NINE ENERGY SERVICE INVESTOR PRESENTATION Q4 2018 1 DISCLAIMER - - PowerPoint PPT Presentation

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NINE ENERGY SERVICE INVESTOR PRESENTATION Q4 2018 1 DISCLAIMER - - PowerPoint PPT Presentation

NINE ENERGY SERVICE INVESTOR PRESENTATION Q4 2018 1 DISCLAIMER Forward-Looking Statements & Non-GAAP Financial Measures Certain statements in this presentation are forward-looking statements that are subject to a number of risks and


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NINE ENERGY SERVICE INVESTOR PRESENTATION Q4 2018

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Forward-Looking Statements & Non-GAAP Financial Measures Certain statements in this presentation are forward-looking statements that are subject to a number of risks and uncertainties, many of which are beyond our

  • control. All statements, other than statements of historical fact included in this presentation, regarding our strategy, future operations, financial position,

estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this presentation, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “continue,” “predict,” “potential,” “project” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Forward- looking statements may include statements about the volatility of future oil and natural gas prices; our ability to successfully manage our growth, including risks and uncertainties associated with integrating and retaining key employees of the businesses we acquire; availability of skilled and qualified labor and key management personnel; our ability to accurately predict customer demand; competition in our industry; governmental regulation and taxation of the oil and natural gas industry; environmental liabilities; our ability to implement new technologies and services; availability and terms of capital; general economic conditions; operating hazards inherent in our industry; our financial strategy, budget, projections, operating results, cash flows and liquidity; and our plans, business strategy and objectives, expectations and intentions that are not historical. Although we believe that our plans, intentions and expectations reflected in or suggested by the forward-looking statements contained herein are reasonable, we can give no assurance that these plans, intentions or expectations will be achieved. For additional information regarding known material factors that could affect our operating results and performance, please see our final IPO prospectus, Current Reports on Form 8-K, Annual Report on Form 10-K and Quarterly Reports on Form 10-Q which are available at the SEC’s website, http://www.sec.gov. Should one or more of these known material risks occur, or should the underlying assumptions change or prove incorrect, our actual results, performance, achievements or plans could differ materially from those expressed or implied in any forward-looking statement. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. All subsequent written or oral forward-looking statements concerning us are expressly qualified in their entirety by the cautionary statements above. We undertake no obligation to publicly update or revise any forward-looking statements after the date they are made, whether as a result of new information, future events or otherwise, except as required by law. All information in this presentation is as of December 31, 2018 or December 31, 2017 as indicated unless otherwise noted. In addition to reporting financial results in accordance with GAAP, the Company has presented Adjusted EBITDA, Adjusted EBITDA margin and return on invested capital (ROIC). These are not recognized measures under, or an alternative to, GAAP. The Company’s management believes that this presentation provides useful information to management, analysts and investors regarding certain additional financial and business trends relating to its results of

  • perations and financial condition. In addition, management uses these measures for reviewing the financial results of the Company. These non-GAAP

measures are intended to provide additional information only and do not have any standard meaning prescribed by GAAP. Use of these terms may differ from similar measures reported by other companies. In particular, because of its limitations, Adjusted EBITDA should not be considered as a measure of discretionary cash available to use to reinvest in growth of the Company’s business, or as a measure of cash that will be available to meet the Company’s

  • bligations. These non-GAAP measures have limitations as an analytical tool, and you should not consider them in isolation or as a substitute for analysis of

the Company’s results as reported under GAAP. Industry and Market Data This presentation includes market data and other statistical information from third party sources, including independent industry publications, government publications and other published independent sources. Although the Company believes these third party sources are reliable as of their respective dates, the Company has not independently verified the accuracy or completeness of this information.

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DISCLAIMER

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COMPANY OVERVIEW

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NINE COMPANY OVERVIEW

PRO FORMA REVENUE BY SERVICE LINE3

  • Focused on ROIC – 2019 annual target of 7%
  • Leveraged to increasing completion intensity including mega-well pads, lateral lengths and stage count
  • Super lateral, deep reach capable service offering and focus
  • Agnostic to completion style – plug and perf (94%1 of horizontal market) and sleeve completions (6%1 of horizontal market)
  • Able to provide downhole conveyance services coupled with forward-leaning technology
  • Diversified completion portfolio and geography

OUR COMPANY

FINANCIAL OVERVIEW ($MM)2

1Spears and Associates, Q4 2018. 2Revenue and Adjusted EBITDA include Magnum contribution as of 10/25/18 closing date. 3Financials based on H1 2018 revenue and pro forma for Magnum acquisition.

Blue color indicates Completion Solutions segment. See appendix for Adjusted EBITDA reconciliation

Cementing 21% Coiled Tubing 19% Wireline 25% Well Service 9% Completion Tools 26% $544 $827 $58 $141 2017A 2018A Revenue

  • Adj. EBITDA

Adj. EBITDA Margin 11% Adj. EBITDA Margin 17%

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NINE’S UNIQUE STRATEGY

5 Sustainability Mitigation of financial risk Capital Intensity Wellsite Execution Real-time information Returns (ROIC) Cash flow generative Capital Light Customer Legitimacy R&D

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DRIVING VALUE FOR CONSTITUENTS

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INVESTORS

Financial Sustainability & Returns

EMPLOYEES

Socioeconomic movement & career progression

CUSTOMERS

Ability to decrease cost to complete and increase EUR

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TECHNOLOGY-DRIVEN COMPLETIONS OFFERING

SmartStart – Strategic alliance FlowGun – Owned IP

TOE OF THE WELL HORIZONTAL LATERAL

Proprietary Liner Hanger Tools MVPTM & Hollow PointTM Dissolvable– Owned IP

Offering includes tools & equipment capable of completing super laterals (10,000 ft.+)

Coil Activated Frac Sleeve – Strategic Alliance Scorpion & Magnum Extended Range Plugs – Owned IP

PRE & POST STIMULATION

Long-string Cementing

Scorpion Composite Plug– Owned IP MorphPackers StormTM Re-frac Packer – Strategic Alliance

2019E New NA HZ Wells Drilled: 22,2911 2019E NA Stage Count: 699,3771

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Extremely reliable in super laterals (10,000 ft.+)

2019E New NA HZ Wells Drilled: 22,2911

Large Diameter Coil + Memory Tools

BreakthruTM Casing Flotation Device

  • Owned IP

Nine is capable of addressing 100% of the onshore wells drilled in North America, regardless of completion type

1 Spears & Associates, Q4 2018.

MagnumDiskTM

  • Owned IP
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ABLE TO SERVE THE ENTIRE ADDRESSABLE ISOLATION TOOL MARKET WITH PROVEN DISSOLVABLE AND COMPOSITE OFFERINGS # 2 MARKET SHARE IN DISSOLVABLE FRAC PLUGS AND #1 IN POLYMER-BASED (PLASTIC) DISSOLVABLE PLUGS

PREMIER ISOLATION TOOL PROVIDER

SCORPIONTM COMPOSITE EXTENDED RANGE PLUGS

For Challenging or Impaired Casing

HIGH TEMP MVPTM (Plastic)

Eagle Ford, Haynesville, Duvernay, Bakken, MidCon, DJ/Niobrara

LOW TEMP MVPTM (Plastic)

Permian, Marcellus/Utica, Fayetteville, Montney

LOW TEMP Hollow PointTM(Magnesium)

Permian, Marcellus/Utica, Fayetteville

DISSOLVABLE FRAC PLUGS · Completely dissolvable eliminating plug drill-out · Applications to address temperatures in all NAM basins · Plastic and Magnesium offering COMPOSITE FRAC PLUGS · Fully composite · Shorter design, minimizing bit wear and tear and resulting in faster drill-out times · Variety of sizes (3.5” – 5.5”) including extended range

PLUGS All Basins

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Source: L.E.K.

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INTEGRATED COMPLETIONS SOLUTION

Scorpion™ Composite Plugs

  • Eliminates drill bit trips & reduces cycle time 2+ days
  • De-risks coil operation with fully composite materials
  • Lower cost option verses dissolvables

MagnumTM Dissolvable Plugs

  • Extends lateral & eliminates intervention
  • De-risks/eliminates coil operation
  • Reduces cycle time up to 4+ days
  • Mitigates parent child/well interference
  • Reduces footprint at surface

Breakthru™ Casing Flotation Device

  • Ensures casing reaches bottom in ultra-long laterals
  • Eliminates debris sub allowing more access to lateral

FlowGun™ Toe Valve

  • Eliminates intervention
  • Reduces cycle time up to 1+ days

NINE CAN HELP OPERATORS DESIGN AND EXECUTE THE MOST COST-EFFICIENT AND PRODUCTIVE DEEP-REACH LATERALS THROUGH BROAD OFFERING OF COMPLETION TOOL PORTFOLIO

ILLUSTRATIVE HYBRID WELLBORE SOLUTION

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SUSTAINABLE VALUE PROPOSITION OF SERVICE & TECHNOLOGY

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Service and technology drives efficiencies and lowers total cost of ownership for operators

SERVICE/TECHNOLOGY PERFORMANCE DAYS SAVED REVENUE GENERATION FOR OPERATORS1

BreakthruTM Casing Flotation Device 99% success rate in floating casing to bottom ~1.5-3 days per 6 well pad 6 well pad = ~$675k 21 well pad = ~$2.3mm Stage 1 Prep Prep and stimulate stage 1 in under 5 hours ~6 days per 6 well pad 6 well pad = $1.8mm 21 well pad = $6.0mm MVPTM & Hollow PointTM Dissolvable Plugs Dissolvable plugs eliminate drill-out times and reduce

  • verall NPT & operational risks

~24 days per 6 well pad2 6 well pad = $7.2mm 21 well pad = $24mm ScorpionTM Composite Plug 144 plugs drilled out with 1 drill-bit. Eliminated a bit trip ~15 days per 6 well pad 6 well pad = $4.5mm 21 well pad = $15mm Nine Wireline 10+ stages per day with 99% success rate ~10.5 days3 per 6 well pad 6 well pad = $3.2mm 21 well pad = $10.5mm Illustrative Days Saved and Revenue Generated ~57.75 days per 6 well pad 6 well pad = $17.3mm 21 well pad = $57.8mm

1 Assumes IP rates of 1,000 boe/d at $50 WTI and $300,000 per day/6-well pad and $1mm/21-well pad. 2 Assumes 7,000-10,000 ft. lateral. 3Assumes 70 stages per well with competitive comparison at 8 stages per day
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LONGER LATERALS l TIGHTER SPACING l PAD DRILLING

Concentration of dollars / pad + exponential impact of Non-Productive Time = highly selective customers

SINGLE-WELL PAD COMPLETIONS MULTI-WELL PAD COMPLETIONS

Source: Spears & Associates, Q4 2018; Company Estimates. 1Assumes IP rates of 1,000 boe/d at $50 WTI and $300,000 per day/6-well pad

  • Total well cost: $5-$7mm
  • ~8,000 feet of lateral

length completed

  • 40 stages
  • 12mm pounds of sand
  • 1,000 boe/d oil produced
  • Total pad cost: $30-$42mm
  • ~48,000 feet of lateral length completed
  • 240 stages
  • 72mm pounds of sand
  • 6,000 boe/d oil produced

E&P Revenue/Day = ~$50,0001

BARRIERS TO ENTRY CONTINUE TO INCREASE

Increased capital efficiency → ↑ROIC

6 wells on a pad requires 1 wireline unit

  • Dissolvable plugs can save operators

~24 days per 6-well pad in reduced drill-out time & ~12 days saved with clean-out run

  • Generating between $7.2 - $3.6mm of

incremental revenue in this featured well pad

  • Eliminates time and risk of drilling out

plugs, as well as associated service costs

E&P Revenue/Day = ~$300,0001

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MULTI-WELL PADS CONCENTRATE RISK

6 single wells required 6 wireline units

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BROAD FOOTPRINT ENABLES TECHNOLOGY LEADERSHIP

Service Coverage Area and Revenue by Region1 Major Unconventional Basins

1 YTD as of 12/31/2018 and pro forma for Magnum acquisition.

Permian 39% Rockies 3% MidCon 10% Marcellus / Utica 19% Haynesville 9% Bakken 6% Canada 4% Barnett 1% Eagle Ford 7%

FOOTPRINT IN EVERY MAJOR NAM BASIN EXCELLENT NAM REACH CAPABILITY LOCALIZED TEAMS WITH REGIONAL KNOWLEDGE

~3% of overall revenue comes from outside NAM

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BARRIERS TO ENTRY THROUGH TECHNOLOGY AND SERVICE

COMPLETION SOLUTIONS PERFORMANCE BARRIERS EQUIPMENT BARRIERS → FIT FOR “DEEP REACH”

Cementing Services

  • ~15,200 cementing jobs with on-time

rate of ~89%1

  • High-quality dedicated Midland, Delaware and Eagle

Ford labs (to API specs) with testing capabilities to cement laterals over 10,000’ long → Redundant pumps with 1,000 HP and dual-sided bulk plants

Completion Tools

  • ~112,200 isolation and stage 1 tools

and ~22,400 frac sleeves deployed2

  • Owned IP of one of the most critical and prolific

isolation tools for laterals reaching beyond 10,000’ → Highly dependable “toe” and casing flotation solutions

Wireline Services

  • ~109,200 stages with a success rate of

~99%1

  • Conveying greaseless wireline with less friction in super

laterals

  • Longest wireline completion of 19,000+ feet in lateral

Coiled Tubing Services

  • ~7,500 jobs and ~157 million running

feet of coiled tubing with a success rate greater than 99%3 (Average lateral length/job +20,000 feet)

  • ~ 75% of coil fleet is “Big Pipe” deep reach (≥2.375”

diameter) → coupled with high HP frac pumps to push coil further downhole

  • Downhole memory tool tracking real-time data

PRODUCTION SOLUTIONS PERFORMANCE BARRIERS EQUIPMENT BARRIERS → FIT FOR “DEEP REACH”

Well Services

  • 66% utilization1 rate compared to 46%

industry average4

  • Fit for purpose fleet
  • ~40% of fleet capable of performing completion-
  • riented work

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HOW DOES NINE BUILD MOATS AROUND THE BUSINESS? Service + technology / equipment + people to service the longest laterals today and tomorrow

1 Management estimates for time period from January 2014 to December 31, 2018. 2 Management estimates for time period from March 2011 to December 31, 2018. 3Management estimates

for time period from April 2014 to December 31, 2018. 4Industry average based on Association of Energy Service Companies; period from January 2014 to December 31, 2018.

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ADVANCEMENTS IN CEMENTING SOLUTIONS

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SLURRY HIGHLIGHTS Blend 27

Light-density slurry engineered to build strength 60% faster and deliver 40% higher compressive strength than similar density slurries Provides the lightness needed for depleted formations along with the strength of heavier density slurries at a fraction of the materials costs

Rapid Set 1

Breakthrough slurry chemistry that sets in about six hours, allowing operator to get back in the hole and complete the well faster

Nine Lite

Advanced formulation that delivers the lightness needed to cement mature geologies, along with the density required to hold form in the formation Can be mixed down to 10 pounds per gallon, speeding pump times and reducing NPT by as much as 48 hours per well

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5.5 13.0

2014 Q4 18

27 58

2014 2018

6% 18%

2014 Q4 2018

Nine Holds a Competitive Advantage in US Cementing Leading to Significant Market Share Gains

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1

2

200%

PROOF OF PERFORMANCE

Nine US Wireline & Completion Tools % of stages completed Nine Avg. Stages Completed Per Well Stages / Employee / Month 3

17% 24%

YE 2014 12/31/2018 Nine % rigs followed – South Texas

2

10% 12%

YE 2014 12/31/2018 Nine % rigs followed – West Texas

2 Source: 1Management estimates of legacy Nine frac stages relative to industry frac stages based on Spears & Associates, Q4 2018. Includes Magnum for closing time period of October 25, 2018. 2Management estimates and includes legacy Nine business only. 3Management estimates and includes Magnum for closing time period of October 25, 2018

115% 41% 20%

Majority Of Nine’s Completion Work Is Long Laterals Has Led To Increased Efficiencies And Higher Barriers To Entry

136%

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CUSTOMERS WHO TRUST US

COMPLETION PRODUCTION

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Diverse, blue-chip customer base with minimal concentration

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SAFETY IMPROVEMENT THROUGHOUT NINE

2.47 1.50 1.26 1.44 0.88

2014 2015 2016 2017 2018

NINE TRIR

64%

REDUCTION

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RETURNS-FOCUSED GROWTH PHILOSOPHY

Permian Midcon Northeast Bakken Rockies Canada Eagle Ford Haynesville Wireline Cementing Completion Tools Coiled Tubing Well Service

NINE PRESENCE

Balance of Organic Growth and Strategic M&A:

Augment technology portfolio + Enhance NAM footprint

ORGANIC GROWTH

  • Strategic expansion of existing service lines within NAM

basins

  • Deployment of capex for high-quality and differentiated

equipment and facilities within the most active basins

  • Market share gains through service and technology
  • Securing and maintaining best talent in the industry

DISCIPLINED M&A

  • Continue to consolidate highly fragmented industry
  • Target only best-in-class companies and management

teams

  • Competitive advantage securing and sourcing non-

marketed deals

  • Entrepreneurs want to partner and stay with “like-

minded” and nimble management team

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FINANCIAL OVERVIEW

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  • 2018 ROIC of 12% for legacy Nine business,

exceeding Management’s target of 8% and 8% for consolidated Nine, Magnum and Frac Tech business

  • Met or exceeded Management’s revenue and

adjusted EBITDA guidance every quarter

  • Grew revenue by ~52% y/y
  • Grew adjusted EBITDA by ~142% y/y
  • Cash flow from operations increased by over 15x

y/y

  • Increased number of cementing jobs by ~21% and

increased price by ~18% y/y

  • Wireline stages completed increased by ~51% and

pricing increased by ~23% y/y

  • Completion tool stages completed increased by

~115% y/y

  • Coil Tubing utilization increased by ~6% and pricing

increased by ~20% y/y

2018 FINANCIAL PERFORMANCE

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All financial and operational information includes Magnum financials from closing period of 10/25/18. See appendix for Adjusted EBITDA and ROIC reconciliation.

REVENUE ($MM)

2018 FINANCIAL AND OPERATIONAL HIGHLIGHTS

$544 $174 $206 $218 $229 $827 FY 2017 1Q 18 2Q 18 3Q 18 4Q 18 FY 2018 +~52%

ADJUSTED EBITDA ($MM)

$58 $24 $31 $38 $48 $141 FY 2017 1Q 18 2Q 18 3Q 18 4Q 18 FY 2018 +~142%

ADJUSTED EBITDA MARGIN

11% 14% 15% 18% 21% 17% FY 2017 1Q 18 2Q 18 3Q 18 4Q 18 FY 2018

Increased by ~700 basis points throughout 2018

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CAPITALIZATION

In conjunction with the Magnum transaction, which closed on October 25, 2018, Nine put a new capital structure in place with long-dated maturities and enhanced financial flexibility

  • Nine issued $400mm in aggregate

principal amount of 8.75% senior unsecured notes due 2023 at par and closed

  • n a new asset-based loan credit facility

with total commitments of $200mm in conjunction with Magnum transaction

  • Nine anticipates a reasonable pathway to

reach target leverage of 1x net debt/EBITDA

  • Current ABL availability doesn’t reflect full

impact of Magnum transaction and should increase in Q1 2019

PRO FORMA CAPITALIZATION

As of December 31, 2018 ($MM) Cash $63.6 Debt New ABL Credit Facility 35.0 New Senior Unsecured Notes 400.0 Total debt $435.0 Net Debt $371.4 Total cash $63.6 ABL availability $83.5 Total liquidity $147.1

COMMENTARY

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UNIQUE VALUE PROPOSITION

Completions focused Technology and service differentiation Ability to service the most technically demanding wells Returns-focused business philosophy Access to entire addressable market Leading market position across broad geographic footprint Entrepreneurial, highly incentivized and aligned management team Strategy works in every basin for every well

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CLOSE TO PERFECTION. FAR FROM ORDINARY. DRIVEN TO SUCCEED.

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APPENDIX

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NINE ADJ. EBITDA RECONCILIATION

Three Months Ended Year ended December 31 ($ mm unless otherwise noted) 31-Dec-18 30-Sep-18 30-Jun-18 31-Mar-18 2018 2017 2016

EBITDA Reconciliation

Net income (loss) ($77.3) $13.7 $9.0 $1.7 ($53.0) ($67.7) ($70.9) Interest expense 16.0 1.6 1.8 2.9 22.3 15.7 14.2 Depreciation 14.3 13.7 13.2 13.1 54.3 53.4 55.3 Amortization 3.9 1.9 1.9 1.9 9.6 8.8 9.1 Provision (benefit) from income taxes 0.5 1.1 .65 0.09 2.4

  • 5.0
  • 26.3

EBITDA ($42.7) $31.9 $26.6 $19.7 $35.5 $5.3 ($18.7)

Adjusted EBITDA Reconciliation

EBITDA ($42.7) $31.9 $26.6 $19.7 $35.5 $5.3 ($18.7) Impairment of property and equipment 45.7

  • 45.7
  • Impairment of goodwill and other intangible assets

32.1

  • 32.1

35.3 12.2 Transaction expenses 7.6 2.3

  • 0.4

10.3 3.6

  • Loss from discontinued operations
  • Loss or gains from the revaluation of contingent liabilities

1.5 0.5 0.6 1.1 3.3 0.4 1.7 Loss on equity investment 0.08 0.8 0.1 .08 0.3 0.4

  • Non-cash stock-based compensation expense

3.5 3.5 4.0 2.2 13.2 7.6 5.7 Loss or gains on sale of assets (.03) (1.2) (0.9) 0.4 (1.7) 4.7 3.3 Legal fees and settlements .16 1.7 0.2 0.3 2.4 1.0 4.1 Inventory writedown

  • 1.4

0.3 Restructuring costs

  • 1.1

Adjusted EBITDA 48.0 $38.4 $30.6 $24.1 $141.1 $59.6 $9.8 Revenue 229.4 218.4 205.5 173.8 827.2 543.7 282.4 % Adj. EBITDA margin 21% 18% 15% 14% 17% 11% 3%

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ROIC RECONCILIATION

Nine Legacy Consolidated

($ MM UNLESS OTHERWISE NOTED)

Three Months Ended 31-Dec-18 Year Ended 31-Dec-18 Three Months Ended 31-Dec-18 Year Ended 31-Dec-18

Net Loss ($77.3) ($53.0) ($77.3) ($53.0) Add back: Impairment of property and equipment 45.7 45.7 45.7 45.7 Impairment of goodwill 13.0 13.0 13.0 13.0 Impairment of intangibles 19.1 19.1 19.1 19.1 Interest expense 16.0 22.3 16.0 22.3 Transaction and integration costs 7.6 10.3 7.6 10.3 Provision (benefit) for deferred income taxes (.07) (.9) (.07) (.9) After-tax net operating profit (1) $24.0 $58.3 $24.0 $58.3 Total capital as of prior period-end: Total stockholders' equity $490.6 $287.4 $490.6 $287.4 Total debt 115.3 242.2 115.3 242.2 Less: Cash and cash equivalents (86.5) (17.5) (86.5) (17.5) Total capital as of prior-year end $519.4 $512.1 $519.4 $512.1 Total capital as of period-end: Total stockholders' equity $594.8 $594.8 $594.8 $594.8 Total debt 435.0 435.0 435.0 435.0 Less: Cash and cash equivalents ($63.6) ($63.6) ($63.6) ($63.6) Total Capital as of year-end, consolidated: $966.2 $966.2 $966.2 $966.2 Less: capital impact of 2018 acquisitions (2) (531.1) (531.1) Total Capital as of year-end, Nine Legacy: $435.1 $435.1 Average total capital $477.2 $473.6 $742.8 $739.1 ROIC 20% 12% 13% 8%

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(1) Because acquisitions completed in 2018 have been fully integrated into the Company’s existing operations, it is impractical to quantify the acquisitions’ contribution to the Company’s net income (loss) since their respective closing dates. As such, Nine legacy’s after-tax net operating profit has not been adjusted to exclude the net income impact of 2018 acquisitions. The Company believes that the net income impact of the acquisitions (both of which were completed in the fourth quarter of 2018) on ROIC for Nine legacy is is immaterial. (2) Amount represents incremental impact to the Company's interest expense, debt balance, cash balance and common stock, as a result of 2018 acquisitions.