Late Operator Billings Result in
Adjustments to Year End and First Quarter Results
First Quarter Earnings Per Share
Unchanged at $.10
Year End Earnings Decrease
$.01 to $.34 Per Share
Credo Petroleum Corporation (Nasdaq:CRED), an oil and gas
exploration and production company with significant assets in the
North Dakota Bakken and Three Forks, Kansas, Nebraska, the Texas
Panhandle and Oklahoma, today reported restated financial results
for its fiscal year ended October 31, 2011 and its first fiscal
quarter of 2012.
Oakley Hall, Chairman of the Audit Committee stated, "The
restatement was caused by late Bakken operator bills that included
well costs which were incurred earlier than we expected, and were
not accrued. This is a growing-pain that, for Credo, is unique to
the Bakken and Three Forks project. We have now modified our
procedures to identify and accrue well costs which are incurred
long before they are actually billed by the operators.
"As is shown in the Financial Highlights section of this
release, the restatement primarily affects working capital and oil
and gas property costs. There was no effect on first quarter
earnings per share, and fiscal 2011 earnings per share decreased
3%, or $.01 per share, to $.34. There were no changes in our
operating data such as production and reserves. Including the
unbilled cost, we have a $3,948,000 working capital deficit at
January 31, 2012. We anticipated working capital deficits for 2012
and previously announced that Credo will borrow money to finance
its record drilling budget. When borrowing is required, our use of
just-in-time financing will result in a working capital deficit due
to the time lag between when costs are estimated and accrued and
when operator invoices are received and paid. This is not unusual
in our business as many companies choose not to pay interest on
borrowed funds in order to dress up their working capital.
"We have concluded an exhaustive review. We are confident that
the full extent of the incurred costs have been identified and
accrued, and that this is a manageable situation going forward.
Therefore, yesterday we filed restated financial statements in Form
10-K/A for the year ended October 31, 2011 and Form 10-Q/A for the
first fiscal quarter ended January 31, 2012. The remainder of this
press release contains comparative year end and first quarter
information as restated. Our numbers continue to show substantial
growth in fiscal 2011 followed by even greater growth in the first
quarter of fiscal 2012. We expect this growth trend to
continue."
Increased Oil Production Drove a
Significant Improvement in Financial Results
For both 2011 and First
Quarter 2012
The following table shows the changes in certain financial and
operational categories for the fiscal year ended October 31, 2011
compared to last year and for the quarter ended January 31, 2012
compared to the same quarter last year.
|
YE 2011 |
1Q 2012 |
Revenue |
+ 45% |
+ 79% |
Operating Income |
+ 83% |
+114% |
EBITDA |
+ 53% |
+ 94% |
Net Income |
+ 57% |
+469% |
Adjusted Net Income |
+ 53% |
+ 78% |
Total Production (BOE) |
+ 12% |
+ 36% |
Oil Production (BO) |
+ 53% |
+ 99% |
For the fiscal year ended October 31, 2011, operating income
increased to $4,867,000 compared to $2,665,000 last year on revenue
of $16,767,000 compared to $11,566,000 last year. Increased
production volumes accounted for 73% of the revenue increase while
price changes accounted for 27%. EBITDA (a non-GAAP measure;
see reconciliation below) for the year ended
October 31, 2011 increased to $9,925,000 compared to
$6,490,000 last year. Net income was $3,453,000, or $.34 per
diluted share, compared to $2,203,000, or $.22 per diluted share,
last year. Adjusted net income (a non-GAAP measure; see
reconciliation below) increased to $3,447,000, or $.34 per share,
compared to $2,260,000, or $.22 per share last year.
For the first quarter ended January 31, 2012, operating income
increased to $1,938,000 compared to $904,000 last year on revenue
of $5,821,000 compared to $3,250,000 last year. Increased
production volumes accounted for 94% of the revenue increase while
price changes accounted for 6% of the increase. EBITDA for the
first quarter of 2012 increased to $3,792,000 compared to
$1,960,000 last year. Net income was $962,000, or $.10 per
diluted share, compared to $169,000, or $.02 per diluted share,
last year. Adjusted net income increased to $1,289,000, or
$.13 per share, compared to $726,000, or $.07 per share last
year.
DRILLING SUCCESS DRIVES SURGE IN OIL
PRODUCTION
The Company's oil-focused drilling success yielded a 53%
increase in fiscal 2011 oil production and a 99% increase in first
quarter 2012 oil production compared to last year. Natural gas
drilling was suspended in 2009 because of low natural gas
prices. As a result, mostly normal declines reduced gas
production in both periods. The following table shows that the
Company's comparative 2011 year end and first quarter 2012
production mix shifted solidly in favor of oil.
Production Mix |
YE 2011 |
YE 2010 |
1Q 2012 |
1Q 2011 |
Crude Oil |
49% |
36% |
61% |
42% |
Natural Gas |
51% |
64% |
39% |
58% |
Total production volumes increased 12% for the year ended
October 31, 2011 to 301,000 BOE (barrels of oil equivalent based on
six Mcf of gas to one barrel of oil), and increased 36% in the
first quarter to 91,000 BOE compared to last year. The
following table shows comparative production volume percentages by
region and highlights the robust shift occurring in the Company's
production mix to crude oil in North Dakota, Kansas and Nebraska
and away from natural gas in Oklahoma.
Production by Region |
YE 2011 |
YE 2010 |
1Q 2012 |
1Q 2011 |
North Dakota Bakken and Three Forks |
12% |
2% |
21% |
10% |
Kansas and Nebraska Lansing Kansas
City |
20% |
16% |
21% |
15% |
Texas Panhandle Tonkawa and Cleveland |
8% |
4% |
10% |
8% |
Other (primarily Oklahoma natural gas) |
60% |
78% |
48% |
67% |
Michael D. Davis, Chief Executive Officer (interim), stated,
"Although we are required to report production volumes on their six
to one energy equivalent basis, the current price equivalent is
more than fifty to one. That makes oil worth about eight times
more than natural gas, which is magnifying our revenue growth and
bottom line results compared to our production growth. For
example, in the first quarter of 2012, oil represented 86% of the
value of production compared to 61% of production volumes."
The following table shows comparative revenue percentages by
region.
Revenue by Region |
YE 2011 |
YE 2010 |
1Q 2012 |
1Q 2011 |
North Dakota Bakken and Three Forks |
17% |
7% |
27% |
15% |
Kansas and Nebraska Lansing Kansas
City |
30% |
49% |
32% |
26% |
Texas Panhandle Tonkawa and Cleveland |
10% |
8% |
9% |
5% |
Other (primarily Oklahoma natural gas) |
43% |
36% |
32% |
54% |
WELLHEAD PRICES MIXED
For the year ended October 31, 2011, wellhead oil prices
increased 20% to $85.16 compared to $70.88 last year. Natural
gas prices were unchanged at $4.54 last year due to the high Btu
content of Bakken and Three Forks gas. For the year, the
Company had realized hedging losses of $191,000 compared to gains
of $115,000 last year. Fiscal 2011 oil hedges had the
effect of reducing the Company's oil price realizations by $1.16
per barrel to $84.00. Last year, natural gas hedges increased
first quarter price realizations by $.11 per Mcf to $4.65.
First quarter 2012 wellhead oil prices increased 13% to $90.33
compared to $79.75 last year. Natural gas prices fell 14% to
$3.73 compared to $4.34 last year. For the quarter ended
January 31, 2012, the Company had realized hedging losses
of $44,000 compared to gains of $36,000 last year. First
quarter oil hedges had the effect of reducing the Company oil price
realizations by $.79 per barrel to $89.54. Last year, natural
gas hedges increased first quarter price realizations by $.16 per
Mcf to $4.50.
At January 31, 2012, the Company held short swap hedge positions
on 6,000 barrels of oil per month for the production months of
February 2012 through December 2012, at prices ranging from
$91.95 to $93.00. The hedge is expected to cover
approximately 15% to 25% of estimated production for the hedged
period. At first quarter end, unrealized hedging losses were
$481,000 compared to $741,000 last year. The unrealized losses
are a non-cash charge calculated at a point in time by applying oil
prices as of first quarter-end to open hedging contract
volumes. Actual realized gains or losses on the hedges are
determined based on oil prices at the time each month's hedge
contract expires.
RECORD CAPITAL EXPENDITURES
TO BE PARTIALLY FINANCED BY BANK
BORROWING
For fiscal 2011, capital expenditures increased 116% to a record
$18,744,000 as the Company ramped up drilling on its North Dakota,
Kansas, Nebraska and Texas Panhandle projects. For 2012,
capital expenditures are expected to almost double to $35,000,000,
of which approximately 65% is earmarked for Bakken and Three Forks
drilling.
At first quarter end, the Company had a working capital deficit
of $3,948,000 due to accrual of well cost liabilities that are not
yet payable. As noted above, the Company has previously
reported that it will use bank financing to fund a portion of its
2012 drilling budget. When borrowing is required, the Company
will use just-in-time financing which will result in a working
capital deficit due to the time lag between when costs are accrued
and when operator invoices are received and paid.
The Company has established a revolving credit line with its
principal bank which provides for a $25,000,000 credit
facility. The initial borrowing base is $7 million but will be
increased as the Company pledges additional properties as
collateral. Borrowing in 2012 is expected to range from
$7 million to $12 million. The credit facility is
governed by a borrowing base which is determined semi-annually by
the lender based on review of the Company's reserves at April 30
and October 31. To date, the Company has drawn $2 million
on the line of credit with an effective interest rate
of 3.5%.
MANAGEMENT COMMENT
Davis continued, "Our Bakken and Three Forks project is Credo's
flagship drilling play and provides enormous growth potential for
the Company. It is also our most challenging project primarily
because the costs and complexities of horizontal Bakken wells are
much greater than most of our other drilling
projects. Nevertheless, problems like late operator billings
are manageable and are far outweighed by our opportunity to
participate in this world class oil play."
Davis continued, "We have been extremely successful
transitioning Credo from natural gas to oil in a relatively short
time frame. Our comparative first quarter oil production grew
99% and for the quarter, oil represented 61% of our production
mix. We will continue to build on that momentum throughout
2012 with the objective of oil comprising 75% of our production mix
by year-end.
"We entered 2012 with a balanced, multi-year inventory of
scalable and repeatable projects that will propel Credo's organic
production and reserve gains in the years ahead. In our Bakken
and Three Forks project alone we have approximately 200 drilling
locations based on only two Bakken and two Three Forks wells in
each spacing unit. That number could double if, as many of the
larger Bakken operators predict, well density increases to eight
wells per spacing unit."
About Credo Petroleum
Credo Petroleum Corporation is an independent oil and gas
exploration and production company based in Denver,
Colorado. The Company has significant operations in the
Williston Basin of North Dakota, Kansas, Nebraska, the Anadarko
Basin of the Texas Panhandle and northwest Oklahoma, and in
southern Oklahoma. Credo uses advanced technologies to
systematically explore for oil and gas and, through its patented
Calliope Gas Recovery System, to recover stranded reserves from
depleted gas reservoirs. For more information, please visit
our website at www.credopetroleum.com or contact us at
303-297-2200.
Supplemental Non-GAAP Financial
Measures
EBITDA
The Company uses this non‑GAAP operating performance measure
primarily to compare its performance with other companies in the
industry that make a similar disclosure. The Company believes
that this performance measure may also be useful to investors for
the same purpose. Investors should not consider this measure
in isolation or as a substitute for operating income or any other
measure for determining the Company's operating performance that is
calculated in accordance with GAAP. In addition, because
EBITDA is not a GAAP measure, it may not necessarily be comparable
to similarly titled measures employed by other companies. A
reconciliation of Net Income to EBITDA (as used by the Company) is
provided in the table below:
|
Year Ended October
31 |
Three Months Ended
January 31 |
|
2011 |
2010 |
2012 |
2011 |
|
|
|
|
|
Net Income |
$ 3,453,000 |
$ 2,203,000 |
$ 962,000 |
$ 169,000 |
Add Back: |
|
|
|
|
Income Tax Expense |
1,289,000 |
612,000 |
453,000 |
56,000 |
Depreciation, Depletion and
Amortization |
5,191,000 |
3,602,000 |
1,896,000 |
994,000 |
Unrealized Derivative Losses |
(8,000) |
73,000 |
481,000 |
741,000 |
|
|
|
|
|
EBITDA |
$ 9,925,000 |
$ 6,490,000 |
$ 3,792,000 |
$ 1,960,000 |
Adjusted Net Income
The following table provides information that the Company
believes may be useful to investors that follow the practice of
some industry analysts who adjust reported company earnings to
match realizations to production settlement months and make other
adjustments to exclude certain non-cash items. The following
table provides a reconciliation of Net Income to non-GAAP Adjusted
Net Income.
|
Year Ended October
31 |
Three Months Ended
January 31 |
|
2011 |
2010 |
2012 |
2011 |
|
|
|
|
|
Net Income as reported |
$ 3,453,000 |
$ 2,203,000 |
$ 962,000 |
$ 169,000 |
|
|
|
|
|
Adjustments for certain non-cash items: |
|
|
|
|
Unrealized mark-to-market (gain) or loss
on commodity derivatives |
$ (8,000) |
$ 73,000 |
$ 481,000 |
$ 741,000 |
Tax impact |
$ 2,000 |
$ (16,000) |
$ (154,000) |
$ (184,000) |
|
|
|
|
|
Adjusted Net Income |
$ 3,447,000 |
$ 2,260,000 |
$ 1,289,000 |
$ 726,000 |
|
|
|
|
|
Adjusted Diluted Earnings per Share |
$ 0.34 |
$ 0.22 |
$ 0.13 |
$ 0.07 |
This press release includes certain statements that may be
deemed to be "forward-looking statements" within the meaning of
Section 27A of the Securities Act of 1933, as amended, and
Section 21E of the Securities Exchange Act of 1934, as
amended. All statements included in this press release, other
than statements of historical facts, address matters that the
Company reasonably expects, believes or anticipates will or may
occur in the future. Such statements are subject to various
assumptions, risks and uncertainties, many of which are beyond the
control of the Company. Investors are cautioned that any such
statements are not guarantees of future performance and that actual
results or developments may differ materially from those described
in the forward-looking statements. Investors are encouraged to
read the "Forward-Looking Statements" and "Risk Factors" sections
included in the Company's Annual Report on Form 10-K for more
information. Although the Company may from time to time
voluntarily update its prior forward looking statements, it
disclaims any commitment to do so except as required by securities
laws.
CREDO PETROLEUM
CORPORATION |
FINANCIAL
HIGHLIGHTS |
|
|
Condensed Statements of
Operations |
|
|
|
|
|
Three Months Ended |
Year Ended |
|
January 31 |
October 31 |
|
2012 |
2011 |
2011 |
2010 |
REVENUES: |
|
|
|
|
Oil sales |
$ 5,031,000 |
$ 2,235,000 |
$ 12,599,000 |
$ 6,855,000 |
Natural gas sales |
790,000 |
1,015,000 |
4,168,000 |
4,711,000 |
|
5,821,000 |
3,250,000 |
16,767,000 |
11,566,000 |
COSTS AND EXPENSES: |
|
|
|
|
Oil and natural gas production |
1,222,000 |
867,000 |
4,034,000 |
3,192,000 |
Depreciation, depletion and
amortization |
1,896,000 |
994,000 |
5,191,000 |
3,602,000 |
General and administrative |
765,000 |
485,000 |
2,675,000 |
2,107,000 |
|
3,883,000 |
2,346,000 |
11,900,000 |
8,901,000 |
|
|
|
|
|
Income from Operations |
1,938,000 |
904,000 |
4,867,000 |
2,665,000 |
|
|
|
|
|
Other Income and (Expense) |
|
|
|
|
Realized and unrealized (losses) from
derivative contracts |
(525,000) |
(705,000) |
(183,000) |
42,000 |
Investment and other income |
2,000 |
26,000 |
58,000 |
108,000 |
|
(523,000) |
(679,000) |
(125,000) |
150,000 |
|
|
|
|
|
INCOME BEFORE INCOME TAXES |
1,415,000 |
225,000 |
4,742,000 |
2,815,000 |
|
|
|
|
|
INCOME TAXES |
(453,000) |
(56,000) |
(1,289,000) |
(612,000) |
|
|
|
|
|
NET INCOME |
$ 962,000 |
$ 169,000 |
$ 3,453,000 |
$ 2,203,000 |
|
|
|
|
|
Earnings per share - basic |
$ .10 |
$ .02 |
$ .34 |
$ .22 |
|
|
|
|
|
Earnings per share - diluted |
$ .10 |
$ .02 |
$ .34 |
$ .22 |
|
|
|
|
|
CREDO PETROLEUM
CORPORATION |
FINANCIAL
HIGHLIGHTS |
|
|
Condensed Balance Sheet |
|
|
|
January 31,
2012 |
October 31, 2011 |
|
|
|
Cash and Short-Term Investments |
$ 2,165,000 |
$ 4,800,000 |
Other Current Assets |
6,262,000 |
4,271,000 |
Oil and Natural Gas Properties, Net |
56,000,000 |
49,851,000 |
Intangible Assets, Net |
3,033,000 |
3,142,000 |
Other Assets |
1,925,000 |
1,857,000 |
|
|
|
|
$ 69,385,000 |
$ 63,921,000 |
|
|
|
|
|
|
Current Liabilities |
$ 12,375,000 |
$ 8,248,000 |
Deferred Income Taxes |
4,977,000 |
4,524,000 |
Asset Retirement Obligations |
1,120,000 |
1,213,000 |
Stockholders' Equity |
50,913,000 |
49,936,000 |
|
|
|
|
$ 69,385,000 |
$ 63,921,000 |
CONTACT: Michael D. Davis
Chief Operating Officer
and CEO (Interim)
or
Alford B. Neely
Chief Financial Officer
303-297-2200
Website: www.credopetroleum.com
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