UOP LLC, A Honeywell Company

UOP LLC, A Honeywell Company
Refining & Petrochemicals Technology Solutions through Integrated Optimisation Matthew Lippmann UOP LLC, A Honeywell Company Good afternoon. First I’d like to thank you all for coming today. During this conference you will be hear many presentations about recent developments in UOP’s refining and petrochemical technologies. In this session, we will discuss the benefits of integrating these technologies and the importance of proper technology selection to deliver maximum value from your facility. OR In this session, we will discuss how proper integration of these technologies can deliver maximum value from your facility. Iraq Refinery 2012 April London, England © 2012 UOP LLC. All rights reserved. UOP

Agenda Market Overview Why Integrate?
Maximum Fuels to Maximum Petrochemicals Here is the agenda for this session. It will include a brief overview of the petrochemical market. It will then highlight some of the advantages of integration. Next, we will step through an example showing how different technology selections can be used to take a maximum fuels refinery to a maximum petrochemical facility. Finally, it will highlight some technologies used for integration and the importance of proper technology selection. UOP

Petrochemical Demand Soars into the Future
Paraxylene Demand Million MTA Million MTA 60 100% Increase! 40 20 10 years 1990 2000 2010 2020 90 million MTA of incremental light olefins needed over next 10 years Annual demand growth of 6.7% u The emerging middle class in many parts of the world has driven a significant growth in the petrochemical market of the past 20 years and this trend is expected to continue in the foreseeable future. For light olefins, the key point is that propylene demand is increasing faster than ethylene demand, creating a need for On Purpose propylene generation. On the aromatics side, paraxylene demand growth is expected to double over the next 10 years. These market drivers are the reason there is so much interest in maximizing petrochemical production, and an excellent way of doing this is through proper technology integration Fiber (fabric, yarn, cord) Film (packaging, media, electrical components) Resin (bottles, packaging, containers) Additional Need for “On Purpose” Propylene Demand of pX Projected to Double Over the Next 10 Years! UOP

Feedstock Selection Depends on Regional Feedstock Availability
Ethylene Cracker Feedstock is Variable by Region 100% 90% 80% 70% 60% Percent 50% 40% 30% 20% 10% 0% However while global petrochemical demand is increasing, the feedstocks we use to derive petrochemicals change from region to region. Here we show a chart from CMAI giving the type of ethylene cracker feedstocks in various regeions around the world. It is clear that places like north america and the middle east, lower ethane costs are drivers while in europoe and asia the trend is towards using petrochemical naphthas. So feedstock selection depends on regional feedstock price and availability North America South America Europe CIS & Baltic States Middle East/ Africa Northeast Asia Southeast Asia Ethane Propane n-Butane Naphtha Gasoil Other Source: CMAI 2011 World Ethylene Cost Study Feedstock Selection Depends on Regional Feedstock Availability UOP

Ethylene Cash Cost Curve Cumulative Ethylene Capacity (million tons)
Ethylene Production Costs are Increasing Ethylene Cash Cost Curve 1,050 Middle East North America NE Asia SE Asia Western Europe Source: CMAI 2009 Curve: February 10, 2010 Asia Light Olefins Market Advisory Service (Graphical Analysis) 2004 Curve: 2005 World Light Olefins Analysis Ethylene CCOP $/MT Refinery Integration 850 2009 650 450 Feedstock Price Increasing 2004 250 Well what does that do to the cost of production of petrochemicals? Here is another CMAI chart that shows the Ethylene cost of production compared to the cumulative global capacity. The dotted line is 2004 and the solid line is If we now overlay the different regions on top of here we see that for places like the middle east, there is a cost advantage due to the lower cost of ethylene whereas in the rest of the world the costs are higher. But note also the CHANGE from 2004 to 2009 you see that in every area of the world the costs are increasing, even in the middle east due to the fact that feedstock costs are increasing. However one way to fight this trend and drive a facility down on to the left is through proper refinery-petrochemical integration. Position on cost curve is very important to success given the large capital investment costs 50 20 40 60 80 100 120 140 160 Cumulative Ethylene Capacity (million tons) Offset Higher Feedstock Costs through Proper Refinery Integration UOP

Trend Towards More Integrated Complexes is Increasing
Major Oil Companies Recognize Value of Integration Percent of Ethylene Capacity Integrated with a Refinery by Same Company in Europe 90% 74% 39% 24% The major oil companies recongize this trend. This chart shows the percentage of etheylene capactity integrated with a refinery by the same company in Europe. Successful companies like Total and Exxon recognize and promote their leadership in integration as a way to upgrade their refinery intermediate streams and secure reliable feedstock supply for their petrochemical plants. And at UOP we regognize that this trend is increasing over time. BP Shell Total ExxonMobil Source: Morgan Stanley Trend Towards More Integrated Complexes is Increasing UOP

Why Integrate? Increase product valuation
Secure reliable feedstock supply at reduced cost Other Advantages: Reduced Shipping Costs Reduced Tankage Costs Common Offsites / Utilities Common Maintenance / Admin Upgrade of byproduct streams Refinery Processes Petrochemical Processes Let’s talk now about the some of the advantages of integration. For refiners the primary benefit is on increasing the value of their products. For Petrochemical producers, it’s about securing a feedstock at the lowest cost. And there are some other advantages including reduced shipping and tankage costs, common offsites and utilities and upgrading of byproduct streams. In general, the focus is on leveraging synergies between these technologies to maximize product values, while also lowering capital and operating costs. Leverage Synergies to Maximize Product Values Lowers Operating & Capital Costs UOP 7

What is Refinery-Petrochemical Integration?
Fuel Gas Refinery Processes $800/Te Light Naphtha/ LPG $880/Te Heavy Naphtha $870/Te Reformate $900/Te Distillate So why do we want to integrate refineries with petrochemical facilities? Well before we answer that, lets discuss what integration really means because it can mean different things to different customers. Integration can mean simply adding a BTX complex to extract high value aromatics out of the gasoline pool, it could mean running higher severity on the FCC unit to recover incremental propylene yields or routing refinery intermediate streams to a steam cracker or it can mean doing all of these things. But ultimately the goal for anyone looking to integrate is to maximize the value of their complex through balanced vertical integration. Now maybe it is obvious that a refiner wants to maximize the value of his products by upgrading them in a petrochemical facility and the petrochemical producer has a need to secure reliable feedstock at lower cost, and sure we all know that there are advantages of sharing common storage, utilities and reducing transportation costs between facilities. However lets look at this a slightly different way. A standalone refinery that produce petrochemical feedstocks are selling a commodity. There is little opportunity to extract incremental value out of those products. As long as they meet certain specifications they are sold for a fixed value. Likewise the petrochemical facility is at the mercy of whatever product qualities and even quantities the refinery is willing to send them. However, the integrated refinery-petrochemical complex holds all the cards. We can now custom design our refining technologies specifically to produce high quality petrochemcial feedstocks. This allows the intergrated complex to gain a competative advantage over the standalone complex and take full advantage of new technology developments that UOP has to offer. UOP

Petrochemical Processes Refinery Optimization
What is Refinery-Petrochemical Integration? $600/Te Fuel Gas Petrochemical Processes C2=/C3= Refinery Processes $800/Te $1,500/Te Light Naphtha/ LPG $880/Te Heavy Naphtha BZ/pX $870/Te $1,200/Te Reformate $900/Te Distillate Now let’s assume the refinery is selling some intermediate products as petrochemical feedstocks. In many cases, the refinery will only be getting commodity prices for these intermediates. The refiner will continue to maximize distillate. Refinery Optimization UOP

Petrochemical Processes Integrated Complex Optimization
What is Refinery-Petrochemical Integration? $600/Te Fuel Gas Petrochemical Processes C2=/C3= Refinery Processes $800/Te $1,500/Te Light Naphtha/ LPG $880/Te Heavy Naphtha BZ/pX $870/Te Reformate $1,200/Te $900/Te Distillate However, the game changes with an integrated complex. Now the incentive will optimizing the quantity and quality of the intermediate streams in order to maximize the highest value petrochemical products. It is therefore important to select the right technology solutions to accomplish this. OR Proper technology selection is therefore important and would provide a competitive advantage over stand alone facilities. Integrated Complex Optimization Optimize Quantity and Quality of Intermediate Streams Select the Right Technology Solutions for the Integrated Complex UOP

Maximum Fuels to Maximum Petrochemicals Case Study
400 KBPD FCC Based Complex Case 1: Traditional Fuels Refinery Case 2: Fuels Refinery with BTX Complex Case 3: Maximum Petrochemical Refinery Case 4: Integrated Refinery – Petrochemical Complex Case 5: Integrated Refinery – Petrochemical Complex No Fuels Now lets walk through a simple example of how different technology selections can take a facility from a traditional maximum fuels refinery all the way to a maximum petrochemical complex with no fuel production. First we start with the fuels facility, and then we add a BTX recovery section. Next we move to maximizing petrochemicals from a standalone refinery then we move to an integrated refinery – petrochemical complex and finally end up with an integrated complex with no fuels production. This example is for illustrative purposes only to show relative product yields and one economic example as we convert an increasing percentage of our fuels to petrochemicals. We are not saying that any one of this is preferred for every case. Highlight how UOP technology can be applied across the entire spectrum and help drive towards an optimum point for a particular set of objectives. UOP

Integration Example: FCC Based Complex Case 1
Light Naphtha/LPG F. G. Heavy Naphtha Gasoline CDU CCR Platforming Unit Distillate LCN HCN Crude Case 1 shows the traditional fuels refinery with a Vacuum unit, delayed coker, FCC, CCR platformer and diesel hydrotreater making primarily gasoline and diesel products Distillate UnionfiningTM Unit Diesel Gasoline Mode FCC Unit VDU LCO Delayed Coking Pitch CSO UOP

Integration Example Yields: FCC Based Complex Case 1
50% 45% 40% 35% 30% 25% 20% 15% 10% 5% 0% $22 $20 $18 $16 $14 $12 $10 $8 $6 $4 $2 $0 Fuel/Coke Distillate Gasoline LPG 41% 35% Product Yield (Wt-%) Product Values – Feedstock Cost – Variable Costs – Fixed Costs Net Operating Margin ($/BBL) Net Margin = 18% 6% Net Margin Less Capital = Net Margin – Capital Charges For our base case economics, we run an LP model to generate product yields. Using a standard price set we calculate a net operating margin which takes product values and subtracs feedstock, variable and fixed costs. We also calculate a margin less capital value which takes the net margin and subtracts out the capital investment payments plus interest over a fixed time period Low Severity FCC Unit (Fuels) Case 1 Case 2 Case 3 Case 4 Case 5 UOP

50% 45% 40% 35% 30% 25% 20% 15% 10% 5% 0% $22 $20 $18 $16 $14 $12 $10 $8 $6 $4 $2 $0 Fuel/Coke Distillate Gasoline LPG 41% 35% ~75% Fuels Product Yield (Wt-%) Net Operating Margin ($/BBL) Net Margin 18% 6% Net Margin Less Capital So when we sum up the gasoline and distillate production from our baseline facility we see we convert approximately 75% of our feed into fuels with about a $2 per barrel net margin less capital expense. Low Severity FCC Unit (Fuels) Case 1 Case 2 Case 3 Case 4 Case 5 Traditional Refinery Produces ~75% Transportation Fuels UOP

Light Naphtha/LPG F. G. Heavy Naphtha Gasoline CDU CCR Platforming Unit Distillate LCN HCN Crude Now we are going to take our fuels refinery and move towards increased petrochemicals by adding a BTX complex, increasing the severity of the FCC unit and adding in a propylene recovery unit. Distillate Unionfining Unit Diesel Gasoline Mode FCC Unit VDU LCO Delayed Coking Pitch CSO UOP

Light Naphtha/LPG C3= Recovery C3= Heavy Naphtha Gasoline CDU CCR Platforming Unit Raffinate Distillate Aromatics Complex Bz LCN HCN pX Crude Distillate Unionfining Unit Diesel Med Severity FCC Unit VDU LCO Delayed Coking Pitch CSO UOP

50% 45% 40% 35% 30% 25% 20% 15% 10% 5% 0% $22 $20 $18 $16 $14 $12 $10 $8 $6 $4 $2 $0 Fuel/Coke Distillate Gasoline LPG 41% 35% Delta Net Margin Product Yield (Wt-%) Net Operating Margin ($/BBL) 18% Net Margin Less Capital 6% Low Severity FCC Unit (Fuels) Case 1 Case 2 Case 3 Case 4 Case 5 UOP

50% 45% 40% 35% 30% 25% 20% 15% 10% 5% 0% $22 $20 $18 $16 $14 $12 $10 $8 $6 $4 $2 $0 Fuel/Coke Distillate Gasoline LPG BTX C3= 43% 41% 35% Delta Net Margin Product Yield (Wt-%) Net Operating Margin ($/BBL) 21% 18% 13% 11% Net Margin Less Capital 9% 6% +16% BTX + C3= 3% And with those changes we have decreased our gasoline production and produced 16 percent higher value petrochemicals and the economics improve Low Severity FCC Unit (Fuels) Med Severity FCC Unit BTX Complex Case 1 Case 2 Case 3 Case 4 Case 5 FCC Severity and BTX Complex Converts 16% of Gasoline Into Higher Value Petrochemicals UOP

Light Naphtha/LPG C3= Recovery C3= Heavy Naphtha Gasoline CDU CCR Platforming Unit Raffinate Distillate Aromatics Complex Bz LCN HCN pX Crude In the next phase we will increase the FCC severity further by adding in a RxPro unit for maximum propylene production and add LCO unicracking to upgrade the LCO into aromatics. Distillate Unionfining Unit Diesel Med Severity FCC Unit VDU LCO Delayed Coking Pitch CSO UOP

Light Naphtha/LPG C3= Recovery C3= Heavy Naphtha Gasoline CDU CCR Platforming Unit Raffinate Distillate Aromatics Complex Bz LCN HCN pX Crude Distillate Unionfining Unit Diesel RxProTM High C3= FCC Unit VDU LCO Unicracking Unit LCO Delayed Coking Pitch CSO UOP

50% 45% 40% 35% 30% 25% 20% 15% 10% 5% 0% $22 $20 $18 $16 $14 $12 $10 $8 $6 $4 $2 $0 Fuel/Coke Distillate Gasoline LPG BTX C3= 43% Delta Net Margin Product Yield (Wt-%) Net Operating Margin ($/BBL) 21% 13% 11% Net Margin Less Capital 9% 3% Low Severity FCC Unit (Fuels) Med Severity FCC Unit BTX Complex Case 1 Case 2 Case 3 Case 4 Case 5 UOP

50% 45% 40% 35% 30% 25% 20% 15% 10% 5% 0% $22 $20 $18 $16 $14 $12 $10 $8 $6 $4 $2 $0 Fuel/Coke Distillate Gasoline LPG BTX C3= 43% 41% Delta Net Margin Product Yield (Wt-%) Net Operating Margin ($/BBL) 21% 21% 15% 13% 11% 10% Net Margin Less Capital 9% +6% BTX + C3= 6% 7% 3% And by doing these modifications we can an additional 6 wt% petrochemical yield from our same barrel of feed. Low Severity FCC Unit (Fuels) Med Severity FCC Unit BTX Complex RxPro FCC Unit BTX Complex LCO UC Unit Case 1 Case 2 Case 3 Case 4 Case 5 RxPro FCC and LCO Unicracking Unit Shifts Product Yields Towards BTX and C3= UOP

Light Naphtha/LPG C3= Recovery C3= Heavy Naphtha Gasoline CDU CCR Platforming Unit Raffinate Distillate Aromatics Complex Bz LCN HCN pX Crude Now we are going to integrate our refinery with a naphtha steam cracker and start recovering ethylene in addition to propylene Distillate Unionfining Unit Diesel RxPro High C3= FCC Unit VDU LCO Unicracking Unit LCO Delayed Coking Pitch CSO UOP

Recovery C2=/C3= Light Naphtha/LPG Steam Cracker Heavy Naphtha PyGas CDU CCR Platforming Unit Raffinate Distillate Aromatics Complex Bz LCN HCN pX Crude Distillate Unionfining Unit Diesel RxPro High C3= FCC Unit VDU LCO Unicracking Unit LCO Delayed Coking Pitch CSO UOP

50% 45% 40% 35% 30% 25% 20% 15% 10% 5% 0% $22 $20 $18 $16 $14 $12 $10 $8 $6 $4 $2 $0 Fuel/Coke Distillate Gasoline LPG BTX C3= 41% Delta Net Margin Product Yield (Wt-%) Net Operating Margin ($/BBL) 21% 15% 10% Net Margin Less Capital 6% 7% Low Severity FCC Unit (Fuels) Med Severity FCC Unit BTX Complex RxPro FCC Unit BTX Complex LCO UC Unit Case 1 Case 2 Case 3 Case 4 Case 5 UOP

50% 45% 40% 35% 30% 25% 20% 15% 10% 5% 0% $22 $20 $18 $16 $14 $12 $10 $8 $6 $4 $2 $0 Fuel/Coke Distillate Gasoline LPG C2= BTX C3= 41% 41% Delta Net Margin Product Yield (Wt-%) 23% Net Operating Margin ($/BBL) 21% 17% 15% +4% C2= 10% Net Margin Less Capital 8% 6% 7% 7% 4% Now in addition to increasing Propylene and BTX yeilds, we are now recovering 4 wt percent of our feed as ethylene. For the first time our FCC dry gas ethylene becomes economical to recover. Also note that gasoline fuel production has been eliminated. Low Severity FCC Unit (Fuels) Med Severity FCC Unit BTX Complex RxPro FCC Unit BTX Complex LCO UC Unit RxPro FCC Unit BTX Complex LCO UC Unit Steam Cracker Case 1 Case 2 Case 3 Case 4 Case 5 Steam Cracker Integration Enables Entry Into C2= Market UOP

Recovery C2=/C3= Light Naphtha/LPG Steam Cracker Heavy Naphtha PyGas CDU CCR Platforming Unit Raffinate Distillate Aromatics Complex Bz LCN HCN pX Crude Finally we are going to go all the way and take all of our distillate and convert it to petrochemicals by adding a full conversion distillate hydrocracker. Distillate Unionfining Unit Diesel RxPro High C3= FCC Unit VDU LCO Unicracking Unit LCO Delayed Coking Pitch CSO UOP

Recovery C2=/C3= Light Naphtha/LPG Steam Cracker Heavy Naphtha PyGas CDU CCR Platforming Unit Raffinate Distillate Aromatics Complex Bz LCN HCN pX Crude Lt Naph Hvy Naph RxPro High C3= FCC Unit VDU Full Conv Distillate Unicracking Unit LCO Delayed Coking Pitch CSO UOP

50% 45% 40% 35% 30% 25% 20% 15% 10% 5% 0% $22 $20 $18 $16 $14 $12 $10 $8 $6 $4 $2 $0 Fuel/Coke Distillate Gasoline LPG C2= BTX C3= 41% Delta Net Margin Product Yield (Wt-%) 23% Net Operating Margin ($/BBL) 17% Net Margin Less Capital 8% 7% 4% Low Severity FCC Unit (Fuels) Med Severity FCC Unit BTX Complex RxPro FCC Unit BTX Complex LCO UC Unit RxPro FCC Unit BTX Complex LCO UC Unit Steam Cracker Case 1 Case 2 Case 3 Case 4 UOP

50% 45% 40% 35% 30% 25% 20% 15% 10% 5% 0% $22 $20 $18 $16 $14 $12 $10 $8 $6 $4 $2 $0 Fuel/Coke Distillate Gasoline LPG BTX C2= C3= +32% BTX+C3=+C2= 41% 38% 31% Delta Net Margin Product Yield (Wt-%) 23% Net Operating Margin ($/BBL) 17% 12% 11% Net Margin Less Capital 8% 8% 7% 4% In this case we have increased petrochemical yields by an additional 32% over the previous case. Gasoline and distillate have both been eliminated but now lets look at the impact on operating margins. Low Severity FCC Unit (Fuels) Med Severity FCC Unit BTX Complex RxPro FCC Unit BTX Complex LCO UC Unit RxPro FCC Unit BTX Complex LCO UC Unit Steam Cracker RxPro FCC Unit BTX Complex LCO UC Unit Steam Cracker (No Fuels) Case 1 Case 2 Case 3 Case 4 Case 5 Converting 100% of Fuels Increases Petrochemical Yields by 32 Wt-% UOP

Integration Example Yields: FCC Based Complex Comparison
50% 45% 40% 35% 30% 25% 20% 15% 10% 5% 0% $22 $20 $18 $16 $14 $12 $10 $8 $6 $4 $2 $0 Fuel/Coke Distillate Gasoline LPG C2= C3= 41% 38% 31% Delta Net Margin Margin Optimum Identified Product Yield (Wt-%) 23% Net Operating Margin ($/BBL) 17% 12% 11% Net Margin Less Capital 8% 8% 7% 4% As we can see here, net margins continued to improve through each case as the lower value fuels get converted to higher value petrochemicals. Note however that when capital costs are considered, we reach an optimum point in case 4 before the margin starts to decline. This is because we are spending an enormous amount of capital to add 2 large hydrocracker trains to take relatively high value distillate and convert it all to petrochemicals. This simple example highlights the need to find the optimal balance point between product values and capital expenditures, and our goal at UOP is to help you identify this point to maximize the value of your facility. Notes from Russian Slides So this demonstrates that having the right technology is important and at UOP we firmly believe we have the best technology but we recognize that just having the best technology is not enough and to really take advantage of an integrated complex you need to know how to apply the technology to each individual case. Low Severity FCC Unit (Fuels) Med Severity FCC Unit BTX Complex RxPro FCC Unit BTX Complex LCO UC Unit RxPro FCC Unit BTX Complex LCO UC Unit Steam Cracker RxPro FCC Unit BTX Complex LCO UC Unit Steam Cracker (No Fuels) Case 1 Case 2 Case 3 Case 4 Case 5 UOP’s Extensive Technology Portfolio Can Optimize Configuration to Client Needs UOP

Evaluating the Appropriate Conversion Technology
Nat Gas H2 Plant H2 H2 Plant Off Gas SR Naphtha Steam Cracker Olefins CDU Crude Oil Aromatics Complex UnicrackingTM Unit Aromatics Complex Aromatics Vacuum Unit So lets look at a recent real world example that UOP was evaluating for a customer. In this case we have a customer integrated a crude upgrading facility to make petrochemical naptha for a steam cracker and an aromatics complex. In this example we want to ask what conversion technology should we choose to generate the highest value for the complex? Should we use a vacuume unit with a delayed coker and UOP’s hydrocracker technology? Heavy Oils Delayed Coking Unit Coke UOP

LCO UnicrackingTM Unit
Evaluating the Appropriate Conversion Technology Nat Gas H2 Plant H2 H2 Plant Off Gas SR Naphtha Steam Cracker Olefins Crude Oil Aromatics Complex RCD UnionfiningTM Unit Aromatics Complex Aromatics Or should we use a resid desulfurization unit and a FCC along with a LCO hydrocracker to upgrade the heavy oil? Well in this case it depends on the cost of hydrogen, Heavy Oils RFCC Unit LCO UnicrackingTM Unit Coke UOP

Delayed Coking/ Unicracking Complex Product Streams (KMTD)
Evaluating the Appropriate Conversion Technology Delayed Coking/ Unicracking Complex RCD/RFCC Complex Delta Feed Streams (KMTD) Crude Oil 30 0.0 Natural Gas 0.7 1.0 0.3 Product Streams (KMTD) Olefins 15.4 16.1 Aromatics 4.5 4.1 (0.4) Offgas 5.3 5.4 0.1 Heavy Oils 3.2 3.3 Coke 1.6 0.9 (0.8) This table shows a side by side comparion between the delayed coking/hydrocracker complex, these units are in thousand metric tons per day. Because of the resid defulrization unit the FCC complex consumes hydrogen and thus requires more natural however if you look at the overall coke yields, the FCC complex makes about 800 tons/day less coke and therefore more liquid product which offset the higher operating and capital costs of the RCD/RFCC configuration. RCD/RFCC Complex Provides Higher Liquid Yields Offsetting Higher Capital and Operating Expense UOP

LCO UnicrackingTM Unit
Evaluating the Appropriate Operating Severity Nat Gas H2 Plant H2 H2 Plant Naphtha/LPG Off Gas SR Naphtha Steam Cracker Olefins Crude Oil Aromatics Complex HDT Severity RCD Unionfining Unit Aromatics Complex Aromatics Now that we have chosen our configuration lets look at other synergies in the integrated complex. Traditionally in a fuels driven refinery we try and avoid producing incremental LPG and light ends since they are difficult to blend into the fuels pool. Therefore we limit the severity of our hydrotreating units. But in the integrated complex with a steam cracker we can afford to increase the hydrotreating severity, and the incremental naphtha LPG is fed to the steam cracker. Heavy Oils RFCC Unit LCO UnicrackingTM Unit Coke UOP

Hydrotreating Severity Improves Olefin Yields
Commercial FCC C3= Yields vs Feed Contaminants Operating Units FCC C3= Yield (Lb/BBL FF) 40 Hydrotreated Resid Hydrotreating Severity 35 30 25 Straight Run Resid Meanwhile there are also benefits for the FCC. This chart shows 4 commercial operating units FCC propylene production on the y axis and Feed contaminent metals on the x axis which are a proxy for the hydrogen content in the FCC feed. We see in this example that the hydrotreated resid units make more propylene per barrell than the straight run resid units, and so as we increase hydrotreating severity, we not only generate additional SC feedstock, but we increase the propylene production from the FCC as well. 20 10 20 30 40 FCC Feed Ni + V (wppm) Increased RCD Severity Increases Olefin Yields, Generates Additional SC Feedstock UOP

Worlds Largest Process Licensing Organization
Refining Aromatics UOP Fluid Catalytic Cracking Process UOP LCO-XTM Process UOP UnicrackingTM Process UOP Distillate UnionfiningTM Process UOP SelectFiningTM Process UOP MeroxTM Process UOP PenexTM Process UOP CCR PlatformingTM Process UOP HF Alkylation Process UOP RCD UnionfiningTM Process UOP UniflexTM Process UOP ParexTM Process UOP IsomarTM Process UOP TatorayTM Process UOP SulfolaneTM Process UOP MX SorbexTM Process UOP Q-MaxTM Process Olefins UOP/HYDRO MTO Process Total Petrochemicals/UOP Olefins Cracking Process UOP OleflexTM Process UOP MaxEneTM Process UOP Propylene Recovery Unit UOP Is the worlds largest process licensing organization which includes a comprehensive portfolio of refining (click), aromatics (click), olefins (click) and hydrogen technologies. However, simply having the best set of individual technologies is not enough. It also requires the knowledge and capabilities that UOP has to properly integrate these technologies Hydrogen UOP PolybedTM PSA System UOP PolysepTM Membrane System Having the Best Technology Solutions is Not Enough UOP 37 37 37

Integration Opportunities Realized
Capture Integration Opportunities Project Objectives UOP Capabilities Minimize energy consumption and environmental footprint CapEx/ OpEx Targets Fuels/Petrochemical Product Slate Rapid Project Implementation Catalyst and Adsorbent Technology Process Technology Technical Services Optimization Services Field Operating Services Integration Opportunities Realized In summary, the continued increase in petrochemical demand will drive companies to move toward integrated complexes to gain a competitive advantage. As we’ve seen it’s very important to select the proper technologies to meet the specific objectives. As an industry leader in refining and petrochemical technologies, UOP offers unmatched capability to bring our customers customized, integrated solutions to deliver maximum value However, it doesn’t stop there. UOP also has a full compliment of services and will be with during every step of the project from the initial concept thru design commissioning and optimization of the on-stream units and will be with every step of the way. And with that I’d like to thank you again for you time and would be happy to take any questions. UOP offers unmatched capability to deliver customized, integrated solutions UOP

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