shale oil impacts on refining and transportation · 2014-08-28 · 0.00 2.00 4.00 6.00 8.00 10.00...
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© 2012 BAKER HUGHES INCORPORATED. ALL RIGHTS RESERVED. TERMS AND CONDITIONS OF USE: BY ACCEPTING THIS DOCUMENT, THE RECIPIENT AGREES THAT THE DOCUMENT TOGETHER WITH ALL INFORMATION INCLUDED THEREIN IS THE CONFIDENTIAL AND PROPRIETARY PROPERTY OF BAKER HUGHES INCORPORATED AND INCLUDES VALUABLE TRADE SECRETS AND/OR PROPRIETARY INFORMATION OF BAKER HUGHES (COLLECTIVELY "INFORMATION"). BAKER HUGHES RETAINS ALL RIGHTS UNDER COPYRIGHT LAWS AND TRADE SECRET LAWS OF THE UNITED STATES OF AMERICA AND OTHER COUNTRIES. THE RECIPIENT FURTHER AGREES THAT THE DOCUMENT MAY NOT BE DISTRIBUTED, TRANSMITTED, COPIED OR REPRODUCED IN WHOLE OR IN PART BY ANY MEANS, ELECTRONIC, MECHANICAL, OR OTHERWISE, WITHOUT THE EXPRESS PRIOR WRITTEN CONSENT OF BAKER HUGHES, AND MAY NOT BE USED DIRECTLY OR INDIRECTLY IN ANY WAY DETRIMENTAL TO BAKER HUGHES’ INTEREST.
Baker Hughes Downstream Chemicals
Shale Oil Impacts on Refining and Transportation
Baker HughesLarry Kremer
Shale Oil Processing Issues
• Wax deposits in tanks• Emulsion stabilization &
water hold up in crude oil • High filterable solids • Crude blending• Overhead corrosion
• Cold & hot train fouling• Fuel blending• Odor and hydrogen sulfide• Cold flow and lubricity
properties of fuels
Shale oil quality variability from one field
© 2012 Baker Hughes Incorporated. All Rights Reserved. 2
Characteristics of Shale Production
• Some times called ‘tight oil’• Horizontal drilling was key technology
advance• Hydraulic fracturing of shale formation• Infrastructure does not exist to meet needs
– Most shale oil moved by rail or trucks– Limited pipelines expanding to meet transportation needs
• Unit trains bring Bakken to east coast, west coast, and gulf coast• Truck transportation leads to quality fluctuations• As oil is consolidated into larger shipments, quality variations should
be reduced
© 2012 Baker Hughes Incorporated. All Rights Reserved. 3
Analytical - Eagle Ford Crude Variability
Value Yellow Red Black
API 55.0 44.6 52.3
TAN <0.05 0.07 <0.05
Sulfur <0.2% <0.2% <0.2%
Asphaltene 0% 0% 0.1%
Resin 0.5% 3.2% 1.6%
Filterable solids 176 PTB 295 PTB 225 PTB
© 2012 Baker Hughes Incorporated. All Rights Reserved. 4
Paraffin Analysis Bottom of Sample
• Considerable high molecular weight wax in bottom• High MW = High melting point Some wax melts above 100ºC (212ºF)
© 2012 Baker Hughes Incorporated. All Rights Reserved. 6
Transportation Issues
• Incompatibility with asphaltenic crude oils
• Paraffin deposits
• H2S – HS&E issue
• Odor – Trains and trucks
• Mercaptans in Utica production
• Tendency to over treat with scavengers can lead to amines in crude unit
© 2012 Baker Hughes Incorporated. All Rights Reserved. 7
Shale Oil Hydrogen Sulfide
• Although low in S they can be high in H2S– HS&E concerns– Trucks and trains travel through towns– Fittings on sweet tanks may not handle H2S
• Misapplication can cause downstream issues– Excessive chemical use– Some scavengers can lead to downstream salting– Amine chlorides salts in overhead can be corrosive
© 2012 Baker Hughes Incorporated. All Rights Reserved. 8
Paraffin Deposits
• Transportation– Pipelines– Barges– Trains– Cold train exchangers
• Crude storage tank– Sludge increase– Wall deposits
• H/C Atomic Ratio =1.5 • 24% Fe + S• 63% C + H
Deposit Composition
mV
0.00
50.00
100.00
150.00
200.00
250.00
Minutes0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00 16.00 18.00 20.00 22.00 24.00 26.00 28.00 30.00
C11
C12
C13 C
14 C15
C16
C17
C18
C19
C20
C21
C22
C23
C24
C25
C26
C27
C28
C29
C30
C31
C32
C33 C34 C35 C36 C
37 C38 C
39C
40 C41
C42
C43 C
44C4
5 C46
C47 C
48C
49C
50C
51C
52C
53C
54C
55C
56C
57C
58C
59C
60C
61C
62C
63C
64C
65C6
6C
67C
68 C69 C70 C71 C72 C73
© 2012 Baker Hughes Incorporated. All Rights Reserved. 9
Cold Train Fouling Trial
• Customer must clean cold train exchangers every 10 days• Deposits have wax and asphaltene components• Developed new LIFESPAN™ fouling control additives• Treatment continued 6 months without cleaning shut down• Reduction in fouling so significant that customer will not
turn off chemical
© 2012 Baker Hughes Incorporated. All Rights Reserved. 10
LIFESPAN is a trademark of Baker Hughes Incorporated
Issues with Asphaltene Destabilization
• Shale oil can destabilize asphaltenic crude
• Problem shows up first as emulsion stabilization
– Oil in desalter brine– Increased BS&W
• Potential destabilization in tankage
• Asphaltene fouling of hot train• Customers have also seen cold train fouling• Destabilization can be quantified with the Field ASIT
services™ technologyField ASIT services is a trademark of Baker Hughes Incorporated.© 2012 Baker Hughes Incorporated. All Rights Reserved. 11
ASIT™ Asphaltene Stability Index Test• ASIT Test measures the onset of the flocculation of the asphaltenes
with high accuracy by inducing the asphaltene precipitation via titration with a paraffinic solvent
© 2012 Baker Hughes Incorporated. All Rights Reserved. 12
ASIT is a trademark of Baker Hughes Incorporated
Shale Oil Blending
• Paraffins destabilize asphaltenes• Negative impact on desalter operation
–Brine quality–Rag stability
• Can lead to fouling:–Cold train–Hot train–Furnace
© 2012 Baker Hughes Incorporated. All Rights Reserved. 14
Summary
• Shale oils are paraffinic– Low sulfur and TAN– Blending issues with asphaltenic crude oils
• Low sulfur but can have H2S– Apply correct product properly
• Paraffin content raises new fouling issues– Additives have demonstrated effective control
• Cold train fouling• Hot train fouling• Furnace fouling
© 2012 Baker Hughes Incorporated. All Rights Reserved. 15
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