68. RETAILTexasmarketingpresentationFINAL.pdf - Enerplus

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We Can Deliver Growth • Portfolio has mature, stable cash generating assets complemented by key growth opportunities • $1.3 billion in capital spending over next 2 years • Production growth of 10 - 15% • 5% debt-adjusted growth in 2012 • Cash flow growth of 15% by end of 2012 • Capital increases by 20% to $650 million in 2011 • 2011 capital spending focused on oil projects Production growth of 10 – 15% over next two-year period • 85% of spending on Bakken, Waterfloods and Marcellus • Similar level of spending in 2012 • Beyond 2012, expect 5% debt-adjusted growth per year 9
2011 Capital Focus Resource Play Capital ($MM) # of Net Wells 2010 Exit Production (MBOE/day) 2011E Exit Production (MBOE/day) Change Exit to Exit IRR** BESC** Bakken/Tight Oil 300 48 13.3 18 – 21 35 – 55% >40% $40 – 55/bbl Waterfloods 110 26 13.8 13 – 15 0 – 10% >30% $60/bbl Marcellus Shale Gas 160 27 2.9 7 – 8 140 – 170% 10 – 30% $3.50 – 4.50/Mcf Sub-Total $570 101 30 38.5 – 44 30 – 45% Company Total* $650 113 77.2 80 – 84 5 – 10% Over 90% of drilling is horizontal wells * Includes spending on Shallow Gas ($10 MM), Tight Gas ($60 MM) and Other Conventional Oil & Gas ($10 MM) ** Using February 14, 2011 forward prices. Marcellus economics are based on 4, 5 and 6 Bcf type wells assuming a $4.50/MMBtu gas price BESC – Breakeven supply cost providing a 12% rate of return 10
Page 1 and 2: The Game Plan Enerplus Corporation
Page 3 and 4: Corporate Profile • Trading Symbo
Page 5 and 6: Significant Portfolio Repositioning
Page 7 and 8: 2010 Year-End Reserves Summary P+P
Page 9: Added Meaningful Upside Potential C
Page 13 and 14: Financial Outlook 900 800 Oil Gas A
Page 15 and 16: Crude Oil
Page 17 and 18: Bakken & Three Forks Geology Middle
Page 19 and 20: Fort Berthold, North Dakota Key Fac
Page 21 and 22: Fort Berthold Results Long laterals
Page 23 and 24: Significant Future Production Growt
Page 25 and 26: Waterfloods Key Facts OOIP P+P Rese
Page 27 and 28: Waterflood Development Plans • 20
Page 29 and 30: Marcellus Shale Gas Overview • Cu
Page 31 and 32: Marcellus Performance - Cumulative
Page 33 and 34: Marcellus Drilling Activity To Date
Page 35 and 36: Future Production Growth in the Mar
Page 37 and 38: Long-Term Strategy for Enerplus •
Page 39 and 40: 2011 Guidance Summary of 2011 Expec
Page 41 and 42: Cash Flow Sensitivity The sensitivi
Page 43 and 44: Reserves and Contingent Resources P
Page 45 and 46: Enerplus Ownership Canadian US & Fo
Page 47 and 48: Long-Term Debt ($ thousands) Decemb
Page 49 and 50: Fort Berthold Development Plans B 1
Page 51 and 52: Fort Berthold Well Costs Long Later
Page 53 and 54: Fort Berthold Production - Gatherin
Page 55 and 56: Supplemental Waterflood Information
Page 57 and 58: Polymer Flood • Polymer is chemic
Page 59 and 60: Dec-14 Dec-13 Dec-12 Dec-11 Dec-10
Page 61 and 62:
Giltedge - Polymer Project Costs an
Page 63 and 64:
Medicine Hat Glauc C - Production H
Page 65 and 66:
2011 Development Capital Plans at M
Page 67 and 68:
Freda Lake Ratcliffe Unit Freda Lak
Page 69 and 70:
Supplemental Marcellus Information
Page 71 and 72:
Marcellus Well Design • Drilling
Page 73 and 74:
Gathering Gas in the Marcellus NE P
Page 75 and 76:
Supplemental Deep Basin Information
Page 77 and 78:
Stacked Mannville Key Facts Key pro
Page 79 and 80:
Stacked Mannville Type Curve Econom
Page 81 and 82:
Montney Type Curve Economics AECO (
Page 83 and 84:
Disclaimers Assumptions All economi
Page 85:
Disclaimers NOTICE TO U.S. READERS
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68. RETAILTexasmarketingpresentationFINAL.pdf - Enerplus

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