EX-99.1 2 d154215dex991.htm EX-99.1

Raymond James 37 Annual Institutional Investors Conference March 8, 2016 th Exhibit 99.1

Forward Looking Statements This material and any oral statements made in connection with this material include "forward-looking statements" within the meaning of the Securities Act of 1933 and the Securities Exchange Act of 1934. Statements made which provide the Company’s or management’s intentions, beliefs, expectations or predictions for the future are forward- looking statements and are inherently uncertain. The opinions, forecasts, projections or other statements other than statements of historical fact, including, without limitation, plans and objectives of management of the Company are forward-looking statements. It is important to note that actual results could differ materially from those discussed in such forward-looking statements. Important factors that could cause actual results to differ materially include the risk factors and other cautionary statements contained from time to time in the Company’s SEC filings, which may be obtained by contacting the Company or the SEC. These filings are also available through the Company’s web site at http://www.patenergy.com or through the SEC’s Electronic Data Gathering and Analysis Retrieval System (EDGAR) at http://www.sec.gov. We undertake no obligation to publicly update or revise any forward-looking statement. Statements made in this presentation include non-GAAP financial measures. The required reconciliation to GAAP financial measures are included on our website and/or at the end of this presentation. The Red Circular Rig Logo, the Universal Logo, and the terms PATTERSON UTI, and APEX are registered trademarks of Patterson–UTI Energy, Inc. 2

Contract Drilling • High quality fleet of land drilling rigs including 161 APEX ® rigs • Leader in walking rig technology for pad drilling applications • Large footprint across North American drilling markets Patterson-UTI reported results for the year ended December 31, 2015 3 Components of Revenue Contract Drilling 61% Pressure Pumping 38% Oil & Natural Gas 1%

Pressure Pumping • High quality fleet of modern pressure pumping equipment • Strong reputation for regional knowledge and efficient operations • Concentrated footprint provides economies of scale 4 Patterson-UTI reported results for the year ended December 31, 2015 Components of Revenue Contract Drilling 61% Pressure Pumping 38% Oil & Natural Gas 1%

Scaling The Business Scaling our business effectively is key to our success… …both in upturns and downturns Patterson-UTI U.S. rig count and U.S. drilling staff size through February 25, 2016 5 Rig Count Drilling Staff Size Patterson-UTI U.S. Rig Count vs. U.S. Drilling Staff Size

Managing Supply Chain 6 • Sourcing and Supply Security – Negotiated critical cost elements for both Drilling and Pressure Pumping – Solidified availability of strategic commodities • Reduced Costs in 2015 – Sand costs down 25% - 35% – Sand hauling costs down 25% - 35% – Pump parts costs down 15% - 20% – Chemical costs down as much as 40%

Contract Drilling

High Quality Drilling Rigs 128 30 3 APEX ® Rig Fleet by Drawworks Horsepower 1500hp 1000hp 2000hp 8 161 APEX ® Rigs

Majority of Adjusted EBITDA from APEX ® Rigs APEX ® Other Electric Mechanical Adjusted EBITDA Contribution by Rig Class *Adjusted EBITDA contribution by rig class excluding early termination revenues for the year ended December 31, 2015. 9

The APEX-XK ® • Enhanced X-Y mobility – Walk with full set-back of pipe in mast – More efficient rig up / rig down – Walking times average 45 minutes for 10’ – 15’ well spacing • Advanced environmental spill control integrated into drilling floor • Reduced number of truck loads for rig moves • 53 APEX-XK 1500 ® and four APEX- XK 1000 ® rigs in fleet http://patenergy.com/drilling/technology 10

APEX-XK ® Integrated Walking System 11

APEX-XK ® Rig Walking on Pad 12 http://patenergy.com/drilling/technology/apexwalk/ Video of APEX-XK ® Rig 12

West Texas 17 Rigs Large Geographic Footprint PTEN’s Active Rig Count by Region as of March 3, 2016 Appalachia 23 Rigs East Texas 5 Rigs Mid-Continent 6 Rigs Rockies 2 Rigs South Texas 7 Rigs North Dakota 8 Rigs 13 Canada 2 Rigs http://patenergy.com/

Pressure Pumping

Modern Pumping Equipment 15 < 5 Years 70% 5 - 10 Years 25% >10 Years 5% Frac Horsepower by Age 4 Years Average Age

Modern Pumping Equipment Quintuplex 80% Modern Triplex 15% Legacy Triplex 5% Frac Horsepower by Pump Type 1Million Horsepower 16 Modern triplex pumps defined as being placed in service within the last seven years.

Southwest Region: Northeast Region: 35% 65% Frac Horsepower Fracturing horsepower: 663,800 Other horsepower: 32,165 Fracturing horsepower: 353,800 Other horsepower: 55,400 Market Concentration Provides Economies of Scale Pressure Pumping Areas Horsepower distribution as of December 31, 2015 17

Technology Focused PropLogic™ Sand Management System 18 • Fully enclosed well-site sand management system • More accurate than conventional sand trailers/bins • More efficient use of proppant as less sand is wasted

Technology Focused PowderStim ® Dry Friction Reducer 19 • System hydrates powder form of friction reducer directly into the fluid stream • Logistically safer and more efficient compared to liquefied friction reducers • Successful with both fresh water and heavy brines • More cost effective by utilizing produced water

Technology Focused Comprehensive Lab Services • Ability to test vendors’ chemicals enhances quality controls • Unique in-house friction flow loop test assembly for faster test results • In-house lab services are faster and more cost efficient than outsourcing 20

Strong Financial Position

Investing in Our Company 22 $598 $637 $445 $453 $976 $1,012 $974 $662 $1,229 $744 $190 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016E Year End Capital Expenditures and Acquisitions ($ in millions) 2016 Capital expenditure forecast as of February 4, 2016

Strong Financial Position 25% Debt/ Total Cap Stockholder’s Equity 4.97% Series A notes Due October 5, 2020 4.27% Series B notes Due June 14, 2022 Bank Term Loans Maturing September 27, 2017 23 * Debt and equity balances as of December 31, 2015. $255 million of bank term loans includes quarterly principal payments totaling $64 million in 2016. Principal payments in 2017 include two quarterly payments totaling $47 million and payments at the maturity date of $144 million. Capital Structure ($ in Millions) $2,561 $255 $300 $300

Total Liquidity $500 $113 $ in Millions Line of Credit Availability Cash 24 * * Debt and equity balances as of December 31, 2015. $255 million of bank term loans includes quarterly principal payments totaling $64 million in 2016. Principal payments in 2017 include two quarterly payments totaling $47 million and payments at the maturity date of $144 million. • $113 million cash • $500 million revolver availability • Of $855 million debt – $255 million matures September 2017 – $300 million matures October 2020 – $300 million matures June 2022

Why Invest in Patterson-UTI Energy? • High Quality Assets – 161 APEX ® rigs comprised primarily of 1500 horsepower and pad capable rigs – Creating value through focus on well site execution • Technology leader – Leader in walking rigs for pad drilling – Innovator in deploying latest technologies for pressure pumping • Financially flexible – Strong balance sheet – History of share buybacks – Dividends – Scalable business structure 25

Raymond James 37 th Annual Institutional Investors Conference March 8, 2016

Additional References

Three Months Ended December 31, Twelve Months Ended December 31, 2015 2014 2015 2014 Adjusted Earnings Before Interest, Taxes, Depreciation and Amortization (Adjusted EBITDA)(1): Net income (loss) $ (58,658) $ 57,583 $(294,486) $ 162,664 Income tax expense (benefit) (27,511) 41,216 (147,963) 91,619 Net interest expense 9,391 8,034 35,511 28,846 Depreciation, depletion, amortization and impairment 175,302 180,157 864,759 718,730 Impairment of goodwill - - 124,561 - Adjusted EBITDA $ 98,524 $ 286,990 $ 582,382 $1,001,859 Total revenue $ 338,566 $ 901,219 $1,891,277 $3,182,291 Adjusted EBITDA margin 29.1% 31.8% 30.8% 31.5% Adjusted EBITDA by operating segment: Contract drilling $ 95,681 $ 208,200 $ 527,204 $ 765,874 Pressure pumping 10,904 78,763 84,115 236,676 Oil and natural gas 1,184 7,671 13,431 37,094 Corporate and other (9,245) (7,644) (42,368) (37,785) Consolidated Adjusted EBITDA $ 98,524 $ 286,990 $ 582,382 $1,001,859 (1) The company makes use of financial measures that are not calculated in accordance with U.S. generally accepted accounting principles (“GAAP”) to help in the assessment of ongoing operating performance. These non-GAAP financial measures are reconciled to their most directly comparable GAAP measures in the tables above. We define Adjusted EBITDA as net income plus net interest expense, income tax expense and depreciation, depletion, amortization and impairment expense. We present Adjusted EBITDA because we believe it provides additional information with respect to both the performance of our fundamental business activities and our ability to meet our capital expenditures and working capital requirements. Adjusted EBITDA is not defined by GAAP and, as such, should not be construed as an alternative to net income (loss) or operating cash flow. We define margin as revenues less direct operating costs. We present margin because we believe it to be the component of our earnings most impacted by the variability in our contract drilling and pressure pumping operations. Margin is not defined by GAAP and, as such, should not be construed as an alternative to net income (loss). PATTERSON-UTI ENERGY, INC. Non-GAAP Financial Measures (Unaudited) (dollars in thousands) Non-GAAP Financial Measures 28