Swift Energy Announces: 96% Increase in First Quarter 2013 Net Income to $7.2 Million, or $0.16 Per Diluted Share

  Swift Energy Announces: 96% Increase in First Quarter 2013 Net Income to
  $7.2 Million, or $0.16 Per Diluted Share

8% Increase in First Quarter 2013 Revenues to $146 Million;

First Quarter 2013 Adjusted Cash Flow of $72.6 Million, or $1.67 Per Diluted
Share;

Business Wire

HOUSTON -- May 02, 2013

Swift Energy Company (NYSE: SFY) announced today earnings of $7.2 million for
the first quarter of 2013, or $0.16 per diluted share, an increase of 96% when
compared to first quarter 2012 earnings from net income of $3.6 million, or
$0.08 per diluted share, and a decrease of 37% when compared to net income of
$11.2 million in the fourth quarter of 2012.

Adjusted cash flow (cash flow before working capital changes, a non-GAAP
measure - see page 7 for reconciliation to the GAAP measure) for the first
quarter of 2013 increased 5% to $72.6 million, or $1.67 per diluted share,
compared to $69.1 million, or $1.61 per diluted share, for the first quarter
of 2012, and decreased 21% when compared to adjusted cash flow of $91.4
million, or $2.13 per diluted share, for the fourth quarter of 2012.

Swift Energy produced 2.82 million barrels of oil equivalent (“MMBoe”) during
the first quarter of 2013, a 1% increase over first quarter 2012 production of
2.80 MMBoe, and down 9% compared to fourth quarter 2012 production of 3.11
MMBoe.

Terry Swift, CEO of Swift Energy commented, “Swift Energy delivered strong
operational results during the first quarter. Our refined drilling and
completion techniques in the Eagle Ford shale and the strong performance of
our base production in Lake Washington resulted in higher than forecast
production volumes. We’re encouraged by our progress so far this year.

“Near term, our focus remains on improving performance, cost efficiencies and
results throughout our active operational areas. We are also taking steps to
introduce new, high value opportunities to our operations through horizontal
drilling in the Louisiana Wilcox, horizontal drilling in the Southwestern
Colorado Niobrara and Subsalt exploration in South Louisiana. Finally, as
demonstrated by the sale of our Brookeland field, we will be looking at
monetizing assets we control that are not a focus of our operations to bring
forward unrecognized value in our portfolio.”

First Quarter Revenues and Expenses

Total revenues for the first quarter of 2013 increased 8% to $146.2 million
from the $135.9 million generated in the first quarter of 2012. This increase
is primarily attributable to higher oil production and higher gas prices in
the 2013 period.

Depreciation, depletion and amortization expense (“DD&A”) of $21.33 per barrel
of oil equivalent (“Boe”) in the first quarter of 2013 decreased 3% from
$21.92 of DD&A per Boe in the comparable period in 2012 due to higher reserves
volumes partially offset by a higher depletable base.

Lease operating costs before severance and ad valorem taxes, were $9.73 per
Boe in the first quarter 2013, an approximate 11% increase when compared to
$8.80 per Boe incurred in the same period of 2012. These expenses were higher
due to activities associated with a well control incident in Lake Washington,
coupled with increased salt water disposal, chemical treating, lease operator
and compressor rental costs in South Texas, offset partially by lower workover
costs.

Transportation and processing expense in the first quarter of 2013 of $2.14
per Boe increased from $1.64 per Boe in the first quarter of 2012 due
primarily to a one-time prior period amount recognized in the first quarter of
2013.

Severance and ad valorem taxes decreased to $3.47 per Boe in the first quarter
of 2013 from $4.63 per Boe in the first quarter of 2012 primarily due to a
higher percentage of revenues associated with production in Texas which
carries a lower overall severance tax rate than Louisiana and some prior
period retroactive tax credits approved and received during the first quarter
of 2013.

General and administrative expenses increased to $4.51 per Boe during the
first quarter of 2013, up from $4.25 per Boe in the same period in 2012.
Interest expense increased to $5.96 per Boe in the first quarter of 2013
compared to $4.81 per Boe for the same period in 2012 due to new long term
debt that was issued during the fourth quarter of 2012.

First Quarter Pricing

The Company realized an aggregate average price of $51.97 per Boe during the
quarter, an increase from the $48.64 per Boe average price received in the
first quarter of 2012.

In the first quarter of 2013, Swift Energy’s average crude oil prices
decreased 3% to $108.45 per barrel from $111.99 per barrel realized in the
same period in 2012. For the same period, average natural gas prices were
$2.96 per thousand cubic feet (“Mcf”), up 36% from the $2.18 per Mcf average
price realized a year earlier. Prices for NGLs averaged $29.90 per barrel in
the 2013 first quarter, a 34% decrease from first quarter 2012 NGL prices of
$45.30 per barrel.

First Quarter Drilling Activity

In the first quarter of 2013, Swift Energy drilled ten operated development
wells and one non-operated development well. In the Company’s South Texas core
area, six horizontal wells were drilled to the Eagle Ford shale, five in La
Salle County and one in McMullen County, and three were drilled to the Olmos
formation in McMullen County.

In Swift Energy’s Southeast Louisiana core area, one well was drilled in the
Lake Washington field. In the Company’s Central Louisiana/East Texas core
area, one non-operated well targeting the Austin Chalk was drilled in the Burr
Ferry field.

There are currently four operated rigs drilling in the Company’s South Texas
core area and one operated barge rig drilling in its Southeast Louisiana area.
One non-operated rig is also active in the Central Louisiana area.

Operations Update:

South Texas Operations

In the Company’s South Texas core area, nine operated wells were completed
during the first quarter. In McMullen County, four Eagle Ford wells and two
Olmos wells were completed. In La Salle County, three Eagle Ford wells were
completed.

Initial Production Test Rates of South Texas Horizontal Wells
Completed in First Quarter 2013
(Operated and 100% Working Interest, unless otherwise noted)
                                                                                         
                                                  Natural      Residual
                                                  Gas          Natural      Barrels of
                                    Oil          Liquids      Gas          Oil            Pressure     Choke
Well Name     County/Formation   (Bbls/d)   (Bbls/d)   (MMcf/d)   Equivalent   (psi)      Setting
                Target
Baetz A EF      La Salle – Eagle     315          407          3.4          1,293          2,800        20/64”
3H              Ford
PCQ EF 7H       McMullen – Eagle     1,288        191          1.6          1,742          2,537        16/64”
                Ford
Hayes EF 3H     McMullen – Eagle     713          75           0.6          891            3,183        14/64”
                Ford
HayesEF 4H      McMullen – Eagle     678          74           0.6          854            2,891        14/64”
                Ford
Siddons OL      McMullen – Olmos     21           366          4.3          1,108          3,950        20/64”
4H
Quintanilla     McMullen – Eagle
Me-You EF       Ford                 500          121          1.0          788            2,400        17/64”
2H
SMR OL 6H       McMullen – Olmos     884          91           0.6          1,074          2,127        20/64”
ARN EF 6H       La Salle – Eagle     360          115          1.0          637            2,148        18/64”
                Ford
ARN EF 7H       La Salle – Eagle     407          136          1.2          735            2,402        18/64”
                Ford
                                                                                                        

Southeast Louisiana

In the Lake Washington field in Plaquemines Parish, LA, the Company continued
its ongoing recompletion and production optimization program, performing one
recompletion and twenty-two production optimization projects during the
quarter.

In the Lake Washington field, the BLD CM 21, drilled to a measured depth of
6,441 feet and encountering 150 feet of true vertical pay, was recently
completed and tested at initial test rates of 667 bbls/d of oil and 0.5 Mmcf/d
of natural gas with flowing tubing pressure of 580 psi on a 26/64” choke.

At Bay de Chene, the BDC UA #139, drilled during the fourth quarter to a
measured depth of 11,233 feet and encountering 81 feet of true vertical pay,
was completed and initially tested at rates of 5.3 Mmcf/d of natural gas and
17 bbls/d of condensate with flow tubing pressure of 3,120 psi on a 16/64”
choke.

Central Louisiana

In South Bearhead Creek, the Company has drilled its first upper Wilcox
horizontal test well. The James O Dolby H1 has a horizontal length of 3,387
feet and a 12 stage completion will be performed during the second quarter.

The GASRS 29-1-10 well, drilled and completed during the first quarter in the
Burr Ferry Field in Vernon Parish, produced hydrocarbons at an initial test
rate of 1,042 bbls/d of oil and 3.1 MMcf/d of natural gas with flowing tubing
pressure of 5,900 psi on a 16/64” choke. This well experienced a significant
mechanical problem shortly after being placed on production and has been
shut-in pending further evaluation.

Borrowing Base Reaffirmed

After a regularly scheduled semi-annual review by its 11 member bank group,
Swift Energy’s borrowing base and commitment amount of $450 million was
reaffirmed under its revolving credit facility effective April 26, 2013. The
credit facility matures on November 1, 2017.

Divestiture

Swift Energy divested of its interest in the Brookeland field in Louisiana on
May 1, 2013 and received sale proceeds of approximately $6.0 million. The sale
which has an effective date of April 1, 2013 also included the buyer’s
assumption of a plugging and abandonment liability, which was carried at a net
present value of $11.3 million at March 31, 2013. Swift Energy will use the
net cash proceeds from this transaction to fund a portion of its 2013 capital
expenditures.

Production attributable to the divested field averaged 359 barrels of oil
equivalent per day during the first quarter of 2013 with aggregate proved
reserves of approximately 0.8 million barrels of oil equivalent (100% proved
developed producing and 30% oil/31% NGL/39% natural gas) at year-end 2012. The
disposition sales price is subject to any customary post-closing adjustments,
which are not expected to be material.

Price Risk Management

Swift Energy has natural gas floors in place covering approximately 35% - 40%
of expected second quarter natural gas production at an average NYMEX strike
price of $3.81 per MMBtu. The company also has crude oil floors covering
approximately 20-25% of expected second quarter crude oil production at an
average NYMEX strike price of $93.60 per barrel. For the third quarter, the
Company has also purchased natural gas floors covering 620,000 MMbtu per month
at an average NYMEX strike price of $3.95 per MMBtu. Additionally, the Company
has entered into a collar transaction for the fourth quarter of 2013 that
provides a floor price of $3.75 per MMBtu covering 590,000 MMBtu per month of
natural gas production and a ceiling price of $5.08 per MMBtu for 590,000
MMBtu per month, as well as, a three-way collar with a floor price of $4.00
per MMBtu, a ceiling price of $5.00 per MMBtu and a higher call price of $6.00
per MMBtu for 600,000 MMBtu per month during the fourth quarter. 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, May 2, at 10:00 a.m.
EDT to discuss first quarter 2013 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 May 2
until May 9, by dialing 855-859-2056 and using Conference ID # 30161571.
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.

About Forward Looking Statements

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 contained herein, other than
statements of historical fact, are forward-looking statements, including
targets for 2013 production and reserves growth, estimates of 2013 capital
expenditures And guidance estimates for the first quarter of 2013 and
full-year 2013. 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
(Unaudited)
(In Thousands Except Per Share and Price Amounts)
                                    
                                       Three Months Ended
                                       March 31
                                                                   Percent
                                       2013            2012            Change
Revenues:
Oil & Gas Sales                        $ 146,477       $ 136,142       8    %
Other                                   (240    )      (264    )
Total Revenue                          $ 146,237       $ 135,878       8    %
Net Income                             $ 7,209         $ 3,570         102  %
Basic EPS                              $ 0.16          $ 0.08          95   %
Diluted EPS                            $ 0.16          $ 0.08          96   %
Net Cash Provided By Operating         $ 62,223        $ 63,783        (2)  %
Activities
Net Cash Provided By Operating         $ 1.43          $ 1.49          (4)  %
Activities, Per Diluted Share
Cash Flow Before Working Capital       $ 72,632        $ 69,097        5    %
Changes^(2) (non-GAAP measure)
Cash Flow Before Working Capital       $ 1.67          $ 1.61          3    %
Changes, Per Diluted Share
Weighted Average Shares                  43,167          42,674        (1)  %
Outstanding (Basic)
Weighted Average Shares                  43,323          42,874        (1)  %
Outstanding (Diluted)
EBITDA (non-GAAP measure)              $ 90,283        $ 81,822        10   %
Production (MBoe)                        2.82            2.80          1    %
Realized Price ($/Boe)                 $ 51.97         $ 48.64         7    %
                                                                            

(1)   The production, revenue, expense, cash flow and income information
        reported are the results of continuing operations of Swift Energy.
        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
(2)     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.
        


SWIFT ENERGY COMPANY
RECONCILIATION OF GAAP^(a) TO NON-GAAP MEASURES
(Unaudited)
(In Thousands)
                                                                  
                                 Three Months Ended
                                                                     Percent
                                 March 31, 2013     March 31, 2012     Change
CASH FLOW RECONCILIATIONS:
Net Cash Provided by             $   62,223         $   63,783         (2)  %
Operating Activities
Increases and Decreases In:
Accounts Receivable                  5,191              (3,193  )
Accounts Payable and Accrued         (3,085  )          7,913
Liabilities
Accrued Interest                    8,303            594     
Cash Flow Before Working         $   72,632        $   69,097        5    %
Capital Changes
                                                                            
INCOME TO EBITDA                                                     
RECONCILIATIONS:
                                                                            
Net Income                       $   7,209          $   3,570          102  %
Provision for Income Taxes           4,377              2,312
Interest Expense, Net                16,802             13,465
Depreciation, Depletion &           61,895           62,475  
Amortization & ARO (b)
EBITDA                           $   90,283        $   81,822        10   %
                                                                            
                                                                            
(a)GAAP—Generally Accepted Accounting Principles
(b)Includes accretion of asset retirement obligation
                                                                            
Note: Items may not total due to rounding



SWIFT ENERGY COMPANY
SUMMARY BALANCE SHEET INFORMATION
(Unaudited)
(In Thousands)
                                              
                                As of              As of
                                March 31, 2013     December 31, 2012
Assets:
Current Assets:
Cash and Cash Equivalents       $ 248              $  170
Other Current Assets             84,051            80,367      
Total Current Assets              84,299              80,537
                                                   
Oil and Gas Properties            5,295,365           5,151,103
Other Fixed Assets                41,907              41,690
Less-Accumulated DD&A            (2,908,302 )       (2,847,773  )
Total Properties                  2,428,970           2,345,020
                                                   
Other Assets                     17,930            18,504      
                                $ 2,531,199       $  2,444,061   
Liabilities:
Current Liabilities             $ 179,867          $  177,480
Long-Term Debt                    987,168             916,934
Deferred Income Taxes             226,286             223,243
Asset Retirement Obligation       79,523              79,643
Other Long-term Liabilities       10,069              9,901
Stockholders’ Equity             1,048,286         1,036,860   
                                $ 2,531,199       $  2,444,061   
                                                                  
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             Three Months Ended
                      March 31, 2013     Per Boe     March 31,         Per Boe
                                                     2012
Revenues:
Oil & Gas Sales       $  146,477         $ 51.97     $  136,142        $ 48.64
Other Revenue           (240     )                   (264     )     
                        146,237         51.88       135,878        48.55
Costs and
Expenses:
General and
Administrative,          12,725            4.51         11,883           4.25
net
Depreciation,
Depletion &              60,120            21.33        61,363           21.92
Amortization
Accretion of
Asset Retirement         1,775             0.63         1,112            0.40
Obligation (ARO)
Lease Operating          27,424            9.73         24,619           8.80
Costs
Transportation
and Processing           6,030             2.14         4,594            1.64
Expense
Severance & Other        9,775             3.47         12,960           4.63
Taxes
Interest Expense,       16,802          5.96        13,465         4.81
Net
Total Costs &           134,651         47.77       129,996        46.45
Expenses
Income Before            11,586            4.11         5,882            2.10
Income Taxes
Provision for           4,377           1.55        2,312          0.83
Income Taxes
Net Income            $  7,209          $ 2.56      $  3,570         $ 1.28
                                                                       
                                                                       
Additional
Information:
Total Capital         $  144,479                     $  181,842
Expenditures
Capitalized
Geological &          $  9,129                       $  8,157
Geophysical
Capitalized           $  1,943                       $  1,999
Interest Expense
Deferred Income       $  4,377                       $  2,312
Tax
                                                                       
Note: Items may not total due to rounding



SWIFT ENERGY COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOW
(Unaudited)
(In Thousands)
                                          
                                             Three Months Ended
                                             March 31, 2013   March 31, 2012
Cash Flows From Operating Activities:
Net Income                                   $  7,209           $  3,570
Adjustments to Reconcile Net Income to
Net Cash Provided by Operating
Activities -
Depreciation, Depletion, and                    60,120             61,363
Amortization
Accretion of Asset Retirement Obligation        1,775              1,112
(ARO)
Deferred Income Taxes                           4,377              2,312
Stock Based Compensation Expense                3,015              3,629
Other                                           (3,864    )        (2,889    )
Change in Assets and Liabilities -
(Increase)/Decrease in Accounts                 (5,191    )        3,193
Receivable
Increase/(Decrease) in Accounts Payable         3,085              (7,913    )
and Accrued Liabilities
Decrease in Accrued Interest                   (8,303    )       (594      )
Net Cash Provided by Operating                 62,223           63,783    
Activities
                                                                
Cash Flows From Investing Activities:
Additions to Property and Equipment             (132,981  )        (187,915  )
Proceeds from the Sale of Property and         999              532       
Equipment
Net Cash Used in Investing Activities          (131,982  )       (187,383  )
                                                                
Cash Flows From Financing Activities:
Net Proceeds From Bank Borrowings               70,300             ---
Net Proceeds From Issuance of Common            946                1,329
Stock
Purchase of Treasury Shares                    (1,409    )       (2,636    )
Net Cash Provided by (Used in) Financing       69,837           (1,307    )
Activities
Increase/(Decrease) in Cash and Cash            78                 (124,907  )
Equivalents
                                                                
Cash and Cash Equivalents at the               170              251,696   
Beginning of the Period
Cash and Cash Equivalents at the End of      $  248            $  126,789   
the Period
                                                                             


SWIFT ENERGY COMPANY
OPERATIONAL INFORMATION
QUARTERLY COMPARISON -- SEQUENTIAL & YEAR-OVER-YEAR
(Unaudited)
                                                            
                 Three Months Ended                       Three
                                                          Months
                                                          Ended
                 March 31,     December       Percent     March        Percent
                               31,                        31,
                2013          2012           Change      2012         Change
Production:
Oil &
Natural Gas         2,819         3,108       (9)   %       2,799      1     %
Equivalent
(MBoe)
Natural Gas         7.64          8.69        (12)  %       9.24       (17)  %
(Bcf)
Crude Oil           988           1,115       (11)  %       884        12    %
(MBbl)
NGL (MBbl)          557           545         2     %       376        48    %
                                                                       
Average
Prices:
Combined Oil
& Natural        $  51.97      $  50.87       2     %     $ 48.64      7     %
Gas ($/Boe)
Natural Gas      $  2.96       $  3.04        (3)   %     $ 2.18       36    %
($/Mcf)
Crude Oil        $  108.45     $  102.73      6     %     $ 111.99     (3)   %
($/Bbl)
NGL ($/Bbl)      $  29.90      $  31.42       (5)   %     $ 45.30      (34)  %
                                                                             


SWIFT ENERGY COMPANY
SECOND QUARTER AND FULL YEAR 2013
GUIDANCE ESTIMATES
                                                                   
                                 Actual       Guidance                    Guidance
                                 For          For Second                  For Full
                                 First
                                 Quarter      Quarter 2013                Year 2013
                                 2013                                    
Production Volumes (MMBoe)       2.82         2.75      -  2.90         11.7      -  12.1
                                                                                         
Production Mix:
Natural Gas (Bcf)                7.64         8.13       -   8.57         33.8       -   34.9
Crude Oil (MMBbl)                0.99         0.91       -   0.96         3.93       -   4.06
Natural Gas Liquids (MMBbl)      0.56         0.49       -   0.51         2.14       -   2.21
Product Pricing (Note 1):
Natural Gas (per Mcf)
NYMEX Differential (Note 2)      ($0.37)      ($0.25)    -   ($0.50)      ($0.25)    -   ($0.50)
Crude Oil (per Bbl)
NYMEX differential (Note 3)      $14.08       $7.00      -   $10.00       $7.00      -   $10.00
NGL (per Bbl)
Percent of NYMEX Crude           32%          30%        -   35%          30%        -   35%
Oil & Gas Production Costs:
Lease Operating Costs (per       $9.73        $9.20      -   $9.70        $8.50      -   $8.80
Boe)
Transportation and               $2.14        $1.95      -   $2.05        $1.95      -   $2.05
Processing (per Boe)
Severance & Ad Valorem Taxes     6.7%         8.0%       -   9.0%         8.0%       -   9.0%
(as % of Revenue dollars)
Other Costs:
G&A per Boe                      $4.51        $4.35      -   $4.60        $4.15      -   $4.35
Interest Expense per Boe         $5.96        $5.90      -   $6.20        $5.70      -   $5.90
DD&A per Boe                     $21.33       $21.10     -   $21.25       $20.50     -   $21.00
Supplemental Information:
Capital Expenditures (in
Thousands)
Operations                       $134,406     $136,700   -   $156,100     $410,000   -   $446,000
Acquisitions/(Dispositions),     ($999)       ($6,000)   -   ($6,000)     ($6,000)   -   ($6,000)
net
Capitalized G&G (Note 4)         $9,129       $7,300     -   $7,600       $28,000    -   $30,000
Capitalized Interest             $1,943       $2,000     -   $2,300       $8,000     -   $10,000
Total Capital Expenditures       $144,479     $140,000   -   $160,000     $440,000   -   $480,000
                                                                                         
Basic Weighted Average           43,167       43,300     -   43,500       43,300     -   43,600
Shares
                                                                                         
Diluted Weighted Average         43,323       43,800     -   44,000       43,800     -   44,100
Shares
                                                                                         
Effective Tax Rate               37.8%        39.0%      -   43.0%        39.0%      -   42.0%
Deferred Tax Percentage          100%         98%        -   100%         98%        -   100%
                                                                                         

            Swift Energy maintains all its current price risk management
Note 1:   instruments (hedge positions) on its Hedge Activity page on the
            Swift Energy website (www.swiftenergy.com).
            Average of monthly closing Henry Hub NYMEX futures price for the
Note 2:     respective contract months, included in the period, which best
            benchmarks the 30-day price received for natural gas sales.
            Average of daily WTI NYMEX futures price during the calendar
Note 3:     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.

Contact:

Swift Energy Company
Paul Vincent, 281-874-2700 or 800-777-2412
Director – Finance & Investor Relations
 
Press spacebar to pause and continue. Press esc to stop.