CJES Investor Presentation v3.3.2017 1600filecache.investorroom.com/mr5ir_cjenergy/137... · Basins...
Transcript of CJES Investor Presentation v3.3.2017 1600filecache.investorroom.com/mr5ir_cjenergy/137... · Basins...
Investor PresentationMarch 2, 2017
© C&J Energy Services, Inc. 2017 2
This presentation includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as
amended (the “Exchange Act”). The words “anticipate,” “believe,” “ensure,” “expect,” “if,” “intend,” “plan,” “estimate,” “project,” “forecast,” “predict,” “outlook,” “aim,” “will,” “could,” “should,” “potential,” “would,”
“may,” “probable,” “likely,” and similar expressions that convey the uncertainty of future events or outcomes, and the negative thereof, are intended to identify forward-looking statements. Forward-looking statements,
which are not generally historical in nature, include those that express a belief, expectation or intention regarding our future activities, plans and goals and our current expectations with respect to, among other things: Our
outlook on the market for our services and products; general business and economic conditions; crude oil and natural gas commodity prices; demand for services in our industry; our plans to deploy our fleets; our
maintenance backlog, expected recovery and future prices and utilization; our outlook with respect to industry growth and market demand; our business strategy and future activity; pricing pressure and competitive factors;
our ability to obtain or renew customer contracts; the market price and availability of materials or equipment; technological developments; financial strategy, liquidity, capital required for our ongoing operations and
acquisitions and our ability to raise additional capital; our ability to obtain permits, approvals and authorizations from governmental and third parties, and the effects of governmental regulation; dividends; future financial
and operating results; and plans, objectives, expectations and intentions.
Forward-looking statements are not assurances of future performance and actual results could differ materially from our historical experience and our present expectations or projections. These forward-looking statements
are based on our current expectations and beliefs, forecasts for our existing operations, experience, expectations and perception of historical trends, current conditions, anticipated future developments and their effect on
us, and other factors believed to be appropriate. Although we believe the expectations and assumptions reflected in these forward-looking statements are reasonable as and when made, no assurance can be given that
these assumptions are accurate or that any of these expectations will be achieved (in full or at all). Our forward-looking statements involve significant risks, contingencies and uncertainties, most of which are difficult to
predict and many of which are beyond our control. Known material factors that could cause actual results to differ materially from those in the forward-looking statements include, but are not limited to, risks associated
with the following: a decline in demand for our services, including due to declining commodity prices, overcapacity and other competitive factors affecting our industry; the cyclical nature and volatility of the oil and gas
industry, which impacts the level of exploration, production and development activity and spending patterns by exploration and production companies; a decline in, or substantial volatility of, crude oil and gas commodity
prices, which generally leads to decreased spending by our customers and negatively impacts drilling, completion and production activity; pressure on pricing for our core services, including due to competition and industry
and/or economic conditions, which may impact, among other things, our ability to implement price increases or maintain pricing on our core services; the loss of, or interruption or delay in operations by, one or more
significant customers; the failure to pay amounts when due, or at all, by one or more significant customers; changes in customer requirements in markets or industries we serve; costs, delays, regulatory compliance
requirements and other difficulties in executing our long-term growth strategy, including those related to expansion into new geographic regions and new business lines; the effects of future acquisitions on our business,
including our ability to successfully integrate our operations and the costs incurred in doing so; business growth outpacing the capabilities of our infrastructure; adverse weather conditions in oil or gas producing regions;
the effect of environmental and other governmental regulations on our operations, including the risk that future changes in the regulation of hydraulic fracturing could reduce or eliminate demand for our hydraulic
fracturing services; the incurrence of significant costs and liabilities resulting from litigation; the incurrence of significant costs and liabilities resulting from our failure to comply, or our compliance with, new or existing
environmental regulations or an accidental release of hazardous substances into the environment; the loss of, or inability to attract, key management personnel; a shortage of qualified workers; the loss of, or interruption or
delay in operations by, one or more of our key suppliers; operating hazards inherent in our industry, including the significant possibility of accidents resulting in personal injury or death, property damage or environmental
damage; accidental damage to or malfunction of equipment; uncertainty regarding our ability to improve our operating structure, financial results and profitability and to maintain relationships with suppliers, customers,
employees and other third parties following emergence from bankruptcy and other risks and uncertainties related to our emergence from bankruptcy; our ability to maintain sufficient liquidity and/or obtain adequate
financing to allow us to execute our business plan; and our ability to comply with covenants under our new credit facility.
For additional information regarding known material factors that could affect our operating results and performance, please see our most recently filed Annual Report on Form 10-K, subsequent Quarterly Reports on Form
10-Q, recent Current Reports on Form 8-K, 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 March 2, 2017 unless otherwise indicated.
Non-GAAP Financial Measures: This presentation includes Adjusted EBITDA, a measure not calculated in accordance with generally accepted accounting principles in the U.S. ("U.S. GAAP"). Please see slide 25 for a
reconciliation of Adjusted EBITDA to net income (loss), the nearest measure calculated in accordance with U.S. GAAP.
Important Disclaimer
© C&J Energy Services, Inc. 2017
C&J Energy Services
3
Market Data (3/2/2017)
Ticker (NYSE Mkt) (1) CJ
Share Price (2) $40.00
Estimated Fully Diluted Shares
Outstanding (MM)57.5
Market Capitalization ($MM) $2,300
Net Cash Position (3) ($MM) $159
Enterprise Value ($MM) $2,141
(1) The company’s common stock has been approved to be listed on the NYSE MKT and the company expects it to begin
trading on the NYSE MKT on or about 3/6/2017
(2) Share price as of 3/2/2017 as traded on the OTC Grey Market under the ticker “CJJY”
(3) As of emergence on 1/6/2017
© C&J Energy Services, Inc. 2017 4
C&J Energy Services Snapshot
• Leading Provider of Fracturing, Wireline, Coiled Tubing, Service
Rigs and Fluids Management
• One of the largest integrated providers of completion and
production services with assets deployed across all active onshore
basins in the continental United States and Western Canada
• Diversified portfolio of products and services across the life of a
well, focused on premium customers in all active onshore basins
in the continental United States and Western Canada
• A technology leader, with a state-of-the art Research and
Technology Platform focused on new products, improving margins
and assuring cost-effective supply
Diversified Revenue Across the Spectrum
Expansive Geographic FootprintKey Differentiators
• Hydraulic Fracturing Activity: ~820K HHP fracturing capacity,
11 deployed fleets and 9 fleets available, plans to deploy 1-2
fleets per quarter through 2018
• Other Equipment: 127 wireline trucks, 44 coiled tubing units,
57 pumpdown units, 36 cementing units, 459 well service rigs,
1,121 fluid trucks and support equipment
• Supply: New supply contracts support 80% of future sand
needs at attractive pricing; internal manufacturing and refurb
capabilities
• Technology: Dedicated technology center, 25+ patents; path
to new products, margin expansion and cost effective supply
Key Facts
One of North America’s largest vertically-integrated oilfield services providers with equipment, facilities and
technical expertise distributed across all active onshore basins
Basins / Shale Plays
Business Units Regions
C&J Energy Services Assets
Appalachian BasinUtica & Marcellus
Tuscaloosa-Marine ShaleHaynesville Shale
Eagle Ford Shale
Cana Woodford Shale
Permian Basin
Granite Wash
Mississippian
Niobrara
Los Angeles Basin
San Joaquin Basin
Piceance
Uinta Basin
Denver-Julesburg Basin
Bakken Shale
CardiumMontney
36%
16%
4%
20%
14% 6% 4%
Hydraulic Fracturing
Wireline & Pumping
Other D&C Services
Well Service Rigs
Fluid Services
CT
Other Well Support
Fracturing was
53% of 2014
Revenue and is
expected to
track back
towards this in
coming years
2016 Revenue: $971MM
Service Rigs
Fluids Management
Coiled Tubing
© C&J Energy Services, Inc. 2017
Our Evolution Into Today’s C&J Energy Services
5
1997 – 2011
Co
rpo
rate
De
velo
pm
en
tsP
ort
foli
o G
row
th
2012 – 2014 2015 2016 2017
2012-2014:
2012: Introduced wireline
services with acquisition of
Casedhole Solutions
2013: Acquisition of Tellus
Oilfield directional drilling
technology
2013: Acquisition of MDT™
data acquisition and
controls manufacturing
2014: Acquisition of Tiger
Casedhole Solutions,
expanding wireline services
and geographic footprint
into California
2012-2014
2013: Opened New R&T
Center in Houston, TX
2016
Mar: Josh Comstock
passed away
Jun: New CEO, CFO
and GC appointed
following strategic
management
changes
Jul: Filed for Chapter
11
2015
Mar: Combination
with Nabors’
Completion and
Production
May: Acquisition
of ESP Completion
Technology,
artificial lift
systems business
2017
Jan: Emergence
from Chapter 11
January 6th
2016
Jun: Divested Blue
Ribbon Technology
(started in 2012)
Jul: Exited MENA
Operations
1997-2011
2002: Introduced
coiled tubing services
2007: Introduced
fracturing services
1997-2011
1997: Josh Comstock
founded C&J in
Robstown, TX
2011: Initial Public
Offering on NYSE
2011: Corporate
office moved to
Houston, TX
Mar 2017
Re-introduction of
the New C&J
Energy services
2017
Feb: Divested
Total Equipment
and Services
(acquired in 2011)
Focused Our Operations
on Core Activities
© C&J Energy Services, Inc. 2017 6
Leading Provider of Products and Services Across the Life of a Well
Strong Footprint in All Active Onshore Basins in the Continental U.S. and Western Canada
Modern, High-Quality Asset Base and Streamlined Cost Structure
Robust Logistics Network Ensures Efficient Operations for Our Customers
Long-Term, Established Relationships with Blue-Chip Customer Base
Recognized Leader in Quality, Safety and Reliability
Capitalized for Growth – No Leverage and Significant Liquidity
1
2
3
4
5
6
7
Experienced Management Team with Deep Operational Expertise9
The Differentiated NAm Oilfield Services Company
Unique Research & Technology Platform
8
© C&J Energy Services, Inc. 2017
Capital Expense Driven Operational Expense Driven
• Lateral Science™
• Diverters• Plugs• SCS• Wireline • Tanks• Fluids
Management
7
Market Leadership Across the Life of the Well
Drilling and
CementingCompletions Solutions Drill / Clean Out Re-Stimulation Well Servicing Decommissions
Research and
Technology
• Primary Cementing• Remedial
Cementing• Directional Services
Horizontal Vertical • Agitator• Coiled Tubing• Rig Services• Tanks• Fluids
Management• Disposal• Snubbing• Rigs• Flowback
• Re-Con Design• Diverters• Coiled Tubing• Rig Services• SCS• Pump Down (Acid)• Wireline• Fishing Tools• Tanks • Fluids Management• Waste & Water
Disposal • Flowback
• Rig Services• Fluids
Management• Fishing Tools• Tanks• Waste & Water
Disposal • Wireline• Coiled Tubing• Special Services• Squeeze
Cementing
• Rig Services • Fishing Tools• Wireline
(dedicated)• Cementing
(dedicated)• Tanks• Fluids
Management
• Lateral Science™
• Diverters• Plugs• Re-Con Design
• Coiled Tubing (Stdby)
• Pump Down• Tanks• Fluids
Management
We are a
leading provider
in our core
service offerings
Hydraulic Fracturing (1)
Casedhole Wireline & Pumpdown
Coiled Tubing
Rig Services Fluids Management
Top 5 #1 Top 3 #2 #1
Well Construction
Well Completions Well ServicesWell
Abandonment
• Lateral Science™
• Diverters • Plugs• Fracturing• Wireline
• Wireline• Coiled Tubing• TCP• Pump Down• Tanks• Fluids
Management• Tractor
Toe Prep
Stage Frac
C&J Manufactured Products 3rd Party ProductsC&J Core Services
~70% of Total Well Cost; 3 - 6 months
R&T
Note: Rankings based on internal data and industry sources
(1) Based on active fleets as of 1/1/2017
~30% of Total Well Cost; 20+ years
© C&J Energy Services, Inc. 2017 8
Our Modern, High Quality Asset Base
• 20 hydraulic
fracturing fleets,
~820,000 HHP
• 11 deployed fleets
• Advanced,
proprietary design
with CAT-CAT
configurations
Fracturing
• 127 fit-for-purpose
casedhole wireline
trucks
• 57 pumpdown
units
• Standard in the
market for
reliability and
efficiency
Casedhole Wireline
& Pumpdown
• 36 advanced
cementing units
• Advanced in-house
lab capabilities
• #1 in Customer
Satisfaction, ‘15-16
– EnergyPoint
Survey
Cementing
• 459 workover rigs
• Capability to
support complex,
deep wells with
long laterals
• ~60% have 400 HP
or greater
Rig Services
• 1,121 service
trucks, 4,243 tanks
and 29 captive (C&J
only) salt water
disposal facilities
• Provides customers
with integrated
waste and fluids
solutions
Fluids
Management
• 44 coiled tubing
units
• Over 70% of the
fleet consists of
large diameter coil
(2” or greater)
• Majority of fleet
optimized to
support operating
depths of ~23,000
feet
Coiled Tubing
We have rationalized our fleet of equipment across all service lines, leaving us well-positioned to deliver high quality services to
our customers and attractive returns to our shareholders
© C&J Energy Services, Inc. 2017 9
Strong Presence in All Active Onshore NAm Basins
C&J is Present in All Active Onshore Basins in the Continental U.S. and Western Canada…
Basins / Shale Plays
Business Units Regions
C&J Energy Services Assets
Tuscaloosa-Marine Shale
Haynesville Shale
Eagle Ford Shale
Cana Woodford Shale
Permian Basin
Granite Wash
Mississippian
Niobrara
Los Angeles Basin
San Joaquin Basin Piceance
Uinta Basin
Denver-Julesburg Basin
Bakken Shale
CardiumMontney
Appalachian BasinUtica & Marcellus
Established Footprint Provides
a Scalable Platform
• Founded in South Texas with a proven
reputation in the Eagle Ford and
Haynesville shales, we expanded our
footprint through organic and
acquisitive growth
‒ Casedhole Solutions: Bakken,
Mid-Con, West Texas, Rockies,
North East
‒ Tiger Casedhole: California
‒ Nabors C&P: US and Western
Canada
• Today, C&J has a strong presence in
all active onshore basins in the
continental US and Western Canada
• Four out of five major service lines are
present in all active US basins, which
avails our diversified offering to all
customers and provides scale benefits
• Also serves as a platform for growth
as we develop new services and
products organically and through bolt-
on acquisitions
… with a Diversified Offering In All Active Onshore NAm Basins
0
1
2
3
4
5
WestTexas
SouthTexas
NorthEast
Mid-Continent
SouthEast
California Bakken /Rockies
Canada
Frac Wireline & Pumping Coil Tubing Rig Services Fluids Mgmt.
Number of Segments Served in Each Basin
2016 Revenue by Geography
West
Texas
34%
South
Texas /
South East
18%North East
8%
Rockies /
Bakken
14%
California
13%
Mid-Con
8%
Canada
4%
Corp.
1%
© C&J Energy Services, Inc. 2017 10
Completions Footprint Poised to Benefit from Cyclical Rebound
147.2
78.0
38.351.5
66.8
0.0
50.0
100.0
150.0
2014A 2015A 2016E 2017E 2018E
Drilling CompletionSource: Coras Oilfield Research
Source: Coras Oilfield Research
U.S. Drilling and Completion Spending is Increasing Key Drivers Point Towards Cyclical Recovery
$Bn
Spending Growth Levered to Completions
$Bn
Rigs
% HZ Rigs
Avg Rig
Efficiency
Well
Count
Stage
Count
Stages Per
Well
Frac HHP
Demand
2014 Peak 2016 Average2018 Estimate
vs 2016
447
(49% y/y)1,875
87%
+4% y/y73%
17.3 HZ Wells
per Rig-Year
14.7 HZ Wells
per Rig-Year
9,124
(51% y/y)37,773
233,521
(27% y/y)489,159
25.6 Stages per
Well +49% y/y
17.7
Stages per Well
7.2MM HHP
(25% y/y)14.7MM HHP
Frac HHP
Utilization
48%
(3% y/y)79%
Dri
ve
rs
Pe
rfo
rma
nce
Me
tric
s
� Increased Spending � Rig Efficiency
� Increased HZ Drilling � More Stages
� Greater Intensity
� Higher Frac Demand
Source: Coras Oilfield Research
13.9
22.3
4.2 4.7 4.86.9
5.7 6.24.6
5.7
0.0
6.0
12.0
18.0
24.0
2016 2017 2016 2017 2016 2017 2016 2017 2016 2017
Drilling CompletionMid-conPermian Bakken Eagle Ford Marcellus /
Utica
(1)
(1) Management estimates based on industry sources
14%70% 58% 10% 22%% ∆ in Completion
Spending
© C&J Energy Services, Inc. 2017 11
Our Frac Refurbishments Are Targeting Fleet Optimization
Cat-On-Cat• Lowest cost of total ownership
• 30% longer run times and fewer catastrophic failures
• Enables real-time data sharing
• Higher reliability throughout all conditions
Warm Start• Potential 25% fuel savings
• Higher reliability, longer equipment life
Stainless
Fluid Ends
• Higher upfront costs but longer durability
• Requires sophisticated maintenance program
Frac Iron• Internal capabilities save up to 50% on re-cert costs (1)
• Increased reliability, shortened turnaround
Support
Equipment
• Patent pending sand silo system
• Integrated silica dust management
A
D
E
B
C
Standardizing our fleets with upgraded technology will improve operating efficiency and lower cost of ownership
Illustrative Reactivation CostStandardized Fleet Will Increase Efficiency and Lower Costs
A
BC
D
E
Our In-House Manufacturing and Refurb Capabilities Provide Secure Capacity to Service Our Equipment
Rigorous preventative maintenance program
results in less downtime, lower operating costs
and ensures reliable operations
Targeting equipment upgrades, providing a
platform of standardized equipment with truly
differentiated operating capabilities
Internal maintenance and service center
provides reliable access to upgrades /
refurbishment and reduces cost
$5.0 - 6.0MM per
Warm-Stacked Fleet
Refurb & Maintenance: ~35%
($1.8 - 2.1MM)
Standardization: &
Upgrades: ~65%
($3.3 - 3.9MM)
(1) Relative to third party providers and based on internal estimates of re-certification costs
© C&J Energy Services, Inc. 2017
Optimized Logistics & Supply Chain Capabilities
12
Secure supply of critical materials and streamlined processes will provide operating leverage in the recovery
● Streamlined the number of sand and chemical vendors while meeting future volume needs
● Eliminated all take or pay contracts related to sand
● 80% of future sand needs secured at attractive pricing
● San Angelo facility provides internal capacity as third party rebuilders become capacity constrained
● Preferred supply agreement with a premier pump manufacturer for fluid ends and component needs
● Proprietary design, fully automated and tied in with our MDT™ controls (patent pending)
● Effective dust control and accurately measures amount of sand delivered per stage
● Smaller footprint on location
● Internal capacity supports sand supply and logistics, as well as lowers “Last Mile” costs
● In negotiations with key trucking vendors to ensure driver and vehicle support ahead of projected shortages
Sand & Chemicals
Fleet Repair and
Upgrades
C&J Sand
Silo System
Trucking Fleet
Active Supply Chain Initiatives…
“Last Mile” Solution…
C&J Sand Silo System
© C&J Energy Services, Inc. 2017
Maintenance and workover activity lagged through
the downturn due to capex deferrals, but activity is
expected to turn around
Increased prices shorten payback, drive frequency of
well maintenance
An increase in commodity pricing should result in
increasing workover demand for existing vertical well
infrastructure
Well services rigs are also used for frac plug mill-outs
during completions
Proliferation of horizontal wells has created a
significant service backlog – each well comprised of
vertical & horizontal components requiring well
services
13
Well Servicing Presence Provides Long-Term Upside
Deferred
Maintenance
Backlog
Commodity
Recovery
Demand
Normalization
Demand for
Completions
Activity
Aging
Horizontal Oil
Well Backlog
Supply of Older Horizontal Wells is Growing
Source: IHS
0
20,000
40,000
60,000
80,000
100,000
2000 2003 2006 2009 2012 2015
Cumulative HZ Wells >4 Years Old Horizontal Wells
~65,000 HZ
wells to enter
well
maintenance
phase over
next 4 years
Horizontal Wells Cumulative HZ Wells >4 Years Old
Horizontal well maintenance also
includes work related to the vertical
portion of the horizontal well
Multiple Drivers of Growth
� Multiple Sources of Demand Growth
� Limited Capital Needed to Drive Significant Cash Flow
� Historically Profitable in All Market Conditions
Source Source text goes here
Note: WTI prices quoted are monthly averages per Bloomberg
(1) Utilization defined as active rigs as a percent of total rigs (active rigs, available rigs, idle rigs and stacked rigs)
Activity Levels Poised For Mid / Late Cycle Recovery
Active U.S. Workover Rig Count Utilization (1)
2,066
1,826
1,170 1,099
0%
15%
30%
45%
60%
75%
0
500
1,000
1,500
2,000
2,500
Jan-14
WTI: $95
Jan-15
WTI: $47
Jan-16
WTI: $32
Jan-17
WTI: $53
Permian Texas Gulf Coast Rockies
West Coast Mid-Con Arklatex
Eastern US South Louisiana Utilization
Jan 2017 posted the
first significant yoy
increase in rig count in
key regions since 2014
18% yoy
5% yoy
Source: AESC, Bloomberg
© C&J Energy Services, Inc. 2017
~60% of Service Rigs are Class 4 or better
0
60
120
180
Class 1 Class 2 Class 3 Class 4 Class 5
0 200 400 600 800 1,000
14
High Spec Well Servicing Rig Fleet
#
Rig classifications: Class 1: 100-199 HP, Class 2: 200-299 HP, Class 3: 300- 399, Class 4: 400-499 HP, Class 5: 500+ HP
459Total Service
Rigs
275 Capable of HZ Services
Leading Provider of Service RigsA Leading Provider of Service Rigs in the Market
Premium Equipment Optimized For High Spec Services
• 2nd largest well service rig
business in NAm
• ~60% class 4+ rigs
capable of the most
complex jobs
• Top 10 customers are
majors and large
independents
• 300+ customers served in
2016
• Strong operating
presence in California,
Rockies, Permian, South
Texas and Western
Canada
• Attract new customers
due to our culture of
service and safety
• AESC 2016 Gold Safety
Award
Significant
Scale
Diversified
Footprint
Premium
Provider
Loyal
Customers
© C&J Energy Services, Inc. 2017 15
Long-Term Relationships With Blue-Chip Customers
We Seek Customers Aligned With Our Strengths
● Established E&P companies – significant portion of our revenue generated by IOCs, large independents and well-capitalized companies
● Premium acreage positions in the most active basins –targeting “manufacturing” oriented operators seeking dedicated resources
● Customers who value our technology, scale, diversification and expertise – and the efficiencies C&J can generate for them
● Our strong reputation / track record opens doors for cross-selling opportunities at existing clients – delivering integrated services
Our Relationships Have Spanned the Cycle
● Our customer base has proven to be reliable through market and company changes
● High customer retention driven by safety and superior service quality
● Differentiated capabilities and management focus resulted in our retention of nearly all customers through recent restructuring
– Minimal lost revenue from bankruptcy and now working with nearly all previous customers post emergence
● We maintain a diverse customer base with no individual customer accounting for more than 10% of 2016 revenue
Logos from next few pages
Core Customers with Deep Ties to C&J Energy Services
© C&J Energy Services, Inc. 2017 16
Our Evolutionary Technology Advantage
Perf. Guns & Switches
• One of the lowest cost
producers of perforating guns
in the industry
• Added new line of proprietary
addressable switches
• At least 20 - 30% savings over
3rd party on switches and
accessories
Lateral Science™
• Engineered solution that
optimizes the frac design and
reduces overall costs
• Over 320 wells analyzed to
date
• Successfully used on frac jobs
for Oasis, Silverback, Virtex,
Covey Park and Energen
• Product improvement and new technologies expand quality service offerings and improve operational execution and safety
• Quality services and tools that cater directly to client’s needs resulting in lower overall costs and greater customer retention
• Allows for more effective competition vs. peers and establishes C&J as the partner of choice
• Initiatives improve margins and help protect market share in current environment, positioning C&J for growth as activity levels improve
• Ensures that we have the best components and a secure supply as market intensity increases
Research & Technology Initiative
Engineering Services
• 3rd party contracts with major
IOC
– Casing w/ burst discs and
stringshot wireline tool to
replace perf cluster
• Sold proprietary Resistivity
Tool technology to a major
OEM
– Ongoing engineering services
MDT™ (1) Frac Controls
• Costs ~50% less than
competing systems
• Total fleet synchronization
improves automation and
efficiency
• Automated blender control
improves job execution
(1) Mobile Data Technologies
© C&J Energy Services, Inc. 2017 17
R&T Capabilities Provide Product Development Platform
Our Facility Supports and Enhances Our Product Portfolio
• Experienced management team with expertise in the development and manufacturing of oilfield service products
• Experts in perforating, downhole and high-temperature electronics, data acquisition, controls, drilling tools and nuclear measurement
– 25 engineers and 75 technicians dedicated to customers' most difficult well site challenges
– Sizable Patent Portfolio: 25 granted, 40 pending, 30 patent families
Operational
Efficiency
New Business
Perforating Guns & Tools Frac Pump Warm Start
Mobile Data Technologies (MDT™) Pumpdown Tension Tools
Directional Drilling (USBS)
Cost Reduction
Lateral Science™
© C&J Energy Services, Inc. 2017
1.20
0.99 0.95 0.92
1.801.60
1.10
0.50
1.00
1.50
2.00
2013 2014 2015 2016
18
Our Strong Track Record of Safety
Programs That Make a Difference
• Focus on QHSE and Risk
Management is lowering reportable
incidents / accidents and winning us
new customers
• Our customers value safety and
choose us because our record rivals
larger oilfield service majors
Quality, Health, Safety, Environmental (“QHSE”) identifies critical risks and requires our employees to apply a company-wide risk mitigation strategy in everything they do
Partnered with OSHA to adopt the Voluntary Protection Plan including comprehensive safety and health programs that exceed basic compliance; recognized by the program at 6 of our Well Service facilities (C&J has 6 out of 7 of OSHA VPP worksites)
Customized training and development centers that feature intense skill-based learning courses on well control, crane operation, field & hydraulic operations, driver and master driver training
All employees are trained to work within our industry leading initiative featuring “12 Rules to Live By” that promotes a culture where safety is second nature
QHSE OSHA VPP Employee Training Start Safe. Finish Safe
Total Recordable Incident Rate
C&J Energy Services
Industry Average (1)
(1) Industry average based on Bureau of Labor and Statistics
© C&J Energy Services, Inc. 2017 19
Quality Management System That Rivals the OFS Majors’
Our Quality Management System supports our core values and sets us apart from other companies of our size
Well Control Maintenance Telematics Partnerships
Core Focus Areas of QMS
● Improved visibility of transfers, standardized processes, ability to monitor equipment in real time
● Active employee monitoring and consequence management
● Partnerships with organizations like OSHA strengthen safety and health in the workplace
● Comprehensive training system designed to prevent injury and environmental damage
How it WorksHow it Works Why QMSWhy QMS
• Identify the critical risk
• Systematically and consistently
streamline our work processes
utilizing our best practices
• Focus on pragmatic employee
training and development
• Adopt firm-wide risk mitigation
strategy and management
analytics
• Creates standardization
throughout all facets of our
business
• Allows replication of success and
efficiency across every business
line and location
• Reduces on-the-job incidents
and accidents
• Enhances the reliability and
quality of our products
© C&J Energy Services, Inc. 2017
FINANCIAL REVIEW
© C&J Energy Services, Inc. 2017
2015
21
Summary of Key Business Drivers
Hydraulic Fracturing
Wireline and
Pumpdown
Rig Services
Fluids Management
Coiled Tubing
Product Lines 20162014 4Q 2016
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Average Active HHP (k) 1,040 840 480 430
Total Stages 29,800 18,649 11,413 2,760
Revenue ($MM) 2,038 960 354 89
Average Active Wireline Trucks 130 115 68 60
Average Active Pumpdown Units 44 56 44 42
Revenue ($MM) 455 306 159 44
Average Active Rigs 342 275 197 190
Rig Hours (k) 967 645 430 113
Revenue ($MM) 592 345 197 51
Average Active Trucks 1,216 1,076 725 640
Truck Hours (k) 3,107 2,215 1,385 302
Revenue ($MM) 357 232 133 29
Average Active CT Units 44 34 27 25
Revenue ($MM) 210 127 56 13
(1) Pro forma for March 2015 Nabors Completion & Production Services transaction
Revenue ($MM) 123 90 38 10Cementing & Other
Revenue ($MM) 85 54 34 9Other Well Support
(1) (1)
© C&J Energy Services, Inc. 2017 22
Company’s Current Outlook on Market
Hydraulic
Fracturing
Wireline &
Pumpdown
Rig Services
Fluids
Management
Coiled
Tubing
Other Well
Support
Activity Outlook Pricing Expectations
• We expect pricing to increase 30 - 35% from 2016 average
– Pricing to-date is up 15 - 25% versus the Q4’16 average
• Anticipated further improvement in 2018 of between 15 -
25% assuming activity remains strong
• Given current market trends, we anticipate redeploying 160
- 200K HHP of additional upgraded HHP in 2017 and another
160 - 240K HHP in 2018
• Anticipated utilization gains expected to drive stage count
per fleet growth of 15 - 20% in 2017 with sustained
performance through 2018
• We anticipate activating an additional 10 - 20 combined
wireline trucks and pumpdown units by the end of 2017
• An additional 10 - 20 trucks and units would be deployed in
2018 if the rebound continues to show strength
• We expect 2017 average revenue per wireline truck and
pumpdown unit to rise 20 - 25% over the 2016 average as a
result of improving pricing and utilization
• Further improvement of between 10 - 20% is expected in
2018 assuming robust activity levels
• We expect high single digit percentage increases in rig
hours across 2017 and 2018 as a result of improving
utilization and more efficient operations
• Robust demand fundamentals point to a strong mid / late
cycle recovery for well services
• We anticipate pricing remains near Q4 2016 with a modest
rise of less than 5% in 2017 and a 10%+ improvement in
2018
• We estimate low single digit percentage increases in total
truck hours in 2017 improving by 5 - 10% in 2018
• We expect 2017 pricing to remain flat versus 2016 average
and anticipate a modest rise through 2018
• Given current activity, we anticipate operating between 23
- 28 units on average in 2017 and between 25 - 32 units on
average in 2018
• We expect 2017 pricing, utilization and efficiency gains
should result in revenue per unit growth of between 35 -
40% over the 2016 average, with further improvement of
between 10 - 20% anticipated in 2018
• We anticipate annual revenue growth between 5-10% in 2017 and approximately 10 - 20% in 2018
EBITDA Margins
& Capex
• Expect consolidated adjusted EBITDA margins to be in the mid single digits for 2017 and to be in the mid-teens in 2018
– ~65 - 75% of the adjusted EBITDA to be related to our Completion Services line and ~25 - 35% related to our Well Support
Services line
– By 2018 we expect margins to be generally in line with 2014 PF margin, which included select underperforming assets
• Total capital expenditures expected to range between ~$140 - $160 million in 2017 and ~$180 - $220 million in 2018
Cementing
& Other
• We expect annual revenue growth between 20 - 25% in 2017 and approximately 40 - 50% in 2018
– Majority of the growth driven by our cementing service line
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© C&J Energy Services, Inc. 2017 23
Conservative Capital Structure
Key Highlights
• As of emergence, C&J had ~$224MM in total
liquidity comprised of $159MM of cash and
additional liquidity provided by its $100MM
credit facility
– Initial ABL availability is limited to $80MM
and subject to any outstanding letters of
credit
–At time of emergence, outstanding letters of
credit totaled ~$15MM
–We do not anticipate the need to draw on our
ABL facility in the near term
• At emergence, C&J had no outstanding long
term debt or any off-balance sheet
arrangements
Clean Balance Sheet and Strong Liquidity
Note: All metrics as of emergence on 1/6/2017
$MM At Emergence
1/6/2017
Total Debt -
Liquidity
Total Cash 159
ABL Availability 80
Letters of Credit (15)
Total Liquidity 224
© C&J Energy Services, Inc. 2017 24
Historical Financial Summary
Select Historical Financial Information
(1) Pro forma for March 2015 Nabors Completion & Production Services transaction
(2) Please see slide 25 for a reconciliation of Adjusted EBITDA to net income (loss), the nearest measure
calculated in accordance with U.S. GAAP
$MM; unless otherwise stated
2013 2014 2015 2016
Full Year Pro Forma (1)
Q1'16 Q2'16 Q3'16 Q4'16 Full Year
Revenue
Completion Services 1,933 2,597 1,327 152 124 128 140 544
Well Support Services 1,202 1,244 759 116 99 103 102 420
Other & Corporate 12 20 28 2 2 2 2 8
Total Revenue 3,147 3,861 2,115 270 225 233 244 971
Gross Profit
Total Gross Profit 842 846 240 8 (5) 16 5 24
% Margin 27% 22% 11% 3% (2%) 7% 2% 2%
Net Income / (Loss) 96 (244) (879) (428) (291) (106) (118) (944)
Adjusted EBITDA (2)
Completion Services 381 384 36 (18) (17) (6) 1 (39)
Well Support Services 249 255 100 6 2 6 4 17
Other & Corporate (66) (84) (82) (20) (17) (19) (17) (73)
Total Adjusted EBITDA 564 555 53 (32) (33) (18) (12) (95)
% Margin 18% 14% 3% (12%) (15%) (8%) (5%) (10%)
© C&J Energy Services, Inc. 2017 25
Non-GAAP Reconciliation
Adjusted EBITDA Reconciliation*
(1) Pro forma for March 2015 Nabors Completion & Production Services transaction
(2) FY 2014 and FY 2015 pro forma net income (loss) is net of acquisition related costs of $20MM and $43MM, respectively, as
disclosed in the 2015 10K filing
* We present Adjusted EBITDA, because management believes that the disclosure of Adjusted EBITDA as a measure of the Company’s operating performance allows investors to
make a direct comparison to competitors, without regard to differences in capital and financing structure and the incurrence of other charges that impact comparability of our
results of operations to those of our competitors. Investors should be aware, however, that there are limitations inherent in using Adjusted EBITDA as a measure of overall
profitability because it excludes significant expense items. An improving trend in Adjusted EBITDA may not be indicative of an improvement in the Company’s profitability. To
compensate for the limitations in utilizing Adjusted EBITDA as an operating measure, management also uses U.S. GAAP measures of performance, including operating income (loss)
and net income (loss), to evaluate performance. As required under Regulation G and Item 10(e) of Regulation S-K, the table above provides a reconciliation of Adjusted EBITDA, a
non-GAAP financial measure, to net income (loss), which is the nearest comparable U.S. GAAP financial measure for the years ended December 31, 2016, 2015, 2014 and 2013. We
generally define Adjusted EBITDA as net income (loss) before interest expense, income taxes, depreciation and amortization, other income (expense), gain or loss on the disposal of
assets and other items that our management considers to be extraordinary, such as impairment expenses, acquisition-related costs, costs and charges associated with severance,
facility closures, write-offs of bad debts and similar charges. Additionally, for the year ended December 31, 2016, we have deducted in calculating Adjusted EBITDA several categories
of expenses and charges incurred in connection with our Chapter 11 proceedings which are detailed in the table above. For the years ended December 31, 2013, 2014 and 2015, we
are presenting Adjusted EBITDA and net income on a pro forma basis for the March 2015 Nabors completion and production services transaction. For a discussion of the adjustments
made in preparing the pro forma information, please see the pro forma financial statements included in our Registration Statement on Form S-4/A, Current Report on Form 8-K/A
and Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission on February 12, 2015, March 24, 2015 and March 2, 2017, respectively. A reconciliation of
2017 and 2018 Adjusted EBITDA cannot be provided without unreasonable efforts due to the uncertainty in identifying the categories and amounts of items that will impact net
income in those periods.
$MM
2013 2014 2015 2016
Full Year Pro Forma (1)
Q1'16 Q2'16 Q3'16 Q4'16 Full Year
Net Income / (Loss) (2) 96 (244) (879) (428) (291) (106) (118) (944)
Interest Expense 94 98 99 25 122 8 2 157
Income Tax / (Benefit) 56 56 (330) (94) (11) (21) (2) (129)
Depreciation and Amortization 261 246 310 59 54 51 53 217
Other (Income) / Expense (0) 33 10 (3) (2) (7) 3 (10)
(Gain) / Loss on Disposal of Assets 9 2 (1) 3 2 (1) (1) 3
Impairment Expense 20 364 792 382 49 - 6 436
Debt Restructuring & Reorganization Costs - - - - 15 49 21 86
Inventory Write-down - - 31 1 12 0 22 35
Acquisition-Related Costs - - - 4 3 1 2 11
Severance, Facility Closures and Other 27 0 21 19 14 7 2 42
Adjusted EBITDA 564 555 53 (32) (33) (18) (12) (95)