68. RETAILTexasmarketingpresentationFINAL.pdf - Enerplus

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Hedging The following is a summary of the financial contracts in place at February 14, 2011 expressed as a percentage of our forecasted net production volumes: Natural Gas (CDN$/Mcf) January 1, 2011 – March 31, 2011 January 1, 2011 – December 31, 2011 Crude Oil (US$/bbl) January 1, 2012 – December 31, 2012 Sold Puts (limiting downside protection) $4.15 $56.50 - % of forecasted 2011 net production 26% 11% - Swaps (fixed price) $6.39 $87.27 $94.60 % of forecasted 2011 net production 33% 58% 20% Purchased Calls (repurchasing upside) $6.48 $ 101.17 - % of forecasted 2011 net production 26% 11% - 41
Reserves and Contingent Resources Play Types Proved Proved plus Probable Reserves Proved plus Probable Booked Net Drilling Locations “Best Estimate” Contingent Resources Future Contingent Resource Drilling locations Bakken/Tight Oil (MMBOE) 38.0 57.5 39 60* 90 Crude Oil Waterfloods (MMBOE) 65.2 83.7 45 60** n/a Other Conventional Oil (MMBOE) 20.8 27.7 23 - - Total Oil (MMBOE) 124.0 1<strong>68.</strong>9 107 120 90 Marcellus Shale Gas (Bcfe) 52.4 117.2 13 3,904 926 Tight Gas (Bcfe) 228.7 320.8 40 - - Shallow Gas (Bcfe) 164.8 220.5 152 - - Other Conventional Gas (Bcfe) 126.3 165.0 1 - - Total Gas (Bcfe) 572.1 823.5 206 3,904 926 Total Company (MMBOE) 219.4 306.2 313 771 1,016 * Bakken at Fort Berthold only – excludes Three Forks upside ** Includes both IOR and EOR opportunities which could include future drilling locations only on a portion of our waterflood portfolio 42
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 and 10: Added Meaningful Upside Potential C
Page 11 and 12: 2011 Capital Focus Resource Play Ca
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: Cash Flow Sensitivity The sensitivi
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

68. RETAILTexasmarketingpresentationFINAL.pdf - Enerplus

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