2009 Annual Convention Rocky Road Ahead for Gas Pipeline Construction in North America Allan Bradley President & CEO Questar Pipeline Company
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April 16, 2009 1
Interstate Natural Gas Association of America (INGAA) INGAA • Trade organization that advocates regulatory and legislative positions of importance to the natural gas pipeline industry • Members comprise nearly all interstate natural gas pipelines and transport 95% of nation’s natural gas through 200,000 miles of pipe The INGAA Foundation Inc. • Formed in 1990 as the research arm of INGAA • INGAA Foundation Mission • advance use of natural gas for benefit of environment and consuming public • facilitate efficient construction and safe, reliable operation of North American natural gas pipeline system • Currently 123 members comprising pipelines and service providers 2
INGAA Foundation Studies Studies Underway
Natural Gas Pipeline and Storage Infrastructure Projections through 2030 – Completion: April 2009
The Evolution of the Interstate Natural Gas Facility Approval Process
Studies Approved
Natural Gas – A Key to Climate Change
Permit Program for MBTA Take
Workforce: Knowledge Transition
Agency Education & Stakeholder Outreach
– Completion: March 2009
3
Questar Corporation (STR-NYSE) A Natural Gas Focused Company 2008 Net Income Contribution - $684 million
Wexpro (E&P)
11%
Market Resources 86%
Gas Management (Gathering & Processing)
12% Questar E&P 63%
Questar Pipeline (Interstate Transportation)
8% Questar Gas (Distribution)
6%
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$7.5 billion enterprise value 4
Questar Pipeline Assets 2,533 miles of regulated natural gas pipelines 4,155 Mdth per day of firm contract capacity 53.1Bcf of regulated natural gas working storage capacity Rockies-centric pipeline system expanding to support export pipeline markets
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When the Road Turned Rocky 9/11/01 Housing Boom Record Energy Prices Housing Bust Credit Squeeze I’m laying down rigs until gas prices improve!
Banking Bailout Recession Falling Energy Prices
6 6
Also Playing: The Greatest Story
Never Told
We’ve cracked the code!
7
U.S. Shale Basins Align with the Pipeline Grid Bakken Antrim Baxter
Niobrara Marcellus New Albany
Paradox
Monterey/ McClure
Lewis
Huron Woodford Fayetteville FloydConasauga Barnett
Haynesville
8
U.S. Production Grew by 4 Bcf/d in 2008
9
The U.S. is Adding Reserves at a Record Rate EIA Reserve Additions (Bcf)
Est. US Reserves (Tcf) 3000
250 200 150 100 50 0
2000
Proved Unproven
1000
2007
2006
2005
2004
2003
2002
2001
2000
1999
1998
1997
0
PGC 2006 Report
PGC 2006 w/ Updated ‘07 Proven Reserves
Clean Skies 2008 Report
In Nov 2008, EIA announces largest ever annual gas reserve additions (up 13%) PGC 06 Report plus new reserve additions amounts to 88 years of consumption assuming 2007 consumption rates Clean Skies Report indicates 118 years of consumption at 2007 consumption levels. 10
A Rocky Road Lies Ahead 9/11
I’m not signing any new pipeline contracts until times improve.
Surplus Supply New Fin. Products Restricted Access New E&P Legislation Tight Credit
Higher Taxes
Higher Taxes
GHG Cap & Trade Recession Shrinking Demand
11
U. S. Gas Prices Reflect Supply & Demand Perceptions Independence Hub 2,450,000
$12.00 Ike Hurricane
Hurricane Katrina
2,400,000 $10.00
Monthly Volume (MMcf)
$8.00
2,300,000 2,250,000
$6.00 2,200,000 $4.00
2,150,000 2,100,000 2,050,000
Total Supply Total Demand
$2.00
Average Wellhead Price ($/MMBtu)
2,350,000
Wellhead Price 2,000,000
Source: EIA
$0.00
Note: Supply & Demand are 12 Mo. Moving Averages
12
2009 Working Gas Storage Inventory is Near the 5-year Maximum 2009 inventory is 372 Bcf higher than 2007 and 280 Bcf above the 5year average
Source: EIA Form 912
13
Production is Slow to Respond to the “Drill Signal” Average Daily Production (bcf/d) 66.00 64.00 62.00
Almost 4.0 Bcf/d lost to Gustav and Ike
60.00 58.00 56.00 54.00 52.00
Source: EIA 914 Report
Dec-08
Nov-08
Oct-08
Sep-08
Aug-08
Jul-08
Jun-08
May-08
Apr-08
Mar-08
Feb-08
Jan-08
Dec-07
Nov-07
Oct-07
Sep-07
Aug-07
Jul-07
Jun-07
May-07
Apr-07
Mar-07
Feb-07
Jan-07
50.00
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Steep Drop in the Natural Gas Rig Count North American Gas Rigs vs. Henry Hub Price Rigs
Price
1800
$14.00
1600
$12.00
1400
Rig count adjusted to account for 4 month drilling lag.
1200 1000
$10.00
$8.00
800
$6.00
600 $4.00 400 Henry Hub Price
$2.00
200 North American Natural Gas Rigs
$-
Source: Baker Hughes & Platts Energy Trader 3/20/2009
Jan-09
Oct-08
Jul-08
Apr-08
Jan-08
Oct-07
Jul-07
Apr-07
Jan-07
Oct-06
Jul-06
Apr-06
Jan-06
Oct-05
Jul-05
Apr-05
Jan-05
Oct-04
Jul-04
Apr-04
Jan-04
Oct-03
Jul-03
Apr-03
Jan-03
Oct-02
Jul-02
Apr-02
Jan-02
Oct-01
0
15
Rig Declines from Peak in Key Shale Plays Major Shale Plays – Total Rigs
Barnett Fayetteville Southeast Woodford Haynesville Northeast Marcellus Green River Other Wyoming Rockies Uinta Piceance Williston Total
Peak Rig Count
Current
%
11/21/2008 159 56 39 44 25 67 15 55 102 86 648
4/3/2009 81 47 34 70 26 35 6 18 26 46 389
Change -49% -16% -13% 59% 4% -48% -60% -67% -75% -47% -40%
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Restricted Access to Public Lands Utah BLM Lease Sale 12/19/08
Canceled on 2/4/09 Interior Secretary Salazar canceled lease sales by BLM on 77 parcels in Utah based on impact to scenic views • Valued at $6 million • Covers 103,225 acres ENGOs accused BLM of last minute “fire sale” Claimed BLM did not fully comply with NEPA and National Historic Preservation Act Salazar directed BLM to take a “fresh look” questioning adequacy of environmental review 17
Myth vs. Reality What the media would have you think!
Most parcels are miles away from Utah’s most treasured landscapes.
Gas producers in Utah and Intermountain West produce 25% of the country’s natural gas on less than 1% of its public land. 18
Credit Markets Remain Tight Spread (bps)
S&P 500 Index
1200 1700
1000
1500
800
1100
200
900
0
700 Feb-05 Aug-05 Feb-06 Aug-06 Feb-07 Aug-07 Feb-08 Aug-08 Feb-09
400
Feb-05 Aug-05 Feb-06 Aug-06 Feb-07 Aug-07 Feb-08 Aug-08 Feb-09
1300
600
Barclays Capital CMBS AAA is an index that tracks a cross section of bonds in the CMBS market; spread is vs. ten-year U.S. Treasuries 19
Elimination of Oil and Gas Tax Preferences Proposed Budget Provisions Eliminates tax deductions: •intangible drilling costs •percentage depletion allowance •tertiary injectants Repeals tax credits: • enhanced oil recovery • marginal wells • advanced earned Increases geological and geophysical amortization period to seven years Levies new 13% excise tax on Gulf of Mexico production and a “drill or lose” rule and per acre fee increase on non-producing offshore leases 20
The Administration’s Game Changer for Greenhouse Gases Water vapor CO2 CH4 N2O O3 CFCs HFCs PFCs SF6
Preference for cap and trade legislation, but moving forward on direct regulation of GHG emissions • • • •
EPA evaluating an Endangerment Finding for CO2 Reconsidering the Deseret memo Reconsidering the California denial Completing the GHG reporting rule
Federal budget proposal assumes the existence of a GHG cap and trade program in 2012 • 14% below 2005 levels by 2020 • 83% below 2005 levels by 2050 • All allowances auctioned (no free credits) with approximately 80% of the proceeds going directly to taxpayers and the remainder to support clean energy 21
Base Case Assumptions Energy Conservation
Moderate goals consistent with recent trends are set and achieved.
Climate Policy
Emissions targets decrease gradually at first, but more aggressively after 2020. Liberal offset policy reduces impact of targets before 2020.
Carbon Capture and Sequestration
Technology is widely available and incentives are provided for CCS projects. About 40 GW of coal with carbon capture built by 2030.
Renewables
Growth driven by state Renewable Portfolio Standards (RPS) requirements.
Nuclear Power
About 25 GW of new nuclear capacity built through 2030, exclusively at existing sites.
Source: INGAA , ICF International
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Base Case Assumptions (continued) Plug-in Electric Hybrids
Modest market penetration before 2030.
CNG and LNG Vehicles
No national policy focused on incentives for natural gas vehicle use.
Upstream Technologies
Growth in unconventional gas is very substantial.
Drilling Moratoria
Despite 2008 action, most restrictions are re-introduced.
Arctic Gas
Pipelines develop slowly.
Source: INGAA , ICF International
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Base Case - Gas Demand Outlook U.S. & Canada Gas Consumption (Trillion Cubic Feet, Tcf) The recent economic
downturn will delay growth for a few years.
Gas consumption in
the power sector will grow substantially.
Carbon policy
encourages growth of gas-fired power generation; GHG emissions are nearly 50% lower than coalfired generation.
Delta
35
Delta
2007-2015 2007-2030
30
Power Generation
1.6
3.6
Industrial
0.4
0.6
10
Commercial
0.1
0.2
5
Residential
0.2
0.6
Other
0.1
0.1
25
20
15
Other sectors will
grow more modestly consistent with recent trends (i.e., GDP, disposable income, population, industrial activity). Source: INGAA , ICF International
0 2000
2005
2010
2015
2020
2025
2030
Total 2.4 Tcf
5.1 Tcf
24
Change in North American Pipeline Flows Base Case 2007-2015 Pipeline Flow (MMcfd)
Greatest increases in supply are from shales in the Rockies and Midcontinent.
Change from 2007 to 2015 (3162)
11
Canaport
(67)
U.S and Canada LNG imports modestly increase to about 2.8 Bcfd by 2015.
Source: INGAA , ICF International
(1742)
(1402)
183 (85)
(97)
(400)
(9)
30
Exports from Western Canada are down due to declining production and increased gas consumption in Western Canada.
Lower-48 Net imports from Canada down by about 4.2 Bcfd from 2007 to 2015. Increased gas use in Western Canada dominates the trends.
(1287) (107)
(688)
(154)
(6)
(52) 413
(457)
(1053) (670) (436)
361
397
(107) (655)
(59)
2431
733
(20)
75
2061
2121
545 (341)
(10) Costa Azul
265
(14)
Cove Point
(21)
(64)
(19)
(533)
650
(707) (319) 1723
(649)
307
(42) (221)
4765
623 (111) (84)
Lazaro Cardenas
867
Blue Lines indicate LNG Gray Lines indicate an increase Red Lines indicate a decrease
Altamira
(270) (106)
(14)
32
268
(1232)
Manzanillo
Elba Island
26
2580 (17)
Blue = LNG Gray = Increasing Red = Decreasing
358
29
(384) (21)
(482)
4
(56)
21
(155)
Everett
1321
333
293
337 (129)
211
203
(159)
2004
(287)
NE Gateway
379 411 < Freeport and Golden Pass
348
1042 78
117
Florida (Offshore)
Gulf LNG Energy < Lake Charles, Gulf Gateway, Sabine Pass and Cameron
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Rockies Export Capacity Increases when REX Completed to Ohio Phase I – Greasewood to Wamsutter to Cheyenne Hub Feb 14, 2007
REX West/ Phase II – 1.4 Bcf Cheyenne Hub to Audrain County, MO – May 2008
REX East/Phase III – Audrain County, MO to Lebanon , OH – June 15, 2009 – 1.6 Bcf ; Then to and Clarington, OH expanding to 1.8 Bcf November 1, 2009
NNG
Green River/ Overthrust
Wamsutter NGPL Cheyenne Hub
Uinta/ Piceance
Lebanon ANR
Greasewood Pi c ean c e Ba s i n
Denver/ Julesburg
Clarington
Anadarko
PEPL
Mexico
• REX East to Lebanon delayed until June 15, 2009 • Lebanon to Clarington delayed until November 1, 2009 • Capital cost overrun is currently $1.4 billion. 26
FERC Certificate Process Guide to Future Pipeline Construction
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1. Algonquin (285) 2. Islander East (285) 3. Iroquois (230,85, 100, 200) 4. Columbia (135,270) 5. Algonquin (140) 6. Transcontinental (105) 7. Transcontinental (130) 8. Transcontinental (100,142) 9. Columbia (94) 10. Maritimes (80,360,418) 11. Algonquin (301) 12. Tennessee (500) 13. Mill River (800) 14. Tennessee (136) 15. Texas Eastern (900) 16. Algonquin (325) 17. Algonquin (800) 18. Broadwater (1,000) 19. Mid-Atlantic (1,500) 20. Algonquin (140)
FERC Certificated Major Pipeline Projects: 2000 - Feb. 2009 (MMcf/d)
Northwest (162,113) NorthernStar (1,300)
21. CIG (282,92) 22. CIG (85,133,118,105,899) 23. TransColorado (125,300,250) 24. WIC (120,116,675,350,556,330,230) 25. El Paso (140) 26. Rendezvous (300) 27. Entrega (1,500) 28. Northwest (450) 29. Rockies Express West (1,800) 30. White River Hub (2,565)
Northwe st (224)
Dominion (700)
GTN (207)
Empire(250)
WBI (80) 26
24
Questar Overthrust (550, 750) Questar (272,102,175)
27 29
30 8 23
Kern River (135,886) El Paso (502) North Baja (500, 2,700)
TETCO (150, 150) TETCO (250)
12 9
8
6 15 19 4
32
18
Rockies Express East (1,800) Columbia Transco (165) Cheyenne Equitrans (172, 100) Midwester Plains (560,170) (130) 25 n East Tenn. (510) MarkWest (638) (120) East Tenn. East Tenn. (86) Center Southern Trails (120) (276) Point (113,132) East Tenn. (170) Midcontinent (1,500) Transco (204,236,323) Transwestern (150,375,500) Southern/Magolia (82)
El Paso (230,320,620,150)
94.74 BCF/D Total 13,435 Miles
Trailblazer (324)
7
10 20 13 17 1 11 5
621
28
Kern River (282)
16
Millenium (525) NFS/DTI (150)
Northwest(191)
Tuscarora (96)
14
22
Trunkline (510) Center Point (1,237, 280) Discovery (150) Natural (200,300)
Port Arthur (3,000) Trunkline (200) Point Comfort (1,000) Dominion South (200) San Patricio (1,000) Sonora (1,000) Tennessee (320) Vista del Sol (1,100)
Cameron Southern (1,500) (336,330) Florida Gas (239,270,100) Gulf LNG (1,500) Tennessee Calypso (832) (400,200,100) Cheniere Creole Trail (2,000) Ocean Express(842) Trunkline(1,500 Gulfstream ) (1,130, 345, 155) Kinder Morgan (3,395) Golden Pass (2,500) Cheniere Sabine Cheniere (2,600) Corpus Christi (2,600)
Source: FERC
Source: FERC
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FERC Certificated or Pending Major Pipeline Projects: 2009 Construction (MMcf/d)
Alliance Compression (213) Point of Rocks (Questar Overthrust) (300) Meeker to Cheyenne (Rockies Express) (200) Phoenix Lateral (Transwestern) (500)
REX East (Kinder Morgan) (1,800) Colorado Hub (Northwest) (360) Barnett Pipeline (Enterprise) (1,100)
+ 3,800 MMcf/d of other various projects
Fayetteville & Greenville Laterals (Texas Gas) (2,300) Midcontinent Express (1,400)
Texas Independence (Energy Transfer) (1,100)
20.33 BCF/D Total 2,447 Miles
Gulf Crossing (1,500)
Katy Extension (Energy Transfer) (400) Golden Pass Pipeline (Exxon) (2,500)
Gulfstream Phase IV (1,550)
Source: FERC 29
Major Pipeline Projects in FERC Pre-Filing Process or Pending: 2010 Construction (MMcf/d)
Bison Pipeline (400)
Ruby Pipeline (1,300)
Sundance (Northwest) (150)
Raton Basin (CIG) (750)
Kern River (145) Regency Pipeline (1,500)
+ 3,800 MMcf/d of other various projects
11.95 BCF/D Total 1,939 Miles
LNG Header (Kinder Morgan) (2,100)
Source: FERC 30
Major Pipeline Projects on the Horizon Construction 2011 and Beyond (MMcf/d)
Alaska (4,500)
Panhandle Eastern (750) Kinder Morgan (360) Kinder Morgan (170) Northern Natural (82) Spectra (400) Hub III (Dominion) (570) Bakken Pipeline (WIC) (100) Williston Basin (20) Vector (120) REX East Exp. (1,000) ANR (1,000) Trunkline (650) Southern Star (65) Seminole (80)
Paso Norte Pipeline Project (380) Greasewood Lateral (Northwest) (200) Eastern & Western Flow Path (Questar) (2,000) White River Lateral (Questar) (810) Grassland Expansion (Williston Basin) (40) Blue Bridge (Williams) (500) Raton Expansion (CIG) (130) Bronco Pipeline (Spectra) (1,000) Kern River (500) WIC (255) Western Energy (1,000)
38.69 BCF/D Total 4,320 Miles
Northeast Expansion (NFG) (500) MetroExpress (Iroquois) (300) Northeast Express (Rockies) (1,500) New Penn (Nisource) (500) Appalachia to Northeast (Spectra) (300) Liberty Natural (2,400) Dominion Keystone (Dominion) (1,000) Rockies Connector (Williams) (688) East-West Connector (NFG) (750)
A/G Line Expansion (Natural)(139) Enogex Pipeline (Southern Star) (100) Gulfstream (750) Greenway Expansion (East Tennessee) (450) Centerville Expansion (Columbia Gulf) (235) Discovery Pipeline (Williams) (150) Midcontinent Express (300) Worsham-Steed (Falcon Gas) (150) Gulf South (500) Gulf Coast Connector (NGS) (2,000) 800 Line Expansion (Tennessee) (400) Henry Hub Expansion (Trunkline) (600) Haynesville (ANR) (1,800) Houston Market (KM Interstate) (400) Highland Trails (Southern Star)(1,000) ETX Exp (TETCO) (600) Henry Hub (Columbia Gulf) (200) Eagle Hub Project (Lehman) (2,000) Shenzi Lateral (Enbridge) (100) Mobil Bay South II (Transco)(550) Destin Pipeline (380) Tiger Pipeline (Energy Transfer) (1,250)
Source: FERC 31
Alaska and Mackenzie Delta Pipelines There are large proven reserves (55+ TCF) in both northern Alaska and Canada’s Mackenzie Delta region. Combined these areas could provide 7 Bcf/d to the North American market. The Mackenzie Delta pipeline is smaller and could be built sooner. The prospects for both pipelines are risky, at best.
Prudhoe Bay
Mackenzie Delta 1.5 Bcf/d in 2015
Anchorage Inuvik Whitehorse
Alaska Gas Pipeline 4.0 Bcf/d in 2020 2.0 Bcf/d expansion in 2023
Norman Wells Yellowknife
Edmonton
32
Base Case - Total Inch Miles Transmission Pipe - U.S. and Canada 140 120
1000's Inch Miles
100 80
Alaska
60 Mackenzie
40 20
Source: INGAA , ICF International
0 20 3
8 20 2
6 20 2
4 20 2
2 20 2
0 20 2
8 20 1
6 20 1
4 20 1
2 20 1
0 20 1
8 20 0
6 20 0
4 20 0
2 20 0
20 0
0
0
33
Base Case - Projected Investment Transmission Pipe - U.S. and Canada 14 Alaska
12 Mackenzie
Billions $'s
10 8 6 4 2
Source: INGAA , ICF International
0 20 3
8 20 2
6 20 2
4 20 2
2 20 2
0 20 2
8 20 1
6 20 1
4 20 1
2 20 1
0 20 1
8 20 0
6 20 0
4 20 0
2 20 0
20 0
0
0
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Gas Pipeline Costs by Component $110,000 $100,000 $90,000
Dollars per Inch-Mile
$80,000 $70,000
Misc. R.O.W. Labor Material
$60,000 $50,000 $40,000 $30,000 $20,000 $10,000
29 20
26 20
3 20 2
0 20 2
17 20
20 14
20 11
08 20
20 05
20 02
19 99
19 96
19 93
$0
Average of large-diameter gas pipelines 30 to 36 inches FERC data compiled by Oil & Gas Journal
Source: INGAA , ICF International
35
Base Case Coating Forecast Inch-miles (transmission) External area (millions sq. ft.) Year-to-year change
2008 132,000 182
2009 123,000 170 -7%
WASHINGTON, D.C. - Land surface = 61.4 sq. mile (or 1,711 million sq. feet) - At current production, NAPCA would take roughly 10-years to “paint the town” with FBE 36
Coatings – Key to Gas Pipeline Safety External coatings are critical to pipeline safety Non-shielding to cathodic protection (FBE) Critical life cycle protection of pipe vs. corrosion
Importance of good quality assurance Inspection / testing (assure coating performance) Minimize field issues (e.g. bevel overspray/damage)
Flow efficiency internal coatings Improved throughput & capital savings Life cycle reduction in required fuel usage
Specialty coatings (abrasion-resistant, etc.) 37
Coaters as Key Partners New DOT Alternative Design Rule Thinner wall (0.8 vs. 0.72 design factor) Requirement for non-shielding coating (FBE) Comprehensive QA program in coating mill New post-construction measures Close-interval survey (c.p. effectiveness) Coating integrity testing (DCVG or ACVG) Baseline internal inspections (smart-pigging)
Bottom Line: Increased importance of high-
performance external coatings 38
Key Findings
North America is not running out of natural gas. E&P technology advancements create bright future for shale development.
Current gas supply development is risky because of gas price uncertainty.
Market growth is driven by power sector, but gas not a “slam dunk”.
No clear direction for energy and carbon policies.
Negative bias of some policy makers toward natural gas.
Capital for expansions is difficult to arrange due to shortened shipper contract lengths and higher credit risk of shippers.
Difficult to secure capacity commitments from shippers.
Supply/demand equilibrium will remain fragile.
Siting, ROW, access, and environmental issues will persist.
Escalating construction costs, mostly driven by uncontrolled outside factors.
Longer term, robust market growth with development of new supplies requires additional pipeline capacity, particularly in the Rockies, South East Supply Area and Appalachia. 39
2009 Annual Convention
Thank You, NAPCA
Questions?
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