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.
“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
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
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!
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.
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
Traditional Operations
Standard SAGD CMG 10 Year Field Production Plot 75 Meter Separation
at 1 Darcy
Traditional producer plots show consistent production
over 10 years with peak of approximately 80 cubes a day
Traditional Operations
Standard SAGD CMG 10 Year Field SOR Plot 75 Meter Separation
Field SOR for standard operation shows declining rate as oil rate increases
CS EOR vs. Traditional Operations
CS EOR SAGD CMG 10 Year Production Simulation Iteration #1
compared to base 75 meter well pair at 1 Darcy
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 vs. Traditional Operations
CS EOR SAGD CMG 10 Year Field SOR Simulation Iteration #1
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 vs. Traditional Operations
CS EOR SAGD CMG 10 Year Production Simulation Iteration #2
compared to base 75 meter well pair at 1 Darcy
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 vs. Traditional Operations
CS EOR SAGD CMG 10 Year Field SOR Simulation Iteration #2
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 vs. Traditional Operations
CS EOR SAGD CMG 10 Year Production Simulation Iteration #3
compared to base 75 meter well pair at 1 Darcy
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 vs. Traditional Operations
CS EOR SAGD CMG 10 Year Field SOR Simulation Iteration #3
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 vs. Traditional Operations
CS EOR SAGD CMG 10 Year Production Simulation Iteration #4
compared to base 75 meter well pair at 1 Darcy
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 vs. Traditional Operations
CS EOR SAGD CMG 10 Year Field SOR Simulation Iteration #4
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 vs. Traditional Operations
CS EOR SAGD CMG 10 Year simulation Iterations #1,2,3, at 4 Darcy
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
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
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: [email protected]
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: [email protected]