John R Auers Turner Mason amp Company Dallas AIChE October Section Meeting October 23 2012 Presented by International consulting practice since 1971 Downstream focus refinerychemical engineers ID: 816500
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Slide1
The Game Shifts: The North American Crude Boom and Its Impacts Downstream
John
R. Auers
Turner
, Mason & Company
Dallas
AIChE October Section MeetingOctober 23, 2012
Presented by
Slide2International consulting
practice since 1971
Downstream focus; refinery/chemical engineers
Industry and financial clientsPublish
various outlook and forecast productsCrude and Refined Products OutlookRefinery Construction Outlook
World Crude Oil OutlookThe Great NGL Surge! (with BENTEK Energy)Special Studies2Turner, Mason & Company
Slide3Detailed regional production forecasts
Updates of refinery demand by facility/region
Analysis of required logisticsEvaluate challenges and opportunities for producers and refiners and midstream operators
Initial publication – June 2012
Update issued in October 2012
32012 North American Crude Study
Slide4US Refining Industry Largely Balanced Until 1970
Run domestic crude to supply domestic demand
Limited imports of either crude or products
Growing Dependence on Imports after 1970
Falling production/growing demand led to rapidly growing crude importsANS discovery/recession temporarily reversed trend in early 80’s
Low prices accelerated trend after 1985; Imports more than tripled to over 10 million BPD by 2005Somewhat similar story on product imports – gasoline imports grew from just over 300 MBPD in 1995 to almost 1.2 million BPD by 2007. 4
Historical Perspective
Slide5US Production Makes a U-Turn Towards Strong Growth
Canadian Production Growth Accelerating
New Crude Production Is Causing Regional Imbalances
Crude Quality is Different from Previous ForecastsNet Effects:
Pricing DislocationsIncentives for Finding Midstream OptionsUS Appetite for Imports Receding
Regulatory Implications Yield/Processing/Operating/Investment Issues at RefineriesLower supply costs/contribute to US ability to become major product exporter5
What’s Happening Now?
Slide6Today’s Presentation
Crude Production
Changes in Crude Quality
Crude Supply Balance
Impacts on Refiners
6
Slide7History of NA Crude Production
U.S. production up by over 1.5 MMBPD since 2008
Reverses 20+ year trend of declines
Comes despite slowdown in Gulf after
MacondoCanadian crude on upward trend for 3 decades
Up by almost 1 million MBPD in the last decadeLargest reserve base in the world/unconventional resources Almost all reserves located in Western CanadaDriven by high prices and technology advances
7
Slide8Production Forecasts
US forecasts differ widely
Official EIA LT forecast for 2020 = 6.7 MMBPD
IEA and OPEC forecast higher levels
Some analysts have production over 10 MMBPDAll credible forecasts shows continued growth
Canadian production forecasts less variableResource base is better understoodDependent on price/ability to remove logistical limits8
Slide9TM&C Forecasts
Total US/Canada increase of 4.6 MMBPD by 2020 (from 2011 levels)
U.S. growth of 3.1 MMBPD (to 8.8 MMBPD)
Canadian growth of 1.5 MMBPD (to 4.5 MMBPD)
U.S. growth mostly in PADDs 2 and 3Declines in Alaska/California to continue
Canadian growth primarily in the WestRevision in upward direction is more likelyForecast assumptionsCrude prices (LLS/Brent) remain in $90 to $120 rangeAssumes some limitations (manpower, materials, regulatory, etc.)
Limited production from some high potential prospectsLogistical assets are built to move crude to markets in a timely fashion9
Slide10U.S. Crude Production Forecast
10
Slide11U.S. Crude Production Change by PADD
2011 to 2020
11
Slide12U.S. Crude Production Change by Area
2011 to 2020
12
Slide13Canadian Crude Production Forecast
13
Slide14Presentation Agenda
Crude Production Forecast
Changes in Crude Quality
Crude Supply Balance
Impacts on Refiners
14
Slide15Gravity
°
API
Sulfur
Wt.%
Super Light≥ 40.0
AllLight Sweet31.0 – 39.9
≤ 0.99
Light Sour
31.0 – 39.9
≥1.00
Medium Sweet
24.1 – 30.9
≤ 0.99
Medium Sour
24.1 – 30.9
≥1.00
Heavy
≤ 24.0
All
TM&C Crude Quality Categories
15
Slide16U.S. Change in Crude Production by Grade
2011 to 2020
16
Slide17Shale Crude
vs Displaced Light Imports Key Qualities
17
Property
Bakken
Eagle FordSoyo
Bonny LightAPI Gravity4145
39
34
Sulfur,
wt%
0.20
0.60
0.14
0.24
Distillation Yield, volume %
Lt. Ends, C
1
-C
4
3.5
3.8
2.1
1.3
Naphtha
35.7
40.1
23.5
20.3
Middle
Distillates
30.9
29.7
34.5
45.5
Gas
Oil
24.8
21.2
31.1
27.4
Vacuum Residue
5.2
5.2
8.7
5.4
Slide18Heavy Canadian Crude Quality Shift
18
Property
Current
2020
ChangeAPI
Gravity20.320.3- -
Sulfur,
wt%
3.4
3.4
- -
TAN, mg KOH/gm
1.15
1.50
0.35
Distillation Yield, volume %
Lt. Ends, C
1
-C
4
2.7
6.0
3.3
Naphtha
14.0
13.1
-0.9
Middle
Distillates
21.7
18.6
-3.1
Gas
Oil
33.8
32.1
-1.7
Vacuum Residue
27.8
30.2
2.4
Slide19Future Quality of U.S. Crude Oil Production
19
Slide20Crude Run Gravity Change for U.S. Refineries
20
Slide21Crude Production Forecast
Changes in Crude Quality
Crude Supply Balance
Impacts on Refiners
Presentation Agenda
21
Slide22PADD I/East
Coast 2011 crude runs at 1.1 MMBPD (down from 1.6 in 2005)
98% imported; 20% from Canada/Most of rest from Africa
80% light or super light
Very limited pipeline accessPADD II/Mid-Continent
2011 crude runs at 3.2 MMBPD (very steady year to year)Canadian imports 45%; In-PADD production and movements from PADD III about equal at 25%Non-Canadian imports at 150 MBPD (down from 700 MBPD in 1999 and over 1 MMBPD in early 90’s.66% light/27% heavy/7% medium
22US Regional Crude Slates
Slide23PADD III/Gulf Coast
2011 crude runs at 7.4 MMBPD (very steady year to year)
65% imported; 35% produced in PADD
44% light/24% medium/32% heavy
Total light and medium imports at 2.6 MMBPD; down by 900 MBPD in last four years
PADD IV/Rocky Mountains2011 crude runs at 532 MBPD (very steady year to year)Canadian imports 44%; In-PADD production 56%; no non-Canadian imports47% light/13% medium/40% heavy23US Regional Crude Slates
(cont.)
Slide24PADD V/West Coast
2011 crude runs at 2.3 MMBPD (down by 300 MBPD since 2005)
8% Canadian; 50% other foreign; 42% produced in PADD
54% light/13% medium/33% heavy
Crude imports constant at 1.1-1.2 MMBPD for last six yearsLimited pipeline access from Canada/none from rest of US
24US Regional Crude Slates (cont.)
Slide25Crude Flow Timeline
Crude Oil Milestones
Midstream
Devopments
2012
Lt/Med foreign imports to PADD II end
Seaway Expansion to 400 MBPD
Keystone Cushing to USGC Startup
Longhorn Pipeline Startup
Lt
Swt
foreign imports to PADD III end
Reversal of Enbridge Line 9
Seaway Expansion to 850 MBPD
ONEOK
Bakken
Crude Express Startup
Keystone XL Startup
Lt Sour foreign imports to PADD III end
Med
Swt
foreign imports to PADD III end
Lt
Swt
movements to PADD I increase
Med Sour foreign imports to PADD III end
Lt/Med Sour imports to PADD I end
Canadian crude to PADD V increases
KM Trans Mountain Expansion to 750 MBPD
2013
2014
2015
2016
2017
2019
2018
2020
25
Slide26U.S. Crude Balance
26
Slide27Non-Canadian Imports
27
Slide28PADD I
Bakken
replaces over 80% of non-Canadian importsCanadian imports relatively steady/move to heavier grades
Crude slate significantly lighter (1.6 API gravity)
PADD II
No non-Canadian importsCanadian non-heavy imports replaced by in-PADD productionPADD III crude replaced by in-PADD productionCrude slate lighter by about 0.5 API gravity/much lighter than capabilityPADD IIIAlmost all but heavy imports replaced by domestic crude
Canadian dilbits replace significant volume of Latin heaviesOverall crude slate lighter by almost 1.0 API gravity28Changes in Regional Crude Slates
Slide29PADD IV
Canadian non-heavy production replaced by in-PADD crude
Only region with production greater than demandSignificant export of crude to other PADDs
Crude run quality relatively constant
PADD V
Canadian imports increase to over 20% PADD IV, PADD II and possibly PADD III crude reaches refineries These make up for production decreases and start to displace waterborne importsCrude run quality relatively constant29
Changes in Regional Crude Slates(cont.)
Slide30Limited Remaining US Destinations
PADD I Non-Canadian imports less than 150 MBPD
PADD III heavy imports displacement slows as most remaining Latin imports are contractually/economically “locked-in”
PADD V still importing almost 1 million BPD
PADD V Challenges
LCFS could limit/prevent heavy Canadian importsLimited logical mid-stream options from Continental USReturn of in-PADD crude production growth possibleExportsNot forbidden/requires export license in most casesPolitically controversial
Potential destinations – Asia/Europe30What Happens After 2020?
Slide31U.S. Crude Oil Exports
1990 to 2011
31
Slide32Crude Oil Exports
Liquid hydrocarbons from
underground reservoirs thathave not been processed through a crude distillation unit
Pre Approved
Export
LicenseRequired
Crude OilAlaska Cook InletTo Canada for consumption thereHeavy California crude up to 25 MBPD
Case by Case
Presidential determination that it is consistent with national interest
1979 Congressional Act, expired in 1994 but extended each year by Presidential Notice
Export
License
Not Required
Intermediates/
Products
32
Slide33Crude Production Forecast
Changes in Crude Quality
Crude Supply Balance
Impacts on Refiners
Presentation Agenda33
Slide34US refiners will enjoy crude cost advantage
As light imports disappear, LLS flips to permanent discount vs. BrentDomestic light crudes priced to incentivize USGC refiners to replace imported medium crude barrels
Regional differentials
Inland refiners continue to be most advantaged
Pipeline access to USGC will decease WTI/LLS spreadSt. James becomes price setting locationEconomics for EC and WC refiners improve as they gain access
Heavy crude discount increases when Canadian crude arrives on USGC34
Price Impacts
Slide35Influx of light/super light crude could reduce capacity
Loss could be 10%+ at refineries designed for heavier crudes
Units impacted include crude and vacuum units, gas plants, and debutanizers
Displacement of higher sulfur crude will impact sulfur unitsUS refining system could lose the equivalent of 2 or 3 average refineries if capital investment is not made
Other concerns
Higher TAN from Canadian dilbits will require capital/treating costsPotential compatibility issuesLoss of access to imports will decrease crude slate flexibilityBenefits
Lower resid yield/metals content of shale oil will facilitate resid crackingSulfur plant limited refineries will benefit from sweeter crudes
35
Operating Impacts
Slide36Yield Concerns
“
Dumbbelling
” of Crude Slate
Higher NGL and naphthaLower middle distillateResid
yield yields up in Canadian heavy crudesImplicationsHigher NGL yield adds to surplus from field productionHigher naphtha runs counter to declining domestic gasoline demand/potential lower aromatics limitsDistillate demand growing faster than gasoline Remedies
Construction of hydrocracking units – very capital intensiveDevelopment of NGL and gasoline export markets36
Slide37Change in U.S. Product Yields
2011 to 2020
37
Slide38U.S. Net Product Export Forecast
38
Slide39Concluding Thoughts
US refiners will see a major shift in their crude slates over the next 10 years
Almost all non-Canadian and non-heavy crude imports will be
be
displaced except in PADD VAbility to move new crudes into PADD I, PADD V and ultimately offshore will be important
39
Slide40Concluding Thoughts
(cont.)
Domestic surplus will lead to crude cost advantages for all US refiners
“
Dumbbelling” of crude slate will provide numerous yield and processing challengesWill have to spend significant capital to maintain capacity
Ability to maintain distillate production will require hydrocrackersDevelopment of gasoline export markets will be important 40
Slide41John R. Auers – Senior Vice President
Turner Mason & Company
Email: jauers@turnermason.com
Telephone: 214-754-0898
Presenter41