UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended June 30, 2014

OR

 

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

For the transition period from                      to                     

Commission File Number: 001-33801

APPROACH RESOURCES INC.

(Exact name of registrant as specified in its charter)

 

Delaware		51-0424817
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)
One Ridgmar Centre 6500 West Freeway, Suite 800 Fort Worth, Texas		76116
(Address of principal executive offices)		(Zip Code)

(817) 989-9000

(Registrant’s telephone number, including area code)

N/A

(Former name, former address and former fiscal year, if changed since last report)

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.    x  Yes    ¨  No

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

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

 

Large accelerated filer  x				Accelerated filer		¨
Non-accelerated filer    ¨  (Do not check if smaller reporting company)				Smaller reporting company		¨

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

The number of shares of the registrant’s common stock, $0.01 par value, outstanding as of July 24, 2014, was 39,369,986.

 

 

 

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PART I—FINANCIAL INFORMATION

Item 1. Financial Statements.

Approach Resources Inc. and Subsidiaries

Unaudited Consolidated Balance Sheets

(In thousands, except shares and per-share amounts)

 

		June 30, 2014				December 31, 2013
ASSETS
CURRENT ASSETS:
Cash and cash equivalents		$	444			$	58,761
Restricted cash			—				7,350
Accounts receivable:
Joint interest owners			108				158
Oil, NGL and gas sales			24,590				22,871
Prepaid expenses and other current assets			1,012				592
Deferred income taxes – current			4,573				681
Total current assets			30,727				90,413
PROPERTIES AND EQUIPMENT:
Oil and gas properties, at cost, using the successful efforts method of accounting			1,510,623				1,320,195
Furniture, fixtures and equipment			4,607				2,537
Total oil and gas properties and equipment			1,515,230				1,322,732
Less accumulated depletion, depreciation and amortization			(327,701	)			(275,702	)
Net oil and gas properties and equipment			1,187,529				1,047,030
Other assets			9,579				8,041
Total assets		$	1,227,835			$	1,145,484
LIABILITIES AND STOCKHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable		$	27,385			$	38,575
Oil, NGL and gas sales payable			9,519				6,101
Accrued liabilities			50,015				37,918
Unrealized loss on commodity derivatives			12,764				1,847
Total current liabilities			99,683				84,441
NON-CURRENT LIABILITIES:
Senior secured credit facility			46,000				—
Senior notes			250,000				250,000
Deferred income taxes			99,609				91,883
Unrealized loss on commodity derivatives			3,002				315
Asset retirement obligations			8,790				8,350
Total liabilities			507,084				434,989
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS’ EQUITY:
Preferred stock, $0.01 par value, 10,000,000 shares authorized none outstanding			—				—
Common stock, $0.01 par value, 90,000,000 shares authorized, 39,367,485 and 39,047,699 issued and outstanding, respectively			391				390
Additional paid-in capital			568,754				565,237
Retained earnings			151,606				144,868
Total stockholders’ equity			720,751				710,495
Total liabilities and stockholders’ equity		$	1,227,835			$	1,145,484

See accompanying notes to these unaudited consolidated financial statements

 

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Approach Resources Inc. and Subsidiaries

Unaudited Consolidated Statements of Operations

(In thousands, except shares and per-share amounts)

 

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2014				2013				2014				2013
REVENUES:
Oil, NGL and gas sales		$	73,408			$	42,272			$	135,335			$	78,541
EXPENSES:
Lease operating			7,946				3,993				15,797				9,376
Production and ad valorem taxes			4,925				3,068				9,094				5,624
Exploration			1,966				557				2,704				817
General and administrative			7,402				5,229				15,937				11,639
Depletion, depreciation and amortization			28,573				18,482				52,179				35,538
Total expenses			50,812				31,329				95,711				62,994
OPERATING INCOME			22,596				10,943				39,624				15,547
OTHER:
Interest expense, net			(5,357	)			(2,451	)			(10,494	)			(3,680	)
Equity in losses of investee			(186	)			(64	)			(186	)			(180	)
Realized loss on commodity derivatives			(3,320	)			(714	)			(4,659	)			(407	)
Unrealized (loss) gain on commodity derivatives			(7,678	)			4,290				(13,604	)			190
Other expense			(109	)			—				(109	)			—
INCOME BEFORE INCOME TAX PROVISION			5,946				12,004				10,572				11,470
INCOME TAX PROVISION			2,153				4,217				3,834				4,030
NET INCOME		$	3,793			$	7,787			$	6,738			$	7,440
EARNINGS PER SHARE:
Basic		$	0.10			$	0.20			$	0.17			$	0.19
Diluted		$	0.10			$	0.20			$	0.17			$	0.19
WEIGHTED AVERAGE SHARES OUTSTANDING:
Basic			39,368,606				39,007,361				39,306,296				38,965,811
Diluted			39,384,613				39,029,203				39,322,392				38,976,732

See accompanying notes to these unaudited consolidated financial statements

 

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Approach Resources Inc. and Subsidiaries

Unaudited Consolidated Statements of Cash Flows

(In thousands)

 

		Six Months Ended June 30,
		2014				2013
OPERATING ACTIVITIES:
Net income		$	6,738			$	7,440
Adjustments to reconcile net income to cash provided by operating activities:
Depletion, depreciation and amortization			52,179				35,538
Amortization of loan origination fees			689				—
Unrealized loss (gain) on commodity derivatives			13,604				(190	)
Exploration expense			2,704				817
Share-based compensation expense			3,761				3,790
Deferred income taxes			3,834				4,030
Equity in losses of investee			186				180
Changes in operating assets and liabilities:
Accounts receivable			(1,669	)			(1,485	)
Prepaid expenses and other current assets			(420	)			250
Accounts payable			(11,433	)			(3,957	)
Oil, NGL and gas sales payable			3,418				437
Accrued liabilities			12,097				(2,011	)
Cash provided by operating activities			85,688				44,839
INVESTING ACTIVITIES:
Additions to oil and gas properties			(192,872	)			(119,586	)
Contribution to equity method investment			(186	)			(6,280	)
Change in restricted cash			7,350				—
Additions to furniture, fixtures and equipment, net			(2,070	)			(317	)
Cash used in investing activities			(187,778	)			(126,183	)
FINANCING ACTIVITIES:
Borrowings under credit facility			114,421				129,059
Repayment of amounts outstanding under credit facility			(68,421	)			(235,950	)
Proceeds from issuance of senior notes			—				242,746
Loan origination fees			(2,227	)			—
Cash provided by financing activities			43,773				135,855
CHANGE IN CASH AND CASH EQUIVALENTS			(58,317	)			54,511
CASH AND CASH EQUIVALENTS, beginning of period		$	58,761			$	767
CASH AND CASH EQUIVALENTS, end of period		$	444			$	55,278
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid for interest		$	9,961			$	2,124
SUPPLEMENTAL DISCLOSURE OF NON-CASH TRANSACTION:
Asset retirement obligations capitalized		$	260			$	306

See accompanying notes to these unaudited consolidated financial statements

 

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Approach Resources Inc. and Subsidiaries

Notes to Consolidated Financial Statements (Unaudited)

June 30, 2014

1. Summary of Significant Accounting Policies

Organization and Nature of Operations

Approach Resources Inc. (“Approach,” the “Company,” “we,” “us” or “our”) is an independent energy company engaged in the exploration, development, production and acquisition of oil and gas properties. We focus on finding and developing oil and natural gas reserves in oil shale and tight gas sands. Our properties are primarily located in the Permian Basin in West Texas. We also own interests in the East Texas Basin.

Consolidation, Basis of Presentation and Significant Estimates

The interim consolidated financial statements of the Company are unaudited and contain all adjustments (consisting primarily of normal recurring accruals) necessary for a fair statement of the results for the interim periods presented. Results for interim periods are not necessarily indicative of results to be expected for a full year due in part to the volatility in prices for oil, NGLs and gas, future commodity prices for commodity derivative contracts, global economic and financial market conditions, interest rates, access to sources of liquidity, estimates of reserves, drilling risks, geological risks, transportation restrictions, the timing of acquisitions, product supply and demand, market competition and interruptions of production. You should read these consolidated interim financial statements in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2013, filed with the Securities and Exchange Commission on February 25, 2014.

The accompanying interim consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America and include the accounts of the Company and its wholly owned subsidiaries. Intercompany accounts and transactions are eliminated. In preparing the accompanying financial statements, management has made certain estimates and assumptions that affect reported amounts in the financial statements and disclosures of contingencies. Actual results may differ from those estimates. Significant assumptions are required in the valuation of proved oil and gas reserves, which affect our estimate of depletion expense as well as our impairment analyses. Significant assumptions also are required in our estimation of accrued liabilities, commodity derivatives, income tax provision, share-based compensation and asset retirement obligations. It is at least reasonably possible these estimates could be revised in the near term, and these revisions could be material. Certain prior-year amounts have been reclassified to conform to current-year presentation. These classifications have no impact on the net income reported.

Recent Accounting Pronouncements

In April 2014, the Financial Accounting Standards Board (“FASB”) issued guidance that raised the threshold for a disposal to qualify as a discontinued operation and requires new disclosures of both discontinued operations and certain other disposals that do not meet the definition of a discontinued operation. Under the updated standard, a discontinued operation is (i) a component of an entity or group of components that has been disposed of by sale, disposed of other than by sale or is classified as held for sale that represents a strategic shift that has or will have a major effect on an entity’s operations and financial results, or (ii) an acquired business or nonprofit activity that is classified as held for sale on the date of the acquisition. This update is aimed at reducing the frequency of disposals reported as discontinued operations by focusing on strategic shifts that have or will have a major effect on an entity’s operations and financial results. This accounting standards update is effective for annual reporting periods beginning on or after December 15, 2014, and will be applied prospectively. The Company is evaluating the impact of this new guidance and does not expect it to have a significant impact on the consolidated financial statements.

 

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Approach Resources Inc. and Subsidiaries

Notes to Consolidated Financial Statements (Unaudited)

June 30, 2014

 

In May 2014, the FASB issued an accounting standards update for “Revenue from Contracts with Customers,” which supersedes the revenue recognition requirements in “Topic 605, Revenue Recognition”. This accounting standard update provides new guidance concerning recognition and measurement of revenue and requires additional disclosures about the nature, timing and uncertainty of revenue and cash flows arising from contracts with customers. This new guidance is effective retrospectively for annual reporting periods beginning on or after December 15, 2016, with early application not permitted. The Company is evaluating our existing revenue recognition policies to determine whether any contracts will be affected by the new requirements.

2. Equity Method Investment

In September 2012, we entered into a joint venture to build an oil pipeline in Crockett and Reagan Counties, Texas, which is used to transport our oil to market. In October 2012, we made an initial contribution of $10 million to the joint venture for pipeline and facilities construction, and in 2013, we contributed $8.3 million to the joint venture for pipeline and facilities construction. Our contributions are recorded at cost and are included in investing activities under “Contribution to equity method investment” on our consolidated statements of cash flows. Our share of the investee’s earnings was recorded on our consolidated statement of operations for the three months ended June 30, 2013. In October 2013, we completed the sale of the joint venture, and net proceeds to Approach at closing totaled approximately $109.1 million, after deducting our share of transactional costs paid at closing. Of the $109.1 million in proceeds, $7.4 million was restricted pursuant to an escrow agreement. The escrow agreement terminated on June 1, 2014, and the cash held in escrow was subsequently released. We incurred $0.2 million in post-closing working capital adjustments during the three months ended June 30, 2014.

3. Earnings Per Common Share

We report basic earnings per common share, which excludes the effect of potentially dilutive securities, and diluted earnings per common share, which includes the effect of all potentially dilutive securities unless their impact is antidilutive. The following table provides a reconciliation of the numerators and denominators of our basic and diluted earnings per share (dollars in thousands, except per-share amounts).

 

		Three Months Ended June 30,								Six Months Ended June 30,
		2014				2013				2014				2013
Income (numerator):
Net income – basic		$	3,793			$	7,787			$	6,738			$	7,440
Weighted average shares (denominator):
Weighted average shares – basic			39,368,606				39,007,361				39,306,296				38,965,811
Dilution effect of share-based compensation, treasury method			16,007				21,842				16,096				10,921
Weighted average shares – diluted			39,384,613				39,029,203				39,322,392				38,976,732
Net income per share:
Basic		$	0.10			$	0.20			$	0.17			$	0.19
Diluted		$	0.10			$	0.20			$	0.17			$	0.19

 

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Approach Resources Inc. and Subsidiaries

Notes to Consolidated Financial Statements (Unaudited)

June 30, 2014

 

4. Long-Term Debt

The following table provides a summary of our long-term debt at June 30, 2014, and December 31, 2013 (in thousands).

 

		June 30,				December 31,
		2014				2013
Senior secured credit facility		$	46,000			$	—
Senior notes			250,000				250,000
Total long-term debt		$	296,000			$	250,000

Revolving Credit Facility

In May 2014, we entered into an amended and restated senior secured revolving credit facility (the “Credit Facility”) with an initial $450 million borrowing base, maximum commitments from the lenders of $1 billion and a maturity date of May 7, 2019. The borrowing base is redetermined semi-annually in April and October based on our oil, NGL and gas reserves. We, or the lenders, can each request one additional borrowing base redetermination each calendar year.

Borrowings under the Credit Facility bear interest based on the agent bank’s prime rate plus an applicable margin ranging from 0.50% to 1.50%, or the sum of the LIBOR rate plus an applicable margin ranging from 1.50% to 2.50%. In addition, we pay an annual commitment fee ranging from 0.375% to 0.50% of unused borrowings available under the Credit Facility. Margins vary based on the borrowings outstanding compared to the borrowing base.

We had outstanding borrowings of $46 million under our Credit Facility at June 30, 2014, compared to no outstanding borrowings at December 31, 2013. The weighted average interest rate applicable to borrowings under our Credit Facility for the six months ended June 30, 2014, was 2%. We had outstanding unused letters of credit under our Credit Facility totaling $0.3 million at June 30, 2014, and December 31, 2013, which reduce amounts available for borrowing under our Credit Facility.

Obligations under the Credit Facility are secured by mortgages on substantially all of the oil and gas properties of the Company and its subsidiaries. The Company is required to maintain liens covering the oil and gas properties of the Company and its subsidiaries representing at least 80% of the total value of all oil and gas properties of the Company and its subsidiaries.

Covenants

Our Credit Facility contains two principal financial covenants:

 

•

a consolidated modified current ratio covenant (as defined in the Credit Facility) that requires us to maintain a ratio of not less than 1.0 to 1.0 as of the last day of any fiscal quarter; and

 

•

a consolidated interest coverage ratio covenant (as defined in the Credit Facility) that requires us to maintain a ratio of consolidated EBITDAX to interest of not less than 2.5 to 1.0 as of the last day of any fiscal quarter.

 

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Approach Resources Inc. and Subsidiaries

Notes to Consolidated Financial Statements (Unaudited)

June 30, 2014

 

Our Credit Facility also contains covenants restricting cash distributions and other restricted payments, transactions with affiliates, incurrence of other debt, consolidations and mergers, the level of operating leases, asset sales, investment in other entities and liens on properties.

In addition, the obligations of the Company may be accelerated upon the occurrence of an Event of Default (as defined in the Credit Facility). Events of Default include customary events for a financing agreement of this type, including, without limitation, payment defaults, the inaccuracy of representations and warranties, defaults in the performance of affirmative or negative covenants, defaults on other indebtedness of the Company or its subsidiaries, bankruptcy or related defaults, defaults related to judgments and the occurrence of a Change of Control (as defined in the Credit Facility), which includes instances where a third party becomes the beneficial owner of more than 50% of the Company’s outstanding equity interests entitled to vote.

Senior Notes

In June 2013, we completed the public offering of $250 million principal amount of 7% Senior Notes due 2021 (the “Senior Notes”). Annual interest on the Senior Notes is $17.5 million, payable semi-annually on June 15 and December 15.

We issued the Senior Notes under a senior indenture dated June 11, 2013, as supplemented by a supplemental indenture of even date, among the Company, our subsidiary guarantors and Wells Fargo Bank, National Association, as trustee.

On and after June 15, 2016, we may redeem some or all of the Senior Notes at specified redemption prices, plus accrued and unpaid interest to the redemption date. Before June 15, 2016, we may redeem up to 35% of the Senior Notes at a redemption price of 107% of the principal amount, plus accrued and unpaid interest to the redemption date, with the proceeds of certain equity offerings. In addition, before June 15, 2016, we may redeem some or all of the Notes for cash at a redemption price equal to 100% of their principal amount plus an applicable make-whole premium and accrued and unpaid interest to the redemption date. If we sell certain of our assets or experience specific kinds of changes of control, we may be required to offer to purchase the Senior Notes from holders. The Senior Notes are fully and unconditionally guaranteed on a senior unsecured basis by each of our subsidiaries, subject to certain customary release provisions. A subsidiary guarantor may be released from its obligations under the guarantee:

 

•

in connection with any sale or other disposition of all or substantially all of the assets of that guarantor (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) the Company or a subsidiary guarantor, if the sale or other disposition otherwise complies with the indenture;

 

•

in connection with any sale or other disposition of the capital stock of that guarantor to a person that is not (either before or after giving effect to such transaction) the Company or a subsidiary guarantor, if that guarantor no longer qualifies as a subsidiary of the Company as a result of such disposition and the sale or other disposition otherwise complies with the indenture;

 

•

if the Company designates any restricted subsidiary that is a guarantor to be an unrestricted subsidiary in accordance with the indenture;

 

•

upon defeasance or covenant defeasance of the notes or satisfaction and discharge of the indenture, in each case, in accordance with the indenture;

 

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Approach Resources Inc. and Subsidiaries

Notes to Consolidated Financial Statements (Unaudited)

June 30, 2014

 

•

upon the liquidation or dissolution of that guarantor, provided that no default or event of default occurs under the indenture as a result thereof or shall have occurred and is continuing; or

 

•

in the case of any restricted subsidiary that, after the issue date of the notes is required under the indenture to guarantee the notes because it becomes a guarantor of indebtedness issued or an obligor under a credit facility with respect to the Company and/or its subsidiaries, upon the release or discharge in full from its (i) guarantee of such indebtedness or (ii) obligation under such credit facility, in each case, which resulted in such restricted subsidiary’s obligation to guarantee the notes.

The Indenture restricts our ability, among other things, to (i) sell certain assets, (ii) pay distributions on, redeem or repurchase, equity interests, (iii) incur additional debt, (iv) make certain investments, (v) enter into transactions with affiliates, (vi) incur liens and (vii) merge or consolidate with another company. These restrictions are subject to a number of important exceptions and qualifications. If at any time the Senior Notes are rated investment grade by both Moody’s Investors Service and Standard & Poor’s Ratings Services and no default (as defined in the Indenture) has occurred and is continuing, many of these restrictions will terminate. The Indenture contains customary events of default.

Subsidiary Guarantors

The Senior Notes are guaranteed on a senior unsecured basis by each of our consolidated subsidiaries. Approach Resources Inc. is a holding company with no independent assets or operations. The subsidiary guarantees are full and unconditional and joint and several, and any subsidiaries of the Company other than the subsidiary guarantors are minor. There are no significant restrictions on the Company’s ability, or the ability of any subsidiary guarantor, to obtain funds from its subsidiaries through dividends, loans, advances or otherwise.

At June 30, 2014, we were in compliance with all of our covenants, and there were no existing defaults or events of default, under our debt instruments.

5. Commitments and Contingencies

Our contractual obligations include long-term debt, daywork drilling contracts, operating lease obligations, asset retirement obligations and employment agreements with our executive officers. On January 3, 2014, we entered into an employment agreement with Sergei Krylov as the Company’s Executive Vice President and Chief Financial Officer. Our maximum commitment under this employment agreement, which would apply if Mr. Krylov were terminated without cause, is $1.3 million. Since December 31, 2013, there have been no other material changes to our contractual obligations. In August 2014, we extended our existing gas purchase and processing agreement with DCP Midstream, LP through August 2023.

We are involved in various legal and regulatory proceedings arising in the normal course of business. While we cannot predict the outcome of these proceedings with certainty, we do not believe that an adverse result in any pending legal or regulatory proceeding, individually or in the aggregate, would be material to our consolidated financial condition or cash flows.

6. Income Taxes

The effective income tax rate for the three and six months ended June 30, 2014, was 36.2% and 36.3%, respectively. Total income tax expense for the three and six months ended June 30, 2014, differed from amounts computed by applying the U.S. federal statutory tax rates to pre-tax income due primarily to state taxes.

 

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Approach Resources Inc. and Subsidiaries

Notes to Consolidated Financial Statements (Unaudited)

June 30, 2014

 

The effective income tax rate for the three and six months ended June 30, 2013, was 35.1%. Total income tax expense for the three and six months ended June 30, 2013, differed from amounts computed by applying the U.S. federal statutory tax rates to pre-tax income due primarily to state taxes and the impact of permanent differences between book and taxable income.

7. Fair Value of Financial and Derivative Instruments

The following table provides our outstanding commodity derivative positions at June 30, 2014.

 

Commodity and Period		Contract Type		Volume Transacted		Contract Price
Crude Oil
July 2014 – December 2014		Collar		550 Bbls/d		$90.00/Bbl – $105.50/Bbl
July 2014 – December 2014		Collar		950 Bbls/d		$85.05/Bbl – $95.05/Bbl
July 2014 – December 2014		Collar		2,000 Bbls/d		$89.00/Bbl – $98.85/Bbl
July 2014 – March 2015		Collar		1,500 Bbls/d		$85.00/Bbl – $95.30/Bbl
January 2015 – December 2015		Collar		2,600 Bbls/d		$84.00/Bbl – $91.00/Bbl
Natural Gas Liquids
Propane
July 2014 – December 2014		Swap		500 Bbls/d		$41.16/Bbl
Natural Gasoline
July 2014 – December 2014		Swap		175 Bbls/d		$83.37/Bbl
Natural Gas
July 2014 – December 2014		Swap		360,000 MMBtu/month		$4.18/MMBtu
July 2014 – December 2014		Swap		35,000 MMBtu/month		$4.29/MMBtu
July 2014 – December 2014		Swap		160,000 MMBtu/month		$4.40/MMBtu
September 2014 – June 2015		Collar		80,000 MMBtu/month		$4.00/MMBtu –$4.74/MMBtu
January 2015 – December 2015		Swap		200,000 MMBtu/month		$4.10/MMBtu
January 2015 – December 2015		Collar		130,000 MMBtu/month		$4.00/MMBtu – $4.25/MMBtu

Subsequent to June 30, 2014, we entered into two crude oil collars covering a total of 1,000 Bbls per day for 2015 at a floor price of $90.00/Bbl and a ceiling price of $102.50/Bbl.

The following table summarizes the fair value of our open commodity derivatives as of June 30, 2014, and December 31, 2013 (in thousands).

 

		Asset Derivatives										Liability Derivatives
				Fair Value										Fair Value
				June 30,				December 31,						June 30,				December 31,
		Balance Sheet Location		2014				2013				Balance Sheet Location		2014				2013
Derivatives not designated as hedging instruments
Commodity derivatives		Unrealized gain on commodity derivatives		$	—			$	9,108			Unrealized loss on commodity derivatives		$	15,766			$	11,270

 

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Approach Resources Inc. and Subsidiaries

Notes to Consolidated Financial Statements (Unaudited)

June 30, 2014

 

The following table summarizes the change in the fair value of our commodity derivatives (in thousands).

 

		Income Statement Location		Three Months Ended								Six Months Ended
				June 30,								June 30,
				2014				2013				2014				2013
Derivatives not designated as hedging instruments
Commodity derivatives		Realized loss on commodity derivatives		$	(3,320	)		$	(714	)		$	(4,659	)		$	(407	)
		Unrealized (loss) gain on commodity derivatives			(7,678	)			4,290				(13,604	)			190
				$	(10,998	)		$	3,576			$	(18,263	)		$	(217	)

Unrealized gains and losses, at fair value, are included on our consolidated balance sheets as current or non-current assets or liabilities based on the anticipated timing of cash settlements under the related contracts. Changes in the fair value of our commodity derivative contracts are recorded in earnings as they occur and included in other income (expense) on our consolidated statements of operations. We estimate the fair values of swap contracts based on the present value of the difference in exchange-quoted forward price curves and contractual settlement prices multiplied by notional quantities. We internally valued the option contracts using industry-standard option pricing models and observable market inputs. We use our internal valuations to determine the fair values of the contracts that are reflected on our consolidated balance sheets. Realized gains and losses are also included in other income (expense) on our consolidated statements of operations.

We are exposed to credit losses in the event of nonperformance by the counterparties on our commodity derivatives positions and have considered the exposure in our internal valuations. However, we do not anticipate nonperformance by the counterparties over the term of the commodity derivatives positions.

To estimate the fair value of our commodity derivatives positions, we use market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. We primarily apply the market approach for recurring fair

 

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Approach Resources Inc. and Subsidiaries

Notes to Consolidated Financial Statements (Unaudited)

June 30, 2014

 

value measurements and attempt to use the best available information. We determine the fair value based upon the hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and lowest priority to unobservable inputs (Level 3 measurement). The three levels of fair value hierarchy are as follows:

 

•

Level 1 — Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. At June 30, 2014, we had no Level 1 measurements.

 

•

Level 2 — Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Our derivatives, which consist primarily of commodity swaps and collars, are valued using commodity market data which is derived by combining raw inputs and quantitative models and processes to generate forward curves. Where observable inputs are available, directly or indirectly, for substantially the full term of the asset or liability, the instrument is categorized in Level 2. At June 30, 2014, all of our commodity derivatives were valued using Level 2 measurements.

 

•

Level 3 — Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. At June 30, 2014, we had no Level 3 measurements.

Financial Instruments Not Recorded at Fair Value

The following table sets forth the fair values of financial instruments that are not recorded at fair value on our financial statements (in thousands).

 

		June 30, 2014
		Carrying Amount				Fair Value
Senior Notes		$	250,000			$	262,530

The fair value of the Senior Notes uses pricing that is readily available in the public market. Accordingly, the fair value of the Senior Notes would be classified as Level 2 in the fair value hierarchy.

8. Share-Based Compensation

In February 2014, we awarded an aggregate of 245,157 restricted shares to our executive officers, of which 163,438 shares are subject to certain performance conditions and 81,719 shares are subject to three-year total shareholder return (“TSR”) conditions, assuming maximum TSR is achieved. Assuming target TSR is achieved, then 54,479 shares are subject to three-year TSR conditions. The aggregate fair market value of the award, assuming target TSR is achieved is $4.5 million, which will be expensed over a service period of approximately three years, subject to performance and three-year TSR conditions.

 

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Approach Resources Inc. and Subsidiaries

Notes to Consolidated Financial Statements (Unaudited)

June 30, 2014

 

Effective May 16, 2014, we entered into an executive grant and separation agreement (the “Separation Agreement”) with Ralph P. Manoushagian, former Executive Vice President — Land, upon his retirement. As set forth in the Separation Agreement, we granted Mr. Manoushagian 41,281 restricted stock units with an aggregate fair market value of $0.8 million that will be settled on December 31, 2014. We also recorded a benefit of $1.1 million in share-based compensation expense related to the forfeiture of 66,684 outstanding unvested shares of restricted stock previously awarded to Mr. Manoushagian.

 

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

The following discussion is intended to assist in understanding our results of operations and our financial condition. This section should be read in conjunction with management’s discussion and analysis contained in our Annual Report on Form 10-K for the year ended December 31, 2013, filed with the Securities and Exchange Commission (“SEC”) on February 25, 2014. Our consolidated financial statements and the accompanying notes included elsewhere in this Quarterly Report on Form 10-Q contain additional information that should be referred to when reviewing this material. Certain statements in this discussion may be forward-looking. These forward-looking statements involve risks and uncertainties, which could cause actual results to differ from those expressed in this report. A glossary containing the meaning of the oil and gas industry terms used in this management’s discussion and analysis follows the “Results of Operations” table in this Item 2.

Cautionary Statement Regarding Forward-Looking Statements

Various statements in this report, including those that express a belief, expectation or intention, as well as those that are not statements of historical fact, are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). The forward-looking statements may include projections and estimates concerning the timing and success of specific projects, typical well economics and our future reserves, production, revenues, costs, income, capital spending, 3-D seismic operations, interpretation and results and obtaining permits and regulatory approvals. When used in this report, the words “will,” “believe,” “intend,” “expect,” “may,” “should,” “anticipate,” “could,” “estimate,” “plan,” “predict,” “project,” “potential” or their negatives, other similar expressions or the statements that include those words, are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words.

These forward-looking statements are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions and other factors. Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control. In addition, management’s assumptions about future events may prove to be inaccurate. We caution all readers that the forward-looking statements contained in this report are not guarantees of future performance, and we cannot assure any reader that such statements will be realized or the forward-looking events and circumstances will occur. Actual results may differ materially from those anticipated or implied in the forward-looking statements due to the factors listed or referred to in the “Risk Factors” section and elsewhere in this report. All forward-looking statements speak only as of the date of this report. We disclaim any obligation to publicly update or revise any forward-looking statements as a result of new information, future events or otherwise, unless required by law. These cautionary statements qualify all forward-looking statements attributable to us, or persons acting on our behalf. The risks, contingencies and uncertainties relate to, among other matters, the following:

 

•

uncertainties in drilling, exploring for and producing, oil and gas;

 

•

oil, NGL and gas prices;

 

•

overall United States and global economic and financial market conditions;

 

•

domestic and foreign demand and supply for oil, NGLs, gas and the products derived from such hydrocarbons;

 

•

our inability to obtain additional financing necessary to fund our operations and capital expenditures and to meet our other obligations;

 

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•

the effect of government regulation and permitting and other legal requirements, including laws or regulations that could restrict or prohibit hydraulic fracturing;

 

•

disruption of credit and capital markets;

 

•

our financial position;

 

•

our cash flows and liquidity;

 

•

disruptions to, capacity constraints in or other limitations on the pipeline systems that deliver our oil, NGLs and gas and other processing and transportation considerations;

 

•

marketing of oil, NGLs and gas;

 

•

high costs, shortages, delivery delays or unavailability of drilling and completion equipment, materials, labor or other services;

 

•

competition in the oil and gas industry;

 

•

uncertainty regarding our future operating results;

 

•

interpretation of 3-D seismic data;

 

•

replacing our oil, NGL and gas reserves;

 

•

our ability to retain and attract key personnel;

 

•

our business strategy, including our ability to recover oil, NGLs and gas in place associated with our Wolfcamp shale oil resource play in the Permian Basin;

 

•

development of our current asset base or property acquisitions;

 

•

estimated quantities of oil, NGL and gas reserves and present value thereof;

 

•

plans, objectives, expectations and intentions contained in this report that are not historical; and

 

•

other factors discussed in our Annual Report on Form 10-K for the year ended December 31, 2013, filed with the SEC on February 25, 2014.

 

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Overview

Approach Resources Inc. is an independent energy company focused on the exploration, development, production and acquisition of unconventional oil and gas reserves in the Midland Basin of the greater Permian Basin in West Texas, where we lease approximately 138,000 net acres. We believe our concentrated acreage position provides us an opportunity to achieve cost, operating and recovery efficiencies in the development of our drilling inventory. We are currently developing significant resource potential from the Wolfcamp shale oil formation. Additional drilling targets could include the Clearfork, Canyon Sands, Strawn and Ellenburger zones. We sometimes refer to our development project in the Permian Basin as “Project Pangea,” which includes “Pangea West.” Our management and technical team have a proven track record of finding and developing reserves through advanced drilling and completion techniques. As the operator of all of our estimated proved reserves and production, we have a high degree of control over capital expenditures and other operating matters.

At December 31, 2013, our estimated proved reserves were 114.7 million barrels of oil equivalent (“MMBoe”), made up of 40% oil, 29% NGLs, 31% gas and 39% proved developed. Substantially all of our proved reserves are located in the Permian Basin in Crockett and Schleicher Counties, Texas. At June 30, 2014, we owned working interests in 741 producing oil and gas wells.

Second Quarter 2014 Activity

During the three months ended June 30, 2014, we produced 1,286 MBoe, or 14.1 MBoe/d. We drilled 16 horizontal wells and completed 16 horizontal wells. We currently have three horizontal rigs running in Project Pangea.

2014 Capital Expenditures

For the three months ended June 30, 2014, our capital expenditures totaled $92.3 million, consisting of $85.8 million for drilling and completion activities, $3.8 million for infrastructure projects and equipment and $2.7 million for acreage acquisitions and extensions. Our 2014 capital budget is $400 million, including $385 million for horizontal drilling and completion activity and $15 million for infrastructure projects and equipment.

Our 2014 capital budget excludes acquisitions and lease extensions and renewals and is subject to change depending upon a number of factors, including additional data on our Wolfcamp shale oil resource play, results of horizontal drilling and completions, economic and industry conditions at the time of drilling, prevailing and anticipated prices for oil, NGLs and gas, the availability of sufficient capital resources for drilling prospects, our financial results and the availability of lease extensions and renewals on reasonable terms.

 

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Results of Operations

The following table sets forth summary information regarding oil, NGL and gas revenues, production, average product prices and average production costs and expenses for the three and six months ended June 30, 2014 and 2013. We determine a barrel of oil equivalent using the ratio of six Mcf of natural gas to one Boe, and one barrel of NGLs to one Boe. The ratios of six Mcf of natural gas to one Boe and one barrel of NGLs to one Boe do not assume price equivalency and, given price differentials, the price for a Boe for natural gas or NGLs may differ significantly from the price for a barrel of oil.

 

		Three Months Ended June 30,								Six Months Ended June 30,
		2014				2013				2014				2013
Revenues (in thousands):
Oil		$	51,570			$	30,381			$	93,315			$	55,842
NGLs			11,560				6,214				21,858				12,451
Gas			10,278				5,677				20,162				10,248
Total oil, NGL and gas sales			73,408				42,272				135,335				78,541
Realized loss on commodity derivatives			(3,320	)			(714	)			(4,659	)			(407	)
Total oil, NGL and gas sales including derivative impact		$	70,088			$	41,558			$	130,676			$	78,134
Production:
Oil (MBbls)			525				344				975				655
NGLs (MBbls)			370				227				665				440
Gas (MMcf)			2,348				1,477				4,282				2,855
Total (MBoe)			1,286				817				2,353				1,571
Total (MBoe/d)			14.1				9.0				13.0				8.7
Average prices:
Oil (per Bbl)		$	98.28			$	88.25			$	95.73			$	85.29
NGLs (per Bbl)			31.21				27.43				32.87				28.27
Gas (per Mcf)			4.38				3.84				4.71				3.59
Total (per Boe)		$	57.06			$	51.74			$	57.51			$	49.99
Realized loss on commodity derivatives (per Boe)			(2.58	)			(0.87	)			(1.99	)			(0.26	)
Total including derivative impact (per Boe)		$	54.48			$	50.87			$	55.52			$	49.73
Costs and expenses (per Boe):
Lease operating		$	6.18			$	4.89			$	6.71			$	5.97
Production and ad valorem taxes			3.83				3.76				3.86				3.58
Exploration			1.53				0.68				1.15				0.52
General and administrative			5.75				6.40				6.77				7.41
Depletion, depreciation and amortization			22.21				22.62				22.17				22.62

 

Glossary

Bbl. One stock tank barrel, of 42 U.S. gallons liquid volume, used herein to reference oil, condensate or NGLs.

Boe. Barrel of oil equivalent, determined using the ratio of six Mcf of gas to one Bbl of oil equivalent, and one Bbl of NGLs to one Bbl of oil equivalent.

MBbl. Thousand barrels of oil, condensate or NGLs.

MBoe. Thousand barrels of oil equivalent.

 

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Mcf. Thousand cubic feet of natural gas.

MMBoe. Million barrels of oil equivalent.

MMcf. Million cubic feet of natural gas.

NGLs. Natural gas liquids.

/d. “Per day” when used with volumetric units or dollars.

Three Months Ended June 30, 2014, Compared to Three Months Ended June 30, 2013

Oil, NGL and gas sales. Oil, NGL and gas sales increased $31.1 million, or 74%, for the three months ended June 30, 2014, to $73.4 million, from $42.3 million for the three months ended June 30, 2013. The increase in oil, NGL and gas sales was due to an increase in production volumes ($26 million) and an increase in average realized commodity prices ($5.1 million). Production volumes increased as a result of our continued development in Project Pangea.

Net income. Net income for the three months ended June 30, 2014, was $3.8 million, or $0.10 per diluted share, compared to net income of $7.8 million, or $0.20 per diluted share, for the three months ended June 30, 2013. Net income for the three months ended June 30, 2014, included an unrealized loss on commodity derivatives of $7.7 million and a realized loss on commodity derivatives of $3.3 million. Net income for the three months ended June 30, 2014, decreased due to losses on both our realized and unrealized commodity derivatives ($11 million), higher operating expenses as a result of increased production, and an increase in interest expense, partially offset by higher revenues ($31.1 million).

Oil, NGL and gas production. Production for the three months ended June 30, 2014, totaled 1,286 MBoe (14.1 MBoe/d), compared to production of 817 MBoe (9 MBoe/d) in the prior-year period, a 58% increase. Production for the three months ended June 30, 2014, was 41% oil, 29% NGLs and 30% gas, compared to 42% oil, 28% NGLs and 30% gas in the 2013 period. Production volumes increased during the three months ended June 30, 2014, as a result of our continued development in Project Pangea. We expect production to increase during 2014 due to our development project in the Permain Basin.

Commodity derivatives activities. Our commodity derivatives activity resulted in a realized loss of $3.3 million and $0.7 million for the three months ended June 30, 2014 and 2013, respectively. Our average realized price, including the effect of commodity derivatives, was $54.48 per Boe for the three months ended June 30, 2014, compared to $50.87 per Boe for the three months ended June 30, 2013. Realized gains and losses on commodity derivatives are derived from the relative movement of commodity prices in relation to the fixed pricing in our derivatives contracts for the respective periods. The unrealized loss on commodity derivatives for the three months ended June 30, 2014, was $7.7 million, compared to an unrealized gain of $4.3 million for the three months ended June 30, 2013. As commodity prices increase or decrease, the fair value of the open portion of those positions decreases or increases, respectively.

Historically, we have not designated our derivative instruments as cash-flow hedges. We record our open derivative instruments at fair value on our consolidated balance sheets as either unrealized gains or losses on commodity derivatives. We record changes in such fair value in net income on our consolidated statements of operations under the caption entitled “unrealized (loss) gain on commodity derivatives.”

Lease operating. Our lease operating expenses (“LOE”) increased $3.9 million, or 99%, for the three months ended June 30, 2014, to $7.9 million, or $6.18 per Boe, from $4 million, or $4.89 per Boe, for the three months ended June 30, 2013. The increase in LOE per BOE for the three months ended June 30, 2014, was primarily due to increases in water hauling, well repairs, workovers and maintenance, and compressor rental and repair, partially offset by a decrease in pumpers and supervision. The following table summarizes LOE per Boe.

 

		Three Months Ended June 30,
		2014				2013				Change				% Change
Well repairs, workovers and maintenance		$	1.86			$	1.23			$	0.63				51.2	%
Compressor rental and repair			1.73				1.58				0.15				9.5
Water hauling and other			1.67				1.00				0.67				67.0
Pumpers and supervision			0.92				1.08				(0.16	)			(14.8	)
Total		$	6.18			$	4.89			$	1.29				26.4	%

 

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Production and ad valorem taxes. Our production and ad valorem taxes increased $1.8 million, or 61%, for the three months ended June 30, 2014, to $4.9 million from $3.1 million for the three months ended June 30, 2013. The increase in production and ad valorem taxes was primarily due to the increase in oil, NGL and gas sales between the two periods. Production and ad valorem taxes were $3.83 per Boe and $3.76 per Boe and approximately 6.7% and 7.3% of oil, NGL and gas sales for the three months ended June 30, 2014 and 2013, respectively.

Exploration. We recorded $2 million, or $1.53 per Boe, and $0.6 million, or $0.68 per Boe, of exploration expense for the three months ended June 30, 2014 and 2013, respectively. Exploration expense for the respective periods resulted primarily from lease expirations and the acquisition of 3-D seismic data.

General and administrative. Our general and administrative expenses (“G&A”) increased $2.2 million, or 42%, to $7.4 million, or $5.75 per Boe, for the three months ended June 30, 2014, from $5.2 million, or $6.40 per Boe, for the three months ended June 30, 2013. The increase in G&A was primarily due to higher salaries and benefits resulting from increased staffing. The increase in G&A was partially offset by a decrease in share-based compensation due to the benefit of forfeited stock awards related to the retirement of one of our executive officers during the three months ended June 30, 2014. The following table summarizes G&A in millions and G&A per Boe.

 

		Three Months Ended June 30,
		2014								2013								Change
		$MM				Boe				$MM				Boe				$MM				Boe				% Change
Salaries and benefits		$	4.1			$	3.17			$	2.3			$	2.83			$	1.8			$	0.34				12.0	%
Share-based compensation			1.1				0.86				1.5				1.88				(0.4	)			(1.02	)			(54.3	)
Professional fees			0.5				0.39				0.1				0.12				0.4				0.27				225.0
Other			1.7				1.33				1.3				1.57				0.4				(0.24	)			(15.3	)
Total		$	7.4			$	5.75			$	5.2			$	6.40			$	2.2			$	(0.65	)			(10.2	)%

Depletion, depreciation and amortization. Our depletion, depreciation and amortization expense (“DD&A”) increased $10.1 million, or 55%, to $28.6 million for the three months ended June 30, 2014, from $18.5 million for the three months ended June 30, 2013. Our DD&A per Boe decreased by $0.41 per Boe, or 2%, to $22.21 per Boe for the three months ended June 30, 2014, compared to $22.62 per Boe for the three months ended June 30, 2013. The increase in DD&A expense over the prior-year period was primarily due to higher production. The decrease in DD&A per Boe over the prior-year period was primarily due to lower oil and gas property carrying costs relative to estimated proved developed reserves.

Interest expense, net. Our interest expense, net, increased $2.9 million, or 119%, to $5.4 million for the three months ended June 30, 2014, from $2.5 million for the three months ended June 30, 2013. This increase was primarily due to higher interest expense from the issuance of Senior Notes in June 2013, partially offset by lower average debt balance under our revolving credit facility (the “Credit Facility”). We expect our interest expense to remain higher than the prior-year period as a result of increased borrowings during 2014 as we continue to develop Project Pangea.

 

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Income taxes. Our income taxes were $2.2 million and $4.2 million for the three months ended June 30, 2014 and 2013, respectively. The decrease in income taxes was primarily due to a decrease in income before income taxes in the 2014 period. Our effective income tax rate for the three months ended June 30, 2014, was 36.2%, compared to 35.1% for the three months ended June 30, 2013.

Six Months Ended June 30, 2014, Compared to Six Months Ended June 30, 2013

Oil, NGL and gas sales. Oil, NGL and gas sales increased $56.8 million, or 72%, for the six months ended June 30, 2014, to $135.3 million, from $78.5 million for the six months ended June 30, 2013. The increase in oil, NGL and gas sales was due to an increase in production volumes ($44.7 million) and an increase in average realized commodity prices ($12.1 million). Production volumes increased as a result of our continued development in Project Pangea.

Net income. Net income for the six months ended June 30, 2014, was $6.7 million, or $0.17 per diluted share, compared to net income of $7.4 million, or $0.19 per diluted share, for the six months ended June 30, 2013. Net income for the six months ended June 30, 2014, included an unrealized loss on commodity derivatives of $13.6 million and a realized loss on commodity derivatives of $4.7 million. Net income for the six months ended June 30, 2014, decreased due to losses on both our realized and unrealized commodity derivatives ($18.3 million), higher operating expenses as a result of increased production, and an increase in interest expense, partially offset by higher revenues ($56.8 million).

Oil, NGL and gas production. Production for the six months ended June 30, 2014, totaled 2,353 MBoe (13.0 MBoe/d), compared to production of 1,571 MBoe (8.7 MBoe/d) in the prior-year period, a 50% increase. Production for the six months ended June 30, 2014 and 2013, was 42% oil, 28% NGLs and 30% gas. Production volumes increased during the six months ended June 30, 2014, as a result of our continued development in Project Pangea. We expect production to increase during 2014 due to our development project in the Permain Basin.

Commodity derivatives activities. Our commodity derivatives activity resulted in a realized loss of $4.7 million and $0.4 million for the six months ended June 30, 2014 and 2013, respectively. Our average realized price, including the effect of commodity derivatives, was $55.52 per Boe for the six months ended June 30, 2014, compared to $49.73 per Boe for the six months ended June 30, 2013. Realized gains and losses on commodity derivatives are derived from the relative movement of commodity prices in relation to the fixed pricing in our derivatives contracts for the respective periods. The unrealized loss on commodity derivatives was $13.6 million for the six months ended June 30, 2014, compared to an unrealized gain of $0.2 million for the six months ended June 30, 2013. As commodity prices increase or decrease, the fair value of the open portion of those positions decreases or increases, respectively.

Lease operating. Our LOE increased $6.4 million, or 69%, for the six months ended June 30, 2014, to $15.8 million, or $6.71 per Boe, from $9.4 million, or $5.97 per Boe, for the six months ended June 30, 2013. The increase in LOE per BOE for the six months ended June 30, 2014, was primarily due to an increase in well repairs, workovers and maintenance, compressor rental and repair, and water hauling, partially offset by decreases in pumpers and supervision. The following table summarizes LOE per Boe.

 

		Six Months Ended June 30,
		2014				2013				Change				% Change
Well repairs, workovers and maintenance		$	2.32			$	1.92			$	0.40				20.8	%
Compressor rental and repair			1.87				1.59				0.28				17.6
Water hauling and other			1.61				1.43				0.18				12.6
Pumpers and supervision			0.91				1.03				(0.12	)			(11.7	)
Total		$	6.71			$	5.97			$	0.74				12.4	%

 

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Production and ad valorem taxes. Our production and ad valorem taxes increased $3.5 million, or 62%, for the six months ended June 30, 2014, to $9.1 million from $5.6 million for the six months ended June 30, 2013. The increase in production and ad valorem taxes was primarily a function of the increase in oil, NGL and gas sales between the two periods. Production and ad valorem taxes were $3.86 per Boe and $3.58 per Boe and approximately 6.7% and 7.2% of oil, NGL and gas sales for the six months ended June 30, 2014 and 2013, respectively.

Exploration. We recorded $2.7 million, or $1.15 per Boe, and $0.8 million, or $0.52 per Boe, of exploration expense for the six months ended June 30, 2014 and 2013, respectively. Exploration expense for the respective periods resulted primarily from lease expirations and the acquisition of 3-D seismic data.

General and administrative. Our G&A increased $4.3 million, or 37%, to $15.9 million, or $6.77 per Boe, for the six months ended June 30, 2014, from $11.6 million, or $7.41 per Boe, for the six months ended June 30, 2013. The increase in G&A was primarily due to higher salaries and share-based compensation resulting from increased staffing. Share-based compensation remained consistent for the six months ended June 30, 2014 compared to the prior-year period due to the benefit of forfeited stock awards of $1.1 million related to the retirement of one of our executive officers during the six months ended June 30, 2014. The following table summarizes G&A in millions and G&A per Boe.

 

		Six Months Ended June 30,
		2014								2013								Change
		$MM				Boe				$MM				Boe				$MM				Boe				% Change
Salaries and benefits		$	7.6			$	3.22			$	4.6			$	2.93			$	3.0			$	0.29				9.9	%
Share-based compensation			3.8				1.60				3.8				2.41				0.0				(0.81	)			(33.6	)
Professional fees			1.2				0.51				0.5				0.31				0.7				0.20				64.5
Other			3.3				1.44				2.7				1.76				0.6				(0.32	)			(18.2	)
Total		$	15.9			$	6.77			$	11.6			$	7.41			$	4.3			$	(0.64	)			(8.6	)%

Depletion, depreciation and amortization. Our DD&A increased $16.7 million, or 47%, to $52.2 million for the six months ended June 30, 2014, from $35.5 million for the six months ended June 30, 2013. Our DD&A per Boe decreased by $0.45 per Boe, or 2%, to $22.17 per Boe for the six months ended June 30, 2014, compared to $22.62 per Boe for the six months ended June 30, 2013. The increase in DD&A expense over the prior-year period was primarily due to higher production. The decrease in DD&A per Boe over the prior-year period was primarily due to lower oil and gas property carrying costs relative to estimated proved developed reserves.

Interest expense, net. Our interest expense, net, increased $6.8 million, or 185%, to $10.5 million for the six months ended June 30, 2014, from $3.7 million for the six months ended June 30, 2013. This increase was primarily due to higher interest expense from the issuance of Senior Notes in June 2013, partially offset by lower average debt balance under our Credit Facility. We expect our interest expense to remain higher than the prior-year period as a result of increased borrowings during 2014 as we continue to develop Project Pangea.

 

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Income taxes. Our income taxes were $3.8 million and $4 million for the six months ended June 30, 2014 and 2013, respectively. The decrease in income taxes was primarily due to a decrease in income before income taxes in the 2014 period. Our effective income tax rate for the six months ended June 30, 2014, was 36.3%, compared to 35.1% for the six months ended June 30, 2013.

Liquidity and Capital Resources

We generally will rely on cash generated from operations, borrowings under our Credit Facility and, to the extent that credit and capital market conditions will allow, future public equity and debt offerings to satisfy our liquidity needs. Our ability to fund planned capital expenditures and to make acquisitions depends upon our future operating performance, availability of borrowings under our Credit Facility, and more broadly, on the availability of equity and debt financing, which is affected by prevailing economic conditions in our industry and financial, business and other factors, some of which are beyond our control. We cannot predict whether additional liquidity from equity or debt financings beyond our Credit Facility will be available on acceptable terms, or at all, in the foreseeable future.

Our cash flow from operations is driven by commodity prices, production volumes and the effect of commodity derivatives. Commodity prices are affected by national and international economic and political environments, national and global supply and demand for hydrocarbons, seasonal influences of weather and other factors beyond our control. Cash flows from operations are primarily used to fund development of our oil and gas properties.

We believe we have adequate liquidity from cash generated from operations and unused borrowing capacity under our Credit Facility for current working capital needs and maintenance of our current development project. However, we may determine to use various financing sources, including the issuance of common stock, preferred stock, debt, convertible securities and other securities for future development of reserves, acquisitions, additional working capital or other liquidity needs, if such financing is available on acceptable terms. We cannot guarantee that such financing will be available on acceptable terms or at all. Using some of these financing sources may require approval from the lenders under our Credit Facility.

Liquidity

We define liquidity as funds available under our Credit Facility, cash and cash equivalents. At June 30, 2014, and December 31, 2013, we had $46 million and no outstanding borrowings under our Credit Facility and liquidity of $404.1 million and $408.4 million, respectively. The table below summarizes our liquidity position at June 30, 2014, and December 31, 2013 (dollars in thousands).

 

		Liquidity at June 30,				Liquidity at December 31,
		2014				2013
Borrowing base		$	450,000			$	350,000
Cash and cash equivalents			444				58,761
Long-term debt – Credit Facility			(46,000	)			—
Undrawn letters of credit			(325	)			(325	)
Liquidity		$	404,119			$	408,436

 

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In May 2014, we entered into an amended and restated $1 billion Credit Facility with an initial borrowing base of $450 million. Additional information regarding the Credit Facility is included in Note 4. “Long-Term Debt.”

Working Capital

Our working capital is affected primarily by our cash and cash equivalents balance and our capital spending program. We had a working capital deficit of $69 million at June 30, 2014, compared to a working capital surplus of $6 million at December 31, 2013. The primary reason for the change in working capital was an increase in accrued liabilities, and a decrease in our cash balance due to an increase in our capital expenditures. To the extent we operate, or end fiscal year 2014, with a working capital deficit, we expect such deficit to be more than offset by liquidity available under our Credit Facility.

Cash Flows

The following table summarizes our sources and uses of funds for the periods noted (in thousands).

 

		Six Months Ended June 30,
		2014				2013
Cash flows provided by operating activities		$	85,688			$	44,839
Cash flows used in investing activities			(187,778	)			(126,183	)
Cash flows provided by financing activities			43,773				135,855
Net (decrease) increase in cash and cash equivalents		$	(58,317	)		$	54,511

Operating Activities

Cash flows provided by operating activities increased by 91%, or $40.8 million, to $85.7 million during the six months ended June 30, 2014, compared to the prior-year period. The increase in our cash flows provided by operating activities was primarily due to an increase in oil, NGL and gas sales from higher production and the timing of payments and receipts of working capital components, partially offset by an increase in total expenses.

Investing Activities

Cash flows used in investing activities increased by $61.6 million for the six months ended June 30, 2014, to $187.8 million, compared to the prior-year period. Our capital expenditures for the six months ended June 30, 2014, were primarily attributable to drilling and development ($182.9 million), infrastructure projects and equipment ($9.9 million) and acreage acquisitions and extensions ($2.9 million). Additionally, $7.4 million in restricted cash was released from escrow related to the sale of our interest in the Wildcat pipeline, offset by $0.2 million in post-closing working capital adjustments related to the sale. During the six months ended June 30, 2014, we drilled a total of 32 horizontal wells and completed 35 horizontal wells in Project Pangea.

Financing Activities

During the six months ended June 30, 2014, cash flows provided by financing activities decreased by $92.1 million, compared to the prior-year period. We had $46 million of outstanding borrowings under our Credit Facility at June 30, 2014. During the six months ended June 30, 2014, net cash flows provided by financing activities included borrowings under our Credit Facility of $114.4 million that were partially offset by repayments of outstanding borrowings under our Credit Facility of $68.4 million. This compares

 

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to the six months ended June 30, 2013, when we had net cash flows provided by financing activities that primarily included borrowings under our Credit Facility of $130 million and net proceeds from our offering of the Senior Notes of $243 million that were partially offset by repayments of outstanding borrowings under our Credit Facility of $236 million.

Credit Facility

At June 30, 2014, the borrowing base under our Credit Facility was $450 million, with maximum commitments from the lenders of $1 billion and a maturity date of May 7, 2019. We had outstanding borrowings of $46 million under our Credit Facility at June 30, 2014, compared to no outstanding borrowings at December 31, 2013. The weighted average interest rate applicable to borrowings under our credit facility for the six months ended June 30, 2014, was 2%. Additional information regarding our credit arrangements is included in Note 4. “Long-Term Debt.”

To date, we have experienced no disruptions in our ability to access our Credit Facility. However, our lenders have substantial ability to reduce our borrowing base on the basis of subjective factors, including the loan collateral value that each lender, in its discretion and using the methodology, assumptions and discount rates as such lender customarily uses in evaluating oil and gas properties, assigns to our properties.

Contractual Obligations

Our contractual obligations include long-term debt, daywork drilling contracts, operating lease obligations, asset retirement obligations and employment agreements with our executive officers. On January 3, 2014, we entered into an employment agreement with Sergei Krylov as the Company’s Executive Vice President and Chief Financial Officer. Our maximum commitment under Mr. Krylov’s employment agreement, which would apply if Mr. Krylov were terminated without cause, is $1.3 million. Since December 31, 2013, there have been no other material changes to our contractual obligations. In August 2014, we extended our existing gas purchase and processing agreement with DCP Midstream, LP through August 2023.

Off-Balance Sheet Arrangements

From time to time, we enter into off-balance sheet arrangements and transactions that can give rise to off-balance sheet obligations. As of June 30, 2014, the off-balance sheet arrangements and transactions that we have entered into include undrawn letters of credit and operating lease agreements. We do not believe that these arrangements have or are reasonably likely to have a current or future material effect on our financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.

General Trends and Outlook

Our financial results depend upon many factors, particularly the price of oil and gas. Commodity prices are affected by changes in market demand, which is impacted by domestic and foreign supply of oil and gas, overall domestic and global economic conditions, commodity processing, gathering and transportation availability and the availability of refining capacity, price and availability of alternative fuels, price and quantity of foreign imports, domestic and foreign governmental regulations, political conditions in or affecting other gas producing and oil producing countries, weather and technological advances affecting oil and gas consumption. As a result, we cannot accurately predict future oil and gas prices, and therefore, we cannot determine what effect increases or decreases will have on our capital program, production volumes and future revenues. A substantial or extended decline in oil and gas prices could have a material adverse effect on our business, financial condition, results of operations, quantities of oil and gas reserves that may be economically produced and liquidity that may be accessed through our borrowing base under our Credit Facility and through capital markets.

 

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In addition to production volumes and commodity prices, finding and developing sufficient amounts of oil and gas reserves at economical costs are critical to our long-term success. Future finding and development costs are subject to changes in the industry, including the costs of acquiring, drilling and completing our projects. We focus our efforts on increasing oil and gas reserves and production while controlling costs at a level that is appropriate for long-term operations. Our future cash flow from operations will depend on our ability to manage our overall cost structure.

Like all oil and gas production companies, we face the challenge of natural production declines. Oil and gas production from a given well naturally decreases over time. Additionally, our reserves have a rapid initial decline. We attempt to overcome this natural decline by drilling to develop and identify additional reserves, farm-ins or other joint drilling ventures, and by acquisitions. However, during times of severe price declines, we may from time to time reduce current capital expenditures and curtail drilling operations in order to preserve liquidity. A material reduction in capital expenditures and drilling activities could materially reduce our production volumes and revenues and increase future expected costs necessary to develop existing reserves.

We also face the challenge of financing exploration, development and future acquisitions. We believe we have adequate liquidity from cash generated from operations and unused borrowing capacity under our Credit Facility for current working capital needs and maintenance of our current development project. However, we may determine to use various financing sources, including the issuance of common stock, preferred stock, debt, convertible securities and other securities for future development of reserves, acquisitions, additional working capital or other liquidity needs, if such financing is available on acceptable terms. We cannot guarantee that such financing will be available on acceptable terms or at all. Using some of these financing sources may require approval from the lenders under our Credit Facility.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

Some of the information below contains forward-looking statements. The primary objective of the following information is to provide forward-looking quantitative and qualitative information about our potential exposure to market risks. The term “market risk” refers to the risk of loss arising from adverse changes in oil and gas prices, and other related factors. The disclosure is not meant to be a precise indicator of expected future losses, but rather an indicator of reasonably possible losses. This forward-looking information provides an indicator of how we view and manage our ongoing market risk exposures. Our market risk sensitive instruments were entered into for commodity derivative and investment purposes, not for trading purposes.

Commodity Price Risk

Given the current economic outlook, we expect commodity prices to remain volatile. Even modest decreases in commodity prices can materially affect our revenues and cash flow. In addition, if commodity prices remain suppressed for a significant amount of time, we could be required under successful efforts accounting rules to perform a write down of our oil and gas properties.

We enter into financial swaps and options to reduce the risk of commodity price fluctuations. We do not designate such instruments as cash flow hedges. Accordingly, we record open commodity derivative positions on our consolidated balance sheets at fair value and recognize changes in such fair values as other income (expense) on our consolidated statements of operations as they occur.

 

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The following table provides our outstanding commodity derivative positions at June 30, 2014.

 

Commodity and Period		Contract Type		Volume Transacted		Contract Price
Crude Oil
July 2014 – December 2014		Collar		550 Bbls/d		$90.00/Bbl - $105.50/Bbl
July 2014 – December 2014		Collar		950 Bbls/d		$85.05/Bbl - $95.05/Bbl
July 2014 – December 2014		Collar		2,000 Bbls/d		$89.00/Bbl - $98.85/Bbl
July 2014 – March 2015		Collar		1,500 Bbls/d		$85.00/Bbl - $95.30/Bbl
January 2015 – December 2015		Collar		2,600 Bbls/d		$84.00/Bbl - $91.00/Bbl
Natural Gas Liquids
Propane
July 2014 – December 2014		Swap		500 Bbls/d		$41.16/Bbl
Natural Gasoline
July 2014 – December 2014		Swap		175 Bbls/d		$83.37/Bbl
Natural Gas
July 2014 – December 2014		Swap		360,000 MMBtu/month		$4.18/MMBtu
July 2014 – December 2014		Swap		35,000 MMBtu/month		$4.29/MMBtu
July 2014 – December 2014		Swap		160,000 MMBtu/month		$4.40/MMBtu
September 2014 – June 2015		Collar		80,000 MMBtu/month		$4.00/MMBtu - $4.74/MMBtu
January 2015 – December 2015		Swap		200,000 MMBtu/month		$4.10/MMBtu
January 2015 – December 2015		Collar		130,000 MMBtu/month		$4.00/MMBtu - $4.25/MMBtu

Subsequent to June 30, 2014, we entered into two crude oil collars covering a total of 1,000 Bbls per day for 2015 at a floor price of $90.00/Bbl and a ceiling price of $102.50/Bbl.

At June 30, 2014, the fair value of our open derivative contracts was a net liability of $15.8 million, compared to a net liability of $2.2 million at December 31, 2013.

JPMorgan Chase Bank, N.A. and KeyBank National Association are currently the only counterparties to our commodity derivatives positions. We are exposed to credit losses in the event of nonperformance by counterparties on our commodity derivatives positions. However, we do not anticipate nonperformance by the counterparties over the term of the commodity derivatives positions. JPMorgan is the administrative agent and a participant, and KeyBank is the documentation agent and a participant, in our Credit Facility, and the collateral for the outstanding borrowings under our Credit Facility is used as collateral for our commodity derivatives.

Unrealized gains and losses, at fair value, are included on our consolidated balance sheets as current or non-current assets or liabilities based on the anticipated timing of cash settlements under the related contracts. Changes in the fair value of our commodity derivative contracts are recorded in earnings as they occur and included in other income (expense) on our consolidated statements of operations. We estimate the fair values of swap contracts based on the present value of the difference in exchange-quoted forward price curves and contractual settlement prices multiplied by notional quantities. We internally valued the option contracts using industry-standard option pricing models and observable market inputs. We use our internal valuations to determine the fair values of the contracts that are reflected on our consolidated balance sheets. Realized gains and losses are also included in other income (expense) on our consolidated statements of operations.

 

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For the six months ended June 30, 2014, we recorded an unrealized loss on commodity derivatives of $13.6 million from the change in fair value of our commodity derivatives positions, compared to an unrealized gain of $0.2 million for the six months ended June 30, 2013. A hypothetical 10% increase in commodity prices would have resulted in a $20.3 million decrease in the fair value of our commodity derivative positions recorded on our balance sheet at June 30, 2014, and a corresponding increase in the unrealized loss on commodity derivatives recorded on our consolidated statement of operations for the six months ended June 30, 2014.

Item 4. Controls and Procedures.

Evaluation of Disclosure Controls and Procedures

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in the reports we file under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. Such controls include those designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is accumulated and communicated to management, including the President and Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”), as appropriate, to allow timely decisions regarding required disclosure.

Our management, with the participation of our CEO and CFO, has evaluated the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) promulgated under the Exchange Act) as of June 30, 2014. Based on this evaluation, the CEO and CFO have concluded that, as of June 30, 2014, our disclosure controls and procedures were effective, in that they ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is (1) recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and (2) accumulated and communicated to our management, including our CEO and CFO, as appropriate to allow timely decisions regarding required disclosure.

Internal Control over Financial Reporting

There were no changes made in our internal control over financial reporting (as defined in Rule 13a-15(f) promulgated under the Exchange Act) during the three months ended June 30, 2014, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Limitations Inherent in All Controls

Our management, including the CEO and CFO, recognizes that the disclosure controls and procedures and internal controls (discussed above) cannot prevent all errors or all attempts at fraud. Any controls system, no matter how well-crafted and operated, can only provide reasonable, and not absolute, assurance of achieving the desired control objectives. Because of the inherent limitations in any control system, no evaluation or implementation of a control system can provide complete assurance that all control issues and all possible instances of fraud have been or will be detected.

 

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PART II—OTHER INFORMATION

Item 1. Legal Proceedings.

There have been no material developments in the legal proceedings described in Part I, Item 3. “Legal Proceedings” of our Annual Report on Form 10-K for the year ended December 31, 2013, filed with the SEC on February 25, 2014.

Item 1A. Risk Factors.

In addition to the other information set forth in this report, you should carefully consider the risks discussed in the following report that we have filed with the SEC, which risks could materially affect our business, financial condition and results of operations: Annual Report on Form 10-K for the year ended December 31, 2013, under the headings Item 1. “Business – Markets and Customers; Competition; and Regulation,” Item 1A. “Risk Factors,” Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations – General Trends and Outlook” and Item 7A. “Quantitative and Qualitative Disclosures about Market Risk” filed with the SEC on February 25, 2014.

There have been no material changes to the risk factors discussed in our Annual Report on Form 10-K for the year ended December 31, 2013, filed with the SEC on February 25, 2014, which is accessible on the SEC’s website at www.sec.gov and our website at www.approachresources.com.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

The following table provides information relating to our purchase of shares of our common stock during the three months ended June 30, 2014. The repurchases reflect shares withheld upon vesting of restricted stock under our 2007 Stock Incentive Plan to satisfy statutory minimum tax withholding obligations.

ISSUER PURCHASES OF EQUITY SECURITIES

 

Period		(a) Total Number of Shares Purchased				(b) Average Price Paid Per Share				(c) Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs				(d) Maximum Number of Shares that May Yet Be Purchased Under the Plans or Programs
Month #1 April 1, 2014 – April 30, 2014			67			$	21.54				—				—
Month #2 May 1, 2014 – May 31, 2014			1,794				19.85				—				—
Month #3 June 1, 2014 – June 30, 2014			—				—				—				—
Total			1,861			$	19.92				—				—

Item 6. Exhibits.

See “Index to Exhibits” following the signature page of this report for a description of the exhibits furnished as part of this report.

 

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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.

 

				APPROACH RESOURCES INC.
Date: August 5, 2014				By:		/s/ J. Ross Craft
						J. Ross Craft
						President and Chief Executive Officer (Principal Executive Officer)
Date: August 5, 2014				By:		/s/ Sergei Krylov
						Sergei Krylov
						Executive Vice President and Chief Financial Officer (Principal Financial Officer)

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Index to Exhibits

 

Exhibit Number		Description of Exhibit
3.1		Restated Certificate of Incorporation of Approach Resources Inc. (filed as Exhibit 3.1 to the Company’s Quarterly Report on Form 10-Q filed December 13, 2007, and incorporated herein by reference).
3.2		Second Amended and Restated Bylaws of Approach Resources Inc., effective November 6, 2013 (filed as Exhibit 3.2 to the Company’s Current Report on Form 8-K filed November 8, 2013, and incorporated herein by reference).
4.1		Specimen Common Stock Certificate (filed as Exhibit 4.1 to the Company’s Registration Statement on Form S-1/A filed October 18, 2007 (File No. 333-144512), and incorporated herein by reference).
4.2		Senior Indenture, dated as of June 11, 2013, among Approach Resources Inc., as issuer, the subsidiary guarantors named therein, as guarantors, and Wells Fargo Bank, National Association, as trustee (filed as Exhibit 4.1 to the Company’s Current Report on Form 8-K filed June 11, 2013, and incorporated herein by reference).
4.3		First Supplemental Indenture, dated as of June 11, 2013, among Approach Resources Inc., as issuer, the subsidiary guarantors named therein, as guarantors, and Wells Fargo Bank, National Association, as trustee (filed as Exhibit 4.2 to the Company’s Current Report on Form 8-K filed June 11, 2013, and incorporated herein by reference).
*10.1†		Separation Agreement by and between Approach Resources Inc. and Ralph P. Manoushagian dated May 12, 2014.
10.2		Amended and Restated Credit Agreement, dated as of May 7, 2014, among Approach Resources Inc., as Borrower, JPMorgan Chase Bank, N.A., as administrative agent and KeyBank National Association, as Documentation Agent, and the lenders from time-to-time party thereto, and Approach Oil & Gas Inc., Approach Resources I, LP, Approach Operating, LLC, Approach Delaware, LLC, Approach Services, LLC and Approach Midstream Holdings LLC, as guarantors (filed as Exhibit 10.1 to the Company’s Current Report on Form 8-K filed May 8, 2014, and incorporated herein by reference).
10.3		Amended and Restated Guaranty and Pledge Agreement, dated as of May 7, 2014, by and among the Company, the subsidiary guarantors and JPMorgan Chase Bank, N.A., as Administrative Agent (filed as Exhibit 10.2 to the Company’s Current Report on Form 8-K filed May 8, 2014, and incorporated herein by reference).
*31.1		Certification by the President and Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*31.2		Certification by the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*32.1		Certification by the President and Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*32.2		Certification by the Chief Financial Officer Pursuant to U.S.C. Section 1350, as adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*101.INS		XBRL Instance Document.
*101.SCH		XBRL Taxonomy Extension Schema Document.
*101.CAL		XBRL Taxonomy Extension Calculation Linkbase Document.
*101.LAB		XBRL Taxonomy Extension Label Linkbase Document.
*101.PRE		XBRL Taxonomy Extension Presentation Linkbase Document.
*101.DEF		XBRL Taxonomy Extension Definition Linkbase Document.

 

*	Filed herewith.

†	Denotes management contract