1. Canada Chemical Corporation 24, 4807-32 Street S.E. Calgary, Alberta, Canada T2B 2X3 canchem@telusplanet.net (403) 560-7483, Conrad Ayasse, Ph.D., FCIC, President NOVEL H 2 S RECOVERY PROCESSES

2. US 8,703,084 Removal of sulfur compounds from a gas stream This process uses water and an oxygen-containing gas to simultaneously hydrolyze COS and CS 2 to H 2 S and convert H 2 S to elemental sulfur by "direct oxidation" with low energy consumption. The hydrolysis protects amine H 2 S absorbers from damage by COS and SO 2. H 2 S recovery is >95%. US 8,501,135 Process for the removal of sulfur from a gas stream Complete removal of sulfur compounds from a gas stream is achieved by a direct oxidation process with re-cycling to virtual sulfur species extinction. Because of its low energy requirements and zero sulphur gas emissions, this process could replace Amine/Claus plants for treating sour natural gas.

3. Field Skid Test of Catalytic Direct Oxidation of H 2 S with Air Pass the gas stream and air over a catalyst at 220 ºc. to get sulphur and water. The field test skid was operated sporatically for 6-months on the THAI- produced combustion gas (4000 ppm H 2 S) from a heavy oil reservoir. The gas was already saturated with water- so none was added. Our catalyst in the field achieved 95+ % H 2 S conversion for several weeks before terminating the test. H 2 S + O 2 (air) = S + H 2 O

4. How it works: Complete removal of sulfur compounds from a gas stream is achieved by solid-state absorption. After complete saturation of the absorbent in a first Absorber, the H 2 S is stripped to a DO Reactor and hot un-reacted gas is recycled to further strip the absorbent. This is continued until the H 2 S gets to the desired low level. Then a second Absorber is connected to the DO Reactor and the process is repeated for it while the first Absorber converts to the absorption mode. Because of its low energy requirements, low operating costs and zero emissions, this process and modifications could replace all traditional H 2 S processes requiring over 150 lb/d for treating sour gas, including amine/Claus plants.

5. Feed gas air Gas Chromatograph SS Heater Guard bed D.O. Reactor Sulfur traps or pits Re-cycle compressor Mass flow controller Flow controller Sulfa-Nil tm Natural Gas Sweetener Plant Solid-state H 2 S Absorber 1 (Saturated 130 C) Solid-state H 2 S Absorber 2 (Fresh, 50 C) Clean gas Plant Operation: Absorber 2 is on the absorption cycle and Absorber 1 is being stripped of H 2 S to the Direct Oxidation Reactor, where elemental sulphur is formed and sent to traps. Hot gas generated by the D.O. reaction is sent back through the Absorber 1, to provide more H2S stripping. At intervals, the Absorbers are switched and Absorber 2 starts it’s stripping cycle. Prior to switching absorbers, some raw gas is swept through Absorber 1 to cool it and remove inter-particle H2S to Absorber 2. Throughout the Process, the “Clean Gas” contains no sulphur species Red indicates the absorber stripping loop Heater

6. Sulfa-Nil tm CTG(Claus Tail Gas, Process upgrades existing Claus Plants) This sulfur removal process eliminates all sulfur emissions from Claus sulfur plants. Claus tail gas is subjected to a unique form of Direct Oxidation that provides complete sulfur removal. Sulfa-Nil tm WG(Waste Gas processing) This sulfur removal process treats sulfur-contaminated waste gas or combustion gas to meet emission standards. 95+% sulfur recovery. Applications: THAI or other waste combustion gases, or SAGD gas. Sulfa-Nil tm C(A Direct Oxidation Plant that replaces the traditional Amine/Claus technology) This sulfur removal process fills the natural gas sulfur removal size gap from less than 1 tonne/d to over 20 tonnes/d sulfur, achieving zero sulfur emissions. This process eliminates the need for amine scrubbers and provides emission-free sulfur removal from natural gas. CCC Proprietary Sulfur Removal Processes