outlook for natural gas and co2 infrastructure recent studies and analysis
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8/11/2019 Outlook for Natural Gas and CO2 Infrastructure Recent Studies and Analysis
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2009 ICF International. All rights reserved.
Outlook for Natural Gas and CO2
InfrastructureRecent Studies and Analysis
Outlook for Natural Gas and CO2
InfrastructureRecent Studies and Analysis
Contact:Contact:
Geoffrey N. Brand PhDGeoffrey N. Brand PhD
Senior Project Manger, Gas Market ModelingSenior Project Manger, Gas Market Modeling
ICF InternationalICF International
703703--218218--27422742
[email protected]@icfi.com
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8/11/2019 Outlook for Natural Gas and CO2 Infrastructure Recent Studies and Analysis
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Information in this presentation is proprietary and confidential.Do not distribute to third parties.
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Recent INGAA Infrastructure Studies
Natural Gas Availability, Economics, and Production Potential of
North American Unconventional Natural Gas SuppliesNovember 2008
Natural Gas Pipeline and Storage InfrastructureProjections Through 2030 October 2009
CO2 Developing a Pipeline Infrastructure for CO2 Capture
and Storage: Issues and Challenges February 2009
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Information in this presentation is proprietary and confidential.Do not distribute to third parties.
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Unconventional Gas Supplies
Driver of future North American natural gas production. Changes in production (location or volume) drive infrastructure
needs.
Definition
Relative to conventional supplies - Unconventional natural gas
resources are lower in resource concentration, are more dispersed,and require well stimulation or other technologies to produce.
Most common types:
Tight (sandstone or carbonate)
Shale
Coal bed methane
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Historical U.S. Unconventional Gas Production
0
1,000
2,000
3,000
4,000
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7,000
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10,000
1970
1972
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BcfperYe
ar
Coalbed
Shale
Tight
Strong Production Growth since the Mid-1990s
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Unconventional Fraction of U.S. Gas Production
0
5
10
15
20
25
1997 1999 2001 2003 2005 2007 2009 2011 2013 2015 2017 2019
TcfperYear
Conventional Tight Coalbed Shale
2007 Unconventional9.1 Tcf
48% of total
2020
Unconventional
15.9 Tcf
69% of total
U.S. Lower-48
Growing TotalProduction
Growing
Fraction ofUnconventional
Unconventional productiongrowth projected to continue
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Unconventional Resources are Widespread
Haynesville
Marcellus
Eagleford
Major Coalbed Methane Areas
Shale Basins
Major Tight SandsAreas
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Increases in Interregional Flow, 2008 to 2030INGAA Base Case Infrastructure Report
Increases ininterregional flowmainly driven by
shifting gassupply locations.
New pipeline
infrastructure willbe needed tomake theincremental
transportpossible.
49
230
497
1398
669
(79)
1442
1277
306
893
211
1391
1905
1189
475
1683
1655
453
279
3
150
1542
2883
534
361
428
126
699
146
444
326
118
69
1763872
860
264
40
68
264
192
Elba Island
Cove Point
Everett
Blue Lines indicate LNG
Gray Lines indicate an increase
Red Lines indicate a decrease
1554
< Freeport and
Golden Pass
55
1051 Gulf LNGEnergy
478CostaAzul
< Lake Charles, Gulf Gateway,
Sabine Pass and Cameron
Canaport
Alt amira
Florida
(Offshore)
749
2560
207NE Gateway
453
228
Lazaro
Cardenas
Manzanillo
7149 Units: Million cubic feet per day
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Base Case Miles of New PipelinePipeline Mileage Added Each Year
From 2009 through 2030, about 1,700 miles of gas transmission pipeline will be addedeach year. These additions are fairly consistent with recent levels.
Construction of laterals will likely account for a greater share of the incremental mileage inthe future. Much of the new pipeline in the future is likely to rely on and add to recentlybuilt projects.
Arctic projects and associated downstream pipes account for 5,000 miles of new pipeline.
0
1,000
2,000
3,000
4,000
5,000
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7,000
1999
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2030
MilesofPipe
Alaska / Arctic
New
Expansion
Lateral
MacKenzie
Project
Alaska Pro ject
1
2Pipeline added to new basins
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Capital Expenditures for New Pipeline CapacityMillion Dollars (Nominal$) Spent Each Year, Including the Cost of Compression
From 2009 through 2030, the annual expenditures will average about $6 billion. Somewhat above recent expenditures that have averaged $4 to $5 billion per year.
Arctic pipeline projects will account for 30 to 40 percent of the total expendituresover the period.
Without the Arctic projects, expenditures would only average $3 to $5 billion per year,more closely aligning with recent averages.
0
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4,000
6,000
8,000
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MillionsofDollars
Alaska / Arctic
New
Expansion
Lateral
1Includes cost of downstream expansions on existing corridors in the U.S. and Canada in addition to the cost of arctic Canada
and Alaska frontier projects.2
Lateral is defined as a spur off the main transmission line, normally used to connect production, storage, power plants, LNG
terminals or isolated demand centers.
MacKenzie Project
Alaska Pro ject
1
2
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Summary of Pipeline and Storage DevelopmentFrom 2009 Through 2030
U.S. and Canada Gas Market Growth
(Tril lion Cubic Feet)+4.9 (+18%)
Interregional Gas Transport Capabil ity
(Billion Cubic Feet Per Day)+25 (+20%)
Storage Working Gas Capacity (Billion
Cubic Feet)+453 (+10%)
Added Pipeline Mileage37,700 Total Miles
1,700 Miles Per Year
Added Horsepower of Compression for
Pipelines
8.1 Million HP
370,000 HP Per Year
Capital Expenditures for New Pipeline
and Storage Capacity
~ $135 Billion~ $6 Billion Per Year
Base Case
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Other Midstream DevelopmentFrom 2009 Through 2030
Gathering Line Mileage+18,200
miles$13.8 Billion
Gas Processing Capacity +15.6 Bcfd $10.1 Billion
LNG Import Capacity +3.0 Bcfd $1.5 Billion
Base Case
Capital Expenditures for All MidstreamInfrastructure Development for the INGAA BaseCase was $160 Billion from 2009 through 2030.
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CO2
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Carbon Capture and Sequestration Steps and Costs
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Potential CO2 Pipeline Network
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Pipeline Requirements are between 5,900 and 36,000 Miles
91040
91040
2,950
470
4,080
430
20,610
5,900
36,050
7,900
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
High CCS Case: Less
EOR
Low CCS Case: Less
EOR
High CCS Case:
Greater EOR
Low CCS Case:
Greater EOR
Miles
2015
2020
2030
By 2030 Annual CO2 Sequestration Rates
High Case 1,000 million tonnes
Low Case 300 million tonnes
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Costs Range between $8.5 and $65.6 billion
1,04438
1,04438
4,256
543
6,699
453
32,234
8,512
65,622
12,836
0
10,000
20,000
30,000
40,000
50,000
60,000
70,000
High CCS Case: Less
EOR
Low CCS Case: Less
EOR
High CCS Case:
Greater EOR
Low CCS Case:
Greater EOR
MillionDo
llars
2015
2020
2030
Most Costs Post 2020
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Key Issues Identified by Industry and Government Experts
Liability for performance of both the pipelines and thesequestration reservoirs in short term and long term
ensuring pipeline deliverability and the permanence of storage
Financing of pipeline and sequestration facilities corporate balance sheet financing, to project financing, to hybrid
approaches including some public financing
Siting and right-of-way acquisition whether federal eminent domain is desirable
how to address overlapping federal, state, and local sitingauthorities and processes
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Need for a National Approach
Future CO2, unlike in EOR applications, will have noeconomic value outside what a GHG carbon policy (cap
and trade or tax) confers on it Creates special challenges for financing
CO2 transport and sequestration will be continent wide
Involving large investment Requiring standard operating capabilities and rules, e.g., CO2
quality standards
Ensure access and performance
Future pipelines will be in more heavily populated areaswith more siting and construction challenges