8-K 1 cpr1210138k.htm 8-K CPR 12.10.13 8K


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
FORM 8-K
 
CURRENT REPORT
Pursuant to Section 13 or Section 15(d) of
the Securities Exchange Act of 1934
Date of Report (Date of earliest event reported): December 10, 2013
  
CHAPARRAL ENERGY, INC.
(Exact name of registrant as specified in its charter)
 
 
 
 
 
 
Delaware
 
333-134748
 
73-1590941
(State or other jurisdiction
of incorporation)
 
(Commission
File Number)
 
(IRS Employer
Identification No.)
 
 
 
701 Cedar Lake Boulevard
Oklahoma City, OK
 
73114
(Address of principal executive offices)
 
(Zip Code)
Registrant's telephone number, including area code: (405) 478-8770
Not Applicable
(Former name or former address, if changed since last report)
 
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
 
o
Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
 
o
Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
 
o
Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
 
o
Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))





Item 7.01.
Regulation FD Disclosure.
On December 11, 2013, Chaparral Energy, Inc. (referred to herein as “we”, “us,” and “our”) presented the slide show, attached hereto as Exhibit 99.1 and incorporated herein by reference, at the Wells Fargo 12th Annual MLP, Pipeline & Energy Symposium in New York, New York.
Note Regarding Non-GAAP Financial Measures
The investor presentation attached as an exhibit hereto contains certain references to adjusted EBITDA and PV-10 value, which are non-GAAP financial measures, as defined under Regulation G of the rules and regulations of the SEC.
Adjusted EBITDA
Management uses adjusted EBITDA as a supplemental financial measurement to evaluate our operational trends. Items excluded generally represent non-cash adjustments, the timing and amount of which cannot be reasonably estimated and are not considered by management when measuring our overall operating performance. In addition, adjusted EBITDA is generally consistent with the Consolidated EBITDAX calculation that is used in the covenant ratio required under our senior secured revolving credit facility. We consider compliance with this covenant to be material. Adjusted EBITDA is used as a supplemental financial measurement in the evaluation of our business and should not be considered as an alternative to net income, as an indicator of our operating performance, as an alternative to cash flows from operating activities, or as a measure of liquidity. Adjusted EBITDA is not defined under GAAP and, accordingly, it may not be a comparable measurement to those used by other companies.
We define adjusted EBITDA as net income, adjusted to exclude (1) interest and other financing costs, net of capitalized interest, (2) income taxes, (3) depreciation, depletion and amortization, (4) unrealized (gain) loss on hedge reclassification adjustments, (5) non-cash change in fair value of non-hedge derivative instruments, (6) interest income, (7) stock-based compensation expense, (8) gain or loss on disposed assets, and (9) impairment charges and other significant, unusual non-cash charges.
Through March 31, 2010, our calculation of adjusted EBITDA excluded any cash proceeds received from the monetization of derivatives with a scheduled maturity date more than 12 months following the date of such monetization, in accordance with the terms of our prior credit facility. In July 2010, we amended the definition of Consolidated EBITDAX in our senior secured revolving credit facility to (1) permit cash proceeds received from the monetization of derivatives to be included in the calculation of Consolidated EBITDAX, to the extent that such monetizations, in any period between scheduled redeterminations, do not exceed 5% of the borrowing base then in effect, and (2) permit the exclusion from the calculation of Consolidated EBITDAX of up to $4.5 million in one-time cash expenses associated with our financing transactions that were incurred and paid during the second quarter of 2010. As a result, beginning with the second quarter of 2010, we have changed our calculation of adjusted EBITDA to include cash proceeds received from the monetization of derivatives with a scheduled maturity date more than 12 months following the date of such monetization, to the extent permitted by our senior secured revolving credit facility. However, we have not changed our calculation of adjusted EBITDA to exclude approximately $2.3 million of one-time cash expenses associated with our financing transactions. As a result of the permitted exclusion of these expenses, our Consolidated EBITDAX as calculated for covenant compliance purposes is higher than our adjusted EBITDA for the year ended December 31, 2010.
In April 2011, we amended the definition of Consolidated EBITDAX in our senior secured revolving credit facility to permit the exclusion of our reasonable and customary fees and expenses related to the refinancing of our 8.5% Senior Notes due 2015 from the calculation of Consolidated EBITDAX.
In May 2012, we amended the definition of Consolidated EBITDAX in our senior secured revolving credit facility to permit the exclusion of our reasonable and customary fees and expenses related to the refinancing of our 8.875% Senior Notes due 2017 from the calculation of Consolidated EBITDAX.
 

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The following table provides a reconciliation of our net income (loss) to adjusted EBITDA for the specified periods:

 
 
Nine months ended September 30,
 
Year ended December 31,
(in thousands)
 
2013
 
2012
 
2012
 
2011
 
2010
Net income (loss)
 
$
35,142

 
$
45,299

 
$
64,403

 
$
42,048

 
$
33,713

Interest expense
 
72,565

 
72,666

 
98,402

 
96,720

 
81,370

Income tax expense (benefit)
 
19,993

 
25,645

 
37,837

 
35,924

 
23,803

Depreciation, depletion, and amortization
 
139,439

 
119,807

 
169,307

 
146,083

 
109,503

Unrealized (gain) loss on ineffective portion of hedges and reclassification adjustments
 
(28,544
)
 
(35,777
)
 
(46,746
)
 
27,452

 
23,889

Non-cash change in fair value of non-hedge derivative instruments
 
39,581

 
(12,726
)
 
(12,411
)
 
(57,899
)
 
(2,523
)
Proceeds from monetization of derivatives with a scheduled maturity date more than 12 months from the monetization date included in EBITDA
 
—

 
—

 
—

 
—

 
9,418

Interest income
 
(206
)
 
(168
)
 
(225
)
 
(165
)
 
(144
)
Stock-based compensation expense
 
2,553

 
3,058

 
3,065

 
3,747

 
2,600

(Gain) loss on sale of assets
 
(556
)
 
21

 
(149
)
 
(1,284
)
 
(184
)
Loss on extinguishment of debt
 
—

 
21,714

 
21,714

 
20,592

 
2,241

Loss on impairment of oil and natural gas properties
 
1,090

 
—

 
—

 
—

 
—

Other non-cash charges
 
—

 
—

 
2,000

 
—

 
4,150

Adjusted EBITDA
 
$
281,057

 
$
239,539

 
$
337,197

 
$
313,218

 
$
287,836

 
PV-10 value
PV-10 value is a non-GAAP measure that differs from the standardized measure of discounted future net cash flows in that PV-10 value is a pre-tax number, while the standardized measure of discounted future net cash flows is an after-tax number. We believe that the presentation of the PV-10 value is relevant and useful to investors because it presents the discounted future net cash flows attributable to our proved reserves prior to taking into account future corporate income taxes, and it is a useful measure of evaluating the relative monetary significance of our oil and natural gas properties. Further, investors may utilize the measure as a basis for comparison of the relative size and value of our reserves to other companies. We use this measure when assessing the potential return on investment related to our oil and natural gas properties. However, PV-10 value is not a substitute for the standardized measure of discounted future net cash flows. Our PV-10 value measure and the standardized measure of discounted future net cash flows do not purport to present the fair value of our oil and natural gas reserves.
The following table provides a reconciliation of PV-10 value to the standardized measure of discounted future net cash flows for the periods shown:

 
 
As of December 31,
(in thousands)
 
2012
 
2011
 
2010
PV-10 value
 
$
2,068,620

 
$
2,309,089

 
$
1,770,061

Present value of future income tax discounted at 10%
 
(544,939
)
 
(711,177
)
 
(534,035
)
Standardized measure of discounted future net cash flows
 
$
1,523,681

 
$
1,597,912

 
$
1,236,026




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Item 9.01.
Financial Statements and Exhibits
 
 
(d)
Exhibits.
 
 
 
 
Exhibit
Number
 
Description
 
 
 
99.1
 
Investor Presentation


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

 
 
 
 
 
 
 
 
December 10, 2013
 
 
 
 
 
 
 
 
 
 
 
By:
 
/s/    JOSEPH O. EVANS        
 
 
 
 
 
Name:
 
Joseph O. Evans
 
 
 
 
 
Title:
 
Chief Financial Officer and Executive Vice President
 

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Exhibit Index
 

 
 
 
Exhibit
Number
 
Description
 
 
 
99.1
 
Investor Presentation



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