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EX-31.2 - EX-31.2 - Pike Corp | c15945exv31w2.htm |
EX-31.1 - EX-31.1 - Pike Corp | c15945exv31w1.htm |
EX-32.1 - EX-32.1 - Pike Corp | c15945exv32w1.htm |
Table of Contents
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
þ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2011
OR
o | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
COMMISSION FILE NUMBER 001-32582
PIKE ELECTRIC CORPORATION
(Exact name of registrant as specified in its charter)
Delaware (State or other jurisdiction of incorporation) |
20-3112047 (I.R.S. Employer Identification No.) |
100 Pike Way, PO Box 868, Mount Airy, NC 27030
(Address of principal executive offices)
(336) 789-2171
(Registrants telephone number, including area code)
(Address of principal executive offices)
(336) 789-2171
(Registrants telephone number, including area code)
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 þ No o
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
o No o
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 and smaller reporting company in Rule 12b-2 of the
Exchange Act. (Check one):
Large accelerated filer o | Accelerated filer þ | Non-accelerated filer o (Do not check if smaller reporting company) | Smaller reporting company o |
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of
the Exchange Act). Yes o No þ
As of April 29, 2011, there were 33,651,559 shares of our Common Stock, par value $0.001 per
share, outstanding.
PIKE ELECTRIC CORPORATION
FORM 10-Q
FOR THE THREE AND NINE MONTHS ENDED MARCH 31, 2011
INDEX
FORM 10-Q
FOR THE THREE AND NINE MONTHS ENDED MARCH 31, 2011
INDEX
Table of Contents
PART I FINANCIAL INFORMATION
Item 1. | Financial Statements |
PIKE ELECTRIC CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except per share amounts)
March 31, | June 30, | |||||||
2011 | 2010 | |||||||
(Unaudited) | ||||||||
ASSETS |
||||||||
Current assets: |
||||||||
Cash and cash equivalents |
$ | 11,851 | $ | 11,133 | ||||
Accounts receivable from customers, net |
69,374 | 64,672 | ||||||
Costs and estimated earnings in excess of billings on uncompleted contracts |
51,005 | 50,215 | ||||||
Inventories |
9,734 | 6,401 | ||||||
Prepaid expenses and other |
14,230 | 9,115 | ||||||
Deferred income taxes |
8,044 | 10,526 | ||||||
Total current assets |
164,238 | 152,062 | ||||||
Property and equipment, net |
178,599 | 194,885 | ||||||
Goodwill |
110,893 | 114,778 | ||||||
Other intangibles, net |
39,484 | 38,527 | ||||||
Deferred loan costs, net |
2,484 | 3,021 | ||||||
Other assets |
1,847 | 2,105 | ||||||
Total assets |
$ | 497,545 | $ | 505,378 | ||||
LIABILITIES AND STOCKHOLDERS EQUITY |
||||||||
Current liabilities: |
||||||||
Accounts payable |
$ | 27,926 | $ | 17,484 | ||||
Accrued compensation |
20,683 | 22,589 | ||||||
Billings in excess of costs and estimated earnings on uncompleted contracts |
11,372 | 8,925 | ||||||
Accrued expenses and other |
12,041 | 6,112 | ||||||
Current portion of insurance and claim accruals |
17,028 | 23,422 | ||||||
Total current liabilities |
89,050 | 78,532 | ||||||
Long-term debt |
99,000 | 114,500 | ||||||
Insurance and claim accruals, net of current portion |
6,487 | 6,005 | ||||||
Deferred compensation, net of current portion |
6,065 | 5,844 | ||||||
Deferred income taxes |
43,537 | 48,170 | ||||||
Other liabilities |
2,247 | 2,859 | ||||||
Commitments and contingencies |
||||||||
Stockholders equity: |
||||||||
Preferred stock, par value $0.001 per share; 100,000 authorized shares; no
shares issued and outstanding |
| | ||||||
Common stock, par value $0.001 per share; 100,000 authorized shares; 33,651
and 33,544 shares issued and outstanding at March 31, 2011 and
June 30, 2010, respectively |
6,427 | 6,427 | ||||||
Additional paid-in capital |
160,416 | 158,030 | ||||||
Accumulated other comprehensive loss, net of taxes |
(188 | ) | (142 | ) | ||||
Retained earnings |
84,504 | 85,153 | ||||||
Total stockholders equity |
251,159 | 249,468 | ||||||
Total liabilities and stockholders equity |
$ | 497,545 | $ | 505,378 | ||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
1
Table of Contents
PIKE ELECTRIC CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
(In thousands, except per share amounts)
Three Months Ended | Nine Months Ended | |||||||||||||||
March 31, | March 31, | |||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
Revenues |
$ | 153,825 | $ | 120,931 | $ | 431,146 | $ | 383,349 | ||||||||
Cost of operations |
137,416 | 110,500 | 386,377 | 344,287 | ||||||||||||
Gross profit |
16,409 | 10,431 | 44,769 | 39,062 | ||||||||||||
General and administrative expenses |
13,810 | 12,007 | 40,114 | 38,261 | ||||||||||||
Loss on sale and impairment of
property
and equipment |
39 | 240 | 588 | 1,202 | ||||||||||||
Restructuring expenses |
| 59 | | 8,983 | ||||||||||||
Income (loss) from operations |
2,560 | (1,875 | ) | 4,067 | (9,384 | ) | ||||||||||
Other expense (income): |
||||||||||||||||
Interest expense |
1,620 | 1,441 | 5,094 | 6,085 | ||||||||||||
Other, net |
(22 | ) | (49 | ) | (38 | ) | (229 | ) | ||||||||
Total other expense |
1,598 | 1,392 | 5,056 | 5,856 | ||||||||||||
Income (loss) before income taxes |
962 | (3,267 | ) | (989 | ) | (15,240 | ) | |||||||||
Income tax expense (benefit) |
342 | (1,236 | ) | (340 | ) | (5,802 | ) | |||||||||
Net income (loss) |
$ | 620 | $ | (2,031 | ) | $ | (649 | ) | $ | (9,438 | ) | |||||
Earnings (loss) per share: |
||||||||||||||||
Basic |
$ | 0.02 | $ | (0.06 | ) | $ | (0.02 | ) | $ | (0.28 | ) | |||||
Diluted |
$ | 0.02 | $ | (0.06 | ) | $ | (0.02 | ) | $ | (0.28 | ) | |||||
Shares used in computing
earnings (loss) per share: |
||||||||||||||||
Basic |
33,446 | 33,149 | 33,368 | 33,119 | ||||||||||||
Diluted |
34,062 | 33,149 | 33,368 | 33,119 | ||||||||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
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Table of Contents
PIKE ELECTRIC CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
(In thousands)
Nine Months Ended | ||||||||
March 31, | ||||||||
2011 | 2010 | |||||||
Cash flows from operating activities: |
||||||||
Net loss |
$ | (649 | ) | $ | (9,438 | ) | ||
Adjustments to reconcile net loss to net cash provided by
operating activities: |
||||||||
Depreciation and amortization |
28,598 | 26,860 | ||||||
Non-cash interest expense |
1,749 | 1,415 | ||||||
Deferred income taxes |
(3,347 | ) | (6,573 | ) | ||||
Loss on sale and impairment of property and equipment |
588 | 1,202 | ||||||
Restructuring expenses, non-cash |
| 7,958 | ||||||
Equity compensation expense |
2,991 | 3,514 | ||||||
Excess tax (benefit) expense from stock-based compensation |
(79 | ) | 43 | |||||
Changes in operating assets and liabilities: |
||||||||
Accounts receivable |
(4,702 | ) | (4,087 | ) | ||||
Costs and estimated earnings in excess of billings on
uncompleted contracts |
(790 | ) | 1,486 | |||||
Inventories, prepaid expenses and other |
(7,257 | ) | 2,452 | |||||
Insurance and claim accruals |
(5,912 | ) | (2,403 | ) | ||||
Accounts payable and other |
15,692 | (2,623 | ) | |||||
Deferred compensation |
| (1,402 | ) | |||||
Net cash provided by operating activities |
26,882 | 18,404 | ||||||
Cash flows from investing activities: |
||||||||
Purchases of property and equipment |
(11,206 | ) | (13,628 | ) | ||||
Business acquisitions, net |
| | ||||||
Net proceeds from sale of property and equipment |
1,616 | 5,840 | ||||||
Net cash used in investing activities |
(9,590 | ) | (7,788 | ) | ||||
Cash flows from financing activities: |
||||||||
Principal payments on long-term debt |
(15,500 | ) | | |||||
Stock option and employee stock purchase activity, net |
(162 | ) | 82 | |||||
Excess tax benefit (expense) from stock-based compensation |
79 | (43 | ) | |||||
Deferred loan costs |
(991 | ) | (2,792 | ) | ||||
Net cash used in financing activities |
(16,574 | ) | (2,753 | ) | ||||
Net increase in cash and cash equivalents |
718 | 7,863 | ||||||
Cash and cash equivalents beginning of year |
11,133 | 43,820 | ||||||
Cash and cash equivalents end of period |
$ | 11,851 | $ | 51,683 | ||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
3
Table of Contents
PIKE ELECTRIC CORPORATION
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
For the three and nine months ended March 31, 2011 and 2010
(In thousands, except per share amounts)
1. Basis of Presentation
The accompanying condensed consolidated financial statements of Pike Electric Corporation and
its wholly-owned subsidiaries (Pike, we, us, and our) are unaudited and have been prepared
in accordance with United States generally accepted accounting principles (U.S. GAAP) for interim
financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X.
Accordingly, they do not include all of the information and footnotes required by U.S. GAAP for
complete financial statements. In the opinion of management, the unaudited consolidated financial
statements included herein contain all adjustments necessary to present fairly our financial
position, results of operations and cash flows for the periods indicated. Such adjustments, other
than nonrecurring adjustments that have been separately disclosed, are of a normal, recurring
nature. We recorded an approximately $2,000 reduction of costs and estimated earnings in excess of
billings on uncompleted contracts during the quarter ended September 30, 2010 that relates to prior
periods, the impact of which is not material to any individual prior period or our expected annual
results for fiscal 2011. The operating results for interim periods are not necessarily indicative
of results to be expected for a full year or future interim periods. The balance sheet at June 30,
2010 has been derived from our audited financial statements but does not include all of the
information and footnotes required by U.S. GAAP for complete financial statements. Certain amounts
reported previously have been reclassified to conform to the current year presentation. These
financial statements should be read in conjunction with our financial statements and related notes
included in our report on Form 10-K for the year ended June 30, 2010.
2. Business
We are one of the largest providers of energy solutions for investor-owned, municipal and
co-operative utilities in the United States. Since our founding in 1945, we have evolved from a
specialty non-unionized contractor focused on the electric distribution sector in the southeastern
United States to a leading turnkey energy solutions provider throughout the United States with
diverse capabilities servicing over 200 private and municipal electric utilities. Our
comprehensive suite of energy solutions now includes siting, permitting, engineering, designing,
planning, constructing, maintaining and repairing power delivery systems, including renewable
energy projects. We currently operate our business as one reportable segment.
During our first quarter of fiscal 2011, we, along with a joint service provider, were awarded
approximately $84,000 in distribution overhead powerline projects in Tanzania. These projects will
utilize our engineering, procurement and construction capabilities and represent our first
international work. We anticipate work will begin during the fourth quarter of fiscal 2011. This
project is expected to continue through the second quarter of fiscal 2013. We continue to explore
other international opportunities.
We monitor revenue by two categories of services: core and storm restoration. We use this
breakdown because core services represent ongoing service revenues, most of which are generated by
our customers recurring maintenance needs, and storm restoration revenues represent additional
revenue opportunities that depend on weather conditions.
4
Table of Contents
The table below sets forth our revenues by category of service for the periods indicated:
Three Months Ended | Nine Months Ended | |||||||||||||||||||||||||||||||
March 31, | March 31, | |||||||||||||||||||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||||||||||||||||||
Core services |
$ | 137,702 | 89.5 | % | $ | 98,643 | 81.6 | % | $ | 407,314 | 94.5 | % | $ | 340,587 | 88.8 | % | ||||||||||||||||
Storm restoration
services |
16,123 | 10.5 | % | 22,288 | 18.4 | % | 23,832 | 5.5 | % | 42,762 | 11.2 | % | ||||||||||||||||||||
Total |
$ | 153,825 | 100.0 | % | $ | 120,931 | 100.0 | % | $ | 431,146 | 100.0 | % | $ | 383,349 | 100.0 | % | ||||||||||||||||
3. Acquisition Activity
On June 30, 2010, we acquired Klondyke Construction LLC (Klondyke) based in Phoenix, AZ, for
a price of $17,000 ($15,157 net of cash acquired), plus the assumption of certain operating
liabilities. Klondyke provides substation and transmission construction and maintenance services.
Klondyke also constructs renewable energy generation facilities and provides civil related
services. Klondykes range of construction services complements our west coast engineering
capabilities and enables the continued expansion of turnkey EPC (engineering, procurement and
construction) services.
We completed our analysis of the valuation of the acquired assets and liabilities of Klondyke
during the quarter ended December 31, 2010. The purchase price of $17,000 has been allocated to
the assets acquired and liabilities assumed at the effective date of the acquisition based on
estimated fair values as follows: $6,023 of tangible net assets and $6,300 in identifiable
intangible assets, resulting in goodwill of approximately $4,677. All changes in goodwill for the
nine months ended March 31, 2011 are related to purchase price allocation adjustments for Klondyke.
The goodwill recognized is attributable primarily to expected synergies and the assembled
workforce, and is expected to be amortizable for tax purposes.
The financial results of the operations of Klondyke have been included in our consolidated
financial statements since the date of the acquisition. The following unaudited pro forma
statement of income data gives effect to the acquisition of Klondyke as if it had occurred on July
1, 2009. The pro forma results are not necessarily indicative of what actually would have occurred
had the acquisition been in effect for the periods presented.
Three months ended | Nine months ended | |||||||
March 31, 2010 | March 31, 2010 | |||||||
Revenues |
$ | 126,502 | $ | 408,792 | ||||
Net loss |
$ | (2,591 | ) | $ | (8,838 | ) | ||
Basic loss per common share |
$ | (0.08 | ) | $ | (0.27 | ) | ||
Diluted loss per common share |
$ | (0.08 | ) | $ | (0.27 | ) | ||
4. Assets Held For Sale
Amounts reported as loss on sale and impairment of property and equipment relate primarily to
aging, damaged or excess fleet equipment. Assets held for sale are recorded at the lower of
carrying value or fair value, less selling costs. Fair value for this purpose is generally
determined based on prices in the used equipment market. Assets held for sale totaled $603 and
$898 at March 31, 2011 and June 30, 2010, respectively, and are included in prepaid expenses and
other in the condensed consolidated balance sheets. Substantially all of the assets held for sale
at March 31, 2011 are expected to be sold in the next twelve months.
5
Table of Contents
5. Derivative Instruments and Hedging Activities
All derivative instruments are recorded on the consolidated balance sheets at their respective
fair values. Changes in fair value are recognized either in income (loss) or other comprehensive
income (loss) (OCI), depending on whether the transaction qualifies for hedge accounting and, if
so, the nature of the underlying exposure being hedged and how effective the derivatives are at
offsetting price movements in the underlying exposure. The effective portions recorded in OCI are
recognized in the statement of operations when the hedged item affects earnings.
We have used certain derivative instruments to enhance our ability to manage risk relating to
diesel fuel and interest rate exposure. Derivative instruments are not entered into for trading or
speculative purposes. We document all relationships between derivative instruments and related
items, as well as our risk-management objectives and strategies for undertaking various derivative
transactions.
Interest Rate Risk
We are exposed to market risk related to changes in interest rates on borrowings under our
senior credit facility, which bears interest based on LIBOR, plus an applicable margin dependent
upon our total leverage ratio. We use derivative financial instruments to manage exposure to
fluctuations in interest rates on our senior credit facility.
Effective December 2007, we entered into two interest rate swap agreements (the 2007 Swaps)
with a total notional amount of $100,000 to help manage a portion of our interest risk related to
our floating-rate debt interest risk. The 2007 Swaps expired in December 2009. Under the 2007
Swaps, we paid a fixed rate of 3.99% and received a rate equivalent to the thirty-day LIBOR,
adjusted monthly. The 2007 Swaps qualified for hedge accounting and were designated as cash flow
hedges. There was no hedge ineffectiveness for the 2007 Swaps for the nine months ended March 31,
2010. The 2007 Swaps expired in December 2009.
Effective May 2010, we entered into an interest rate swap agreement (the May 2010 Swap) with
a notional amount of $20,000 to help manage a portion of our interest risk related to our
floating-rate debt interest risk. The May 2010 Swap will expire in May 2012. Under the May 2010
Swap, we pay a fixed rate of 1.1375% and receive a rate equivalent to the thirty-day LIBOR,
adjusted monthly. The May 2010 Swap qualified for hedge accounting and was designated as a cash
flow hedge. There was no hedge ineffectiveness for the May 2010 Swap for the three and nine months
ended March 31, 2011.
Effective June 2010, we entered into an interest rate swap agreement (the June 2010 Swap)
with a notional amount of $20,000 to help manage an additional portion of our interest risk related
to our floating-rate debt interest risk. The June 2010 Swap will expire in June 2012. Under the
June 2010 Swap, we pay a fixed rate of 1.0525% and receive a rate equivalent to the thirty-day
LIBOR, adjusted monthly. The June 2010 Swap qualified for hedge accounting and was designated as a
cash flow hedge. There was no hedge ineffectiveness for the June 2010 Swap for the three and nine
months ended March 31, 2011.
The net derivative income (loss) recorded in OCI will be reclassified into earnings over the
term of the underlying cash flow hedge. The amount that will be reclassified into earnings will
vary depending upon the movement of the underlying interest rates. As interest rates decrease, the
charge to earnings will increase. Conversely, as interest rates increase, the charge to earnings
will decrease.
Diesel Fuel Risk
We have a large fleet of vehicles and equipment that primarily uses diesel fuel. As a result,
we have market risk for changes in diesel fuel prices. If diesel prices rise, our gross profit and
operating income (loss) would be negatively affected due to additional costs that may not be fully
recovered through increases in prices to customers.
We periodically enter into diesel fuel swaps to decrease our price volatility. As of March
31, 2011, we had hedged approximately 55% of our next 12 months of projected diesel fuel purchases
at prices ranging from $2.94 to $3.83 per gallon at a weighted-average price of $3.52. We are not
currently utilizing hedge accounting for any active diesel fuel derivatives.
6
Table of Contents
Balance Sheet and Statement of Operations Information
The fair value of derivatives at March 31, 2011 and June 30, 2010 is summarized in the
following table:
Asset Derivatives | Liability Derivatives | |||||||||||||||||
Fair Value | Fair Value | Fair Value | Fair Value | |||||||||||||||
at Mar. 31, | at June 30, | at Mar. 31, | at June 30, | |||||||||||||||
Balance Sheet Location | 2011 | 2010 | 2011 | 2010 | ||||||||||||||
Derivatives designated as hedging
instruments under U.S. GAAP: |
||||||||||||||||||
Interest rate swaps |
Accrued expenses and other | $ | | $ | | $ | 309 | $ | 245 | |||||||||
Total derivatives designated as
hedging instruments under U.S.
GAAP |
$ | | $ | | $ | 309 | $ | 245 | ||||||||||
Derivatives not designated as hedging
instruments under U.S. GAAP: |
||||||||||||||||||
Diesel fuel swaps (gross) (1) |
Prepaid expenses and other | $ | 2,195 | $ | 169 | $ | | $ | | |||||||||
Diesel fuel swaps (gross) (1) |
Accrued expenses and other | | | | 166 | |||||||||||||
Total derivatives not designated as
hedging instruments under U.S.
GAAP |
$ | 2,195 | $ | 169 | $ | | $ | 166 | ||||||||||
Total derivatives |
$ | 2,195 | $ | 169 | $ | 309 | $ | 411 | ||||||||||
(1) | The fair values of asset and liability derivatives with the same counterparty are netted on the balance sheet. |
7
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The effects of derivative instruments on the condensed consolidated statements of operations
for the three and nine months ended March 31, 2011 and 2010 are summarized in the following tables:
Derivatives designated as cash flow hedging instruments under U.S. GAAP:
Location of Loss | Amount of Loss | |||||||||||||||||
Amount of Gain (Loss) | Reclassified from | Reclassified from | ||||||||||||||||
Recognized in OCI | Accumulated OCI into | Accumulated OCI into | ||||||||||||||||
(Effective Portion) | Earnings | Earnings | ||||||||||||||||
For the Three Months Ended March 31, | 2011 | 2010 | 2011 | 2010 | ||||||||||||||
Interest rate swaps |
$ | 28 | * | $ | | Interest expense | $ | (51 | )* | $ | | |||||||
Totals |
$ | 28 | * | $ | | $ | (51 | )* | $ | | ||||||||
For the Nine Months Ended March 31, | 2011 | 2010 | 2011 | 2010 | ||||||||||||||
Interest rate swaps |
$ | (46) | * | $ | 1,109 | * | Interest expense | $ | (152 | )* | $ | (1,068 | )* | |||||
Totals |
$ | (46) | * | $ | 1,109 | * | $ | (152 | )* | $ | (1,068 | )* | ||||||
* | Net of tax |
Derivatives not designated as cash flow hedging instruments under U.S. GAAP:
Location of Gain | ||||||||||
Recognized in | Amount of Gain Recognized in | |||||||||
Earnings | Earnings | |||||||||
For the Three Months Ended March 31, | 2011 | 2010 | ||||||||
Diesel fuel swaps |
Cost of operations | $ | 1,387 | $ | 232 | |||||
Total |
$ | 1,387 | $ | 232 | ||||||
For the Nine Months Ended March 31, | 2011 | 2010 | ||||||||
Diesel fuel swaps |
Cost of operations | $ | 2,192 | $ | 927 | |||||
Total |
$ | 2,192 | $ | 927 | ||||||
Accumulated OCI
For the interest rate swaps, the following table summarizes the net derivative gains or
losses, net of taxes, recorded into accumulated OCI and reclassified to loss for the periods
indicated below.
For the Three Months | For the Nine Months | |||||||||||||||
Ended March 31, | Ended March 31, | |||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
Net accumulated derivative loss deferred at beginning of
period |
$ | (216 | ) | $ | (2,031 | ) | $ | (142 | ) | $ | (9,438 | ) | ||||
Changes in fair value |
(23 | ) | | (198 | ) | | ||||||||||
Reclassification to net income (loss) |
51 | | 152 | 1,109 | ||||||||||||
Net accumulated derivative loss deferred at end of period |
$ | (188 | ) | $ | (2,031 | ) | $ | (188 | ) | $ | (8,329 | ) | ||||
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The estimated net amount of the existing losses in OCI at March 31, 2011 expected to be
reclassified into net income (loss) over the next twelve months is approximately $150. This amount
was computed using the fair value of the cash flow hedges at March 31, 2011 and will differ from
actual reclassifications from OCI to net income (loss) during the next twelve months.
For the three and nine months ended March 31, 2011 and 2010, respectively, there were no
reclassifications to earnings due to hedged firm commitments no longer deemed probable or due to
hedged forecasted transactions that had not occurred by the end of the originally specified time
period.
6. Comprehensive Income (Loss)
The components of comprehensive income (loss) were as follows for the periods presented:
For the Three Months Ended | ||||||||
March 31, | ||||||||
2011 | 2010 | |||||||
Net income (loss) |
$ | 620 | $ | (2,031 | ) | |||
Change in fair value of interest rate cash
flow hedges, net
of income taxes of $18 |
28 | | ||||||
Comprehensive income (loss) |
$ | 648 | $ | (2,031 | ) | |||
For the Nine Months Ended | ||||||||
March 31, | ||||||||
2011 | 2010 | |||||||
Net loss |
$ | (649 | ) | $ | (9,438 | ) | ||
Change in fair value of interest rate
cash flow hedges, net
of income taxes of ($25) and $711,
respectively |
(46 | ) | 1,109 | |||||
Comprehensive loss |
$ | (695 | ) | $ | (8,329 | ) | ||
7. Fair Value
Fair value rules currently apply to all financial assets and liabilities and for certain
nonfinancial assets and liabilities that are required to be recognized or disclosed at fair value.
For this purpose, fair value is defined as the price that would be received to sell an asset or
paid to transfer a liability in an orderly transaction between market participants at the
measurement date. Valuation techniques used to measure fair value must maximize the use of
observable inputs and minimize the use of unobservable inputs.
U.S. GAAP establishes a three-tier fair value hierarchy, which prioritizes the inputs used in
measuring fair value. These tiers include:
| Level 1 Valuations based on quoted prices in active markets for identical instruments that we are able to access. Since valuations are based on quoted prices that are readily and regularly available in an active market, valuation of these products does not entail a significant degree of judgment. | ||
| Level 2 Valuations based on quoted prices in active markets for instruments that are similar, or quoted prices in markets that are not active for identical or similar instruments, and model-derived valuations in which all significant inputs and significant value drivers are observable in active markets. | ||
| Level 3 Valuations based on inputs that are unobservable and significant to the overall fair value measurement. |
As of March 31, 2011, we held certain items that are required to be measured at fair value on
a recurring basis. These included interest rate derivative instruments and diesel fuel derivative
instruments. Derivative instruments are used to hedge a portion of our diesel fuel costs and our
exposure to interest rate fluctuations. These derivative instruments currently consist of swaps
only. See Note 5 for further information on our derivative instruments and hedging activities.
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Our interest rate derivative instruments and diesel fuel derivative instruments consist of
over-the-counter contracts, which are not traded on a public exchange. The fair values for our
interest rate swaps and diesel fuel swaps are based on current settlement values and represent the
estimated amount we would have received or paid upon termination of these agreements. The fair
values are derived using pricing models that rely on market observable inputs such as yield curves
and commodity forward prices, and therefore are classified as Level 2. We also consider
counterparty credit risk in our determination of all estimated fair values. We have consistently
applied these valuation techniques in all periods presented.
At March 31, 2011 and June 30, 2010, the carrying amounts and fair values for our interest
rate swaps and diesel fuel swaps were as follows:
March 31, | ||||||||||||||||
Description | 2011 | Level 1 | Level 2 | Level 3 | ||||||||||||
Asset: |
||||||||||||||||
Diesel fuel swap agreements |
$ | 2,195 | $ | | $ | 2,195 | $ | | ||||||||
Liability: |
||||||||||||||||
Interest rate swap agreements |
(309 | ) | | (309 | ) | | ||||||||||
Total |
$ | 1,886 | $ | | $ | 1,886 | $ | | ||||||||
Description | June 30, 2010 |
Level 1 | Level 2 | Level 3 | ||||||||||||
Asset: |
||||||||||||||||
Diesel fuel swap agreements |
$ | 3 | $ | | $ | 3 | $ | | ||||||||
Liability: |
||||||||||||||||
Interest rate swap agreements |
(245 | ) | | (245 | ) | | ||||||||||
Total |
$ | (242 | ) | $ | | $ | (242 | ) | $ | | ||||||
The carrying amounts of cash and cash equivalents, accounts receivable and accounts
payable approximate fair values due to the short-term nature of these instruments. The carrying
value of our debt approximates fair value based on the market-determined, variable interest rates.
Assets and liabilities that are measured at fair value on a nonrecurring basis include
reporting units valued in connection with annual and interim goodwill impairment testing and assets
held for sale. For goodwill impairment testing we rely primarily on a discounted cash flow
approach, using Level 3 inputs. This approach requires significant estimates and judgmental
factors, including revenue growth rates, terminal values, and weighted average cost of capital,
which is used to discount future cash flows. Assets held for sale are valued using Level 2 inputs,
primarily observed prices for similar assets in the used equipment market.
8. Stock-Based Compensation
Compensation expense related to stock-based compensation plans was $973 and $1,209 for the
three months ended March 31, 2011 and March 31, 2010, respectively, and $2,991 and $3,514 for the
nine months ended March 31, 2011 and March 31, 2010, respectively. The income tax benefit
recognized for stock-based compensation
arrangements was $380 and $472 for the three months ended March 31, 2011 and March 31, 2010,
respectively, and $1,169 and $1,373 for the nine months ended March 31, 2011 and March 31, 2010,
respectively.
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9. Income Taxes
The liability method is used in accounting for income taxes as required by U.S. GAAP. Under
this method, deferred tax assets and liabilities are recognized for the future tax consequences
attributable to the differences between the financial statement carrying amounts of existing assets
and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured
using enacted tax rates expected to apply to taxable income in the years in which those temporary
differences are expected to be recovered or settled. The effect on deferred tax assets and
liabilities of a change in tax rates is recognized in the results of operations in the period that
includes the enactment date.
In assessing the value of deferred tax assets, the Company considers whether it was more
likely than not that some or all of the deferred tax assets would not be realized. The ultimate
realization of deferred tax assets is dependent upon the generation of future taxable income during
the periods in which those temporary differences become deductible. The Company considers the
scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning
strategies in making this assessment. Based upon these considerations, the Company provides a
valuation allowance to reduce the carrying value of certain of its deferred tax assets to their net
expected realizable value, if applicable. The Company has concluded that no valuation allowance is
required for deferred tax assets at March 31, 2011 and June 30, 2010, respectively.
Effective income tax rates of 35.5% and 37.8% for the three months ended March 31, 2011 and
March 31, 2010, respectively, and 34.4% and 38.1% for the nine months ended March 31, 2011 and
March 31, 2010, respectively, varied from the statutory federal income tax rate of 35% primarily as
a result of the effect of state income taxes.
10. Earnings (Loss) Per Share
The following table sets forth the calculations of basic and diluted earnings (loss) per
share:
Three Months Ended | Nine Months Ended | |||||||||||||||
March 31, | March 31, | |||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
Basic: |
||||||||||||||||
Net income (loss) |
$ | 620 | $ | (2,031 | ) | $ | (649 | ) | $ | (9,438 | ) | |||||
Weighted average common shares |
33,446 | 33,149 | 33,368 | 33,119 | ||||||||||||
Basic earnings (loss) per share |
$ | 0.02 | $ | (0.06 | ) | $ | (0.02 | ) | $ | (0.28 | ) | |||||
Diluted: |
||||||||||||||||
Net income (loss) |
$ | 620 | $ | (2,031 | ) | $ | (649 | ) | $ | (9,438 | ) | |||||
Weighted average common shares |
33,446 | 33,149 | 33,368 | 33,119 | ||||||||||||
Potential common stock arising
from stock
options and restricted stock |
592 | | | | ||||||||||||
Weighted average common shares
diluted |
34,038 | 33,149 | 33,368 | 33,119 | ||||||||||||
Diluted earnings (loss) per share |
$ | 0.02 | $ | (0.06 | ) | $ | (0.02 | ) | $ | (0.28 | ) | |||||
Outstanding options and restricted stock awards equivalent to 1,949 shares of common
stock were excluded from the calculation of diluted earnings per share for the three months ended
March 31, 2011 because their effect would have been anti-dilutive.
All outstanding options and restricted stock awards were excluded from the calculation of
diluted earnings per share for the three months ended March 31, 2010 and the nine months ended
March 31, 2011 and 2010, respectively, because their effect would have been anti-dilutive.
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11. Recent Accounting Pronouncements
In December 2010, the Financial Accounting Standards Board (FASB) issued an accounting
standards update for business combinations. This standards update specifies that if a public
entity presents comparative financial statements, the entity should disclose revenue and earnings
of the combined entity as though the business combination(s) that occurred during the current year
had occurred as of the beginning of the comparable prior annual reporting period only. The
amendments also expand the supplemental pro forma disclosures to include a description of the
nature and amount of material, nonrecurring pro forma adjustments directly attributable to the
business combination included in the reported pro forma revenue and earnings. The amendments
are effective prospectively for business combinations for which the acquisition date is on or after
the beginning of the first annual reporting period beginning on or after December 15, 2010 (July 1,
2011 for Pike). Early adoption is permitted. The adoption of this new guidance will not have a
significant impact on our consolidated financial statements.
12. Commitments and Contingencies
Legal Proceedings
We are from time to time a party to various lawsuits, claims and other legal proceedings that
arise in the ordinary course of business. These actions typically seek, among other things: (i)
compensation for alleged personal injury, workers compensation, employment discrimination, breach
of contract or property damages, (ii) punitive damages, civil penalties or other damages, or (iii)
injunctive or declaratory relief. With respect to all such lawsuits, claims and proceedings, we
record reserves when it is probable that a liability has been incurred and the amount of loss can
be reasonably estimated. We do not believe that any of these proceedings, individually or in the
aggregate, would be expected to have a material adverse effect on our results of operations,
financial position or cash flows.
Performance Bonds and Parent Guarantees
In the ordinary course of business, we are required by certain customers to post surety or
performance bonds in connection with services that we provide to them. These bonds provide a
guarantee to the customer that we will perform under the terms of a contract and that we will pay
subcontractors and vendors. If we fail to perform under a contract or to pay subcontractors and
vendors, the customer may demand that the surety make payments or provide services under the bond.
We must reimburse the surety for any expenses or outlays it incurs. As of March 31, 2011, we had
$159,795 in surety bonds outstanding and we also had provided collateral in the form of letters of
credit to sureties in the amount of $2,000. To date, we have not been required to make any
reimbursements to our sureties for bond-related costs. We believe that it is unlikely that we will
have to fund significant claims under our surety arrangements in the foreseeable future. Pike
Electric Corporation, from time to time, guarantees the obligations of its wholly-owned
subsidiaries, including obligations under certain contracts with customers.
Collective Bargaining Agreements
With the acquisition of Klondyke (Note 3), we are now party to various collective
bargaining agreements with various unions representing craftworkers performing field construction
operations. The agreements require Klondyke to pay specified wages, provide certain benefits to
its union employees and contribute certain amounts to multi-employer pension plans and employee
benefit trusts. If Klondyke withdrew from, or otherwise terminated participation in, one or more
multi-employer pension plans or the plans were to otherwise become underfunded, Klondyke could be
assessed liabilities for additional contributions related to the underfunding of these plans. We
do not believe that this potential underfunded liability would have a material adverse effect on
our results of operations, financial position or cash flows. The collective bargaining agreements
expire at various times and have typically been renegotiated and renewed on terms similar to the
ones contained in the expiring agreements.
Indemnities
We generally indemnify our customers for the services we provide under our contracts, as well
as other specified liabilities, which may subject us to indemnity claims and liabilities and
related litigation. As of March 31, 2011, we were not aware of circumstances that would lead to
future indemnity claims against us for material amounts in connection with these indemnity
obligations.
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Item 2. | Managements Discussion and Analysis of Financial Condition and Results of Operations |
The following discussion and analysis of our financial condition and results of
operations should be read in conjunction with our historical consolidated financial statements and
related notes thereto in this Quarterly Report on Form 10-Q and with our Annual Report on Form 10-K
for the fiscal year ended June 30, 2010. The discussion below contains forward-looking statements
that are based upon our current expectations and are subject to uncertainty and changes in
circumstances. Actual results may differ materially from these expectations due to inaccurate
assumptions and known or unknown risks and uncertainties, including those identified in
Uncertainty of
Forward-Looking Statements and Information below in this Item 2 and in Risk Factors in Item
1A of Part I of our Annual Report on Form 10-K for the fiscal year ended June 30, 2010.
Overview
We are one of the largest providers of energy solutions for investor-owned, municipal and
co-operative utilities in the United States. Since our founding in 1945, we have evolved from a
specialty non-unionized contractor focused on the electric distribution sector in the southeastern
United States to a leading turnkey energy solutions provider throughout the United States with
diverse capabilities servicing over 200 electric utilities, including American Electric Power
Company, Inc., Dominion Resources, Inc., Duke Energy Corporation, Duquesne Light Company, E.On AG,
Florida Power & Light Company, Los Angeles Department of Water and Power, PacifiCorp, Progress
Energy, Inc., and The Southern Company. Leveraging our core competencies as a company primarily
focused on providing a broad range of electric infrastructure services for our customers, we
believe our experienced management team has positioned us to benefit from the substantial long-term
growth drivers in our industry.
Over the past three years, we have reshaped our business platform and territory significantly
from being a distribution construction company based primarily in the southeastern United States to
a national energy solutions provider. We have done this organically and through strategic
acquisitions of companies with complementary service offerings and geographic footprints. Our
comprehensive suite of energy solutions now includes siting, permitting, engineering, designing,
planning, constructing, maintaining and repairing power delivery systems, including renewable
energy projects. Our planning and siting process leverages technology and the collection of
environmental, cultural, land use and scientific data to facilitate successful right-of-way
negotiations and permitting for transmission and distribution construction projects, powerlines,
substations and renewable energy installations. Our engineering and design capabilities include
designing, providing engineering, procurement and construction (EPC) services, owner engineering,
project management, multi-entity coordination, grid integration, electrical balance-of-plant
(BOP) and system planning for individual or turnkey powerline, substation and renewable energy
projects. Our construction and maintenance capabilities include substation, distribution
(underground and overhead) and transmission with voltages up to 345 kilovolt. We are also a
recognized leader in storm restoration due to our ability to rapidly mobilize thousands of existing
employees and equipment within 24 hours, while maintaining a functional workforce for unaffected
customers.
Critical Accounting Policies
The discussion and analysis of our financial condition and results of operations are based on
our condensed consolidated financial statements, which have been prepared in accordance with U.S.
GAAP. The preparation of these financial statements requires management to make certain estimates
and assumptions for interim financial information that affect the amounts reported in the financial
statements and accompanying notes. On an ongoing basis, we evaluate these estimates and
assumptions, including those related to revenue recognition for work in progress, allowance for
doubtful accounts, self-insured claims liability, valuation of goodwill and other intangible
assets, asset lives and salvage values used in computing depreciation and amortization, including
amortization of intangibles, and accounting for income taxes, contingencies, litigation and
stock-based compensation. Application of these estimates and assumptions requires the exercise of
judgment as to future uncertainties and, as a result, actual results could differ from these
estimates. Please refer to Managements Discussion and Analysis of Financial Condition and
Results of Operations Critical Accounting Policies included in our Annual Report on Form 10-K
for the year ended June 30, 2010 for further information regarding our critical accounting policies
and estimates.
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Results of Operations
The following table sets forth selected statements of operations data as approximate
percentages of revenues for the periods indicated:
Three Months Ended | Nine Months Ended | |||||||||||||||
March 31, | March 31, | |||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
Revenues: |
||||||||||||||||
Core services |
89.5 | % | 81.6 | % | 94.5 | % | 88.8 | % | ||||||||
Storm restoration services |
10.5 | % | 18.4 | % | 5.5 | % | 11.2 | % | ||||||||
Total |
100.0 | % | 100.0 | % | 100.0 | % | 100.0 | % | ||||||||
Cost of operations |
89.3 | % | 91.4 | % | 89.6 | % | 89.8 | % | ||||||||
Gross profit |
10.7 | % | 8.6 | % | 10.4 | % | 10.2 | % | ||||||||
General and administrative expenses |
9.0 | % | 9.9 | % | 9.3 | % | 10.0 | % | ||||||||
Loss on sale and impairment of property and equipment |
0.0 | % | 0.2 | % | 0.2 | % | 0.3 | % | ||||||||
Restructuring expenses |
| 0.1 | % | | 2.3 | % | ||||||||||
Income (loss) from operations |
1.7 | % | (1.6 | %) | 0.9 | % | (2.4 | %) | ||||||||
Interest expense and other, net |
1.1 | % | 1.1 | % | 1.1 | % | 1.6 | % | ||||||||
Income (loss) before income taxes |
0.6 | % | (2.7 | %) | (0.2 | %) | (4.0 | %) | ||||||||
Income tax expense (benefit) |
0.2 | % | (1.0 | %) | 0.0 | % | (1.5 | %) | ||||||||
Net income (loss) |
0.4 | % | (1.7 | %) | (0.2 | %) | (2.5 | %) | ||||||||
Three Months Ended March 31, 2011 Compared to Three Months Ended March 31, 2010
Revenues. Revenues increased 27.2%, or $32.9 million, to $153.8 million for the three months
ended March 31, 2011 from $120.9 million for the three months ended March 31, 2010.
Our core revenues increased 39.6% to $137.7 million for the three months ended March 31, 2011
from $98.6 million for the same period in the prior year. Our acquisition of Klondyke on June 30,
2010 provided $10.8 million in core revenues for the quarter ($5.0 million for substation, $1.0
million for transmission and $4.8 million for civil projects included in the overhead distribution
and other category below). We recognized approximately $20.2 million in material procurement
revenues ($18.6 million for engineering and substation, $1.3 million for transmission and $0.3
million for combined distribution) for the quarter ended March 31, 2011 compared to approximately
$3.8 million ($3.2 million for engineering and substation, $0.4 million for transmission and $0.2
million for combined distribution) for the same period in the prior year. The material procurement
revenues above are approximations, as certain material procurement services are provided as a
portion of larger fixed-price projects, in which we recognize project revenues using the
percentage-of-completion method.
The following table contains information on core revenue and percentage changes by category
for the periods indicated:
Three Months Ended | ||||||||||||
March 31, | ||||||||||||
Category of Core Revenue | 2011 | 2010 | % Change | |||||||||
Overhead distribution and other |
$ | 67.9 | $ | 51.2 | 32.5 | % | ||||||
Underground distribution |
14.8 | 14.6 | 1.3 | % | ||||||||
Transmission |
17.5 | 16.3 | 7.5 | % | ||||||||
Engineering and substation |
37.5 | 16.5 | 127.0 | % | ||||||||
Total |
$ | 137.7 | $ | 98.6 | 39.6 | % | ||||||
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| Distribution Revenues. Our combined revenues for overhead and underground distribution services increased 25.3% from the prior year, primarily due to a general increase in demand for overhead distribution maintenance coupled with the addition of Klondyke. Distribution revenues were also positively impacted by less storm restoration revenues compared to the same period in the prior year, as storm restoration work generally diverts man-hours from core work, which had decreased core revenues in the prior year. Underground maintenance experienced a smaller level of quarter-over-quarter growth and demand for underground distribution remains depressed due to the weak market for new residential housing. |
| Transmission Revenues. Transmission revenues increased 7.5% from the prior year, primarily due to the timing of certain projects that have started in the southeast United States, increased material procurement revenues and the addition of Klondyke. We expect our transmission revenues to continue to increase year-over-year, but revenues may vary period to period due to the timing of work on significant projects. |
| Engineering and Substation Revenues. Engineering and substation revenues increased 127.0% from the prior year, primarily due to material procurement services, including for the VC Summer project, along with the addition of Klondyke. Our engineering and substation services continue to produce increased revenues, and we expect that trend to continue in the foreseeable future. However, engineering and substation revenues may fluctuate, especially on a quarterly basis, due to the timing of material procurement revenues. |
Our storm restoration revenues decreased 27.7% to $16.1 million for the three months ended
March 31, 2011 from $22.3 million for the same period in the prior year due to fewer severe storms.
Storm restoration revenues during both periods primarily included work resulting from winter storm
events. Our storm restoration revenues are highly volatile and unpredictable.
The majority of our distribution services are provided to investor-owned, municipal and
co-operative utilities under master service agreements (MSAs). Services provided under these
MSAs include both overhead and underground powerline distribution services. Our MSAs do not
guarantee a minimum volume of work. The MSAs provide a framework for core and storm restoration
pricing and provide an outline of the service territory in which we will work or the percentage of
overall outsourced distribution work we will provide for the customer. Our MSAs also provide a
platform for multi-year relationships with our customers. We can easily ramp up staffing for a
customer without exhaustive contract negotiations and the MSAs also allow our customers to reduce
staffing needs.
Gross Profit. Gross profit increased 57.3% to $16.4 million for the three months ended March
31, 2011 from $10.4 million for the three months ended March 31, 2010. Gross profit as a
percentage of revenues increased to 10.7% for the three months ended March 31, 2011 from 8.6% for
the three months ended March 31, 2010. Gross profit for the quarter ended March 31, 2011 was aided
by more business volume, including the overhead distribution business, which provided improved
leverage to fixed costs. In addition, gross profit for the quarter ended March 31, 2010 was
negatively impacted by $1.5 million in environmental charges and significant crew start-up costs.
General and Administrative Expenses. General and administrative expenses increased 15.0% to
$13.8 million for the three months ended March 31, 2011 from $12.0 million for the three months
ended March 31, 2010. As a percentage of revenues, general and administrative expenses decreased
to 9.0% for the three months ended March 31, 2011 from 9.9% for the same period in the prior year.
The increase in general and administrative expenses was primarily due to the approximately $0.8
million of overhead costs related to Klondyke, which was acquired on June 30, 2010. International
and domestic business development activities also contributed to the increase in general and
administrative expenses.
Loss on Sale and Impairment of Property and Equipment. Loss on sale and impairment of property
and equipment was approximately $0 for the three months ended March 31, 2011 compared to $0.2
million for the three months ended March 31, 2010. The level of losses is affected by several
factors, including the timing of the continued replenishment of aging, damaged or excess fleet
equipment, and conditions in the market for used equipment. We continually evaluate the
depreciable lives and salvage values of our equipment.
Interest Expense and Other, Net. Interest expense and other, net increased 14.8% to $1.6
million for the quarter ended March 31, 2011 from $1.4 million for the quarter ended March 31,
2010. This increase was primarily due to increased settlement costs related to interest rate swaps
and increased amortization of deferred loan costs. See Note 5 of Notes to Condensed Consolidated
Financial Statements for full details of derivative instruments, including interest rate swaps.
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Income Tax Expense or Benefit. The income tax expense was $0.3 million for the three months
ended March 31, 2011 compared to an income tax benefit of $1.2 million for the three months ended
March 31, 2010. The effective tax rate was 35.5% and 37.8% for the three months ended March 31,
2011 and March 31, 2010, respectively.
Nine Months Ended March 31, 2011 Compared to Nine Months Ended March 31, 2010
Revenues. Revenues increased 12.5%, or $47.8 million, to $431.1 million for the nine months
ended March 31, 2011 from $383.3 million for the nine months ended March 31, 2010.
Our core revenues increased 19.6% to $407.3 million for the nine months ended March 31, 2011
from $340.6 million for the same period in the prior year. Our acquisition of Klondyke on June 30,
2010 provided $23.4 million in core revenues for the first nine months of fiscal 2011 ($10.4
million for substation, $4.4 million for transmission and $8.6 million for civil projects included
in the overhead distribution and other category below). We recognized approximately $45.0 million
in material procurement revenues ($39.0 million for engineering and substation, $5.1 million for
transmission and $0.9 million for combined distribution) for the nine months ended March 31, 2011
compared to approximately $17.4 million ($14.7 million for engineering and substation, $0.9 million
for transmission and $1.8 million for combined distribution) for the same period in the prior year.
The material revenues above are approximations, as certain material procurement services are
provided as a portion of larger fixed-price projects, in which we recognize project revenues using
the percentage-of-completion method.
The following table contains information on core revenue and percentage changes by category
for the periods indicated:
Nine Months Ended | ||||||||||||
March 31, | ||||||||||||
Category of Core Revenue | 2011 | 2010 | % Change | |||||||||
Overhead distribution and other |
$ | 209.1 | $ | 185.1 | 12.9 | % | ||||||
Underground distribution |
48.1 | 46.9 | 2.5 | % | ||||||||
Transmission |
60.8 | 51.7 | 17.5 | % | ||||||||
Engineering and substation |
89.3 | 56.9 | 57.0 | % | ||||||||
Total |
$ | 407.3 | $ | 340.6 | 19.6 | % | ||||||
| Distribution Revenues. Our combined revenues for overhead and underground distribution services increased 10.7% from the prior year, primarily due to a general increase in demand for overhead distribution maintenance during the period coupled with the addition of Klondyke. Distribution revenues were also positively impacted by less storm restoration revenues compared to the same period in the prior year, as storm restoration work generally diverts man-hours from core work, which had decreased core revenues in the prior year. Underground maintenance experienced a smaller level of period-over-period growth and demand for underground distribution remains depressed due to the weak market for new residential housing. |
| Transmission Revenues. Transmission revenues increased 17.5% from the prior year, primarily due to the timing of certain projects that have started in the southeast United States, increased material procurement revenues and the addition of Klondyke. We expect our transmission revenues to continue to increase year-over-year, but revenues may vary period to period due to the timing of work on significant projects. |
| Engineering and Substation Revenues. Engineering and substation revenues increased 57.0% increase from the prior year, primarily due to material procurement services, including for the VC Summer project, along with the addition of Klondyke. Our engineering and substation services continue to produce increased revenues, and we expect that trend to continue in the foreseeable future. However, engineering and substation revenues may fluctuate, especially on a quarterly basis, due to the timing of material procurement revenues. |
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Our storm restoration revenues decreased 44.3% to $23.8 million for the nine months ended
March 31, 2011 from $42.7 million for the same period in the prior year due to fewer severe storms.
Storm restoration revenues during both periods primarily included work resulting from various
winter storm events, as we experienced minimal storm work from tropical storms and hurricanes for
both periods. Our storm restoration revenues are highly volatile and unpredictable.
Gross Profit. Gross profit increased 14.6% to $44.8 million for the nine months ended March
31, 2011 from $39.1 million for the nine months ended March 31, 2010. Gross profit as a percentage
of revenues increased to 10.4% for the nine months ended March 31, 2011 from 10.2% for the nine
months ended March 31, 2010. Gross profit for the nine months ended March 31, 2011 was aided by
more business volume, including the overhead distribution business, which provided improved
leverage to fixed costs. In addition, gross profit for the nine months ended March 31, 2010 was
negatively impacted by $3.2 million in environmental charges.
General and Administrative Expenses. General and administrative expenses increased 4.8% to
$40.1 million for the nine months ended March 31, 2011 from $38.3 million for the nine months ended
March 31, 2010. As a percentage of revenues, general and administrative expenses decreased to 9.3%
from 10.0%. The increase in general and administrative expenses was primarily due to the
approximately $2.7 million of overhead costs related to Klondyke, which was acquired on June 30,
2010. International and domestic business development activities also contributed to the increase
in general and administrative expenses. Partially offsetting the increase was a $0.7 million
decrease in compensation-related expense and a $0.5 million decrease in stock-based compensation
expense.
Loss on Sale and Impairment of Property and Equipment. Loss on sale and impairment of property
and equipment was $0.6 million for the nine months ended March 31, 2011 compared to $1.2 million
for the nine months ended March 31, 2010. The level of losses is affected by several factors,
including the timing of the continued replenishment of aging, damaged or excess fleet equipment,
and conditions in the market for used equipment. We continually evaluate the depreciable lives and
salvage values of our equipment.
Restructuring Expenses. During the second quarter ended December 31, 2009, we initiated plans
to implement cost restructuring measures in our distribution operations and support services. The
cost restructuring initiatives included reductions in headcount, pay levels and employee benefits
in distribution operations and support services, and the disposition of excess fleet assets. We
have made these changes in order to improve our efficiency and to better align our costs with the
current operating environment.
We recorded a pre-tax restructuring charge related to these measures of $9.0 million ($5.5
million or $0.17 per diluted share on an after-tax basis) for the nine months ended March 31, 2010,
comprised of $1.0 million for
severance and other termination benefits and an $8.0 million non-cash writedown of fleet and
other fixed assets to be disposed.
Interest Expense and Other, Net. Interest expense and other, net decreased 13.7% to $5.1
million for the nine months ended March 31, 2011 from $5.9 million for the nine months ended March
31, 2010. This decrease was primarily due to reduced settlement costs related to interest rate
swaps and reduced debt balances, partially offset by increased amortization of deferred loan costs.
See Note 5 of Notes to Condensed Consolidated Financial Statements for full details of derivative
instruments, including interest rate swaps.
Income Tax Benefit. The income tax benefit was $0.3 million and $5.8 million for the nine
months ended March 31, 2011 and March 31, 2010, respectively. The effective tax rate was 34.4% and
38.1% for the nine months ended March 31, 2011 and March 31, 2010, respectively.
Liquidity and Capital Resources
Our primary cash needs have been for working capital, capital expenditures, payments under our
senior credit facility and acquisitions. Our primary source of cash for the nine months ended
March 31, 2011 and 2010 was cash provided by operations.
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We need working capital to support seasonal variations in our business, primarily due to the
impact of weather conditions on the electric infrastructure and the corresponding spending by our
customers on electric service and repairs. The increased service activity during storm restoration
events temporarily causes an excess of customer billings over customer collections, leading to
increased accounts receivable during those periods. In the past, we have utilized borrowings under
the revolving portion of our senior credit facility and cash on hand to satisfy normal cash needs
during these periods.
As of March 31, 2011, our cash totaled $11.8 million and we had $89.4 million available under
the $115.0 million revolving portion of our senior credit facility (after giving effect to the
outstanding balance of $25.6 million of standby letters of credit). This borrowing availability is
subject to, and potentially limited by, our compliance with the covenants of our senior credit
facility, which are described below. We anticipate refinancing our senior credit facility during
late fiscal 2011 or early fiscal 2012.
We consider our cash investment policies to be conservative in that we maintain a diverse
portfolio of what we believe to be high-quality cash investments with short-term maturities.
Accordingly, we do not expect that the current volatility in the capital markets will have a
material impact on the principal amounts of our cash investments.
We believe that our cash flow from operations, available cash and cash equivalents, and
borrowings available under our senior credit facility will be adequate to meet our ordinary course
liquidity needs for the foreseeable future. However, we expect our ability to satisfy our
obligations or to fund planned capital expenditures will depend on our future performance, which to
a certain extent is subject to general economic, financial, competitive, legislative, regulatory
and other factors beyond our control. In addition, if we fail to comply with the covenants
contained in our senior credit facility, we may be unable to access the revolving portion of our
senior credit facility upon which we depend for letters of credit and other short-term borrowings.
This would have a negative impact on our liquidity and require us to obtain alternative short-term
financing. We also believe that if we pursue any material acquisitions in the foreseeable future
we may need to finance this activity through additional equity or debt financing.
Changes in Cash Flows:
Nine Months Ended | ||||||||
March 31, | ||||||||
2011 | 2010 | |||||||
(In millions) | ||||||||
Net cash provided by operating activities |
$ | 26.9 | $ | 18.4 | ||||
Net cash used in investing activities |
$ | (9.6 | ) | $ | (7.8 | ) | ||
Net cash used in financing activities |
$ | (16.6 | ) | $ | (2.7 | ) |
Net cash provided by operating activities increased to $26.9 million for the nine months ended
March 31, 2011 from $18.4 million for the nine months ended March 31, 2010. The increase in cash
provided by operating activities was primarily related to the $8.8 million improvement in net
income (loss).
We are currently paying the commercial insurance carrier that administers our partially
self-insured individual workers compensation, vehicle and general liability insurance programs
retrospective premium payment adjustments of $5.2 million in four equal, monthly installments that
began in February 2011. Net cash provided by operating activities includes payments of $2.6
million of retrospective insurance premium payments to the commercial insurance carrier for the
three months ended March 31, 2011. These payments are included in changes in insurance and claims
accruals. Retrospective adjustments have historically been prepared annually on a paid-loss
basis by our commercial insurance carrier. The last retrospective premium payment adjustment from
our commercial insurance carrier resulted in a refund to Pike of approximately $0.2 million that
was received during December 2009.
Net cash used in investing activities increased to $9.6 million for the nine months ended
March 31, 2011 from $7.8 million for the nine months ended March 31, 2010. Capital expenditures
for both periods consisted primarily of purchases of vehicles and equipment used to service our
customers.
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Net cash used in financing activities increased to $16.6 million for the nine months ended
March 31, 2011 from $2.7 million for the nine months ended March 31, 2010. Financing activities
for the nine months ended March 31, 2011 included $15.5 million of term loan payments and $1.0
million of fees associated with an amendment to our senior credit facility. Our cash used in
financing activities during the nine months ended March 31, 2010 was primarily related to $2.8
million of fees associated with the July 29, 2009 closing of our senior credit facility.
EBITDA U.S. GAAP Reconciliation
EBITDA is a non-U.S.GAAP financial measure that represents the sum of net income (loss),
income tax expense (benefit), interest expense, depreciation and amortization. EBITDA is used
internally when evaluating our operating performance and allows investors to make a more meaningful
comparison between our core business operating results on a consistent basis over different periods
of time, as well as with those of other similar companies. Management believes that EBITDA, when
viewed with our results under U.S. GAAP and the accompanying reconciliation, provides additional
information that is useful for evaluating the operating performance of our business without regard
to potential distortions. Additionally, management believes that EBITDA permits investors to gain
an understanding of the factors and trends affecting our ongoing cash earnings, from which capital
investments are made and debt is serviced. However, EBITDA has limitations and should not be
considered in isolation or as a substitute for performance measures calculated in accordance with
U.S. GAAP, such as net loss or cash flow from operating activities, as indicators of operating
performance or liquidity. This non-U.S. GAAP measure excludes certain cash expenses that we are
obligated to make. In addition, other companies in our industry may calculate this non-U.S. GAAP
measure differently than we do or may not calculate it at all, limiting its usefulness as a
comparative measure. The table below provides a reconciliation between net income (loss) and
EBITDA.
Three months ended | Nine months ended | |||||||||||||||
March 31, | March 31, | |||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
(In millions) | (In millions) | |||||||||||||||
Net income (loss) |
$ | 0.6 | $ | (2.0 | ) | $ | (0.6 | ) | $ | (9.4 | ) | |||||
Adjustments: |
||||||||||||||||
Interest expense |
1.6 | 1.4 | 5.1 | 6.1 | ||||||||||||
Income tax expense (benefit) |
0.3 | (1.2 | ) | (0.3 | ) | (5.8 | ) | |||||||||
Depreciation and
amortization |
9.4 | 8.5 | 28.5 | 26.8 | ||||||||||||
EBITDA |
$ | 11.9 | $ | 6.7 | $ | 32.7 | $ | 17.7 | ||||||||
EBITDA increased 76.3% to $11.9 million for the three months ended March 31, 2011 from
$6.7 million for the three months ended March 31, 2010. EBITDA increased 84.7% to $32.7 million
for the nine months ended March 31, 2011 from $17.7 million for the nine months ended March 31,
2010. EBITDA for the nine months ended March 31, 2010 was negatively impacted by a $9.0 million
pre-tax restructuring charge, comprised of $1.0 million for severance and other termination
benefits and an $8.0 million non-cash writedown of fleet and other fixed assets.
Senior Credit Facility
As of March 31, 2011, we had $99.0 million of term loans outstanding under our senior credit
facility. As of March 31, 2011, our borrowing availability under the $115.0 million revolving
portion of our senior credit facility was $89.4 million (after giving effect to the outstanding
balance of $25.6 million of outstanding standby letters of credit). This borrowing availability is
subject to, and potentially limited by, our compliance with the covenants of our senior credit
facility, which are discussed below. The obligations under our senior credit facility are
unconditionally guaranteed by us and each of our existing and subsequently acquired or organized
subsidiaries (other than Pike Electric, LLC, which is a borrower under the facility) and secured on
a first-priority basis by security interests (subject to permitted liens) in substantially all
assets owned by us, Pike Electric, LLC and each of our other subsidiaries, subject to limited
exceptions.
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Our senior credit facility contains a number of financial covenants including a leverage ratio
requirement. Our leverage ratio (as defined in the first amendment to our senior credit facility
to include specific environmental charges for fiscal 2010) increased during fiscal 2010 due
primarily to reduced revenues and profit from our distribution services and $3.3 million in
unanticipated environmental charges. As a result of these factors, our leverage ratio on June 30,
2010 would have exceeded our covenant leverage ratio requirement of no greater than 3.00 to 1.00
under our senior credit facility in effect at such time. On August 30, 2010, we entered into an
amendment to our senior credit facility, which: (i) amended the required leverage ratio to be no
more than 3.75 to 1.00 for the fiscal quarters ending June 30, 2010 through March 31, 2011 and 3.25
to 1.00 for the fiscal quarter ending June 30, 2011 and thereafter; (ii) waived non-compliance with
the leverage ratio covenant prior to giving effect to the foregoing amendment with regard to the
quarter ending June 30, 2010; and (iii) added Qualified Remedial Expenses (as defined in the first
amendment to include specific environmental charges for fiscal 2010) into the calculation of
adjusted EBITDA under our senior credit facility. We believe that we will be in compliance with
the financial covenants of our senior credit facility for the remainder of the term of such
facility. We paid and capitalized $1.0 million of fees related to the amendment that are being
amortized on an effective interest basis as part of interest expense over the remaining term of our
senior credit facility.
Our senior credit facility contains a number of other affirmative and restrictive covenants
including limitations on mergers, consolidations and dissolutions, sales of assets, investments and
acquisitions, indebtedness and liens, and other restricted payments. Under our senior credit
facility, we are permitted to incur maximum capital expenditures of $70.0 million in fiscal 2011
and in any fiscal year thereafter, subject to a one year carry-forward of 50% of the unused amount
from the previous fiscal year. In addition, our senior credit facility includes a requirement that
we maintain: (i) a leverage ratio, which is the ratio of total debt to adjusted EBITDA (as defined
in our senior credit facility; measured on a trailing four-quarter basis), of no more than 3.75 to
1.0 as of the last day of each fiscal quarter, declining to 3.25 on June 30, 2011 and thereafter,
and (ii) a cash interest coverage ratio, which is the ratio of adjusted EBITDA (as defined in our
senior credit facility; measured on a trailing four-quarter basis) to cash interest expense
(measured on a trailing four-quarter basis) of at least 3.5 to 1.0 as of the last day of each
fiscal quarter. We were in compliance with all of our debt covenants as of March 31, 2011,
including those noted above, with a leverage ratio of 2.39 to 1.00 and a cash interest coverage
ratio of 9.20 to 1.00. We anticipate refinancing our senior credit facility during late fiscal
2011 or early fiscal 2012. This refinancing will result in a non-cash charge of approximately $2.0
million related to unamortized deferred loan costs.
We repaid $15.5 million of term loans outstanding under our senior credit facility during the
nine months ended March 31, 2011 with cash provided by operations and cash on hand.
Concentration of Credit Risk
We are subject to concentrations of credit risk related primarily to our cash and cash
equivalents and accounts receivable. We maintain substantially all of our cash investments with
what we believe to be high credit quality financial institutions. We grant credit under normal
payment terms, generally without collateral, to our customers, which include electric power
companies, governmental entities, general contractors and builders, and owners and managers of
commercial and industrial properties located in the United States. Consequently, we are subject to
potential credit risk related to changes in business and economic factors throughout the United
States. However, we generally have certain statutory lien rights with respect to services
provided.
Legal Proceedings
We are from time to time a party to various lawsuits, claims and other legal proceedings that
arise in the ordinary course of business. These actions typically seek, among other things: (i)
compensation for alleged personal injury, workers compensation, employment discrimination, breach
of contract, or property damages, (ii) punitive damages, civil penalties or other damages, or (iii)
injunctive or declaratory relief. With respect to all such lawsuits, claims and proceedings, we
record reserves when it is probable that a liability has been incurred and the amount of loss can
be reasonably estimated. We do not believe that any of these proceedings, individually or in the
aggregate, would be expected to have a material adverse effect on our results of operations,
financial position or cash flows.
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Off-Balance Sheet Arrangements
As is common in our industry, we have entered into certain off-balance sheet arrangements in
the ordinary course of business that result in risks not directly reflected in our balance sheets.
Our significant off-balance sheet transactions include liabilities associated with non-cancelable
operating leases, letter of credit obligations, and surety guarantees entered into in the normal
course of business. We have not engaged in any off-balance sheet financing arrangements through
special purpose entities.
Letters of Credit
Certain of our vendors require letters of credit to ensure reimbursement for amounts they are
disbursing on our behalf. In addition, from time to time some customers require us to post letters
of credit to ensure payment to our subcontractors and vendors under those contracts and to
guarantee performance under our contracts. Such letters of credit are generally issued by a bank
or similar financial institution. The letter of credit commits the issuer to pay specified amounts
to the holder of the letter of credit if the holder claims that we have failed to perform specified
actions. If this were to occur, we would be required to reimburse the issuer of the letter of
credit. Depending on the circumstances of such a reimbursement, we may also have to record a
charge to earnings for the reimbursement. We do not believe that it is likely that any material
claims will be made under a letter of credit in the foreseeable future. We use the revolving
portion of our senior credit facility to issue letters of credit. As of March 31, 2011, we had
$25.6 million of standby letters of credit issued under our senior credit facility primarily for
insurance and bonding purposes. Our ability to obtain letters of credit under the revolving portion
of our senior credit facility is conditioned on our continued compliance with the affirmative and
negative covenants of our senior credit facility.
Performance Bonds and Parent Guarantees
In the ordinary course of business, we are required by certain customers to post surety or
performance bonds in connection with services that we provide to them. These bonds provide a
guarantee to the customer that we will perform under the terms of a contract and that we will pay
subcontractors and vendors. If we fail to perform under a contract or to pay subcontractors and
vendors, the customer may demand that the surety make payments or provide services under the bond.
We must reimburse the surety for any expenses or outlays it incurs. As of March 31, 2011, we had
$159.8 million in surety bonds outstanding, and we also had provided collateral in the form of a
letter of credit to sureties in the amount of $2.0 million, which is included in the total letters
of credit outstanding above. To date, we have not been required to make any reimbursements to our
sureties for bond-related costs. We believe that it is unlikely that we will have to fund
significant claims under our surety arrangements in the foreseeable future.
Pike Electric Corporation, from time to time, guarantees the obligations of its wholly-owned
subsidiaries, including obligations under certain contracts with customers.
Seasonality; Fluctuations of Results
Because our services are performed outdoors, our results of operations can be subject to
seasonal variations due to weather conditions. These seasonal variations affect both our core and
storm restoration services. Extended periods of rain affect the deployment of our core crews,
particularly with respect to underground work. During the winter months, demand for core work is
generally lower due to inclement weather. In addition, demand for core work generally increases
during the spring months due to improved weather conditions and is typically the highest during the
summer due to better weather conditions. Due to the unpredictable nature of storms, the level of
our storm restoration revenues fluctuates from period to period.
Recent Accounting Pronouncements
See Note 11, Recent Accounting Pronouncements, to our Notes to Condensed Consolidated
Financial Statements in Item 1 of this Quarterly Report for a description of recent accounting
pronouncements, including the expected dates of adoption and estimated effects, if any, on our
consolidated financial statements.
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Uncertainty of Forward-Looking Statements and Information
This Quarterly Report on Form 10-Q, as well as information included in future filings by Pike
Electric Corporation with the Securities and Exchange Commission (the SEC) and information
contained in written material, press releases and oral statements issued by or on behalf of the
Company, contains, or may contain, certain forward-looking statements under Section 27A of the
Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as
amended (the Exchange Act). Such forward-looking statements include information relating to,
among other matters, our future prospects, developments and business strategies for our operations.
These forward-looking statements are based on current expectations, estimates, forecasts and
projections about our company and the industry in which we operate and managements beliefs and
assumptions. Words such as may, will, should, estimate, expect, anticipate, intend,
plan, predict, potential, project, continue, believe, seek, estimate, variations of
such words and similar expressions are intended to identify such forward-looking statements. These
statements include, among others, statements relating to:
| our expectation that the Tanzanian powerline projects will utilize our engineering, procurement and construction capabilities, that distribution construction work on the project will begin during the fourth quarter of fiscal 2011 and that work on the project will continue through the second quarter of fiscal 2013; |
| our expectation that the goodwill recognized in our acquisition of Klondyke will be amortizable for tax purposes; |
| our expectation that substantially all the assets held for sale at March 31, 2010 will be sold during the next twelve months; |
| our belief that the lawsuits, claims or other proceedings to which we are subject in the ordinary course of business, individually or in the aggregate, will not have a material adverse effect on our results of operations, financial position or cash flows; |
| our expectation that our engineering and substation services will continue to produce increased revenues in the foreseeable future; |
| our expectation that our transmission revenues will continue to increase year-over-year; |
| our expectation that current volatility in the capital markets will not have a material impact on the principal amounts of our cash investments; |
| our belief that our cash flow from operations, available cash and cash equivalents, and borrowings available under our senior credit facility will be adequate to meet our ordinary course liquidity needs for the foreseeable future; | ||
| our expectation that our ability to satisfy our obligations or to fund planned capital expenditures will depend on our future performance and our belief that this is subject to a certain extent on general economic, financial, competitive, legislative, regulatory and other factors beyond our control; |
| the possibility that if we fail to comply with the covenants contained in our senior credit facility, we may be unable to access the revolving portion of our senior credit facility upon which we depend for letters of credit and other short-term borrowings and that this would have a negative impact on our liquidity and could require us to obtain alternative short-term financing; |
| our belief that if we pursue any material acquisitions in the foreseeable future we may need to finance this activity through additional equity or debt financing; |
| our belief that it is unlikely that any material claims will be made under a letter of credit in the foreseeable future; |
| our belief that it is unlikely that we will have to fund significant claims under our surety arrangements in the foreseeable future; |
| our expectation that our gross profit and operating income (loss) would be negatively affected if diesel prices rise due to additional costs that we may not fully recover through increases in prices to customers; |
| our expectation that the net amount of the existing losses in OCI at March 31, 2010 reclassified into net income (loss) over the next twelve months will be approximately $150,000; |
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| our belief that any potential underfunded liability related to one or more multi-employer pension plans in which Klondyke is a participant would not have a material adverse effect on our results of operations, financial position or cash flows; |
| our belief that we will be in compliance with the financial covenants of our senior credit facility for the remainder of the term of such facility; and |
| our anticipation that we will refinance our senior credit facility during late fiscal 2011 or early fiscal 2012. |
These statements are based on certain assumptions and analyses made by us in light of our
experience and perception of historical trends, current conditions, expected future developments
and other factors we believe are appropriate under the circumstances, and involve risks and
uncertainties that may cause actual future activities and results of operations to be materially
different from historical or anticipated results. Factors that could impact those differences or
adversely affect future periods include, but are not limited to, the factors set forth in Item 1A.
Risk Factors of our Annual Report on Form 10-K for the fiscal year ended June 30, 2010.
Caution should be taken not to place undue reliance on our forward-looking statements, which
reflect the expectations of management of Pike only as of the time such statements are made. We
undertake no obligation to publicly update or revise any forward-looking statements, whether as a
result of new information, future events or otherwise.
Item 3. | Quantitative and Qualitative Disclosures About Market Risk |
For quantitative and qualitative disclosures about our market risks, see Item 7A of our Annual
Report on Form 10-K for the fiscal year ended June 30, 2010.
Item 4. | Controls and Procedures |
Evaluation of Disclosure Controls and Procedures
Our management has established and maintains a system of disclosure controls and procedures
that are designed to provide reasonable assurance that information required to be disclosed by us
in the reports that we file or submit under the Exchange Act, such as this quarterly report, is
recorded, processed, summarized and reported within the time periods specified in the SECs rules
and forms. The disclosure controls and procedures are also designed 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 disclosure.
As of the end of the period covered by this quarterly report, we evaluated the effectiveness
of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15(b) of
the Exchange Act. This evaluation was carried out under the supervision and with the participation
of our management, including our Chief Executive Officer and Chief Financial Officer. Based on this
evaluation, these officers have concluded that, as of March 31, 2011, our disclosure controls and
procedures were effective to provide reasonable assurance of achieving their objectives.
Internal Control over Financial Reporting
There has been no change in our internal control over financial reporting during the quarter
ended March 31, 2011 that has materially affected, or is reasonably likely to materially affect,
our internal control over financial reporting.
Design and Operation of Control Systems
Our management, including the Chief Executive Officer and Chief Financial Officer, does not
expect that our disclosure controls and procedures or our internal control over financial reporting
will prevent or detect all errors and all fraud. A control system, no matter how well designed and
operated, can provide only reasonable, not absolute, assurance that the control systems objectives
will be met. The design of a control system must reflect the fact that there are resource
constraints, and the benefits of controls must be considered relative to their costs. Further,
because of the inherent limitations in all control systems, no evaluation of controls can provide
absolute assurance that misstatements due to error or fraud will not occur or that all control
issues and instances of fraud, if any, within our company have been detected. These inherent
limitations include the realities that judgments in decision-making can be faulty and breakdowns
can occur because of simple errors or mistakes. Controls can be circumvented by the individual acts
of some persons, by collusion of two or more people, or by management override of the controls. The
design of any system of controls is based in part on certain assumptions about the likelihood of
future events, and there can be no assurance that any design will succeed in achieving its stated
goals under all potential future conditions. Over time, controls may become inadequate because of
changes in conditions or deterioration in the degree of compliance with policies or procedures.
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PART II OTHER INFORMATION
Item 1. | Legal Proceedings |
We are from time to time a party to various lawsuits, claims and other legal proceedings that
arise in the ordinary course of business. These actions typically seek, among other things, (a)
compensation for alleged personal injury, workers compensation, employment discrimination, breach
of contract, or property damages, (b) punitive damages, civil penalties or other damages, or (c)
injunctive or declaratory relief. With respect to all such lawsuits, claims and proceedings, we
record reserves when it is probable a liability has been incurred and the amount of loss can be
reasonably estimated. We do not believe that any of these proceedings, individually or in the
aggregate, would be expected to have a material adverse effect on our results of operations,
financial position or cash flows.
Item 1A. | Risk Factors |
There have been no material changes from the risk factors disclosed in Part I, Item 1A, of
our Annual Report on Form 10-K for the fiscal year ended June 30, 2010.
Item 6. | Exhibits |
Exhibit | Description | |||
3.1 | Certificate of Incorporation of Pike Electric Corporation
(Incorporated by reference to Exhibit 3.1 on our Registration
Statement on Form S-1/A filed July 11, 2005) |
|||
3.2 | Amended and Restated Bylaws of Pike Electric Corporation, as of
April 30, 2009 (Incorporated by reference to Exhibit 3.1 on our
Form 8-K filed May 5, 2009) |
|||
31.1 | Certification of Periodic Report by Chief Executive Officer
pursuant to Rule 13a-14(a)/15d-14(a) and pursuant to Section 302
of the Sarbanes-Oxley Act of 2002 (filed herewith) |
|||
31.2 | Certification of Periodic Report by Chief Financial Officer
pursuant to Rule 13a-14(a)/15d-14(a) and pursuant to Section 302
of the Sarbanes-Oxley Act of 2002 (filed herewith) |
|||
32.1 | Certification of Periodic Report by Chief Executive Officer and
Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as
adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
(filed herewith) |
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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.
PIKE ELECTRIC CORPORATION | ||||||
(Registrant) | ||||||
Date: May 10, 2011
|
By: | /s/
|
||||
Chairman, Chief Executive Officer and President | ||||||
Date: May 10, 2011
|
By: | /s/
|
||||
Executive Vice President and Chief Financial Officer |
25