Linn Energy
08/03/2017

LINN Energy Reports Second-Quarter 2017 Results

HOUSTON, Aug. 03, 2017 (GLOBE NEWSWIRE) -- LINN Energy, Inc. (OTCQB:LNGG) ("LINN" or the "Company") announced today financial and operating results for the second quarter of 2017 and provided updated guidance for the third quarter, fourth quarter and full-year 2017.

The Company highlights the following:

"We had another outstanding quarter as we outperformed midpoint of guidance for volumes, costs and financial targets along with executing on several strategic and value-adding initiatives. This is highlighted by signing an agreement to form Roan Resources LLC, a premier pure play company in the Merge/SCOOP/STACK. With 140,000 total net acres, Roan is expected to have the inventory depth to provide production and reserve growth for many years to come. In addition, LINN's acreage committed in the deal will remain dedicated to our Chisholm Trail Cryogenic facility that is currently under construction. This year, we successfully closed on more than $1 billion of asset sales resulting in the Company extinguishing all its outstanding debt. This gives us tremendous financial flexibility as we finalize negotiations on a new credit facility and continue to work with the Board of Directors to maximize shareholder value," said Mark E. Ellis, President and Chief Executive Officer.

  
Key Financial Results (1) 
 Second Quarter
$ in millions, except per unit amounts 2017  2016 
Average daily production (MMcfe/d) 710  802 
Total oil, natural gas and NGL revenues $243 $196 
Income from continuing operations$223 $204 
Income (loss) from discontinued operations net of income taxes$(3)$4 
Net income$220 $208 
Adjusted EBITDAX (a non-GAAP financial measure)(3)$112 $179 
Total debt(4)$183 $5,961(2)
Net cash provided by operating activities$103 $536 
Oil and natural gas capital$71 $14 
Total capital$96 $23 
       
  1. All amounts reflect continuing operations with the exception of net income
  2. Includes approximately $4,023 million classified as liabilities subject to compromise on the balance sheet
  3. Excludes Adjusted EBITDAX from discontinued operations of approximately $12 million and $29 million for the three months ended June 30, 2017, and for the three months ended June 30, 2016, respectively
  4. As of June 30, 2017 and June 30, 2016

Formation of Roan Resources — Merge/SCOOP/STACK pure play company
On June 27, 2017, LINN and Citizen Energy II, LLC announced an agreement to contribute certain upstream assets to form a new company, Roan, which will be focused on the accelerated development of the prolific Merge/SCOOP/STACK play in the Anadarko Basin. In exchange, LINN will receive 50 percent of the equity interest in Roan. The combined entity is expected to have no outstanding debt at closing, intends to establish a revolving credit facility of approximately $100 million to $300 million that will be secured by its own assets. The transaction is expected to close in the third quarter of 2017. Roan continues to actively recruit an executive management team and there has been significant interest in this opportunity. Subject to market conditions, Roan anticipates an initial public offering in 2018.

Positive test of a third bench in the Merge
In the second quarter of 2017, LINN completed its first horizontal test of the Hunton with positive results. The Campbell Farms 14-9-6 2H (lateral length of 4,186 feet) had a peak IP-30 rate (gross two-stream) of more than 850 BOE/d (~64% liquids). This test has the potential to add four to eight wells per drilling unit in specific areas of the Roan AMI (area of mutual interest). LINN is currently drilling both Sycamore and Woodford targets from multi-well pads with two operated drilling rigs and the next several completions are scheduled to commence early in the fourth quarter.

Exceeded $1 billion of proceeds from asset sales
As of August 1, 2017, net cash proceeds received from closed transactions this year have exceeded $1 billion, including $560 million for the Jonah and Pinedale fields in Wyoming, $351 million for the South Belridge and Brea fields in California, $76 million for the Salt Creek Field in Wyoming, $32 million for two South Texas asset packages and approximately $25 million (~$21 million and ~$4 million) for a portion of our Permian Basin assets.

The Company has also signed a purchase and sale agreement related to the majority of its remaining South Texas assets for approximately $20 million, subject to normal closing adjustments and transaction costs. We expect this transaction to close in the third quarter of 2017.

Pending and future asset sales
LINN continues to market the remaining packages in Permian, Williston and South Texas. Additionally, the Company plans to sell its interest in the Altamont Bluebell Field in Utah and its mature waterfloods in Oklahoma. LINN continues to work with Jefferies LLC to explore strategic alternatives for the Company.

Eliminated all debt and negotiating a new credit facility
As of August 1, 2017, the Company had extinguished all outstanding debt and is in the final stages of negotiating a new senior revolving credit facility. The new facility is expected to have an initial borrowing base of $500 million.

Initiated share repurchase program and evaluation of uplisting
On June 28, 2017, the Board of Directors authorized an increase in the share repurchase program to a total of $200 million, subject to the closing of the new credit facility. As of July 31, 2017, the Company had purchased approximately 841,000 shares in the open market for approximately $27 million at an average price of $32.41 per share and continues to evaluate further repurchases. In addition, LINN is evaluating uplisting to the New York Stock Exchange or NASDAQ in 2018.

General & administrative expense
Current general and administrative ("G&A") expense guidance for 2017 is $95 million, down significantly from the previous 2017 guidance of $120 million. Following the completion of all contemplated asset sales, closing the Roan transaction and related transition periods, the Company expects an ongoing annual G&A run rate of approximately $60 million and continues to evaluate further value-adding reductions to our cost structure.

NW STACK activity continues to increase
The Company has a significant acreage position of approximately 105,000 net acres in the NW STACK and offset horizontal results in the Osage and Meramec have been positive with recent IP-30 rates of more than 1,000 BOE/d. Industry activity has significantly increased in the area, with 41 rigs currently running and 101 horizontal well permits filed in the second quarter of 2017 compared to 43 in the first quarter of 2017. LINN is evaluating adding a rig in the NW STACK to test horizontal potential along with evaluating several other potential productive horizons in the area.

Blue Mountain Midstream
The Company's subsidiary, LINN Midstream, LLC, has been renamed Blue Mountain Midstream LLC ("Blue Mountain") and holds all previously held LINN Midstream assets, including Chisholm Trail in central Oklahoma and the Jayhawk natural gas processing plant in southwest Kansas. The rebranding of Blue Mountain highlights the significant value of the Company's growing midstream business that is additive to the upstream value estimates provided at emergence. Blue Mountain charges the upstream business a market rate that is included in the upstream economics.

Chisholm Trail Cryogenic gas plant in the Merge
Chisholm Trail is located in the heart of the prolific liquids-rich Merge/SCOOP/STACK play and has approximately 30 miles of existing gas gathering pipeline and approximately 60 MMcf/d of current refrigeration capacity. LINN acreage recently contributed to Roan remains dedicated to Chisholm Trail.  Infrastructure expansions are underway to add 35 miles of low-pressure gathering, increase compression throughput and construct a new cryogenic plant to improve liquids recoveries. Blue Mountain has entered into a definitive agreement with BCCK to construct a highly efficient, state-of-the-art 225 MMcf/d cryogenic gas processing facility with a total capacity of 250 MMcf/d. Construction is underway and the facility is expected to be commissioned during the second quarter of 2018. Blue Mountain is also pursuing third-party dedications to accelerate throughput growth for the facility. The Company estimates that a midstream business of this type at full capacity could generate annual EBITDA (a non-GAAP financial measure) between $100 million and $125 million.

Jayhawk natural gas processing plant in the Hugoton Basin
Blue Mountain owns and operates the Jayhawk natural gas processing plant in southwest Kansas with a capacity of approximately 450 MMcf/d, allowing the Company to receive maximum value from the liquids-rich natural gas and helium produced in the area. The Company's production in the area is delivered to the plant at market gathering rates via a system of approximately 3,930 miles of pipeline and related facilities operated by the Company, of which approximately 2,075 miles of pipeline are owned by the Company.

Emerging Growth Potential
North Louisiana
The Company has approximately 150,000 net acres that are largely held by production with a focus on acreage in the Ruston and Calhoun areas. There are 10 active rigs in the areas and more than 30 drilling permits have been filed in the first half of 2017. LINN recently drilled two operated horizontal wells in Ruston for our first test of the Lower Red and our third test of the Upper Red. The recently completed Lower Red test continues to clean up with a choked back 24-hr IP rate of 12.6 MMcf/d and the completion of the Upper Red is expected to commence in the next 30 days. Additionally, the Company plans to drill an operated horizontal well to test the Calhoun acreage in the fourth quarter of 2017.

East Texas
LINN has approximately 115,000 net acres that are held by production in East Texas. Horizontal activity is increasing in the area with seven active horizontal rigs and more than 40 horizontal drilling permits filed in the first half of 2017 that target several prospective formations including the Cotton Valley and Bossier formations. The Company sees significant upside by applying enhanced horizontal drilling and completion technologies across its acreage position and is currently drilling one of two planned operated horizontal wells for the second half of 2017.

Washakie
LINN has approximately 200,000 net acres that are held by production in the Washakie, where there has been significant offset horizontal activity. There are currently three active horizontal drilling rigs in the area with more than 60 horizontal drilling permits approved in the first half of 2017. Emerging horizontal targets include the Lewis, Almond marine bar and Middle Almond formations with peak IP-30 well results of greater than 10 MMcf/d.  LINN continues to evaluate the play and plans to participate in non-operated horizontal activity in the second half of 2017.

Arkoma
The Company has approximately 49,000 net acres in the Arkoma area that are held by production and there are currently 10 active horizontal rigs in the area with 50 horizontal drilling permits filed in the first half of 2017. About 40 percent of the operated sections have only one horizontal well and LINN is evaluating infill development using enhanced drilling and completion technology.

Capital spending
Adjusted for discontinued operations and the sale of Jonah, LINN forecasted $49 million of oil and natural gas capital for the second quarter of 2017. Actual oil and gas capital for the quarter was approximately $71 million. This was higher than guidance primarily due to an increase in lease acquisition spending in the Merge.

The Company has reduced capital guidance for the full year 2017 from $413 million to $338 million.  The reduction is primarily related to the expected closing of all announced asset sales and the contribution of our Merge/SCOOP/STACK acreage to Roan, partially offset by increased non-operated horizontal drilling capital and leasing in the Merge area.

Second Quarter Actuals versus Adjusted Guidance
Second quarter guidance has been adjusted for the closing of the Jonah sale at the end of May and classification of California properties as discontinued operations.

   
 Q2 ActualsAdjusted Q2 Guidance
Net Production (MMcfe/d) 710  663 - 737 
Natural gas (MMcf/d) 432  428 - 475 
Oil (Bbls/d) 21,600  19,122 - 21,609 
NGL (Bbls/d) 24,800  20,135 - 22,044 
     
Other revenues, net (in thousands) (1)$11,962 $9,000 -$10,000 
     
Costs (in thousands)$ 126,316 $ 122,000 -$ 137,000 
Lease operating expenses$71,057 $68,000 -$75,000 
Transportation expenses$37,388 $35,000 -$40,000 
Taxes, other than income taxes$17,871 $19,000 -$22,000 
     
General and administrative expenses (2)$19,036 $27,000 -$30,000 
     
Costs per Mcfe (Mid-Point)$1.96 $2.03 
Lease operating expenses$1.10 $1.12 
Transportation expenses$0.58 $0.59 
Taxes, other than income taxes$0.28 $0.32 
   
General and administrative expenses (2)$0.29 $0.45 
   
Targets (Mid-Point) (in thousands)  
Adjusted EBITDAX(3)$111,932 $95,000 
Interest expense$7,551 $9,000 
Oil and natural gas capital$70,640 $49,000 
Total capital$95,741 $85,000 
   
Weighted Average NYMEX Differentials      
Natural gas (MMBtu)($0.37)($0.35)-($0.15)
Oil (Bbl)($2.86)($5.00)-($3.00)
NGL price as a % of crude oil price 42%34% - 38%

__________________________

  1. Includes other revenues and margin on marketing activities
  2. As included in operating cash flow and excludes share-based compensation expenses of approximately $15 million
  3. Excludes Adjusted EBITDAX from discontinued operations of approximately $12 million

Third Quarter, Fourth Quarter and Full Year 2017 Guidance Update
Guidance estimates have been adjusted for the closing of the Jonah, Salt Creek, South Texas, Permian and California sales as well as expected timing of the closing for Roan. The guidance provided below excludes LINN's 50% equity interest in Roan after closing.

 Q3 2017EQ4 2017EFY 2017E
Net Production (MMcfe/d)540 — 600500 — 550618 — 655
Natural gas (MMcf/d)330 — 365325 — 355390 — 415 
Oil (Bbls/d)16,000 — 18,00014,000 — 16,00018,000 — 19,000
NGL (Bbls/d)19,000 — 21,00015,000 — 16,50020,000 — 21,000
    
Other revenues, net (in thousands) (1)$ 7,000 - $ 8,000$ 7,000 - $ 8,000$ 40,000 —  $ 42,000
    
Costs (in thousands)$ 101,000 — $ 111,000$ 96,000 — $ 105,000$ 456,000 — $ 485,000
Lease operating expenses$ 56,000 — $ 62,000$ 55,000 — $ 60,000$ 255,000 —  $ 270,000
Transportation expenses$ 31,000 — $ 34,000$ 28,000 — $ 31,000$ 136,000 — $ 144,000
Taxes, other than income taxes$ 14,000 — $ 15,000$ 13,000 — $ 14,000$ 65,000 — $ 71,000
    
General and administrative expenses (2)$ 24,000 — $ 27,000$ 22,000 — $ 24,000$ 92,000 — $ 99,000
    
Costs per Mcfe (Mid-Point) $2.03$2.08 $2.02 
Lease operating expenses$1.13$1.19$1.13
Transportation expenses$0.62$0.61$0.60
Taxes, other than income taxes$0.28$0.28$0.29
    
General and administrative expenses (2)$0.49$0.48$0.41
    
Targets (Mid-Point) (in thousands)   
Adjusted EBITDAX(3)$71,000$63,000$360,000
Interest expense$1,000$—$28,000
Oil and natural gas capital$78,000$24,000$229,000
Total capital$116,000$62,000$338,000
    
Weighted Average NYMEX Differentials   
Natural gas (MMBtu)($0.35) — ($0.25)($0.35) — ($0.25)($0.35) — ($0.25)
Oil (Bbl)($4.00) — ($3.00)($4.00) — ($3.00)($4.00) — ($3.00)
NGL price as a % of crude oil price34% — 40%34% — 40%36% — 42%


Unhedged Commodity Price Assumptions (4)JulyAugSeptOctNovDec2017E
Natural gas (MMBtu)$3.07$2.97$2.96$3.00$3.07$3.22$3.15
Oil (Bbl)$45.86$45.77$45.95$46.19$46.45$46.69$48.09
NGL (Bbl)$17.04$16.99$17.28$17.02$17.09$17.17$18.95

___________________________

  1. Includes other revenues and margin on marketing activities
  2. As included in operating cash flow and excludes share-based compensation expenses
  3. Excludes Adjusted EBITDAX from discontinued operations of approximately $4 million for Q3 2017E, and $31 million for FY 2017E
  4. Strip prices as of July 21, 2017
 
Hedging Update
       
 2017
2018
2019
Natural GasVolume (MMMBtu/d)Average Price
(per MMBtu)
Volume (MMMBtu/d)Average Price
(per MMBtu)
Volume (MMMBtu/d)Average Price
(per MMBtu)
Swaps370$3.17131$3.0131$2.97
OilVolume (Bbls/d)Average Price
(per Bbl)
Volume
(Bbls/d)
Average Price
(per Bbl)
Volume
(Bbls/d)
Average Price
(per Bbl)
Swaps12,000$52.131,500$54.07--
Collars--5,000$50.00 - $55.505,000$50.00 - $55.50
       

Form 10‑Q / Earnings Call
LINN plans to file its Quarterly Report on Form 10-Q for the quarter ended June 30, 2017, with the Securities and Exchange Commission on August 3, 2017 and will host a conference call Thursday, August 3, 2017 at 10 a.m. (CDT) to discuss the Company's second quarter 2017 results. Investors and analysts are invited to participate in the call by dialing (844) 625-4392, or (409) 497-0988 for international calls using Conference ID: 51104553. Interested parties may also listen over the internet at www.linnenergy.com. A replay of the call and a transcript will be available on the Company's website until August 17, 2017.

Supplemental information can be found at the following link on our website: http://ir.linnenergy.com/presentations.cfm

About LINN Energy

LINN Energy, Inc. was formed in February 2017 as the reorganized successor to LINN Energy, LLC. Headquartered in Houston, Texas, the Company's core focus is the upstream and midstream development of the Merge/SCOOP/STACK in Oklahoma. Additionally, the Company is pursuing emerging horizontal opportunities in the Mid-Continent, Rockies, North Louisiana and East Texas while continuing to add value by efficiently operating and applying new technology to a diverse set of long-life producing assets.

Forward-Looking Statements
Statements made in this press release that are not historical facts are "forward-looking statements." These statements are based on certain assumptions and expectations made by the Company which reflect management's experience, estimates and perception of historical trends, current conditions, and anticipated future developments. 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 anticipated in the forward-looking statements. These include risks relating to financial performance and results, ability to improve our financial results and profitability following emergence from bankruptcy, availability of sufficient cash flow to execute our business plan, ability to execute planned asset sales, continued low or further declining commodity prices and demand for oil, natural gas and natural gas liquids, ability to hedge future production, ability to replace reserves and efficiently develop current reserves, the capacity and utilization of midstream facilities, the regulatory environment and other important factors that could cause actual results to differ materially from those anticipated or implied in the forward-looking statements. These and other important factors could cause actual results to differ materially from those anticipated or implied in the forward-looking statements. Please read "Risk Factors" in the Company's Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q and other public filings. We undertake no obligation to publicly update any forward-looking statements, whether as a result of new information or future events.

 
Condensed Consolidated Balance Sheets (Unaudited)
 
 Successor  Predecessor
 June 30, 2017  December 31, 2016
(in thousands)    
ASSETS       
Current assets:    
Cash and cash equivalents$16,903   $694,857 
Accounts receivable — trade, net163,935   198,064 
Derivative instruments23,959    
Restricted cash98,616   1,602 
Other current assets71,836   105,310 
Assets held for sale236,421    
Current assets of discontinued operations235,643   701 
Total current assets847,313   1,000,534 
     
Noncurrent assets:    
Oil and natural gas properties (successful efforts method)1,444,110   12,349,117 
Less accumulated depletion and amortization(37,572)  (9,843,908)
 1,406,538   2,505,209 
     
Other property and equipment441,483   618,262 
Less accumulated depreciation(12,739)  (217,724)
 428,744   400,538 
     
Derivative instruments12,759    
Deferred income taxes492,182    
Other noncurrent assets13,980   13,984 
Noncurrent assets of discontinued operations   740,326 
 518,921   754,310 
Total noncurrent assets2,354,203   3,660,057 
Total assets$3,201,516   $4,660,591 
     
LIABILITIES AND EQUITY (DEFICIT)    
Current liabilities:    
Accounts payable and accrued expenses$268,605   $295,081 
Derivative instruments486   82,508 
Current portion of long-term debt, net   1,937,729 
Other accrued liabilities135,416   25,979 
Liabilities held for sale36,387    
Current liabilities of discontinued operations28,218   321 
Total current liabilities469,112   2,341,618 
     
Derivative instruments   11,349 
Long-term debt183,430    
Other noncurrent liabilities264,025   360,405 
Noncurrent liabilities of discontinued operations   39,202 
Liabilities subject to compromise   4,305,005 
     
     
Temporary equity:
    
Redeemable noncontrolling interests  28,132    
Stockholders'/unitholders' equity (deficit):    
Predecessor units issued and outstanding   5,386,885 
Predecessor accumulated deficit   (7,783,873)
Successor Class A common stock89    
Successor additional paid-in capital2,043,927    
Successor retained earnings212,801    
Total stockholders'/unitholders' equity (deficit)2,256,817   (2,396,988)
Total liabilities and equity (deficit)$3,201,516   $4,660,591 


Condensed Consolidated Statements of Operations (Unaudited)
 
 Successor  Predecessor
 Three Months Ended June 30, 2017  Three Months Ended June 30, 2016
(in thousands, except per share and per unit amounts)    
Revenues and other:    
Oil, natural gas and natural gas liquids sales$243,167   $195,847 
Gains (losses) on oil and natural gas derivatives45,714   (183,794)
Marketing revenues12,547   8,551 
Other revenues6,391   23,641 
 307,819   44,245 
Expenses:    
Lease operating expenses71,057   70,367 
Transportation expenses37,388   41,092 
Marketing expenses6,976   6,727 
General and administrative expenses34,458   52,169 
Exploration costs811   48 
Depreciation, depletion and amortization51,987   86,358 
Taxes, other than income taxes17,871   18,180 
(Gains) losses on sale of assets and other, net(306,969)  2,517 
 (86,421)  277,458 
Other income and (expenses):    
Interest expense, net of amounts capitalized(7,551)  (50,320)
Other, net(1,163)  (1,226)
 (8,714)  (51,546)
Reorganization items, net(3,377)  485,798 
Income from continuing operations before income taxes382,149   201,039 
Income tax expense (benefit)158,770   (3,652)
Income from continuing operations223,379   204,691 
Income (loss) from discontinued operations, net of income taxes(3,322)  3,801 
Net income$220,057   $208,492 
     
 Income from continuing operations per share/unit - Basic$2.49   $0.58 
 Income from continuing operations per share/unit - Diluted$2.47   $0.58 
     
 Income (loss) from discontinued operations per share/unit - Basic$(0.04)  $0.01 
 Income (loss) from discontinued operations per share/unit - Diluted$(0.04)  $0.01 
     
Net income per share/unit - Basic$2.45   $0.59 
Net income per share/unit - Diluted$2.43   $0.59 
     
 Weighted average shares/units outstanding - Basic 89,849    352,789 
 Weighted average shares/units outstanding - Diluted 90,484    352,789 


Condensed Consolidated Statements of Operations — Continued (Unaudited)
 
 Successor  Predecessor
 Four Months Ended June 30, 2017  Two Months Ended February 28, 2017 Six Months Ended June 30, 2016
(in thousands, except per share and per unit amounts)      
Revenues and other:      
Oil, natural gas and natural gas liquids sales$323,492   $188,885  $380,288 
Gains (losses) on oil and natural gas derivatives33,755   92,691  (74,341)
Marketing revenues15,461   6,636  17,612 
Other revenues8,419   9,915  51,947 
 381,127   298,127  375,506 
Expenses:      
Lease operating expenses95,687   49,665  153,613 
Transportation expenses51,111   25,972  83,623 
Marketing expenses9,515   4,820  14,560 
General and administrative expenses44,869   71,745  135,889 
Exploration costs866   93  2,741 
Depreciation, depletion and amortization71,901   47,155  175,467 
Impairment of long-lived assets     123,316 
Taxes, other than income taxes24,948   14,877  35,541 
(Gains) losses on sale of assets and other, net(306,524)  672  3,786 
 (7,627)  214,999  728,536 
Other income and (expenses):      
Interest expense, net of amounts capitalized(11,751)  (16,725) (134,193)
Other, net(1,551)  (149) (1,158)
 (13,302)  (16,874) (135,351)
Reorganization items, net(5,942)  2,331,189  485,798 
Income (loss) from continuing operations before income taxes369,510   2,397,443  (2,583)
Income tax expense (benefit)153,455   (166) 6,594 
Income (loss) from continuing operations216,055   2,397,609  (9,177)
Loss from discontinued operations, net of income taxes(3,254)  (548) (1,130,077)
Net income (loss)$212,801   $2,397,061  $(1,139,254)
       
 Income (loss) from continuing operations per share/unit - Basic$2.41   $6.80  $(0.02)
 Income (loss) from continuing operations per share/unit - Diluted$2.40   $6.80  $(0.02)
       
Loss from discontinued operations per share/unit - Basic$(0.04)  $(0.01) $(3.21)
Loss from discontinued operations per share/unit - Diluted$(0.04)  $(0.01) $(3.21)
       
 Net income (loss) per share/unit - Basic$2.37   $6.79  $(3.23)
 Net income (loss) per share/unit - Diluted$2.36   $6.79  $(3.23)
       
Weighted average shares/units outstanding - Basic 89,849    352,792   352,511 
Weighted average shares/units outstanding - Diluted 90,065    352,792   352,511 


Condensed Consolidated Statements of Cash Flows (Unaudited)
 

 
Successor  Predecessor
 Four Months Ended June 30, 2017  Two Months Ended February 28, 2017 Six Months Ended June 30, 2016
(in thousands)      
       
Cash flow from operating activities:      
Net income (loss)$212,801   $2,397,061  $(1,139,254)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:      
Loss from discontinued operations3,254   548  1,130,077 
Depreciation, depletion and amortization71,901   47,155  175,467 
Impairment of long-lived assets     123,316 
Deferred income taxes131,055   (166) 3,850 
Noncash (gains) losses on oil and natural gas derivatives(25,826)  (104,263) 931,251 
Share-based compensation expenses19,599   50,255  18,553 
Amortization and write-off of deferred financing fees82   1,338  9,227 
(Gains) losses on sale of assets and other, net(293,811)  1,069  3,929 
Reorganization items, net   (2,359,364) (498,954)
Changes in assets and liabilities:      
(Increase) decrease in accounts receivable — trade, net27,212   (7,216) (12,046)
(Increase) decrease in other assets(1,245)  402  (19,039)
Increase in restricted cash   (80,164)  
Increase (decrease) in accounts payable and accrued expenses(49,984)  20,949  47,062 
Increase in other liabilities22,421   2,801  26,150 
Net cash provided by (used in) operating activities — continuing operations117,459   (29,595) 799,589 
Net cash provided by operating activities — discontinued operations13,966   8,781  1,612 
Net cash provided by (used in) operating activities131,425   (20,814) 801,201 
       
Cash flow from investing activities:      
Development of oil and natural gas properties(61, 534)  (50,597) (80,909)
Purchases of other property and equipment(27,287)  (7,409) (13,655)
Proceeds from sale of properties and equipment and other641, 219   (166) (2,713)
Net cash provided by (used in) investing activities — continuing operations552,398   (58,172) (97,277)
Net cash provided by (used in) investing activities — discontinued operations(1,645)  (584) 26,166 
Net cash provided by (used in) investing activities550,753   (58,756) (71,111)
       
Cash flow from financing activities:      
Proceeds from rights offering, net   514,069   
Proceeds from borrowings160,000     978,500 
Repayments of debt(876,570)  (1,038,986) (913,210)
Debt issuance costs paid(2,973)    (623)
Payment to holders of claims under the second lien notes   (30,000)  
Other(87)  (6,015) (20,687)
Net cash provided by (used in) financing activities — continuing operations(719,630)  (560,932) 43,980 
Net cash used in financing activities — discontinued operations     (1,593)
Net cash provided by (used in) financing activities(719,630)  (560,932) 42,387 
       
Net increase (decrease) in cash and cash equivalents(37,452)  (640,502) 772,477 
Cash and cash equivalents:      
Beginning54,355   694,857  2,168 
Ending16,903   54,355  774,645 
Less cash and cash equivalents of discontinued operations at end of period     (15,008)
Ending — continuing operations$16,903   $54,355  $759,637 
 

Adjusted EBITDAX (Non-GAAP Measure)

The non-GAAP financial measure of adjusted EBITDAX, as defined by the Company, may not be comparable to similarly titled measures used by other companies. Therefore, this non-GAAP measure should be considered in conjunction with net income (loss) and other performance measures prepared in accordance with GAAP. Adjusted EBITDAX should not be considered in isolation or as a substitute for GAAP.

Adjusted EBITDAX is a measure used by Company management to evaluate the Company's operational performance and for comparisons to the Company's industry peers. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company's financial results.

The following presents a reconciliation of net income (loss) to adjusted EBITDAX:

    
 Three Months Ended June 30,
 Six Months Ended June 30,
 2017
 2016 2017 (1)
 2016
                
 (in thousands)
Net income (loss)$    220,057  $    208,492  $    2,609,862  $    (1,139,254)
Plus (less):               
(Income) loss from discontinued operations 3,322   (3,801)  3,802   1,130,077 
Interest expense 7,551   50,320   28,476   134,193 
Income tax expense (benefit) 158,770   (3,652)  153,289   6,594 
Depreciation, depletion and amortization 51,987   86,358   119,056   175,467 
Exploration costs 811   48   959   2,741 
EBITDAX 442,498   337,765   2,915,444   309,818 
Plus (less):               
Impairment of long-lived assets          123,316 
Noncash (gains) losses on oil and natural gas derivatives (43,567)  349,158   (130,089)  574,416 
Noncash settlements on derivatives (2)    34,335      34,335 
Accrued settlements on oil derivative contracts related to current production period (3) 1,583   (65,492)  2,885   (73,354)
Share-based compensation expenses 15,422   6,128   69,854   18,553 
Write-off of deferred financing fees    1,332      1,348 
(Gains) losses on sale of assets and other, net (4) (307,381)  2,018   (307,407)  3,376 
Reorganization items, net (5) 3,377   (485,798)  (2,325,247)  (485,798)
Adjusted EBITDAX$    111,932  $    179,446  $    225,440  $    506,010 
                

In addition, the Company reported the following other items:

    
 Three Months Ended June 30,
 Six Months Ended June 30,
 
2017
 2016 
2017 (1)
 2016
                
 (in thousands)
Prepetition restructuring costs included in general and administrative expenses (6)$  $2,403  $  $19,567 
Premiums paid for put options that settled during the period (7)    (20,761)     (58,246)
                
  1. All amounts reflect the combined results of the four months ended June 30, 2017 (successor) and the two months ended February 28, 2017 (predecessor).
  2. Represent derivative settlements that were paid directly by the counterparties to the lenders under the predecessor's credit facility, and as such were not included on the Company's consolidated statement of cash flows.
  3. Represent amounts related to oil derivative contracts that settled during the respective period (contract terms had expired) but cash had not been received as of the end of the period.
  4. Primarily represent gains or losses on the sale of assets, gains or losses on inventory valuation and amortization of basis difference for equity method investments.
  5. Represent costs and income directly associated with the Company's filing for voluntary reorganization under Chapter 11 of the U.S. Bankruptcy Code since the petition date, and also include adjustments to reflect the carrying value of certain liabilities subject to compromise at their estimated allowed claim amounts, as such adjustments are determined.
  6. Represent restructuring costs incurred by the Company prior to its filing for voluntary reorganization under Chapter 11 of the U.S. Bankruptcy Code, which are included in general and administrative expenses.
  7. Represent premiums paid at inception for put options that settled during the respective period.  The Company has not purchased any put options since 2012.

 

CONTACTS: LINN Energy, Inc.

Investors:

Thomas Belsha, Vice President — Investor Relations & Corporate Development
(281) 840-4110
ir@linnenergy.com