Does Heavy Oil Recovery Need Steam?
•Download as PPTX, PDF•
2 likes•12,613 views
Heavy Oil recovery traditionally starts with depletion drive and (natural) waterdrive with very low recoveries as a result. As EOR technique, steam injection has been matured since the 1950s using CSS (cyclic steam stimulation), steam drive or steam flooding, and SAGD (steam assisted gravity drainage). The high energy cost of heating up the oil bearing formation to steam temperature and the associated high CO2 footprint make steam based technology less attractive today and many companies in the industry have been actively trying to find alternatives or improvements. As a result there are now many more energy efficient recovery technologies that can unlock heavy oil resources compared with only a decade ago. This presentation will discuss breakthrough alternatives to steam based recovery as well as incremental improvement options to steam injection techniques. The key message is the importance to consider these techniques because steam injection is costly and has a high CO2 footprint Johan van Dorp holds an MSc in Experimental Physics from Utrecht University and joined Shell in 1981. He has served on several international assignments, mainly in petroleum and reservoir engineering roles. He recently led the extra heavy-oil research team at the Shell Technology Centre in Calgary, focusing on improved in-situ heavy-oil recovery technologies. Van Dorp also was Shell Group Principal Technical Expert in Thermal EOR and has been involved with most thermal projects in Shell throughout the world, including in California, Oman, the Netherlands, and Canada. He retired from Shell after more than 35 years in Oct 2016. Van Dorp (co-)authored 13 SPE papers on diverse subjects.
Recommended
More Related Content
What's hot
What's hot (20)
Similar to Does Heavy Oil Recovery Need Steam?
Similar to Does Heavy Oil Recovery Need Steam? (20)
More from Society of Petroleum Engineers
More from Society of Petroleum Engineers (20)
Recently uploaded
Recently uploaded (20)
Does Heavy Oil Recovery Need Steam?
- 1. Society of Petroleum Engineers Distinguished Lecturer Program www.spe.org/dl 2 Johan van Dorp Does Heavy Oil Recovery Need Steam? 35 years with Shell Group - Retired Oct 2016
- 2. OUTLINE • GLOBAL HEAVY OIL & BITUMEN • THE HEAVY OIL RECOVERY CHALLENGE • NEW TECHNOLOGIES & DEVELOPMENT OPTIONS • MODELLING CHALLENGES 3
- 3. mln bbl/day from thermal (steam based) projects (2%-4% per annum depletion). WORLD HEAVY OIL – RESOURCE BASE (IN PLACE) ~ 10 trillion bbls STOIIP Includes technically and economically challenged in-place resources (e.g. low So, thin beds, low net-to-gross, low permeability, immobile oil). Worldwide HO production is ±10 mln bbl/day (<0.1% p.a. depletion rate), of which 2 4
- 4. WORLD HEAVY OIL – THERMAL PRODUCTION (2014) Sources: - Hart Energy - Oil Sands Review Total: 2 million Bopd Note: Excludes production from surface mining in Canada (1,050 kbpd) (in planning 1,750 kbpd) 5Note: Heavy Oil = API < 18 (HartE&P)
- 5. Heavy Oil Production - It’s All About the Viscosity Heavy Oil and Bitumen viscosity varies vertically and laterally. Usually limited data Ref. Adams et al., University of Calgary,2008 Larter & Adams, JCPT Jan 2008V47 #1 MUST REDUCE VISCOSITY TO PRODUCE Need an accurate fluid model to design and optimize processes 6 1 10 100 1,000 10,000 100,000 0 50 100 150 200 250 300 HEAT DILUTE UPGRADE 350 (cP) T (deg C)
- 6. 250 200 150 100 50 0 0 30 CO2intensity(kg/bo) ThermalInput 10 20 Reservoir Thickness (m) 250 200 150 100 50 0 0 CO2intensity(kg/bo) ThermalInput 0.1 0.2 0.3 Reservoir Richness So.phi 250 200 150 100 50 0 CO2intensity(kg/bo) ThermalInput 0 20 40 60 80 100 Reservoir Pressure (bar) Energy Break-Even THERMAL PROCESS EFFICIENCY-CASE FOR ACTION IN LOW CO2 WORLD Thermal EOR is Energy Intensive Heat mostly rock (~90% of mass) Key Efficiency Factors Reservoir Pressure (determines steam T) Resource Richness (14 %wt 20% So.) Reservoir Thickness CO2 Footprint > 40 kg/bbl oil (avg. US refinery intake) HO Project 7
- 7. 50 200 250 0 10 CO2intensity(kg/bo) ThermalInput 250 200 150 100 50 0 0 CO2intensity(kg/bo) ThermalInput 0.1 0.2 0.3 Reservoir Richness So.phi 250 200 150 100 50 0 CO2intensity(kg/bo) ThermalInput 0 20 40 60 80 100 Reservoir Pressure (bar) Energy Break-Even THERMAL PROCESS EFFICIENCY-CASE FOR ACTION IN LOW CO2 WORLD Thermal EOR is Energy Intensive Heat mostly rock Key Efficiency Factors Reservoir Pressure Resource Richness Reservoir Thickness CO2 Footprint > 40 kg/bbl oil 8 Focus on: • Recovery Technologies − Incremen1t5a0l Improvements − Step Cha1n00ge Improvements • Process Impr0ovements − 2C0arbon30Capture& Storage, Reservoir −Thickn Ses os l( am r) Steam
- 8. EOR Technology Maturity – Application to Heavy Oil Process Maturity Novel Solvents Low Maturity In Testing Cyclic Solvents Foam Microbial In-Situ Combustion / HPAI Alkaline Surfactant Polymer Low Salinity Waterflooding In-situ Upgrading Process Contaminated / Acid Gas inj. Joule Heating / EM Heating VAPEX / Condensing Pure Solvent Commercial Technology Steam (SF, CSS, SAGD) Miscible Steam additives (Foam, Solvents) Polymer Flooding Thermal GOGD Faint colour = N/A for HO Underlined = Lower Energy Time 9
- 9. R&D RECOVERY TECHNOLOGIES – HEAVY OIL & BITUMEN 4. Solvent assisted (like ES-SAGD) Steam foam Hybrids (e.g. with In- situ combustion) In-Situ upgrading 1. Pure solvents (VAPEX & improvements) 2. Electro Magnetic heating & hybrids (3 types) 3. Polymer Surfactants 10 R&D Focus Reduce CO2 footprint of Heavy Oil and Bitumen recovery Unlock stranded Assets Thin reservoirs / Low quality reservoirs Fractured Carbonates Mature Breakthrough Improvements Incremental Improvements
- 10. PURE SOLVENTS 11 Solvent: “A usually liquid substance capable of dissolving or dispersing one or more other substances” Dissolve: “To mix with a liquid and become part of the liquid” Examples of Pure Solvents (Single component): Propane Butane Pentane Chloroform Ether Toluene Carbon di-sulfide Di-chloromethane Etc. P T V L
- 11. HOW CAN VAPEX BE IMPROVED? Unsuccessful VAPEX Field Pilots e.g. Dover Vapour solvent diffusion into viscous HO / bitumen is slow: Tabs itb rsolv Methane & NCG (solution gas) “poisons” the process D 12
- 12. 1E+0 1E+1 1E+2 1E+3 1E+4 1E+5 1E+6 1E-2 1E-1 1E+0 1E+1 1E+2 1E+3 1E+4 1E+5 1E+6 1E+7 MassFlux[g/m2.h ] /k. [ cP/Darcy ] Sand Packs NEI Sand Pack,2008 HeleShaw Nsolv, prediction VAPEX, prediction SOLVENT EXTRACTION USING LIQUID SOLVENT IS FAST Ref. Nenniger PETSOC 2008-139 1E-9 1E-8 1E-7 1E-6 1E-5 1E-4 1E-3 Flux[kg/m2.s] Total fluid flux Bitumenflux Bitumen diffusion into liquid Convective dispersion refreshes solvent front abs solv bit r solvent is fast: D T Solvent is a pure paraffinic H.C. (e.g, C3, C4 or C5) Gravity Drainage Fluxes 0 0.2 0.4 0.6 0.8 1 Solvent massfraction VAPEX outliers 13
- 13. TECHNOLOGY – CONDENSING SOLVENTS Technology Solvent at 40-60ºC instead of Steam Fast extraction at Solvent interface Upgraded product (less asphaltenes) Small inventory (vapour) Business Impact (comparison with Steam) 5x lower energy & GHG Faster than SAGD, similar R.F. 50% lower Capex: (no water, no water use) Applicable to low So, thinner resource (~5 m) Commercialisation Pilot & Demonstration by Technology Providers Ref. N-solv website 100 80 60 40 20 0 CO2(kg/bbloil) 0 100 200 300 Extraction Temperature (°C) STEAM Condensing Solvent 14
- 14. SOLVENT EXTRACTION – FIELD TRIALS Nsolv pilot: Bitumen Extraction Solvent Technology SAGD Well Configuration Operate 30-50 °C above Treservoir Faster than Steam Extraction Produce Upgraded Product Imperial: Cyclic Solvent Pilot Reservoir Conditions 31 Bar / 19 C Propane + diluent 100,000 to 200,000 bbl/well; 5 cycles Claim to have solution to manage unstable displacement 15 Ref. AER website, N-solv website IPTC 18214 Booneet.al
- 16. Reservoir Overburden Reservoir OverburdenOverburden Reservoir Electrode Electrode Production well Current Electro-thermal – (ET Energy) GE ~ Hz GHF CABLE LOOP ~ kHz ANTENNA GHF ~ MHz FORMATION ELECTRICAL HEATING – 4 PROCESSES HEATING ELEMENT Resistive – IUP process (Shell) GE ~ Hz Overburden Reservoir Heating by Thermal Conduction Induction – (Siemens) Deep Heating by Ohmic Heating of Formation Water High Frequency (RF) – (Harris) Heating by Eddy Currents in Formation Water Di-Electric Heating of Formation where Formation Water has Evaporated 17
- 17. Process – Formation “Joule” Heating (50-60 Hz) Drill electrodes wells (around 25 m spacing) Apply e-power and pre-heat to 60-110 C 1-2 years at 5A/m, Uniform Heating Produce oil by thermal expansion (5-10% OIP) Produce oil by (Foamy) Solution Gas Drive (15-25% OIP) Produce oil by EOR displacement method Technology Challenges: • Electrode Design not Mature • Cooling of Electrode may be required • Current Uniformity along Electrode ET Energy Vertical Well Pilot success (2011) 18McGee JCPT Jan 2007, V46 #1 SPE 117470McGee,
- 18. POLYMER FOR HEAVY OIL 19
- 19. Polymer for Heavy Oil EOR Reduce Waterflood Mobility Ratio by increasing Viscosity of Displacing Water (HPAM – Hydrolized PolyAcrylaMide) Mitigates Heterogeneity, Stabilises Injection Conformance Polymer applications for typical Heavy Oil (benign conditions): Low Temperature T < 70-80C Low Salinity environment <10,000 ppm TDS Medium/High Permeability K > 50 mD Polymers available with demonstrated stability at low cost and ease of handling, i.e. HPAM Low/Medium Viscosity < 100 cP CNRL & Cenovus apply polymer at large scale in Pelican Lake / Brintnell field (next slide). They do not target stable displacement. Research: increase flooding temperature to ~70C instead of 20C 20
- 20. POLYMER FOR HEAVY OIL & BITUMEN (CNRL – BRINTNEL) Formation: Thickness: Well Length (I&P): Live Oil Viscosity: Polymer Viscosity: Whabasca 3-6 m 1500 m+ 900 cP 25 cP Breakthrough polymer: 6 cP in 1.5 y WaterFlood comparison: Mobility Ratio: 250 10 Microscopic U.R.@ BT: 21% 50% Polymer Conversion 21 Ref. AER public website SPE 165234 Delamaide BTw BTp 0.3 0.2 0.1 0 0.7 0.6 0.5 0.4 0 0.5 1 1.5 MicroscopicRecovery PV Inj. Np (WaterFlood) Np (Polymer)
- 22. EXPANDING SOLVENT-SAGD INDUSTRY MOMENTUM Germain SC-SAGD 4WPs Firebag Sour naphtha Senlac SAP Butane CLSAP Chamber merged Christina Lake = CL SAP CLCondenSAP Condensate 5wt% Firebag - 2days Diluent Great Divide AlgarSAGD+ Condensate GD AlgarSAGD+ Condensate Surmont E-SAGD NGL mix; Ops.Upsets CLSAP Butane Cold Lake SA-SAGD Diluent Long Lake Long Lake SCI Pad13 2WPs Jackfish multipleWPs Cold Lake LASER - Commercial Condensate ~ 240 wells Cold Lake LASER Condensate Leismer SCIP Diluent CLSAP Butane Success / Fail / Ongoing 23 Peace River Steam Drive Pad19 diluent 0% 30% 60% Bitumen Uplift (%) SOR Improvement (%) Finished, ongoing and planned ES-SAGD field tests & LASER Nasr JCPT Jan 2003 V42 #1 Leaute JCPT Sep 2007 V46 #9
- 23. Viscosity Model to Accurately Fit Lab Data 0.1 1. 10. 100. 1,000. 10,000. 100,000. 1,000,000. 20 40 60 120 140 160 Viscosty(mPa.s) 80 100 Temperature (C) 0%wt 5%wt 10%wt 20%wt 30%wt 59%wt 100%wt AARD =11% MARD=33% Data & model on Bitumen blended with condensate A A w1w2 (A1 A2)12ideal mix mix Bmix B mix w1w2 (B1 B2 )12ideal SPE-160314 Yarrantonet.al. 24M/AARD=Max/Avg Absolute value RelativeDeviation Viscosity mixing rules based on Walther relationship
- 24. ES-SAGD RECOVERY MECHANISM Solvent Solvent condensation and evaporation mixing with remaining bitumen MOBILE BITUMEN IMMOBILE BITUMEN HOT STEAM FRONT First drop of water Temperature STEAM CHAMBER INJ. PROD. Bitumen Flux Initial reservoir Temperature Non-condensablegas Watercondensation SOLVENT HEAT FLOW Remaining oil saturation Water wet rock + bitumen Solvent evaporationGas + aqueous phase Reduced remaining oilsaturation 25
- 25. -100% -80% -60% -40% -20% 0% 20% 40% 60% 80% 100% -20% -40% -60% -80% -100% 100% 80% 60% 40% 20% 0% 0 5 10 15 20 25 Year Bitumen-SAGD Bitumen-Late Slug Bitumen-Early Slug Abandon @ OSR=0.13 Late Slug (wt%) Early Slug (wt%) Solvent R.F.-Late Slug Solvent R.F.-Early Slug ES-SAGD TIMING OF DILUENT SLUG ADDITION (10%WT) Modelling Results e t Solv en c R Bitumen Recovery cOSR (v/v) Net Solvent Efficiency (V oil / V solvent retained) R.F. Diluent (%) U.R. Bitumen (%) SAGD 0.21 79 Late Slug 0.28 6.6 93 82 Early Slug 0.33 6.1 95 83 26 Diluent Diluent Diluent overy
- 27. Reservoir Simulation Challenges Use of 9-pt scheme in Dynamic LGR (local grid refinement) Unstructured Grids to reduce orientation effects Convective dispersion as a mixing mechanism in miscible displacement Very thin solvent interfaces Diffusion dependent on (T, c); diffusive flux between phases 28 Include Maxwell’s Electromagnetic Equations in Thermal Reservoir Simulator SPE 141711 Batenburg et.al.
- 28. CONCLUSIONS Breakthrough technologies and incremental improvements to steam injection result in significant environmental footprint (CO2) reductions Steam Recovery Processes are here to stay, but with 30%-50% efficiency improvements (adding solvents or foam to the steam) Promising technologies aim at lower reservoir operating temperatures to 40-100 °C (polymer flooding; pure solvent extraction; electric heating) Some of these technologies are mature and can be selected Pure Solvent Extraction and Electrical heating are being demonstrated. Modelling the solvent processes and electric heating processes require significant enhancements to modelling technology Vast Heavy Oil resources worldwide (10,000 billion Bbls), but underdeveloped Developments are economically challenged without innovative solutions 29
- 29. Society of Petroleum Engineers Distinguished Lecturer Program www.spe.org/dl 30 Your Feedback is Important Enter your section in the DL Evaluation Contest by completing the evaluation form for this presentation Visit SPE.org/dl
- 30. QUESTIONS ? 31 Abbreviations CNRL = Canadian natural resources Ltd. CWE = cold water equivalent EM = electromagnetic heating EOR = enhanced oil recovery GHG = green house gas H.C. = hydrocarbon HO = heavy oil HPAM = Hydrolized Poly AcrylaMide NCG = non condensable gas NGL = natural gas liquids OSR = oil – steam ratio (v/v) RF = radio frequency SOR = steam – oil ratio TDS = total dissolved solids U.R. = ultimate recovery WP = well pair (in SAGD) Recovery Processes CSS = cyclic steam stimulation ES-SAGD= expanding solvent SAGD GOGD HPAI IUP LASER = gas-oil gravity drainage = high pressure air injection = in-situ upgrading process = liquid addition to steam to enhance recovery SA-SAGD= solvent aided SAGD SAGD SAP = steam assisted gravity drainage = solvent aided process SC-SAGD= solvent cyclic SAGD SCIP = solvent co-injection pilot SF = steam flooding VAPEX = vapour assisted petroleum extraction An e-list with ±100 literature references with local SPE section
- 31. ABSTRACT & BIO Abstract: Heavy Oil recovery traditionally starts with depletion drive and (natural) waterdrive with very low recoveries as a result. As EOR technique, steam injection has been matured since the 1950s using CSS (cyclic steam stimulation), steam drive or steam flooding, and SAGD (steam assisted gravity drainage). The high energy cost of heating up the oil bearing formation to steam temperature and the associated high CO2 footprint make steam based technology less attractive today and many companies in the industry have been actively trying to find alternatives or improvements. As a result there are now many more energy efficient recovery technologies that can unlock heavy oil resources compared with only a decade ago. This presentation will discuss breakthrough alternatives to steam based recovery as well as incremental improvement options to steam injection techniques. The key message is the importance to consider these techniques because steam injection is costly and has a high CO2 footprint. Bio: Johan van Dorp holds an MSc in Experimental Physics from Utrecht University and joined Shell in 1981. He has served on several international assignments, mainly in petroleum and reservoir engineering roles. He recently led the extra heavy-oil research team at the Shell Technology Centre in Calgary, focusing on improved in-situ heavy-oil recovery technologies. Van Dorp also was Shell Group Principal Technical Expert in Thermal EOR and has been involved with most thermal projects in Shell throughout the world, including in California, Oman, the Netherlands, and Canada. He retired from Shell after more than 35 years in Oct 2016. Van Dorp (co-)authored 13 SPE papers on diverse subjects. 32
- 32. LITERATURE LIST (1) 33 I. Condensing Solvents • Dunn, S.G., Nenniger, E.H., Rajan, V.S.V., “A Study of Bitumen Recovery by Gravity Drainage UsingLow • Temperature Soluble Gas Injection”, The Canadian Journal of Chemical Engineering, 67, 978-991, Dec1989. • Butler, R. M., & Mokrys, I. J. (1991, January 1). A New Process (VAPEX) For Recovering Heavy Oils Using Hot WaterAnd Hydrocarbon Vapour. Petroleum Society of Canada. doi:10.2118/91-01-09 • Butler, R. M., Mokrys, I. J., & Das, S. K. (1995, January 1). The Solvent Requirements for Vapex Recovery. Society of Petroleum Engineers. doi:10.2118/30293-MS • Das, S. K. (1998, September 1). Vapex: An Efficient Process for the Recovery of Heavy Oil and Bitumen. Society of Petroleum Engineers. doi:10.2118/50941-PA • Nenniger, J. E., & Dunn, S. G. (2008, January 1). How Fast is Solvent Based Gravity Drainage? Petroleum Society of Canada. doi:10.2118/2008-139 • Nenniger, J. E., & Gunnewiek, L. (2009, January 1). Dew Point vs Bubble Point: A MisunderstoodConstraint on Gravity Drainage Processes. Petroleum Society of Canada. doi:10.2118/2009-065 • Alkindi, A. S., Muggeridge,A. H., & Al-Wahaibi, Y. M. (2010, January 1). Experimental Investigation into the Influence of Convective Dispersion and Model Height on Oil Drainage Rates during VAPEX. Society of Petroleum Engineers. doi:10.2118/129169-MS • Alkindi,A. S., Al-Wahaibi, Y. M., & Muggeridge,A. (2008, January 1). An Experimental Investigation into the Influence of Diffusion and Dispersion on Heavy Oil Recovery by VAPEX. International Petroleum Technology Conference. doi:10.2523/IPTC-12710-MS • Alkindi, A., Al-Wahaibi, Y., & Muggeridge, A. (2011, June 1). Experimental and Numerical Investigations Into Oil-Drainage Rates During Vapor Extraction of Heavy Oils. Society of Petroleum Engineers. doi:10.2118/141053-PA • Frauenfeld, T., Jossy, C., Jossy, E., Wasylyk, B., & Meza Diaz, B. (2012, January 1). Experimental Evaluation of Dispersion and Diffusion in UTF Bitumen/n-Butane System. Society of Petroleum Engineers. doi:10.2118/157904-MS • Ghesmat, K., “In-Situ Solvent-Assisted Gravity Drainage of Bitumen: Nonlinear Numerical Analysis, SPE journalFeb 2014, 109-121 (SPE 165579)
- 33. LITERATURE LIST (2) 34 I. Electrical Heating Joule Heating • Vermeulen, F.E., Chute, F.S., “Electromagnetic Techniques in the In-Situ Recovery of Heavy Oils”, Journal of Microwave Power, 18(1), 1983. • Chute, F.S., Vermeulen, F.E., “Present and Potential Applications of Electromagnetic Heating in the In-Situ Recovery of Oil”, AOSTRA Journal of Research, 4 (1988),19-33. • Glandt, C. A., & Chia-Fu, H. (1992, January 1). Electric Preheating in Low-Injectivity Tar Sand Deposits. Society of Petroleum Engineers. doi:10.2118/24165-MS • McGee, B. C. W., Vermeulen, F. E., & Yu, L. (1999, March 1). Field Test of Electrical Heating With Horizontal And Vertical Wells. Petroleum Society of Canada.doi:10.2118/99-03-04 • Sahni,A., Kumar, M., & Knapp, R. B. (2000, January 1). Electromagnetic Heating Methods for Heavy Oil Reservoirs. Society of Petroleum Engineers. doi:10.2118/62550-MS • Vermeulen, F., & McGee, B. (2000, August 1). In-Situ Electromagnetic Heating for Hydrocarbon Recovery and Environmental Remediation. Petroleum Society of Canada.doi:10.2118/00-08-DAS • McGee, B.C.W., Vermeulen, F.E., ”Power Losses in Steel Pipe Delivering Very Large Currents”, IEEE TRANSACTIONS ON POWER DELIVERY, 17(1), p25-32, 2002 • McGee, B. C. W., & Vermeulen, F. E. (2007, January 1). The Mechanisms of Electrical Heating For the Recovery of Bitumen From Oil Sands. Petroleum Society of Canada.doi:10.2118/07-01-03 • McGee, B. C. W., McDonald, C. W., & Little, L. (2008, January 1). Electro-Thermal Dynamic Stripping Process- Integrating Environmentalism with Bitumen Production. Society of Petroleum Engineers.doi:10.2118/117470-MS • McGee, B. C. W., & Donaldson, R. D. (2009, January 1). Heat Transfer Fundamentals for Electro-thermalHeating of Oil Reservoirs. Petroleum Society of Canada. doi:10.2118/2009-204 • Arora, D. et.al., “Systems and Methods for Treating a Subsurface Formation with Electrical Conductors”, Patent CA 3 739 039 • Lashgari, H., Delshad, M., Sepehrnoori, K., & De Rouffignac, E. P. (2014, June 10). Development of Electrical Joule’’s Heating Simulation for Heavy Oil Reservoirs. Society of Petroleum Engineers. doi:10.2118/170173-MS
- 34. LITERATURE LIST (3) 35 I. Electrical Heating Induction heating • Koolman, M., Huber, N., Diehl, D., & Wacker, B. (2008, January 1). Electromagnetic Heating Method to Improve Steam Assisted Gravity Drainage. Society of Petroleum Engineers. doi:10.2118/117481-MS • Wacker, B., Karmeileopardus, D., Trautmann, B., Helget, A., & Torlak, M. (2011, January 1). Electromagnetic Heating for In- Situ Production of Heavy Oil and Bitumen Reservoirs. Society of Petroleum Engineers. doi:10.2118/148932-MS RF Heating • Bermudez, J. M., Acosta, W., Andarcia, L., Suarez, A. F., Vaca, P., Pasalic, D., & Okoniewski, M. (2014, September 24). Assisted Extra Heavy Oil Sampling by Electromagnetic Heating. Society of Petroleum Engineers. doi:10.2118/171073-MS • Ghannadi, S., Irani, M., & Chalaturnyk, R. J. (2014, June 10). Induction and Radio Frequency Heating Strategies for Steam- Assisted Gravity Drainage Start-Up Phase. Society of Petroleum Engineers. doi:10.2118/170037-MS • Despande, S.R., Wright, B.N., Watt, A., 2015. “Techniques for Installing Effective Solvent Extraction Incorporating Electromagnetic Heating (“ESEIEH”) Completions”, WHOC15-317, Edmonton, Alberta. • Wise, S., & Patterson, C. (2016, June 7). Reducing Supply Cost With EseiehTM Pronounced Easy. Society ofPetroleum Engineers. doi:10.2118/180729-MS • http://www.acceleware.com/
- 35. LITERATURE LIST (4) I. III. Enhanced Waterflood Polymer • Beliveau, D. (2009, October 1). Waterflooding Viscous Oil Reservoirs. Society of Petroleum Engineers. doi:10.2118/113132- PA • Delamaide, E., Zaitoun, A., Renard, G., Tabary, R.,” Pelican Lake Polymer Flood - First Successful Application in a High Viscosity Reservoir”, EAGE 17th European Symposium on Improved Oil Recovery, St.Petersburg, Russia, April 2013, B33. • Delamaide, E., Zaitoun,A., Renard, G., & Tabary, R. (2013, July 2). Pelican Lake Field: First SuccessfulApplication of Polymer Flooding in a Heavy Oil Reservoir. Society of Petroleum Engineers. doi:10.2118/165234-MS • Delamaide, E., Bazin, B., Rousseau, D., & Degre, G. (2014, March 31). Chemical EOR for Heavy Oil: The Canadian Experience. Society of Petroleum Engineers. doi:10.2118/169715-MS • RODRIGUEZ MANRIQUE, F., Rousseau, D., Bekri, S., Djabourov, M., & Bejarano, C. A. (2014, December 8). Polymer Flooding for Extra-Heavy Oil: New Insights on the Key Polymer Transport Properties in Porous Media. Society of Petroleum Engineers. doi:10.2118/172850-MS • http://www.snf-group.com/about-us Chemical • Fortenberry, R. P., Kim, D. H., Nizamidin, N., Adkins, S., Pinnawala Arachchilage, G. W. P., Koh, H. S., … Pope, G. A. (2013, September 30). Use of Co-Solvents to Improve Alkaline-Polymer Flooding. Society of Petroleum Engineers. doi:10.2118/166478-MS • Taghavifar, M., Fortenberry, R. P., De Rouffignac, E., Sepehrnoori, K., & Pope, G. A. (2014, June 10). Hybrid Thermal- Chemical Processes (HTCP) for Heavy-Oil and Oil-Sand Recovery. Society of Petroleum Engineers. doi:10.2118/170161- MS • Vermolen, E. C. M., Pingo Almada, M., Wassing, B. M., Ligthelm, D. J., & Masalmeh, S. K. (2014, January 19). Low-Salinity Polymer Flooding: Improving Polymer Flooding Technical Feasibility and Economics by Using Low-Salinity Make-up Brine. International Petroleum Technology Conference. doi:10.2523/IPTC-17342-MS • Aminzadeh, B., Hoang, V., Inouye, A., Izgec, O., Walker, D., Chung, D., … Dwarakanath, V. (2016, April 11). Improving Recovery of a Viscous Oil Using Optimized Emulsion Viscosity. Society of Petroleum Engineers. doi:10.2118/179698-MS 36
- 36. LITERATURE LIST (5) IIV. Steam-Solvent Viscosity • Larter, S. R.,Adams, J., Gates, I. D., Bennett, B., & Huang, H. (2006, January 1). The Origin, Prediction and Impact of Oil Viscosity Heterogeneity on the Production Characteristics of Tar Sand and Heavy Oil Reservoirs. Petroleum Society of Canada. doi:10.2118/2006-134 or /08-01-52 • Gates, I. D., Adams, J., & Larter, S. (2007, January 1). The Impact of Oil Viscosity Heterogeneity on theProduction Characteristics of Tar Sand and Heavy Oil Reservoirs. Part II: Intelligent, Geotailored Recovery Processes in Compositionally Graded Reservoirs. Petroleum Society of Canada. doi:10.2118/2007-023 or /08-09-40 • Larter, S. R., Gates, I. D., & Adams, J. J. (2008, January 1). From Steam Towards Sustainability! PossibleTransition Technologies For the Heavy Oil And Bitumen Industry. Petroleum Society of Canada.doi:10.2118/2008-133 • Huang, H., Bennett, B., Oldenburg, T., Adams, J., & Larter, S. (2006, January 1). Geological Controls on the Origin of Heavy Oil and Tar Sands and Their Impacts on In Situ Recovery. Petroleum Society of Canada. doi:10.2118/2006-045or /08-04-37 • Yarranton, H., van Dorp, J., Verlaan, M., & Lastovka, V. (2013, May 1). Wanted Dead or Live: Crude-Cocktail Viscosity--A Pseudocomponent Method to Predict the Viscosity of Dead Oils, Live Oils, and Mixtures. Society of Petroleum Engineers. doi:10.2118/160314-PA General • Ziritt, J. L., and Burger, J., "Combined Steam and Solvent Injection", 2nd International Conference on the Future of Heavy Crude and Tar Sands, UNITAR ( Feb. 7 17, 1982) Caracas, Venezuela,760-772. • Bracho, L. G., & Oquendo, O. A. (1991, January 1). Steam-Solvent Injection, Well LSJ-4057, Tia Juana Field, Western Venezuela. Society of Petroleum Engineers. doi:10.2118/21530-MS ES-SAGD • Nasr, T. N., Beaulieu, G., Golbeck, H., & Heck, G. (2003, January 1). Novel Expanding Solvent-SAGD Process “ES-SAGD.” Petroleum Society of Canada.doi:10.2118/03-01-TN • Khaledi, R. R., Beckman, M. S., Pustanyk, K., Mohan, A., Wattenbarger, C. C., Dickson, J. L., & Boone, T. T.(2012, January 1). Physical Modeling of Solvent-Assisted SAGD. Society of Petroleum Engineers.doi:10.2118/150676-MS • Dittaro, L. M., Dickson, J. L., & Boone, T. J. (2013, June 11). Integrating the Key Learnings from Laboratory, Simulation, and Field Tests to Assess the Potential for Solvent Assisted - Steam Assisted Gravity Drainage. Society of Petroleum Engineers. doi:10.2118/165485-MS • Khaledi, R., Boone, T. J., Motahhari, H. R., & Subramanian, G. (2015, June 9). Optimized Solvent for Solvent Assisted- Steam Assisted Gravity Drainage (SA-SAGD) Recovery Process. Society of Petroleum Engineers. doi:10.2118/174429-MS37
- 37. LITERATURE LIST (6) 38 IIV. Steam-Solvent (cont.) LASER • Leaute, R. P. (2002, January 1). Liquid Addition to Steam for Enhancing Recovery (LASER) of Bitumen with CSS: Evolution of Technology from Research Concept to a Field Pilot at Cold Lake. Society of Petroleum Engineers. doi:10.2118/79011-MS • Leaute, R. P., & Carey, B. S. (2005, January 1). Liquid Addition to Steam for Enhancing Recovery (LASER) of Bitumen With CSS: Results From the First Pilot Cycle. Petroleum Society of Canada. doi:10.2118/2005-161 • Leaute, R. P., & Carey, B. S. (2007, September 1). Liquid Addition to Steam for Enhancing Recovery (LASER) of Bitumen with CSS: Results from the First Pilot Cycle. Petroleum Society of Canada. doi:10.2118/07-09-01 Steam Drive • Lastovka, V., Hooijkaas, T., van Dorp, J.J., Verlaan, M., “Experimental Investigation of Solvent Addition to Vertical Steam Drive (VSD) as an Improved Method for Thermal Recovery of Extra-heavy Oil/Bitumen”, EAGE 18th EuropeanSymposium on Improved Oil Recovery, Dresden, Germany, April 2015, B15. • Castellanos-Diaz, O., Verlaan, M. L., & Hedden, R. (2016, March 21). Solvent Enhanced Steam Drive: Results from the First Field Pilot in Canada. Society of Petroleum Engineers. doi:10.2118/179815-MS • Hedden, R., Verlaan, M., & Lastovka, V. (2014, April 12). Solvent Enhanced Steam Drive. Society of Petroleum Engineers. doi:10.2118/169070-MS • Verlaan, M. L., Hedden, R., Castellanos Díaz, O., Lastovka, V., & Giraldo Sierra, C. A. (2015, October 11). Solvent Enhanced Steam Drive: Experiences from the First Field Pilot in Canada. Society of Petroleum Engineers. doi:10.2118/175414-MS
- 38. LITERATURE LIST (7) 39 V. Steam-Foam • Keijzer, P. P. M., Muijs, H. M., Janssen-van, R. R., Teeuw, D., Pino, H., Avila, J., & Rondon, L. (1986, January 1). Application of Steam Foam in the Tia Juana Field, Venezuela: Laboratory Tests and Field Results. Society ofPetroleum Engineers. doi:10.2118/14905-MS • Falls, A. H., Lawson, J. B., & Hirasaki, G. J. (1988, January 1). The Role of Noncondensable Gas in Steam Foams. Society of Petroleum Engineers. doi:10.2118/15053-PA • Muijs, H. M., Keijzer, P. P. M., & Wiersma, R. J. (1988, January 1). Surfactants for Mobility Control in High-Temperature Steam-Foam Applications. Society of Petroleum Engineers.doi:10.2118/17361-MS • Patzek, T. W., & Koinis, M. T. (1990, April 1). Kern River Steam-Foam Pilots. Society of Petroleum Engineers. doi:10.2118/17380-PA • Patzek, T. W., & Myhill, N. A. (1989, January 1). Simulation of the Bishop Steam Foam Pilot. Society of Petroleum Engineers. doi:10.2118/18786-MS • Hirasaki, G. J. (1989, May 1). The Steam-Foam Process. Society of Petroleum Engineers. doi:10.2118/19505-PA • Hirasaki, G. J. (1989, January 1). Supplement to SPE 19505, The Steam-Foam Process--Review of Steam-Foam Process Mechanisms. Society of Petroleum Engineers. • Kovscek, A. R., Patzek, T. W., & Radke, C. J. (1993, January 1). Simulation of Foam Transport in Porous Media. Society of Petroleum Engineers. doi:10.2118/26402-MS • Patzek, T. W. (1996, May 1). Field Applications of Steam Foam for Mobility Improvement and Profile Control. Society of Petroleum Engineers. doi:10.2118/29612-PA • Lau, H. C. (2012,August 1).Alkaline Steam Foam: Concepts and Experimental Results. Society of Petroleum Engineers. doi:10.2118/144968-PA • Bagheri, S. R., & Clark, H. P. (2015, October 11). Steam-Foam Technology as an Option to Improve Steam Drive Efficiency. Society of Petroleum Engineers. doi:10.2118/175278-MS
- 39. LITERATURE LIST (8) 40 VI. Fractured Carbonates • Van Wunnik, J. N. M., & Wit, K. (1992, February 1). Improvement of Gravity Drainage by Steam Injection Into aFractured Reservoir: An Analytical Evaluation. Society of Petroleum Engineers.doi:10.2118/20251-PA • Shahin, G. T., Moosa, R., Al-Kharusi, B. S., & Chilek, G. (2006, January 1). The Physics of Steam Injection in Fractured Carbonate Reservoirs: Engineering Development Options That Minimize Risk. Society of Petroleum Engineers. doi:10.2118/102186-MS • Boerrigter, P.M., van Dorp, J.J., “Advances in Understanding Thermally Assisted GOGD”, EAGE 15th European Symposium on Improved Oil Recovery, Paris, France, April 2009,A15. • Edmunds, N., Barrett, K., Solanki, S., Cimolai, M., & Wong, A. (2009, September 1). Prospects for Commercial Bitumen Recovery from the Grosmont Carbonate, Alberta. Petroleum Society of Canada. doi:10.2118/09-09-26 • Hosseininejad Mohebati, M., Yang, D., & MacDonald, J. (2014, July 1). Thermal Recovery of Bitumen From the Grosmont Carbonate Formation - Part 1: The Saleski Pilot. Society of Petroleum Engineers.doi:10.2118/171560-PA • Yang, D., Hosseininejad Mohebati, M., Brand, S., & Bennett, C. (2014, July 1). Thermal Recovery of Bitumen From the Grosmont Carbonate Formation—Part 2: Pilot Interpretation and Development Strategy. Society of Petroleum Engineers. doi:10.2118/171561-PA • Niz-Velasquez, E., Bagheri, S. R., van Dorp, J. J., Verlaan, M. L., & Jennings, J. W. (2014, July 1). Modelling Development of a Thermal Gas/Oil Gravity-Drainage Process in an Extraheavy-Oil Fractured Reservoir. Society of Petroleum Engineers.doi:10.2118/169031-PA • Roberts, B., & Hamida, T. (2014, July 1). Recovery of Bitumen From a Carbonate Reservoir by Thermal-Assisted Gravity Drainage (TAGD). Society of Petroleum Engineers. doi:10.2118/171562-PA • Yang, D., Hosseininejad, M., Stewart, D., & Brand, S. (2015, June 9). Type Curves for Cyclic Steam Operations in the Grosmont Saleski Pilot and Their Implications for Recovery Mechanisms. Society of Petroleum Engineers. doi:10.2118/174448-MS
- 40. LITERATURE LIST (9) VII. Modelling • Van Heel, A. P., Boerrigter, P. M., & van Dorp, J. J. (2008, August 1). Thermal and Hydraulic Matrix-Fracture Interaction in Dual-Permeability Simulation. Society of Petroleum Engineers. doi:10.2118/102471-PA • Liu, K., Subramanian, G., Dratler, D. I., Lebel, J.-P., & Yerian, J. A. (2009, June 1).A General Unstructured-Grid, Equation- of-State-Based, Fully Implicit Thermal Simulator for Complex Reservoir Processes. Society of Petroleum Engineers. doi:10.2118/106073-PA • Wong,A. H. W., & Edmunds, N. R. (2010, January 1). Numerical Simulation of the Solvent Drainage Process. Society of Petroleum Engineers. doi:10.2118/137721-MS • Van Batenburg, D. W., Bosch, M., Boerrigter, P. M., De Zwart, A. H., & Vink, J. C. (2011, January 1). Application of Dynamic Gridding Techniques to IOR/EOR-Processes. Society of Petroleum Engineers. doi:10.2118/141711-MS • Bogdanov, I., Torres, J., & Corre, B. (2012, January 1). Numerical Simulation of Electromagnetic Driven Heavy Oil Recovery. Society of Petroleum Engineers. doi:10.2118/154140-MS • Cuthiell, D., & Edmunds, N. (2013, May 1). Thoughts on Simulating the VAPEX Process. Society of Petroleum Engineers. doi:10.2118/158499-PA • Ghesmat, K. (2014, February 1). In-Situ, Solvent-Assisted Gravity Drainage of Bitumen: Nonlinear Numerical Analysis. Society of Petroleum Engineers. doi:10.2118/165579-PA • Pasalic, D., Vaca., P., Okoniewski, M., “Modelling EM Assisted Oil Recovery”, International Conference on Electromagnetics in Advanced Applications (ICEAA),Aug 2014. VIII. Solar Steam • Van Heel, A. P., Van Wunnik, J. N. M., Bentouati, S., & Terres, R. (2010, January 1). The Impact Of Daily And Seasonal Cycles In Solar-Generated Steam On Oil Recovery. Society of Petroleum Engineers. doi:10.2118/129225-MS • Palmer, D., & O’Donnell, J. (2014, March 31). Construction, Operations and Performance of the First Enclosed Trough Solar Steam Generation Pilot for EOR Applications. Society of Petroleum Engineers.doi:10.2118/169745-MS • Chaar, M., Venetos, M., Dargin, J., & Palmer, D. (2015, December 1). Economics Of Steam Generation For Thermal Enhanced Oil Recovery. Society of Petroleum Engineers. doi:10.2118/172004-PA • Testa, D., L. Carnelli, L., Corso, G., Lazzari, C., De Simoni, M., Sassi, G., Tegami, A., “Concentrating Solar Power Applied to EOR: High Temperature Fluid Circulation for Enhancing the Recovery of Heavy Oil”, 12th Offshore Mediterranean Conference and Exhibition in Ravenna, Italy, March 25-27, 2015. 41
- 41. LITERATURE LIST (10) 42 IX. Miscellaneous • Belgrave, J. D. M., Nzekwu, B. I., & Chhina, H. S. (2007, January 1). SAGD Optimization With Air Injection. Societyof Petroleum Engineers. doi:10.2118/106901-MS • Freeman, L.W., Nzekwu, B.I., Belgrave, J.D.M., “A Breath of Fresh Air – EnCana’s Gas Displacement Solution to theGas Over Bitumen Issue”, World Heavy Oil Congress Edmonton, March 2008, WHOC08-497 • Boone, T.J., Sampath, K., Courtnage, D.E., “Assessment of GHG emissions associated with in-situ heavy oil recovery processes”, World Heavy Oil Congress, Aberdeen, Schotland, 2012,WHOC12-412 • Boone, T. T., Wattenbarger, C. C., Clingman, S., & Dickson, J. L. (2011, January 1). An Integrated Technology Development Plan for Solvent-based Recovery of Heavy Oil. Society of Petroleum Engineers. doi:10.2118/150706-MS • Smith, R. J., Meier, S. W., Adair, N. L., Kushnick, A. P., Leonardi, S. A., Herbolzheimer, E., … Wang, J. (2013,June 11). Slurrified Heavy Oil Reservoir Extraction (SHORE): A non-thermal, recovery method. Society of Petroleum Engineers. doi:10.2118/165498-MS • Boone, T. J., Dickson, J. L., Lu, P., & Elliott, J. (2014, December 10). Development of Solvent and Steam-Solvent Heavy Oil Recovery Processes Through an Integrated Program of Simulation, Laboratory Testing and Field Trials. International Petroleum Technology Conference. doi:10.2523/IPTC-18214-MS • Judzis, A., & Poddar, A. (2012, September 1). R&D Grand Challenges - Reviewing the Five R&D Grand ChallengesPlus One. Society of Petroleum Engineers. doi:10.2118/0912-0069-JPT • Karanikas, J. M. (2012, May 1). Unconventional Resources: Cracking the Hydrocarbon Molecules In Situ. Society of Petroleum Engineers. doi:10.2118/0512-0068-JPT • Judzis, A., Felder, R., Curry, D., Seiller, B., Pope, G. A., Burnett, D., … Poddar,A. (2011, January 1). R&D Grand Challenges - JPT Article Series. Society of Petroleum Engineers.doi:10.2118/163061-MS