UOP SeparALL Overview

© 2013 UOP LLC. All rights reserved.

The New UOP SeparALL™ Process and UOP Polybed™ PSA

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Honeywell’s Businesses

Aerospace Transportation Systems

Performance Materials & Technologies

Automation & Control Solutions

Morristown, NJ global corporate headquarters

$37.6 billion in revenues in 2012, 50% outside of U.S. Nearly 125,000 employees operating in 100 countries 19,000 engineers and scientists

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UOP Company Profile Serving the Gas Processing, Refining & Petrochemical Industries

Profile — Significant Technology Position

Business Units: Gas Processing and Hydrogen (GP&H) Process Technology & Equipment (PT&E) Catalysts, Adsorbents & Specialties (CA&S) Renewable Energy and Chemicals (RE&C)

Offering: Technology, catalyst & services to the refining,

petrochemical and gas processing industries Supplier of molecular sieve adsorbents to process

and manufacturing industries

UOP Facilities — Global Footprint Sales: Geographic

Sales: Breakdown

North America

32%

Asia Pacific19%

China12%

Middle East9%

SouthAmerica

9%

E&A 9%

CIS 5%India5%

UOP Offices UOP Manufacturing Sites

20 Offices 17 Countries 12 Manufacturing Facilities 5 Engineering Centers

Worldwide Headquarters Des Plaines, Illinois (suburban Chicago) 3,500+ Employees

Global Customers

Equipment

45%

Licensing

7%

Services

13%

Products

35%Equipment

Products

Services

Licensing

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Benefits of a UOP Integrated Solution in a Refinery

Our technologies and products are designed to deliver superior performance, safety and value when combined in an integrated system:

High availability and reliability of processes and products

Lower capital expenditure and operating costs resulting in lower cost of production of hydrogen

Acid Gas Removal PSA Sulfur Recovery

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Hydrogen Dynamics in China

Growth for hydrogen will mainly come from the oil refining industry

2. Environmental regulation / improved refinery performance

3. Demand for transportation fuels

1. Critical feedstock for various industries

State Mandate – upgrade diesel and gasoline Process heavier and more sour crude Long on Heavy Fuel Oil (HFO) and Petroleum Coke Improve margins by maximizing high-value refined product output

Oil demand rising at >8% CAGR Refining capacity to double from 2012 to 2022 China’s footprint expanding as a global supplier of refined products and fuels

Refining industry Hydrocracking, hydrotreating and isomerization processes

Ammonia Production Approx. 0.18 – 0.20 kg hydrogen per kg of ammonia required

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Growth Potential for Hydrogen

9.3 9.9 9.6 9.8 10.2 10.9 12.0 12.6

2.9 3.6 4.0 4.3

4.9

7.6

10.0 11.2

1.1 1.1 1.6

2.0 2.6

2.8

4.5

5.4

0

5

10

15

20

25

30

2008 2009 2010 2011 2012 2015 2020 2022

Mill

ion

Tons

Years

Methanol Refineries Ammonia

21

26

29

18 16

15 15 13

Source: Chem1 Market Assessment Study for Hydrogen

Growth for hydrogen will mainly come from the oil refining industry

Hydrogen segment assessment in China (Million tons) CAGR 2012-2022

8%

8%

2%

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Five Year Plan Target … Control Sulfur Emissions

Increasing sour crude processing and stricter sulfur controls requires added capacity for hydrogen production

Fuel Standards State II Current

State III 2013

State IV 2015

State V

GASOLINE Sulfur, ppm

Olefin, v% Manganese, g/L Vapor pressure

(Summer), kappa

500 35 0.018 74

150 30 0.016 72

50 28 0.008 40~68

10 25 0.002 40~65

DIESEL Sulfur, ppm

Cetane number Density, 20℃ kg/cm3

Fatty acid ester Heavy Aromatics

500 49 820-860 /,/

350 49 810-850 0.5%v,11%m

50 51 820-845 /, 11%m

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Source: Chem1 Market Assessment Study for Hydrogen; Hart Energy Consulting Analysis (2010)

DIESEL

Comments

Improving energy efficiency combined with reducing greenhouse gas emissions are key in the five year plan

China relies heavily on the ME for most of its oil supplies which is sour

ME Crude Oil Specs: Current API = 34 S (wt%) = 1.75 API = 33.9 S (wt%) = 1.84

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Breakdown of Feedstock for Hydrogen Production

Coal gaining prominence as an alternative cheaper feedstock

1.1 1.2 1.3 1.4 1.5 1.7 1.9 2.1

0.6 0.7 0.8

0.8 0.9

1.1

1.9 2.1

0.1 0.1

0.1 0.1 0.1

0.6

0.6

0.8

0

1

2

3

4

5

6

2008 2009 2010 2011 2012 2015 2020 2022

Mill

ion

Tons

Year

others coal NG ROG

Source: Chem1 Market Assessment Study for Hydrogen

Hydrogen market assessment in China (Million tons)

1.8 2.0

2.2 2.4

2.5

3.4

4.4

5.0

18%

9%

4%

CAGR 2012-2022

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Current Hydrogen Production Methods

TECHNOLOGY TARGET H2 USERS

SMR + PSA CH4 + H2O CO + 3H2 CO + H2O CO2 + H2

Gasification C+ H2O CO + H2 CO + H2O CO2 + H2

Refining Hydrocracker / Hydrotreating / Isomerization

Naphtha / HFO

Coal

Gasification CnHm+(n/2)O2 = nCO+m/2 H2 CnHm+nH2O=nCO + (n+m/2)H2 CO + H2O CO2 + H2

Chemicals Methanol / Ammonia / Aromatic derivatives

FEEDSTOCK

Natural gas / Off gas / LPG Coal / Refinery Bottoms

Others ( H2O, methanol etc.)

Electrolysis 2H2O 2H2 + O2 CH3OH CO + 2H2 CO + H2O CO2 + H2

Others Electronics / Metallurgy / Fuel

Lower cost feedstock improves product margins

Power Coal to liquids > DME / Gasoline

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Case Study Comparing SMR & Gasification

1. Basis

Natural Gas Price: $13/MMBtu (HHV = 22,400 Btu/lb) - based on LNG imports

Petcoke Price: $1/MMBtu (HHV = 15,000 Btu/lb)

Coal Price: $3.50/MMBtu (HHV = 12,000 Btu/lb)

Hydrogen required for refinery: 100,000 Nm3/h

2. Configurations

H2

CO2

H2S

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Petcoke

Coal

O2

ASU

Pure H2 To Refinery

Syngas

Natural

Gas/ROG

Gasification

Pure H2 To Refinery

Polybed PSA

Polybed PSA

SMR

CO Shift UOP

SeparALL Process

H2

CO Shift

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Desulfurization

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Hydrogen Production Cost

0.212

0.153 0.110

Natural gas Coal Petcoke

Hydrogen production cost in China, $/Nm3

UOP processes drive value in hydrogen production

Cheaper feedstock cost directly influences the cost of hydrogen production

1.01 1.67

0.10 0.11 0.12 0.13 0.14

Capex $ MM

Feedstock $/MMBTU

SENSITIVITY ANALYSIS FOR PETCOKE FEED

11.89 14.11

0.18 0.19 0.20 0.21 0.22 0.23 0.24

Feedstock, $/MMBTU

Capex $MM

SENSITIVITY ANALYSIS FOR NATURAL GAS FEED

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What is the UOP SeparALL Process?

Absorption / regeneration process for selective removal of H2S, COS, & CO2 Uses a “next generation” physical solvent (SELEXOL™ MAX Solvent) Uses a typical solvent-extraction flow-scheme Loading directly proportional to partial pressure

Physical vs Chemical Typical Gasification Application

High Pressure is advantageous

Acid Gas

Feed Gas

Treated Gas

Solv

ent L

oadi

ng

Physical Solvent Chemical Solvent

Partial Pressure

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SELEXOL MAX Solvent Characteristics

SELEXOL MAX Solvent: A physical solvent Chemically similar and completely compatible with SELEXOL Solvent Clear fluid that looks like tinted water

Regenerated by changing pressure, temperature or applying a stripping gas

Unique selectivity characteristics desirable for gasification syngas treating Relative Solubility Data

H2 ~ 1 CO ~ 2.2 CO2 ~ 76 COS ~ 175 H2S ~ 680

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SELEXOL MAX Solvent = Selective

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Two Basic Flow-schemes

Sulfur removal only Typically for power applications Can reduce treated gas any desired sulfur level One solvent absorber with solvent regeneration

Sulfur removal with separate CO2 removal (CCS or chemicals production) Typically for chemicals, SNG or coal to liquids applications Typically involves more stringent product specifications Integrated solvent absorbers and solvent regeneration

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UOP SeparALL Process Advantages

Mild chilling Simple flow schemes with few pieces of equipment

Lower solvent losses

Absorbs NH3, HCN and other trace contaminants,

without the need for additional equipment Removes metal carbonyls Metal carbonyls in treated syngas decompose at gas turbine burners and

potentially plate-out on the gas turbine blades Metal carbonyl can also act as catalyst poisons for chemical applications

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Through its improved efficiency and next generation technology, the SeparALL process can reduce capital

expenditures by up to 10 percent and operating expenditures by more than 20 percent.

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Reliability / Availability / Maintainability

The UOP SeparALL process provides > 99% availability Availability exceeds typical gasifier availability

(typically 80 - 90%) UOP training and services teams work with

operators to help optimize and maintain the system at peak efficiency

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Commercial Experience in Gasification

ITALY Sarlux IGCC CLICK TO LEARN MORE

U.S. Coffeyville Resources CLICK TO LEARN MORE

CANADA OPTI Canada CLICK TO LEARN MORE

ITALY API Energia IGCC CLICK TO LEARN MORE

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OPTI Canada Plant

Start-Up 2008

Application H2 Production & Fuel Gas

Production 337,000 Nm³/h syngas

AGRU Duty Sulfur

Syngas Flow 320 MMSCFD @ 550 psia

Feedstock Visbreaker Residue Canada

OPTI Canada Plant


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Sarlux IGCC Complex Plantt

Start-Up 2000

Application Power H2 Production

Production 550 MW net / 40000 Nm³/h

AGRU Duty Sulfur

Syngas Flow 404 MMSCFD @420 psia

Feedstock Visbreaker Residue


Sarroch, Sardinia, Italy

Sarlux IGCC Complex Plant

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Electric Power

Raw Hydrogen

Elemental Sulfur

Steam for Export

High Purity Hydrogen to Hydrocracker

Combined Cycle Power Plant

Claus Plant Gas Cooling

& COS Hydrolysis

Air Separation Unit

Gasifier w/ Quench

& Scrubbing

Tail Gas

Air

O2

Block Flow Diagram | Sarlux IGCC

Purified Syngas

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PolybedTM

PSA

PolysepTM Membrane

Visbroken Residue

SELEXOL

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API Energia IGCC Complex Plant

Start-Up 1999

Application Power

Production 250 MW net

AGRU Duty Sulfur


Feedstock Visbreaker Residue Falconara, Italy

API Energia IGCC Complex Plant


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Elemental Sulfur

Syngas Expander

Gas Cooling & COS

Hydrolysis

Gasifier w/ Quench

& Scrubbing

Tail Gas Treatment & Incinerator

Air

O2

Block Flow Diagram | API Energia Asphalt

N2

Combined Cycle Power

Plant

Electric Power

Steam for Export

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Air Separation Unit

Claus Plant SELEXOL Visbroken Residue

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Coffeyville Resources Plant

Start-Up 2000

Application Ammonia Urea

Production 21 T/h | 62 T/h

AGRU Duty Sulfur & CO2


Feedstock Petcoke Coffeyville, Kansas

Coffeyville Resources Plant


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Acid Gas

Claus Plant

Syngas Scrubbing

Quench Gasification

Air

N2

NH3 Product

UAN Product

Block Flow Diagram | Coffeyville Resources

Petroleum Coke

CO Shift & Gas Cooling

Raw CO2

CO2

Vent CO2 Purification

SELEXOL 2-Stage

Purified CO2

Polybed PSA

Tail Gas

High Purity H2

Raw H2

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O2

Air Separation Unit UAN Plant Ammonia

Synthesis

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SELEXOL Unit POLYBED PSA Unit

Coffeyville Resources Gasification Ammonia Complex


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H2 Purification – Polybed PSA Systems

H2 @ High Purity High Pressure

Impurities (+H2) Low Pressure

H2 + Impurities High Pressure

H2 Purity 99.9 – 99.9999% H2 Recovery 60 – 90% H2 Feed pressure 6 - 40 bar g H2 Product pressure 5 - 39 bar g

PRODUCT

FEED GAS

TAIL GAS

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Components of a PSA Unit

Control System

Valve Skid

Vessels & Adsorbents

UOP Service & Support

1

1

2

3

4

2

3

4

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PSA Technology - Delivered as Equipment

Equipment & Fabrication Adsorber Vessels Surge Tank Valve Skid Instrumentation & Valves Adsorbent Control System

Process

Mechanical

Instrumentation

Control System

Project Management

Quality Control

Engineering & Services Adsorbent Loading Supervision

Control Loop Testing

Unit Start-up

Installation Checkout

Operator Training

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PSA with Maximum On-Stream Reliability

For a customer in China that needs a reliable source of high purity hydrogen, UOP Polybed™ PSA provides greater than 99.8% on-stream availability that results in $500,000/day of additional value due to downtime avoided versus local PSA suppliers. We do this by providing proven designs, proprietary adsorbents, and equipment.

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Assumptions: • 100,000 Nm3/hour product PSA unit • H2 value = 15000 RMB/MT = $0.21/Nm3 • Calculation: 100,000 x 24 x 0.21 = $504,000/day • The cost from the loss of production from the

downstream hydroprocessing units, if known, would be added to the cost of the loss of H2

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Q u e s t i o n a n d A n s w e r

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UOP SeparALL Overview

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