John Auers of Turner, Mason & Company presented on the impacts of increasing North American crude oil production on US and PADD IV refiners. Production is forecasted to significantly increase in the US and Canada through 2020. This will change the crude slate available, providing more light sweet crude from areas like the Bakken and heavier sour crude from Canada. This is expected to displace some imported crude and cause regional crude price imbalances. PADD IV in particular will see a growing crude surplus that refiners must find markets for through pipelines, rail, or exports. PADD IV refiners should continue to experience strong margins due to lower local crude costs and demand growth above the US average.
Osisko Development - Investor Presentation - May 2024
The North American Crude Boom: Impacts on U.S. & PADD IV Refiners
1. The North American Crude Boom:
Impacts on US and PADD IV Refiners
John R. Auers
Turner, Mason & Company
Platts’ 7th Annual Rockies Oil & Gas Conference
April 15, 2013
Denver, CO
Presented by
2. International consulting practice since 1971
Downstream focus; refinery/chemical engineers
Industry and financial clients
Publish various outlook and forecast products
Crude and Refined Products Outlook
Refinery Construction Outlook
World Crude Oil Outlook
The Great NGL Surge! (with BENTEK Energy)
Special Studies
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Turner, Mason & Company
3. Detailed regional production forecasts; focus on quality
Determination of refinery demand and capability to run
different types of crude by facility/region
Analysis of required logistics
Evaluate challenges and opportunities for producers and
refiners and midstream operators
Initial publication – June 2012
Update issued in October 2012
Next edition scheduled for release in June 2013
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4. US Production Makes a U-Turn Towards Strong Growth
Canadian Production Growth Accelerating
New Production Is Causing Regional Imbalances
Crude Quality is Different from Previous Forecasts
Net Effects:
Pricing Dislocations
Incentives for Finding Midstream Options
US Appetite for Imports Receding
Regulatory Implications
Yield/Processing/Operating/Investment Issues at Refineries
Lower supply costs enable US refiners to become major product exporters
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Driving Force for Crude Study
5. Presentation Agenda
• North American Production Forecast
• Changes in Crude Quality
• Impacts on Crude Supply Balance
• Focus on PADD IV
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6. Recent Developments
U.S. production up by about 2 MMBPD since 2008
•Reverses 20+ year trend of declines
•Comes despite slowdown in Gulf after Macondo
Canadian crude on upward trend for 3 decades
•Up by almost 1 million BPD in the last decade
•Largest reserve base in the world/unconventional resources
•Almost all reserves located in Western Canada
Driven by high prices and technology advances
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7. Production Forecasts
US forecasts differ widely
•All credible forecasts show continued strong growth
•Most expect 2020 production to be 9 to 11+ MMBPD
•Growth levels beyond 2020 even more uncertain
Canadian production forecasts less variable
•Resource base is better understood
•Dependent on price/ability to remove logistical limits
•Expect about 5 MMBPD by 2020 (>50% vs. 2012)
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8. Production Forecasts (cont.)
Where/What Type?
• U.S. growth mostly in PADDs 2 and 3
• Declines in Alaska/California to continue
• Predominantly light sweet
• Canadian growth primarily in the West
• Vast majority heavy sour
Production dependent on key assumptions
• Crude prices – both absolute and regional
• Production potential of tight oil plays very uncertain
• Prospective fields (Utica, Tuscaloosa, SCOOP) even harder to forecast
• Various limitations (manpower, materials, regulatory, etc.) affect growth
• Ability to move crude to markets in timely and cost effective ways will be
particularly critical
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10. U.S. Crude Production Change by PADD
2012 to 2020
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-1000
-500
0
500
1000
1500
2000
2500
3000
3500
PADD I PADD II PADD III PADD IV PADD V
MBPD
Low High
11. U.S. Crude Production Change by Area
2012 to 2020
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-1000
-500
0
500
1000
1500
2000
2500
3000
3500
Permian/Bakken/Eagle
Ford
Gulf of Mexico All Others California/Alaska
MBPD
Low High
12. 0
1
2
3
4
5
6
2012 2013 2014 2015 2016 2017 2018 2019 2020
MillionBPD
Western Eastern
Forecast
Canadian Crude Production Forecast
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Actual
13. Presentation Agenda
• Crude Production Forecast
• Changes in Crude Quality
• Impacts on Crude Supply Balance
• Focus on PADD IV
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14. Gravity
°API
Sulfur
Wt.%
Condensate ≥ 55.0 All
Super Light ≥ 42.0 All
Light Sweet 31.0 – 42.0 ≤ 0.99
Light Sour 31.0 – 42.0 ≥1.00
Medium 24.0 – 31.0 All
Heavy ≤ 24.0 All
TM&C Crude Quality Categories
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15. Change in Crude Production by Grade
2012 to 2020
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-500
0
500
1000
1500
2000
2500
3000
3500
4000
4500
Condensate/ Light
Sweet
Light Sour Medium Heavy
MBPD
US Low US High Canada
20. • Crude Production Forecast
• Changes in Crude Quality
• Impacts on Crude Supply Balance
• Focus on PADD IV
Presentation Agenda
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21. Waterborne Imports into PADD I Replaced by Bakken
Refineries particularly well suited for Bakken quality; FCC resid capability
Unit rail unloading capacity expanding quickly – 700 MBPD by end of 2013
Rail likely remains primary transportation option thru the end of the decade
Rail will allow even heavier WB imports to be replaced
PADD II to Rely on In-PADD and Heavy Canadian Crude
Non-Canadian imports already displaced
PADD III and Canadian non-heavy to decline rapidly
Growing production/coking additions limit ability to absorb more light sweet
PADD III Will Reach Limit in Ability to Absorb Light Crude
Strong in-PADD growth from Eagle Ford/Permian
Bakken deliveries to substantially decrease over the next two years
Will incentivize ways to move PADD III crude to other markets
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22. Significant Heavy Crude Imports into PADD III Will Remain
Estimate floor of 1.0 to 1.5 MMBPD for Latin American imports
PDVSA and PEMEX control about 600 MBPD of heavy crude capacity
Additional heavy capacity is contractually “locked-in”
Overall Latin American heavy production will grow/natural home is USGC
Small amounts of other WB imports remain – Motiva and for lubes/other quality reasons
PADD V Challenges
LCFS could limit/prevent heavy Canadian imports
Requires new mid-stream projects to access PADD II/III/IV crude
California refineries built for heavy crude; will continue to import some heavier grades
Pacific Northwest is first to absorb PADD II crude; better fit for refineries and also
supported by rapid build-out of rail unloading facilities
Exports
Not forbidden/requires export license in most cases
Politically controversial
Potential destinations – first Canada and then Asia
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23. U. S. Waterborne Imports
Recent History
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31%
11%
58%
2005
8493 MBPD
PADD III Heavy
PADD V
Other
34%
17%
49%
2012
6086 MBPD
24. U. S. Waterborne Imports
Forecast
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68%
22%
10%
2020 Low
2500 MBPD
PADD III Heavy
PADD V
Other
81%
13%
6%
2020 High
1600 MBPD
25. Presentation Agenda
• Crude Production Forecast
• Changes in Crude Quality
• Impacts on Crude Supply Balance
• Focus on PADD IV
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26. Total PADD IV
No. Refineries 14
Total Capacity 625 MBPD
PADD IV Refineries
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Billings
Salt Lake
City
29. PADD IV Product Balance
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Denver/Colorado
Springs
TX Panhandle
Refineries
Las Vegas, NV
Spokane, WA
Salt Lake
City
North Dakota
South Dakota/
Nebraska
30. Gasoline Diesel Jet/Kero Total
Demand 308 190 51 549
Refinery Prod.
(incl. ethanol) 309 193 26 528
From PADD II/III 30 3 25 58
To PADD V (31) (6) 0 (37)
Total Supply 308 190 51 549
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35. Surplus of Crude in PADD IV will Continue to Grow
Only PADD with production greater than in-PADD demand
Wide range for potential surplus due to unknown production prospects
Quality of new crude will be light; question is how light?
Finding Markets for New Crude/Ways to Access Markets Critical
Several P/L projects are being developed
Rail projects are also moving ahead; well behind developments in Bakken
A major challenge: PADD II and III are already saturated with light crude
PADD V could be potential destination; challenge is logistics
One advantage in marketing to California refiners is the low CI assigned to Niobrara
PADD IV Refiners Should Continue to Experience Superior Margins
Lower crude costs than in other regions
Product demand growth above U.S. averages
Incentivize some small projects – focus on running local crude/produce distillates
Expansion of capacity/crude runs limited by regional demand
More exposed to domestic economic conditions because of inability to export products
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