Press Release
Laredo Petroleum Announces 2018 Second-Quarter Financial and Operating Results
2018 Second-Quarter Highlights
- Produced a Company record 67,206 barrels of oil equivalent ("BOE") per day, an increase of 15% from second-quarter 2017
- Increased anticipated production growth for full-year 2018 to greater than 15%
- Increased Adjusted EBITDA to
$152.5 million , up 33% from the second quarter of 2017 - Repurchased 3,150,651 shares of common stock at a weighted-average price of
$9.12 per share for$28.7 million under the Company's share repurchase program
"The Company continued its impressive operational performance in the second quarter, with improving efficiencies enabling the Company to complete more wells than projected and exceed production guidance," stated
E&P Update
In the second quarter of 2018, Laredo completed 20 gross (19.9 net) horizontal wells with an average completed lateral length of approximately 10,700 feet, surpassing Company expectations of 17 gross completions. Laredo produced a Company record 67,206 BOE per day in second-quarter 2018, an increase of 15% from the second quarter of 2017 and higher than Company guidance of 64,000 BOE per day.
Operational efficiency gains experienced in the first quarter of 2018 continued through second-quarter 2018, facilitating higher than anticipated completion counts in both quarters. Completions efficiency has increased by approximately 34% compared to 2017, reflecting the benefits of contracting a second dedicated completion crew and the Company's focus on best practices in drilling and completions operations.
At the end of the second quarter of 2018, the Company signed a one-year contract that is expected to enable the full implementation of in-basin sand in future completions. Laredo anticipates savings of approximately
Unit lease operating expenses ("LOE") decreased in the second quarter of 2018 to
Previously, the Company announced a fire caused by a lightning strike on
Laredo expects to complete 16 gross horizontal wells (16 net) in the third quarter of 2018 with an average lateral length of approximately 11,400 feet. Third-quarter 2018 production is expected to be positively impacted by the 14 wells completed at the end of the second quarter. Eight of the completions during the third quarter of 2018 are expected to be at the end of the quarter and thus have limited impact on production for the third quarter.
The Company has signed a contract for a fourth horizontal rig and expects to begin drilling with the rig in mid-August. Laredo anticipates maintaining four horizontal rigs and two completion crews for the remainder of 2018.
Results from previous co-development packages in the Upper and Middle Wolfcamp formations continue to be very positive. Both the five-well Sugg-A 157/158 and the nine-well
Crude Marketing
In the second quarter of 2018, Laredo contracted firm transportation to the
Laredo's contract with the Medallion intra-basin pipeline provides flow assurance to multiple long-haul pipelines that connect to the
Approximately 85% of the Company's gross operated volumes are gathered directly on pipe by
Water Infrastructure
Through LMS, the Company has built approximately 110 miles of water gathering and distribution pipelines, recycling facilities capable of processing 54,000 barrels of water per day and water storage capacity of 22.5 million barrels of water. In the second quarter of 2018, Laredo gathered 81% of produced water by pipe and recycled 35% of produced water. In total, LMS' water assets produced savings net to the Company of approximately
2018 Capital Program
During the second quarter of 2018, Laredo invested approximately
Through the first half of 2018, the Company has completed 40 gross (39.9 net) horizontal wells with an average lateral length of approximately 10,200 feet, or more than 60% of the total lateral feet originally expected to be completed during 2018. Operational efficiencies have shortened cycle times and Laredo now expects to complete approximately 70 net horizontal wells with an average lateral length of approximately 10,400 feet during 2018, an increase from original expectations of 60 - 65 net wells.
Commensurate with the increase in operational efficiencies and expected completions, the Company is increasing the drilling and completion portion of its capital budget to
Liquidity
At
At
Commodity Derivatives
Laredo maintains a disciplined hedging program to reduce the variability in its anticipated cash flow due to fluctuations in commodity prices. The Company utilizes a combination of puts, swaps and collars, entering into contracts solely with banks that are part of its senior secured credit facility. Laredo currently has hedges in place for approximately 90% of anticipated oil production in the second half of 2018 and has oil hedges through 2021. Laredo has also entered into NGL and natural gas hedges through 2018 and basis hedges through 2020. Details of the Company's hedge positions are included in the current Corporate Presentation available on the Company's website at www.laredopetro.com.
Guidance
The Company is increasing its anticipated full-year 2018 total production growth guidance to greater than 15% and reiterating previously issued oil production growth guidance of greater than 10% as compared to 2017. The table below reflects the Company's guidance for the third quarter of 2018.
3Q-2018E | |||
Total production (MBOE/d) | 71.0 |
||
Oil production (MBO/d) | 29.1 | ||
Price Realizations (pre-hedge): | |||
Crude oil (% of WTI) | 86% | ||
Natural gas liquids (% of WTI) | 33% | ||
Natural gas (% of Henry Hub) | 47% | ||
Operating Costs & Expenses: | |||
Lease operating expenses ($/BOE) | $3.65 | ||
Midstream expenses ($/BOE) | $0.15 | ||
Transportation and marketing expenses ($/BOE) | $0.80 | ||
Production and ad valorem taxes (% of oil, NGL and natural gas revenue) | 6.25% | ||
General and administrative expenses: | |||
Cash ($/BOE) | $2.60 | ||
Non-cash stock-based compensation ($/BOE) | $1.55 | ||
Depletion, depreciation and amortization ($/BOE) | $8.30 |
Conference Call Details
On
About Laredo
Additional information about Laredo may be found on its website at www.laredopetro.com.
Forward-Looking Statements
This press release and any oral statements made regarding the subject of this release, including in the conference call referenced herein, contain forward-looking statements as defined under Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical facts, that address activities that Laredo assumes, plans, expects, believes, intends, projects, estimates or anticipates (and other similar expressions) will, should or may occur in the future are forward-looking statements. The forward-looking statements are based on management’s current belief, based on currently available information, as to the outcome and timing of future events.
General risks relating to Laredo include, but are not limited to, the decline in prices of oil, natural gas liquids and natural gas and the related impact to financial statements as a result of asset impairments and revisions to reserve estimates, the increase in service and supply costs, tariffs on steel, pipeline transportation constraints in the
The
Laredo Petroleum, Inc. | ||||||||||||||||
Condensed consolidated statements of operations | ||||||||||||||||
Three months ended June 30, | Six months ended June 30, | |||||||||||||||
(in thousands, except per share data) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
(unaudited) | (unaudited) | |||||||||||||||
Revenues: | ||||||||||||||||
Oil, NGL and natural gas sales | $ | 208,561 | $ | 141,837 | $ | 405,995 | $ | 280,573 | ||||||||
Midstream service revenues | 1,976 | 2,703 | 4,335 | 5,702 | ||||||||||||
Sales of purchased oil | 140,509 | 42,461 | 200,412 | 89,732 | ||||||||||||
Total revenues | 351,046 | 187,001 | 610,742 | 376,007 | ||||||||||||
Costs and expenses: | ||||||||||||||||
Lease operating expenses | 22,642 | 20,104 | 44,593 | 37,096 | ||||||||||||
Production and ad valorem taxes | 12,405 | 8,472 | 24,217 | 17,253 | ||||||||||||
Transportation and marketing expenses | 1,534 | — | 1,534 | — | ||||||||||||
Midstream service expenses | 403 | 896 | 1,096 | 1,812 | ||||||||||||
Costs of purchased oil | 140,578 | 44,020 | 201,242 | 94,276 | ||||||||||||
General and administrative | 26,834 | 22,008 | 51,559 | 47,605 | ||||||||||||
Depletion, depreciation and amortization | 50,762 | 38,003 | 96,315 | 72,115 | ||||||||||||
Other operating expenses | 1,121 | 1,437 | 2,227 | 2,463 | ||||||||||||
Total costs and expenses | 256,279 | 134,940 | 422,783 | 272,620 | ||||||||||||
Operating income | 94,767 | 52,061 | 187,959 | 103,387 | ||||||||||||
Non-operating income (expense): | ||||||||||||||||
Gain (loss) on derivatives, net | (45,976 | ) | 28,897 | (36,966 | ) | 65,568 | ||||||||||
Income from equity method investee(1) | — | 2,471 | — | 5,539 | ||||||||||||
Interest expense | (14,424 | ) | (23,173 | ) | (27,942 | ) | (45,893 | ) | ||||||||
Other, net | (915 | ) | 854 | (3,079 | ) | 785 | ||||||||||
Non-operating income (expense), net | (61,315 | ) | 9,049 | (67,987 | ) | 25,999 | ||||||||||
Income before income taxes | 33,452 | 61,110 | 119,972 | 129,386 | ||||||||||||
Income tax: | ||||||||||||||||
Deferred | — | — | — | — | ||||||||||||
Total income tax | — | — | — | — | ||||||||||||
Net income | $ | 33,452 | $ | 61,110 | $ | 119,972 | $ | 129,386 | ||||||||
Net income per common share: | ||||||||||||||||
Basic | $ | 0.14 | $ | 0.26 | $ | 0.51 | $ | 0.54 | ||||||||
Diluted | $ | 0.14 | $ | 0.25 | $ | 0.51 | $ | 0.53 | ||||||||
Weighted-average common shares outstanding: | ||||||||||||||||
Basic | 230,933 | 239,231 | 234,561 | 238,870 | ||||||||||||
Diluted | 231,706 | 244,417 | 235,501 | 244,385 |
_______________________________________________________________________________
(1) | On October 30, 2017, LMS, together with Medallion Midstream Holdings, LLC, which is owned and controlled by an affiliate of the third-party interest holder, The Energy & Minerals Group, completed the sale of 100% of the ownership interests in Medallion Gathering & Processing, LLC, a Texas limited liability company formed on October 12, 2012, which, together with its wholly-owned subsidiaries (collectively, "Medallion"), to an affiliate of Global Infrastructure Partners ("GIP"), for cash consideration of $1.825 billion (the "Medallion Sale"). LMS' net cash proceeds for its 49% ownership interest in Medallion in 2017 were $829.6 million, before post-closing adjustments and taxes, but after deduction of its proportionate share of fees and other expenses associated with the Medallion Sale. On February 1, 2018, closing adjustments were finalized and LMS received additional net cash of $1.7 million for total net cash proceeds before taxes of $831.3 million. The Medallion Sale closed pursuant to the membership interest purchase and sale agreement, which provides for potential post-closing additional cash consideration that is structured based on GIP's realized profit at exit. There can be no assurance as to when and whether the additional consideration will be paid. |
Laredo Petroleum, Inc. | ||||||||||||||||
Condensed consolidated statements of cash flows | ||||||||||||||||
Three months ended June 30, | Six months ended June 30, | |||||||||||||||
(in thousands) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
(unaudited) | (unaudited) | |||||||||||||||
Cash flows from operating activities: | ||||||||||||||||
Net income | $ | 33,452 | $ | 61,110 | $ | 119,972 | $ | 129,386 | ||||||||
Adjustments to reconcile net income to net cash provided by operating activities: | ||||||||||||||||
Depletion, depreciation and amortization | 50,762 | 38,003 | 96,315 | 72,115 | ||||||||||||
Non-cash stock-based compensation, net | 10,676 | 8,687 | 20,015 | 17,911 | ||||||||||||
Mark-to-market on derivatives: | ||||||||||||||||
(Gain) loss on derivatives, net | 45,976 | (28,897 | ) | 36,966 | (65,568 | ) | ||||||||||
Settlements received (paid) for matured derivatives, net | 181 | 13,705 | (2,055 | ) | 21,156 | |||||||||||
Settlements received for early terminations of derivatives, net | — | 4,234 | — | 4,234 | ||||||||||||
Premiums paid for derivatives | (5,451 | ) | (9,987 | ) | (9,475 | ) | (12,094 | ) | ||||||||
Other, net(1) | 3,636 | (1,158 | ) | 8,944 | (1,920 | ) | ||||||||||
Cash flows from operations before changes in assets and liabilities | 139,232 | 85,697 | 270,682 | 165,220 | ||||||||||||
(Increase) decrease in current assets and liabilities, net | (24,867 | ) | 7,512 | (9,372 | ) | (8,183 | ) | |||||||||
Decrease (increase) in other noncurrent assets and liabilities, net | 1,765 | (92 | ) | 1,291 | (136 | ) | ||||||||||
Net cash provided by operating activities | 116,130 | 93,117 | 262,601 | 156,901 | ||||||||||||
Cash flows from investing activities: | ||||||||||||||||
Acquisitions of oil and natural gas properties | (16,340 | ) | — | (16,340 | ) | — | ||||||||||
Capital expenditures: | ||||||||||||||||
Oil and natural gas properties | (146,509 | ) | (121,677 | ) | (341,534 | ) | (232,219 | ) | ||||||||
Midstream service assets | (1,843 | ) | (4,386 | ) | (5,205 | ) | (6,117 | ) | ||||||||
Other fixed assets | (1,002 | ) | (1,480 | ) | (4,965 | ) | (2,683 | ) | ||||||||
Proceeds from disposition of equity method investee, net of selling costs(1) | — | — | 1,655 | — | ||||||||||||
Proceeds from dispositions of capital assets, net of selling costs | 11,296 | 3,926 | 12,317 | 63,441 | ||||||||||||
Net cash used in investing activities | (154,398 | ) | (123,617 | ) | (354,072 | ) | (177,578 | ) | ||||||||
Cash flows from financing activities: | ||||||||||||||||
Borrowings on Senior Secured Credit Facility | 55,000 | 40,000 | 110,000 | 90,000 | ||||||||||||
Payments on Senior Secured Credit Facility | — | — | — | (55,000 | ) | |||||||||||
Share repurchases | (33,504 | ) | — | (87,218 | ) | — | ||||||||||
Other, net | (2,513 | ) | (4,828 | ) | (6,866 | ) | (11,971 | ) | ||||||||
Net cash provided by financing activities | 18,983 | 35,172 | 15,916 | 23,029 | ||||||||||||
Net (decrease) increase in cash and cash equivalents | (19,285 | ) | 4,672 | (75,555 | ) | 2,352 | ||||||||||
Cash and cash equivalents, beginning of period | 55,889 | 30,352 | 112,159 | 32,672 | ||||||||||||
Cash and cash equivalents, end of period | $ | 36,604 | $ | 35,024 | $ | 36,604 | $ | 35,024 |
_______________________________________________________________________________
(1) | See footnote 1 to the condensed consolidated statements of operations. |
Laredo Petroleum, Inc. | ||||||||||||||||
Selected operating data | ||||||||||||||||
Three months ended June 30, | Six months ended June 30, | |||||||||||||||
2018 | 2017 | 2018 | 2017 | |||||||||||||
(unaudited) | (unaudited) | |||||||||||||||
Sales volumes: | ||||||||||||||||
Oil (MBbl) | 2,514 | 2,482 | 4,953 | 4,602 | ||||||||||||
NGL (MBbl) | 1,778 | 1,433 | 3,341 | 2,696 | ||||||||||||
Natural gas (MMcf) | 10,947 | 8,524 | 21,120 | 16,524 | ||||||||||||
Oil equivalents (MBOE)(1)(2) | 6,116 | 5,336 | 11,814 | 10,052 | ||||||||||||
Average daily sales volumes (BOE/D)(2) | 67,206 | 58,632 | 65,270 | 55,536 | ||||||||||||
% Oil(2) | 41 | % | 47 | % | 42 | % | 46 | % | ||||||||
Average sales Realized Prices(2): | ||||||||||||||||
Oil, without derivatives ($/Bbl)(3) | $ | 63.26 | $ | 42.00 | $ | 62.58 | $ | 44.26 | ||||||||
NGL, without derivatives ($/Bbl)(3) | $ | 20.71 | $ | 13.82 | $ | 19.51 | $ | 15.07 | ||||||||
Natural gas, without derivatives ($/Mcf)(3) | $ | 1.16 | $ | 2.09 | $ | 1.46 | $ | 2.19 | ||||||||
Average price, without derivatives ($/BOE)(3) | $ | 34.10 | $ | 26.58 | $ | 34.37 | $ | 27.91 | ||||||||
Oil, with derivatives ($/Bbl)(4) | $ | 58.71 | $ | 46.95 | $ | 58.62 | $ | 48.22 | ||||||||
NGL, with derivatives ($/Bbl)(4) | $ | 20.07 | $ | 13.61 | $ | 19.15 | $ | 14.75 | ||||||||
Natural gas, with derivatives ($/Mcf)(4) | $ | 1.72 | $ | 2.12 | $ | 1.78 | $ | 2.21 | ||||||||
Average price, with derivatives ($/BOE)(4) | $ | 33.04 | $ | 28.88 | $ | 33.18 | $ | 29.66 | ||||||||
Average costs per BOE sold(2): | ||||||||||||||||
Lease operating expenses | $ | 3.70 | $ | 3.77 | $ | 3.78 | $ | 3.69 | ||||||||
Production and ad valorem taxes | 2.03 | 1.59 | 2.05 | 1.72 | ||||||||||||
Transportation and marketing expenses | 0.25 | — | 0.13 | — | ||||||||||||
Midstream service expenses | 0.07 | 0.17 | 0.09 | 0.18 | ||||||||||||
General and administrative: | ||||||||||||||||
Cash | 2.64 | 2.50 | 2.67 | 2.95 | ||||||||||||
Non-cash stock-based compensation, net | 1.75 | 1.63 | 1.69 | 1.78 | ||||||||||||
Depletion, depreciation and amortization | 8.30 | 7.12 | 8.15 | 7.17 | ||||||||||||
Total costs and expenses | $ | 18.74 | $ | 16.78 | $ | 18.56 | $ | 17.49 | ||||||||
Cash margins per BOE sold(2) | ||||||||||||||||
Realized | $ | 25.41 | $ | 18.56 | $ | 25.65 | $ | 19.37 | ||||||||
Hedged | $ | 24.35 | $ | 20.86 | $ | 24.46 | $ | 21.12 |
_______________________________________________________________________________
(1) | BOE is calculated using a conversion rate of six Mcf per one Bbl. |
(2) | The numbers presented are based on actual results and are not calculated using the rounded numbers presented in the table above. |
(3) | Realized oil, NGL and natural gas prices are the actual prices received when control passes to the purchaser/customer adjusted for quality, transportation fees, geographical differentials, marketing bonuses or deductions and other factors affecting the price received at the wellhead. See "Transportation and marketing expenses" under "Average costs per BOE sold" for costs incurred prior to control passing to the final customer per BOE. |
(4) | Price reflects the after-effects of our derivative transactions on our average Realized Prices. Our calculation of such after-effects includes current period settlements of matured derivatives in accordance with GAAP and an adjustment to reflect premiums incurred previously or upon settlement that are attributable to instruments that settled in the period. |
Laredo Petroleum, Inc. | ||||||||||||||||
Costs incurred | ||||||||||||||||
The following table presents costs incurred in the acquisition, exploration and development of oil and natural gas properties, with asset retirement obligations included in evaluated property acquisition costs and development costs, for the periods presented: | ||||||||||||||||
Three months ended June 30, | Six months ended June 30, | |||||||||||||||
(in thousands) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
(unaudited) | (unaudited) | |||||||||||||||
Property acquisition costs: | ||||||||||||||||
Evaluated | $ | 13,847 | $ | — | $ | 13,847 | $ | — | ||||||||
Unevaluated | 2,790 | — | 2,790 | — | ||||||||||||
Exploration costs | 5,108 | 5,658 | 11,245 | 21,201 | ||||||||||||
Development costs | 178,796 | 125,738 | 327,834 | 236,896 | ||||||||||||
Total costs incurred | $ | 200,541 | $ | 131,396 | $ | 355,716 | $ | 258,097 | ||||||||
Supplemental reconciliations of GAAP to non-GAAP financial measures
Non-GAAP financial measures
The non-GAAP financial measures of Adjusted Net Income and Adjusted EBITDA, as defined by us, may not be comparable to similarly titled measures used by other companies. Therefore, these non-GAAP measures should be considered in conjunction with net income or loss and other performance measures prepared in accordance with GAAP, such as operating income or loss or cash flows from operating activities. Adjusted Net Income and Adjusted EBITDA should not be considered in isolation or as a substitute for GAAP measures, such as net income or loss, operating income or loss or any other GAAP measure of liquidity or financial performance.
Adjusted Net Income
Adjusted Net Income is a non-GAAP financial measure we use to evaluate performance, prior to income tax expense or benefit, mark-to-market on derivatives, premiums paid for derivatives, gains or losses on disposal of assets and other non-recurring income and expenses and after applying adjusted income tax expense. We believe Adjusted Net Income helps investors in the oil and natural gas industry to measure and compare our performance to other oil and natural gas companies by excluding from the calculation items that can vary significantly from company to company depending upon accounting methods, the book value of assets and other non-operational factors.
The following table presents a reconciliation of income before income taxes (GAAP) to Adjusted Net Income (non-GAAP):
Three months ended June 30, | Six months ended June 30, | |||||||||||||||
(in thousands, except per share data) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
(unaudited) | (unaudited) | |||||||||||||||
Income before income taxes | $ | 33,452 | $ | 61,110 | $ | 119,972 | $ | 129,386 | ||||||||
Plus: | ||||||||||||||||
Mark-to-market on derivatives: | ||||||||||||||||
(Gain) loss on derivatives, net | 45,976 | (28,897 | ) | 36,966 | (65,568 | ) | ||||||||||
Settlements received (paid) for matured derivatives, net | 181 | 13,705 | (2,055 | ) | 21,156 | |||||||||||
Settlements received for early terminations of derivatives, net | — | 4,234 | — | 4,234 | ||||||||||||
Premiums paid for derivatives | (5,451 | ) | (9,987 | ) | (9,475 | ) | (12,094 | ) | ||||||||
(Gain) loss on disposal of assets, net | 1,358 | (805 | ) | 3,975 | (591 | ) | ||||||||||
Adjusted income before adjusted income tax expense | 75,516 | 39,360 | 149,383 | 76,523 | ||||||||||||
Adjusted income tax expense(1) | (16,614 | ) | (14,170 | ) | (32,864 | ) | (27,548 | ) | ||||||||
Adjusted Net Income | $ | 58,902 | $ | 25,190 | $ | 116,519 | $ | 48,975 | ||||||||
Net income per common share: | ||||||||||||||||
Basic | $ | 0.14 | $ | 0.26 | $ | 0.51 | $ | 0.54 | ||||||||
Diluted | $ | 0.14 | $ | 0.25 | $ | 0.51 | $ | 0.53 | ||||||||
Adjusted Net Income per common share: | ||||||||||||||||
Basic | $ | 0.26 | $ | 0.11 | $ | 0.50 | $ | 0.21 | ||||||||
Diluted | $ | 0.25 | $ | 0.10 | $ | 0.49 | $ | 0.20 | ||||||||
Weighted-average common shares outstanding: | ||||||||||||||||
Basic | 230,933 | 239,231 | 234,561 | 238,870 | ||||||||||||
Diluted | 231,706 | 244,417 | 235,501 | 244,385 |
_______________________________________________________________________________
(1) | Adjusted income tax expense is calculated by applying a statutory tax rate of 22% for the three and six months ended June 30, 2018, in response to recent changes in the tax code, and 36% for the three and six months ended June 30, 2017. |
Adjusted EBITDA
Adjusted EBITDA is a non-GAAP financial measure that we define as net income or loss plus adjustments for depletion, depreciation and amortization, non-cash stock-based compensation, net, accretion expense, mark-to-market on derivatives, premiums paid for derivatives, interest expense, gains or losses on disposal of assets, income or loss from equity method investee, proportionate Adjusted EBITDA of equity method investee and other non-recurring income and expenses. Adjusted EBITDA provides no information regarding a company's capital structure, borrowings, interest costs, capital expenditures, working capital movement or tax position. Adjusted EBITDA does not represent funds available for discretionary use because those funds are required for debt service, capital expenditures, working capital, income taxes, franchise taxes and other commitments and obligations. However, our management believes Adjusted EBITDA is useful to an investor in evaluating our operating performance because this measure:
- is widely used by investors in the oil and natural gas industry to measure a company's operating performance without regard to items excluded from the calculation of such term, which can vary substantially from company to company depending upon accounting methods, the book value of assets, capital structure and the method by which assets were acquired, among other factors;
- helps investors to more meaningfully evaluate and compare the results of our operations from period to period by removing the effect of our capital structure from our operating structure; and
- is used by our management for various purposes, including as a measure of operating performance, in presentations to our board of directors and as a basis for strategic planning and forecasting.
There are significant limitations to the use of Adjusted EBITDA as a measure of performance, including the inability to analyze the effect of certain recurring and non-recurring items that materially affect our net income or loss, the lack of comparability of results of operations to different companies and the different methods of calculating Adjusted EBITDA reported by different companies. Our measurements of Adjusted EBITDA for financial reporting as compared to compliance under our debt agreements differ.
The following table presents a reconciliation of net income (GAAP) to Adjusted EBITDA (non-GAAP):
Three months ended June 30, | Six months ended June 30, | |||||||||||||||
(in thousands) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
(unaudited) | (unaudited) | |||||||||||||||
Net income | $ | 33,452 | $ | 61,110 | $ | 119,972 | $ | 129,386 | ||||||||
Plus: | ||||||||||||||||
Depletion, depreciation and amortization | 50,762 | 38,003 | 96,315 | 72,115 | ||||||||||||
Non-cash stock-based compensation, net | 10,676 | 8,687 | 20,015 | 17,911 | ||||||||||||
Accretion expense | 1,121 | 943 | 2,227 | 1,871 | ||||||||||||
Mark-to-market on derivatives: | ||||||||||||||||
(Gain) loss on derivatives, net | 45,976 | (28,897 | ) | 36,966 | (65,568 | ) | ||||||||||
Settlements (paid) received for matured derivatives, net | 181 | 13,705 | (2,055 | ) | 21,156 | |||||||||||
Settlements received for early terminations of derivatives, net | — | 4,234 | — | 4,234 | ||||||||||||
Premiums paid for derivatives | (5,451 | ) | (9,987 | ) | (9,475 | ) | (12,094 | ) | ||||||||
Interest expense | 14,424 | 23,173 | 27,942 | 45,893 | ||||||||||||
(Gain) loss on disposal of assets, net | 1,358 | (805 | ) | 3,975 | (591 | ) | ||||||||||
Income from equity method investee(1) | — | (2,471 | ) | — | (5,539 | ) | ||||||||||
Proportionate Adjusted EBITDA of equity method investee(1)(2) | — | 6,601 | — | 12,966 | ||||||||||||
Adjusted EBITDA | $ | 152,499 | $ | 114,296 | $ | 295,882 | $ | 221,740 |
_______________________________________________________________________________
(1) | See footnote 1 to the condensed consolidated statements of operations. |
(2) | Proportionate Adjusted EBITDA of Medallion, our equity method investee until its sale on October 30, 2017, is calculated as follows: |
Three months ended June 30, | Six months ended June 30, | |||||||||||||||
(in thousands) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
(unaudited) | (unaudited) | |||||||||||||||
Income from equity method investee | $ | — | $ | 2,471 | $ | — | $ | 5,539 | ||||||||
Adjusted for proportionate share of depreciation and amortization | — | 4,130 | — | 7,427 | ||||||||||||
Proportionate Adjusted EBITDA of equity method investee | $ | — | $ | 6,601 | $ | — | $ | 12,966 | ||||||||
Contacts:
Ron Hagood: (918) 858-5504 - RHagood@laredopetro.com
18-9