FORM 10-Q

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2011

Commission File Number 1-7850

SOUTHWEST GAS CORPORATION

(Exact name of registrant as specified in its charter)

 

California   88-0085720

(State or other jurisdiction of

incorporation or organization)

 

(I.R.S. Employer

Identification No.)

5241 Spring Mountain Road

Post Office Box 98510

Las Vegas, Nevada

  89193-8510
(Address of principal executive offices)   (Zip Code)

Registrant’s telephone number, including area code: (702) 876-7237

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes  X    No    

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes  X    No    

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” “non-accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

 

Large accelerated filer     X 

  Accelerated filer           Non-accelerated filer           Smaller reporting company        

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes        No  X 

Indicate the number of shares outstanding of each of the issuer’s classes of common stock as of the latest practicable date.

Common Stock, $1 Par Value, 45,879,314 shares as of July 29, 2011.

 

 


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Thousands of dollars, except par value)

(Unaudited)

 

000000000000 000000000000
     JUNE 30,
2011
     DECEMBER 31,
2010
 

ASSETS

     

Utility plant:

     

Gas plant

     $ 4,626,360           $ 4,569,105     

Less: accumulated depreciation

     (1,586,724)          (1,535,429)    

Acquisition adjustments, net

     1,181           1,271     

Construction work in progress

     49,866           37,489     
  

 

 

    

 

 

 

Net utility plant

     3,090,683           3,072,436     
  

 

 

    

 

 

 

Other property and investments

     176,725           134,648     
  

 

 

    

 

 

 

Restricted cash

     37,782           37,781     
  

 

 

    

 

 

 

Current assets:

     

Cash and cash equivalents

     85,964           116,096     

Accounts receivable, net of allowances

     121,865           147,605     

Accrued utility revenue

     31,700           64,400     

Income taxes receivable, net

     7,461           21,514     

Deferred income taxes

     10,755           8,046     

Deferred purchased gas costs

             -         356     

Prepaids and other current assets

     68,337           87,877     
  

 

 

    

 

 

 

Total current assets

     326,082           445,894     
  

 

 

    

 

 

 

Deferred charges and other assets

     293,772           293,434     
  

 

 

    

 

 

 

Total assets

     $ 3,925,044           $ 3,984,193     
  

 

 

    

 

 

 

CAPITALIZATION AND LIABILITIES

     

Capitalization:

     

Common stock, $1 par (authorized - 60,000,000 shares; issued and outstanding - 45,879,314 and 45,599,036 shares)

     $ 47,509           $ 47,229     

Additional paid-in capital

     816,288           807,885     

Accumulated other comprehensive income (loss), net

     (31,731)          (30,784)    

Retained earnings

     391,079           343,131     
  

 

 

    

 

 

 

Total Southwest Gas Corporation equity

     1,223,145           1,167,461     

Noncontrolling interest

     (702)          (465)    
  

 

 

    

 

 

 

Total equity

     1,222,443           1,166,996     

Long-term debt, less current maturities

     941,551           1,124,681     
  

 

 

    

 

 

 

Total capitalization

     2,163,994           2,291,677     
  

 

 

    

 

 

 

Current liabilities:

     

Current maturities of long-term debt

     200,000           75,080     

Accounts payable

     95,460           165,536     

Customer deposits

     87,463           86,891     

Accrued general taxes

     35,104           40,438     

Accrued interest

     16,770           20,162     

Deferred purchased gas costs

     98,813           123,344     

Other current liabilities

     93,021           85,510     
  

 

 

    

 

 

 

Total current liabilities

     626,631           596,961     
  

 

 

    

 

 

 

Deferred income taxes and other credits:

     

Deferred income taxes and investment tax credits

     503,922           466,628     

Taxes payable

     2,476           1,234     

Accumulated removal costs

     222,000           211,000     

Other deferred credits

     406,021           416,693     
  

 

 

    

 

 

 

Total deferred income taxes and other credits

     1,134,419           1,095,555     
  

 

 

    

 

 

 

Total capitalization and liabilities

     $ 3,925,044           $ 3,984,193     
  

 

 

    

 

 

 

The accompanying notes are an integral part of these statements.

 

   2   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(In thousands, except per share amounts)

(Unaudited)

 

0000000000 0000000000 0000000000 0000000000 0000000000 0000000000
     THREE MONTHS ENDED
JUNE 30,
     SIX MONTHS ENDED
JUNE 30,
     TWELVE MONTHS ENDED
JUNE 30,
 
     2011      2010      2011      2010      2011      2010  

Operating revenues:

                 

Gas operating revenues

     $ 273,414           $ 305,269           $ 827,267           $ 919,778           $ 1,419,396           $ 1,582,771     

Construction revenues

     115,091           80,556           189,678           134,798           373,344           288,119     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total operating revenues

     388,505           385,825           1,016,945           1,054,576           1,792,740           1,870,890     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Operating expenses:

                 

Net cost of gas sold

     117,055           147,736           400,861           499,991           637,045           803,126     

Operations and maintenance

     88,708           86,935           179,658           173,640           360,961           351,074     

Depreciation and amortization

     49,415           47,160           98,277           94,856           193,884           188,689     

Taxes other than income taxes

     10,296           9,616           20,165           19,382           39,652           37,085     

Construction expenses

     102,463           70,347           171,081           120,944           327,941           254,176     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total operating expenses

     367,937           361,794           870,042           908,813           1,559,483           1,634,150     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Operating income

     20,568           24,031           146,903           145,763           233,257           236,740     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Other income and (expenses):

                 

Net interest deductions

     (17,355)          (19,003)          (35,314)          (37,178)          (73,813)          (75,074)    

Net interest deductions on subordinated debentures

     -           -           -           (1,912)          -           (5,778)    

Other income (deductions)

     1,551           (5,154)          1,273           (5,677)          10,800           220     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total other income and (expenses)

     (15,804)          (24,157)          (34,041)          (44,767)          (63,013)          (80,632)    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Income (loss) before income taxes

     4,764           (126)          112,862           100,996           170,244           156,108     

Income tax expense

     751           867           40,495           37,529           57,891           54,910     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Net income (loss)

     4,013           (993)          72,367           63,467           112,353           101,198     

Net income (loss) attributable to noncontrolling interest

     (42)          (60)          (237)          (248)          (413)          (612)    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Net income (loss) attributable to Southwest Gas Corporation

     $ 4,055           $ (933)          $ 72,604           $ 63,715           $ 112,766           $ 101,810     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Basic earnings (loss) per share

     $ 0.09           $ (0.02)          $ 1.58           $ 1.41           $ 2.47           $ 2.26     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Diluted earnings (loss) per share

     $ 0.09           $ (0.02)          $ 1.57           $ 1.39           $ 2.45           $ 2.24     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Dividends declared per share

     $ 0.2650           $ 0.2500          $ 0.5300           $ 0.5000           $ 1.0300           $ 0.9750     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Average number of common shares outstanding

     45,864           45,391          45,814           45,306           45,656           45,113     

Average shares outstanding (assuming dilution)

     46,299           -           46,239           45,698           46,091           45,484     

The accompanying notes are an integral part of these statements.

 

   3   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands of dollars)

(Unaudited)

 

000000000000 000000000000 000000000000 000000000000
     SIX MONTHS ENDED
JUNE 30,
     TWELVE MONTHS ENDED
JUNE 30,
 
     2011      2010      2011      2010  

CASH FLOW FROM OPERATING ACTIVITIES:

           

Net income

     $ 72,367           $ 63,467           $ 112,353           $ 101,198     

Adjustments to reconcile net income to net cash provided by operating activities:

           

Depreciation and amortization

     98,277           94,856           193,884           188,689     

Deferred income taxes

     35,166           1,157           84,120           25,382     

Changes in current assets and liabilities:

           

Accounts receivable, net of allowances

     25,740           52,851           (16,994)          938     

Accrued utility revenue

     32,700           40,100           (100)          1,000     

Deferred purchased gas costs

     (24,175)          45,361           (36,523)          53,119     

Accounts payable

     (70,076)          (93,362)          29,966           (2,474)    

Accrued taxes

     9,961           22,278           (27,557)          42,730     

Other current assets and liabilities

     13,542           24,249           2,188           2,771     

Gains on sale

     (1,304)          (557)          (2,294)          (1,938)    

Changes in undistributed stock compensation

     3,660           3,320           4,769           4,414     

AFUDC and property-related changes

     (318)          (486)          (777)          (949)    

Changes in other assets and deferred charges

     (14,269)          4,617           (31,148)          (2,865)    

Changes in other liabilities and deferred credits

     7,015           741           (11,200)          2,951     
  

 

 

    

 

 

    

 

 

    

 

 

 

Net cash provided by operating activities

     188,286           258,592           300,687           414,966     
  

 

 

    

 

 

    

 

 

    

 

 

 

CASH FLOW FROM INVESTING ACTIVITIES:

           

Construction expenditures and property additions

     (139,103)          (94,114)          (260,428)          (194,501)    

Change in restricted cash

     (1)          11,991           (4)          (37,778)    

Changes in customer advances

     (1,815)          366           (3,011)          1,290     

Miscellaneous inflows

     2,617           1,648           5,044           4,990     

Miscellaneous outflows

     (2,719)          (2,800)          (2,719)          (2,934)    
  

 

 

    

 

 

    

 

 

    

 

 

 

Net cash used in investing activities

     (141,021)          (82,909)          (261,118)          (228,933)    
  

 

 

    

 

 

    

 

 

    

 

 

 

CASH FLOW FROM FINANCING ACTIVITIES:

           

Issuance of common stock, net

     4,728           6,461           9,365           13,690     

Dividends paid

     (23,602)          (22,093)          (46,355)          (43,423)    

Interest rate swap settlement

     -           -           (11,691)          -     

Issuance of long-term debt, net

     164,884           -           288,844           49,834     

Retirement of long-term debt

     (223,407)          (656)          (226,078)          (9,599)    

Redemption of subordinated debentures

     -           (100,000)          -           (100,000)    

Change in long-term portion of credit facility

     -           (92,400)          -           (91,000)    
  

 

 

    

 

 

    

 

 

    

 

 

 

Net cash provided by (used in) financing activities

     (77,397)          (208,688)          14,085           (180,498)    
  

 

 

    

 

 

    

 

 

    

 

 

 

Change in cash and cash equivalents

     (30,132)          (33,005)          53,654           5,535     

Cash and cash equivalents at beginning of period

     116,096           65,315           32,310           26,775     
  

 

 

    

 

 

    

 

 

    

 

 

 

Cash and cash equivalents at end of period

     $ 85,964           $ 32,310           $ 85,964           $ 32,310     
  

 

 

    

 

 

    

 

 

    

 

 

 

Supplemental information:

           

Interest paid, net of amounts capitalized

     $ 37,019           $ 37,985           $ 86,034           $ 78,080     

Income taxes paid (received)

     (14,591)          8,167           (3,558)          (14,540)    

The accompanying notes are an integral part of these statements.

 

   4   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Note 1 – Nature of Operations and Basis of Presentation

Nature of Operations. Southwest Gas Corporation and its subsidiaries (the “Company”) are composed of two segments: natural gas operations (“Southwest” or the “natural gas operations” segment) and construction services. Southwest is engaged in the business of purchasing, distributing, and transporting natural gas in portions of Arizona, Nevada, and California. The public utility rates, practices, facilities, and service territories of Southwest are subject to regulatory oversight. The timing and amount of rate relief can materially impact results of operations. Natural gas sales are seasonal, peaking during the winter months; therefore, results of operations for interim periods are not necessarily indicative of results for a full year. Variability in weather from normal temperatures, primarily in Arizona, can materially impact results of operations. Natural gas purchases and the timing of related recoveries can materially impact liquidity. NPL Construction Co. (“NPL” or the “construction services” segment), a wholly owned subsidiary, is a full-service underground piping contractor that provides utility companies with trenching and installation, replacement, and maintenance services for energy distribution systems.

Basis of Presentation. The condensed consolidated financial statements included herein have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). Certain information and footnote disclosures normally included in financial statements prepared in accordance with generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to such rules and regulations. The preparation of the condensed consolidated financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expense during the reporting period. Actual results could differ from those estimates. In the opinion of management, all adjustments, consisting of normal recurring items and estimates necessary for a fair presentation of results for the interim periods, have been made. It is suggested that these condensed consolidated financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the 2010 Annual Report to Shareholders, which is incorporated by reference into the 2010 Form 10-K, and the first quarter 2011 Form 10-Q.

Intercompany Transactions. NPL recognizes revenues generated from contracts with Southwest (see Note 3 below). Accounts receivable for these services are presented in the table below (thousands of dollars):

 

0000000 0000000
         June 30, 2011              December 31, 2010      

Accounts receivable for NPL services

     $ 9,644            $ 8,111      
  

 

 

    

 

 

 

The accounts receivable balance, revenues, and associated profits are included in the condensed consolidated financial statements of the Company and were not eliminated during consolidation in accordance with accounting treatment for rate-regulated entities.

Other Income (Deductions). The following table provides the composition of significant items included in Other income (deductions) on the consolidated statements of income (thousands of dollars):

 

0000000000 0000000000 0000000000 0000000000 0000000000 0000000000
     Three Months Ended      Six Months Ended      Twelve Months Ended  
     June 30      June 30      June 30  
     2011      2010      2011      2010      2011      2010  

Change in COLI policies

     $ 2,600           $ (3,620)          $ 4,800           $ (2,130)          $ 16,700           $ 4,343     

Interest income

     98           57           190           78           306           134     

Pipe replacement costs

     (962)          (1,422)          (1,847)          (2,991)          (3,879)          (4,103)    

Miscellaneous income and (expense)

     (185)          (169)          (1,870)          (634)          (2,327)          (154)    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total other income (deductions)

     $ 1,551           $ (5,154)          $ 1,273           $ (5,677)          $ 10,800         $ 220     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Reflected in the table above is the change in cash surrender values of company-owned life insurance (“COLI”) policies (including net death benefits recognized). These life insurance policies on members of management and other key employees are used by Southwest to indemnify itself against the loss of talent, expertise, and knowledge, as well as to provide indirect funding for certain nonqualified benefit plans. Current tax regulations provide for tax-free treatment of life insurance (death benefit) proceeds. Therefore, the change in the cash surrender value components of COLI policies, as they progress toward the ultimate death benefits, is also recorded without tax consequences.

 

   5   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Reclassifications. A reclassification between two miscellaneous operating cash flow categories was made to the prior year’s financial information to present it on a basis comparable with the current year’s presentation with no impact on net cash provided by operating activities.

Recently Issued Accounting Standards Updates. In May 2011, the Financial Accounting Standards Board (“FASB”) issued the update “Fair Value Measurement (Topic 820) Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRSs.” The amended guidance includes several new fair value disclosure requirements, including, among other things, information about transfers between Level 1 and Level 2 of the fair value hierarchy, enhanced information about valuation techniques and unobservable inputs used in Level 3 fair value measurements, and a narrative description of Level 3 measurements’ sensitivity to changes in unobservable inputs. For the Company, the update is effective prospectively beginning January 2012. The adoption of the update is not expected to significantly impact the disclosures of the Company.

In June 2011, The FASB issued the update “Comprehensive Income (Topic 220) Presentation of Comprehensive Income” which eliminates the current option to report the components of other comprehensive income in the statement of changes in equity. An entity will have the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in one continuous statement of comprehensive income or in two separate but consecutive statements. The update includes no changes to the components that are recognized in net income or other comprehensive income under current U.S. GAAP. The provisions of the update are effective for the Company beginning January 1, 2012 (however, early adoption is permitted). The Company is evaluating the update to determine which presentation option to adopt and the timing of adoption.

 

   6   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Note 2 – Components of Net Periodic Benefit Cost

Southwest has a noncontributory qualified retirement plan with defined benefits covering substantially all employees and a separate unfunded supplemental retirement plan (“SERP”) which is limited to officers. Southwest also provides postretirement benefits other than pensions (“PBOP”) to its qualified retirees for health care, dental, and life insurance.

 

0000 0000 0000 0000 0000 0000
     Qualified Retirement Plan  
     Period Ended June 30,  
     Three Months      Six Months      Twelve Months  
     2011      2010      2011      2010      2011      2010  

(Thousands of dollars)

                 

Service cost

     $ 4,431           $ 4,233           $ 8,862           $ 8,466           $ 17,328           $ 16,161     

Interest cost

     9,319           8,903           18,638           17,807           36,445           35,071     

Expected return on plan assets

     (10,028)          (9,134)          (20,057)          (18,269)          (38,326)          (35,879)    

Amortization of prior service costs (credits)

     -           -           -           -           -           (1)    

Amortization of net loss

     3,587           2,619           7,174           5,239           12,413           7,365     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Net periodic benefit cost

     $ 7,309           $ 6,621           $ 14,617           $ 13,243           $ 27,860           $ 22,717     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 
     SERP  
     Period Ended June 30,  
     Three Months      Six Months      Twelve Months  
     2011      2010      2011      2010      2011      2010  

(Thousands of dollars)

                 

Service cost

     $ 54           $ 93           $ 109           $ 186           $ 295           $ 283     

Interest cost

     442           511           883           1,022           1,906           2,055     

Amortization of net loss

     158           289           315           578           892           1,033     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Net periodic benefit cost

     $ 654           $ 893           $ 1,307           $ 1,786           $ 3,093           $ 3,371     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 
     PBOP  
     Period Ended June 30,  
     Three Months      Six Months      Twelve Months  
     2011      2010      2011      2010      2011      2010  

(Thousands of dollars)

                 

Service cost

     $ 214           $ 214           $ 429           $ 428           $ 857           $ 793     

Interest cost

     658           623           1,316           1,246           2,561           2,431     

Expected return on plan assets

     (595)          (523)          (1,190)          (1,046)          (2,237)          (1,848)    

Amortization of transition obligation

     217           217           433           434           866           867     

Amortization of net loss

     148           122           295           244           540           461     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Net periodic benefit cost

     $ 642           $ 653           $ 1,283           $ 1,306           $ 2,587           $ 2,704     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

 

   7   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Note 3 – Segment Information

The following tables present revenues from external customers, intersegment revenues, and segment net income (thousands of dollars):

 

0000000 0000000 0000000
     Natural Gas
Operations
     Construction
Services
     Total  

Three months ended June 30, 2011

        

Revenues from external customers

     $ 273,414           $ 96,162           $ 369,576     

Intersegment revenues

     -           18,929           18,929     
  

 

 

    

 

 

    

 

 

 

Total

     $ 273,414           $ 115,091           $ 388,505     
  

 

 

    

 

 

    

 

 

 

Segment net income

     $ 199           $ 3,856           $ 4,055     
  

 

 

    

 

 

    

 

 

 

Three months ended June 30, 2010

        

Revenues from external customers

     $ 305,269           $ 65,593           $ 370,862     

Intersegment revenues

     -           14,963           14,963     
  

 

 

    

 

 

    

 

 

 

Total

     $ 305,269           $ 80,556           $ 385,825     
  

 

 

    

 

 

    

 

 

 

Segment net income (loss)

     $ (4,101)          $ 3,168           $ (933)    
  

 

 

    

 

 

    

 

 

 

Six months ended June 30, 2011

        

Revenues from external customers

     $ 827,267           $ 157,939           $ 985,206     

Intersegment revenues

     -           31,739           31,739     
  

 

 

    

 

 

    

 

 

 

Total

     $ 827,267           $ 189,678           $ 1,016,945     
  

 

 

    

 

 

    

 

 

 

Segment net income

     $ 68,214           $ 4,390           $ 72,604     
  

 

 

    

 

 

    

 

 

 

Six months ended June 30, 2010

        

Revenues from external customers

     $ 919,778           $ 107,750           $ 1,027,528     

Intersegment revenues

     -           27,048           27,048     
  

 

 

    

 

 

    

 

 

 

Total

     $ 919,778           $ 134,798           $ 1,054,576     
  

 

 

    

 

 

    

 

 

 

Segment net income

     $ 61,216           $ 2,499           $ 63,715     
  

 

 

    

 

 

    

 

 

 

Twelve months ended June 30, 2011

        

Revenues from external customers

     $ 1,419,396           $ 307,402           $ 1,726,798     

Intersegment revenues

     -           65,942           65,942     
  

 

 

    

 

 

    

 

 

 

Total

     $ 1,419,396           $ 373,344           $ 1,792,740     
  

 

 

    

 

 

    

 

 

 

Segment net income

     $ 98,380           $ 14,386           $ 112,766     
  

 

 

    

 

 

    

 

 

 

Twelve months ended June 30, 2010

        

Revenues from external customers

     $ 1,582,771           $ 235,373           $ 1,818,144     

Intersegment revenues

     -           52,746           52,746     
  

 

 

    

 

 

    

 

 

 

Total

     $ 1,582,771           $ 288,119           $ 1,870,890     
  

 

 

    

 

 

    

 

 

 

Segment net income

     $ 93,520           $ 8,290           $ 101,810     
  

 

 

    

 

 

    

 

 

 

 

   8   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Note 4 – Derivatives and Fair Value Measurements

Derivatives. In managing its natural gas supply portfolios, Southwest has historically entered into fixed- and variable-price contracts, which qualify as derivatives. Additionally, Southwest utilizes fixed-for-floating swap contracts (“Swaps”) to supplement its fixed-price contracts. The fixed-price contracts, firm commitments to purchase a fixed amount of gas in the future at a fixed price, qualify for the normal purchases and normal sales exception that is allowed for contracts that are probable of delivery in the normal course of business and are exempt from fair value reporting. The variable-price contracts have no significant market value. The Swaps are recorded at fair value.

The fixed-price contracts and Swaps are utilized by Southwest under its volatility mitigation programs to effectively fix the price on a portion (historically ranging from 25% to 50%, depending on the jurisdiction) of its natural gas supply portfolios. The maturities of the Swaps highly correlate to forecasted purchases of natural gas, during time frames ranging from July 2011 through October 2012. Under such contracts, Southwest pays the counterparty at a fixed rate and receives from the counterparty a floating rate per MMBtu (“dekatherm”) of natural gas. Only the net differential is actually paid or received. The differential is calculated based on the notional amounts under the contracts, which are detailed in the table below (thousands of dekatherms):

 

000000 000000
         June 30, 2011              December 31, 2010      

Swaps contracts

     14,810           14,207     
  

 

 

    

 

 

 

Southwest does not utilize derivative financial instruments for speculative purposes, nor does it have trading operations.

Gains (losses) recognized in income for derivatives not designated as hedging instruments:

(Thousands of dollars)

 

          Three Months Ended     Six Months Ended     Twelve Months Ended  
      Location of Gain or (Loss)    June 30     June 30     June 30  

Instrument

   Recognized in Income on Derivative    2011     2010     2011     2010     2011     2010  

Swaps

   Net cost of gas sold      $ (2,258)         $ (1,626)         $ (1,969)         $ (17,968)         $ (11,691)         $ (15,076)    

Swaps

   Net cost of gas sold      2,258       1,626       1,969       17,968       11,691       15,076  
     

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total

        $ -          $ -          $ -          $        $        $ -     
     

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 
*

Represents the impact of regulatory deferral accounting treatment under U.S. GAAP for rate-regulated entities.

In January 2010, Southwest entered into two forward-starting interest rate swaps (“FSIRS”) to hedge the risk of interest rate variability during the period leading up to the planned issuance of fixed-rate debt to replace $200 million of debt that matured in February 2011 and $200 million maturing in May 2012. The counterparties to each agreement are four major banking institutions. The first FSIRS was a designated cash flow hedge and terminated in December 2010 concurrent with the related issuance of $125 million 4.45% 10-year Senior Notes. The terms of the second FSIRS are as follows:

 

Notional amount

   $100 million

Fixed rate to be paid by Southwest

   4.78%

Mandatory termination date (on or before)

   March 20, 2012

Southwest previously designated the second FSIRS agreement as a cash flow hedge of forecasted future interest payments. At the inception of the hedge, the terms of the derivative were the same as a perfect hypothetical derivative; thus, there is an expectation that there will be no ineffectiveness, and that the effective portion of unrealized gains and losses on the FSIRS leading up to the forecasted debt issuance will be reported as a component of other comprehensive income. At termination, the final value will be reclassified from accumulated other comprehensive income into earnings over the same period the hedged forecasted transaction affects earnings. However, should conditions occur that indicate the existence of ineffectiveness (e.g., deterioration of counterparty creditworthiness, delay in the forecasted debt issuance, etc.), Southwest will measure ineffectiveness by comparing the change in fair value of the FSIRS with the change in fair value of a hypothetical swap (the hypothetical derivative method). Gains and losses due to ineffectiveness will be recognized immediately in earnings. At June 30, 2011, the remaining FSIRS continued to qualify as an effective hedge. There was no gain or loss reclassified from accumulated other comprehensive income (“AOCI”) into income (effective portion) and no gain or loss recognized in income (ineffective portion) for the Company’s remaining derivative designated as a hedging instrument. See Note 6 – Equity, Comprehensive Income, and Accumulated Other Comprehensive Income for additional information on both FSIRS contracts.

 

   9   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

00000000 00000000 00000000 00000000 00000000 00000000
Gains (losses) recognized in other comprehensive income for derivatives designated as cash flow hedging instruments:  
(Thousands of dollars)                                          
     Three Months Ended      Six Months Ended      Twelve Months Ended  
     June 30, 2011      June 30, 2010      June 30, 2011      June 30, 2010      June 30, 2011      June 30, 2010  

Amount of gain (loss) on unrealized FSIRS recognized in other comprehensive income on derivative (effective portion)

     $ (3,816)          $ (20,272)          $ (3,145)          $ (21,259)          $ 11,359          $ (21,259)    

Amount of loss on realized FSIRS recognized in other comprehensive income on derivative

     -           -           -           -           (11,691)          -     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 
     $ (3,816)          $ (20,272)          $ (3,145)          $ (21,259)          $ (332)          $ (21,259)    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

The following table sets forth the fair values of the Company’s Swaps and FSIRS and their location in the balance sheets (thousands of dollars):

 

00000000 00000000 00000000 00000000
Fair values of derivatives not designated as hedging instruments:         

June 30, 2011

Instrument

  

Balance Sheet Location

   Asset
Derivatives
     Liability
Derivatives
     Net Total  
           

Swaps

   Deferred charges and other assets      $ 225           $ (1)        $ 224     

Swaps

   Other current liabilities      308           (5,134)          (4,826)    

Swaps

   Other deferred credits      -           (19)          (19)    
     

 

 

    

 

 

    

 

 

 

Total

        $ 533           $ (5,154)          $ (4,621)    
     

 

 

    

 

 

    

 

 

 

December 31, 2010

Instrument

  

Balance Sheet Location

   Asset
Derivatives
     Liability
Derivatives
     Net Total  
           

Swaps

   Deferred charges and other assets      $ 656         $ -           $ 656     

Swaps

   Other current liabilities      65           (11,547)          (11,482)    
     

 

 

    

 

 

    

 

 

 

Total

        $ 721           $ (11,547)          $ (10,826)    
     

 

 

    

 

 

    

 

 

 
Fair values of derivatives designated as hedging instruments:  

June 30, 2011

Instrument

  

Balance Sheet Location

   Asset
Derivatives
     Liability
Derivatives
     Net Total  

FSIRS

   Other current liabilities      $ -           $ (9,900)          $ (9,900)    
     

 

 

    

 

 

    

 

 

 

December 31, 2010

Instrument

  

Balance Sheet Location

   Asset
Derivatives
     Liability
Derivatives
     Net Total  

FSIRS

   Other deferred credits      $ -           $ (6,755)          $ (6,755)    
     

 

 

    

 

 

    

 

 

 

The estimated fair values of the natural gas derivatives were determined using future natural gas index prices (as more fully described below). The Company has master netting arrangements with each counterparty that provide for the net settlement of all contracts through a single payment. As applicable, the Company has elected to reflect the net amounts in its balance sheets.

Pursuant to regulatory deferral accounting treatment for rate-regulated entities, Southwest records the unrealized gains and losses in fair value of the Swaps as a regulatory asset and/or liability. When the Swaps settle, Southwest reverses any prior positions held and records the settled position as an increase or decrease in purchased gas under the related purchased gas adjustment (“PGA”) mechanism in determining its deferred PGA balances. Neither changes in fair value, nor settled amounts, of Swaps have a direct effect on earnings or other comprehensive income.

 

   10   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

The following table shows the amounts Southwest paid to and received from counterparties for settlements of matured Swaps.

 

0000000000 0000000000 0000000000
(Thousands of dollars)    Three Months Ended
June 30, 2011
     Six Months Ended
June 30, 2011
     Twelve Months Ended
June 30, 2011
 

Paid to counterparties

     $ 4,194           $ 8,173           $ 17,460     
  

 

 

    

 

 

    

 

 

 

No amounts were received from counterparties for settlements of matured Swaps for the three months, six months, and twelve months ended June 30, 2011.

The following table details the regulatory assets/(liabilities) offsetting the amounts in the balance sheets (thousands of dollars).

 

June 30, 2011

Instrument

  

Balance Sheet Location

   Net Total  

Swaps

   Other deferred credits      $ (224)    

Swaps

   Prepaids and other current assets      4,826     

Swaps

   Deferred charges and other assets      19     

December 31, 2010

Instrument

  

Balance Sheet Location

   Net Total  

Swaps

   Other deferred credits      $ (656)    

Swaps

   Prepaids and other current assets      11,482     

Fair Value Measurements. The estimated fair values of Southwest’s Swaps were determined at June 30, 2011 and December 31, 2010 using NYMEX futures settlement prices for delivery of natural gas at Henry Hub adjusted by the price of NYMEX ClearPort basis Swaps, which reflect the difference between the price of natural gas at a given delivery basin and the Henry Hub pricing points. These Level 2 inputs are observable in the marketplace throughout the full term of the Swaps, but have been credit-risk adjusted with no significant impact to the overall fair value measure.

The estimated fair values of Southwest’s FSIRS were determined using a discounted cash flow model that utilizes forward interest rate curves. The inputs to the model are the terms of the FSIRS. These Level 2 inputs are observable in the marketplace throughout the full term of the FSIRS, but have been credit-risk adjusted with no significant impact to the overall fair value measure.

The following table sets forth, by level within the three-level fair value hierarchy that ranks the inputs used to measure fair value by their reliability, the Company’s financial assets and liabilities that were accounted for at fair value:

Level 2 - Significant other observable inputs

 

0000000000 0000000000
(Thousands of dollars)    June 30, 2011      December 31, 2010  

Assets at fair value:

     

Deferred charges and other assets - Swaps

     $ 224           $ 656     

Liabilities at fair value:

     

Other current liabilities - Swaps

     (4,826)          (11,482)    

Other deferred credits - Swaps

     (19)          -     

Other current liabilities - FSIRS

     (9,900)          -     

Other deferred credits - FSIRS

     -           (6,755)    
  

 

 

    

 

 

 

Net Assets (Liabilities)

     $ (14,521)          $ (17,581)    
  

 

 

    

 

 

 

No financial assets or liabilities accounted for at fair value fell within Level 1 or Level 3 of the fair value hierarchy.

 

   11   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Related Tax Effects of Designated Hedging Activities Allocated to Each Component of Other Comprehensive Income

 

0000000000 0000000000 0000000000 0000000000 0000000000 0000000000
     Three Months Ended
June 30,
 
     2011     2010  
     Before-
Tax
Amount
    Tax
(Expense)
or Benefit (1)
    Net-of-
Tax
Amount
    Before-
Tax
Amount
    Tax
(Expense)
or Benefit (1)
     Net-of-
Tax
Amount
 
(Thousands of dollars)                                      

FSIRS:

             

Realized/unrealized gain (loss)

     $ (3,816)         $ 1,450          $ (2,366)         $ (20,272)         $ 7,703           $ (12,569)    

Amounts reclassified into net income

     293          (111)         182          -          -           -     
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

    

 

 

 

Other comprehensive income (loss)

     $ (3,523 )       $ 1,339          $ (2,184 )       $ (20,272 )       $ 7,703           $ (12,569 )  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

    

 

 

 
     Six Months Ended
June 30,
 
     2011     2010  
     Before-
Tax
Amount
    Tax
(Expense)
or Benefit (1)
    Net-of-
Tax
Amount
    Before-
Tax
Amount
    Tax
(Expense)
or Benefit (1)
     Net-of-
Tax
Amount
 
(Thousands of dollars)                                      

FSIRS:

             

Realized/unrealized gain (loss)

     $ (3,145)         $ 1,195          $ (1,950)         $ (21,259)         $ 8,078         $ (13,181)    

Amounts reclassified into net income

     585          (222)         363          -          -           -     
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

    

 

 

 

Other comprehensive income (loss)

     $ (2,560 )       $ 973         $ (1,587 )       $ (21,259 )       $ 8,078          $ (13,181 )  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

    

 

 

 
     Twelve Months Ended
June 30,
 
     2011     2010  
     Before-
Tax
Amount
    Tax
(Expense)
or Benefit (1)
    Net-of-
Tax
Amount
    Before-
Tax
Amount
    Tax
(Expense)
or Benefit (1)
     Net-of-
Tax
Amount
 
(Thousands of dollars)                                      

FSIRS:

             

Realized/unrealized gain (loss)

     $ (332)         $ 127          $ (205)         $ (21,259)         $ 8,078           $ (13,181)    

Amounts reclassified into net income

     682          (259)         423          -          -           -     
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

    

 

 

 

Other comprehensive income (loss)

     $ 350          $ (132 )       $ 218          $ (21,259 )       $ 8,078           $ (13,181 )  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

    

 

 

 

(1)   Tax amounts are calculated using a 38% rate.

 

   12   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Note 5 – Long-Term Debt

Carrying amounts of the Company’s long-term debt and their related estimated fair values as of June 30, 2011 and December 31, 2010 are disclosed in the following table. The fair values of the revolving credit facility and the variable-rate Industrial Development Revenue Bonds (“IDRBs”) approximate carrying value. Market values for the debentures, fixed-rate IDRBs, and other indebtedness were determined based on dealer quotes using trading records for June 30, 2011 and December 31, 2010, as applicable, and other secondary sources which are customarily consulted for data of this kind.

 

00000000 00000000 00000000 00000000
     June 30, 2011      December 31, 2010  
     Carrying
Amount
     Market
Value
     Carrying
Amount
     Market
Value
 
(Thousands of dollars)                            

Debentures:

           

Notes, 8.375%, due 2011

     $ -           $ -           $ 200,000           $ 201,560     

Notes, 7.625%, due 2012

     200,000           210,994           200,000           214,666     

Notes, 4.45%, due 2020

     125,000           121,551           125,000           125,325     

Notes, 6.1%, due 2041

     125,000           121,996           -           -     

8% Series, due 2026

     75,000           90,967           75,000           99,968     

Medium-term notes, 7.59% series, due 2017

     25,000           29,819           25,000           30,295     

Medium-term notes, 7.78% series, due 2022

     25,000           30,330           25,000           32,063     

Medium-term notes, 7.92% series, due 2027

     25,000           29,892           25,000           33,211     

Medium-term notes, 6.76% series, due 2027

     7,500           7,999           7,500           8,956     

Unamortized discount

     (2,293)             (2,534)       
  

 

 

       

 

 

    
     605,207              679,966        
  

 

 

       

 

 

    

Revolving credit facility and commercial paper, due 2012

     -           -           -           -     
  

 

 

       

 

 

    

Industrial development revenue bonds:

           

Variable-rate bonds:

           

Tax-exempt Series A, due 2028

     50,000           50,000           50,000           50,000     

2003 Series A, due 2038

     50,000           50,000           50,000           50,000     

2008 Series A, due 2038

     50,000           50,000           50,000           50,000     

2009 Series A, due 2039

     50,000           50,000           50,000           50,000     

Fixed-rate bonds:

           

6.10% 1999 Series A, due 2038

     12,410           12,265           12,410           11,968     

5.95% 1999 Series C, due 2038

     14,320           13,998           14,320           13,594     

5.55% 1999 Series D, due 2038

     8,270           7,754           8,270           7,468     

5.45% 2003 Series C, due 2038 (rate resets in 2013)

     30,000           31,703           30,000           31,547     

5.25% 2003 Series D, due 2038

     20,000           18,175           20,000           17,474     

5.80% 2003 Series E, due 2038 (rate resets in 2013)

     15,000           15,180           15,000           15,436     

5.25% 2004 Series A, due 2034

     65,000           60,375           65,000           58,574     

5.00% 2004 Series B, due 2033

     31,200           28,198           31,200           27,295     

4.85% 2005 Series A, due 2035

     100,000           87,299           100,000           84,485     

4.75% 2006 Series A, due 2036

     24,855           21,243           24,855           20,518     

Unamortized discount

     (3,431)             (3,502)       
  

 

 

       

 

 

    
     517,624              517,553        
  

 

 

       

 

 

    

Other

     18,720           18,720           2,242           2,473     
  

 

 

       

 

 

    
     1,141,551              1,199,761        

Less: current maturities

     (200,000)             (75,080)       
  

 

 

       

 

 

    

Long-term debt, less current maturities

     $ 941,551              $ 1,124,681        
  

 

 

       

 

 

    

 

   13   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Note 6 – Equity, Comprehensive Income, and Accumulated Other Comprehensive Income

The table below provides details of activity in equity during the six months ended June 30, 2011.

 

00000000 00000000 00000000 00000000 00000000 00000000 00000000
     Southwest Gas Corporation Equity         
     Common Stock      Additional
Paid-in
Capital
     Accumulated
Other
Comprehensive
Income (Loss)
     Retained
Earnings
     Non-
controlling
Interest
     Total  
                 
                 

(In thousands, except per share amounts)

   Shares      Amount                 

DECEMBER 31, 2010

       45,599           $ 47,229           $ 807,885           $ (30,784)          $ 343,131           $ (465)          $ 1,166,996     

Common stock issuances

     280           280           8,403                    8,683     

Net income (loss)

                 72,604           (237)          72,367     

Other comprehensive income (loss):

                    

Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax

              640                 640     

FSIRS unrealized loss, net of tax

              (1,950)                (1,950)    

Amounts reclassified to net income, net of tax (Note 4)

              363                 363     

Dividends declared

                    

Common: $0.53 per share

                 (24,656)             (24,656)    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

JUNE 30, 2011

       45,879           $ 47,509           $ 816,288           $ (31,731)           $ 391,079           $ (702)          $ 1,222,443     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

The tables below provide details of comprehensive income and year-to-date activity in AOCI. See Note 4 – Derivatives and Fair Value Measurements for additional information on the FSIRS, including reclassifications into net income.

 

00000000 00000000 00000000 00000000 00000000 00000000
Comprehensive Income                     
(Thousands of dollars)    Three Months Ended      Six Months Ended      Twelve Months Ended  
     June 30,      June 30,      June 30,  
     2011      2010      2011      2010      2011      2010  

Net income (loss)

     $ 4,013           $ (993)          $ 72,367           $ 63,467           $ 112,353           $ 101,198     

Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax

     320           342           640           683           2,799           (2,554)    

FSIRS realized and unrealized gains (losses), net of tax

     (2,366)          (12,569)          (1,950)          (13,181)          (205)          (13,181)    

Amounts reclassifed into net income, net of tax

     182           -            363           -            423           -      
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Comprehensive income (loss)

     2,149           (13,220)          71,420           50,969           115,370           85,463     

Comprehensive loss attributable to noncontrolling interest

     (42)          (60)          (237)          (248)          (413)          (612)    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Comprehensive income (loss) attributable to Southwest Gas Corporation

     $ 2,191           $ (13,160)          $ 71,657           $ 51,217           $ 115,783           $ 86,075     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Tax (expense) benefit associated with net actuarial gain (loss) arising during period

     $ (196)          $ (209)          $ (392)          $ (419)          $ (1,714)          $ 1,567     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Tax benefit associated with FSIRS realized and unrealized gain (loss) recognized in other comprehensive income

     $ 1,450           $ 7,703           $ 1,195           $ 8,078           $ 127           $ 8,078     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Tax (expense) benefit associated with FSIRS reclassified out of AOCI to net income

     $ (111)          $ -            $ (222)          $ -            $ (259)          $ -      
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

AOCI - Rollforward

(Thousands of dollars)

 

000000000 000000000 000000000 000000000 000000000 000000000 000000000
     Defined Benefit Plans     FSIRS        
     Before-
Tax
     Tax
(Expense)
Benefit
     After-
Tax
    Before -
Tax
     Tax
(Expense)
Benefit
     After -Tax     AOCI  

Beginning Balance AOCI December 31, 2010

     $ (31,304)          $ 11,896           $ (19,408)         $ (18,349)          $ 6,973           $ (11,376)         $ (30,784)    

Current period change

     1,032           (392)          640       (2,560)          973           (1,587)  **      (947)    
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

 

Ending Balance AOCI June 30, 2011

     $ (30,272)         $ 11,504           $ (18,768)         $ (20,909)          $ 7,946           $ (12,963)         $ (31,731)    
  

 

 

    

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

 

 

*

Net actuarial gain (loss), less amortization of unamortized benefit plan cost

**

FSIRS unrealized loss of $1,950,000 recognized in other comprehensive income less the portion of the previous FSIRS realized loss that was reclassified to net income in the current period ($363,000).

Approximately $904,000 of realized/unrealized losses (net of tax) related to the FSIRS reported in AOCI at June 30, 2011 will be reclassified into expense within the next 12 months as the related interest payments on long-term debt occur.

 

   14   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

ITEM 2.         MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Southwest Gas Corporation and its subsidiaries (the “Company”) consist of two business segments: natural gas operations (“Southwest” or the “natural gas operations” segment) and construction services.

Southwest is engaged in the business of purchasing, distributing, and transporting natural gas in portions of Arizona, Nevada, and California. Southwest is the largest distributor in Arizona, selling and transporting natural gas in most of central and southern Arizona, including the Phoenix and Tucson metropolitan areas. Southwest is also the largest distributor of natural gas in Nevada, serving the Las Vegas metropolitan area and northern Nevada. In addition, Southwest distributes and transports natural gas in portions of California, including the Lake Tahoe area and the high desert and mountain areas in San Bernardino County.

On a seasonally adjusted basis as of June 30, 2011, Southwest had 1,839,000 residential, commercial, industrial, and other natural gas customers, of which 990,000 customers were located in Arizona, 667,000 in Nevada, and 182,000 in California. Residential and commercial customers represented over 99% of the total customer base. During the twelve months ended June 30, 2011, 54% of operating margin was earned in Arizona, 35% in Nevada, and 11% in California. During this same period, Southwest earned 86% of its operating margin from residential and small commercial customers, 4% from other sales customers, and 10% from transportation customers. These general patterns are expected to remain materially consistent for the foreseeable future.

Southwest recognizes operating revenues from the distribution and transportation of natural gas (and related services) to customers. Operating margin is the measure of gas operating revenues less the net cost of gas sold. Management uses operating margin as a main benchmark in comparing operating results from period to period. The principal factors affecting operating margin are general rate relief, weather, conservation and efficiencies, and customer growth. Of these, weather is the primary reason for volatility in margin. Variances in temperatures from normal levels, primarily in Arizona, can have a significant impact on the margin and associated net income of the Company. See also Rates and Regulatory Proceedings. A decoupled rate structure designed to mitigate the impacts of weather variability and conservation on margin is utilized in the Nevada service territories. Weather impacts and conservation are also offset by the margin tracking mechanism in Southwest’s California service territories.

NPL Construction Co. (“NPL” or the “construction services” segment), a wholly owned subsidiary, is a full-service underground piping contractor that provides utility companies with trenching and installation, replacement, and maintenance services for energy distribution systems. NPL operates in 18 major markets nationwide. Construction activity is cyclical and can be significantly impacted by changes in general and local economic conditions, including the housing market, interest rates, employment levels, job growth, the equipment resale market, pipe replacement programs of utilities, and local and federal tax rates. Generally, revenues and profits are lowest during the first quarter of the year due to less favorable winter weather conditions. Operating results typically improve as more favorable weather conditions occur during the summer and fall months.

This Management’s Discussion and Analysis (“MD&A”) of Financial Condition and Results of Operations should be read in conjunction with the consolidated financial statements and the notes thereto, as well as the MD&A, included in the 2010 Annual Report to Shareholders, which is incorporated by reference into the 2010 Form 10-K, and the first quarter 2011 Form 10-Q.

 

   15   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Executive Summary

The items discussed in this Executive Summary are intended to provide an overview of the results of the Company’s operations. As needed, certain items are covered in greater detail in later sections of management’s discussion and analysis. As reflected in the table below, the natural gas operations segment accounted for an average of 89% of twelve-month-to-date consolidated net income over the past two years. As such, management’s discussion and analysis is primarily focused on that segment. Natural gas sales are seasonal, peaking during the winter months; therefore, results of operations for interim periods are not necessarily indicative of the results for a full year.

Summary Operating Results

 

0000000000 0000000000 0000000000 0000000000 0000000000 0000000000
     Period Ended June 30,  
     Three Months      Six Months      Twelve Months  
     2011      2010      2011      2010      2011      2010  
     (In thousands, except per share amounts)  

Contribution to net income (loss)

                 

Natural gas operations

     $ 199           $ (4,101)          $ 68,214           $ 61,216           $ 98,380           $ 93,520     

Construction services

     3,856           3,168           4,390           2,499           14,386           8,290     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Net income (loss)

     $ 4,055           $ (933)          $ 72,604           $ 63,715           $ 112,766           $ 101,810     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Average number of common shares outstanding

     45,864           45,391           45,814           45,306           45,656           45,113     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Basic earnings (loss) per share

                 

Consolidated

     $ 0.09           $ (0.02)          $ 1.58           $ 1.41           $ 2.47           $ 2.26     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Natural Gas Operations

                 

Operating margin

     $ 156,359           $ 157,533           $ 426,406           $ 419,787           $ 782,351           $ 779,645     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Consolidated results for the second quarter of 2011 improved compared to the same period in 2010. The improvement primarily resulted from an increase in other income and lower financing costs, partially offset by decreased gas segment operating margin and increased operating costs.

2nd Quarter 2011 Overview

Natural gas operations highlights include the following:

   

Other income increased $6.7 million compared to the same period in 2010 primarily due to increases in the cash surrender values of the Company’s COLI policies (including net death benefits) in the current period while the prior-year period experienced a negative swing in the cash surrender values of the policies

   

Operating margin decreased approximately $1 million compared to the prior-year quarter primarily due to minor weather variations between periods

   

Net financing costs declined $1.7 million between quarters

   

Standard & Poors upgraded the Company’s credit rating from BBB to BBB+ in April 2011

   

Fitch upgraded the Company’s credit rating from BBB to BBB+ in June 2011

   

Liquidity position remains strong

Construction services highlights include the following:

   

Revenues increased 43% compared to the prior-year quarter

   

Contribution to consolidated net income improved $688,000 between quarters

 

   16   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Company-Owned Life Insurance (“COLI”). Southwest has life insurance policies on members of management and other key employees to indemnify itself against the loss of talent, expertise, and knowledge, as well as to provide indirect funding for certain nonqualified benefit plans. The COLI policies have a combined net death benefit value of approximately $213 million at June 30, 2011. The net cash surrender value of these policies (which is the cash amount the Company would receive if it voluntarily terminated the policies) is approximately $77 million at June 30, 2011 and is included in the caption “Other property and investments” on the balance sheet. Cash surrender values are directly influenced by the investment portfolio underlying the insurance policies. This portfolio includes both equity and fixed income (mutual fund) investments. As a result, generally the cash surrender value (but not the net death benefit) moves up and down consistent with movements in the broader stock and bond markets. During the twelve months ended June 30, 2011, the cash surrender values of COLI policies grew by $11.2 million primarily due to the significant increases in the stock investments underlying the policies. Both the Dow Jones Industrial Average and S&P 500 indices increased over 25% during the same period. In addition to the market-related increase of $11.2 million, Southwest also recognized $5.5 million in incremental death benefits in excess of the cash surrender values. Management believes these COLI returns are significantly in excess of currently expected average returns of $2 million to $4 million annually. Based on the current investment mix, both positive and negative deviations from expected levels are likely to continue.

Weather. The rate structures in each of Southwest’s three states provide varying levels of protection from risks that drive operating margin volatility, particularly weather risk and conservation efforts. Southwest’s exposure to these risks on operating margin is largely limited to its Arizona operating areas as both Nevada and California operations are now under decoupled rate structures. Weather was not a significant factor in either the second quarter of 2010 or 2011.

Arizona Rate Proceedings. In December 2010, the Arizona Corporation Commission (“ACC”) issued a Policy Statement which allowed utilities to file proposals for alternative mechanisms, including revenue-per-customer decoupling, in general rate case filings, to address the financial disincentives to utilities of promoting energy efficiency. In anticipation of the Policy Statement, the Company’s recent Arizona rate case filing requested a rate structure to decouple recovery of the Company’s fixed costs from fluctuations in usage, both higher and lower, to enable the Company to aggressively advocate increased energy efficiency by its customers by eliminating the existing financial disincentive. A settlement agreement containing provisions to mitigate the impacts on operating margin of weather and conservation was filed with the ACC in July 2011. For more information see the Rates and Regulatory Proceedings discussion.

Customer Growth. Southwest added 14,000 net new customers over the last twelve months which approximates the number of first time meter sets. Southwest continues to project net customer growth of 1% or less for 2011.

Credit Rating Upgrades. In April 2011, Standard & Poor’s Ratings Services (“S&P”) upgraded the Company’s unsecured long-term debt ratings from BBB (with a positive outlook) to BBB+ (with a stable outlook). S&P cited the Company’s improved financial results and stable financial metrics. S&P debt ratings range from AAA (highest rating possible) to D (obligation is in default). The S&P rating of BBB+ indicates the issuer of the debt is regarded as having an adequate capacity to pay interest and repay principal.

In June 2011, Fitch Ratings (“Fitch”) upgraded the Company’s long-term issuer default rating and its senior unsecured rating to BBB+ from BBB; the outlook has been revised to stable from positive. Fitch debt ratings range from AAA (highest credit quality) to D (defaulted debt obligation). The Fitch rating of BBB+ indicates a credit quality that is considered prudent for investment.

Liquidity. Southwest believes its liquidity position remains strong. Southwest has a $300 million credit facility maturing in May 2012. The facility is provided through a consortium of eight major banking institutions. The facility was not used during the first half of 2011 and there was no balance outstanding at June 30, 2011, leaving the entire $300 million available for borrowing. The lack of usage was primarily due to existing cash reserves and natural gas prices that were relatively stable. The current slowdown in housing construction has also allowed Southwest to fund construction expenditures primarily with internally generated cash. Management believes the Company currently has a solid liquidity position and will be able to replenish such borrowing capacity.

 

   17   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Results of Natural Gas Operations

Quarterly Analysis

 

0000000000 0000000000
     Three Months Ended
June 30,
 
  
     2011      2010  
     (Thousands of dollars)  

Gas operating revenues

     $ 273,414           $ 305,269     

Net cost of gas sold

     117,055           147,736     
  

 

 

    

 

 

 

Operating margin

     156,359           157,533     

Operations and maintenance expense

     88,708           86,935     

Depreciation and amortization

     43,476           42,146     

Taxes other than income taxes

     10,296           9,616     
  

 

 

    

 

 

 

Operating income

     13,879           18,836     

Other income (deductions)

     1,525           (5,176)    

Net interest deductions

     17,153           18,862     
  

 

 

    

 

 

 

Income (loss) before income taxes

     (1,749)          (5,202)    

Income tax expense (benefit)

     (1,948)          (1,101)    
  

 

 

    

 

 

 

Contribution to consolidated net income (loss)

     $ 199           $ (4,101)    
  

 

 

    

 

 

 

Contribution to consolidated net income from natural gas operations improved by $4.3 million in the second quarter of 2011 compared to the same period a year ago. The improvement was primarily due to an increase in other income and a decrease in financing costs, partially offset by a decrease in operating margin and higher operating expenses.

Operating margin decreased $1 million in the second quarter of 2011 compared to the second quarter of 2010. Weather changes between quarters accounted for a $2 million margin decrease as warmer-than-normal temperatures were experienced in the current quarter. Rate relief in California and customer growth combined for a $1 million increase in operating margin, partially offsetting the weather impact. Approximately 14,000 net new customers were added during the last twelve months.

Operations and maintenance expense increased $1.8 million, or 2%, between quarters primarily due to general cost increases, partially offset by lower uncollectible expenses.

Depreciation expense increased $1.3 million, or 3%, as a result of additional plant in service. Average gas plant in service for the current period increased $134 million, or 3%, compared to the corresponding period a year ago.

Taxes other than income taxes increased $680,000 primarily due to a change in Arizona property tax rates recognized in the current quarter, but retroactive to January 2011.

Other income increased $6.7 million between periods. This was primarily due to increases in the cash surrender values (including recognized net death benefits) of COLI policies. The current quarter includes $2.7 million in other income associated with net death benefits recognized. The prior year included a $3.6 million decrease in COLI cash surrender values.

Net financing costs decreased $1.7 million between periods primarily due to cost savings from refinancing and reduced interest rates associated with variable-rate debt.

 

   18   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Six-Month Analysis

 

0000000000 0000000000
     Six Months Ended
June 30,
 
  
     2011      2010  
     (Thousands of dollars)  

Gas operating revenues

     $ 827,267           $ 919,778     

Net cost of gas sold

     400,861           499,991     
  

 

 

    

 

 

 

Operating margin

     426,406           419,787     

Operations and maintenance expense

     179,658           173,640     

Depreciation and amortization

     87,357           84,842     

Taxes other than income taxes

     20,165           19,382     
  

 

 

    

 

 

 

Operating income

     139,226           141,923     

Other income (deductions)

     1,289           (5,707)    

Net interest deductions

     34,981           36,886     

Net interest deductions on subordinated debentures

     -           1,912     
  

 

 

    

 

 

 

Income before income taxes

     105,534           97,418     

Income tax expense

     37,320           36,202     
  

 

 

    

 

 

 

Contribution to consolidated net income

     $ 68,214           $ 61,216     
  

 

 

    

 

 

 

Contribution to consolidated net income from natural gas operations increased by $7 million in the first six months of 2011 compared to the same period a year ago. The improvement was primarily due to an increase in other income, an increase in operating margin, and a decrease in financing costs, partially offset by higher operating expenses.

Operating margin increased $7 million between periods. Differences in heating demand, caused primarily by weather variations, provided $4 million of the operating margin increase. Unusually cold weather in Arizona in early February 2011 resulted in $6 million of incremental operating margin, but was partially offset by a $2 million decrease in the second quarter due to warmer-than-normal weather. Temperatures for the first six months of 2010, on average, were relatively normal. Rate relief in California provided $2 million of the operating margin increase and new customers contributed an additional $1 million.

Operations and maintenance expense increased $6 million, or 3%, between periods primarily due to general cost increases (including higher employee-related costs) and approximately $1 million of costs associated with restoring service to approximately 20,000 Arizona customers in early February 2011, following an outage due to extreme weather conditions.

Depreciation expense increased $2.5 million, or 3%, as a result of additional plant in service. Average gas plant in service for the current period increased $141 million, or 3%, compared to the corresponding period a year ago.

The $783,000 increase in taxes other than income taxes is primarily due to higher property tax rates in Arizona.

Other income, which principally includes returns on COLI policies and non-utility expenses, increased $7 million between the six-month periods of 2011 and 2010. The current period includes $2.1 million of COLI cash surrender value increases and $2.7 million of recognized net death benefits in excess of the cash surrender value. The prior-year period includes a decrease in COLI cash surrender values of $2.1 million.

Net financing costs decreased $3.8 million between periods primarily due to the redemption of $100 million of Subordinated Debentures in March 2010, cost savings from debt refinancing, and reduced interest rates associated with variable-rate debt.

 

   19   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

0000000000 0000000000
Twelve-Month Analysis       
     Twelve Months Ended
June 30,
 
  
     2011      2010  
     (Thousands of dollars)  

Gas operating revenues

     $ 1,419,396           $ 1,582,771     

Net cost of gas sold

     637,045           803,126     
  

 

 

    

 

 

 

Operating margin

     782,351           779,645     

Operations and maintenance expense

     360,961           351,074     

Depreciation and amortization

     172,971           167,480     

Taxes other than income taxes

     39,652           37,085     
  

 

 

    

 

 

 

Operating income

     208,767           224,006     

Other income (deductions)

     11,012           246     

Net interest deductions

     73,208           74,264     

Net interest deductions on subordinated debentures

     -           5,778     
  

 

 

    

 

 

 

Income before income taxes

     146,571           144,210     

Income tax expense

     48,191           50,690     
  

 

 

    

 

 

 

Contribution to consolidated net income

     $ 98,380           $ 93,520     
  

 

 

    

 

 

 

Contribution to consolidated net income from natural gas operations increased by $4.9 million in the current twelve-month period as compared to the corresponding period a year ago. The improvement was primarily due to an increase in other income, an increase in operating margin, and a decrease in financing costs, partially offset by higher operating expenses.

Operating margin increased $3 million between periods. Rate relief provided $6 million of the operating margin increase, consisting of $3 million in Nevada and $3 million in California. Customer growth contributed $2 million in operating margin. Differences in heating demand caused primarily by weather variations between periods resulted in a decrease of $5 million.

Operations and maintenance expense increased $9.9 million, or 3%, primarily due to higher general costs and employee-related benefit costs including pension expense. The increases were mitigated by cost containment efforts (including lower staffing levels) and a decrease in uncollectible expense, partially due to the impact of a tracking mechanism in Nevada for the gas-cost portion of uncollectible accounts.

Depreciation expense increased $5.5 million, or 3%, as a result of additional plant in service. Average gas plant in service for the current period increased $134 million, or 3%, compared to the corresponding period a year ago. This was attributable to reinforcement work, franchise requirements, routine pipe replacement activities and new business.

Other income, which principally includes returns on COLI policies and non-utility expenses, increased $10.8 million between the twelve-month periods of 2011 and 2010. The current period includes $11.2 million of COLI cash surrender value increases and $5.5 million in recognized net death benefits in excess of the related cash surrender values, compared to $4.3 million of cash surrender value increases in the prior-year period. Both periods reflect above average returns on investments underlying the policies.

Net financing costs decreased $6.8 million between the twelve-month periods of 2011 and 2010 primarily due to the redemption of the Subordinated Debentures in March 2010, cost savings from debt refinancing, and reduced interest rates associated with variable-rate debt.

 

   20   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Results of Construction Services

Quarter. Contribution to consolidated net income from construction services for the three months ended June 30, 2011 increased $688,000 compared to the same period of 2010.

Revenues increased $34.5 million, a 43% improvement, when compared to the same period of 2010. Revenue from replacement construction continues to be strong while revenue related to new construction remains at low levels, Gains on sale of equipment were $419,000 and $324,000 for the second quarters of 2011 and 2010, respectively.

Six Months-to-Date. Contribution to consolidated net income from construction services for the six months ended June 30, 2011 increased $1.9 million compared to the same period of 2010.

Revenues increased $54.9 million, a 41% improvement, when compared to the same period of 2010 primarily due to increased replacement construction. Construction expenses increased $50.1 million due to the increase in replacement construction work. Depreciation expense increased $907,000 between the current period and the prior-year period due to an increase in equipment purchases. Gains on sale of equipment were $1.3 million and $557,000 for the first six months of 2011 and 2010, respectively.

Twelve Months-to-Date. The contribution to consolidated net income from construction services for the twelve-month period ended June 30, 2011 increased $6.1 million compared to the same period of 2010.

Revenues increased $85.2 million due primarily to an increase in the volume of replacement work. Construction expenses increased $73.8 million between the twelve-month periods due primarily to costs associated with the increase in replacement construction work, while depreciation expense declined $293,000 due to the timing of equipment purchases. Gains on sale of equipment were $2.3 million and $1.9 million for the twelve-month periods of 2011 and 2010, respectively.

NPL’s revenues and operating profits are influenced by weather, customer requirements, mix of work, local economic conditions, bidding results, the equipment resale market, and the credit market. Typically, revenues and profit are lowest during the first quarter of the year due to unfavorable winter weather conditions. Operating results typically improve as more favorable weather conditions occur during the summer and fall months. Current low interest rates, the impact of bonus deprecation legislation, and the regulatory environment (encouraging the natural gas industry to replace aging pipeline infrastructure), are having a positive influence on NPL’s growth and resulting earnings.

Rates and Regulatory Proceedings

Arizona Energy Efficiency and Decoupling Proceeding. In August 2010, the ACC issued a Notice of Proposed Rulemaking on Gas Energy Efficiency, which adopted an energy efficiency requirement for Arizona’s gas utilities, including Southwest, to achieve cumulative annual energy savings of 6% by December 2020. In October 2010, the Chairman of the ACC issued a draft Policy Statement, which would allow utilities to file proposals for alternative mechanisms including revenue-per-customer decoupling, in connection with a general rate case to address the financial disincentives to utilities of promoting energy efficiency. The Policy Statement was approved by the ACC in December 2010.

Arizona General Rate Case. Southwest filed a general rate application with the ACC in November 2010 requesting an increase in authorized annual operating revenues of $73.2 million, or 9.26%, to reflect increased operating costs, investments in infrastructure, and costs of capital, as well as margin attrition due to decreased average usage by customers. The application requested an overall rate of return of 9.73% on original cost rate base of $1.074 billion, an 11% return on common equity, and a capital structure utilizing 52% common equity.

The rate case filing also requested a rate structure to decouple recovery of the Company’s fixed costs from natural gas usage and enable the Company to aggressively advocate for increased energy efficiency by its customers. The filed structure anticipated the approval of the Policy Statement discussed in the Arizona Energy Efficiency and Decoupling Proceeding section above. The proposed mechanism, referred to as the Energy Efficiency Enabling Provision (“EEEP”), is a revenue-per-customer decoupling mechanism designed to eliminate the link between volumetric sales and revenues that currently exists with traditional rate designs, such that

 

   21   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

the existing financial disincentive associated with the Company’s pursuit of cost-effective energy efficiency is eliminated. This will allow management to focus on customers and to concentrate its attention on the cost of providing service. The pursuit of increased energy efficiency by customers is supported by the requested approval of a detailed energy efficiency and renewable energy resource plan.

After several weeks of negotiations, a majority of the parties agreed to a settlement, which was filed with the ACC in July 2011. In addition to Southwest, parties supporting the settlement include the ACC Staff, the Arizona Community Action Association, the Arizona Investment Council, the Natural Resources Defense Council, and the Southwest Energy Efficiency Project. The Residential Utility Consumer Office and Tucson Electric Power Company are not parties to the agreement. Two options were presented in the settlement; one providing for partial decoupling (Alternative A) and one with a full decoupling provision (Alternative B). Alternative A would include a $54.9 million revenue increase, or 6.95%, with a 9.75% return on common equity. Rate design improvements would include adoption of a weather normalization provision along with a “lost fixed-cost recovery mechanism” which would hold the Company financially harmless from reduced sales associated with conservation and energy efficiency programs. Alternative B would include a $52.6 million revenue increase, or 6.66%, with a 9.5% return on common equity. This option would allow for monthly weather normalization and an annual true-up for any non-weather margin variances from authorized amounts per customer. If approved, Alternative B would also require a rate case moratorium, preventing Southwest from filing a general rate case prior to April 2016. Hearings on the proposed settlement are scheduled for August and a decision from the ACC is expected by the end of the year. The settlement recommends that new rates be placed in effect by January 2012. Management cannot predict whether either settlement alternative will be approved by the ACC or the timing of rate relief.

PGA Filings

The rate schedules in all of Southwest’s service territories contain provisions that permit adjustments to rates as the cost of purchased gas changes. These deferred energy provisions and purchased gas adjustment clauses are collectively referred to as “PGA” clauses. Differences between gas costs recovered from customers and amounts paid for gas by Southwest result in over- or under-collections. At June 30, 2011, over-collections in all service territories resulted in a liability of $98.8 million on the Company’s balance sheet. Filings to change rates in accordance with PGA clauses are subject to audit by state regulatory commission staffs. PGA changes impact cash flows but have no direct impact on profit margin. However, gas cost deferrals and recoveries can impact comparisons between periods of individual income statement components. These include Gas operating revenues, Net cost of gas sold, Net interest deductions, and Other income (deductions).

As of June 30, 2011, December 31, 2010, and June 30, 2010, Southwest had the following outstanding PGA balances receivable/(payable) (millions of dollars):

 

000000 000000 000000
         June 30, 2011              December 31, 2010              June 30, 2010      

Arizona

     $ (35.3)          $ (45.2)          $ (43.7)    

Northern Nevada

     (14.8)          (8.4)          (13.6)    

Southern Nevada

     (46.7)          (69.8)          (71.6)    

California

     (2.0)          0.4           (6.4)    
  

 

 

    

 

 

    

 

 

 
     $ (98.8)          $ (123.0)          $ (135.3)    
  

 

 

    

 

 

    

 

 

 

Nevada Annual Rate Adjustment (“ARA”) Application. In June 2011, Southwest filed its ARA application with the Public Utilities Commission of Nevada (“PUCN”) to establish revised Deferred Energy Account Adjustment (“DEAA”) rates (in addition to adjustments to the Variable Interest Expense Recovery, the Uncollectible Gas Cost Expense rates, and other rate-related items). Recently approved legislation will allow Southwest to make quarterly DEAA adjustments based upon a twelve-month rolling average. Southwest filed its first quarterly DEAA rate adjustment application under the new rules in July 2011.

 

   22   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

Capital Resources and Liquidity

Cash on hand and cash flows from operations have generally been sufficient over the past two years to provide for net investing activities (primarily construction expenditures and property additions). During the past two years, the Company has been able to use cash inflows to reduce the net amount of debt outstanding. The Company’s capitalization strategy is to maintain an appropriate balance of equity and debt.

To facilitate future financings, the Company has a universal shelf registration statement providing for the issuance and sale of registered securities from time to time, which may consist of secured debt, unsecured debt, preferred stock, or common stock. The number and dollar amount of securities issued under the universal shelf registration statement, which was filed with the SEC and automatically declared effective in December 2008, will be determined at the time of the offerings, if any, and presented in the applicable prospectuses.

Cash Flows

Operating Cash Flows. Cash flows provided by consolidated operating activities decreased $70.3 million in the first six months of 2011 as compared to the same period in 2010. The primary drivers of the change were temporary fluctuations in working capital components partially offset by an increase in net income between periods.

Investing Cash Flows. Net cash used in consolidated investing activities increased $58.1 million in the first six months of 2011 as compared to the same period in 2010. The increase was primarily due to additional construction expenditures, including routine and accelerated pipe replacement (to take advantage of bonus depreciation tax incentives), and equipment purchases by NPL due to increased replacement construction work of its customers. In addition, 2010 included a draw-down of funds, restricted for construction activities, associated with an industrial development revenue bond issuance in 2009. Similar draw-downs to fund construction did not occur in 2011.

Financing Cash Flows. Net cash used in consolidated financing activities decreased $131.3 million during the first six months of 2011 as compared to the same period in 2010 primarily due to the issuance of new debt ($125 million 6.1% Senior Notes), partially offset by debt repayments including the $200 million 8.375% Notes repaid in February 2011. The prior-year period included the redemption of the subordinated debentures as well as the repayment of other debt, primarily repayment of previous borrowings under Southwest’s credit facility. Dividends paid increased in the first half of 2011 as compared to 2010 as a result of a quarterly dividend increase and an increase in the number of shares outstanding.

The capital requirements and resources of the Company generally are determined independently for the natural gas operations and construction services segments. Each business activity is generally responsible for securing its own financing sources. The capital requirements and resources of the construction services segment are not material to the overall capital requirements and resources of the Company.

Gas Segment Construction Expenditures, Debt Maturities, and Financing

During the twelve-month period ended June 30, 2011, construction expenditures for the natural gas operations segment were $202 million. The majority of these expenditures represented costs associated with routine and accelerated replacement of existing transmission, distribution, and general plant (see also Bonus Depreciation below). Cash flows from operating activities of Southwest were $265 million which provided sufficient funding for construction expenditures and dividend requirements of the natural gas operations segment.

Southwest estimates natural gas segment construction expenditures during the three-year period ending December 31, 2013 will be approximately $680 million (including $110 million of accelerated expenditures). During the three-year period, cash flows from operating activities of Southwest (including bonus depreciation benefits) are expected to provide approximately 80% of the gas operations total construction expenditures and dividend requirements. During the three-year period, the Company expects to raise approximately $15 million from its various common stock programs. Any cash requirements not met by operating activities are expected to be provided by cash on hand, existing credit facilities and/or other external financing sources. The timing, types, and amounts of these additional external financings will be dependent on a number of factors, including conditions in the capital markets, timing and amounts of rate relief, growth levels in Southwest’s service areas, and earnings. These external financings may include the issuance of both debt and equity securities, bank and other short-term borrowings, and other forms of financing.

 

   23   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

In December 2010, the Company issued $125 million in 4.45% Senior Notes, due December 2020 at a discount of 0.182%. A portion of the net proceeds was used to pay down borrowings under the credit facility. In February 2011, the Company used approximately $75 million of the remaining net proceeds in connection with its repayment of the 8.375% $200 million Notes that matured in February 2011. The remaining proceeds were used for general corporate purposes.

In February 2011, the Company issued $125 million of 6.1% Senior Notes to certain institutional investors pursuant to a November 2010 note purchase agreement. The Senior Notes are unsecured and unsubordinated obligations of the Company, due in February 2041. Funds from the issuance were used to partially repay the 8.375% $200 million Notes that matured in February 2011.

Southwest also has $200 million of long-term debt maturing in May 2012 and plans to fund that obligation by issuing $200 million of debentures by the maturity date. In connection with the planned 2012 debt issuance, the Company, in January 2010, entered into a forward-starting interest rate swap (“FSIRS”) agreement to partially hedge the risk of interest rate variability during the period leading up to the planned issuance. See Note 4 – Derivatives and Fair Value Measurements for more information on the FSIRS.

During the six months ended June 30, 2011, the Company issued shares of common stock through the Stock Incentive Plan, raising approximately $5 million.

Bonus Depreciation. As a result of two tax acts signed into law in 2010, a bonus depreciation tax deduction of 100% is available for qualified property acquired or constructed and placed in service from September 9, 2010 through December 31, 2011 and 50% bonus tax depreciation is available for qualified property acquired or constructed and placed in service from January 1, 2012 through December 31, 2012. Based on forecasted qualifying construction expenditures, Southwest estimates the bonus depreciation provisions of the two acts will defer the payment of approximately $55 million and $25 million of federal income taxes during 2011 and 2012, respectively.

Dividend Policy

The Company has a common stock dividend policy which states that common stock dividends will be paid at a prudent level that is within the normal dividend payout range for its respective businesses, and that the dividend will be established at a level considered sustainable in order to minimize business risk and maintain a strong capital structure throughout all economic cycles. In February 2011, the Board of Directors increased the quarterly dividend payout from 25 cents to 26.5 cents per share, effective with the June 2011 payment.

Liquidity

Liquidity refers to the ability of an enterprise to generate sufficient amounts of cash through its operating activities and external financing to meet its cash requirements. Several general factors (some of which are out of the control of the Company) that could significantly affect liquidity in future years include: variability of natural gas prices, changes in the ratemaking policies of regulatory commissions, regulatory lag, customer growth in the natural gas segment’s service territories, Southwest’s ability to access and obtain capital from external sources, interest rates, changes in income tax laws, pension funding requirements, inflation, and the level of Company earnings. Natural gas prices and related gas cost recovery rates have historically had the most significant impact on Company liquidity.

On an interim basis, Southwest generally defers over- or under-collections of gas costs to PGA balancing accounts. In addition, Southwest uses this mechanism to either refund amounts over-collected or recoup amounts under-collected as compared to the price paid for natural gas during the period since the last PGA rate change went into effect. At June 30, 2011, the combined balance in the PGA accounts totaled an over-collection of $98.8 million. See PGA Filings for more information on recent regulatory filings.

The Company has a $300 million credit facility that expires in May 2012. Southwest previously designated $150 million of the $300 million facility as long-term debt and the remaining $150 million for working capital purposes. At June 30, 2011, no borrowings were outstanding on the credit facility and the Company had $86 million of cash on hand. The facility was not used during the first six months of 2011. The credit facility can be used as necessary to meet liquidity requirements, including temporarily financing under-collected PGA balances, if any, or meeting the refund needs of over-collected balances. This credit facility has been, and is expected to continue to be, adequate for Southwest’s working capital needs outside of funds raised through operations and other types of external financing prior to its expiration. Management believes the Company currently has a solid liquidity position and will be able to replenish such borrowing capacity.

 

   24   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

The following table sets forth the ratios of earnings to fixed charges for the Company. Due to the seasonal nature of the Company’s business, these ratios are computed on a twelve-month basis:

 

0000 0000
             For the Twelve Months Ended           
     June 30,
2011
     December 31,
2010
 

Ratio of earnings to fixed charges

     3.09         2.87   

Earnings are defined as the sum of pretax income plus fixed charges. Fixed charges consist of all interest expense including capitalized interest, one-third of rent expense (which approximates the interest component of such expense), and net amortized debt costs.

Forward-Looking Statements

This quarterly report contains statements which constitute “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995 (“Reform Act”). All statements other than statements of historical fact included or incorporated by reference in this quarterly report are forward-looking statements, including, without limitation, statements regarding the Company’s plans, objectives, goals, projections, strategies, future events or performance, and underlying assumptions. The words “may,” “will,” “should,” “could,” “expect,” “plan,” “anticipate,” “believe,” “estimate,” “predict,” “continue,” “forecast,” and similar words and expressions are generally used and intended to identify forward-looking statements. For example, statements regarding operating margin patterns, customer growth, the composition of our customer base, price volatility, seasonal patterns, the Company’s COLI strategy, annual COLI returns, amount and timing for completion of estimated future construction expenditures, forecasted operating cash flows and results of operations, funding sources of cash requirements, sufficiency of working capital, bank lending practices, the Company’s views regarding its liquidity position, ability to raise funds and receive external financing capacity, the amount and form of any such financing, plans to fund maturing obligations, the effectiveness of the forward-starting interest rate swap agreement in hedging against changing interest rates, liquidity, certain benefits of tax acts, statements regarding future gas prices, gas purchase contracts and derivative financial interests, the impact of certain legal proceedings, and the timing and results of future rate hearings and approvals (including the form of approved rate mechanisms) are forward-looking statements. All forward-looking statements are intended to be subject to the safe harbor protection provided by the Reform Act.

A number of important factors affecting the business and financial results of the Company could cause actual results to differ materially from those stated in the forward-looking statements. These factors include, but are not limited to, the impact of weather variations on customer usage, customer growth rates, conditions in the housing market, the ability to recover costs through PGA mechanisms, the effects of regulation/deregulation, the timing and amount of rate relief, changes in rate design, changes in gas procurement practices, changes in capital requirements and funding, the impact of conditions in the capital markets on financing costs, changes in construction expenditures and financing, renewal of franchises, easements and rights-of-way, changes in operations and maintenance expenses, effects of pension expense forecasts, accounting changes, future liability claims, changes in pipeline capacity for the transportation of gas and related costs, acquisitions and management’s plans related thereto, competition, and the ability to raise capital in external financings. In addition, the Company can provide no assurance that its discussions regarding certain trends relating to its financing and operations and maintenance expenses will continue in future periods. For additional information on the risks associated with the Company’s business, see Item 1A. Risk Factors and Item 7A. Quantitative and Qualitative Disclosures About Market Risk in the Company’s Annual Report on Form 10-K for the year ended December 31, 2010.

All forward-looking statements in this quarterly report are made as of the date hereof, based on information available to the Company as of the date hereof, and the Company assumes no obligation to update or revise any of its forward-looking statements even if experience or future changes show that the indicated results or events will not be realized. We caution you not to unduly rely on any forward-looking statement(s).

 

   25   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

ITEM 3.        QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

See Item 7A. Quantitative and Qualitative Disclosures about Market Risk in the Company’s 2010 Annual Report on Form 10-K filed with the SEC. No material changes have occurred related to the Company’s disclosures about market risk.

ITEM 4.        CONTROLS AND PROCEDURES

The Company has established disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) that are designed to provide reasonable assurance that information required to be disclosed in reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms and to provide reasonable assurance that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosures. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and benefits of controls must be considered relative to their costs. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or management override of the control. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and may not be detected.

Based on the most recent evaluation, as of June 30, 2011, management of the Company, including the Chief Executive Officer and Chief Financial Officer, believe the Company’s disclosure controls and procedures are effective at attaining the level of reasonable assurance noted above.

There have been no changes in the Company’s internal controls over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act) during the second quarter of 2011 that have materially affected, or are likely to materially affect, the Company’s internal controls over financial reporting.

PART II - OTHER INFORMATION

ITEM 1.        LEGAL PROCEEDINGS

The Company is named as a defendant in various legal proceedings. The ultimate dispositions of these proceedings are not presently determinable; however, it is the opinion of management that none of this litigation individually or in the aggregate will have a material adverse impact on the Company’s financial position or results of operations.

ITEMS 1A. through 3.    None.

ITEM 4.        [REMOVED AND RESERVED]

ITEM 5.        OTHER INFORMATION        None.

ITEM 6.        EXHIBITS

The following documents are filed, or furnished, as applicable, as part of this report on Form 10-Q:

 

Exhibit 3(ii)   -   Amended Bylaws of Southwest Gas Corporation.
Exhibit 12.01   -   Computation of Ratios of Earnings to Fixed Charges.
Exhibit 31.01   -   Section 302 Certifications.
Exhibit 32.01   -   Section 906 Certifications.
Exhibit 101   -  

The following materials from the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2011, formatted in Extensible Business Reporting Language (“XBRL”): (i) the Condensed Consolidated Balance Sheets, (ii) the Condensed Consolidated Statements of Income, (iii) the Condensed Consolidated Statements of Cash Flows, and (iv) the Notes to the Condensed Consolidated Financial Statements.

 

   26   


SOUTHWEST GAS CORPORATION

   Form 10-Q

June 30, 2011

  

 

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

 

 

Southwest Gas Corporation

(Registrant)

Date: August 8, 2011

 
 

/s/ Gregory J. Peterson

  Gregory J. Peterson
  Vice President/Controller and Chief Accounting Officer

 

   27