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COMPANY CONTACT: Paul Vincent Director – Finance & Investor Relations (281) 874-2700, (800) 777-2412 | FOR IMMEDIATE RELEASE |
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SWIFT ENERGY ANNOUNCES: | |
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81% INCREASE IN THIRD QUARTER 2011 EARNINGS FROM CONTINUING OPERATIONS TO $17 MILLION, OR $0.39 PER DILUTED SHARE;
46% INCREASE IN THIRD QUARTER 2011 ADJUSTED CASH FLOW TO $90 MILLION, OR $2.11 PER DILUTED SHARE;
23% INCREASE IN THIRD QUARTER 2011 PRODUCTION TO 2.54 MILLION BARRELS OF OIL EQUIVALENT
HOUSTON, November 3, 2011 – Swift Energy Company (NYSE: SFY) announced today earnings from continuing operations of $17.0 million for the third quarter of 2011, or $0.39 per diluted share, an 81% increase when compared to third quarter 2010 earnings from continuing operations of $9.3 million, or $0.24 per diluted share.
Adjusted cash flow (cash flow before working capital changes, a non-GAAP measure - see page 7 for reconciliation to the GAAP measure) for the third quarter of 2011 increased 46% to $90.0 million, or $2.11 per diluted share, compared to $61.7 million, or $1.62 per diluted share, for the third quarter 2010.
Swift Energy production increased 23% to 2.54 million barrels of oil equivalent (“MMBoe”) for the third quarter of 2011, when compared to third quarter 2010 production of 2.07 MMBoe.
“Swift Energy continued to achieve operational and supply chain milestones during the third quarter”, noted Terry Swift, CEO of Swift Energy. “The Company now has 90 million cubic feet of gas per day of dedicated transportation and processing capacity available for its natural gas production in McMullen County. We completed ten new horizontal wells in South Texas during the quarter and continue to bring new wells online in the fourth quarter. Our first operated well targeting the Austin Chalk in the Burr Ferry area was drilled, and we have resumed drilling in the Masters Creek field.
“In South Texas, our industry has accelerated activity levels very quickly over the past two years, going from less than 10 drilling rigs operating in the Eagle Ford in January of 2009 to over 180 rigs as of the end of September of this year. As a result, we have witnessed
extreme tightness in the access, availability and timing of delivery of goods, services and manpower. To ensure our ability to execute our strategy of growing while maintaining liquidity and reducing leverage, we have continued our comprehensive approach to managing our projects in emerging resource basins. We now have dedicated access to drilling rigs, fracture stimulation crews, source water, raw materials and human resources necessary to carry out much of our operating strategy for 2012 and beyond. This approach is expanding to all applicable areas of our business over time and allows us to manage our entire supply chain and mitigate service cost inflation where possible.
“Our year end production exit rate is expected to be 31,000 – 33,000 barrels of oil equivalent per day (“Boe/d”). We still anticipate some temporary third party service, infrastructure, and transportation delays, which will affect the on-line date of certain wells that were included in our previous exit rate target of 34,000 – 36,000 Boe/d. This revised exit rate target represents a 17% - 24% increase over our 2010 production exit rate.
“Strong production, reserves and cash flow growth, combined with three diverse core operating areas, exceptional financial liquidity and low leverage, has Swift Energy in a great position to deliver consistent growth for the next several years.”
Revenues and Expenses
Total revenues for the third quarter of 2011 increased 35% to $142.5 million from the $105.6 million generated in the third quarter of 2010, primarily attributable to both higher commodity prices and production volumes.
Depreciation, depletion and amortization expense (“DD&A”) of $21.40 per barrel of oil equivalent (“Boe”) in the third quarter of 2011 increased 9% from $19.69 per Boe of DD&A in the comparable period in 2010, primarily due to a higher overall depletable base.
Lease operating expenses, before severance and ad valorem taxes, were $10.31 per Boe in the third quarter 2011, an increase of 2% compared to $10.12 per Boe in the third quarter of 2010. Lease operating expenses increased due to higher product transportation costs, salt water disposal costs, as well as other various cost increases from our South Texas operations.
Severance and ad valorem taxes increased to $5.32 per Boe from $5.23 per Boe in the comparable period due to higher oil and NGL prices in the 2011 period.
General and administrative expenses increased to $4.48 per Boe during the third quarter of 2011 from $4.21 per Boe in the same period in 2010. Interest expense decreased to $3.32 per Boe in the third quarter of 2011 compared to $3.99 per Boe for the same period in 2010.
Production & Pricing
Swift Energy’s third quarter 2011 production was 2.54 MMBoe, an increase of 23% when compared to 2010 third quarter production of 2.07 MMBoe, as a result of increased activity levels in South Texas. Natural gas production increased 67%, while crude oil production decreased 7% and NGL production decreased 4% in the same period in 2011.
Sequentially, production decreased 4% from the 2.64 MMBoe produced in the second quarter of 2011. Events affecting production volumes during the third quarter include: Tropical Storm Lee shutting in production across South Louisiana, delays in the commissioning of a third party natural gas pipeline and processing plant in McMullen
County, TX, periodic transportation and processing curtailments under existing interruptible agreements (also in McMullen County) and the failure in late September of a third-party operated natural gas gathering line in Webb County, TX. Additionally, late in the third quarter, a contracted drilling rig went out of service to undergo significant repairs. The loss of drilling activity caused by this rig being out of service will also affect fourth quarter production volumes and year-end exit rate. These events negatively impacted production by approximately 120,000 Boe in the third quarter and are expected to negatively impact full year 2011 production by approximately 530,000 Boe.
The Company realized an aggregate average price of $56.31 per Boe during the quarter, up from the $51.06 per Boe average price received in the third quarter of 2010. In the third quarter of 2011, average crude oil prices increased 38% to $105.55 per barrel from $76.39 per barrel realized in the same period in 2010. For the same periods, average natural gas prices were $3.68 per thousand cubic feet (“Mcf”), a decrease of 5% from the $3.87 per Mcf domestic average price realized a year earlier. Prices for NGLs averaged $57.76 per barrel in the third quarter, a 45% increase from third quarter 2010 NGL prices of $39.88 per barrel.
Third Quarter Drilling Activity
In the third quarter of 2011, Swift Energy drilled eleven operated development wells and participated in one non-operated well. In the Company’s South Texas core area, ten operated horizontal development wells were drilled to the Eagle Ford shale: six wells in McMullen County, three in Webb County and one in LaSalle County.
In Swift Energy’s Central Louisiana/East Texas core area, one operated well and one non- operated well were drilled in the Burr Ferry field.
There are currently four operated rigs and one non-operated rig drilling in the Company’s South Texas core area. A fifth contracted rig is undergoing repairs and should return to this area during the quarter. Additionally, one operated drilling rig is active in the Central Louisiana/East Texas core area.
Operations Update:
South Texas Operations
In the Company’s South Texas core area, nine operated wells and one non-operated well were completed during the third quarter. In McMullen County, four operated Olmos wells and two operated Eagle Ford wells were completed. In Webb County, two operated Eagle Ford wells were completed and in LaSalle County, one operated Eagle Ford well was completed.
Initial Production Test Rates of South Texas Horizontal Wells
Completed in Third Quarter 2011
| Well Name | | County/Formation Target | | Oil (Bbls/d) | | Natural Gas (MMcf/d) | | Natural Gas Liquids (Bbls/d) | | Choke Setting | | Pressure (psi) |
| Siddons OL 3H | | McMullen – Olmos | | -- | | 5.0 | | 327 | | 20/64” | | 5,400 |
| Whitehurst OL 3H | | McMullen – Olmos | | 608 | | 1.4 | | 87 | | 20/64” | | 2,685 |
| AFP OL 7H | | McMullen – Olmos | | 144 | | 3.9 | | 256 | | 20/64” | | 4,525 |
AFP OL 6H (4 stages) | | McMullen – Olmos | | 168 | | 1.0 | | 68 | | 18/64” | | 1,800 |
| NBR EF 1H | | McMullen – Eagle Ford | | 80 | | 2.6 | | 274 | | 20/64” | | 1,464 |
| Y Bar EF 2H | | McMullen – Eagle Ford | | 624 | | 1.6 | | 225 | | 20/64” | | 2,575 |
Bracken JV 10H (Non-Operated) | | McMullen – Eagle Ford | | 240 | | 6.9 | | 767 | | 20/64” | | 6,300 |
| Fasken B EF 2H | | Webb – Eagle Ford | | -- | | 10.4 | | -- | | 20/64” | | 5,294 |
| Fasken B EF 5H | | Webb – Eagle Ford | | -- | | 8.3 | | -- | | 20/64” | | 4,210 |
| Snowden EF 1H | | LaSalle – Eagle Ford | | 672 | | 3.3 | | 261 | | 20/64” | | 1,800 |
Initial Production Test Rates of South Texas Horizontal Wells
Completed to Date in Fourth Quarter 2011
| Well Name | | County/Formation Target | | Oil (Bbls/d) | | Natural Gas (MMcf/d) | | Natural Gas Liquids (Bbls/d) | | Choke Setting | | Pressure (psi) |
| SMR EF 4H | | McMullen – Eagle Ford | | 1,398 | | 2.7 | | 392 | | 16/64” | | 3,125 |
| SMR EF 5H | | McMullen – Eagle Ford | | 1,188 | | 0.4 | | 57 | | 14/64” | | 3,600 |
During the first week of November, Swift Energy resumed production and sales of natural gas from the Eagle Ford shale in the Fasken field in Webb County, TX. This production had been shut-in as a result of a third party pipeline failure, which was announced on September 29. Intermittent production curtailments are expected in this area as work necessary to ensure the integrity of the system is performed by the operator.
Southeast Louisiana
In the Lake Washington field in Plaquemines Parish, LA, the Company continued its ongoing recompletion and production optimization program. The average initial production response of six recompletions that were performed was approximately 563 gross Boe/d. The ten production optimization projects that were carried out averaged an initial production response of approximately 167 gross Boe/d.
Central Louisiana/East Texas
In the Company’s Central Louisiana/East Texas core area, one operated well and one non-operated well were drilled, both targeting the Austin Chalk formation in the Burr Ferry field in Vernon Parish, LA.
The GASRS 16-1 well, a non-operated well, was completed in the Austin Chalk and had an initial production rate of 207 bbls/d of oil and 1.3 MMcfg/d with flowing casing pressure of 1,250 psi on a 25/64” choke. This well, drilled near the southern extent of the Company’s joint operating area, encountered fewer natural fractures than the wells drilled farther north have encountered. This well is important in understanding the geology in the area, which is essential to future development plans.
The Swift Energy operated GASRS 20-1 finished drilling operations during the third quarter and was completed in the Austin Chalk. A mechanical problem occurred during the initial cleanup of the well that required a workover rig to resolve. A workover rig is currently on this well and work is underway to remedy the issue. This well bore remained in zone for the extent of the 4,254 foot lateral and encountered high natural fracture density and strong tubing pressure.
Reaffirmation of Borrowing Base
After a regularly scheduled semi-annual review in November, Swift Energy’s ten member bank group affirmed the Company’s borrowing base under its revolving credit facility to be $400 million, which is equal to the previous borrowing base amount. Swift Energy elected to retain the existing $300 million commitment amount and there are currently no borrowings outstanding.
Divestiture
During the third quarter, Swift Energy sold its interest in six fields in South Louisiana, two in Texas and one in Alabama to EnergyQuest II, LLC effective August 1, 2011. The final sales price of the property interests sold was $53.5 million. This sale closed in October. Swift Energy will use the net cash proceeds of approximately $48.8 million from this transaction (as adjusted for cash flows from effective date through the closing date) to fund a portion of its 2011 capital expenditures. The disposition sales price is further subject to any customary post-closing adjustments, which are not expected to be material.
Price Risk Management
Swift Energy currently has no natural gas or crude oil price risk protection in place. On an ongoing basis, details of Swift Energy’s complete price risk management activities can be found on the Company’s website (www.swiftenergy.com).
Earnings Conference Call
Swift Energy will conduct a live conference call today, November 3, at 10:00 a.m. EDT to discuss third quarter 2011 financial results. To participate in this conference call, dial 973-339-3086 five to ten minutes before the scheduled start time and indicate your intention to participate in the Swift Energy conference call. A digital replay of the call will be available later on November 3 until November 10, by dialing 404-537-3406 and using Conference ID # 15587761. Additionally, the conference call will be available over the Internet by accessing the Company’s website at www.swiftenergy.com and by clicking on the event hyperlink. This webcast will be available online and archived at the Company’s website.
Swift Energy Company, founded in 1979 and headquartered in Houston, engages in developing exploring, acquiring and operating oil and gas properties, with a focus on oil and natural gas reserves onshore in Texas and Louisiana and in the inland waters of Louisiana.
This press release includes “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. The opinions, forecasts, projections, guidance or other statements other than statements of historical fact, are forward-looking statements. These statements are based upon assumptions that are subject to change and to risks, especially the uncertainty and costs of finding, replacing, developing and acquiring reserves, availability and cost of capital, labor, services, supplies and facility capacity, hurricanes or tropical storms disrupting operations, and, volatility in oil or gas prices, uncertainty and costs of finding, replacing, developing or acquiring reserves, and disruption of operations Although the Company believes that the expectations reflected in such forward-looking statements are reasonable, it can give no assurance that such expectations will prove to have been correct. Certain risks and uncertainties inherent in the Company’s business are set forth in the filings of the Company with the Securities and Exchange Commission. Estimates of future financial or operating performance provided by the Company are based on existing market conditions and engineering and geologic information available at this time. Actual financial and operating performance may be higher or lower. Future performance is dependent upon oil and gas prices, exploratory and development drilling results, engineering and geologic information and changes in market conditions.
SWIFT ENERGY COMPANY
SUMMARY FINANCIAL INFORMATION
FROM CONTINUING OPERATIONS
(Unaudited)
(In Thousands Except Per Share and Price Amounts)
| | | Three Months Ended September 30 | | | Nine Months Ended September 30 | |
| | | 2011 | | | 2010 | | | Percent Change | | | 2011 | | | 2010 | | | Percent Change | |
| Revenues: | | | | | | | | | | | | | | | | | | |
| Oil & Gas Sales | | $ | 143,123 | | | $ | 105,811 | | | | 35 | % | | $ | 446,537 | | | | 320,887 | | | | 39 | % |
| Other | | | (591 | ) | | | (165 | ) | | | | | | | (2,499 | ) | | | 1,505 | | | | | |
| Total Revenue | | $ | 142,532 | | | $ | 105,646 | | | | 35 | % | | $ | 444,038 | | | | 322,392 | | | | 38 | % |
| Income From Continuing Operations | | $ | 17,007 | | | $ | 9,403 | | | | 81 | % | | $ | 63,938 | | | | 36,156 | | | | 77 | % |
| Basic EPS – Continuing Operations | | $ | 0.39 | | | $ | 0.24 | | | | 61 | % | | $ | 1.48 | | | | 0.94 | | | | 58 | % |
| Diluted EPS – Continuing Operations | | $ | 0.39 | | | $ | 0.24 | | | | 61 | % | | $ | 1.47 | | | | 0.93 | | | | 58 | % |
| Net Cash Provided By Operating Activities – Continuing Operations | | $ | 101,573 | | | $ | 64,723 | | | | 57 | % | | $ | 288,514 | | | | 193,741 | | | | 49 | % |
| Net Cash Provided By Operating Activities, Per Diluted Share – Continuing Operations | | $ | 2.38 | | | $ | 1.70 | | | | 40 | % | | $ | 6.77 | | | | 5.10 | | | | 33 | % |
Cash Flow Before Working Capital Changes(2) (non-GAAP measure) – Continuing Operations | | $ | 90,021 | | | $ | 61,709 | | | | 46 | % | | $ | 274,764 | | | | 191,360 | | | | 44 | % |
| Cash Flow Before Working Capital Changes, Per Diluted Share – Continuing Operations | | $ | 2.11 | | | $ | 1.62 | | | | 30 | % | | $ | 6.45 | | | | 5.04 | | | | 28 | % |
| Weighted Average Shares Outstanding (Basic) | | | 42,470 | | | | 37,880 | | | | (12 | )% | | | 42,365 | | | | 37,792 | | | | (12 | )% |
| Weighted Average Shares Outstanding (Diluted) | | | 42,678 | | | | 38,058 | | | | (12 | )% | | | 42,619 | | | | 37,995 | | | | (12 | )% |
| EBITDA (non-GAAP measure) | | $ | 91,421 | | | $ | 65,117 | | | | 40 | % | | $ | 293,832 | | | | 202,778 | | | | 45 | % |
| Production (MBoe) – Continuing Operations | | | 2.54 | | | | 2.07 | | | | 23 | % | | | 7.83 | | | | 6.14 | | | | 27 | % |
| Realized Price ($/Boe) – Continuing Operations | | $ | 56.31 | | | $ | 51.06 | | | | 10 | % | | $ | 57.04 | | | | 52.22 | | | | 9 | % |
| (1) | The production, revenue, expense, cash flow and income information reported are the results of continuing operations of Swift Energy. |
| (2) | See reconciliation on page 7. Management believes that the non-GAAP measures EBITDA and cash flow before working capital changes are useful information to investors because they are widely used by professional research analysts in the valuation, comparison, rating and investment recommendations of companies within the oil and gas exploration and production industry. Many investors use the published research of these analysts in making their investment decisions. |
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RECONCILIATION OF GAAP (A) TO NON-GAAP MEASURES
(Unaudited)
(In Thousands)
| | | Three Months Ended | | | | |
| | | September 30, 2011 | | | September 30, 2010 | | | | |
| INCOME TO EBITDA RECONCILIATIONS: | | | | | | | | | |
| Income from Continuing Operations | | $ | 17,007 | | | $ | 9,403 | | | | 81 | % |
| Provision for Income Taxes | | | 10,388 | | | | 5,652 | | | | | |
| Interest Expense, Net | | | 8,439 | | | | 8,264 | | | | | |
| Depreciation, Depletion & Amortization & ARO (b) | | | 55,587 | | | | 41,798 | | | | | |
| EBITDA | | $ | 91,421 | | | $ | 65,117 | | | | 40 | % |
| | | Nine Months Ended | | | | |
| | | September 30, 2011 | | | September 30, 2010 | | | | |
| INCOME TO EBITDA RECONCILIATIONS: | | | | | | | | | |
| Income from Continuing Operations | | $ | 63,938 | | | $ | 36,156 | | | | 77 | % |
| Provision for Income Taxes | | | 37,822 | | | | 20,788 | | | | | |
| Interest Expense, Net | | | 25,449 | | | | 24,804 | | | | | |
| Depreciation, Depletion & Amortization & ARO (b) | | | 166,623 | | | | 121,030 | | | | | |
| EBITDA | | $ | 293,832 | | | $ | 202,778 | | | | 45 | % |
| | | Three Months Ended | | | | |
| | | September 30, 2011 | | | September 30, 2010 | | | | |
| CASH FLOW RECONCILIATIONS: | | | | | | | | | |
| Net Cash Provided by Operating Activities – Continuing Operations | | $ | 101,573 | | | $ | 64,723 | | | | 57 | % |
| Increases and Decreases In: | | | | | | | | | | | | |
| Accounts Receivable | | | (5,012 | ) | | | 1,114 | | | | | |
| Accounts Payable and Accrued Liabilities | | | (7,094 | ) | | | (4,968 | ) | | | | |
| Income Taxes Payable | | | 17 | | | | (3 | ) | | | | |
| Accrued Interest | | | 537 | | | | 843 | | | | | |
| Cash Flow Before Working Capital Changes – Continuing Operations | | $ | 90,021 | | | $ | 61,709 | | | | 46 | % |
| | | Nine Months Ended | | | | |
| | | September 30, 2011 | | | September 30, 2010 | | | | |
| CASH FLOW RECONCILIATIONS: | | | | | | | | | |
| Net Cash Provided by Operating Activities – Continuing Operations | | $ | 288,514 | | | $ | 193,741 | | | | 49 | % |
| Increases and Decreases In: | | | | | | | | | | | | |
| Accounts Receivable | | | (6,694 | ) | | | (1,837 | ) | | | | |
| Accounts Payable and Accrued Liabilities | | | (8,077 | ) | | | 5,812 | | | | | |
| Income Taxes Payable | | | 234 | | | | 38 | | | | | |
| Accrued Interest | | | 787 | | | | (6,394 | ) | | | | |
| Cash Flow Before Working Capital Changes – Continuing Operations | | $ | 274,764 | | | $ | 191,360 | | | | 44 | % |
Note: Items may not total due to rounding
SWIFT ENERGY COMPANY
SUMMARY BALANCE SHEET INFORMATION
(Unaudited)
(In Thousands)
| | | As of September 30, 2011 | | | As of December 31, 2010 | |
| Assets: | | | | | | |
| Current Assets: | | | | | | |
| Cash and Cash Equivalents | | $ | 15,999 | | | $ | 86,367 | |
| Other Current Assets | | | 60,638 | | | | 71,427 | |
| Current Assets Held for Sale | | | - | | | | 564 | |
| Total Current Assets | | | 76,637 | | | | 158,358 | |
| | | | | | | | | |
| Oil and Gas Properties | | | 4,338,878 | | | | 3,913,602 | |
| Other Fixed Assets | | | 37,344 | | | | 37,505 | |
| Less-Accumulated DD&A | | | (2,540,613 | ) | | | (2,378,262 | ) |
| Total Properties | | | 1,835,609 | | | | 1,572,845 | |
| | | | | | | | | |
| Other Assets | | | 12,222 | | | | 12,713 | |
| | | $ | 1,924,468 | | | $ | 1,743,916 | |
| Liabilities: | | | | | | | | |
| Current Liabilities | | $ | 187,577 | | | $ | 156,735 | |
| Long-Term Debt | | | 471,809 | | | | 471,624 | |
| Deferred Income Taxes | | | 192,131 | | | | 157,565 | |
| Asset Retirement Obligation | | | 91,237 | | | | 70,171 | |
| Other Long-term Liabilities | | | 10,221 | | | | 7,804 | |
| Stockholders’ Equity | | | 971,493 | | | | 880,017 | |
| | | $ | 1,924,468 | | | $ | 1,743,916 | |
Note: Items may not total due to rounding
SWIFT ENERGY COMPANY
SUMMARY INCOME STATEMENT INFORMATION
(Unaudited)
In Thousands Except Per Boe Amounts
| | | Three Months Ended | | | Nine Months Ended | |
| | | September 30, 2011 | | | Per Boe | | | September 30, 2011 | | | Per Boe | |
| Revenues: | | | | | | | | | | | | |
| Oil & Gas Sales | | $ | 143,123 | | | $ | 56.31 | | | $ | 446,537 | | | $ | 57.04 | |
| Other Revenue | | | (591 | ) | | | | | | | (2,499 | ) | | | | |
| | | | 142,532 | | | | 56.07 | | | | 444,038 | | | | 56.72 | |
| Costs and Expenses: | | | | | | | | | | | | | | | | |
| General and Administrative, net | | | 11,378 | | | | 4.48 | | | | 32,687 | | | | 4.18 | |
| Depreciation, Depletion & Amortization | | | 54,404 | | | | 21.40 | | | | 163,141 | | | | 20.84 | |
| Accretion of Asset Retirement Obligation (ARO) | | | 1,183 | | | | 0.47 | | | | 3,482 | | | | 0.44 | |
| Lease Operating Costs | | | 26,206 | | | | 10.31 | | | | 78,296 | | | | 10.00 | |
| Severance & Other Taxes | | | 13,527 | | | | 5.32 | | | | 39,223 | | | | 5.01 | |
| Interest Expense, Net | | | 8,439 | | | | 3.32 | | | | 25,449 | | | | 3.25 | |
| Total Costs & Expenses | | | 115,137 | | | | 45.30 | | | | 342,278 | | | | 43.72 | |
| Income from Continuing Operations Before Income Taxes | | | 27,395 | | | | 10.78 | | | | 101,760 | | | | 13.00 | |
| Provision for Income Taxes | | | 10,388 | | | | 4.09 | | | | 37,822 | | | | 4.83 | |
| Income from Continuing Operations | | | 17,007 | | | | 6.69 | | | | 63,938 | | | | 8.17 | |
| Income (Loss) from Discontinued Operations, Net of Taxes | | | (31 | ) | | NM | | | | 14,247 | | | NM | |
| Net Income | | $ | 16,976 | | | NM | | | $ | 78,185 | | | NM | |
| | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | |
| Additional Information: | | | | | | | | | | | | | | | | |
| Total Capital Expenditures | | $ | 175,219 | | | | | | | $ | 425,115 | | | | | |
| Capitalized Geological & Geophysical | | $ | 7,359 | | | | | | | $ | 21,535 | | | | | |
| Capitalized Interest Expense | | $ | 1,973 | | | | | | | $ | 5,720 | | | | | |
| Deferred Income Tax | | $ | 10,255 | | | | | | | $ | 36,332 | | | | | |
Note: Items may not total due to rounding
SWIFT ENERGY COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOW
(Unaudited)
(In Thousands)
| | | Nine Months Ended | |
| | | September 30, 2011 | | | September 30, 2010 | |
| Cash Flows From Operating Activities: | | | | | | |
| Net Income | | $ | 78,185 | | | $ | 35,994 | |
| (Gain) Loss From Discontinued Operations, Net of Taxes | | | (14,247 | ) | | | 162 | |
| Adjustments to Reconcile Net Income to Net Cash Provided by Operating Activities - | | | | | | | | |
| Depreciation, Depletion, and Amortization | | | 163,141 | | | | 118,103 | |
| Accretion of Asset Retirement Obligation (ARO) | | | 3,482 | | | | 2,927 | |
| Deferred Income Taxes | | | 36,332 | | | | 26,151 | |
| Stock Based Compensation Expense | | | 9,281 | | | | 7,550 | |
| Other | | | (1,410 | ) | | | 473 | |
| Change in Assets and Liabilities - | | | | | | | | |
| Decrease in Accounts Receivable | | | 6,694 | | | | 1,837 | |
| Increase (Decrease) in Accounts Payable and Accrued Liabilities | | | 8,077 | | | | (5,812 | ) |
| Decrease in Income Taxes Payable | | | (234 | ) | | | (38 | ) |
| Increase (Decrease) in Accrued Interest | | | (787 | ) | | | 6,394 | |
| Cash Provided by Operating Activities – Continuing Operations | | | 288,514 | | | | 193,741 | |
| Cash Provided by Operating Activities – Discontinued Operations | | | 5 | | | | (29 | ) |
| Net Cash Provided by Operating Activities | | | 288,519 | | | | 193,712 | |
| | | | | | | | | |
| Cash Flows From Investing Activities: | | | | | | | | |
| Additions to Property and Equipment | | | (368,754 | ) | | | (228,379 | ) |
| Proceeds from the Sale of Property and Equipment | | | 6,084 | | | | 133 | |
| Cash Used in Investing Activities – Continuing Operations | | | (362,670 | ) | | | (228,246 | ) |
| Cash Provided by Investing Activities – Discontinued Operations | | | 5,000 | | | | 5,000 | |
| Net Cash Used in Investing Activities | | | (357,670 | ) | | | (223,246 | ) |
| | | | | | | | | |
| Cash Flows From Financing Activities: | | | | | | | | |
| Net Proceeds From Issuance of Common Stock | | | 2,102 | | | | 1,829 | |
| Purchase of Treasury Shares | | | (3,319 | ) | | | (1,775 | ) |
| Payments of Debt Issuance Costs | | | --- | | | | (3,481 | ) |
| Cash Provided by (Used in) Financing Activities – Continuing Operations | | | (1,217 | ) | | | (3,427 | ) |
| Cash Provided by (Used in) Financing Activities – Discontinued Operations | | | --- | | | | --- | |
| Net Cash Provided by (Used in) Financing Activities | | | (1,217 | ) | | | (3,427 | ) |
| Net Increase/(Decrease) in Cash and Cash Equivalents | | | (70,368 | ) | | | (32,961 | ) |
| Cash and Cash Equivalents at the Beginning of the Period | | | 86,367 | | | | 38,469 | |
| Cash and Cash Equivalents at the End of the Period | | $ | 15,999 | | | $ | 5,508 | |
SWIFT ENERGY COMPANY
OPERATIONAL INFORMATION
QUARTERLY COMPARISON -- SEQUENTIAL & YEAR-OVER-YEAR
(Unaudited)
| | | Three Months Ended | | | | | | Three Months Ended | |
| | | Sept. 30, 2011 | | | June 30, 2011 | | | Percent Change | | | Sept. 30, 2010 | | | Percent Change | |
| Production : | | | | | | | | | | | | | | | |
| Oil & Natural Gas Equivalent (MBoe) | | | 2,542 | | | | 2,641 | | | | (4 | ) % | | | 2,072 | | | | 23 | % |
| Natural Gas (Bcf) | | | 8.15 | | | | 7.87 | | | | 4 | % | | | 4.87 | | | | 67 | % |
| Crude Oil (MBbl) | | | 937 | | | | 994 | | | | (6 | ) % | | | 1,005 | | | | (7 | ) % |
| NGL (MBbl) | | | 247 | | | | 335 | | | | (26 | ) % | | | 256 | | | | (4 | ) % |
| | | | | | | | | | | | | | | | | | | | | |
| Average Prices: | | | | | | | | | | | | | | | | | | | | |
| Combined Oil & Natural Gas ($/Boe) | | $ | 56.31 | | | $ | 60.29 | | | | (7 | ) % | | $ | 51.06 | | | | 10 | % |
| Natural Gas ($/Mcf) | | $ | 3.68 | | | $ | 3.93 | | | | (6 | ) % | | $ | 3.87 | | | | (5 | ) % |
| Crude Oil ($/Bbl) | | $ | 105.55 | | | $ | 112.09 | | | | (6 | ) % | | $ | 76.39 | | | | 38 | % |
| NGL ($/Bbl) | | $ | 57.76 | | | $ | 50.41 | | | | 15 | % | | $ | 39.88 | | | | 45 | % |
SWIFT ENERGY COMPANY
FOURTH QUARTER AND FULL YEAR 2011
GUIDANCE ESTIMATES
| | Actual For Third Quarter 2011 | | Guidance For Fourth Quarter 2011 | | Guidance For Full Year 2011 |
| | | | | | | | | | | | |
Production Volumes (MMBoe) | | 2.54 | | | 2.50 | - | 2.70 | | 10.3 | - | 10.5 |
| | | | | | | | | | | | |
| Production Mix: | | | | | | | | | | | |
| Natural Gas (Bcf) | | 8.15 | | | 6.98 | - | 7.83 | | 30.9 | - | 31.8 |
| Crude Oil (MMBbl) | | 0.94 | | | 0.49 | - | 0.96 | | 3.81 | - | 3.88 |
| Natural Gas Liquids (MMBbl) | | 0.25 | | | 0.39 | - | 0.42 | | 1.32 | - | 1.36 |
| Product Pricing (Note 1): | | | | | | | | | | | |
| Natural Gas (per Mcf) | | | | | | | | | | | |
| NYMEX Differential (Note 2) | $ | (0.32) | | | ($0.15) | - | ($0.55) | | ($0.25) | - | ($0.75) |
| Crude Oil (per Bbl) | | | | | | | | | | | |
| NYMEX differential (Note 3) | $ | 16.01 | | | $10.00 | - | $15.00 | | $6.00 | - | $8.00 |
| NGL (per Bbl) | | | | | | | | | | | |
| Percent of NYMEX Crude | | 65% | | | 50% | - | 60% | | 50% | - | 60% |
| Oil & Gas Production Costs: | | | | | | | | | | | |
| Lease Operating Costs (per Boe) | $ | 10.31 | | | $9.00 | - | $9.70 | | $9.65 | - | $9.90 |
| Severance & Ad Valorem Taxes (as % of Revenue dollars) | | 9.5% | | | 9.0% | - | 10.0% | | 8.0% | - | 9.0% |
| Other Costs: | | | | | | | | | | | |
| G&A per Boe | $ | 4.48 | | | $4.35 | - | $4.70 | | $4.05 | - | $4.30 |
| Interest Expense per Boe | $ | 3.32 | | | $3.20 | - | $3.35 | | $3.20 | - | $3.35 |
| DD&A per Boe | $ | 21.40 | | | $21.10 | - | $22.00 | | $20.75 | - | $21.50 |
| Supplemental Information: | | | | | | | | | | | |
| Capital Expenditures | | | | | | | | | | | |
| Operations | $ | 165,887 | | | $96,675 | - | $132,675 | | $494,800 | - | $530,800 |
| Acquisitions/(Dispositions), net | | --- | | | ($48,800) | - | ($48,800) | | ($48,800) | - | ($48,800) |
| Capitalized G&G (Note 4) | $ | 7,359 | | | $ 6,700 | - | $ 7,300 | | $27,000 | - | $29,000 |
| Capitalized Interest | $ | 1,973 | | | $ 1,800 | - | $ 2,100 | | $7,000 | - | $9,000 |
| Total Capital Expenditures | $ | 175,219 | | | $56,375 | - | $93,275 | | $480,000 | - | $520,000 |
| | | | | | | | | | | | |
| Basic Weighted Average Shares | | 42,470 | | | 42,400 | - | 42,600 | | 42,300 | - | 42,500 |
| Diluted Computation: | | | | | | | | | | | |
| Weighted Average Shares | | 42,678 | | | 42,700 | - | 42,900 | | 42,600 | - | 42,800 |
| | | | | | | | | | | | |
| Effective Tax Rate | | 37.9% | | | 36.5% | - | 37.5% | | 36.5% | - | 37.5% |
| Deferred Tax Percentage | | 99% | | | 95% | - | 100% | | 94% | - | 97% |
| Note 1: | Swift Energy now maintains all its current price risk management instruments (hedge positions) on its Hedge Activity page on the Swift Energy website (www.swiftenergy.com). |
| Note 2: | Average of monthly closing Henry Hub NYMEX futures price for the respective contract months, included in the period, which best benchmarks the 30-day price received for domestic natural gas sales. |
| Note 3: | Average of daily WTI NYMEX futures price during the calendar period reflected which best benchmarks the daily price received for the majority of crude oil sales. |
| Note 4: | Does not include capitalized acquisition costs, incorporated in acquisitions when occurred. |
