1

NINE ENERGY SERVICE

CREDIT SUISSE CONFERENCE

FEBRUARY 2019

Forward-Looking Statements & Non-GAAP Financial MeasuresCertain 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 September 30, 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 presentationprovides useful information to management, analysts and investors regarding certain additional financial and business trends relating to its results of operations 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 obligations. 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 DataThis 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.

2

DISCLAIMER

COMPANY OVERVIEW

4

NINE COMPANY OVERVIEW

PRO FORMA REVENUE BY SERVICE LINE3

• Focused on ROIC

• 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

PRO FORMA FINANCIAL OVERVIEW ($MM)2

1Spears and Associates. 2Revenue and Adjusted EBITDA pro forma to include Magnum. Calculations are based on Nine’s historical consolidated financial statements and Magnum’s historical consolidated

financial statements as adjusted to give effect to Nine’s acquisition of Magnum and the related financing transactions. H1 2018 represent annualized figures.; 3Financials based on H1 2018 revenue and pro

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

Cementing21%

Coiled Tubing19%

Wireline25%

Well Service9%

Completion Tools26%

$633

$903

$84$161

2017 H1 2018 Annualized

Revenue Adj. EBITDA

Adj. EBITDA Margin13%

Adj. EBITDA Margin18%

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

DRIVING VALUE FOR CONSTITUENTS

6

INVESTORSFinancial

Sustainability & Returns

EMPLOYEESSocioeconomic

movement & career progression

CUSTOMERSAbility to decreasecost to complete

and increase EUR

TECHNOLOGY-DRIVEN COMPLETIONS OFFERING

SmartStart – Strategic alliance

FlowGun – Owned IP

TOE OF THE WELLHORIZONTAL LATERAL

ProprietaryLiner

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

EON Ball Drop Sleeve System–Strategic Alliance

PRE & POST STIMULATION

Long-stringCementing

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

7

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

• Able to serve the entire addressable isolation tool (isolation tool = plug) market with proven dissolvable

and composite offerings (1 frac stage = 1 plug)

• 2019E NA Stage Count: 699,3771

• # 2 market share in dissolvable frac plugs and #1 in polymer-based (plastic) dissolvable plugs

PREMIER ISOLATION TOOL PROVIDER

SCORPIONTM COMPOSITE

EXTENDED RANGE PLUGSFor Challenging or Impaired Casing

HIGH TEMP MVPTM

Eagles Ford, Haynesville, Duvernay

MID TEMP MVPTM

Permian, Bakken, Midcon, DJ/Niobrara, Duvernay, Montney

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

81 Spears & Associates, Q4 2018.

9

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 4+ 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

SUSTAINABLE VALUE PROPOSITION OF SERVICE & TECHNOLOGY

10

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

SERVICE/TECHNOLOGY PERFORMANCE DAYS SAVED REVENUE GENERATION FOR OPERATORS1

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

MVPTM & Hollow PointTM

Dissolvable Plugs

Dissolvable plugs

eliminate drill-out times

and reduces overall NPT

and operational risks

~24 days per

6 well pad2

6 well pad = $7.2mm

21 well pad = $24mm

Toe Valves

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

Nine Wireline10+ 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

~55.5 days per

6 well pad

6 well pad = $16.7mm

21 well pad = $55.5mm

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. 3 Assumes 70 stages per well with competitive comparison at 8

stages per day.

ADVANCEMENTS IN CEMENTING SOLUTIONS

11

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

Nine is on the cutting-edge of slurry design and execution

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

BROAD FOOTPRINT ENABLES TECHNOLOGY LEADERSHIP

Service Coverage Area and Revenue by Region1

Major Unconventional Basins

1 YTD as of 12/31/2017 and pro forma for Magnum acquisition.

Permian 35%

Rockies 5%

MidCon 10%

Marcellus / Utica 18%

Haynesville 9%

Bakken 8%

Canada 4%

Barnett 1%

Eagle Ford 9%

FOOTPRINT IN EVERY MAJOR NAM BASIN –significant benefit to potential

strategic partners through

distribution volume

EXCELLENT NAM REACH CAPABILITY –

proximity to

the field, customer

and acreage

LOCALIZED TEAMS WITH REGIONAL KNOWLEDGE –

share best practices

internally and

with customers

~2% 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 • ~14,000 cementing jobs with on-time rate of ~90%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 • ~154,000 isolation and stage 1 tools and ~22,000 frac sleeves deployed2

• ~31,000+ dissolvable plugs deployed3

• 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 • ~99,000 stages with a success rate over 99%1

• Conveying greaseless wireline with less friction in super laterals

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

Coiled Tubing Services • ~7,100 jobs and ~147 million running feet of coiled tubing with a success rate greater than 99%4 (Average lateral length/job +20,000 feet)

• ~ 75% of coil fleet by end of year will be “Big Pipe” deep reach (≥2.375” diameter) → coupled with high HP fracpumps to push coil further downhole

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

Well Services • 65% utilization rate compared to 46% industry average5

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

oriented 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 September 30, 2018. 2 Management estimates for time period from March 2011 to September 30, 2018. 3 Management

estimates from Magnum for time period from January 2014 through September 2018. 4 Management estimates for time period from April 2014 to September 30, 2018. 5 Industry average

based on Association of Energy Service Companies; period from January 2015 to September 30, 2018.

5.5

14.5

2014 Q3 2018

27

48

2014 2017

6%

16%

2014 Q3 2018

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

15

1 2

167%

PROOF OF PERFORMANCE

Nine US Wireline & Completion Tools % of stages completed

Nine Avg. Stages Completed Per Well Stages / Employee / Month2

17%

28%

YE 2014 9/30/2018

Nine % rigs followed – South Texas2

10%

13%

YE 2014 9/30/2018

Nine % rigs followed – West Texas2

Source: 1Management estimates of legacy Nine frac stages relative to industry frac stages based on Spears & Associates, Q4 2018. Does not include Magnum; 2Company Information. Does not include Magnum

78%

65%30%

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

164%

CUSTOMERS WHO TRUST US

COMPLETION PRODUCTION

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Diverse, blue-chip customer base with minimal concentration

PROFESSIONALIZED HSE PROGRAM

IMPROVED HSE REPORTING AND PERFORMANCE ACROSS SERVICE LINES

Nine TRIR1

2.47

1.50

1.261.44

0.8

2014 2015 2016 2017 2018 YTD (Q3)

67% Reduction

171Does not include Magnum

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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

FINANCIAL OVERVIEW

19

$24

$31

$38

Q1 18 Q2 18 Q3 18

3%

8%

12%

Q1 18 Q2 18 Q3 18

Revenue

$2

$9

$14

Q1 18 Q2 18 Q3 18

$174

$206$218

Q1 18 Q2 18 Q3 18

NINE STANDALONE 2018 FINANCIAL PERFORMANCE

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2018 QUARTERLY RESULTS – LEGACY NINE ($MM)

+~18%

Does not include any financial information for MagnumSee appendix for Adjusted EBITDA and ROIC reconciliation.

Adjusted EBITDA

+~27%

+~429%

+~167%

+~6% +~25%

Adj. EBITDA Margin

14% 15% 18%

Net Income ROIC

+~51%+~50%

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PRO FORMA FINANCIAL OVERVIEWAD

JUST

ED E

BITD

A -

CAPE

X

$283

$544 $759

2016 2017 1H 2018

$57 $90 $145

2016 2017 1H 2018

$10 $60

$109

2016 2017 1H 2018

$2 $23 $44

2016 2017 1H 2018

$0.4 $13

$73

2016 2017 1H 2018

$2 $23 $44

2016 2017 1H 2018

NINE MAGNUM

Note: 1H 2018 represents annualized figures.1Pro forma calculations are based on Nine’s historical consolidated financial statements and Magnum’s historical consolidated financial statements as adjusted to give effect to Nine’s acquisition of Magnum

and the related financing transactions

ADJU

STED

EBI

TDA

% Margin:

$340

$633

$903

2016 2017 1H 2018

$12

$83

$153

2016 2017 1H 2018

$3 $38

$116

2016 2017 1H2018

PRO FORMA1

CAPE

X

$9 $45 $36

2016 2017 1H 2018

$0.2 $0.3 $0.6

2016 2017 1H 2018

$9 $46 $37

2016 2017 1H 2018

($mm)

REVE

NUE

3% 11% 14% 4% 26% 31% 4% 13% 17%

22

PRO FORMA CAPITALIZATION (9/30/18)

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

• Total upfront consideration of $493mm consisted of approximately $334mm of cash, subject to customary adjustments, as well as 5 million shares of Nine common stock

• In conjunction with the transaction, Nine issued $400mm in aggregate principal amount of 8.75% senior unsecured notes due 2023 at par and closed on a new asset-based loan credit facility with total commitments of $200mm

PRO FORMA CAPITALIZATION

As of September 30, 2018

($MM)

Cash $36.0

Debt

New ABL Credit Facility 35.0

New Senior Unsecured Notes 400.0

Total debt $435.0

Net Debt $399.0

Total cash $36.0

ABL availability $115.0

Total liquidity $151.0

COMMENTARY

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

23

CLOSE TO PERFECTION.

FAR FROM ORDINARY.

DRIVEN TO SUCCEED.

24

APPENDIX

(1) Nine closed the acquisitions of Crest Pumping Technologies on June 30, 2014 and Dak-Tana Wireline on April 30, 2014 and Beckman closed the acquisitions of RedZone Coil Tubing on May 2, 2014 and Big Lake Services, LLC on August 29, 2014. As a result, financial results relating to each acquisition for periods prior to the close of each of the aforementioned acquisitions are not reflected in the full year 2014 results. We believe that presenting investors with the annualized information for the six months ended December 31, 2014 provides a representative period of the profitability of our business in a high demand environment, including six months of results from the acquisitions of Dak-Tana Wireline, Crest Pumping Technologies and RedZone Coil Tubing and the results of the acquisition of Big Lake Services, LLC from August 29, 2014 through December 31, 2014. For comparative purposes, we have also included such information for the six months ended June 30, 2014. (2) For 2014, represents a non-cash impairment charge related to the divestiture of certain assets of a subsidiary whose primary focus was conventional completions. (3) Loss or gain related to the revaluation of liability for contingent consideration relating to our acquisition of Scorpion to be paid in shares of Company common stock and in cash, contingent upon quantities of Scorpion Composite Plugs sold during 2016 and gross margin related to the product sales for three years following the acquisition. (4) Amount represents fees and legal settlements associated with legal proceedings brought pursuant to the Fair Labor Standards Act and/or similar state laws.

NINE STANDALONE ADJ. EBITDA RECONCILIATION

Three Months Ended Year ended December 31Six months

endedSix months

ended

($ mm unless otherwise noted) 30-Sep-18 30-Jun-18 31-Mar-18 2017 2016 2015 2014

June 30,

20141

December 31,

20141

EBITDA Reconciliation

Net income (loss) $13.7 $9.0 $1.68 ($67.68) ($70.90) ($39.10) $48.00 $27.10 $20.90

Interest expense 1.6 1.8 2.9 15.7 14.2 9.9 9.6 2.8 6.7

Depreciation 13.7 13.2 13.1 53.4 55.3 58.9 40.2 13.1 27.1

Amortization 1.9 1.9 1.9 8.8 9.1 8.7 6.4 2.1 4.3

Provision (benefit) from income taxes 1.1 .65 0.09 -5.0 -26.3 -14.3 44.5 17 27.6

EBITDA $31.9 $26.6 $19.71 $5.26 ($18.70) $24.00 $148.60 $62.00 $86.60

Adjusted EBITDA Reconciliation

EBITDA $31.9 $26.6 $19.71 $5.26 ($18.70) $24.00 $148.60 $62.00 $86.60

Impairment of goodwill and other intangible assets - - - 35.3 12.2 35.5 - - -

Transaction expenses 2.3 - 0.4 3.6 - 0.2 3.9 2.8 1.1

Loss from discontinued operations2 - - - - - 0.9 28.2 2 26.2

Loss or gains from the revaluation of contingent liabilities3 0.5 0.6 1.1 0.4 1.7 -0.3 - - -

Loss on equity investment 0.8 0.1 .08 0.4 - - - - -

Non-cash stock-based compensation expense 3.5 4.0 2.2 7.6 5.7 5.5 5.4 1.9 3.5

Loss or gains on sale of assets (1.2) (0.9) 0.4 4.7 3.3 2 1 - 0.9

Legal fees and settlements4 1.7 0.2 0.3 1.0 4.1 - - - -

Inventory writedown - - - 1.4 0.3 2.8 1 - 1

Restructuring costs - - - - 1.1 3.3 - - -

Adjusted EBITDA $38.4 $30.6 $24.1 $59.58 $9.80 $73.90 $188.20 $68.80 $119.40

Revenue 218.4 205.5 173.8 543.7 282.4 478.5 663.2 240 423.2

% Adj. EBITDA margin 18% 15% 14% 11% 3% 15% 28% 29% 28%

26

NINE STANDALONE ROIC RECONCILIATION

($ MM UNLESS OTHERWISE NOTED)

Three Months Ended

30-Sep-18

Three Months Ended

30-Jun-18

Three Months Ended

31-Mar-18

Year Ended December 31

2014

After-tax net operating profit reconciliation:

Income (loss from continuing operations net of tax) $13.7 $9.0 $1.7 $76.2

Add back: Interest expense $1.6 1.8 2.9 9.6

Exclude: Taxes on interest (0.3) (0.4) (0.6) (3.5)

After-tax net operating profit $14.9 $10.5 $4.0 $82.2

Total capital as of prior period-end:1

Total stockholders' equity $472.2 $459.4 $287.4 $192.5

Total debt 115.3 115.3 242.2 140.8

Less: Cash and cash equivalents (70.9) (72.9) (17.5) (18.5)

Total capital $516.6 $501.8 $512.1 $314.8

Total capital as of period-end:

Total stockholders' equity $490.6 $472.2 $459.4 $389.6

Total debt 115.3 115.3 115.3 379.7

Less: Cash and cash equivalents (86.5) (70.9) (72.9) (24.2)

Total capital $519.4 $516.6 $501.8 $745.1

Average total capital $518.0 $509.2 $506.9 $529.9

ROIC 12% 8% 3% 16%

ROIC is defined as after-tax net operating profit divided by average total capital. After-tax net operating profit is defined as income (loss) from continuing operations (net of tax) plus interest expense, less taxes on interest. Total capital is defined as book value of equity plus the book value of debt less balance sheet cash and cash equivalents. Book value of equity is average of current and prior year total equity balances. Book value of net debt is average of current and prior period-end net debt balances.1 For 2014, total capital as of prior year-end is based on Beckman and Nine combined unaudited historical financial information.

27

28

MAGNUM STANDALONE ADJ. EBITDA RECONCILIATION

($ mm unless otherwise noted) 2016 2017 1H'18

EBITDA Reconciliation

Net income (loss) $1 $22 $21

Interest expense 0 0 0

Depreciation 1 1 0.4

Income tax expense (benefit) 0 0 1

EBITDA $2 $23 $22

Adjusted EBITDA Reconciliation

EBITDA $2 $23 $22

Transaction expenses - - -

Adjusted EBITDA $2 $23 $22

29

NINE PRO FORMA ADJ. EBITDA RECONCILIATION

($ mm unless otherwise noted) 2017 1H'18

EBITDA Reconciliation

Net income (loss) ($71) $15

Interest expense 36 18

Depreciation 55 27

Amortization 19 9

Income tax expense (benefit) (7) 3

EBITDA $31 $72

Adjusted EBITDA Reconciliation

EBITDA $31 $72

Impairment of goodwill and other intangible assets 35 -

Transaction expenses 4 0.4

Loss from the revaluation of contingent liabilities 0.4 2

Loss on equity investment 0.4 0.2

Non-cash stock-based compensation expense 8 6

(Gain) loss on sale of assets 5 (1)

Legal fees and settlements 1 0.5

Adjusted EBITDA $84 $80

The above pro forma Adjusted EBITDA calculations are based on Nine’s historical consolidated financial statements and Magnum’s historical consolidated financial statements as adjusted to give effect to Nine’s acquisition of Magnum and the related financing transactions

$57

$90

$145

$2

$23

$44

2016 2017 1H 2018(annualized)

30

MAGNUM OIL TOOLS OVERVIEW

MAGNUM STANDALONE FINANCIAL OVERVIEW ($MM)

• On October 25, 2018 Nine acquired Magnum Oil Tools

• Transaction is accretive to EPS, margins and long-term ROIC, and will significantly enhance Nine’s free

cash flow generation while reducing capital and labor intensity

• Provides patented, market-leading downhole completions products

• Proprietary designs and technology with 80+ patents

• Product sales in major U.S. unconventional basins and internationally

• Robust in-house R&D team with engineers experienced in designing and commercializing new technology

• Debt free balance sheet

$0.2 $0.3 $0.6

2016 2017 1H 2018(annualized)

REVENUE & ADJUSTED EBITDA CAPEX

4% 26% 31%% margin:

$2

$23

$44

2016 2017 1H 2018(annualized)

ADJUSTED EBITDA LESS CAPEX

Note: 1H 2018 represents annualized figures.