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September Miles TAPS Northstar Endicott Prudhoe Bay Kuparuk Milne Point NPRA ANWR Coastal Plain (1002 Area) Colville River LJL (April, 1997) Pt. Thomson Developments Major Discoveries Alpine Liberty Badami Location Map Alaska Gas Resources & Major Producers North Slope discovered resource = 35 Tcf Prudhoe Bay – 8 Bcf/d of production, currently reinjected into reservoir Ultimate ANS resource estimates ~100 Tcf Alaska Gas Owners ExxonMobil Phillips State Others BP
Citation preview
Overview & Status for:
International Association of Energy Economists
Alaska Chapter
October 25, 2001Anchorage, Alaska
September 2001 2
Team Objectives
• Assess the economic viability of a pipeline project
• Focus on route evaluation– Cost and environmental considerations
• Prepare sufficient information to support potential permit applications
Safe and Environmentally Responsible
September 2001 3
Miles
0 5 10 15 20 25
TAPS
Northstar
Endicott
PrudhoeBay
Kuparuk
MilnePoint
NPRA
ANWR
CoastalPlain
(1002 Area)
Colvi
lle R
iver
LJL (April, 1997)
Pt. Thomson
DevelopmentsMajor Discoveries
AlpineLiberty
Badami
Location Map
Alaska Gas Resources & Major Producers
• North Slope discovered resource = 35 Tcf• Prudhoe Bay – 8 Bcf/d of production,
currently reinjected into reservoir• Ultimate ANS resource estimates ~100 Tcf
Alaska Gas Owners
ExxonMobilPhillips
StateOthers
BP
September 2001 4
Preliminary Comparison of Two Pipeline Routes
Southern Route 2,139milesNorthern Route 1,803miles
Pipeline Design Basis
Diameter 52”High pressure 2,500 psiBuried lineThroughput 4-6 bcf/d
Note: Mackenzie Valley Pipeline 1,140miles
September 2001 5
Route Attribute Elements
1. Economics2. Revenues 3. Gas Access4. Jobs5. Environment6. Safety7. Timing
September 2001 6
Total Project Cost ($bn)(4.0bcf/d from Alaska, 0.8bcf/d from MD)
South NorthGas Treatment Plant 2.6 2.7Alaska to Alberta 9.0 6.8Alberta to Market 5.3 5.3NGL Extraction Facilities 0.3
0.3Alaska Project Total 17.2 15.1
Mackenzie Delta Line 2.3 0.9Pt.Thomson Development 1.3
1.3
Notional Toll ($/mcf)(Alaska North Slope to US L-48 Market)
South NorthGas Treatment Plant 0.30 0.32 Alaska to Alberta 1.31 0.97Alberta to Market 0.78 0.78Total 2.39 2.07
All number in US dollars
Price Assumptions• Based after EIA, ~$3.00/mmbtu, escalating with inflation. • View 2000 price spike as an anomaly.
Total Governments* Owners
Project Discounted Cumulative Cash Flows ($bn) (at 15% discount rate)
2000 2005 2010 2015 2020 2025 2030 2035 2040-10.0-8.0-6.0-4.0-2.0
02.04.06.08.0
10.0
EIA Price Scenario
NorthSouth
NorthSouth
• Owner’s investment not repaid. • Additional risk from price and cost uncertainty. • Team is still working to improve economics by
lowering costs.
* Includes Mackenzie Delta Benefits
Element 1: EconomicsNeither Route Is Economic
September 2001 7
Element 1: Economics Gas Price History and Forecast
• Demand growth encouraging• Highly volatile commodity• Intense market competition• Successful project must have competitive cost of supply
1990 1993 1996 1999 2002 2005 2008 2011 20140.001.002.003.004.005.006.007.008.009.00
10.00H
enry
Hub
Gas
Pri
ce (
$/m
mbt
u)
Average ‘90-‘95$1.80/mmbtu
Average ‘96-‘99$2.27/mmbtu
Average ‘00-‘01$4.09/mmbtu
Based after EIA, 2001
September 2001 8
Total Undiscounted RevenueSouth
$66.2bn, MoD
$22.7bn
$1.7bn$23.7bn
State of Alaska
US L-48 StatesUS Federal
$6.9bnCanadian Provinces
$11.2bnCanada Federal
Total Undiscounted RevenueNorth
$68.0bn, MoD
$24.1bn
$1.7bn$24.2
$6.7bn
$11.3bn State of Alaska
US L-48 StatesUS Federal
Canadian Provinces
Canada Federal
Element 2: Revenues Substantial Government Revenues Regardless of
Route
Assumptions:• Both routes include MD upstream and midstream revenues.
September 2001 9
Total State of Alaska Revenues Difference in Alaska State RevenuesNorth vs. South
00.51.01.5
2.02.53.03.5
0 20 40 60 80 100 120ANS Developed Reserves (Tcf)
Del
ta C
um. R
even
ues
($b
n, M
oD)
Current Project
Element 2: Revenues State of Alaska Revenues
0.0
5.0
10.0
15.0
20.0
25.0
South North
Tota
l Rev
enue
s (
$bn,
MoD
)
Royalty
Severance Tax
Ad Valorem Tax
Income Tax 4.0
September 2001 10
U.S. Regulatory Enabling Legislation
• Creates market-driven, expedited regulatory process for any viable project(s)– Subject to FERC regulation; fair and reasonable terms and
conditions; open access– Subject to all environmental laws and regulations; 18 month
EIS completion• Producer participation in Senate Energy Committee testimony
on October 2• Senate Energy Bill now going straight to floor
– Language developed by producers in current mark up• Creates best possible structure for successful Alaska Pipeline
Project
September 2001 11
Way Forward
• Feasibility study underway – expect engineering to be completed by year-end.
• Update of project economics / route attribution comparison to follow
• Then open season decision to be made:– Project economic?– Enabling legislation been enacted? – State fiscal certainty progressed?– Route selected?