Exhibit 99.1
For Immediate Release
November 2, 2011
November 2, 2011
Approach Resources Inc. Reports Third Quarter 2011 Results and
Announces 2012 Capital Budget
Announces 2012 Capital Budget
2012 Capital Budget Set at $160 Million, Targeting 20%+ Production Growth in 2012
Borrowing Base Increases to $260 Million
Horizontal Wolfcamp Wells IP at 1,044 Boe/d —798 Boe/d
Vertical Wolffork Recompletions Average 152 Boe/d IP
Vertical Wolffork Wells Average 140 Boe/d IP
Borrowing Base Increases to $260 Million
Horizontal Wolfcamp Wells IP at 1,044 Boe/d —798 Boe/d
Vertical Wolffork Recompletions Average 152 Boe/d IP
Vertical Wolffork Wells Average 140 Boe/d IP
Fort Worth, Texas, November 2, 2011 — Approach Resources Inc. (NASDAQ: AREX) today reported
its third quarter 2011 results. Highlights for third quarter 2011, compared to third quarter 2010,
include:
| • | Total production increased 46% to 612 MBoe (6.7 MBoe/d) | ||
| • | Oil and NGL production increased 148% to 350 MBbls | ||
| • | Revenues increased 87% to $28 million | ||
| • | Net income increased 240% to $7.1 million, or $0.25 per diluted share | ||
| • | Adjusted net income (non-GAAP) increased 160% to $5.9 million, or $0.21 per diluted share | ||
| • | EBITDAX (non-GAAP) increased 86% to $21.7 million, or $0.76 per diluted share |
Production for third quarter 2011 totaled 612 MBoe (6.7 MBoe/d), compared to 418 MBoe (4.5
MBoe/d) in third quarter 2010, a 46% increase over the prior year period. Oil and NGL production
for third quarter 2011 increased 148% to 350 MBbls, compared to 141 MBbls produced in third quarter
2010. Production for third quarter 2011 was 57% oil and NGLs and 43% natural gas, compared to 34%
oil and NGLs and 66% natural gas in third quarter 2010. Oil and NGL production increased during
third quarter 2011 compared to third quarter 2010 due to continued development of the Wolffork oil
shale resource play, the acquisition of additional working interest in northern Project Pangea in
first quarter 2011 and processing gas in southern Project Pangea beginning in second quarter 2011.
Production for third quarter 2011 was affected by a shortage of oil trucks due to increased
industry activity in the Permian Basin. While production in Project Pangea is running as planned,
we experienced an oil inventory build of approximately 29,000 barrels through third quarter 2011.
We estimate that the inventory build reduced our potential sales volumes by approximately 315
Bbls/d during third quarter 2011. In response to tightness in the Permian oil trucking market, we
have ordered four new oil hauling trucks, which we expect to be delivered by year end 2011. In
addition, the Company is exploring long-term trucking, pipeline and rail alternatives.
J. Ross Craft, President and Chief Executive Officer, said, “We continue to be pleased with
results from our Wolffork oil shale resource play. Although we encountered oil takeaway
constraints during the quarter, our field production is in line with our expectations. Solid well
performance, reserve growth and a strong balance sheet provide the foundation for our 2012 capital
program of $160 million. Our 2012 capital program allows us flexibility to grow production by more
than 20% while being mindful
of volatile commodity markets. With our extensive inventory of low-risk locations, I believe
we’re well positioned to capitalize on our Wolffork resource potential for many years to come.”
INVESTOR CONTACT
|
APPROACH RESOURCES INC. | |
Megan P. Hays
|
One Ridgmar Centre | |
mhays@approachresources.com
|
6500 West Freeway, Suite 800 | |
817.989.9000
|
Fort Worth, Texas 76116 | |
| www.approachresources.com |
Third Quarter 2011 Financial Results
Net income for third quarter 2011 was $7.1 million, or $0.25 per diluted share, on revenues of
$28 million. This compares to net income for third quarter 2010 of $2.1 million, or $0.10 per
diluted share, on revenues of $14.9 million. The $13.1 million increase in revenues in the third
quarter of 2011 was attributable to an increase in oil and NGL production volumes ($11.9 million)
and an increase in oil and NGL prices ($1.2 million).
Third quarter 2011 net income included an unrealized gain on commodity derivatives of $1.7
million, and third quarter 2010 net income included a $312,000 unrealized loss on commodity
derivatives. Excluding the unrealized gain on commodity derivatives and related income taxes,
adjusted net income (non-GAAP) for third quarter 2011 was $5.9 million, or $0.21 per diluted share,
compared to $2.3 million, or $0.11 per diluted share, for third quarter 2010. See “Supplemental
Non-GAAP Financial and Other Measures” below for our reconciliation of adjusted net income to net
income.
EBITDAX (non-GAAP) for third quarter 2011 was $21.7 million, or $0.76 per diluted share,
compared to $11.6 million, or $0.54 per diluted share, for third quarter 2010. See “Supplemental
Non-GAAP Financial and Other Measures” below for our reconciliation of EBITDAX to net income.
Average realized prices for third quarter 2011, before the effect of commodity derivatives,
were $81.51 per Bbl of oil, $52.08 per Bbl of NGLs and $3.99 per Mcf of natural gas, compared to
$72.19 per Bbl of oil, $36.65 per Bbl of NGLs and $4.34 per Mcf of natural gas, for third quarter
2010. Our average realized price, including the effect of commodity derivatives, was $47.98 per
Boe for third quarter 2011, compared to $39.54 per Boe for third quarter 2010.
Lease operating expense (“LOE”) for third quarter 2011 was $3.6 million, or $5.82 per Boe,
compared to $2 million, or $4.77 per Boe, in third quarter 2010. The increase in LOE compared to
third quarter 2010 was principally due to the increase in our working interest in northern Project
Pangea. In February 2011, we acquired the remaining 38% working interest in northern Project
Pangea, which increased our working interest to approximately 100%. We also experienced an
increase in water hauling, insurance and repair and maintenance expenses as well as generally
higher service costs.
Severance and production taxes for third quarter 2011 were $1.4 million, or $2.32 per Boe,
compared to $743,000, or $1.78 per Boe, in third quarter 2010. Severance and production taxes were
approximately 5.1% and 5.0% of oil, NGL and gas sales for third quarter 2011 and 2010,
respectively. The increase in severance and production taxes from third quarter 2010 was driven
mostly by the increase in oil, NGL and gas sales over third quarter 2010.
Exploration expense for third quarter 2011 was $2 million, or $3.22 per Boe, compared to
$568,000, or $1.36 per Boe, in third quarter 2010. Exploration expense for third quarter 2011 and
2010 includes costs related to 3-D seismic data acquisition in Pangea West and Project Pangea. We
began acquiring 3-D seismic data in Pangea West in September 2011. We believe Pangea West is
prospective for the Wolffork oil shale and expect to drill our first horizontal Wolfcamp well in
Pangea West in the first quarter of 2012.
General and administrative expense (“G&A”) for third quarter 2011 was $3.8 million, or $6.18
per Boe, compared to $3.2 million, or $7.68 per Boe, for third quarter 2010. The increase in G&A
was
2
primarily due to salaries and benefits. The decrease in G&A per Boe was primarily attributable
to an increase in production during third quarter 2011 over prior period production volumes.
Depletion, depreciation and amortization expense (“DD&A”) for third quarter 2011 was $8.4
million, or $13.65 per Boe, compared to $5.8 million, or $13.95 per Boe, for third quarter 2010.
The increase in DD&A over the prior year period was primarily due to an increase in capital
expenditures in third quarter 2011. The decrease in DD&A per Boe compared to third quarter 2010
was primarily attributable to an increase in estimated proved developed reserves, partially offset
by an increase in production and capitalized costs over third quarter 2010.
Operations Update
During the third quarter of 2011, we drilled a total of 20 gross (20 net) wells, completed 14
gross (14 net) wells and recompleted four gross (four net) wells. Through September 30, 2011, we
drilled 52 gross (47.3 net) wells, completed 49 gross (42.7 net) wells and recompleted six gross
(six net) wells. At September 30, 2011, we had 10 wells waiting on completion. We currently have
one horizontal rig and two vertical rigs running in Project Pangea. We expect to drill a total of
approximately 58 vertical wells and 13 horizontal wells in 2011. Exploration and development
drilling expenditures totaled $51.9 million for the third quarter of 2011, and $128.9 million for
the first nine months of 2011.
Horizontal Wolfcamp Oil Shale Program
During third quarter 2011, we completed three horizontal Wolfcamp wells. All three horizontal
wells were completed with 23 fracture stimulation stages. The table below summarizes the 24-hour
initial producing rates for these wells.
| Lateral Length | Oil | NGLs | Natural Gas | Total | ||||||||||||||||
| Horizontal Pilot Wells | (Feet) | (Bbls) | (Bbls) | (Mcf) | (Boe/d) | |||||||||||||||
University 45C #803H |
7,358 | 931 | 57 | 335 | 1,044 | |||||||||||||||
University 45B #2401H |
7,613 | 582 | 116 | 677 | 811 | |||||||||||||||
University 45D #902H |
7,770 | 611 | 95 | 552 | 798 | |||||||||||||||
Two horizontal Wolfcamp wells are waiting on completion, the University 42B #1001H well
(7,769 feet lateral) and the University 45E #1101H well (7,712 feet lateral). We plan to complete
both wells in November 2011. The University 42B #1001H well is the Company’s first well testing a
deeper zone, the Wolfcamp “C” zone, within the Wolfcamp formation. Our prior horizontal Wolfcamp
wells tested the Wolfcamp “B” and “A” zones.
We currently are drilling the University 45F #2301H well. We plan to drill this well to a
lateral length of approximately 7,700 feet.
3
Vertical Wolffork Program
Since March 2011, the Company has recompleted nine existing, producing wells in the Wolffork
oil shale. The average initial producing rate for our Wolffork recompletions is 152 Boe/d,
comprised of approximately 75% oil and NGLs. Additionally, the Company has drilled and completed
seven vertical wells targeting the Wolffork oil shale. The average initial producing rate for the
vertical Wolffork wells is 140 Boe/d, comprised of approximately 72% oil and NGLs.
2011 Capital Expenditures
Total capital expenditures in 2011 are expected to be $260 million, with approximately $160.7
million allocated to drilling and completion projects in the Permian Basin, approximately $70.2
million allocated to the acquisition of the remaining 38% working interest in northern Project
Pangea, approximately $29.1 million allocated to lease acquisitions, extensions and renewals in
the Permian Basin, acquisition of 3-D seismic in Project Pangea and Pangea West, infrastructure and
other expenditures.
Commenting on the 2011 capital budget, Mr. Craft said, “The increase in capital expenditures
is primarily due to de-risking our Wolffork oil shale play with a combination of horizontal,
vertical, recompletion and infrastructure projects and the acquisition or extension of
approximately 20,000 net acres in our Permian operating area in 2011. For 2011, we’re on track to
drill more vertical and horizontal wells, and we’re drilling longer laterals and completing with
more frac stages in our horizontal wells. Also, we completed two natural gas pipeline
infrastructure projects for our production in northeast Project Pangea and Block 45. We are making
a significant investment in our core asset base, which has transformed the Company from a natural
gas company to an oil and liquids-weighted producer and which we believe has the potential to
substantially increase our proved reserves over the next several years.”
2012 Capital Expenditures
The Company’s Board of Directors approved a 2012 capital budget of $160 million for drilling
and recompletions in the Company’s Wolffork oil shale resource play in the Permian Basin. The
capital budget excludes acquisitions and assumes an activity level similar to the Company’s current
program, including two vertical rigs, one horizontal rig and two to four recompletions per month.
We estimate 2012 production will range between 2,800 MBoe and 3,000 MBoe, an increase of
approximately 22% over 2011 estimated production, and will be comprised of approximately 65% oil
and natural gas liquids.
Our 2011 and 2012 capital budgets are subject to change depending upon a number of factors,
including economic and industry conditions at the time of drilling, prevailing and anticipated
prices for oil, NGLs and gas, the availability of sufficient capital resources for drilling
prospects, our financial results and the availability of lease extensions and renewals on
reasonable terms.
4
2011 and 2012 Guidance
The table below sets forth the Company’s current production and operating costs and expenses
guidance for 2011 and 2012. The guidance is forward-looking information that is subject to a
number of risks and uncertainties, many of which are beyond the Company’s control.
| 2011 | 2012 | |||||||
| Guidance | Guidance | |||||||
Production: |
||||||||
Total (MBoe) |
2,300—2,450 | 2,800—3,000 | ||||||
Percent oil and NGLs |
55 | % | 65 | % | ||||
Operating costs and expenses (per Boe): |
||||||||
Lease operating |
$ | 5.00 — 6.00 | $ | 4.50 — 5.50 | ||||
Severance and production taxes |
$ | 2.35 — 3.00 | $ | 2.50 — 4.00 | ||||
Exploration |
$ | 4.00 — 5.00 | $ | 4.00 — 5.00 | ||||
General and administrative |
$ | 6.50 — 7.00 | $ | 5.25 — 6.25 | ||||
Depletion, depreciation and amortization |
$ | 12.00 — 15.00 | $ | 12.00 — 15.00 | ||||
Capital expenditures (in millions) |
Approximately $260 | Approximately $160 | ||||||
Financial Update
At September 30, 2011, we had a $300 million revolving credit agreement with a $200 million
borrowing base and $122 million outstanding. At September 30, 2011, our liquidity was $78.4
million. Effective October 7, 2011, we entered into an eleventh amendment to our credit agreement,
which, among other things, increased the borrowing base 30% to $260 million from $200 million.
Including the increase in borrowing base, our liquidity would have been $138.4 million at September
30, 2011. See “Supplemental Non-GAAP Financial and Other Measures” below for our calculation of
“liquidity.”
Commodity Derivatives Positions
In October 2011, the Company added to its 2012 commodity derivatives positions with a crude
oil collar contract covering 700 Bbls/d at a contract price of $85.00/Bbl — $97.50/Bbl. The
following table sets forth our commodity derivative volumes and prices for 2011 and 2012.
| Period | Contract Type | Volume Transacted | Contract Price | |||||||||
Natural Gas |
||||||||||||
2011 |
Swap | 230,000 MMBtu/month | $ | 4.86 | ||||||||
June 2011 — December 2011 |
Swap | 200,000 MMBtu/month | $ | 4.74 | ||||||||
2012 |
Call | 230,000 MMBtu/month | $ | 6.00 | ||||||||
Natural Gas — Basis
Differential |
||||||||||||
2011 |
Swap | 300,000 MMBtu/month | $ | (0.53 | ) | |||||||
Crude Oil |
||||||||||||
May 2011 — December 2011 |
Collar | 1,000 Bbls/day | $ | 100.00 - $127.00 | ||||||||
5
Third Quarter 2011 Conference Call
Approach will host a conference call on Thursday, November 3, 2011, at 10:00 a.m. Central Time
(11:00 a.m. Eastern Time) to discuss third quarter 2011 results. The conference call can be
accessed by dialing (866) 804-6924 (U.S. domestic) or (857) 350-1670 (International).
Additionally, the conference call will be broadcast live over the internet and can be accessed
through the Investor Relations section of the Company’s website, www.approachresources.com. The
webcast will be archived for replay on the Company’s website until February 2, 2012.
Approach Resources Inc. is an independent oil and gas company with core operations, production
and reserves located in the Permian Basin in West Texas. The Company targets multiple oil and
liquids-rich formations in the Permian Basin, where the Company operates approximately 142,000 net
acres. The Company’s estimated proved reserves total 66.8 million Boe, comprised of 55% oil and
NGLs and 45% natural gas. For more information about the Company, please visit
www.approachresources.com. Please note that the Company routinely posts important information
about the Company under the Investor Relations section of its website.
This press release contains forward-looking statements within the meaning of Section 27A of
the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements,
other than statements of historical facts, included in this press release that address activities,
events or developments that the Company expects, believes or anticipates will or may occur in the
future are forward-looking statements. Without limiting the generality of the foregoing,
forward-looking statements contained in this press release specifically include the expectations of
management regarding the Company’s 2012 capital budget, and 2011 and 2012 production, rig program
and operating expenses. These statements are based on certain assumptions made by the Company based
on management’s experience, perception of historical trends and technical analyses, current
conditions, anticipated future developments and other factors believed to be appropriate and
reasonable by management. When used in this press release, the words “will,” “potential,”
“believe,” “estimate,” “intend,” “expect,” “may,” “should,” “anticipate,” “could,” “plan,”
“predict,” “project,” “profile,” “model” or their negatives, other similar expressions or the
statements that include those words, are intended to identify forward-looking statements, although
not all forward-looking statements contain such identifying words. Such statements are subject to a
number of assumptions, risks and uncertainties, many of which are beyond the control of the
Company, which may cause actual results to differ materially from those implied or expressed by the
forward-looking statements. Further information on such assumptions, risks and uncertainties is
available in the Company’s Securities and Exchange Commission (“SEC”) filings. The Company’s SEC
filings are available on the Company’s website at www.approachresources.com. Any forward-looking
statement speaks only as of the date on which such statement is made and the Company undertakes no
obligation to correct or update any forward-looking statement, whether as a result of new
information, future events or otherwise, except as required by applicable law.
For a glossary of oil and gas terms and abbreviations used in this release, please see our
Annual Report on Form 10-K filed with the SEC on March 11, 2011.
6
UNAUDITED RESULTS OF OPERATIONS
| Three Months Ended | Nine Months Ended | |||||||||||||||
| September 30, | September 30, | |||||||||||||||
| 2011 | 2010 | 2011 | 2010 | |||||||||||||
Revenues (in thousands) |
||||||||||||||||
Oil |
$ | 9,568 | $ | 5,135 | $ | 27,792 | $ | 12,630 | ||||||||
NGLs |
12,128 | 2,565 | 29,416 | 6,899 | ||||||||||||
Gas |
6,262 | 7,216 | 20,056 | 21,762 | ||||||||||||
Total oil, NGL and gas sales |
27,958 | 14,916 | 77,264 | 41,291 | ||||||||||||
Realized gain on commodity derivatives |
1,392 | 1,615 | 1,654 | 3,613 | ||||||||||||
Total oil, NGL and gas sales
including derivative impact |
$ | 29,350 | $ | 16,531 | $ | 78,918 | $ | 44,904 | ||||||||
Production |
||||||||||||||||
Oil (MBbls) |
117 | 71 | 310 | 172 | ||||||||||||
NGLs (MBbls) |
233 | 70 | 574 | 174 | ||||||||||||
Gas (MMcf) |
1,569 | 1,664 | 4,829 | 4,646 | ||||||||||||
Total (MBoe) |
612 | 418 | 1,689 | 1,120 | ||||||||||||
Total (MBoe/d) |
6.7 | 4.5 | 6.2 | 4.1 | ||||||||||||
Average prices |
||||||||||||||||
Oil (per Bbl) |
$ | 81.51 | $ | 72.19 | $ | 89.63 | $ | 73.41 | ||||||||
NGLs (per Bbl) |
52.08 | 36.65 | 51.26 | 39.64 | ||||||||||||
Gas (per Mcf) |
3.99 | 4.34 | 4.15 | 4.68 | ||||||||||||
Total (per Boe) |
$ | 45.70 | $ | 35.68 | $ | 45.75 | $ | 36.87 | ||||||||
Realized gain on commodity derivatives (per
Boe) |
2.28 | 3.86 | 0.98 | 3.22 | ||||||||||||
Total including derivative impact
(per Boe) |
$ | 47.98 | $ | 39.54 | $ | 46.73 | $ | 40.09 | ||||||||
Costs and expenses (per Boe) |
||||||||||||||||
Lease operating (1) |
$ | 5.82 | $ | 4.77 | $ | 5.81 | $ | 5.39 | ||||||||
Severance and production taxes |
2.32 | 1.78 | 2.50 | 1.83 | ||||||||||||
Exploration |
3.22 | 1.36 | 4.07 | 2.00 | ||||||||||||
General and administrative |
6.18 | 7.68 | 7.03 | 7.06 | ||||||||||||
Depletion, depreciation and amortization |
13.65 | 13.95 | 13.26 | 14.89 | ||||||||||||
| (1) | Lease operating expense per Boe includes ad valorem taxes. |
7
APPROACH RESOURCES INC. AND SUBSIDIARIES
UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except shares and per-share amounts)
UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except shares and per-share amounts)
| Three Months Ended | Nine Months Ended | |||||||||||||||
| September 30, | September 30, | |||||||||||||||
| 2011 | 2010 | 2011 | 2010 | |||||||||||||
REVENUES: |
||||||||||||||||
Oil, NGL and gas sales |
$ | 27,958 | $ | 14,916 | $ | 77,264 | $ | 41,291 | ||||||||
EXPENSES: |
||||||||||||||||
Lease operating |
3,564 | 1,995 | 9,820 | 6,038 | ||||||||||||
Severance and production taxes |
1,419 | 743 | 4,223 | 2,047 | ||||||||||||
Exploration |
1,969 | 568 | 6,877 | 2,245 | ||||||||||||
General and administrative |
3,785 | 3,212 | 11,878 | 7,902 | ||||||||||||
Depletion, depreciation and amortization |
8,355 | 5,832 | 22,394 | 16,677 | ||||||||||||
Total expenses |
19,092 | 12,350 | 55,192 | 34,909 | ||||||||||||
OPERATING INCOME |
8,866 | 2,566 | 22,072 | 6,382 | ||||||||||||
OTHER: |
||||||||||||||||
Interest expense, net |
(1,016 | ) | (615 | ) | (2,391 | ) | (1,631 | ) | ||||||||
Realized gain on commodity derivatives |
1,392 | 1,615 | 1,654 | 3,613 | ||||||||||||
Unrealized gain (loss) on commodity derivatives |
1,739 | (312 | ) | 3,821 | 2,882 | |||||||||||
Gain on sale of oil and gas properties |
— | — | 491 | — | ||||||||||||
INCOME BEFORE INCOME TAX PROVISION |
10,981 | 3,254 | 25,647 | 11,246 | ||||||||||||
INCOME TAX PROVISION |
3,908 | 1,167 | 9,121 | 4,045 | ||||||||||||
NET INCOME |
$ | 7,073 | $ | 2,087 | $ | 16,526 | $ | 7,201 | ||||||||
EARNINGS PER SHARE: |
||||||||||||||||
Basic |
$ | 0.25 | $ | 0.10 | $ | 0.58 | $ | 0.34 | ||||||||
Diluted |
$ | 0.25 | $ | 0.10 | $ | 0.58 | $ | 0.34 | ||||||||
WEIGHTED AVERAGE SHARES OUTSTANDING: |
||||||||||||||||
Basic |
28,440,909 | 21,357,682 | 28,398,152 | 21,139,089 | ||||||||||||
Diluted |
28,652,211 | 21,484,465 | 28,628,074 | 21,265,794 | ||||||||||||
8
UNAUDITED SELECTED FINANCIAL DATA
| Unaudited Consolidated Balance Sheet Data | September 30, | December 31, | ||||||
| (in thousands) | 2011 | 2010 | ||||||
Cash and cash equivalents |
$ | 736 | $ | 23,465 | ||||
Other current assets |
14,618 | 17,865 | ||||||
Property and equipment, net, successful efforts method |
560,067 | 369,210 | ||||||
Other assets |
1,103 | 2,549 | ||||||
Total assets |
$ | 576,524 | $ | 413,089 | ||||
Current liabilities |
$ | 42,374 | $ | 29,240 | ||||
Long-term debt |
122,000 | — | ||||||
Other long-term liabilities |
59,311 | 50,903 | ||||||
Stockholders’ equity |
352,839 | 332,946 | ||||||
Total liabilities and stockholders’ equity |
$ | 576,524 | $ | 413,089 | ||||
| Nine Months Ended | ||||||||
| Unaudited Consolidated Cash Flow Data | September 30, | |||||||
| (in thousands) | 2011 | 2010 | ||||||
Net cash provided (used) by: |
||||||||
Operating activities |
$ | 74,214 | $ | 32,455 | ||||
Investing activities |
$ | (218,546 | ) | $ | (53,115 | ) | ||
Financing activities |
$ | 121,630 | $ | 18,396 | ||||
Effect of foreign currency translation |
$ | (27 | ) | $ | (4 | ) | ||
9
Supplemental Non-GAAP Financial and Other Measures
This release contains certain financial measures that are non-GAAP measures. We have provided
reconciliations below of the non-GAAP financial measures to the most directly comparable GAAP
financial measures and on the Non-GAAP Financial Information page in the Investor Relations section
of our website at www.approachresources.com.
Adjusted Net Income
This release contains the non-GAAP financial measures adjusted net income and adjusted net
income per diluted share, which exclude the following items:
| (i) | Unrealized (gain) loss on commodity derivatives, | |
| (ii) | Gain on sale of oil and gas properties, and | |
| (iii) | Related income taxes. |
The amounts included in the calculation of adjusted net income and adjusted net income per
diluted share below were computed in accordance with GAAP. We believe adjusted net income and
adjusted net income per diluted share are useful to investors because they provide readers with a
more meaningful measure of our profitability before recording certain items whose timing or amount
cannot be reasonably determined. However, these measures are provided in addition to, and not as
an alternative for, and should be read in conjunction with, the information contained in our
financial statements prepared in accordance with GAAP (including the notes), included in our SEC
filings and posted on our website.
The following table provides a reconciliation of adjusted net income to net income for the
three and nine months ended September 30, 2011 and 2010, respectively (in thousands, except
per-share amounts).
| Three Months Ended | Nine Months Ended | |||||||||||||||
| September 30, | September 30, | |||||||||||||||
| 2011 | 2010 | 2011 | 2010 | |||||||||||||
Net income |
$ | 7,073 | $ | 2,087 | $ | 16,526 | $ | 7,201 | ||||||||
Adjustments for certain items: |
||||||||||||||||
Unrealized (gain) loss on commodity
derivatives |
(1,739 | ) | 312 | (3,821 | ) | (2,882 | ) | |||||||||
Gain on sale of oil and gas properties |
— | — | (491 | ) | — | |||||||||||
Related income tax effect |
591 | (106 | ) | 1,466 | 980 | |||||||||||
Adjusted net income |
$ | 5,925 | $ | 2,293 | $ | 13,680 | $ | 5,299 | ||||||||
Adjusted net income per diluted share |
$ | 0.21 | $ | 0.11 | $ | 0.48 | $ | 0.25 | ||||||||
10
EBITDAX
We define EBITDAX as net income, plus (1) exploration expense, (2) depletion, depreciation and
amortization expense, (3) share-based compensation expense, (4) unrealized (gain) loss on commodity
derivatives, (5) gain on sale of oil and gas properties, (6) interest expense and (7) income taxes.
EBITDAX is not a measure of net income or cash flow as determined by GAAP. The amounts included in
the calculation of EBITDAX were computed in accordance with GAAP. EBITDAX is presented herein and
reconciled to the GAAP measure of net income because of its wide acceptance by the investment
community as a financial indicator of a company’s ability to internally fund development and
exploration activities. This measure is provided in addition to, and not as an alternative for,
and should be read in conjunction with, the information contained in our financial statements
prepared in accordance with GAAP (including the notes), included in our SEC filings and posted on
our website.
The following table provides a reconciliation of EBITDAX to net income for the three and nine
months ended September 30, 2011 and 2010, respectively (in thousands, except per-share amounts).
| Three Months Ended | Nine Months Ended | |||||||||||||||
| September 30, | September 30, | |||||||||||||||
| 2011 | 2010 | 2011 | 2010 | |||||||||||||
Net income |
$ | 7,073 | $ | 2,087 | $ | 16,526 | $ | 7,201 | ||||||||
Exploration |
1,969 | 568 | 6,877 | 2,245 | ||||||||||||
Depletion, depreciation and amortization |
8,355 | 5,832 | 22,394 | 16,677 | ||||||||||||
Share-based compensation |
1,089 | 1,047 | 3,637 | 2,043 | ||||||||||||
Unrealized (gain) loss on commodity
derivatives |
(1,739 | ) | 312 | (3,821 | ) | (2,882 | ) | |||||||||
Gain on sale of oil and gas properties |
— | — | (491 | ) | — | |||||||||||
Interest expense, net |
1,016 | 615 | 2,391 | 1,631 | ||||||||||||
Income tax provision |
3,908 | 1,167 | 9,121 | 4,045 | ||||||||||||
EBITDAX |
$ | 21,671 | $ | 11,628 | $ | 56,634 | $ | 30,960 | ||||||||
EBITDAX per diluted share |
$ | 0.76 | $ | 0.54 | $ | 1.98 | $ | 1.46 | ||||||||
11
Liquidity
Liquidity is calculated by adding the net funds available under our revolving credit facility
and cash and cash equivalents. We use liquidity as an indicator of the Company’s ability to fund
development and exploration activities. However, this measurement has limitations. This
measurement can vary from year to year for the Company and can vary among companies based on what
is or is not included in the measurement on a company’s financial statements. This measurement is
provided in addition to, and not as an alternative for, and should be read in conjunction with, the
information contained in our financial statements prepared in accordance with GAAP (including the
notes), included in our SEC filings and posted on our website.
The table below summarizes our liquidity at September 30, 2011, and our liquidity at September
30, 2011, reflecting the October 2011 borrowing base increase to $260 million from $200 million.
| Liquidity with Borrowing | ||||||||
| Liquidity at | Base Increase at | |||||||
| Unaudited Liquidity Data | September 30, 2011 | September 30, 2011 | ||||||
| (in thousands) | ||||||||
Borrowing base |
$ | 200,000 | $ | 260,000 | ||||
Cash and cash equivalents |
736 | 736 | ||||||
Outstanding letters of credit |
(350 | ) | (350 | ) | ||||
Long-term debt |
(122,000 | ) | (122,000 | ) | ||||
Liquidity |
$ | 78,386 | $ | 138,386 | ||||
12
