comprising the Westside Transaction had occurred as of January 1, 2007. The pro forma results are
for illustrative purposes only and include adjustments in addition to the pre-acquisition
historical results, such as increased depreciation, depletion and amortization expense resulting
from the allocation of fair value to oil and gas properties acquired and change in tax status.
The unaudited pro forma information is not necessarily indicative of the operating results that
would have occurred if the acquisitions had been consummated at that date, nor is it necessarily
indicative of future operating results. During the nine months ended September 30, 2008, the
Company recognized $106,677,219 of compensation expense related to a significant, non-recurring
grant of stock options.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
|
|
Actual
|
|
|
Pro Forma
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Revenues
|
|
$
|
33,512,605
|
|
|
$
|
11,016,752
|
|
|
$
|
33,512,605
|
|
|
$
|
14,959,557
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations
|
|
|
13,670,377
|
|
|
|
3,653,441
|
|
|
|
13,670,377
|
|
|
|
6,251,676
|
|
Net income (loss)
|
|
|
16,419,856
|
|
|
|
2,228,925
|
|
|
|
16,419,856
|
|
|
|
2,419,002
|
|
Earnings per share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and Diluted
|
|
$
|
0.08
|
|
|
$
|
0.02
|
|
|
$
|
0.08
|
|
|
$
|
0.02
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Production volumes:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas (Mcf)
|
|
|
2,208,667
|
|
|
|
809,653
|
|
|
|
2,208,667
|
|
|
|
1,272,140
|
|
Oil (Bbls)
|
|
|
120,766
|
|
|
|
79,489
|
|
|
|
120,766
|
|
|
|
98,717
|
|
Mcfe
|
|
|
2,933,263
|
|
|
|
1,286,587
|
|
|
|
2,933,263
|
|
|
|
1,864,442
|
|
Mcfe/day
|
|
|
31,883
|
|
|
|
13,985
|
|
|
|
31,883
|
|
|
|
20,266
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30,
|
|
|
|
Actual
|
|
|
Pro Forma
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Revenues
|
|
$
|
76,726,643
|
|
|
$
|
27,531,486
|
|
|
$
|
90,295,326
|
|
|
$
|
37,250,908
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations
|
|
|
(70,844,197
|
)
|
|
|
8,858,838
|
|
|
|
(64,432,866
|
)
|
|
|
12,304,472
|
|
Net income (loss)
|
|
|
(103,105,543
|
)
|
|
|
4,426,328
|
|
|
|
(98,906,378
|
)
|
|
|
5,330,636
|
|
Earnings per share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and Diluted
|
|
$
|
(0.77
|
)
|
|
$
|
0.04
|
|
|
$
|
(0.74
|
)
|
|
$
|
0.05
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Production volumes:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas (Mcf)
|
|
|
4,373,077
|
|
|
|
2,213,065
|
|
|
|
5,832,085
|
|
|
|
3,431,416
|
|
Oil (Bbls)
|
|
|
318,693
|
|
|
|
191,554
|
|
|
|
343,237
|
|
|
|
229,200
|
|
Mcfe
|
|
|
6,285,235
|
|
|
|
3,362,389
|
|
|
|
7,891,507
|
|
|
|
4,806,616
|
|
Mcfe/day
|
|
|
22,939
|
|
|
|
12,316
|
|
|
|
28,801
|
|
|
|
17,607
|
|
10
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 2: Summary of Significant Accounting Policies
Interim Financial Statements
The accompanying unaudited interim financial statements of the Company have been prepared in
accordance with accounting principles generally accepted in the United States of America (GAAP)
for interim financial information and with the instructions to Form 10-Q as prescribed by the SEC
for smaller reporting companies and do not include all of the financial information and
disclosures required by GAAP. The financial information as of September 30, 2008 and for the
three and nine months ended September 30, 2008 and 2007 is unaudited. In the opinion of
management, such information contains all adjustments, consisting only of normal recurring
accruals, considered necessary for a fair presentation of the results of the interim periods. The
results of operations for the three and nine months ended September 30, 2008 are not necessarily
indicative of the results of operations that will be realized for the year ended December 31,
2008. The interim financial statements should be read in conjunction with the financial
statements as of December 31, 2007 and notes thereto, included in the proxy statement filed with
the SEC on May 28, 2008.
Use of Estimates
The preparation of financial statements in conformity with GAAP requires management to make
estimates and assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of the financial statements and the
reported amounts of revenues and expenses during the reporting period. Actual results could
differ from these estimates. Significant estimates affecting these financial statements include
estimates for quantities of proved oil and gas reserves, period end oil and gas sales and
expenses, and asset retirement obligations, and are subject to change.
Income Taxes
Pursuant to Statement of Financial Accounting Standards (SFAS) No. 109, Accounting for Income
Taxes, (SFAS No. 109) the Company follows the asset and liability method of accounting for
income taxes, under which the Company recognizes deferred tax assets and liabilities for the
future tax consequences attributable to differences between the financial statement carrying
amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets
and liabilities were measured using enacted tax rates expected to apply to taxable income in the
years in which the Company expects to recover or settle those temporary differences.
As changes in tax laws or rates are enacted, deferred income tax assets and liabilities are
adjusted through the provision for income taxes. Deferred tax assets are reduced by a valuation
allowance if, based on available evidence, it is more likely than not that some portion or all of
the deferred tax assets will not be realized. The classification of current and noncurrent
deferred tax assets and liabilities is based primarily on the classification of the assets and
liabilities generating the difference.
As a result of our conversion to a taxable corporation on June 26, 2008, as part of the Westside
Transaction, a charge to income tax provision of approximately $35,156,000 was made to record
deferred taxes for the differences between the tax basis and financial reporting basis of our
assets and liabilities.
11
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 2: Summary of Significant Accounting Policies Continued
Pro Forma Income Taxes
Prior to consummating the Westside Transaction (see Note 1), the Company (i.e. Knight) was a
limited liability company and classified as a partnership for income tax purposes. Accordingly,
income taxes on net earnings were payable by the members and are not reflected in historical
financial statements. Pro forma adjustments are reflected to provide for income taxes in
accordance with SFAS No. 109. For unaudited pro forma income tax calculations, deferred tax
assets and liabilities were recognized for the future tax consequences attributable to
differences between the assets and liabilities and were measured using enacted tax rates expected
to apply to taxable income in the years in which the Company expects to recover or settle those
temporary differences. The pro forma tax effects assume the Company had been a taxable entity in
the periods presented. Management believes that these assumptions provide a reasonable basis for
presenting the pro forma tax effects.
Earnings (Loss) Per Common Share
Basic earnings (loss) per common share is computed by dividing the net earnings (loss) applicable
to common stockholders by the weighted average number of common shares outstanding for the
period. Diluted earnings (loss) per share are based on the assumption that stock options and
warrants are converted into common shares using the treasury stock method. Conversion or exercise
is not assumed if the results are antidilutive.
Potential common shares of 35,000,000, 501,392 and 370,000 relating to options, warrants and
restricted stock, respectively, were excluded from the computations of diluted earnings (loss)
per share because they are antidilutive for the nine months ended September 30, 2008.
Pro Forma Earnings (Loss) Per Share
Pro forma earnings (loss) per basic and diluted common share is computed based on the weighted
average pro forma number of basic and diluted shares assumed to be outstanding during the
periods. Pro forma basic and diluted earnings (loss) per share is presented for the historical
three and nine months ended September 30, 2007 on the basis of 100,100,000 shares issued to
Knight in the Westside Transaction on June 26, 2008.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months
|
|
|
Three Months
|
|
|
Nine Months
|
|
|
Nine Months
|
|
|
|
Ended
|
|
|
Ended
|
|
|
Ended
|
|
|
Ended
|
|
|
|
September 30, 2008
|
|
|
September 30, 2007
|
|
|
September 30, 2008
|
|
|
September 30, 2007
|
|
Net income available to shareholders
|
|
$
|
16,419,856
|
|
|
$
|
2,228,925
|
|
|
$
|
(103,105,543
|
)
|
|
$
|
4,426,328
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares outstanding basic
|
|
|
198,194,958
|
|
|
|
100,100,000
|
|
|
|
134,469,036
|
|
|
|
100,100,000
|
|
Effect of dilutive securities stock options
|
|
|
11,347,189
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effect of dilutive securities warrants
|
|
|
365,513
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effect of dilutive securities restricted stock
|
|
|
65,645
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares outstanding diluted
|
|
|
209,973,306
|
|
|
|
100,100,000
|
|
|
|
134,469,036
|
|
|
|
100,100,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic net income per share
|
|
$
|
0.08
|
|
|
$
|
0.02
|
|
|
$
|
(0.77
|
)
|
|
$
|
0.04
|
|
Diluted net income per share
|
|
$
|
0.08
|
|
|
$
|
0.02
|
|
|
$
|
(0.77
|
)
|
|
$
|
0.04
|
|
12
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 2: Summary of Significant Accounting Policies Continued
Stock-based Compensation
SFAS No. 123(R), Share-Based Payment requires the Company to measure the costs of employee
services received in exchange for an award of equity instruments based on the grant-date fair
value of the award. That cost will be recognized over the period during which an employee is
required to provide service in exchange for the award.
The fair value of each stock option grant is estimated on the date of grant using the
Black-Scholes options-pricing model with the following assumptions used for grants in 2008: no
expected dividends, volatility ranging from 54% to 50%, risk-free interest rates ranging from
2.36% to 3.34% and expected lives ranging from 1 year to 4 years. The volatility assumptions were
developed using a peer group of similar energy companies and our stock price. The weighted
average fair value of the options issued in 2008 was $3.17. Based upon the provisions of the
grant, no future service was required and as such, the total fair value of the grant was
recognized during the second quarter of 2008.
The fair value of restricted stock awards issued is determined based on the fair market value of
the shares on the date of grant. The Company granted 370,000 shares of restricted stock during
the third quarter, with a grant date fair value of $3.30 per share. The fair value of the award
is amortized ratably over the vesting period. The shares will vest at the rate of 30%, 30%, and
40% on January 1, 2009, 2010, and 2011, respectively.
Oil and Natural Gas Properties
We perform a review of the carrying value of our oil and natural gas properties, referred to as a
ceiling test, under the full-cost accounting rules of the SEC on a quarterly basis. Under the
ceiling test, capitalized costs, less accumulated amortization and related deferred income taxes,
may not exceed an amount equal to the sum of the present value of estimated future net revenues
less estimated future expenditures to be incurred in developing and producing the proved
reserves, less any related income tax effects. Future net revenues are calculated by using the
current prices and costs as of the end of the appropriate quarterly period.
Recently Issued Accounting Standards
In March 2008, the FASB issued SFAS No. 161,
Disclosures about Derivative Instruments and Hedging
Activitiesan amendment of FASB Statement No. 133
(SFAS No. 161). SFAS No. 161 requires
additional disclosures about derivative and hedging activities and is effective for fiscal years
and interim periods beginning after November 15, 2008. The Company is evaluating the impact the
adoption of SFAS No. 161 will have on its financial statement disclosures. However, the Companys adoption of SFAS No. 161 will not affect
its current accounting for derivative and hedging activities.
In December 2007, the FASB issued SFAS No. 141(R),
Business Combinations
. This statement requires
assets acquired and liabilities assumed to be measured at fair value as of the acquisition date,
acquisition-related costs incurred prior to the acquisition to be expensed and contractual contingencies to be recognized
at fair value as of the acquisition date. This statement is effective for financial statements
issued for fiscal years beginning after December 15, 2008. The Company is currently assessing
the impact, if any, the adoption of this statement will have on our financial position, results
of operations or cash flows.
13
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 3: Notes Payable
Notes payable consisted of the following at September 30 and December 31:
|
|
|
|
|
|
|
|
|
|
|
2008
|
|
|
2007
|
|
Revolving line of credit with Union Bank of California
(UBOC), bearing interest at an adjusted rate as defined
in the agreement (6.05% and 7.07% at September 30, 2008
and December 31, 2007) payable quarterly, principal and
any unpaid interest due October 4, 2010, collateralized
by the Companys oil and gas properties.
|
|
$
|
|
|
|
$
|
37,000,000
|
|
|
|
|
|
|
|
|
|
|
Subordinated term facility with UnionBancal Equities,
Inc. an
affiliate of UBOC, quarterly interest due at an adjusted
rate as defined in the agreement (10.07% at December 31,
2007), retired in July 2008.
|
|
|
|
|
|
|
30,000,000
|
|
|
|
|
|
|
|
|
|
|
2
nd
lien term facility with JPMorgan Chase
Bank, N.A., as administrative agent, bearing interest at
an adjusted rate as defined in the agreement (11.25% at
September 30, 2008) payable quarterly, principal and any
unpaid interest due on July 18, 2013, collateralized by a
second mortgage on the Companys oil and gas properties
|
|
|
249,750,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Discount on 2
nd
lien facility (5% discount on total issuance)
|
|
|
(11,979,167
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
237,770,833
|
|
|
$
|
67,000,000
|
|
|
|
|
|
|
|
|
During the second quarter of 2008, the Companys loan agreement was amended to provide for a
revolving line of credit equal to the lesser of $200,000,000 or the borrowing base, as defined,
and a subordinated term facility equal to $30,000,000, which was retired in the third quarter.
The borrowing base was re-determined and was increased to $100,000,000. Additionally, the
variable borrowing rate, as defined, was adjusted and generally calls for the London Interbank
Offered Rate (LIBOR) plus 2.00% on the revolving line of credit and LIBOR plus 5.00% on the
subordinated term facility.
On July 18, 2008 (Effective Date), the Company entered into a five-year $250,000,000 second
lien term facility with JPMorgan Chase Bank, N.A., as administrative agent. Under the terms of
the second lien agreement, the Company received loan proceeds net of a discount in the amount of
5% of the total issuance. The second lien term facility replaced our existing $30,000,000 second lien term facility with
UnionBanCal Equities, Inc.
The second lien term loan facility bears interest at the lesser of: (a) LIBOR (subject to a floor
of 3.50%) plus 7.75% or (b) the reference rate, as defined, plus 6.75%. The second lien facility
has the following prepayment premium on principal amounts prepaid equal to: (i) the Applicable
Premium, as defined, if the prepayment is made from the Effective Date through the first
anniversary thereof, (ii) 5% if the prepayment is made from the first anniversary of the
Effective Date through the second anniversary thereof, (iii) 3% if the prepayment is made from
the second anniversary of the Effective Date through the third anniversary thereof, (iv) 1% if
the prepayment is made from the third anniversary of the Effective Date through the fourth
anniversary thereof and (v) 0% thereafter.
14
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 3: Notes Payable Continued
The second lien term facility proceeds were used to refinance a portion of the outstanding debt
under the revolving line of credit with UBOC and to retire the subordinated term facility and
will be used to fund the Companys drilling activity, acquisitions, and general corporate
purposes. In connection with this transaction, the revolving line of credit was amended to equal
the lesser of $140,000,000 or the borrowing base, as defined, and the borrowing base was reduced
to $70,000,000. The reduction in the loan commitment and borrowing base was a result of one of
our participating banks leaving the syndication. As a result, the Company expensed deferred
financing costs related to its previous revolving and term credit facilities of approximately
$1,100,000 as a loss on debt extinguished. This loss is included in interest expense during the
third quarter of 2008.
The Companys debt agreements have certain financial covenants which provide for, among other
things, maintaining a certain current ratio (excluding fair value of derivative financial
instruments), minimum reserve coverage and leverage ratio, and certain reporting requirements, as
defined. The Company was in compliance with the financial covenants as of September 30, 2008 and
December 31, 2007.
Note 4: Derivative Transactions
SFAS No. 133,
Accounting for Derivative Instruments and Hedging Activities
, as amended, requires
that the Company recognize a derivative as either an asset or a liability measured at fair value.
The accounting for changes in the fair value of a derivative depends on the use of the
derivative and the resulting designation. Derivatives that are not hedges or not elected to be
considered as hedges must be adjusted to fair value through income. If the derivative is a
hedge, depending on the nature of the hedge, changes in the fair value of derivatives will either
be offset against the change in fair value of the hedged assets, liabilities or firm commitments
through income or recognized in other comprehensive income until the hedged item is recognized in
income. The ineffective portion of a hedges change in fair value will be immediately recognized
in income.
Natural Gas and Oil Derivatives
The results of operations and operating cash flows are impacted by changes in market prices for
oil and gas. To mitigate a portion of this exposure, the Company has entered into certain
derivative instruments, none of which were elected to be designated as cash flow hedges. As of
September 30, 2008 and 2007, the Companys derivative instruments are generally comprised of
collars, fixed price swaps, premium puts and basis protection swaps.
Collars contain a fixed floor price (put) and ceiling price (call). If the market price exceeds
the call strike price or falls below the put strike price, the Company receives the fixed price
and pays the market price. If the market price is between the call and the put strike price, no
payments are due from either party.
Premium puts contain a fixed floor price (put). If the market price falls below the put strike
price, the Company receives the fixed price and pays the market price.
15
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 4: Derivative Transactions Continued
In fixed-price swap instruments, the Company receives a fixed-price for the hedged commodity and
pays a floating market price to the counterparty. The fixed-price payment and the floating-price
payment are netted, resulting in a net amount due to or from the counterparty.
Basis protection swaps are arrangements that guarantee a price differential for natural gas from
a specified delivery point. For Mid-Continent basis protection swaps, which have negative
differentials to NYMEX, the Company receives a payment from the counterparty if the price
differential is greater than the stated terms of the contract and pays the counterparty if the
price differential is less than the stated terms of the contract.
Concentration of Credit Risk
The derivative transactions mentioned above expose the Company to credit risk from our
counterparties. To mitigate this risk, we enter into these transactions only with
investment-grade rated counterparties that management believes to be competent and competitive
firms. Currently, concerns have arisen regarding the ability of certain investment banks to
continue to meet their financial obligations. The Company does not believe that a failure by a
counterparty would have a material negative impact on our liquidity. Also, the counterparties in
our derivative contracts are parties to our credit facilities.
As of September 30, 2008, the Company has the following hedging transactions with two financial
counterparties in the form of costless collars, fixed-price swaps, premium puts and basis
protection swaps:
Natural Gas Production
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Collars
|
|
Swaps
|
|
Puts
|
Year
|
|
Month
|
|
MCF
|
|
Floor
|
|
Ceiling
|
|
MCF
|
|
|
|
MCF
|
|
Floor
|
2008
|
|
Oct - Dec
|
|
|
937,000
|
|
|
$
|
8.10
|
|
|
$
|
10.58
|
|
|
|
30,000
|
|
|
$
|
7.45
|
|
|
|
45,450
|
|
|
$
|
8.00
|
|
2009
|
|
Jan - Mar
|
|
|
678,500
|
|
|
$
|
8.13
|
|
|
$
|
10.12
|
|
|
|
|
|
|
$
|
|
|
|
|
259,131
|
|
|
$
|
8.00
|
|
2009
|
|
Apr - Jun
|
|
|
441,000
|
|
|
$
|
8.00
|
|
|
$
|
9.56
|
|
|
|
|
|
|
$
|
|
|
|
|
259,131
|
|
|
$
|
8.00
|
|
2009
|
|
Jul - Dec
|
|
|
882,000
|
|
|
$
|
8.00
|
|
|
$
|
9.56
|
|
|
|
|
|
|
$
|
|
|
|
|
518,262
|
|
|
$
|
8.00
|
|
2010
|
|
Jan - Dec
|
|
|
|
|
|
$
|
|
|
|
$
|
|
|
|
|
|
|
|
$
|
|
|
|
|
2,144,988
|
|
|
$
|
8.00
|
|
Oil Production
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Collars
|
Year
|
|
Month
|
|
Bbls
|
|
Floor
|
|
Ceiling
|
2008
|
|
Oct - Dec
|
|
|
56,280
|
|
|
$
|
77.74
|
|
|
$
|
88.00
|
|
2009
|
|
Jan - Dec
|
|
|
163,200
|
|
|
$
|
79.56
|
|
|
$
|
117.72
|
|
2010
|
|
Jan - Dec
|
|
|
115,200
|
|
|
$
|
100.00
|
|
|
$
|
161.75
|
|
Basis Differential Swap
|
|
|
|
|
|
|
|
|
|
|
|
|
Year
|
|
Month
|
|
MCF
|
|
ANR
|
2008
|
|
Oct - Dec
|
|
|
435,000
|
|
|
$
|
1.11
|
|
2009
|
|
Jan - Dec
|
|
|
1,560,000
|
|
|
$
|
0.76
|
|
16
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 4: Derivative Transactions Continued
Interest Rate Derivatives
The Company uses interest rate derivatives to mitigate its exposure to the volatility in interest
rates, none of which were elected to be designated as hedges. Changes in the fair value of
non-designated derivatives that occur prior to their maturity (i.e., temporary fluctuations in
value) are reported currently in the consolidated statements of operations as unrealized gains
(losses) as risk management income (expense).
As of September 30, 2008, the following interest rate derivatives were outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
Average
|
|
|
|
|
Notional
|
|
Fixed
|
|
Floating
|
|
|
Amount
|
|
Rate
|
|
Rate
|
Floating to Fixed Swaps:
|
|
|
|
|
|
|
|
|
|
|
|
|
August 2008 February 2011
|
|
$
|
250,000,000
|
|
|
|
3.71
|
%
|
|
3 month LIBOR
|
These instruments (natural gas, oil and interest rate derivatives) are recorded at fair value and
changes in fair value, including settlements, have been reported as risk management income
(expense) in the consolidated statement of operations. Settlements on these instruments occur
every three months. The effective rate of long-term debt was 11.46% at September 30, 2008. The
following table provides a summary of the components (cash and non-cash) of risk management
income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
|
Nine Months Ended September 30,
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Gains (losses) from:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Settlements with counterparty
|
|
$
|
(2,924,126
|
)
|
|
$
|
1,406,438
|
|
|
$
|
(5,228,022
|
)
|
|
$
|
2,694,152
|
|
Changes in fair value premiums paid
|
|
|
3,170,962
|
|
|
|
|
|
|
|
3,170,962
|
|
|
|
|
|
Changes in fair value non-cash
|
|
|
20,485,840
|
|
|
|
(574,278
|
)
|
|
|
2,582,768
|
|
|
|
(2,579,122
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total oil and gas derivatives
|
|
|
20,732,676
|
|
|
|
832,160
|
|
|
|
525,708
|
|
|
|
115,030
|
|
Settlements with counterparty
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Changes in fair value
|
|
|
(1,723,696
|
)
|
|
|
|
|
|
|
(1,723,696
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total interest rate derivatives
|
|
|
(1,723,696
|
)
|
|
|
|
|
|
|
(1,723,696
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total risk management income (expense)
|
|
$
|
19,008,980
|
|
|
$
|
832,160
|
|
|
$
|
(1,197,988
|
)
|
|
$
|
115,030
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
17
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 4: Derivative Transactions Continued
Fair Value Measurements
SFAS No. 157,
Fair Value Measurements
(as amended) (SFAS No. 157), defines fair value,
establishes a framework for measuring fair value, outlines a fair value hierarchy based on inputs
used to measure fair value and enhances disclosure requirements for fair value measurements. The
Company has not applied the provisions of SFAS No. 157 to nonrecurring, nonfinancial assets and
liabilities as allowed under FASB Staff Position No. 157-2.
Fair value is defined as the price at which an asset could be exchanged in a current transaction
between knowledgeable, willing parties. A liabilitys fair value is defined as the amount that
would be paid to transfer the liability to a new obligor, not the amount that would be paid to
settle the liability with the creditor. Where available, fair value is based on observable market
prices or parameters or derived from such prices or parameters. Where observable prices or inputs
are not available, use of unobservable prices or inputs are used to estimate the current fair
value, often using an internal valuation model. These valuation techniques involve some level of
management estimation and judgment, the degree of which is dependent on the item being valued.
Beginning January 1, 2008, assets and liabilities recorded at fair value in the consolidated
balance sheets are categorized based upon the level of judgment associated with the inputs used
to measure their fair value. Hierarchical levelsdefined by SFAS No. 157 and directly related to
the amount of subjectivity associated with the inputs to fair valuation of these assets and
liabilitiesare as follows:
Level IInputs are unadjusted, quoted prices in active markets for identical assets or
liabilities at the measurement date.
Level IIInputs (other than quoted prices included in Level I) are either directly or
indirectly observable for the asset or liability through correlation with market data at the
measurement date and for the duration of the instruments anticipated life.
Level IIIInputs reflect managements best estimate of what market participants would use in
pricing the asset or liability at the measurement date. Consideration is given to the risk
inherent in the valuation technique and the risk inherent in the inputs to the model.
The fair value of our derivative contracts are measured using Level II inputs, and are determined
by either market prices on an active market for similar assets or by prices quoted by a broker or
other market-corroborated prices, including analysis of formal pricing curves on national
exchanges.
Our asset retirement obligation is measured using primarily Level III inputs. The significant
unobservable inputs to this fair value measurement include estimates of plugging and abandonment
costs, inflation rate and well life. The inputs are calculated based on historical data as well
as current estimated costs. See Note 6 for a rollforward of the asset retirement obligation.
18
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 4: Derivative Transactions Continued
The estimated fair values of derivatives included in the consolidated balance sheets at September
30, 2008 and December 31, 2007 are summarized below. The decrease in the net derivative liability
from December 31, 2007 to September 30, 2008 is primarily attributable to the effect of lower
natural gas and oil prices, partially offset by cash settlements of derivatives during the period
and new derivatives entered during the period.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair Value Measurements
|
|
|
|
September 30, 2008
|
|
|
December 31, 2007
|
|
|
|
Significant
|
|
|
|
|
|
|
Significant
|
|
|
|
|
|
|
Other
|
|
|
Significant
|
|
|
Other
|
|
|
Significant
|
|
|
|
Observable
|
|
|
Unobservable
|
|
|
Observable
|
|
|
Unobservable
|
|
|
|
Inputs
|
|
|
Inputs
|
|
|
Inputs
|
|
|
Inputs
|
|
|
|
(Level 2)
|
|
|
(Level 3)
|
|
|
(Level 2)
|
|
|
(Level 3)
|
|
Derivative assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas basis protection swaps
|
|
$
|
843,300
|
|
|
$
|
|
|
|
$
|
1,475,042
|
|
|
$
|
|
|
Natural gas derivative instruments
|
|
|
4,031,573
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil derivative instruments
|
|
|
1,498,867
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Derivative liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural gas derivative instruments
|
|
|
|
|
|
|
|
|
|
|
(41,470
|
)
|
|
|
|
|
Oil derivative instruments
|
|
|
(2,326,382
|
)
|
|
|
|
|
|
|
(3,613,072
|
)
|
|
|
|
|
Interest rate instruments
|
|
|
(1,723,696
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net derivative asset (liability)
|
|
$
|
2,323,662
|
|
|
$
|
|
|
|
$
|
(2,179,500
|
)
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asset retirement obligation
|
|
$
|
|
|
|
$
|
1,151,419
|
|
|
$
|
|
|
|
$
|
718,316
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 5: Stockholders Equity
In connection with the acquisition as described in Note 1, Crusader issued 171,723,684 million
shares of unregistered common stock to the following entities: Knight Energy Group I Holding
Co., LLC received 100,100,000 shares, Knight Energy Group II Holding Company, LLC received
53,223,684 shares, Hawk Energy Fund I Holding Company, LLC received 14,700,000 shares and RCH
Energy Opportunity Fund I, L.P. received 3,700,000 shares. None of the shares may be sold or
otherwise transferred until December 26, 2008.
19
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 5: Stockholders Equity Continued
Additionally, Crusader assumed 501,392 warrants in the acquisition of Westside and their fair
value were estimated using the Black-Scholes options-pricing model. A summary of the outstanding
warrants and the assumptions used to estimate their fair value are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Black
|
|
|
|
Number of
|
|
|
Exercise
|
|
Remaining
|
|
Risk Free
|
|
|
|
|
|
Expected
|
|
Scholes
|
|
Estimated
|
|
Warrants
|
|
|
Price
|
|
Term
|
|
Rate
|
|
Volatility
|
|
Dividend
|
|
Value
|
|
Fair Value
|
|
166,392
|
|
|
$
|
0.50
|
|
|
|
2/28/2009
|
|
|
|
2.36
|
%
|
|
|
58.50
|
%
|
|
None
|
|
$
|
5.15
|
|
|
$
|
856,573
|
|
|
100,000
|
|
|
$
|
0.50
|
|
|
|
5/7/2009
|
|
|
|
2.36
|
%
|
|
|
55.27
|
%
|
|
None
|
|
$
|
5.15
|
|
|
|
515,008
|
|
|
235,000
|
|
|
$
|
2.00
|
|
|
|
10/29/2009
|
|
|
|
2.63
|
%
|
|
|
52.53
|
%
|
|
None
|
|
$
|
3.74
|
|
|
|
878,868
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
501,392
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
2,250,449
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The Company has the following stock-based compensation plans:
2004 Consultant Plan
The Consultant Plan provides for the granting of shares of common stock to certain outside
consultants who assisted in the development and success of Westsides business. There are
3,000,000 shares of common stock authorized to be awarded pursuant to the plan, of which 500,000
were registered with the SEC. The plan expires on April 15, 2014, or when no further shares are
available for issuance, whichever comes first. As a result of the business combination as
described in Note 1, any then outstanding awards under the plan either became fully vested or
were forfeited due to the change in control. Any vested shares were included in the common stock
issued to Westside and treated as business combination consideration, as no future service was
required. No grants have been made since June 26, 2008.
2005 Director Stock Plan
The Director Stock Plan provides for the granting of shares of common stock to non-employee
members of the Board of Directors to provide them with incentives for their service to the
Company. There are 500,000 shares of common stock authorized to be awarded pursuant to this
plan. Awards may be made under the plan until there are no further shares available for issuance
or until March 30, 2015, whichever occurs first. Under the plan, each non-employee director
receives a certain number of shares upon becoming a director, and annual awards thereafter,
provided that the individual is still a director of the Company. Certain of the awards are also
subject to time vesting, also provided that the individual is still a director of the Company.
Effective January 1, 2008, the Board determined to cease making grants under this plan and now
may make grants to non-employee directors at such times and in such amounts as the Board
determines appropriate. As a result of the business combination as described in Note 1, any then
outstanding awards under the plan either became fully vested or were forfeited due to the change
in control. Any vested shares were included in the common stock issued to Westside and treated
as business combination consideration, as no future service was required. No grants have been
made since June 26, 2008.
2007 Equity Incentive Plan
The Equity Incentive Plan provides for the granting of incentive stock options, non-qualified
options, stock grants and stock-based awards to attract and retain the services of employees,
consultants, and directors of the Company and its subsidiaries. There are 2,000,000 shares
authorized to be awarded under the plan. The plan has a termination date of July 9, 2017. As a
result of the business combination as described in Note 1, any then outstanding awards under the
plan either became fully vested or were forfeited due to the change in control.
20
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 5: Stockholders Equity Continued
Any vested shares were included in the common stock issued to Westside and treated as business
combination consideration, as no future service was required. No grants have been made since
June 26, 2008.
2008 Long Term Incentive Plan
The Long Term Incentive Plan provides for the granting of incentive stock options, non-qualified
options, restricted stock awards, restricted stock units, and stock appreciation rights to
attract and retain employees, directors, and consultants of the Company. The plan was approved
by the shareholders of Westside on June 26, 2008. There are 37,310,000 shares authorized to be
awarded under the plan.
Stock Options
Pursuant to this plan and in connection with the acquisitions described in Note 1, Crusader
issued options to purchase 35,000,000 shares of common stock, exercisable at $3.00 per share, to
certain employees. The exercise price was determined at December 31, 2007, concurrent with the
execution of the contribution agreement setting forth the terms of the business combination. The
outstanding options vested immediately upon issuance and expire 4.5 years from the date of grant.
Pursuant to the terms of the grant, the options are subject to a mandatory exercise program of
25% each year beginning in 2009.
The following table provides information related to stock option activity during the current
quarter:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
Number of
|
|
|
Average
|
|
|
Weighted
|
|
|
|
|
|
|
Shares
|
|
|
Exercise
|
|
|
Average
|
|
|
Aggregate
|
|
|
|
Underlying
|
|
|
Price
|
|
|
Contract
|
|
|
Intrinsic
|
|
|
|
Options
|
|
|
Per Share
|
|
|
Life in Years
|
|
|
Value(a)
|
|
Outstanding at January 1, 2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Issued
|
|
|
35,000,000
|
|
|
$
|
3.00
|
|
|
|
4.50
|
|
|
$
|
92,400,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding at September 30, 2008
|
|
|
35,000,000
|
|
|
$
|
3.00
|
|
|
|
4.25
|
|
|
$
|
3,500,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Exercisable at September 30, 2008
|
|
|
35,000,000
|
|
|
$
|
3.00
|
|
|
|
4.25
|
|
|
$
|
3,500,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a) The intrinsic value of a stock option is the amount by which the current market value or
the market value upon exercise of the underlying
stock option exceeds the exercise price of
the option.
21
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 5: Stockholders Equity Continued
Restricted Shares
Pursuant to this plan, Crusader granted 370,000 shares of restricted stock to certain employees
on September 18, 2008. Restricted share activity as of September 30, 2008 was as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
Average
|
|
|
|
Shares
|
|
|
Fair Value
|
|
Outstanding at December 31, 2007
|
|
|
|
|
|
$
|
|
|
Granted
|
|
|
370,000
|
|
|
|
3.30
|
|
Vested
|
|
|
|
|
|
|
|
|
Forfeited
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding at September 30, 2008
|
|
|
370,000
|
|
|
$
|
3.30
|
|
|
|
|
|
|
|
|
|
As of September 30, 2008, total unrecognized stock-based compensation expense related to
non-vested restricted shares was approximately $1,038,000, which is expected to be recognized
over a weighted average period of approximately 2.25 years.
To the extent compensation cost relates to employees directly involved in natural gas and oil
exploration and development activities, such amounts are capitalized to natural gas and oil
properties which totaled approximately $27,000 and $4,164,000, during the three and nine months
ended September 30, 2008, respectively. Amounts not capitalized are recognized as general and
administrative expenses and totaled approximately $156,000 and $106,833,000 during the three and
nine months ended September 30, 2008, respectively.
Note 6: Asset Retirement Obligation
The Companys asset retirement obligations relate to estimated future plugging and abandonment
expenses or disposal of its oil and gas properties and related facilities. These obligations to
abandon and restore properties are based upon estimated future costs which may change based upon
future inflation rates and changes in statutory remediation rules. The following table provides
a summary of the Companys asset retirement obligations:
|
|
|
|
|
|
|
Nine Months
|
|
|
|
Ended September
|
|
|
|
30, 2008
|
|
Balance as of December 31, 2007
|
|
$
|
718,316
|
|
Liabilities incurred in current period
|
|
|
146,542
|
|
Liabilities assumed in business combination
|
|
|
238,380
|
|
Accretion expense
|
|
|
48,181
|
|
Balance as
of September 30, 2008
|
|
$
|
1,151,419
|
|
22
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 7: Income Taxes
Income tax expense consists of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
|
Nine Months Ended September 30,
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Current taxes
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
Deferred taxes
|
|
|
8,456,038
|
|
|
|
|
|
|
|
20,282,862
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income tax expense
|
|
$
|
8,456,038
|
|
|
$
|
|
|
|
$
|
20,282,862
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income tax assets and liabilities are as follows:
|
|
|
|
|
|
|
|
|
|
|
September 30,
|
|
|
December 31,
|
|
|
|
2008
|
|
|
2007
|
|
Deferred tax assets:
|
|
|
|
|
|
|
|
|
Net operating loss carryforwards
|
|
$
|
26,360,649
|
|
|
$
|
|
|
Stock option expense
|
|
|
25,289,212
|
|
|
|
|
|
Derivatives
|
|
|
318,001
|
|
|
|
|
|
Other
|
|
|
2,784,346
|
|
|
|
|
|
|
|
|
|
|
|
|
Total deferred tax assets
|
|
$
|
54,752,208
|
|
|
$
|
|
|
|
Deferred tax liabilities:
|
|
|
|
|
|
|
|
|
Property and equipment, principally
due to differences in depreciation
|
|
|
(103,975,810
|
)
|
|
|
|
|
|
|
|
|
|
|
|
Net deferred tax liabilities
|
|
$
|
(49,223,602
|
)
|
|
$
|
|
|
|
|
|
|
|
|
|
Upon the conversion from a limited liability company to a corporation in conjunction with
becoming a public company, the Company incurred a one-time charge to operations in the second
quarter of 2008 of approximately $36,156,000 to record deferred taxes upon change in tax status.
In assessing its ability to realize deferred tax assets, the Company considers whether it is more
likely than not that some portion or all of the deferred tax assets will not be realized. The
ultimate realization of deferred tax assets depends on the generation of future taxable income
during the periods in which those temporary differences become deductible. The Company considers
the scheduled reversal of deferred tax liabilities and projected future taxable income in making
this assessment. The Company believes it is more likely than not that it will realize the
benefits of these deductible differences.
23
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 7: Income Taxes Continued
The provision for income taxes on continuing operations differs from the amounts computed by
applying the federal income tax rate of 35% to net income (loss). The differences are summarized
as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
|
Nine Months Ended September 30,
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Expected tax expense (benefit)
|
|
$
|
8,706,563
|
|
|
$
|
|
|
|
$
|
(28,987,938
|
)
|
|
$
|
|
|
State income taxes
|
|
|
694,037
|
|
|
|
|
|
|
|
(2,368,729
|
)
|
|
|
|
|
Conversion to corporation
|
|
|
|
|
|
|
|
|
|
|
35,156,421
|
|
|
|
|
|
Non-deductible stock compensation expenses
|
|
|
(195,130
|
)
|
|
|
|
|
|
|
16,368,867
|
|
|
|
|
|
Other
|
|
|
(749,432
|
)
|
|
|
|
|
|
|
114,241
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
8,456,038
|
|
|
$
|
|
|
|
$
|
20,282,862
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 8: Related Party Transactions
Prior to the Westside Transaction on June 26, 2008, general and administrative expenses and a fee
for usage of property and equipment (including furniture and fixtures, office furniture and
fixtures and vehicles) were charged to the Company monthly from a related entity, Crusader
Management Corporation (CMC). During the nine months ended September 30, 2008, the Company
incurred approximately $4,035,000 for its share of expenses related to the personnel services
agreement executed with CMC. During the three and nine months ended September 30, 2007, the
Company incurred approximately $1,151,000 and $2,089,000, respectively. Upon closing the
acquisition as described in Note 1, CMC became a wholly-owned subsidiary of the Company.
Included in joint interest billings at December 31, 2007 was approximately $6,261,000, owed by
affiliates. Upon closing the acquisition as described in Note 1, the affiliates became
wholly-owned subsidiaries of the Company.
Note 9: Commitments and Contingencies
Prior to the Westside Transaction on June 26, 2008, the Company executed a personnel services
agreement with CMC to provide all management, employee and other administrative services as
necessary from time to time to operate the business of the Company. Upon closing the acquisition
as described in Note 1, CMC became a wholly-owned subsidiary of the Company, and the existing
personnel services agreement was terminated and a new personnel services agreement was entered
into between the Company and CMC.
CMC has a retirement plan covering substantially all qualified employees under section 401(k) of
the Internal Revenue Code with a matching policy to contribute for each participant a required
matching contribution equal to 100% of the participants contribution up to 4% of each employees
annual compensation and 50% of the participants contribution on the next 2% of each employees
annual compensation. CMCs contributions vest immediately. Knight and Crusaders expenses under
the plan were approximately $58,200, and $25,000 and $151,200 and $74,600 for the three and nine
months ended September 30, 2008 and 2007, respectively, which were a component of the cost
allocated through the CMC personnel services agreement (see Note 8).
24
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 9: Commitments and Contingencies Continued
On December 28, 2007, CMC entered into an agreement with Le Norman Properties, LLC, to lease
approximately 24,000 net square feet of office space located in Oklahoma City, Oklahoma for an
initial term of five years. Le Norman Properties is wholly-owned by David D. Le Norman, who is a
director, president and chief executive officer of the Company. The Company assumed the
obligations under this lease. The lease calls for annual base rent of $624,000 plus expenses
related to maintenance, taxes, insurance and utilities. The Company has an option to renew the
lease for two additional five year terms for a base rent in an amount equal to the fair market
rent for comparable buildings in the area.
The following table summarizes the Companys future minimum payments under non-cancellable
operating lease agreements at September 30, 2008:
|
|
|
|
|
Year ending December 31
|
|
|
|
|
2008
|
|
$
|
156,000
|
|
2009
|
|
|
624,000
|
|
2010
|
|
|
624,000
|
|
2011
|
|
|
624,000
|
|
2012
|
|
|
624,000
|
|
Thereafter
|
|
|
156,000
|
|
|
|
|
|
|
|
$
|
2,808,000
|
|
|
|
|
|
The Company acquired an unsecured Revolving Note and an exploration agreement with Alpine Energy,
LP (Alpine) as a result of acquiring Knight II. The unsecured Revolving Note has a maturity
date of September 30, 2010. Under the terms of the note and subject to approval by the Company,
Alpine may borrow up to $10,000,000 at a floating interest rate equal to the ninety day LIBOR
plus 4.00% per annum. At September 30, 2008, the outstanding balance of $10,000,000 was included
in other assets in the consolidated balance sheets. The interest rate at September 30, 2008 was
7.93%. Interest is due and payable monthly, in arrears, on the first day of each month. As a
condition to the agreement, Alpine must use all advances from the note for expenditures related
to certain prospects, as defined in the agreement. If Alpine fails to repay the note, the
Companys only source of repayment is limited to the oil and gas sales from certain oil and gas
properties, as defined in the agreement.
The Alpine exploration agreement, covering certain prospects, calls for monthly payments of
$200,000 through June 2009. Future commitments related to this agreement are as follows:
$600,000 for the remainder of the year 2008 and $1,200,000 for the year ended December 31, 2009.
Unsecured Standby Letters of Credit (Letters) are used in lieu of surety bonds with various
city, state and federal agencies for liabilities of the operation of oil and gas properties and
to our derivative counter party. The Company had various Letters outstanding totaling $1,270,000
as of September 30, 2008, which were issued by a bank where our cash and cash equivalents reside.
25
Crusader Energy Group Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS CONTINUED
(Unaudited)
Note 9: Commitments and Contingencies Continued
The Company is involved in certain litigation arising in the normal course of business.
Management does not believe that the outcome of these matters will have a material impact on the
financial position or results of operations of the Company.
Note 10: Subsequent Events
In October 2008, the Company entered into the following derivative instruments to raise or
eliminate the ceiling on the following collars (instruments not indicating a premium were
cashless transactions):
|
|
|
11,200 barrels of oil per month from October 2008 through December 2008 with a
original ceiling of $67.00 and was increased to $71.60 per Bbl;
|
|
|
|
|
6,000 barrels of oil per month from October 2008 through December 2008 with a
original ceiling of $92.00 and was increased to $99.90 per Bbl;
|
|
|
|
|
60,000 MCF of gas per month from October 2008 through December 2008 with a original
ceiling of $8.00 and was increased to $10.10 per MCF;
|
|
|
|
|
Removed the ceiling on 1,000 MCF of gas per day from January 2009 through March 2009
with a original ceiling of $12.50 per MCF with a total premium of $11,250;
|
|
|
|
|
Removed the ceiling on 2,500 MCF of gas per day from January 2009 through February
2009 with a original ceiling of $10.35 per MCF with a total premium of $33,925;
|
|
|
|
|
4,000 barrels of oil per month from January 2009 through December 2009 with a
original ceiling of $80.00 and was increased to $102.65 per Bbl;
|
|
|
|
|
6,000 barrels of oil per month from January 2009 through December 2009 with a
original ceiling of $67.00 and was increased to $79.00 per Bbl;
|
|
|
|
|
17,000 MCF of gas per month from January 2009 through December 2009 with a original
ceiling of $8.00 and was increased to $10.05 per MCF;
|
|
|
|
|
130,000 MCF of gas per month from January 2009 through December 2009 with a original
ceiling of $9.50 and was increased to $10.00 per MCF with a total premium of $195,000;
and
|
|
|
|
|
Removed the ceiling on 17,000 MCF of gas per day from January 2009 through December
2009 with a original ceiling of $10.05 per MCF with a total premium of $96,900.
|
26
Item 2. Managements Discussion and Analysis of Financial Condition and Results of Operations.
You should read the following information together with the information presented elsewhere in
this Quarterly Report on Form 10-Q and with the audited financial statements as of December 31,
2007 and notes thereto, included in the proxy statement filed with the Securities and Exchange
Commission (SEC) on May 28, 2008.
Overview
Crusader is an oil and gas company with assets focused in various producing domestic basins.
The Company has a primary focus on the development of unconventional resource plays which includes
the application of horizontal drilling and cutting edge completion technology aimed at developing
shale and tight sand reservoirs. The Crusader assets are located in various domestic basins, the
majority of which are in the Anadarko Basin and Central Uplift, Ft. Worth Basin Barnett Shale,
Delaware Basin, Val Verde Basin, and the Bakken Shale of the Williston Basin.
Segment reporting is not applicable to Crusader as it has a single company-wide management
team that administers all properties as a whole rather than by discrete operating segments.
Crusader tracks only basic operational data by area. Crusader does not maintain complete separate
financial statement information by area. Crusader measures financial performance as a single
enterprise and not on an area-by-area basis. Crusader seeks to increase reserves and production
through internally generated drilling projects, coupled with complementary acquisitions. Crusader
uses the full cost method of accounting for its oil and gas activities.
On December 31, 2007, Westside Energy Corporation (Westside), a public company traded on the
American Stock Exchange, entered into a definitive agreement to combine with several affiliated
privately-held entities, including Knight, Knight Energy Group II, LLC (Knight II), RCH Upland
Acquisition, LLC (RCH), Hawk Energy Fund I, LLC (Hawk) and other entities acquired (consisting
of Knight Energy Management, LLC, Crusader Energy Group, LLC and Crusader Management Corporation)
(with Knight II, Hawk, RCH and the other entities acquired collectively referred to as the
Crusader Entities). On June 26, 2008, the business combination contemplated by the contribution
agreement (the Westside Transaction) was completed and Westside changed its name to Crusader
Energy Group Inc. (Crusader or the Company). For accounting purposes, the Westside Transaction
was treated as a reverse acquisition with Knight as the acquirer and Westside and the Crusader
Entities as the acquired parties. As such, the historical financial statements of Crusader are
Knights historical financial statements which were included in the proxy statement filed with the
Securities and Exchange Commission on May 28, 2008. The acquisitions have been accounted for using
the purchase method and the results of operations for Westside and Crusader Entities are included
subsequent to June 26, 2008.
The aggregate purchase price paid by Knight in the Westside Transaction was approximately
$229.6 million, consisting of unregistered common stock (valued at the closing price ($2.27) of
Westside common stock on January 2, 2008, the announcement date of the Westside Transaction), cash
and warrants assumed. The contribution agreement also called for certain Crusader employees to
receive stock options totaling 35 million shares with an exercise price of $3.00 which were granted
on June 26, 2008 and resulted in a non-cash stock compensation expense of approximately $106.7
million. When the contribution agreement was executed in December 2007 and the grant of 35 million
options to management at an exercise price of $3.00 was agreed to, Westside stock closed at $1.92
per share; 36% below the $3.00 strike price. In addition, because the market price of the Westside
stock was above $3.00 per share at closing, rather than being exercisable immediately, the options
are exercisable over 4 years beginning in 2009. We believe that the structuring of managements
consideration and incentive in the form of stock options benefits the combined Company by resulting
in the contribution of $105.0 million in capital to the Company in the event all of the options are
exercised and aligning the interests of our employees, management team and stockholders.
27
The operations of Westside and the Crusader Entities consist of the acquisition, exploration,
production and sale of crude oil and natural gas currently with an area of production concentration
in Oklahoma and Texas. Knight completed the business combinations for the following reasons:
|
|
|
additional opportunities to transfer its horizontal drilling expertise;
|
|
|
|
|
attractive acreage in areas such as the Barnett Shale in the Fort Worth Basin, Bakken
Shale in the Williston Basin and various shale plays in the Permian Basin;
|
|
|
|
|
expected synergies (elimination of Westside G&A and Knight II management fee);
|
|
|
|
|
appealing route to becoming a publicly-traded company; and
|
|
|
|
|
enhanced access to public markets to execute its business strategy.
|
The following summary presents unaudited pro forma consolidated production volumes for the three
and nine months ended September 30, 2008 and 2007, respectively, as if the acquisitions comprising
the Westside Transaction had occurred as of January 1, 2007. The pro forma results are for
illustrative purposes only. The unaudited pro forma information is not necessarily indicative of
the operating results that would have occurred if the acquisitions had been consummated at that
date, nor is it necessarily indicative of future operating results.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
|
|
Actual
|
|
|
Pro Forma
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Production volumes
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas (Mcf)
|
|
|
2,208,667
|
|
|
|
809,653
|
|
|
|
2,208,667
|
|
|
|
1,272,140
|
|
Oil (Bbl)
|
|
|
120,766
|
|
|
|
79,489
|
|
|
|
120,766
|
|
|
|
98,717
|
|
Total (Mcfe*)
|
|
|
2,933,263
|
|
|
|
1,286,587
|
|
|
|
2,933,263
|
|
|
|
1,864,442
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30,
|
|
|
|
Actual
|
|
|
Pro Forma
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Production volumes
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas (Mcf)
|
|
|
4,373,077
|
|
|
|
2,213,065
|
|
|
|
5,832,085
|
|
|
|
3,431,416
|
|
Oil (Bbl)
|
|
|
318,693
|
|
|
|
191,554
|
|
|
|
343,237
|
|
|
|
229,200
|
|
Total (Mcfe*)
|
|
|
6,285,235
|
|
|
|
3,362,389
|
|
|
|
7,891,507
|
|
|
|
4,806,616
|
|
|
|
|
*
|
|
Oil and NGLs are converted to Mcfe at the rate of one barrel equals six Mcfe.
|
28
Revenue and Expense Drivers
Revenue Drivers
Crude Oil and Natural Gas Sales.
Crusaders revenues are generated from production of crude
oil and natural gas which are substantially dependent on prevailing prices. Crusaders future
production is impacted by its drilling success, acquisitions and decline curves on existing
production. Prices for oil and gas are subject to large fluctuations in response to relatively
minor changes in the supply of or demand for oil and gas, market uncertainty and a variety of
additional factors beyond Crusaders control. Crusader enters into derivative instruments for a
portion of its oil and gas production to achieve a more predictable cash flow and to reduce its
exposure to adverse fluctuations in the prices of oil and gas.
Crusader generally sells its oil and gas at current market prices determined at the wellhead.
Crusader is required to pay gathering and transportation costs with respect to substantially all of
its products. Crusader markets its products in several different ways depending upon a number of
factors, including the availability of purchasers for the product at the wellhead, the availability
and cost of pipelines near the well, market prices, pipeline constraints and operational
flexibility. Also see Risk Management below which discusses Crusaders mitigation of some of the
price risk associated with oil and natural gas sales.
Operating Expenses
Crusaders operating expenses primarily involve the expense of operating and maintaining its
wells.
|
|
|
Lease Operating.
Crusaders lease operating expenses include repair
and maintenance costs, contract labor and supervision, workover costs,
electrical power and fuel costs and other expenses necessary to
maintain its operations. Crusaders lease operating expenses are
driven in part by the type of commodity produced, the level of
maintenance activity and the geographical location of its properties.
Ad valorem taxes represent property taxes.
|
|
|
|
|
Production Taxes.
Production taxes represent the taxes paid on
produced oil and gas based on a percentage of market prices (price
received from purchaser) or at fixed rates established by federal,
state or local taxing authorities.
|
|
|
|
|
General and Administrative Expenses.
General and administrative
expenses include employee compensation and benefits, professional fees
for legal, accounting and other advisory services and corporate
overhead.
|
|
|
|
|
Depreciation, Depletion and Amortization.
Depreciation, depletion and
amortization represent the expensing of the capitalized costs of
Crusaders oil and gas properties, using a units of production method,
and Crusaders other property and equipment.
|
Other Expenses and Income
Other Expenses and Income consist of the following:
Interest Income
. Crusader generates interest income from its cash deposits.
Interest Expense.
Crusaders interest expense reflects its borrowing costs under its revolving
line of credit and its subordinated term facility.
Risk Management.
The results of operations and operating cash flows are impacted by changes in
market prices for oil and gas and interest rates. To mitigate a portion of this exposure, Crusader
has entered into certain derivative instruments which have not been elected to be designated as
cash flow hedges for financial reporting purposes. Generally, Crusaders derivative instruments are
comprised of collars, fixed price swaps or premium puts as defined by the instrument.
These instruments are recorded at fair value and changes in fair value, including settlements, have
been reported as risk management in the statement of operations.
Oil and Natural Gas Properties Impact of Petroleum Prices on Ceiling Test
We review the carrying value of our oil and natural gas properties under the full-cost
accounting rules of the SEC on a quarterly and annual basis. This review is referred to as a
ceiling test. Under the ceiling test, capitalized costs, less accumulated amortization and related
deferred
29
income taxes, may not exceed an amount equal to the sum of the present value of estimated
future net revenues less estimated future expenditures to be incurred in developing and producing
the proved reserves, less any related income tax effects. Any excess of the net book value, less
deferred income taxes, is generally written off as an expense.
In calculating future net revenues, prices and costs used are those as of the end of the
appropriate quarterly period. Based on spot prices for oil and natural gas as of September 30,
2008, we had a significant cushion in the ceiling test. If the September 30, 2008 spot prices for
oil and natural gas were substituted with $65 per bbl and $6 per mcf and the ceiling test at
September 30, 2008 was recomputed, our cushion was reduced however an impairment did not occur.
Currently, it is not possible to determine what the calculated ceiling will be for future quarter
periods. The calculated ceiling at December 31, 2008 will be based on estimated proved reserves as
of that date and the associated commodity prices, including regional price differentials, operating
expenses and future development costs on that date.
Three Months Ended September 30, 2008 Compared to Three Months Ended September 30, 2007
Results of Operations
The following schedule reflects the historical operations of Crusader for the three months
ended September 30, 2008 and 2007, respectively. The operations of the acquired entities
(Westside, Knight II, Hawk, RCH and the other entities acquired) are included in the historical
operations subsequent to June 27, 2008.
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
|
|
2008
|
|
|
2007
|
|
OPERATING REVENUES
|
|
|
|
|
|
|
|
|
Gas sales
|
|
$
|
19,461,726
|
|
|
$
|
5,236,783
|
|
Oil sales
|
|
|
13,682,006
|
|
|
|
5,508,222
|
|
Other
|
|
|
368,873
|
|
|
|
271,747
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating revenue
|
|
|
33,512,605
|
|
|
|
11,016,752
|
|
|
|
|
|
|
|
|
|
|
OPERATING COSTS AND EXPENSES
|
|
|
|
|
|
|
|
|
Lease operating
|
|
|
3,176,995
|
|
|
|
1,102,303
|
|
Production taxes
|
|
|
2,531,769
|
|
|
|
763,536
|
|
General and administrative
|
|
|
3,227,305
|
|
|
|
952,426
|
|
Depreciation, depletion and amortization
|
|
|
10,885,522
|
|
|
|
4,523,575
|
|
Accretion of asset retirement obligations
|
|
|
20,637
|
|
|
|
21,471
|
|
|
|
|
|
|
|
|
Total operating costs and expenses
|
|
|
19,842,228
|
|
|
|
7,363,311
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from operations
|
|
|
13,670,377
|
|
|
|
3,653,441
|
|
|
|
|
|
|
|
|
|
|
OTHER (EXPENSE) INCOME
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(8,283,932
|
)
|
|
|
(862,468
|
)
|
Interest income and other
|
|
|
480,469
|
|
|
|
24,862
|
|
Risk management
|
|
|
19,008,980
|
|
|
|
832,160
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other (expense) income
|
|
|
11,205,517
|
|
|
|
(5,446
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
24,875,894
|
|
|
|
3,647,995
|
|
|
|
|
|
|
|
|
|
|
Income tax expense
|
|
|
8,456,038
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET INCOME
|
|
$
|
16,419,856
|
|
|
$
|
3,647,995
|
|
|
|
|
|
|
|
|
30
Revenues
. Revenues for the three months ended September 30, 2008 increased $22.5 million, to
$33.5 million as compared to $11.0 million for the three months ended September 30, 2007. Revenue
growth was due primarily to continued drilling success, increase of realized prices received and
activities related to the Westside Transaction. Production of oil and gas increased by 41,277 bbls
of oil and 1,399,014 Mcf of gas, respectively, (52% and 173%) during the same three month period in
2008 to 120,766 Bbls of oil and 2,208,667 Mcf of gas, respectively. Production related to acquiring
producing properties associated with the Westside Transaction amounted to approximately 9,300 Bbls
of oil and 783,000 Mcf of gas, respectively, which approximates 23% and 56% of the increase in oil
and gas production for the three months ended September 30, 2008.
The following table highlights production growth by certain projects.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months ended September 30,
|
|
|
|
|
|
|
|
|
|
|
2008
|
|
2007
|
Project
|
|
Operations
|
|
Basin
|
|
Mcf
|
|
Bbls
|
|
Mcf
|
|
Bbls
|
Cleveland Sand
|
|
Operated
|
|
Anadarko
|
|
|
481,888
|
|
|
|
55,881
|
|
|
|
236,489
|
|
|
|
33,171
|
|
SE Barnett
|
|
Operated
|
|
Ft. Worth
|
|
|
470,375
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Mayfield
|
|
Non-Operated
|
|
Anadarko
|
|
|
204,430
|
|
|
|
1,298
|
|
|
|
71,618
|
|
|
|
353
|
|
Eureka
|
|
Non-Operated
|
|
Anadarko
|
|
|
186,327
|
|
|
|
861
|
|
|
|
25,225
|
|
|
|
19
|
|
Lard Ranch
|
|
Non-Operated
|
|
Anadarko
|
|
|
166,081
|
|
|
|
2,916
|
|
|
|
167,496
|
|
|
|
3,317
|
|
Biscuit Hill
|
|
Operated
|
|
Anadarko
|
|
|
3,905
|
|
|
|
16,206
|
|
|
|
1,537
|
|
|
|
17,822
|
|
N. Barnett
|
|
Operated
|
|
Ft. Worth
|
|
|
154,808
|
|
|
|
16,570
|
|
|
|
61,068
|
|
|
|
12,328
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,667,814
|
|
|
|
93,732
|
|
|
|
563,433
|
|
|
|
67,010
|
|
Production from remaining projects
|
|
|
540,853
|
|
|
|
27,034
|
|
|
|
246,220
|
|
|
|
12,479
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total production for the period
|
|
|
2,208,667
|
|
|
|
120,766
|
|
|
|
809,653
|
|
|
|
79,489
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Prices received for oil and gas increased by 64% and 36%, respectively. The average sales
price for oil and gas for the three months ended September 30, 2008 were $113.29 per Bbl and $8.81
per Mcf, respectively, as compared to average sales price for oil and gas for the three months
ended September 30, 2007 of $69.30 per Bbl and $6.47 per Mcf, respectively. Comparatively, the
average NYMEX prices for oil and gas for the three months ended September 30, 2008 were $118.01 per
Bbl and $8.97 per Mcf, respectively. The average NYMEX prices for oil and gas for the
corresponding period in 2007 were $75.23 per Bbl and $6.25 per Mcf, respectively.
Lease Operating Expenses
. Lease operating expenses for the three months ended September 30,
2008 increased $2.1 million, or 188%, to $3.2 million as compared to $1.1 million for the three
months ended September 30, 2007 and increased 26% per Mcfe during the three months ended September
30, 2008 to $1.08 per Mcfe as compared to $0.86 per Mcfe during the three months ended September
30, 2007. The increase in lease operating expenses on a gross dollar basis is primarily a result of
increased well count, while the increase on an Mcfe basis was primarily due to increases in
produced water volumes and associated hauling and disposal costs related to oil production acquired
and to a lesser extent third-party vendor costs rising due to demand for services and general
increase in cost of fuel, raw materials, and labor during 2008 compared to 2007.
Production Taxes.
Production taxes for the three months ended September 30, 2008 increased
$1.7 million, or 232%, to $2.5 million as compared to $.8 million for the three months ended
September 30, 2007 due to increased oil and gas sales during 2008. Production taxes as a percentage of revenues were 7.6% and
7.1% for the three months ended September 30, 2008 and 2007, respectively.
General and Administrative Expenses
. G&A for the three months ended September 30, 2008
increased $2.2 million, or 239%, to $3.2 million as compared to $1.0 million for the three months
ended September 30, 2007. The increase in G&A was driven primarily by employee count and
employee-related costs as a result of hiring additional professional staff (petroleum engineers,
geologists, landmen and other professionals) which resulted in an increase of approximately 20
employees, awarding of annual compensation increases and increase in benefit costs (primarily
health insurance premiums) during the last half of 2007 and continuing into 2008 which totaled
approximately $1.3 million, an increase in professional fees of approximately $.5 million and an
increase in rent expense of $.3 million.
31
Depreciation, Depletion and Amortization
. DD&A for the three months ended September 30, 2008
increased $6.4 million, or 141%, to $10.9 million as compared to $4.5 million for the three months
ended September 30, 2007. DD&A on a per Mcfe basis for the three months ended September 30, 2008
increased 6% to $3.71 per Mcfe, as compared to $3.52 per Mcfe for the three months ended September
30, 2007. The gross increase in DD&A expense for the three months ended September 30, 2008 was due
to an increase in volumes.
Income from Operations.
Due to the factors described above, income from operations increased
$10.0 million, or 274%, to $13.7 million for the three months ended September 30, 2008 compared to
income from operations of $3.7 million for the three months ended September 30, 2007.
Other (Expense) Income
.
The increase in interest expense of approximately $7.4 million for the three months ended
September 30, 2008 compared to the same period in 2007 was a result of Knights weighted average
outstanding debt balance, for the respective periods, increasing from $54.8 million to $217.9
million.
The increase in risk management income for the three months ended September 30, 2008 compared
to the same period in 2007 was a result of the change in fair value of Knights open derivative
contracts during the respective periods, as a result of decreasing commodity prices and
expectations of commodity prices less than the prices in our derivative agreements.
Income before income taxes.
Due to the factors described above, income before income taxes
increased $21.3 million, or 582%, to $24.9 million for the three months ended September 30, 2008
compared to income before income taxes of $3.6 million for the three months ended September 30,
2007.
Income Tax Expense.
Increase in income tax expense was a result of a charge of approximately
$8.5 million related to deferred taxes generated during the quarter ended September 30, 2008.
During the 2007 quarter, the Company was reported as a partnership for income tax reporting
purposes and thus did not recognize any income tax expense.
Net Income
. Due to the factors described above, net income of $16.4 million was recognized
for the three months ended September 30, 2008 compared to net income of $3.6 million for the three
months ended September 30, 2007.
32
Nine Months Ended September 30, 2008 Compared to Nine Months Ended September 30, 2007
Results of Operations
The following schedule reflects the historical operations of Crusader for the nine months
ended September 30, 2008 and 2007, respectively. The operations of the acquired entities
(Westside, Knight II, Hawk, RCH and other entities acquired) are included in the historical
operations from June 27, 2008 to September 30, 2008.
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30,
|
|
|
|
2008
|
|
|
2007
|
|
OPERATING REVENUES
|
|
|
|
|
|
|
|
|
Gas sales
|
|
$
|
40,291,425
|
|
|
$
|
14,789,573
|
|
Oil sales
|
|
|
35,337,557
|
|
|
|
12,127,594
|
|
Other
|
|
|
1,097,661
|
|
|
|
614,319
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating revenue
|
|
|
76,726,643
|
|
|
|
27,531,486
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OPERATING COSTS AND EXPENSES
|
|
|
|
|
|
|
|
|
Lease operating
|
|
|
6,227,443
|
|
|
|
2,347,783
|
|
Production taxes
|
|
|
5,303,388
|
|
|
|
1,766,532
|
|
General and administrative
|
|
|
113,599,183
|
|
|
|
2,715,870
|
|
Depreciation, depletion and amortization
|
|
|
22,392,645
|
|
|
|
11,809,640
|
|
Accretion of asset retirement obligations
|
|
|
48,181
|
|
|
|
32,823
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs and expenses
|
|
|
147,570,840
|
|
|
|
18,672,648
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
(70,844,197
|
)
|
|
|
8,858,838
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OTHER (EXPENSE) INCOME
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(11,384,422
|
)
|
|
|
(1,797,650
|
)
|
Interest income and other
|
|
|
603,926
|
|
|
|
68,182
|
|
Risk management
|
|
|
(1,197,988
|
)
|
|
|
115,030
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other (expense) income
|
|
|
(11,978,484
|
)
|
|
|
(1,614,438
|
)
|
|
|
|
|
|
|
|
|
Income (loss) before income taxes
|
|
|
(82,822,681
|
)
|
|
|
7,244,400
|
|
Income tax expense
|
|
|
20,282,862
|
|
|
|
|
|
|
|
|
|
|
|
|
NET INCOME (LOSS)
|
|
$
|
(103,105,543
|
)
|
|
$
|
7,244,400
|
|
|
|
|
|
|
|
|
Revenues
. Revenues for the nine months ended September 30, 2008 increased $49.2 million, or
179%, to $76.7 million as compared to $27.5 million for the nine months ended September 30, 2007.
Revenue growth was due primarily to continued drilling success, increase of realized prices
received and production related to the Westside Transaction. Production of oil and gas increased by
127,139 bbls of oil and 2,160,012 Mcf of gas, respectively, (66% and 98%) during the same nine
month period in 2008 to 318,693 Bbls of oil and 4,373,077 Mcf of gas, respectively. Production
related to acquiring producing properties associated with the Westside Transaction amounted to
approximately 9,300 Bbls of oil and 783,000 Mcf of gas, respectively, which approximates 7% and 36%
of the increase in oil and gas production for the nine months ended September 30, 2008.
33
The following table highlights production growth by certain projects.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30,
|
|
|
|
|
|
|
|
|
|
|
2008
|
|
2007
|
Project
|
|
Operations
|
|
Basin
|
|
Mcf
|
|
Bbls
|
|
Mcf
|
|
Bbls
|
Cleveland Sand
|
|
Operated
|
|
Anadarko
|
|
|
1,204,923
|
|
|
|
145,480
|
|
|
|
580,060
|
|
|
|
81,506
|
|
Lard Ranch
|
|
Non-Operated
|
|
Anadarko
|
|
|
490,337
|
|
|
|
8,761
|
|
|
|
583,787
|
|
|
|
11,710
|
|
SE Barnett
|
|
Operated
|
|
Ft. Worth
|
|
|
470,375
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Eureka
|
|
Non-Operated
|
|
Anadarko
|
|
|
406,929
|
|
|
|
2,501
|
|
|
|
81,731
|
|
|
|
79
|
|
N. Barnett
|
|
Operated
|
|
Ft. Worth
|
|
|
381,144
|
|
|
|
47,342
|
|
|
|
93,834
|
|
|
|
18,360
|
|
Mayfield
|
|
Non-Operated
|
|
Anadarko
|
|
|
331,058
|
|
|
|
1,708
|
|
|
|
210,373
|
|
|
|
912
|
|
Biscuit Hill
|
|
Operated
|
|
Anadarko
|
|
|
12,831
|
|
|
|
59,644
|
|
|
|
5,576
|
|
|
|
55,819
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3,297,597
|
|
|
|
265,436
|
|
|
|
1,555,361
|
|
|
|
168,386
|
|
Production from remaining projects
|
|
|
1,075,480
|
|
|
|
53,257
|
|
|
|
657,704
|
|
|
|
23,168
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total production for the period
|
|
|
4,373,077
|
|
|
|
318,693
|
|
|
|
2,213,065
|
|
|
|
191,554
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Prices received for oil and gas increased by 75% and 38%, respectively. The average sales
price for oil and gas for the nine months ended September 30, 2008 were $110.88 per Bbl and $9.21
per Mcf, respectively, as
compared to average sales price for oil and gas for the nine months ended September 30, 2007
of $63.31 per Bbl and $6.68 per Mcf, respectively. Comparatively, the average NYMEX prices for oil
and gas for the nine months ended September 30, 2008 were $113.34 per Bbl and $9.74 per Mcf,
respectively. The average NYMEX prices for oil and gas for the corresponding period in 2007 were
$66.25 per Bbl and $7.03 per Mcf, respectively.
Lease Operating Expenses
. Lease operating expenses for the nine months ended September 30,
2008 increased $3.9 million, or 165%, to $6.2 million as compared to $2.3 million for the nine
months ended September 30, 2007 and increased 42% per Mcfe during the nine months ended September
30, 2008 to $.99 per Mcfe as compared to $.70 per Mcfe during the nine months ended September 30,
2007. The increase in lease operating expenses on a gross dollar basis is primarily a result of
increased well count, while the increase on an Mcfe basis was primarily due to increases in
produced water volumes and associated hauling and disposal costs related to oil production acquired
and to a lesser extent third-party vendor costs rising due to demand for services and general
increase in cost of fuel, raw materials, and labor during 2008 compared to 2007.
Production Taxes.
Production taxes for the nine months ended September 30, 2008 increased $3.5
million, or 200%, to $5.3 million as compared to $1.8 million for the nine months ended September
30, 2007 due to increased oil and gas sales during 2008. Production taxes as a percentage of
revenues were 7.0% and 6.6% for the nine months ended September 30, 2008 and 2007, respectively.
General and Administrative Expenses
. G&A for the nine months ended September 30, 2008
increased $110.9 million, or 4,083%, to $113.6 million as compared to $2.7 million for the nine
months ended September 30, 2007. The increase in G&A was driven primarily by a non-cash stock
compensation expense of approximately $106.9 million, employee count and employee-related costs as
a result of hiring additional professional staff (petroleum engineers, geologists, landmen and
other professionals) which resulted in an increase of approximately 20 employees, awarding of
annual compensation increases and increase in benefit costs (primarily health insurance premiums)
during the last half of 2007 and continuing into 2008 which totaled
approximately $2.5 million, an
increase in professional fees of approximately $.9 million and an increase in rent expense of $.3
million.
Depreciation, Depletion and Amortization
. DD&A for the nine months ended September 30, 2008
increased $10.6 million, or 90%, to $22.4 million as compared to $11.8 million for the nine months
ended September 30, 2007. DD&A on a per Mcfe basis for the nine months ended September 30, 2008
increased 1% to $3.56 per Mcfe, as compared to $3.51 per Mcfe for the nine months ended September
30, 2007. The gross increase in DD&A expense for the nine months ended September 30, 2008 was due
to an increase in volumes.
34
Income (loss) from Operations.
Due to the factors described above, loss from operations
increased $79.7 million, or 900%, to $(70.8) million for the nine months ended September 30, 2008
compared to income from operations of $8.9 million for the nine months ended September 30, 2007.
Excluding the effect of stock compensation expense, income from operations increased $27.1
million, or 307%, to $36.0 million for the nine months ended September 30, 2008 compared to the
nine months ended September 30, 2007.
Other (Expense) Income
.
The increase in interest expense for the nine months ended September 30, 2008 compared to the
same period in 2007 was a result of Knights weighted average outstanding debt balance, for the
respective periods, increasing from $54.8 million to $237.8 million.
The increase in risk management expense for the nine months ended September 30, 2008 compared
to the same period in 2007 was a result of the change in fair value of Knights open derivative
contracts during the respective periods, as a result of increasing commodity prices and
expectations of commodity prices less than the prices in our derivative agreements.
Income (loss) before income taxes.
Due to the factors described above, loss before income
taxes increased $90.1 million, or 1243%, to $(82.8) million for the nine months ended September 30,
2008 compared to income before income taxes of $7.2 million for the nine months ended September 30,
2007.
Income Tax Expense.
Increase in income tax expense was a result of a one-time charge of
approximately $35.2 million due to a change in tax status from a partnership to a corporation.
This was partially offset by the deferred tax benefit of
approximately $(16.4) million related to
stock option expense.
Net Income (Loss)
. Due to the factors described above, net loss of $(103.1) million was
recognized for the nine months ended September 30, 2008 compared to net income of $7.2 million for
the nine months ended September 30, 2007.
Excluding the effect of stock compensation expense and the change in tax status, net income of
$24.0 million would have been recognized for the nine months ended September 30, 2008, primarily
due to the increase in operating revenues (production and realized prices received) while operating
margins remained steady.
Liquidity and Capital Resources
Overview
Crusaders business is capital intensive. Historically, Crusader has funded its operations
through private equity offerings, bank debt and cash flows from operations. Our sources of cash
for the nine months ended September 30, 2008 were from operations and financing activities.
On July 18, 2008, the Company entered into a five-year $250.0 million second lien term
facility with JPMorgan Chase Bank, N.A., as administrative agent. The second lien term facility
replaced our existing $30.0 million second lien term facility with UnionBanCal Equities, Inc. The
second lien term loan facility bears interest at the lesser of: (a) LIBOR (subject to a floor of
3.50%) plus 7.75% or (b) the reference rate, as defined, plus 6.75% and matures on July 18, 2013.
The second lien term facility proceeds were used to refinance a portion of the outstanding
debt under the revolving line of credit with Union Bank of California and to retire the
subordinated term facilities and will be used to fund the Companys drilling activity, acquisitions
and general corporate purposes. In connection with this transaction, the revolving line of credit
was amended to equal the lesser of $140.0 million or the borrowing base, as defined and reduced the
borrowing base to $70.0 million. The reduction in the loan commitment and borrowing base was a
result of one of our participating banks leaving the syndication. As a result, the Company
expensed deferred financing costs related to its
35
previous revolving and term credit facilities of
approximately $1.1 million as a loss on debt extinguished during the third quarter of 2008.
Management is currently waiting for lenders approval related to a replacement and anticipates
the loan commitment to be increased to its original amount and borrowing base increased to
approximately $85 million when the replacement facility is closed.
Crusaders consummation of the $250.0 million second lien term facility and its availability
under the senior revolving line of credit (current borrowing base of
$70.0 million) is expected to
provide the necessary capital, along with cash flows generated from operating activities, to grow
our production, reserve base and enhance future cash flows from operating activities for the
foreseeable future.
Virtually all of Crusaders capital expenditures are made based on current economic conditions
and expected future oil and gas prices. Crusader monitors its exploration and development capital
expenditure levels according to liquidity and the other sources of operating capital as economic
conditions change. Currently, Crusader operates 6 drilling rigs, of which, only 1 rig is under
contract through the third quarter of 2009 with the remaining drilling rigs on a well by well
contract. As such, Crusader has the flexibility to reduce its capital expenditures if the current
pricing environment for petroleum products does not improve. Additionally, Crusader believes that
our non-operated drilling activity will decrease due to the recent cuts in capital expenditures
announced by others. We may also improve our liquidity and reduce future capital expenditures in
certain projects by either selling a portion of our working interest where we currently own a
working interest greater than 50% to a third party or by monetizing non-core assets.
Crusaders cash flows from operating activities are significantly affected by changes in oil
and gas prices. Accordingly, its cash flows from operating activities would be significantly
reduced by lower oil and gas prices, which may reduce its exploration and development capital
expenditure levels. Lower oil and gas prices also may reduce Crusaders borrowing base under its
senior credit facility which may further reduce its ability to obtain funds.
Consequently, in an effort to minimize fluctuations in Crusaders cash flows and to reduce its
exposure to adverse fluctuations in the prices of oil and gas, Crusader enters into derivative
instrument arrangements for a portion of its forecasted oil and gas production. Currently,
Crusader has hedged a portion of its oil and gas production through 2010. Additionally, based on
our third quarter 2008 production volumes, our hedges in place for the fourth quarter 2008 protect
approximately 42% of our gas volumes with an weighted average floor of $8.10 and approximately 47%
of our oil volumes with an weighted average floor of $77.74, respectively.
Cash Flows
Operating Activities.
For the nine months ended September 30, 2008, net cash provided by operating activities
increased $2.5 million to $17.8 million as compared to $15.3 million for the nine months ended
September 30, 2007. The increase in net cash provided by operating activities was primarily due to
increased production and commodity prices, partially offset by increased general and administrative
expense (employee count and professional fees), production taxes paid and general increase in lease
operating expenses due to well count and increased demand for services.
Investing Activities.
For the nine months ended September 30, 2008, net cash used in investing activities increased
$82.7 million, or 156%, to $135.7 million as compared to $53.0 million of net cash used in
investing activities for the nine months ended September 30, 2007. Net cash used in investing
activities in 2008 was comprised of $(1.7) million obtained in the
Westside Transaction, $(.3) million obtained in oil and gas property
divestitures and $137.6
million of expenditures on oil and gas properties as compared to $53.0 million of expenditures on
oil and gas properties in 2007. We participated in the drilling of 89 gross wells (37.34 net
wells), which includes 3 gross (2.57 net) injector wells, in the 2008 period compared to 55 gross
wells (15.33 net wells) in the 2007 period, respectively.
Financing Activities.
For the nine months ended September 30, 2008, net cash provided by financing activities
increased $99.2 million, or 258%, to $137.7 million as compared to $38.5 million of net cash
provided by financing activities for the nine months ended September 30, 2007. This increase was
due to increased borrowings related to our second lien term facility.
36
Critical Accounting Policies
Our
discussion and analysis of our financial condition and results of operations are based upon
the consolidated financial statements, which have been prepared in accordance with accounting
principles generally accepted in the United States of America. Preparation of these financial
statements requires us to make estimates and judgments that affect the reported amounts of assets,
liabilities, revenues and expenses. There have been no changes to our critical accounting policies
from those described in our audited financial statements for the year ended December 31, 2007, and
notes thereto, included in the proxy statement filed with the SEC on May 28, 2008.
Recently Issued Accounting Standards
In March 2008, the FASB issued SFAS No. 161,
Disclosures about Derivative Instruments and
Hedging Activitiesan amendment of FASB Statement No. 133
(SFAS No. 161). SFAS No. 161 requires
additional disclosures about derivative and hedging activities and is effective for fiscal years
and interim periods beginning after November 15, 2008. The Company is evaluating the impact the
adoption of SFAS No. 161 will have on its financial statement disclosures. However, the Companys
adoption of SFAS No. 161 will not affect its current accounting for derivative and hedging
activities.
In December 2007, the FASB issued SFAS No. 141(R),
Business Combinations
. This statement
requires assets acquired and liabilities assumed to be measured at fair value as of the acquisition
date, acquisition-related costs incurred prior to the acquisition to be expensed and contractual
contingencies to be recognized at fair value as of the acquisition date. This statement is effective for financial statements issued for
fiscal years beginning after December 15, 2008. We are currently assessing the impact, if any, the
adoption of this statement will have on our financial position, results of operations or cash
flows.
Item 3. Quantitative and Qualitative Disclosures about Market Risk.
Not applicable.
Item 4T. Controls and Procedures.
(a)
Evaluation of Disclosure Controls and Procedures
We maintain a set of disclosure controls and procedures designed to ensure that information
required to be disclosed by us in our reports filed under the Securities Exchange Act of 1934, as
amended (the Exchange Act), is recorded, processed, summarized and reported within the time
periods specified by SEC rules and forms. Disclosure controls are also designed with the objective
of ensuring that this information is accumulated and communicated to our management, including our
chief executive officer and chief financial officer, as appropriate, to allow timely decisions
regarding required disclosure. In designing and evaluating the disclosure controls and procedures,
management recognized that disclosure controls and procedures, no matter how well conceived and
operated, can provide only reasonable, not absolute, assurance that the objectives of the
disclosure controls and procedures are met. Additionally, in designing the disclosure controls and
procedures, our management was required to apply its judgment in evaluating the cost-benefit
relationship of possible disclosure controls and procedures.
Based on an evaluation as of the end of the period covered by this report, our Chief Executive
Officer and Chief Financial Officer concluded that our disclosure controls and procedures (as
defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) were effective to provide
reasonable assurance that information required to be disclosed by us in reports that we file or
submit under the Exchange Act is recorded, processed, summarized and reported within the time
periods specified in SEC rules and forms and that such information is accumulated and communicated
to our management, including our Chief Executive Officer and Chief Financial Officer, to allow
timely decisions regarding required disclosures.
37
(b)
Changes in Internal Controls
On June 26, 2008, the business combination with Westside and the Crusader Entities was
concluded. The Crusader Entities used the same accounting system and were supervised by the same
personnel as the Company. We are in the process of integrating Westsides accounting and other
information into our systems. As a result, we are reviewing our systems and controls to address
any changes required for changes in transaction volume or type. We believe we are taking the
necessary steps for our internal control environment to be effective.
PART II. OTHER INFORMATION
Item 1. Legal Proceedings
.
Not applicable.
Item 1A. Risk Factors
There have been no material changes to the risk factors described in our quarterly report on
Form 10-Q for the quarterly period ended June 30, 2008, except for the following which shall be
added as a risk factor:
The global financial crisis may have impacts on our business and financial condition that we
currently cannot predict.
The continued credit crisis and related turmoil in the global financial system may have an impact
on our business and our financial condition, and we may face challenges if conditions in the
financial markets do not improve. Our
ability to access the capital markets may be restricted at a time when we would like, or need,
to raise financing, which could have an impact on our flexibility to react to changing economic and
business conditions. The economic situation could have an impact on our lenders or customers,
causing them to fail to meet their obligations to us. Additionally, market conditions could have an
impact on our commodity hedging arrangements if our counterparties are unable to perform their
obligations or seek bankruptcy protection. Additionally, the current economic situation could lead
to reduced demand for oil and natural gas, or lower prices for oil and natural gas, or both, which
could have a negative impact on our revenues.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.
(a) Not applicable.
(b) Not applicable.
(c) Not applicable.
Item 3. Defaults Upon Senior Securities.
Not applicable.
Item 4. Submission of Matters to a Vote of Security Holders.
Not applicable.
Item 5. Other Information.
(a) Not applicable.
(b) Not applicable.
38
Item 6. Exhibits.
|
|
|
No.
|
|
Description of Exhibit
|
|
|
|
31.1
|
|
Certification by the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
|
|
|
|
31.2
|
|
Certification by the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
|
|
|
|
32.1
|
|
Certification by the Chief Executive Officer Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
|
|
|
|
32.2
|
|
Certification by the Chief Financial Officer Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
|
39
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.
|
|
|
|
|
|
|
CRUSADER ENERGY GROUP, INC.
(Registrant)
|
|
Date: November 10, 2008
|
By:
|
/S/ David D. Le Norman
|
|
|
|
David D. Le Norman
|
|
|
|
President and Chief Executive Officer
(Principal Executive Officer)
|
|
|
|
|
|
Date: November 10, 2008
|
By:
|
/S/ John G. Heinen
|
|
|
|
John G. Heinen
|
|
|
|
Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer)
|
|
40
INDEX TO EXHIBITS
|
|
|
No.
|
|
Description of Exhibit
|
|
|
|
31.1
|
|
Certification by the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
|
|
|
|
31.2
|
|
Certification by the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
|
|
|
|
32.1
|
|
Certification by the Chief Executive Officer Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
|
|
|
|
32.2
|
|
Certification by the Chief Financial Officer Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
|
41
Proshares Ultra S&P Regional Banking (delisted) (AMEX:KRU)
Graphique Historique de l'Action
De Mai 2024 à Juin 2024
Proshares Ultra S&P Regional Banking (delisted) (AMEX:KRU)
Graphique Historique de l'Action
De Juin 2023 à Juin 2024