1. “The CS technology offers a possibility of flow diversion and modification in SAGD through pressure maintenance. As such the concept is sound. We have reviewed the patent application and we consider it feasible for mature fields where enough data can be obtained for accurate history matching and confident forecasting of the potential flow profile alteration” Dr. Apostolos Kantzas, University of Calgary June 2012 *Mainly Canada, Venezuela, Russia, Kazakhstan, United States CS EOR - Enhanced Oil Recovery Technology With the advent of these inventions it will become incumbent on the operators* that produce these very finite resources to implement these technologies as soon as possible so that the oil that was previously left as unrecoverable is now produced.

2. New Patent Pending* Technology provides for substantial production increases from your standard SAGD operations Update from Patent Office We have received an Office Action and Written Opinion The Examiner finds the claims “novel, inventive and industrially applicable.” Don’t spend all of your development funds on industry standard SAGD operations when CS Pressure Assisted Recovery can dramatically and economically improve your production rates and your per well revenues. * United States, Venezuela, PCT applications filed CS EOR - Enhanced Oil Recovery Technology

3. Background Crude Solutions (CS) has been developing oil field related technologies since 1996 Jason Swist, owner of Crude Solutions and inventor of the EOR technology and holder of the patents, has been involved in the oil industry for 16 years Jason has studied the causes of one of the major issues for all SAGD operation - incomplete sweeping of the target zones – Present approaches don’t sweep the entire production zones leaving vast quantities of producable oil in the ground – CMG STARS third party simulations of standard SAGD operations utilizing the CS EOR technologies show substantial increases in overall well production and complete sweeping of the production zones CS EOR increases total well production which also positively impacts your proven and probable reserves – CS EOR benefits your operations with increased production and increased bookable reserves CS EOR … Getting you your money’s worth!

4. Traditional Operations SAGD mainly deploys a well pair lower in the formation. This well pair is drilled horizontally, parallel and vertically aligned with each other. One of the well is called injection well and other is placed right underneath called production well at a distance of 5m. Bitumen at reservoir conditions is immobile due to very high viscosities in the order of 1,000,000 cp. SAGD utilizes steam to give away its heat to the bitumen and thus increasing the temperature of reservoir and lowering bitumen viscosity thereby making it mobile.

5. Third Party Conclusions respecting CS EOR Technology “ITS quite obvious from the previous cases vs. standard operations that pressure was playing an important role in the start up of injector three and once the oil is heated enough and ready to be mobilized, it is drawn towards the producers by the higher pressure of injector three. Moreover, higher steam pressure from injector three overwhelms the exterior injectors and stops their injectivity by increasing the pressure in the surrounding grid blocks, which can be clearly seen in the plots and snap shots deduced from the simulation runs.” Dr. Ergun Kuru, University of Alberta Study, February 2012 More data, including the University study and independent analysis, as well as reservoir characteristics used for all simulations, available online at www.crudesolutions.com

6. Traditional Operations Traditional producer plots show consistent production over 10 years with peak of approximately 80 cubes a day Standard SAGD CMG 10 Year Field Production Plot 75 Meter Separation at 1 Darcy

7. Traditional Operations Field SOR for standard operation shows declining rate as oil rate increases Standard SAGD CMG 10 Year Field SOR Plot 75 Meter Separation

8. CS EOR vs. Traditional Operations CS EOR operations for iteration #1 show quick uptake followed by steady rise until sustained production increases at 2300 days with peak of approximately 275 cubes a day CS EOR SAGD CMG 10 Year Production Simulation Iteration #1 compared to base 75 meter well pair at 1 Darcy

9. CS EOR vs. Traditional Operations CS EOR field SOR rates for iteration #1 compare favorably to standard operations, Easy to see when injector should be switched to production CS EOR SAGD CMG 10 Year Field SOR Simulation Iteration #1

10. CS EOR vs. Traditional Operations CS EOR operations for iteration #2 show slower uptake followed by steady rise until sustained production increases at 2000 days with peak of approximately 250 cubes a day CS EOR SAGD CMG 10 Year Production Simulation Iteration #2 compared to base 75 meter well pair at 1 Darcy

11. CS EOR vs. Traditional Operations CS EOR field SOR rates for iteration #2 compare favorably to standard operations until 2750 days when injector should be switched to production CS EOR SAGD CMG 10 Year Field SOR Simulation Iteration #2

12. CS EOR vs. Traditional Operations CS EOR operations for iteration #3 show slower uptake followed by steady rise until sustained production increases at 2500 days with peak of approximately 260 cubes a day CS EOR SAGD CMG 10 Year Production Simulation Iteration #3 compared to base 75 meter well pair at 1 Darcy

13. CS EOR vs. Traditional Operations CS EOR field SOR rates for iteration #3 compare favorably to standard operations with small uptick at 3200 days indicates when injector should be switched to production CS EOR SAGD CMG 10 Year Field SOR Simulation Iteration #3

14. CS EOR vs. Traditional Operations CS EOR operations for iteration #4 show early uptake followed by steady rise until sustained production increases at 2400 days, with peak of approximately 550 cubes a day CS EOR SAGD CMG 10 Year Production Simulation Iteration #4 compared to base 75 meter well pair at 1 Darcy

15. CS EOR vs. Traditional Operations CS EOR field SOR rates for iteration #4 compare favorably to standard operations with rise at 2500 days when SOR spikes as injectivity precipitates large production increase CS EOR SAGD CMG 10 Year Field SOR Simulation Iteration #4

16. CS EOR vs. Traditional Operations CS EOR technology at 4 Darcy shows quicker merging of steam chambers and large production spikes as heat and pressure create fluid drive also easy to see when injector should be switched to production CS EOR SAGD CMG 10 Year simulation Iterations #1,2,3, at 4 Darcy

17. Benefits to the SAGD Operator that Uses CS EOR Technology Increased production – increased revenue Increased production capabilities – increased bookable reserves Increased well production life – extended revenue base Economical solution to existing production issues using existing drilling and completion methods Patent/technology licensing ensures an even playing field for the industry A better bottom line for you – A better investment for your shareholders

18. Contact Information Jason Swist Crude Solutions LTD. 503 Lougheed Court, Edmonton AB T6R 2T3 T: 780 993 8540 9725 East Navajo Place, Sun Lakes AZ 85248 T: 602 574 6045 Email: jason@crudesolutions.ca Legal Adrian O'Donnell Intellectual Property Department Perley-Robertson, Hill & McDougall LLP/s.r.l. 1400 - 340 rue Albert Street Ottawa, ON, K1R 0A5 T: 613 238 2022 Ext 858 or 613 566 2858 F: 613 238 8775 Email: aodonnell@perlaw.ca