Tennessee Gas Pipeline Co, LLC

Transcription

1 Co, LLC Northeast Gas Association Regional Market Trends Forum April 30, 2013 Preston Troutman Director, Business Development

2 Kinder Morgan: Unparalleled Asset Footprint 3 rd largest energy company North America Enterprise value ~ $110 billion (a) Largest natural gas network in U.S. Own an interest in / operate ~ 62,000 miles of natural gas pipeline Connected to all important U.S. natural gas resource plays Largest independent transporter of petroleum products in U.S. Transport ~1.9 MMBbl/d (b) Largest transporter of CO 2 in U.S. Transport ~1.3 Bcf/d of CO2 (b) Largest independent terminal operator in U.S. Own an interest in or operate ~180 liquids / dry bulk terminals ~112 MMBbls domestic liquids capacity Handle ~106 MMtons of dry bulk products (b) Only Oilsands pipe serving West Coast TMPL transports ~300 MBbl/d to Vancouver / Washington State; expansion under way increasing capacity to 890 MBbl/d (a) Combined enterprise of KMI, KMP & EPB as of 4/12/2013; see footnotes on slide 4 for further information. (b) 2013 budgeted volumes. 24

3 Natural Gas Pipelines Segment Outlook Well-positioned connecting key natural gas resource plays with major demand centers Project Backlog: $2.8 billion of identified growth projects over next five years (a), including: TGP Northeast upgrade LNG liquefaction Gulf & Elba Island) SNG / Elba Express expansions Sierrita lateral to Mexico border Long-term Growth Drivers: Natural gas the logical fuel of choice Cheap, abundant, domestic and clean Unparalleled natural gas network Sources natural gas from every important natural gas resource play in the U.S. Eagle Ford, Marcellus, Utica, Uinta, Haynesville, Fayetteville and Barnett Connected to every major demand center in the U.S. Demand growth and shifting supply from multiple basins Power / gas-fired generation Industrial and petchem demand Growth in Mexican natural gas demand Repurposing portions of existing footprint Greenfield development Expand service offerings to customers LNG exports Acquisitions (a) Excludes acquisitions and dropdowns, includes KM's share of non-wholly owned projects. Includes projects currently under construction. 3

4 System Overview 13,900 miles of pipeline 1.4 million horsepower 7.2 Bcf/d design capacity >500 firm transportation customers 35 MM households equivalent Utica Shale Northeast Demand Long-term Growth Drivers Demand growth across system Abundant & Growing Supply Eagle Ford, Haynesville, Fayetteville, Barnett, Marcellus & Utica LNG Export Southeast Demand Mexico Demand Linking the best markets to the best supply basins

5 TGP Demand Growth System Wide 8, YTD 6,000 4,000 2,000 0 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Avg Daily Deliveries (MDth/d) ~ 40 % cumulative growth

6 TGP Demand Growth Northeast 3,000 2, YTD 2,000 1,500 1, Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Avg Daily Deliveries (MDth/d) ~ 28 % cumulative growth

7 TGP Power Generation Flows System Wide 2,000 Avg MDth/d ,600 1, Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Northeast Markets: ~ 40 % 7

8 TGP Market Area Supply Traditional supply displaced Bcf/d Bcf/d Summer (Apr Oct) Avg Bcf/d Station Winter (Nov Mar) Avg Bcf/d Station Niagara (TGP) Shelton Wright Dracut Distrigas Stagecoach Marcellus REX 8

9 TGP Northeast Restrictions Interruptible Services: WINTER Locations Percent Days Restricted (November - March) 10 / / / 13 Station % 99 % 100 % Station % 0 % 65 % Station % 0 % 80 % Station % 7 % * 0 % Station % 91% 100 % Station % 9 % * 65 % * Tennessee s 300 Line Expansion in service

10 TGP Northeast Restrictions Interruptible Services: SUMMER Locations Percent Days Restricted (April- October) Station % 79 % 94 % Station % 81 % 100 % Stations 321/ % 73 % 0 % * * Tennessee s 300 Line Expansion in service

11 TGP Northeast Supply Position Large & Growing TGP Direct Access to Northeast Gas Supplies UTICA UTICA MARCELLUS Marcellus Area Production (Q1 2013) ~ 9 Bcf/d TGP Receipt capacity ~ 2.5 Bcf/d Avg receipts TGP ~ 8.5 Bcf/d Avg receipts - All pipelines Continued growth coming 2015 fwd Utica Area Production TGP multiple lines through heart of production ~1.4 Bcf/d TGP Receipt capacity underway Estimated Production ~ 1.5 Bcf/d by 2016; ~ 2.0 Bcf/d by 2018

12 TGP Northeast Development ~ $1.3 Billion Capital spent Fully Subscribed In Service On Time Development Continues Project Dth/d Shippers In-Service Status 300L Project 350,000 EQT Energy Nov 1, 2011 In Service NSD 250,000 Cabot, Seneca, Anadarko, Mitsui Nov 1, 2012 In Service Northampton 10,400 Berkshire, Bay State Nov 1, 2012 In Service MPP Project 240,000 Chesapeake, Southwestern Nov 1, 2013 FERC Order received, On Schedule NE Upgrade 636,000 Chesapeake, Statoil Nov 1, 2013 Construction, On Schedule Rose Lake 230,000 South Jersey Res., Statoil Nov FERC Order pending, On Schedule Uniondale 34,000 UGI Resources Nov. 1, 2014 FERC Prior Notice CT Expansion 72,100 In Active Development Nov 1, 2016 In Active Development Northeast Expansion TBD In Active Development TBD In Active Development

13 TGP s Connecticut Expansion Connecticut Expansion Receipts: Northeast Shale; Wright, NY Deliveries: Connecticut In-service: November 1, 2016 Facilities: Pipeline looping on TGP 200 and 300 lines Wright Supports Connecticut s Comprehensive Energy Strategy Strategic expansion for TGP and the Connecticut customers Provides access to Marcellus Shale Positions Connecticut for future growth 13

14 Northeast Expansion Project Overview New England Highest spot prices in US Capacity constraints into region Reduced deliveries from MN&E and Hubline Production declines Decreased LNG imports Market Need Need for additional capacity into the region Customer desire for Northeast Shale Large subscription level required Power market to be restructured Timing is uncertain 14

15 TGP s Northeast Expansion Project PROJECT OVERVIEW Wright Dracut 0.5 to 1.2 Bcf/d pipeline Scaleable & Expandable Regional solution; 3 rd pipeline 171 miles of loop & build; 60% existing corridors Varied supplies at / near Wright, NY Maximizes market access & options Firm capacity thru bottlenecks Incremental supply to traditional markets Option to serve markets further north Unique opportunity to expand infrastructure Varied market sectors / participants STATUS Significant interest received to date Negotiations continue Fixed negotiated rates; long term commitment Customized in-service date Q and beyond 15

16 Commercial Contacts Preston Troutman Director, Business Development (o) (c ) Becky Mack Manager, Business Development [email protected] (o) (c ) Dodson Skipworth Account Director, Northeast [email protected] (o) (c ) Co., L.L.C 1001 Louisiana Street Houston, TX