FORT WORTH, Texas, Nov. 01, 2017 (GLOBE NEWSWIRE) -- Approach Resources Inc. (NASDAQ:AREX) today reported third quarter 2017 financial and operational results and a bolt-on acquisition.

Third Quarter 2017 Highlights

• Produced 11.5 MBoe/d, despite negative impact of 500 Boe/d from Hurricane Harvey
• Strong well results from two new completions, outperforming a 700 MBoe type curve
• Net loss was $8.5 million or $0.10 per diluted share. Adjusted net loss (non-GAAP) was $6.5 million, or $0.08 per diluted share
• EBITDAX (non-GAAP) was $13.8 million, a 7% increase over the prior quarter
• Revenues of $25.6 million, a 3% increase over the prior quarter
• Unhedged cash margin (non-GAAP) of $13.52 per Boe, up 13% from second quarter

Bolt-On Acquisition

• Producing Wolfcamp shale assets adjacent to Company’s Project Pangea acreage
• Current production of approximately 550 Boe/d, 51% oil
• Estimated PDP reserves 1.8 MBoe, 42% oil
• Transaction value $18 million, payable in Approach common shares

Adjusted net loss, EBITDAX and unhedged cash margin are non-GAAP measures. See “Supplemental Non-GAAP financial and Other Measures” below for our definitions and reconciliations of adjusted net loss and EBITDAX to net loss and unhedged cash margin to revenues.

Management Comment

Ross Craft, Approach’s Chairman and CEO, commented, “Results for this quarter highlight our relentless focus on operational efficiency, cost controls and capital discipline. Our infrastructure system provided operational flexibility in the face of Hurricane Harvey and the results of our optimized completions are driving strong well performance. Due to our continued focus on cash operating expenses and improved realized prices, EBITDAX is up 7% over prior quarter and unhedged cash margin per Boe has increased 13% quarter over quarter and from the prior period last year.

We also are excited to announce an acquisition of producing properties that are complementary to our existing assets, and are pleased to welcome an experienced, upstream E&P investor like Kayne Anderson as a shareholder. As operators in the Permian work to consolidate acreage, we believe our large, contiguous acreage position provides the foundation for future growth as we continue to build value through prudent capital spending and one of the lowest operating cost structures in the Permian Basin.”

Third quarter 2017 Results

Production for third quarter 2017 totaled 1,061 Mboe, or 11.5 MBoe/d, made up of 26% oil, 35% NGLs and 39% natural gas. Average realized commodity prices for third quarter 2017, before the effect of commodity derivatives, were $44.91 per Bbl of oil, $18.96 per Bbl of NGLs and $2.46 per Mcf of natural gas. Our average realized price, including the effect of commodity derivatives, was $23.65 per Boe for third quarter 2017.

Net loss for third quarter 2017 was $8.5 million, or $0.10 per diluted share, on revenues of $25.6 million. Excluding the unrealized loss on commodity derivatives of $3.0 million, adjusted net loss (non-GAAP) for third quarter 2017 was $6.5 million, or $0.08 per diluted share. EBITDAX (non-GAAP) for third quarter 2017 was $13.8 million. See “Supplemental Non-GAAP Financial and Other Measures” below for our reconciliation of adjusted net loss and EBITDAX to net loss.

Lease operating expenses averaged $4.16 per Boe. Production and ad valorem taxes averaged $1.71 per Boe, or 7.1% of oil, NGL and gas sales. Exploration costs were $0.09 per Boe. Total general and administrative (“G&A”) costs averaged $6.00 per Boe, including cash G&A costs of $4.75 per Boe. Depletion, depreciation and amortization expense averaged $15.88 per Boe. Interest expense totaled $5.3 million.

Operations Update

During third quarter 2017, we drilled one horizontal well in the Wolfcamp B bench and completed two horizontal wells: one well in the Wolfcamp B bench and one well in the Wolfcamp C bench. The two wells completed in third quarter 2017, when normalized to a 7,500 feet lateral, are outperforming a 700 MBoe type curve. At September 30, 2017, we had nine horizontal wells waiting on completion.

Capital expenditures incurred during third quarter 2017 totaled $7.9 million and included $7.1 million for drilling and completion activities, $0.6 million for infrastructure projects and equipment and $0.2 million for acreage extensions. Aligning capital expenditures as closely as possible with cash flows, we elected to defer completion of additional wells until first quarter 2018.

Bolt-On Acquisition

The Company has entered into a definitive agreement with Amistad Energy Partners, LLC (“Amistad”) to acquire complementary Wolfcamp shale assets directly adjacent to the Company’s Pangea West project in the Southern Midland Basin, for 7,573,215 shares of Company common stock valued at $18.05 million, based on a 20-day volume weighted average share price, and subject to customary purchase price adjustments. The transaction is subject to customary closing conditions, and the Company expects the acquisition will close in the fourth quarter of 2017, with an effective date of September 1, 2017. Amistad is a portfolio company of Kayne Anderson Capital Advisors, L.P., an independent alternative investment management firm with $24.5 billion in assets focused on investing in upstream oil and gas companies, energy infrastructure, specialized real estate, middle market credit and growth private equity.

The transaction includes current net production of approximately 550 Boe/d (51% oil), estimated PDP reserves of approximately 1.8 MMboe (42% oil), approximately 3,200 net acres held by production, along with existing field infrastructure and facilities and over 35,000 of additional net undeveloped acres that are subject to near-term expiration if a continuous drilling obligation is not met or extended.

Liquidity Update

At September 30, 2017, we had a $1 billion revolving credit facility in place, with a borrowing base and lender commitment amount of $325 million, and liquidity of $32.7 million. The Company currently is in the process of completing its semi-annual borrowing base redetermination. The lead bank under our credit facility has recommended to the other lenders that our borrowing base be maintained at the current level of $325 million. However, there is no assurance that the borrowing base will not be higher or lower than our $325 million borrowing base as of September 30, 2017. See “Supplemental Non-GAAP Financial and Other Measures” below for our definition and calculation of liquidity.

Commodity Derivatives Update

We enter into commodity derivatives positions to reduce the risk of commodity price fluctuations. The table below is a summary of our current derivatives positions.

Commodity and Period		Contract Type		Volume Transacted		Contract Price
Crude Oil
October 2017 – December 2017		Swap		1,000 Bbls/day		$50.20/Bbl
October 2017 – December 2017		Swap		1,500 Bbls/day		$50.25/Bbl
January 2018 – December 2018		Swap		300 Bbls/day		$50.00/Bbl
January 2018 – March 2018		Collar		1,000 Bbls/day		$50.00/Bbl - $55.05/Bbl
Natural Gas
October 2017 – December 2017		Collar		100,000 MMBtu/month		$3.00/MMBtu - $3.65/MMBtu
October 2017 – December 2017		Collar		200,000 MMBtu/month		$2.30/MMBtu - $2.60/MMBtu
October 2017 – December 2017		Collar		200,000 MMBtu/month		$3.00/MMBtu - $3.44/MMBtu
October 2017 – December 2017		Collar		200,000 MMBtu/month		$3.00/MMBtu - $3.50/MMBtu
January 2018 – December 2018		Swap		200,000 MMBtu/month		$3.085/MMBtu
January 2018 – December 2018		Swap		250,000 MMBtu/month		$3.084/MMBtu
NGLs (C2 - Ethane)
October 2017 – December 2017		Swap		1,050 Bbls/day		$11.34/Bbl
NGLs (C3 - Propane)
October 2017 – December 2017		Swap		750 Bbls/day		$27.916/Bbl
October 2017 – March 2018		Swap		450 Bbls/day		$30.24/Bbl
NGLs (IC4 - Isobutane)
October 2017 – December 2017		Swap		75 Bbls/day		$36.7325/Bbl
October 2017 – March 2018		Swap		50 Bbls/day		$36.12/Bbl
NGLs (NC4 - Butane)
October 2017 – December 2017		Swap		250 Bbls/day		$35.9205/Bbl
October 2017 – March 2018		Swap		150 Bbls/day		$35.70/Bbl
NGLs (C5 - Pentane)
November 2017 – December 2017		Swap		250 Bbls/day		$50.61/Bbl

Conference Call Information and Summary Presentation

The Company will host a conference call on Thursday, November 2, 2017, at 10:00 AM CT (11:00 AM ET) to discuss third quarter 2017 financial and operating results.

Those wishing to listen to the conference call, may do so by visiting the Events and Presentations page under the Investor Relations section of the Company’s website, www.approachresources.com, or by phone:

Conference ID	93356938
Participant Toll-Free Dial-In Number:	(844) 884-9950
Participant International Dial-In Number:	(661) 378-9660
A replay of the call will be available on the Company’s website or by dialing:
Replay Toll-Free	(855) 859-2056
Replay International:	(404) 537-3406
Conference ID:	93356938

In addition, a third quarter 2017 summary presentation will be available on the Company’s website.

About Approach Resources

Approach Resources Inc. is an independent energy company focused on the exploration, development, production and acquisition of unconventional oil and natural gas reserves in the Midland Basin of the greater Permian Basin in West Texas. For more information about the Company, please visit www.approachresources.com. Please note that the Company routinely posts important information about the Company under the Investor Relations section of its website.

This press release contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the Company expects, believes or anticipates will or may occur in the future are forward-looking statements. Without limiting the generality of the foregoing, forward-looking statements contained in this press release specifically include expectations of anticipated financial and operating results and closing of the announced acquisition. These statements are based on certain assumptions made by the Company based on management’s experience, perception of historical trends and technical analyses, current conditions, anticipated future developments and other factors believed to be appropriate and reasonable by management. When used in this press release, the words “will,” “potential,” “believe,” “estimate,” “intend,” “expect,” “may,” “should,” “anticipate,” “could,” “plan,” “predict,” “project,” “profile,” “model” 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. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, which may cause actual results to differ materially from those implied or expressed by the forward-looking statements. Further information on such assumptions, risks and uncertainties is available in the Company’s Securities and Exchange Commission (“SEC”) filings. The Company’s SEC filings are available on the Company’s website at www.approachresources.com. Any forward-looking statement speaks only as of the date on which such statement is made and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law.

UNAUDITED RESULTS OF OPERATIONS
		Three Months Ended								Nine Months Ended
		September 30,								September 30,
		2017				2016				2017				2016
Revenues (in thousands):
Oil		$	12,464			$	12,061			$	38,666			$	34,304
NGLs			7,093				5,242				19,172				13,963
Gas			6,051				6,446				19,094				15,530
Total oil, NGLs and gas sales			25,608				23,749				76,932				63,797
Realized (loss) gain on commodity derivatives			(523	)			781				(1,481	)			5,690
Total oil, NGLs and gas sales including derivative impact		$	25,085			$	24,530			$	75,451			$	69,487
Production:
Oil (MBbls)			278				298				837				970
NGLs (MBbls)			374				394				1,109				1,149
Gas (MMcf)			2,455				2,556				7,331				7,873
Total (MBoe)			1,061				1,117				3,168				3,431
Total (MBoe/d)			11.5				12.1				11.6				12.5
Average prices:
Oil (per Bbl)		$	44.91			$	40.53			$	46.19			$	35.36
NGLs (per Bbl)			18.96				13.32				17.28				12.16
Gas (per Mcf)			2.46				2.52				2.60				1.97
Total (per Boe)			24.14				21.26				24.28				18.59
Realized (loss) gain on commodity derivatives (per Boe)			(0.49	)			0.70				(0.47	)			1.66
Total including derivative impact (per Boe)		$	23.65			$	21.96			$	23.81			$	20.25
Costs and expenses (per Boe):
Lease operating		$	4.16			$	3.49			$	4.05			$	4.51
Production and ad valorem taxes			1.71				1.80				2.03				1.61
Exploration			0.09				0.94				1.03				0.94
General and administrative (1)			6.00				5.21				5.95				5.16
Depletion, depreciation and amortization			15.88				17.38				17.15				17.38
(1) Below is a summary of general and administrative expense:
General and administrative - cash component		$	4.75			$	4.00			$	4.84			$	3.91
General and administrative - noncash component (share-based compensation)			1.25				1.21				1.11				1.25

APPROACH RESOURCES INC. AND SUBSIDIARIES
UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except shares and per-share amounts)
	Three Months Ended September 30,								Nine Months Ended September 30,
	2017				2016				2017				2016
REVENUES:
Oil, NGLs and gas sales	$	25,608			$	23,749			$	76,932			$	63,797
EXPENSES:
Lease operating		4,418				3,894				12,826				15,484
Production and ad valorem taxes		1,816				2,013				6,425				5,532
Exploration		100				1,047				3,251				3,238
General and administrative (1)		6,366				5,825				18,842				17,708
Depletion, depreciation and amortization		16,843				19,422				54,348				59,642
Total expenses		29,543				32,201				95,692				101,604
OPERATING LOSS		(3,935	)			(8,452	)			(18,760	)			(37,807	)
OTHER:
Interest expense, net		(5,304	)			(7,067	)			(15,683	)			(20,173	)
Gain on debt extinguishment		—				—				5,053				—
Write-off of debt issuance costs		—				—				—				(563	)
Realized (loss) gain on commodity derivatives		(523	)			781				(1,481	)			5,690
Unrealized (loss) gain on commodity derivatives		(3,037	)			760				2,596				(8,273	)
Other income		29				(10	)			32				1,511
LOSS BEFORE INCOME TAX (BENEFIT) PROVISION		(12,770	)			(13,988	)			(28,243	)			(59,615	)
INCOME TAX (BENEFIT) PROVISION		(4,258	)			(4,915	)			129,933				(20,847	)
NET LOSS	$	(8,512	)		$	(9,073	)		$	(158,176	)		$	(38,768	)
LOSS PER SHARE:
Basic	$	(0.10	)		$	(0.22	)		$	(1.95	)		$	(0.94	)
Diluted	$	(0.10	)		$	(0.22	)		$	(1.95	)		$	(0.94	)
WEIGHTED AVERAGE SHARES OUTSTANDING:
Basic		86,501,242				41,610,083				81,142,672				41,415,260
Diluted		86,501,242				41,610,083				81,142,672				41,415,260
(1) Includes non-cash share-based compensation expense as follows:		1,330				1,357				3,518				4,281

Unaudited Consolidated Balance Sheet Data		September 30,				December 31,
(in thousands)		2017				2016
Cash and cash equivalents		$	21			$	21
Other Current assets			11,982			$	12,473.00
Property and equipment, net, successful efforts method			1,080,611				1,092,061
Other non-current assets			2,360				—
Total assets		$	1,094,974			$	1,104,555
Current liabilities		$	29,148			$	26,369
Long-term debt (1)			375,210				498,349
Deferred income taxes			135,614				5,615
Other long-term liabilities			11,868				11,270
Stockholders' equity			543,134				562,952
Total liabilities and stockholders’ equity		$	1,094,974			$	1,104,555
(1) Long-term debt at September 30, 2017, is comprised of $85.2 million in 7% senior notes due 2021 and $292 million in outstanding borrowings under our revolving credit facility, net of issuance costs of $1.1 million and $0.9 million, respectively. Long-term debt at December 31, 2016, is comprised of $230.3 million in 7% senior notes due 2021 and $273 million in outstanding borrowings under our revolving credit facility, net of issuance costs of $3.7 million and $1.3 million, respectively.

Supplemental Non-GAAP Financial and Other Measures

This release contains certain financial measures that are non-GAAP measures. We have provided reconciliations below of the non-GAAP financial measures to the most directly comparable GAAP financial measures and on the Non-GAAP Financial Information page in the Investor Relations section of our website at www.approachresources.com.

Adjusted Net Loss

This release contains the non-GAAP financial measures adjusted net loss and adjusted net loss per diluted share, which exclude (1) unrealized loss (gain) on commodity derivatives, (2) gain on debt extinguishment, (3) write-off of debt issuance costs, (4) write-off of deferred tax assets and (5) related income tax effect. The amounts included in the calculation of adjusted net loss and adjusted net loss per diluted share below were computed in accordance with GAAP. We believe adjusted net loss and adjusted net loss per diluted share are useful to investors because they provide readers with a meaningful measure of our profitability before recording certain items whose timing or amount cannot be reasonably determined. However, these measures are provided in addition to, and not as an alternative for, and should be read in conjunction with, the information contained in our financial statements prepared in accordance with GAAP (including the notes), included in our SEC filings and posted on our website.

The table below provides a reconciliation of adjusted net loss to net loss for the three and nine months ended September 30, 2017 and 2016 (in thousands, except per-share amounts).

	Three Months Ended September 30,								Nine Months Ended September 30,
	2017				2016				2017				2016
Net loss	$	(8,512	)		$	(9,073	)		$	(158,176	)		$	(38,768	)
Adjustments for certain items:
Unrealized loss (gain) on commodity derivatives		3,037				(760	)			(2,596	)			8,273
Gain on debt extinguishment		—				—				(5,053	)			—
Write-off of debt issuance costs		—				—				—				563
Write-off of deferred tax assets		—				—				139,090				—
Tax effect		(1,063	)			266				2,677				(3,093	)
Adjusted net loss	$	(6,538	)		$	(9,567	)		$	(24,058	)		$	(33,025	)
Adjusted net loss per diluted share	$	(0.08	)		$	(0.23	)		$	(0.30	)		$	(0.80	)

EBITDAX

We define EBITDAX as net loss, plus (1) exploration expense, (2) depletion, depreciation and amortization expense, (3) share-based compensation expense, (4) unrealized loss (gain) on commodity derivatives, (5) gain on debt extinguishment, (6) write-off of debt issuance costs, (7) interest expense, net, and (8) income tax (benefit) provision. EBITDAX is not a measure of net income or cash flow as determined by GAAP. The amounts included in the calculation of EBITDAX were computed in accordance with GAAP. EBITDAX is presented herein and reconciled to the GAAP measure of net loss because of its wide acceptance by the investment community as a financial indicator of a company's ability to internally fund development and exploration activities. This measure is provided in addition to, and not as an alternative for, and should be read in conjunction with, the information contained in our financial statements prepared in accordance with GAAP (including the notes), included in our SEC filings and posted on our website.

The table below provides a reconciliation of EBITDAX to net loss for the three and nine months ended September 30, 2017 and 2016 (in thousands).

	Three Months Ended September 30,								Nine Months Ended September 30,
	2017				2016				2017				2016
Net loss	$	(8,512	)		$	(9,073	)		$	(158,176	)		$	(38,768	)
Exploration		100				1,047				3,251				3,238
Depletion, depreciation and amortization		16,843				19,422				54,348				59,642
Share-based compensation		1,330				1,357				3,518				4,281
Unrealized loss (gain) on commodity derivatives		3,037				(760	)			(2,596	)			8,273
Gain on debt extinguishment		—				—				(5,053	)			—
Write-off of debt issuance costs		—				—				—				563
Interest expense, net		5,304				7,067				15,683				20,173
Income tax (benefit) provision		(4,258	)			(4,915	)			129,933				(20,847	)
EBITDAX	$	13,844			$	14,145			$	40,908			$	36,555

Unhedged Cash Margin and Cash Operating Expenses

We define unhedged cash margin as revenue, less cash operating expenses. We define cash operating expenses as operating expenses, excluding (1) exploration expense, (2) depletion, depreciation and amortization expense, and (3) share-based compensation expense. Unhedged cash margin and cash operating expenses are not measures of operating income or cash flows as determined by GAAP. The amounts included in the calculations of unhedged cash margin and cash operating expenses were computed in accordance with GAAP. Unhedged cash margin and cash operating expenses are presented herein and reconciled to the GAAP measures of revenue and operating expenses. We use unhedged cash margin and cash operating expenses as an indicator of the Company’s profitability and ability to manage its operating income and cash flows. This measure is provided in addition to, and not as an alternative for, and should be read in conjunction with, the information contained in our financial statements prepared in accordance with GAAP (including the notes), included in our SEC filings and posted on our website.

The table below provides a reconciliation of unhedged cash margin and cash operating expenses to revenues and operating expenses for the three and nine months ended September 30, 2017 and 2016 (in thousands, except per-Boe amounts).

		Three Months Ended								Nine Months Ended
		September 30,								September 30,
		2017				2016				2017				2016
Revenues		$	25,608			$	23,749			$	76,932			$	63,797
Production (Mboe)			1,061				1,117				3,168				3,431
Average realized price (per Boe)		$	24.14			$	21.26			$	24.28			$	18.59
Operating expenses		$	29,543			$	32,201			$	95,692			$	101,604
Exploration			(100	)			(1,047	)			(3,251	)			(3,238	)
Depletion, depreciation and amortization			(16,843	)			(19,422	)			(54,348	)			(59,642	)
Share-based compensation			(1,330	)			(1,357	)			(3,518	)			(4,281	)
Cash operating expenses		$	11,270			$	10,375			$	34,575			$	34,443
Cash operating expenses per Boe		$	10.62			$	9.29			$	10.92			$	10.03
Unhedged cash margin		$	14,338			$	13,374			$	42,357			$	29,354
Unhedged cash margin per Boe		$	13.52			$	11.97			$	13.36			$	8.56

Liquidity

Liquidity is calculated by adding the net funds available under our revolving credit facility and cash and cash equivalents. We use liquidity as an indicator of the Company’s ability to fund development and exploration activities. However, this measurement has limitations. This measurement can vary from year-to-year for the Company and can vary among companies based on what is or is not included in the measurement on a company’s financial statements and may further be subject to covenants in a company’s loan agreements. This measurement is provided in addition to, and not as an alternative for, and should be read in conjunction with, the information contained in our financial statements prepared in accordance with GAAP (including the notes), included in our SEC filings and posted on our website.

The table below summarizes our liquidity at September 30, 2017 (in thousands).

		Liquidity at September 30,
		2017
Borrowing base		$	325,000
Cash and cash equivalents		21
Long-term debt – Credit Facility			(292,000	)
Undrawn letters of credit			(325	)
Liquidity		$	32,696

INVESTOR CONTACT
Suzanne Ogle
Vice President – Investor Relations & Corporate Communications
[email protected]
817.989.9000
APPROACH RESOURCES INC.
One Ridgmar Centre
6500 West Freeway, Suite 800
Fort Worth, Texas 76116
www.approachresources.com

Source: Approach Resources Inc