The document discusses trends in drilling and completions in the Montney formation, including an increase in the number of frac stages, fluid pumped, completed length, and total proppant placed from 2010 to 2016. It also notes a shift to slickwater completions. Current completion systems are outlined and their limitations discussed. The innovation presented is the Stage Completions system, which uses a collet-activated fracturing sleeve to enable unlimited stages, higher pumping rates, and improved water management compared to plug-and-perf, sliding sleeve, and ball-drop systems. Successful field testing and initial deployment in Montney wells is also summarized.

1. Innovating Completion Optimization
October 2016

2. The Trends in Drilling & Completions
Innovation
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2010 2011 2012 2013 2014 2015 2016
WTI Prices: 2010 -Present

3. Drilling and Completion Trends in the Montney
Increased Frac Stages
 2010: Average 10 stages
 2016: Average 26 Stages
Increased Fluid Pumped
 2010: ~2,500 cubic meters
 2016: ~15,000 cubic meters
3
Source: Raymond James, Jeremy McCrea

4. Drilling and Completion Trends in the Montney
Increased Completed Length
 2010: ~1,250 meters
 2016: >2,000 meters
Increased Total Proppant Placed
 2010: ~750 tonnes
 2016: ~2,500 tonnes
4
Source: Raymond James, Jeremy McCrea

5. Drilling and Completion Trends in the Montney
Movement to Slickwater
 2010: 20% of wells using
Slickwater
 2016: >70% of wells using
Slickwater
5
Source: Raymond James, Jeremy McCrea

6. The Drivers Behind the Changing Trends
6
The Goal
The Requirements
The Solution
Superior Capital Efficiencies
Higher Productivity and EUR’s
Increased Stimulated Rock Volume
Longer Laterals Tighter Spacing
Higher Pump
Rates
Slickwater
Pinpoint
Fracturing

7. The Challenges

8. Water Management and Social Impact
8
Water Management Issues
o Slickwater becoming dominate completion
o Water to inflate coil tubing
o Potable water requirement for certain
completion styles
o Ability to access adequate water for
completion
Social Impact Issues
o Time on surface
o Noise
o Impact to residents in rural / urban corridors
o Traffic
o Pad size
o Perception of completions (high vs. low
impact)

9. Current Systems Not Meeting all Design-Change Demands
9
Based on 4.5-in (114.3-mm) Casing Plug & Perf
(Clustered Stages)
Sliding Sleeve
(Coil Tubing)
Ball-Drop
Unlimited stages Yes Yes No
Reduced pumping friction pressure Yes No No
Can use high fluid rates and sand concentration Yes No No*
Individual frac Isolation No Yes Yes
Wellbore unrestricted by ball seats or coil tubing
while fracturing
Yes No No
Reduces pumping time on surface No No Yes
Water and chemicals conservation No No Yes
Re-closable sleeve for re-fracturing or shutoff No Yes No
Extended reach capability Yes No No
Production-ready wellbore No Yes Yes
Constant ID heel to toe Yes Yes No
Open hole or Cased hole application No Yes No
Cemented annulus Yes Yes No
Completed without coiled tubing Yes No Yes
* Restricted at the toe

10. 10
Risks and Limitations of Current Systems
Plug and PerfSliding Sleeve with Coil Ball-Drop
Significant time required to place
plugs and perforate while frac
equipment is waiting
Controlling frac placement in cluster
applications and ensuring all intervals
are stimulated
Perforating gun misfire and associated
time to round trip tool string
Plug failures from skidding and pre
sets from cast iron slips
Debris and fluids from drillouts
causing damage to the formation
Difficulty drilling plugs in extended
reach applications
Additional fluid usage to place plugs
and perforating guns
Sanding off with coil in the wellbore
(Higher risk of being stuck in the
wellbore with coil)
Extra costs of friction reducers and
potential inability to the toe of the
wellbore
Setting tool packer failure (limited
number of sets per packer)
Fishing charges if tool becomes stuck
or disconnected
Equipment failures such as coil tubing
breakdowns
Pump rate limitations due to friction
pressure
Limited stage count
Limit on horizontal length due to
decreasing ball seat size
Pump rate limitations, particularly at
the toe
Decreasing seat sizes restrict flow back
Risk of ball extrusion
Screenouts can potentially lead to
partial or complete loss of wellbore

11. The Innovation

12. Stage Completions Inc.
12
Stage Completions Inc. is a downhole technology company
focused on providing innovative completion solutions
 90% privately held, 10% to be acquired by Blackbird Energy Inc. (TSX-V: BBI)
Three main product lines that are fully patented:
 SC Bowhead II: Collet-activated fracturing sleeve system designed for cased
hole and open hole applications
 SC Bowhead: Wireline deployed Baffle isolation fracturing system designed
for cased and open hole applications
 Cemented Ball Drop: ball activated fracturing sleeve designed for
multiple frac stages in a well bore
All systems designed from 2 7/8” (71mm) right through to 5 ½” (139.7 mm) casing

13. 13
Production and Operational Advantages
Pinpoint fracturing
Longer Laterals
and Increased
Stages
Higher Rates and
Tonnages
Asset in the
Wellbore
o 216 stages currently available (>700 available in near term)
o Pump down collet (elimination of coil tubing) allows for industry leading lateral
length
o Only system that can frac beyond current coil / wireline lengths
o Constant ID allows for higher pump rate and higher sand concentrations,
particularly at the toe
o Elimination of coil and ball seats leads to reduced friction
o Optimize every fracture treatment / Accurately place every fracture treatment
o Maximize stimulated reservoir volume
o Constant ID allows for maximum flowback recovery without intervention
o Collets are retrievable and sleeves can be open / closed throughout life of
wellbore
o Refrac available with re-pump down of existing collets and balls

14. Stage’s Advantages
14
Reduced Risk
o Large bore access allows clean outs from heel to toe with no restrictions
in coil or tubing size
o Collets can be removed at any point in time allowing full drift of liner
o Without retrieval, Stage system has largest flowback ID
o Ability to close specific sleeves for production challenges
o Elimination of ball extrusion
o Reduced risk of breached casing
o Sleeve and collet rated for 15k pressure limits
Reduced Cost
o Increased speed of completions – 20 -40 min vs. 1 hr 40 min or higher 
reduced direct and indirect costs (continuous pumping operations)
o Reduced fluids into formation and the associated cost
o No milling and drilling out of balls and seats
o Elimination of Coil Tubing
o Dissolvable ball allows for full wellbore access during flow back and
production operations
o Reduction in pressure pumping and associated costs

15. Discussing Costs and Savings

16. The Cost and Savings Discussion
16
Compared to Ball Drop
o Costs comparable to ball drop but with significant operational advantages
Compared to Plug and Perf
o No coil tubing unit to drill out plugs, no drill bits and accessories
o Reduction in treating and stimulation
o No stand by on frac equipment while having to set bridge plugs / perforate
o Fluid hauling is drastically reduced (reduction in fluid volume for pumping down wireline to set
bridge plugs / perf)
Compared to Sliding Sleeve with Coil
o No coil tubing unit to open and fracture each sleeve
o No coil tubing packer and accessories
o Elimination of fresh water circulating costs to maintain coil integrity
o Fresh water disposal
o Reduction in treating and stimulation

17. Stage’s Deployment

18. Quality Assurance
18
 Ability to land collets at between
1 m3/min and 5 m3/min
 Continuous completion
 Over 100 surface tests
 Varied pressures,
temperatures and rates
 100% success
 Two wells successfully completed
using Stage
 Third well installed – testing in
next two weeks
Blackbird 06-14-70-7W6M Pump Down

19. Innovation Being Deployed
Largest Sliding Sleeve Completion in Elmworth
/Pipestone Corridor

20. Blackbird’s 02/2-20 Montney Well
20
 Blackbird is implementing the
largest sliding sleeve
completion in the Elmworth /
Pipestone Corridor
 71-76 Stage sleeves
 4,000 tonnes of proppant (~2.0
tonnes per linear meter)
 ~2,150 meter lateral
 Slickwater
 Pumpers: Step Energy Services
 Estimated completion:
November 8, 2016

21. Roll Out Achievement
21
The Eagle Ford
The Cardium
The Uinta
The Bakken
The Montney
The Permian
China Successfully Being Deployed in Cased and Open Hole Applications

22. The Stage Advantage

23. Stage Checks All The Boxes
23
Based on 4.5-in (114.3-mm)
Casing
SC Bowhead II Plug & Perf (five
clusters/stage)
Sliding Sleeve
(Coil Tubing)
Ball-Drop
Unlimited stages Yes Yes Yes No
Reduced pumping friction pressure Yes Yes No No
Can use high fluid rates and sand
concentration
Yes Yes No No*
Individual frac Isolation Yes No Yes Yes
Wellbore unrestricted by ball seats or
coil tubing while fracturing
Yes Yes No No
Reduces pumping time on surface Yes No No Yes
Water and chemicals conservation Yes No No Yes
Re-closable sleeve for re-fracturing or
shutoff
Yes No Yes No
Extended reach capability Yes Yes No No
Production-ready wellbore Yes No Yes Yes
Constant ID heel to toe Yes Yes Yes No
Open hole or Cased hole application Yes No Yes No
Cemented annulus Yes Yes Yes No
Completed without coiled tubing Yes No No Yes
* Restricted at the toe

24. Disruptive Completions Technology
24
Higher Tonnages
Higher Rates
Longer laterals
More Stages
Stage’s Bowhead
II Increased EUR’s
High Utility of
Capital
Improved Water
Management