View
16
Download
1
Tags:
Embed Size (px)
DESCRIPTION
Slides upgrade heavy oil
Citation preview
Heavy Oil UpgradingA key solution for heavy oil upstream and midstream operationsA key solution for heavy oil upstream and midstream operations
FORWARD-LOOKING STATEMENTS: This document includes forward-looking statements, includingforward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995.Forward-looking statements include, but are not limited to, statements concerning the potential benefits ofIvanhoe Energy’s heavy oil upgrading technology, the potential for commercialization and futureapplication of the heavy oil upgrading technology and other technologies, statements relating to thecontinued advancement of Ivanhoe Energy’s projects, the potential for successful exploration anddevelopment drilling, dependence on new product development and associated costs, statements relatingto anticipated capital expenditures the necessity to seek additional funding statements relating toto anticipated capital expenditures, the necessity to seek additional funding, statements relating toincreases in production and other statements which are not historical facts. When used in this document,the words such as “could,” “plan,” “estimate,” “expect,” “intend,” “may,” “potential,” “should,” and similarexpressions relating to matters that are not historical facts are forward-looking statements. AlthoughIvanhoe Energy believes that its expectations reflected in these forward-looking statements arereasonable, such statements involve risks and uncertainties and no assurance can be given that actual, gresults will be consistent with these forward-looking statements. Important factors that could cause actualresults to differ from these forward-looking statements include the potential that the company’s projectswill experience technological and mechanical problems, new product development will not proceed asplanned, the HTL technology to upgrade bitumen and heavy oil may not be commercially viable,geological conditions in reservoirs may not result in commercial levels of oil and gas production, theavailability of drilling rigs and other support services, uncertainties about the estimates of reserves, therisk associated with doing business in foreign countries, environmental risks, changes in product prices,our ability to raise capital as and when required, competition and other risks disclosed in IvanhoeEnergy’s Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission onEDGAR and the Canadian Securities Commissions on SEDAR.
Our Company Profile
We are an international, heavy oil and gas company focused on pursuing long‐term growth in its reserves and production. Core operations are in Canada, China, Mongolia and Ecuador, with business development activities worldwide.
We use technologically innovative methods and proprietary technologies in the development of heavy oil and other oil and gas assets, including the application of our patented, Heavy‐to‐Light (HTL) upgrading process.p , y g ( ) pg g p
Ivanhoe Energy Inc.
Ivanhoe Energy Latin America Inc.
Ivanhoe Energy Canada Inc.
Sunwing Energy Ltd.
Ivanhoe Energy MENA Inc.
Ivanhoe Energy Ecuador Inc.
HTL enables economic development of Heavy Oil
Upgrade Heavy Oilinto Lighter Product
EliminateDiluent
Reduce Complexity& Integrate Facilities Lower Cap Ex
MaximizeProduct
Value
MinimizeProduction
Costs
Minimize use ofNatural GasConvert Byproducts
i t U bl E
Value Costs
into Usable Energy
Alliance with engineering &project management contractor
Completed Front End Engineering Cost Estimation Execution Strategy
CommercialReadiness
Validated process yieldsand proved scalability
The Global Heavy Oil Opportunity
• The IEA has estimated that heavy oil deposits (< 20 API) contain nearly 50%
• But, of the 1.0 trillion barrels of oil produced to date only 1% has
E ti t d R bl Oil
deposits (< 20 API) contain nearly 50% of global, future recoverable resources.
oil produced to date, only 1% has been contributed by heavy oil.
1 0
Oil Produced to Datetrillions of barrels
4 0
Estimated Recoverable Oiltrillions of barrels
Conventional 2 3
0.5
1.0Conventional, 1.0
2.0
4.0
Heavy, 2.0
Conventional, 2.3
0.0
Heavy, 0.01
0.0
IEA – International Energy AgencyIEA International Energy Agency”Resources to Reserves—Oil and Gas Technologies for the Energy Markets of the Future”, 2005
Heavy Oil Production Challenges
• Large amounts of external energy required for production,up to 25% of energy accounted for in the heavy oil itself
• High viscosity, requires diluent for transportation
• Low market value due to high content of residual oil
• Conventional upgrading solutions have large minimum
Low market value due to high content of residual oil
scale & are not integrated with upstream energy demand
Result
Stranded and Distressed assets worldwide
HTL Solves each Heavy Oil Challenge
Energy Intensive All byproduct coke & gas is converted on‐site to usable i th f f t l t i l
Heavy Oil Challenges HTL Solutions
gyenergy in the form of steam or electrical power
D t h lt d i i it b 99% dHigh Viscosity
Destroys asphaltenes, reducing viscosity by 99% and eliminating the need for diluent
Large Fractionof Residual Oil
HTL converts 90% of residual oil into lighter & more valuable products
TraditionalUpgradingE i ll
Economic at scales as low as 10,000 ‐ 30,000 bpd; Typical CapEx ranges from US$ 12,000 ‐ $20,000 per bblEconomically
Challenged
Typical CapEx ranges from US$ 12,000 $20,000 per bbl(USGC basis)
Fundamentals of the HTL Process
• Fast thermal cracking at low pressure
Hi h i ld f th ti d il• High yields of synthetic crude oil
• Conversion of all coke & gas into energy
• Effectively utilizes concept of thin films
• Non‐catalytic
• No hydrogen required
HTL Process Description
Prefractionation
HTL Process – Comparison to Crude Distillation Unit
HTL Prefrac. Products CDU Products
Atmospheric Distillate Light Naphtha
Prefractionation
Atmospheric Distillate Light Naphtha
Vacuum Distillate Heavy Naphtha
Vacuum Residuum Kerosene / Jet Fuel
Light Atmos. Gas Oil
Heavy Atmos. Gas Oil
Light Vacuum Gas Oilg
Heavy Vacuum Gas Oil
Vacuum Residuum
HTL Process Description
Prefractionation Reaction Section
HTL Process Description
Prefractionation Reaction Section
HTL Process Description
Prefractionation Reaction Section
HTL Process Description
Prefractionation Reaction Section
HTL Process Description
Prefractionation Reaction Section
HTL Process Description
Prefractionation Reaction Section Product Separation
HTL Mechanically Similar to a Fluid Catalytic Cracker
• Over 450 FCC’s operating globaly
• Robust, thoroughly proven, and reliable
HTL FCC
Reactor / Stripper
Regenerator
HTL Upgrades Residual Oil into Lighter SCO and Energy
Upgrade Heavy Oilinto Lighter Product
EliminateDiluent
Reduce Complexity& Integrate Facilities Lower Cap Ex
MaximizeProduct
Value
MinimizeProduction
Costs
Minimize use ofNatural GasConvert Byproducts
Value Costs
into Usable Energy
Alliance with engineering &project management contractor
Completed Front End Engineering Cost Estimation Execution Strategy
CommercialReadiness
Validated process yieldsand proved scalability Continued Process
Improvement
Product Yields – Athabasca Bitumen Feedstock
Products
SCO 85 wt% (92 LV%)
Coke 10 wt% convertedCoke 10 wt%
Gas 5 wt%Feed
Athabasca Bitumen
converted to steam
Feed and Product Property Comparison
Athabasca Bitumen Upgrading, Feed and Product Properties
Bitumen SCOBitumen SCO
o API 8.5 18.8
Viscosity @40oC, cSt 23,000+ 23
Sulfur, wt% 5.0 2.9
Nitrogen, wt% 0.7 0.4
Nickel, ppm 79 15
Vanadium ppm 209 27Vanadium, ppm 209 27
Resid, 1000oF+, wt% 52 6
Feed and Product Composition Comparison
100%
Athabasca Bitumen Upgrading, Feed and Product Composition
75%
80%
85%
90%
95%
Naphtha, IBP‐375F
50%
55%
60%
65%
70%
75%
olum
e %
Kerosene, 375‐455F
Distillate, 455‐650F
30%
35%
40%
45%
50%
D1160, vo
VGO, 650~1000F
5%
10%
15%
20%
25%
Resid, ~1000F+
0%
Athabasca Bitumen Synthetic Crude Oil
HTL enables Low Cost Production of Heavy Oil
Upgrade Heavy Oilinto Lighter Product
EliminateDiluent
Reduce Complexity& Integrate Facilities Lower Cap Ex
MaximizeProduct
Value
MinimizeProduction
Costs
Minimize use ofNatural GasConvert Byproducts
i t U bl E
Value Costs
into Usable Energy
Alliance with engineering &project management contractor
Completed Front End Engineering Cost Estimation Execution Strategy
CommercialReadiness
Validated process yieldsand proved scalability Continued Process
Improvement
Lower Production Costs – Energy Integration
• Byproduct coke and gas converted within the HTL unit to steam
• Minimizes Natural Gas required for thermal EOR
2.4 bbls of High Pressure Steam produced by HTL…
1 bbl f… per 1 bbl of Athabasca Bitumen processed in HTL
Lower Production Costs – Integration of Facilities
SAGD CPF
SHAREDOFFSITES, UTILITIES & INFRASTRUCTURE
PRODUCTIONFACILITIES
• Tank Farm• Roads & Pipelines• Electrical Power• Source Water Treating
• Oil Degassing• Oil Dewatering• Waste Water Treating• Steam Generation g
• Boiler Water Supply• Air / Nitrogen Utilities
Lower Production Costs – Integration of Facilities
SAGD CPFIntegrated CPF
SHAREDOFFSITES, UTILITIES & INFRASTRUCTURE
PRODUCTIONFACILITIES HTL FACILITIES
SHAREDOFFSITES, UTILITIES & INFRASTRUCTURE
PRODUCTIONFACILITIES
• Tank Farm• Roads & Pipelines• Electrical Power• Source Water Treating
• Oil Degassing• Oil Dewatering• Waste Water Treating• Steam Generation
• Heavy Oil Upgrading• Steam Generation
• Tank Farm• Roads & Pipelines• Electrical Power• Source Water Treating
• Oil Degassing• Oil Dewatering• Waste Water Treating• Steam Generation g
• Boiler Water Supply• Air / Nitrogen Utilities
g• Boiler Water Supply• Air / Nitrogen Utilities
Minimize Infrastructure Investment & Operating Expenses
Production Field
Current Future
bpd 40 000 10 000
Production rate of lighter oil in decline due to depleting resources
bpd 40,000 10,000
API 31 31Marker Crude w/ Pipeline & Contract Specifications
Current FutureProduction Field
Current Future
bpd 40,000 40,000
API 25 19
Current Future
bpd 80,000 80,000
API 28 17
viscosity 100 cP 3,800 cPAPI 25 19
Heavy Production Field
Current Future
bpd 0 30,000
API n/a 8
Main Oil Pipeline
Future projects will bring heavy resources into production
Minimize Infrastructure Investment & Operating Expenses
Production Field
Current Future
bpd 40 000 10 000
Downstream refiners limited by heavy oil processing capabilitiesbpd 40,000 10,000
API 31 31Marker Crude w/ Pipeline & Contract Specifications
Current Future
heavy oil processing capabilities
Production Field
Current Future
bpd 40,000 40,000
API 25 19
Current Future
bpd 80,000 80,000
API 28 17
viscosity 100 cP 3,800 cPAPI 25 19
Heavy Production Field
Current Future
bpd 0 30,000
API n/a 8
Main Oil Pipeline
Pipeline facilities stressed due to increasing viscosity of oilto increasing viscosity of oil
HTL offers a unique Midstream Solution
Midstream HTL upgrades heavy crude oil into lighter, transportable SCO and produces electrical power from excess energy
Gross production of Electrical Power ranges from 1 3 1 7 MW per mpbd of HTL capacityGross production of Electrical Power ranges from 1.3 – 1.7 MW per mpbd of HTL capacity
Minimize Capital Intensity & Complexity of Upgrading
HTL Upgrader
Distillation UnitHTL /
Distillate; < 1000 oF
Sour, Synthetic Distillation Unit
Reactor/Reheater
Integrated Energy Recovery
Heavy Crude
Residuum Crude Oil
Electrical Power
Delayed Coking Upgrader
orSteam
HydrogenPlant
Sulfur Recovery Units
Distillate; S t
SulfurNatural Gas H2 H2S
DistillationUnit
HydrotreatingUnitsHeavy
Crude
;< 1000 oF Sweet,
Synthetic Crude Oil
Delayed CokingUnit
Residuum Coke
Minimize Capital Intensity & Complexity of Upgrading
GHA – Distillation UnitB – Light Hydrotreating UnitsC – Coking Unit
F CA
gD – Heavy Hydrotreating UnitsE – Hydrogen UnitF – Sulfur Recovery UnitsG – Coke StorageH Sulfur Storage
BEDH – Sulfur Storage
Minimize Capital Intensity & Complexity of Upgrading
70 000
HTL economic advantage increases at smaller capacity due to a less complex facility
60,000
70,000
40,000
50,000
Delayed Coking Upgrader, Installed Cost$ / bbl capacity,
20,000
30,000Delayed Coking Upgrader, Installed Cost$ / bbl capacity,
USGC cost basis
0
10,000
0 20,000 40,000 60,000 80,000 100,000 120,000 140,000 160,000
HTL Upgrader, Installed Cost
Barrels per day Upgrading Capacity
Minimize Capital Intensity & Complexity of Upgrading
• HTL process is less severe than coking, and nets a higher liquid product yield
• Captures a majority of quality differential through the rejection of heavy, residual oil
100%
Bitumen9 API5% Sulfur50% > 1000oF Resid
95%
ProductHTL SCO19 API3% Sulfur
85%
90%Yield, vol% 5% > 1000oF Resid
80%
85%
5 10 15 20 25 30
Traditional SCO28 API0.5% Sulfur0% > 1000oF Resid
5 10 15 20 25 30
Product API Gravity
Commercial Readiness
Upgrade Heavy Oilinto Lighter Product
EliminateDiluent
Reduce Complexity& Integrate Facilities Lower Cap Ex
MaximizeProduct
Value
MinimizeProduction
Costs
Minimize use ofNatural GasConvert Byproducts
i t U bl E
Value Costs
into Usable Energy
Alliance with engineering &project management contractor
Completion of Front End Engineering Cost Estimation Execution Strategy
CommercialReadiness
Validation of process yieldsand proved scalability Continued Process
Improvement
Technology Development History
Ensyn Canadian company – developed Rapid Thermal p y p p
Processing (RTP) for conversion of biomass into liquids
― 7 units operating commercially
― demonstrates robust time on‐stream
extended core RTP process to heavy oils → HTL
Ivanhoe acquired HTL process in April 2005
Technology Development History
Commercial Demonstration Facility (CDF)Commercial Demonstration Facility (CDF) proved commercial scalability
tested multitude of heavy crudes
demonstrated high quality of products
provided commercial design parameters
showcased HTL in an operating field
Technology Development History
Feedstock Test Facility (FTF) Mission
• Improve HTL process – test design enhancements and modifications
• Provide product yield & quality data for commercial heavy oil feeds
• Expand upon & refine design parameters for HTL commercial units
30 ft
FTF to Commercialization
FTF Results provide a multi‐discipline design basis for commercial HTL facilities
Safety‐ HAZOP
‐ Risk Assessments
Instrumentation‐ Instrument Selection
‐ Control and Data acquisition‐Training ‐ Cause and Effect
ProcessProcess‐ Heat and Material Balance
‐ Design Philosophies
Mechanical‐Material Selection HTL Commercial
D i B i
FTF Results
‐Mechanical Datasheets Design Basis
Process Advancement Achieved through the FTF
HTL Performance Parameters for Athabasca Bitumen, before and after FTF Design Improvements
Before After
Once‐Through Residuum (1000oF+ in Product), lv% 40% 5%
Yield, Synthetic Crude Oil (SCO), wt% 75% 85%
Synthetic Crude Oil (SCO), lv% 81% 92%
Coke, wt% 16% 10%
C4 minus Gas, wt% 9% 5%
HTL capital intensity lowered by 10%, achieved through reduction in equipment sizing
HTL Commercial Deployment
Engineering and Project Execution Strategy
International provider of engineering & project management services
Project E iOperator & Execution‐ Engineering‐ Procurement‐ Construction
Operator & Internal HTL
Licensor
Tier 1Contractor
‐ Project Mgmt
Engineering Advancements – Field Integrated HTL
• FEED has been completed for Tamarack HTL
blueprint for design of other field integrated HTL projects
d l d h d modularization strategy incorporated into the design
Class 3 cost estimate (+25 / ‐20 %)
Midstream HTL Engineering Advancement
• Conceptual engineering completed for midstream HTL
Tamarack FEED utilized as a blueprint for HTL core processing facility
d ld l d f d l & l engaged world class vendors for desalter, water treating, & power generation solutions
Class 4 (AACE) cost estimate and schedule (+35/‐30 %)
HTL enables economic development of Heavy Oil
Upgrade Heavy Oilinto Lighter Product
EliminateDiluent
Reduce Complexity& Integrate Facilities Lower Cap Ex
MaximizeProduct
Value
MinimizeProduction
Costs
Minimize use ofNatural GasConvert Byproducts
i t U bl E
Value Costs
into Usable Energy
Alliance with engineering &project management contractor
Completed Front End Engineering Cost Estimation Execution Strategy
CommercialReadiness
Validated process yieldsand proved scalability