Corporate Presentation September 2017 Future Oriented Information - - PowerPoint PPT Presentation
Corporate Presentation September 2017 Future Oriented Information - - PowerPoint PPT Presentation
Corporate Presentation September 2017 Future Oriented Information In the interest of providing information regarding Paramount Resources Ltd. ("Paramount", "PRL" or the "Company") and its future plans
Future Oriented Information
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- In
the interest
- f
providing information regarding Paramount Resources Ltd. ("Paramount", "PRL" or the "Company") and its future plans and operations, this presentation contains certain forward-looking information and statements.
- The
projections, estimates and forecasts contained in such forward-looking information and statements necessarily involve a number of assumptions, and are subject to both known and unknown risks and uncertainties that may cause the Company's actual performance and financial results in future periods to differ materially from these projections, estimates and forecasts. The Advisories Appendix attached hereto lists some of the material assumptions, risks and uncertainties that these projections, estimates and forecasts are based on and are subject to.
- Accordingly, shareholders and potential investors are cautioned that events or
circumstances could cause actual results to differ materially from those predicted.
- Any use of information contained in this presentation is expressly forbidden.
- Founded in 1976; IPO in 1978; TSX: POU
- Q2 2017 production: 18,367 Boe/d (~52% Liquids)
- Q2 2017 proforma: ~79,000 Boe/d (~35% Liquids)
- Market Cap: ~2.8 Bln (134.7 MM shares @ $21.00)
- Proforma net debt at June 30, 2017 ~$450 MM(1)
(incl. Trilogy $300 MM notes due 2019)
- H2 2017 Capex: ~$250 MM
- Q4 2017 estimated production: >90,000 Boe/d
Corporate Overview
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Description Paramount Resources Ltd.
Pre-Transactions Post-Transactions
Market Cap $2.2 B $2.8 B Shares Outstanding 106.1 MM 134.7 MM Long-Term Debt nil ~$0.5 B Net Total Acres 588,500 2,669,062 Net Montney Acres 116,425 372,000 Net Duvernay Acres 63,349 223,000 P+P Undeveloped Locations(2) 103 424 P+P and High Grade Locations(2) 590 2,049 P+P Reserves (at June 1,2017) 146 MMBoe 600 MMBoe Q4/2017 Production >30 MBoe/d >90 MBoe/d
Corporate Profile
1) Refer to the heading “Non-GAAP Measures” in the Advisories Appendix 2) Refer to the heading “Reserves and Other Information” in the Advisories Appendix
Historical Performance
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1) As evaluated by McDaniel & Associates Consultants Ltd. as of June 1, 2017
Highlights
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Transaction Highlights
- April 2016 sold Musreau Plant ~$565 MM
- August 2016 sold Musreau Asset ~$2.1 Bln
- December 2016 sold royalty on Cavalier Oil Sands Asset ~$100 MM
- December 2016 dividend declared: ~3.8 MM Seven Generations shares ~$120 MM
- May 2017 closed the sale of Valhalla assets for cash of ~$150 million
- August 16, 2017 closed Apache Canada acquisition for ~$460 million
- September 12, 2017 merged with Trilogy for 1 POU share for every 3.75 TET shares
Operating Highlights
- Q2 2017 sales volumes averaged 18,367 Boe/d (52 percent liquids)
- During last week of July 2017 averaged ~30,000 Boe/d (53 percent liquids)
- All 27 wells from the 2016/17 Karr-Gold Creek Montney program have been drilled
- 21 of the program wells have been completed and 17 are on production
- Testing Karr completion design at Smoky/Resthaven with results expected Q4/2017
- New 6-well pad at Kaybob Duvernay onstream Sept 2017
Liquids Focused Assets
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Asset Description Wellhead Liquids(1) Bbl/MMcf MONTNEY Birch 25 Wapiti 90 Karr 120 Smoky/Resthaven 85 Ante Creek 120 Kaybob 220 Presley/Fir 12 DUVERNAY Kaybob North 360 Kaybob Smoky 220 Kaybob South 100 Kaybob Bigstone 60 Kaybob Pine Creek 30 Willesden Green 650
Montney Assets Duvernay Assets
1) Liquids yields based on internal estimated ultimate recoverable volumes of wellhead oil, condensate, and natural gas before surface losses and shrinkage. Refer to the heading “Reserves and Other information” in the Advisories Appendix
Diversified Assets
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Asset Description Stage of Development Location Inventory P+P | Total(1) Breakeven WTI Oil US$/Bbl(2) Breakeven NYMEX Gas US$/MMbtu(2) Wellhead Production Potential (Gross) Liquids Bbl/d | Total Boe/d(3)
2017 – 2021 Focus Assets
Karr Montney Development 76 | 227 31.92 0.92 18,000 | 43,000 (Phase 1) Wapiti Montney Development 96 | 504 28.81 1.21 13,500 | 38,500 (Phase 1) Kaybob Montney Oil Development 75 | 175 32.03 (1.06) 8,000 | 14,000 Kaybob South Duvernay Development 57 | 167 39.62 1.80 8,000 | 21,000 Kaybob Smoky Duvernay Development 49 | 66 30.52 (0.89) 13,000 | 23,000 Subtotal 353 | 1,139 60,500 Bbl/d | 139,500 Boe/d
Longer-Term Assets
Smoky/Resthaven Montney Piloting 0 | 84 Awaiting results from completion at 01-05 Hz. Ante Creek Montney Demonstration 0 | 50 Analyzing long-term production results from new 6-well pad Presley/Fir Montney Gas Development 41 | 135 9.74 2.69 720 | 10,000 Birch Montney JV Development 26 | 163 35.27 2.47 3,500 | 26,000 Kaybob North Duvernay Delineation 4 | 228 Studying offset performance from MUR Kaybob Bigstone Duvernay Delineation 0 | 50 Studying offset performance from CVX and XTO Kaybob Pine Creek Duvernay Delineation 0 | TBD Commercial potential from new completion learnings Willesden Green Duvernay Piloting 0 | 200 Analyzing results from completion at 02/13-05 Hz.
1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix 2) Breakeven analysis discounted at 10 percent before tax, based on McDaniel P+P type well assumptions, FX rate of $0.775 $US/$C and AECO basis of US$0.95/MMbtu and constant costs based on current cost structure. Breakeven oil prices based on a constant NYMEX gas price of US$3.00/MMbtu. Breakeven gas prices based on a constant WTI oil price of US$50.00/Bbl. 3) Wellhead production volumes are before surface losses and shrinkage. Potential production levels are estimated to be achieved by 2021 or sooner
Permian | Karr Comparison
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Note: Permian Operators based on data provided in Corporate Presentations for CDEV, CPE, CXO, EGN, FANG, OXY, PDCE, PE, RSPP, SM, WPX and XEC. ) Paramount Karr wells IP30 volumes are produced volumes of oil, condensate and natural gas measured at the wellhead. Sales volumes are lower due to surface losses and shrinkage. Refer the heading "Reserves and Other Information" in the Advisories Appendix.
Paramount Completion Evolution
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Gen 1
- Technology and Fluid:
Open Hole Packers and Energized Oil
- Lateral Length and Stage Spacing:
Up to 1,600m and 100m (~16 stages)
- Proppant Loading and Proppant Type:
Up to 0.6 t/m (400 lbs/ft) and uniform sand size
- Cluster Spacing and Pump Rate:
Single point entry up to 4 m3/min
Gen 2
- Technology and Fluid:
Open Hole Packers and Energized Water
- Lateral Length and Stage Spacing:
Up to 2,600m and 80m (~32 stages)
- Proppant Loading and Proppant Type:
Up to 1.5 t/m (1,000 lbs/ft) and uniform sand size
- Cluster Spacing and Pump Rate:
Single point entry up to 6 m3/min
Gen 3
- Technology and Fluid:
Cased Hole (Combo Systems) and Slickwater
- Lateral Length and Stage Spacing:
Up to 3,000m and 40m (~75) stages
- Proppant Loading and Proppant Type:
Up to 2.5 t/m (1,700 lbs/ft) and multiple sand sizes
- Cluster Spacing and Pump Rate:
Multi-point entry (down to 6m) and up to 14 m3/min
Next
- Customized Cluster Design
- Plug Optimizations
- Enhanced Zipper Fracturing
- 100% Plug and Perf
The goal is to achieve the best bang for our buck while optimizing condensate recoveries.
Midstream & Marketing Strategy
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Midstream Portfolio Positioned for Growth
- Focus assets in Montney and Duvernay have
takeaway capacity to manage growth plan through 2021
- Owned and operated infrastructure coupled with 3rd
party midstream provide balanced opex structure
- Opportunities to increase 3rd party fee revenue from
non-core infrastructure assets
Firm, Reliable Market Access
- Portfolio of firm TCPL capacity at receipt points for
growth plays in Wapiti, Karr and Kaybob
- Majority of key gas processing facilities are dually
connected to TCPL and Alliance
Pushing Further Downstream
- Contracts for firm TCPL transport to Dawn and
Malin providing exposure to downstream markets.
- Shipper status on both Pembina and Plains feeder
pipelines allowing for direct marketing of our products.
- Own and operate a major Pembina-connected
battery in Kaybob area which offers terminalling and blending opportunities.
Karr 06-18 Keyera Wapiti Kaybob North 08-09
- Q4 2017 production estimate: ~29,000 Boe/d
- Q4 2017 liquids: ~46%
- 145,000 net acres of Alberta Deep Basin Montney
- P+P inventory of 172 locations
- P+P and high grade inventory of >800 locations(1)
- Current gas processing capacity of ~145 MMcf/d
Grande Prairie Snapshot
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Operational Highlights
- Q2 2017 proforma production: ~17,000 Boe/d
- Q2 2017 proforma revenue: $37.09/Boe
- 27 wells drilled at Karr
- 17 new wells on production at Karr
- 10 wells in progress at Karr
- Testing new Montney zone at Wapiti
- Testing new completion design at Resthaven
Asset Summary
- Three Montney assets in Alberta Deep Basin trend
- Wapiti, Karr, and Smoky/Resthaven
- Over-pressured liquids-rich natural gas
- Up to three development layers
- Midstream capacity in place for growth
- Cretaceous upside across the Deep Basin trend
Grande Prairie Statistics
1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix
Kaybob Snapshot
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Operational Highlights
- Q2 2017 proforma production: ~40,000 Boe/d
- Q2 2017 proforma revenue: $27.33/Boe
- New 6-well Duvernay pad onstream September 2017
- Testing up to 3,000 lb/ft proppant in Duvernay
- New slickwater increased tonnage fracs in Montney
Oil
Asset Summary
- Three Montney assets and five Duvernay assets
- Montney assets includes oil at Ante Creek and
Kaybob with gas at Presley/Fir
- Duvernay assets range from volatile oil in Kaybob
North to wet gas in Kaybob Pine Creek
- Operating and capital synergies due to overlap,
- ptimizations, and shared midstream/marketing
Kaybob Statistics
- Q4 2017 production estimate: ~42,000 Boe/d
- Q4 2017 liquids: ~31%
- 136,000 net acres of Kaybob Duvernay
- 200,000 net acres of Kaybob & Ante Creek Montney
- P+P inventory of 226 locations
- P+P and high grade inventory of >850 locations(1)
- Operated gas plants and oil batteries
1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix
Central Alberta & Other Snapshot
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Operational Highlights
- Q2 2017 proforma production: ~22,000 Boe/d
- Q2 2017 proforma revenue: $22.35/Boe
- Tied in the Willesden Green Duvernay 02/13-05 Hz.
which tested with an IP30 of 375 Bbl/d of oil (restricted) and post tie in IP30 of ~450 Bbl/d of oil (restricted)(1)
Asset Summary
- Contiguous Willesden Green Duvernay position
with 2x over-pressure oil fairway
- Large fee title land position across resource plays
in Ellerslie, Glauconite, and Cardium
- Material acreage positions in the Ellerslie,
Glauconite, and Cardium
- Owned and operated gas processing facilities
Central Alberta & Other Statistics
- Q4 2017 production estimate: ~19,000 Boe/d
- Q4 2017 liquids: ~28%
- 63,000 net-acres of Willesden Green Duvernay
- 176,000 net-acres of fee title lands
- 95,517 net acres of core Ellerslie lands
- 76,879 net acres of core Glauconite lands
- 187,770 net acres of core Cardium lands
1) Refer to the heading “Test results” in the Advisories Appendix
Karr Montney Asset Detail
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Operational Highlights
- Rig released all 27 wells within 10% of budget
- 17 net wells on production and 10 wells in-progress
- Post 3rd party facility outage - 14 day ramp up from
zero to ~23,000 Boe/d sales by September 8th, 2017
Asset Potential
- ~45,000 net acres of liquids-rich Montney rights
- P+P inventory of 76 locations plus 151 internal high
grade locations(1)
- Next growth phase will see 06-18 Facility expanded
from 80 MMcf/d to 100 MMcf/d for late 2018
- Further growth phases in 50 MMcf/d increments up to
200 MMcf/d (2020 & 2021); currently evaluating build versus fee-for-service options
Average Peak 30 Day IP’s(2) Wellhead Boe/d Wellhead Condensate Days On 15-02 Pad (1 Well) 2,628 51% 249 04-19 Pad (4 Well) 2,558 71% 178 15-27 Pad (1 Well) 1,955 48% 145 16-04 Pad (2 Well) 1,996 43% 60 16-36 Pad (3 Well) (3) 1,933 61% 69 13-07 Pad (5 Well) 1,552 58% 33
1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix 2) Refer to the heading “Oil and Gas Measures and Definitions” in the Advisories Appendix 3) 4th well was experimental and had Peak 30 Day IP of 548 boe/d (61% Wellhead Condy)
Karr Montney P+P Type-Well
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Karr West Unit McDaniel(1) Wellhead IP30 Boe/d 2,187 Wellhead IP30 Condensate % 67 Total Sales Gas Bcf 4.4 Bcf Total Sales Condensate MBbl 590 Total Sales Volume MBoe 1,394 DCET (multi-well pad) MM$ 12.3 Btax NPV10 MM$ 9.9 Btax Return % 73.5 Payout Months 12 Karr East Unit McDaniel(1) Wellhead IP30 Boe/d 1,867 Wellhead IP30 Condensate % 62 Total Sales Gas Bcf 4.4 Bcf Total Sales Condensate MBbl 450 Total Sales Volume MBoe 1,257 DCET (multi-well pad) MM$ 12.1 Btax NPV10 MM$ 6.0 Btax Return % 42.9 Payout Months 18 Lateral Length = 2,900m Proppant Loading = 1,600 lbs/ft Stages = 73 Lateral Length = 2,900m Proppant Loading = 1,600 lbs/ft Stages = 73
Note: Includes 7 month spud to first production time and capital for gathering/compression nodes. Economics are based on constant prices and costs with US$50/Bbl WTI & US$3.00/MMbtu NYMEX, US$0.95/MMbtu AECO Basis & US$/C$ 0.775 FX 1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix
Wapiti Montney Asset Detail
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Operational Highlights
- Executing land retention and delineation program
- Testing new Montney zone in East Block
- Third party gas plant and infrastructure under
construction with scheduled Q2 2019 in-service
- Paramount completion design on new wells
Asset Potential
- ~49,000 net acres of liquids rich Montney
- Up to three development layers have been tested
- P+P inventory of 96 locations
- P+P and internal high grade of ~500 locations(1)
- Paramount is anchor tenant in gas plant and
infrastructure 150 MMcf/d expandable to 300 MMcf/d
Delineation & Retention
(Open Hole Packers)
Zone Peak 24 Hr Test Rate
(Wellhead)
Boe/d Condy %
(Wellhead)
Proppant Intensity Lbs/ft 00/13-18-67-7W6 UM 913 26 702 00/01-07-67-7W6 LM 1,462 20 707 02/04-08-67-7W6 UM 1,693 41 1,037 02/01-16-69-6W6 MM 1,336 48 549 00/01-16-69-6W6 MM 1,381 62 681 02/01-29-68-6W6 LM 1,032 71 1,325 00/09-23-67-6W6 LM 3,725 50 924
1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix
Wapiti Montney P+P Type-Well
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Wapiti West Unit McDaniel(1) Wellhead IP30 Boe/d 1,592 Wellhead IP30 Condensate % 53 Total Sales Gas Bcf 6.6 Bcf Total Sales Condensate MBbl 288 Total Sales Volume MBoe 1,551 DCET (multi-well pad) MM$ 11.8 Btax NPV10 MM$ 4.6 Btax Return % 29.8 Payout Months 25 Wapiti East Unit McDaniel(1) Wellhead IP30 Boe/d 1,847 Wellhead IP30 Condensate % 59 Total Sales Gas Bcf 5.7 Bcf Total Sales Condensate MBbl 540 Total Sales Volume Mboe 1,629 DCET (multi-well pad) MM$ 11.1 Btax NPV10 MM$ 9.2 Btax Return % 61.8 Payout Months 13 Lateral Length = 2,900m Proppant Loading = 1,600 lbs/ft Stages = 73 Lateral Length = 3,000m Proppant Loading = 1,600 lbs/ft Stages = 75
Note: Includes 7 month spud to first production time and capital for gathering/compression nodes. Economics are based on constant prices and costs with US$50/Bbl WTI & US$3.00/MMbtu NYMEX, US$0.95/MMbtu AECO Basis & US$/C$ 0.775 FX 1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix
Kaybob Duvernay Asset Details
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Operational Highlights
- New 6-well pad onstream September 2017
- Testing up to 3,000 lbs/ft proppant loading intensity
- Near-term data acquisition projects include micro-
seismic and fiber for optimizing well placement, well spacing and cluster design
Asset Potential
- ~136,000 core Kaybob Duvernay acres
- Development focus on Smoky and Kaybob South
- P+P inventory of 110 locations
- P+P and internal high grade ~400 locations(1)
Kaybob Smoky
- Near-term production to Smoky 06-16 Gas Plant
with two options for longer-term growth including Kaybob 08-09 Gas Plant and SemCAMS KA
Kaybob South
- Existing 40 MMcf/d third party capacity from field
to sales with expansion options for up to 40 MMcf/d of incremental capacity
1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix
Kaybob Duvernay P+P Type-Well
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Kaybob Smoky Unit McDaniel(1) Internal(1) Wellhead IP30 Boe/d 1,505 2,104 Wellhead IP30 Condensate % 67 67 Total Sales Gas Bcf 2.1 2.9 Total Sales Condensate MBbl 439 615 Total Sales Volume MBoe 900 1,260 DCET (multi-well pad) MM$ 11.1 13.4 Btax NPV10 MM$ 7.3 13.0 Btax Return % 50.4 69.7 Payout Months 18 14 Kaybob South Unit McDaniel(1) Internal(1) Wellhead IP30 Boe/d 2,147 2,634 Wellhead IP30 Condensate % 62 62 Total Sales Gas Bcf 4.2 5.9 Total Sales Condensate MBbl 400 550 Total Sales Volume MBoe 1,303 1,798 DCET (multi-well pad) MM$ 11.9 13.7 Btax NPV10 MM$ 3.8 7.8 Btax Return % 27.1 42.0 Payout Months 27 19 McDaniel P+P Lateral Length = 2,600m Proppant Loading = 1,500 lbs/ft Stages = 33 McDaniel P+P Lateral Length = 2,200m Proppant Loading = 2,000 lbs/ft Stages = 37
Note: Includes 7 month spud to first production time, capital for gathering/compression nodes and capital for artificial lift (added 24 – 36 months). Internal P+P Type-Well is McDaniel normalized to 3,000 lbs/ft (0.4 to 1.0 ) and 2,600m lateral length (0.8 to 1.0). Economics are based on constant prices and costs with US$50/Bbl WTI & US$3.00/MMbtu NYMEX, US$0.95/MMbtu AECO Basis & US$/C$ 0.775 FX 1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix 1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix
Kaybob Montney Oil Development
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Operational Highlights
- Gross June 2017 oil production: ~4,900 Bbl/d
- Gross June 2017 total production: ~7,800 Boe/d
- 10 of 16 2017 gross wells have been rig released
- New completion design has 45% more stages and
290% higher proppant loading intensity
Asset Potential
- Discovered 2011 with 132 wells drilled to date
- ~32,000 net-acres
- P+P inventory of 75 locations with an additional 100
internal high grade locations(1)
- Paramount 12-10 Battery with 20,000 Bbl/d of sour
fluid handling capacity
Description Wells Average First 3 Months Oil On Production 2011 18 38,271 Bbl On Production 2012 25 44,325 Bbl On Production 2013 35 27,125 Bbl On Production 2014/15 31 17,983 Bbl New Completion Design 2016/17 11 34,368 Bbl McDaniel Average P+P Type Well N/A 25,700 Bbl
1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix
Kaybob Montney P+P Type Well
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Kaybob Montney Unit McDaniel(1) Internal(1) Wellhead IP30 Boe/d 545 658 Wellhead IP30 Oil % 80 80 Total Sales Gas Bcf 0.6 0.6 Total Sales Oil/Condensate MBbl 152 152 Total Sales Volume MBoe 258 258 DCET (multi-well pad) MM$ 3.0 3.0 Btax NPV10 MM$ 2.0 3.0 Btax Return % 62.1 106.4 Payout Months 12 8 McDaniel P+P Lateral Length = 2,000m Proppant Loading = 167 lbs/ft Stages = 40
Completion Design Update
- New completion design has 45% more stages and
290% higher proppant loading intensity
- Internal P+P type well assumes recovery of 100
MBbl in first three years versus McDaniel average P+P which recovers 100 MBbl in first five years
- Acceleration of recoveries only (no incremental
reserves), same design, and same cost
Note: Includes 7 month spud to first production time and capital for gathering/compression nodes. Economics are based on constant prices and costs with US$50/Bbl WTI & US$3.00/MMbtu NYMEX, US$0.95/MMbtu AECO Basis & US$/C$ 0.775 FX 1) Refer to the heading “Reserves and Other Information” in the Advisories Appendix
Gross Inventory Estimate(1)
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Description Gross Inventory McDaniel P+P Focus Assets 353 Internal High Grade Focus Assets 836 Total Focus Assets 1,189 McDaniel P+P Other Properties 72 Internal High Grade Other Properties 788 Total Focus Assets and Other Properties 2,049 Remaining Internal 1,705 Grand Total 3,754
1) McDaniel P+P effective June 1, 2017. Internal high grade is based on internal economic thresholds and recovery schemes. Internal remaining is based on reduced economic thresholds and more aggressive recovery schemes. Other properties include Montney assets at Birch, Presley, Fir, Ante Creek, Smoky, and Resthaven. Other properties include Duvernay assets at Kaybob North, Kaybob Bigstone, Kaybob Pine Creek, and Willesden Green
Focus Assets – Btax Breakeven @ 10%(1)
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1) Breakeven analysis discounted at 10 percent before tax, based on McDaniel P+P type well assumptions using constant costs, FX rate of $0.775 $US/$C and AECO basis of US$0.95/MMbtu. Breakeven
- il prices based on a constant NYMEX gas price of US$3.00/MMbtu. Breakeven gas prices based on a constant WTI oil price of US$50.00/Bbl. Refer to the heading “Reserves and Other Information” in
the Advisories Appendix
Focus Assets – Btax Return and NPV10(1)
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1) McDaniel P+P unless (Internal), US$50/Bbl WTI & US$3.00/MMbtu NYMEX, US$0.95/MMbtu AECO Basis & FX US$/C$ 0.775. Refer to the heading “Reserves and Other Information” in the Advisories Appendix
Strategic and Long-Term Investments
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(1) Please refer to the heading “Reserves and Other Information” in the Advisories Appendix (2) Publicly disclosed by competitor
Paramount in a Nutshell
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Well-established base production and cash flow Diversified portfolio of liquids rich assets Firm takeaway in place to deliver profitable growth Strong balance sheet and financial flexibility Talented team with a proven ability to deliver top tier results Demonstrating a culture of operational excellence and delivering on our promises
ADVISORIES APPENDIX
Advisories
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Forward-Looking Information Certain statements in this presentation constitute forward-looking information under applicable securities legislation. Forward-looking information typically contains statements with words such as "anticipate", "believe", "estimate", "will", "expect", "plan", "intend", "propose", or similar words suggesting future outcomes or an outlook. Forward-looking information in this presentation includes, but is not limited to: projected production and sales volumes (and the liquids component thereof); forecast capital expenditures; reserve and resource estimates; exploration, development and associated operational plans and strategies (including facility expansions and potential increases in third party processing and related capacities); estimated numbers of drilling locations; the anticipated increase in the size of Paramount’s credit facilities; forecast liquids yields from, and gross liquids and total production potential of, each of the Company’s main operating areas as well as the estimated break-even prices for production from and the projected internal rates of return and discounted net present value of wells in each of these areas; ongoing enhancements in Paramount’s well completion techniques; the projected ability of the Company’s existing midstream infrastructure and commitments to facilitate its Montney and Duvernay development plans through 2021; anticipated opportunities to increase third party fee revenue from non-core midstream assets and realize operating and capital synergies in the Kaybob area; projected type well production profiles (including the liquids component thereof) and associated net present value, internal rate of return and payout estimates (and the initial production rate, sales volumes, capital and operating cost, liquids yield, commodity price and other assumptions used to generate such profiles and estimates) and general business strategies and objectives Such forward-looking information is based on a number of assumptions which may prove to be incorrect. Assumptions have been made with respect to the following matters, in addition to any other assumptions identified in this presentation or Paramount’s continuous disclosure documents: future natural gas and Liquids prices; royalty rates, taxes and capital, operating, general & administrative and other costs; foreign currency exchange rates and interest rates; general economic, market and business conditions; the ability of Paramount to obtain the required capital to finance its exploration, development and other operations and meets its commitments and financial obligations; the ability of Paramount to obtain equipment, services, supplies and personnel in a timely manner and at an acceptable cost to carry out its activities; the ability of Paramount to secure adequate product processing, transportation, de-ethanization, fractionation and storage capacity
- n acceptable terms; the ability of Paramount to market its natural gas and Liquids successfully to current and new customers; the ability of Paramount and its industry
partners to obtain drilling success (including in respect of anticipated production volumes, reserves additions, Liquids yields and resource recoveries) and operational improvements, efficiencies and results consistent with expectations; the timely receipt of required governmental and regulatory approvals; and anticipated timelines and budgets being met in respect of drilling programs and other operations. Although Paramount believes that the expectations reflected in such forward looking information are reasonable, undue reliance should not be placed on them as Paramount can give no assurance that such expectations will prove to be correct. Forward-looking information is based on current expectations, estimates and projections that involve a number of risks and uncertainties which could cause actual results to differ materially from those anticipated by Paramount and described in the forward- looking information. These risks and uncertainties include and/or relate (but are not limited) to: fluctuations in natural gas and Liquids prices; changes in foreign currency exchange rates and interest rates; the uncertainty of estimates and projections relating to future revenue, future production, reserve additions, Liquids yields (including condensate to natural gas ratios), resources recoveries, royalty rates, taxes and costs and expenses; the ability to secure adequate product processing, transportation, de-ethanization, fractionation and storage capacity on acceptable terms; operational risks in exploring for, developing and producing natural gas and Liquids; the ability to obtain equipment, services, supplies and personnel in a timely manner and at an acceptable cost; potential disruptions or unexpected technical or other difficulties in designing, developing, expanding or operating new, expanded or existing facilities (including third-party facilities); processing, pipeline, de-ethanization, and fractionation infrastructure outages, disruptions and constraints; risks and uncertainties involving the geology of oil and gas deposits; the uncertainty of reserves and resources estimates; general business, economic and market conditions; the ability to generate sufficient cash flow from
- perations and obtain financing to fund planned exploration, development and operational activities and meet current and future commitments and obligations (including
product processing, transportation, de-ethanization, fractionation and similar commitments and debt obligations); changes in, or in the interpretation of, laws, regulations or policies (including environmental laws); the ability to obtain required governmental or regulatory approvals in a timely manner and to enter into and maintain leases and licenses; the effects of weather; the timing and costs of future abandonment and reclamation obligations and potential liabilities for environmental damage and contamination; uncertainties regarding aboriginal claims and in maintaining relationships with local populations and other stakeholders; the outcome of existing and potential lawsuits, regulatory actions, audits and assessments; and other risks and uncertainties described elsewhere in this presentation and in Paramount’s filings with Canadian securities authorities, including its Annual Information Form.
The foregoing list of risks is not exhaustive. Additional information concerning these and other factors which could impact Paramount are included in Paramount’s Annual Information Form. The forward-looking information contained in this presentation is made as of the date hereof and, except as required by applicable securities law, Paramount undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise. Oil and Gas Measures and Definitions Abbreviations Liquids Natural Gas Oil Equivalent Bbl Barrels Mcf Thousands of cubic feet Boe Barrels of oil equivalent MBbl Thousands of barrels Bcf Billions of cubic feet MBoe Thousands of barrels of oil equivalent Bbl/d Barrels per day MMcf/d Millions of cubic feet per day MMBoe Millions of barrels of oil equivalent NGLs Natural gas liquids Boe/d Barrels of oil equivalent per day Condensate Pentane and heavier hydrocarbons All natural gas equivalency volumes have been derived using the ratio of six thousand cubic feet of natural gas to one barrel of oil. Equivalency measures may be misleading, particularly if used in isolation. A conversion ratio of six thousand cubic feet of natural gas to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the well head. During the six months ended June 30, 2017, the value ratio between crude oil and natural gas was approximately 23:1. This value ratio is significantly different from the energy equivalency ratio of 6:1. Using a 6:1 ratio would be misleading as an indication of value. Peak 30 Day IP is the highest daily average production rate over a 30 day consecutive period for an individual well, measured at the wellhead. Sales volumes will be lower due to shrinkage. Reserves and Other Information The Company’s reserves, including the reserves acquired in the acquisition of Apache Canada Ltd. (ʺApache Canadaʺ) and the merger with Trilogy Energy Corp. (ʺTrilogyʺ), were evaluated by McDaniel and Associates Consultants Ltd. (ʺMcDanielʺ) as of June 1, 2017 (the ʺMcDaniel Reserve Reportsʺ). P+P Undeveloped Locations referred to in this document are the gross number of undrilled well locations included in the McDaniel Reserve Reports. P+P and High Grade Locations referred to in this document are the P+P Undeveloped Locations plus internally identified high grade locations which have not been assigned reserves by McDaniel. Internal high grade is based on internal economic thresholds and recovery schemes. Internal remaining is based on reduced economic thresholds and more aggressive recovery schemes. Other properties include Montney assets at Birch, Presley, Fir, Ante Creek, Smoky, and Resthaven. Other properties include Duvernay assets at Kaybob North, Kaybob Bigstone, Kaybob Pine Creek, and Willesden Green. Type well information labelled ‘McDaniel’ is derived from type well models incorporated in the McDaniel Reserve Reports. Type well information labelled ‘Internal’ is derived from internally generated type well models. The term “IRR” means the internal rate of return. The "IP 30" is the initial 30 days of production. Paramount has provided information with respect to certain of its plays and emerging opportunities which is "analogous information" as defined in NI 51-101. This analogous information includes Paramount's internally generated production type curves for certain of its wells, internal estimates of estimated ultimate recovery ("EUR") (as defined in the Society of Petroleum Engineers - Petroleum Resources Management System) and total sales volumes. This analogous information is derived from Paramount's internal sources as well as from a variety of publicly available information sources which are predominantly independent in nature (however, it is not clear in all cases whether analogous information derived from public sources was prepared by a qualified reserves evaluator or in accordance with the Canadian Oil and Gas Evaluation Handbook). These type curves and estimates are subject to the specific assumptions identified by Paramount with respect thereto, and the other assumptions contained in these advisories. No reserves, or resources other than reserves, are assigned to these type curve or Estimated Ultimate recovery ("EUR") estimates and, accordingly, such estimates may not be representative of the actual production rates or resources associated with Paramount's wells and properties. The estimates of reserves for individual properties may not reflect the same confidence level as estimates of reserves for all properties, due to the effects of aggregation.
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Analogous information is presented on a basin, sub-basin or area basis utilizing data derived from Paramount’s internal sources as well as from a variety of publicly available sources which are predominantly independent in nature. Internal estimates are subject to the specific assumptions identified by Paramount in respect of such estimates plus other assumptions contained herein, and are not necessarily representative of the actual resources associated with Paramount’s properties. The Liard Basin estimates set forth herein are as publicly disclosed by a large U.S. public E&P company . The resource evaluation disclosed by such E&P company was not noted as having been prepared independently or by a qualified reserves evaluator or auditor (as such terms are defined in NI 51-101) or in accordance with the Canadian Oil and Gas Evaluation Handbook. This information is relevant to Paramount’s landholdings in the Liard Basin as the information is in respect of landholdings in the Liard Basin that are close to Paramount’s lands and are, accordingly, likely to have similar geology. Test Results The test rates disclosed in this document represent the average rate of production at the wellhead during post clean-up production testing at the largest choke setting. Pressure transient analyses and well-test interpretations have not been carried out for any of these wells and, as such, all data should be considered preliminary until such analyses or interpretations have been done. Test results are not necessarily indicative of long-term performance or of ultimate recovery. Non-GAAP Measures In this presentation ʺFunds Flow From Operationsʺ and "Net Debt", collectively the non-GAAP measures, are used and do not have any standardized meaning as prescribed by
- GAAP. Funds flow from operations refers to cash from operating activities before net changes in operating non-cash working capital, geological and geophysical expenses, asset
retirement obligation settlements and corporate acquisition and merger costs. Funds flow from operations is commonly used in the oil and gas industry to assist management and investors in measuring the Company’s ability to fund capital programs and meet financial obligations. Refer to the Consolidated Results section of the Company’s Management’s Discussion and Analysis for the calculation thereof. Net Debt is a measure of the Company’s overall debt position after adjusting for certain working capital and
- ther amounts and is used by management to assess the Company’s overall leverage position. Refer to the Liquidity and Capital Resources section of the Company’s
Management’s Discussion and Analysis for the calculation of Net Debt. Pro forma net debt as at June 30, 2017 is the aggregate of net debt for each of Paramount, Apache Canada and Trilogy plus total consideration paid to the vendor in respect of the acquisition of Apache Canada. Non-GAAP measures should not be considered in isolation or construed as alternatives to their most directly comparable measure calculated in accordance with GAAP, or other measures of financial performance calculated in accordance with GAAP. Non-GAAP measures are unlikely to be comparable to similar measures presented by other issuers.
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