Energizing the World, Bettering People s Lives Investor Handout November 214
Marcellus Shale Maximizing value from a premier resource play Net Risked Resources* of 15 Tcfe, Doubled Over Two Years 35, net acres in southwest fairway 88% NRI enhances returns Premier U.S. Natural Gas Basin Well Performance - EURs and IPs Continue to Improve Multiple Upside Opportunities Downspacing, delineation, completions and new intervals Expanding Market Diversification Securing firm transportation Mixture of in-basin and out-of-basin outlets 18 * Term defined in appendix
Marcellus 214 Activity Delivering value with upside opportunities JV Currently Producing More Than 875 MMcf/d Gross 1 operated wet gas and 7 dry gas wells in 214 Further Improvement in Well Performance Majorsville wet gas type curves increased 1% OH Strong Initial Production from OPS Area High liquids contribution and downspaced wells Maximizing Value Through Enhanced Completion Designs Conducting Downspacing Tests in Multiple Areas Delineating New Areas Multiple areas prospective for Burkett Majorsville OPS Wet Gas Acreage Dry Gas Acreage SW Dry 19
Marcellus Operational Excellence Tremendous value added in short period of time Returns Doubled Through Efficiencies and Performance Improvement BT NPV1 $ MM 8 6 4 2 EURs up 6% from acquisition Realized 1% cost improvement Focus on long laterals Per Well Value Improvements (Wet Gas) Wet Gas Area Historical* 213 AD Future Laterals 5, 7, 7, - 1, Well Cost $7.2 MM $8. MM $ M Per Lateral Foot $7.1 - $8.3 MM $1.44 $1.14 $1.1 - $.83 Zones Marcellus Marcellus Multiple Targets Spacing 1, 75 75-5 Stages 3 15-25 15-25 EURs 4.3 Bcfe.86 Bcfe/1, $1.67 F&D 9.6 Bcfe 1.37 Bcfe/1, $.83 F&D BT NPV1 $1.5 MM $7.4 MM Historical* EUR Uplift Cost Reductions Longer Laterals Today 2 * EUR estimates from JV initiation in 211. Cost estimates from 212 Analyst Conference
Marcellus Majorsville IDP Core area in liquids-rich region OH First Operated Area with More Than 85 Horizontal Wells Online Acreage only 25% developed Well Performance Driving Increased EURs Flatter declines on legacy wells Improved performance on recent pads 7, foot lateral well projected recovery of 1 Bcfe OH MMcfe/d 1 Majorsville Well Performance* 21 8 6 4 2 6 12 18 24 Days on Production Standard Completion Well Avg. Prior Type Curve Current Type Curve *Normalized to 7 lateral length Note: Townships highlighted where holds more than 3, gross acres. Producing Pad Completions Pad Drilling Ongoing
Marcellus Oxford-Pennsboro-Shirley (OPS) Initial performance above expectations OH First Significant Operations Outside of Majorsville Initial performance in line with s best pad in basin Ten Wells Online Producing Combined 9 MMcfe/d After More Than 3 Days Higher Liquids Content than Expected First Pennsboro Pad Online in 4Q OXF1 & SHR1 Well Performance Cum. Mcfe 4 Shirley - 1 4 Wells Online Oxford - 1 6 Wells Online 3 22 2 1 15 3 45 Days on Production OXF1 Avg.* SHR1 Avg.* OPS Type Curve *Normalized to 7, lateral length Producing Pad Completions Pad Drilling Ongoing Note: Townships highlighted where holds more than 3, gross acres.
Marcellus Performance Upside Potential to materially increase resources and type curves Positive Results from Enhanced Completion Designs Reduced stage and cluster spacing (RSCS) average initial rates up 15 to 4% Successes in both dry and wet gas areas More than 5% of Remaining 214 Wells Include Enhanced Completion Techniques Significant Upside EUR Potential WFN6 Completions in Majorsville* Mcf/Lat. Ft. 25 2 15 1 5 3 6 9 12 15 18 Days on Production RSCS Well Standard Additional Design Original *Normalized to 7 lateral length RSCS 23
Marcellus Economics Huge inventory of low-risk, high-value projects Pittsburgh Airport Majorsville SW Dry Individual Gross Well OPS IDP Area Gross Acres EUR % (Bcfe) 1,2 Liquid 2 Lateral Length Well Cost ($ MM) BT NPV1 BT ROR ($ MM) 3 (%) 3 Majorsville 44, 1.2 2% 7, $8. $8.7 37% Oxford/Pennsboro/Shirley 18, 9.6 2% 7, $8. $7.4 34% Pittsburgh Airport 8,7 8.4 31% 7, $8. $1.8 58% Other Wet Gas 9, 8.1 28% 7, $8. $7.2 34% Southwest Dry Gas 82, 9.7-7, $8. $8. 33% Dominion Storage 9, 1.7 1% 8,5 $9.4 $4. 22% Other Dry Gas 365, 6. - 8.3-7, $8. $2. - $5.6 15-25% 24 1 Residue gas up to 1,15 BTU 2 Ethane rejection 3 Reflects uplift from liquids content
Marcellus Marketing Summary Expanding capacity and pricing points Diversified Access to Local and Regional Markets Balanced Blend of Established Firm Sales and Transportation Firm Transport Expands to Approx 8 MMcf/d in 217 / 218 Continued Market Diversification Through Future Pipeline Expansions Recent out of Basin agreements to Gulf Coast, Mid-Atlantic and Great Lakes areas Evaluating other opportunities 8 6 4 2 Jul-14 Jan-15 Jul-15 Jan-16 Jul-16 Jan-17 Jul-17 Jan-18 214 Average Sales by Pipeline TETCO M3 TETCO M2 Dominion TCO Total Firm Sales and Transportation Existing FT Gulf Coast Great Lakes Firm Sales Gulf Coast, Mid-Atl, NE 25