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3.0 PROCESS DESCRIPTION & DISCUSSIONS. CO 2 Capture Study For 800 MW Power Plant – Tjeldbergodden This section provides the process basis for the CO 2 capture facilities and discusses under separate headings the various Power plant interface considerations and design basis assumptions used to establish the CO 2 plant base case design. 3.1 CO 2 Capture – Process Description The following is a process description for the proposed Econamine FG Plus SM (EFG+) plant that will be located at Statoil’s site in Tjeldbergodden, Norway. The plant is designed for a carbon dioxide production capacity of 6,170 Te/d. The product carbon dioxide is compressed and sent to the battery limits of the plant for Enhanced Oil Recovery (EOR). The non-confidential process configuration for the EFG+ plant and carbon dioxide compression is shown in Process Flow Diagrams PFD-001 and PFD-002. The EFG+ plant battery limit for the flue gas feed is at the stacks of the Heat Recovery Steam Generators (HRSG). All of the flue gas from the two HRSGs is diverted from the stacks and is routed to the EFG+ plant thus resulting in a zero flow of gas through the stacks to the atmosphere. The tie-in points are at the two stacks where the flue gas is routed to a common header. The flue gas is then divided equally and routed through three ducts to the EFG+ plants in parallel. The following is a description of Train A for absorption, which is identical to Trains B and C. The stripper and CO 2 compression is one train common to the three absorption trains. The flue gas, at 80°C, enters the Direct Contact Cooler (DCC) (C-100) where the gas is cooled to 30°C by a circulating water stream and any particulates present in the flue gas are removed by scrubbing. The flue gas and the circulating water are contacted over packing. By lowering the gas temperature, much of the water vapor contained in the flue gas is condensed and separated from the feed gas before entering the Absorber (C-101). The circulating water enters the DCC at 25°C and is heated to 42°C by the cooling and condensing of water vapor in the flue gas. The circulating water from the DCC is routed through the DCC Water Cooler (E-100) by the DCC Circulating Water Pump (P-100A/B) and returned to the DCC. Cooling water at 18°C is used to cool the circulating water to 25°C. All cooling water used in the EFG+ plant is sea water from the cooling system in the power plant. A slip stream is diverted from the circulating water upstream of the pump and routed by the DCC Filter Pump (P-101A/B) through the DCC Circulating Water Filter (F-100) to continuously remove particulate matter. A portion of the filtered water is returned to the liquid surge volume in the bottom of the DCC. Excess water, produced in the DCC from the condensing of water vapor in the flue gas, is routed to the battery limits after filtration. The flow rate of this excess water is controlled by a flow controller with a reset by a level controller in the DCC. The cooled, overhead gas from the DCC is routed to Blower (BL-100) to overcome the pressure drop in the system. The flow rate of the feed gas to the Blower is maintained by controlling the inlet guide vanes of the blower. CB2005-0022_Final Report.Doc
CO 2 Capture Study For 800 MW Power Plant – Tjeldbergodden The treated flue gas is routed to the Absorber (C-101). The gas flows upwards counter current to the circulating MEA solvent. The MEA solvent reacts chemically with carbon dioxide, absorbing 80-90% of the carbon dioxide in the incoming flue gas. Residue gas, mainly nitrogen and oxygen , is vented after the wash section through the top of the absorber. The rich MEA solvent from all three trains is pumped from the bottom of the Absorber to the top of the Stripper (C-102) by the Rich Solvent Pump (P-103A/B). It is preheated in Solvent Cross Exchanger (E-103A-L) before entering the top of the stripping tower. In the Stripper, the rich MEA solvent is further heated in the Reboiler (E-104A/B/C/D) by means of low pressure steam, releasing the carbon dioxide. From the reboiler, the lean MEA solvent is pumped by the Lean Solvent Pump (P- 104A/B/C), cooled against rich solvent in the Solvent Cross Exchanger (E-103A-L) and further cooled in the Lean Solvent Cooler (E-106A/B/C). A part of the lean MEA solvent is routed through the Lean Solvent Filter (F-102) in order to remove solution contaminants. The filtered solvent returns to the main lean solvent line. The combined solvent is then divided equally and routed to the three absorption trains. Water in the overhead gas from the Stripper is condensed in Condenser (E- 105A/B) and separated from the carbon dioxide product in the Overhead Accumulator (V-100). A portion of the condensed water is returned to the Stripper with the balance being equally distributed to each of the Absorbers. The carbon dioxide product is then sent to the battery limit. To maintain the highest possible absorption capacity of the MEA solvent, contaminants, such as heat stable salts, are removed in the Reclaimer (E-107). The Reclaimer is operated as a semi-batch process. Heat stable salts are removed using a thermal process utilizing both LP and MP steam. The carbon dioxide product from the Overhead Accumulator is compressed in the Product CO 2 Compressor (K-100) to the required 103 kg/cm 2 (a) pressure. The compressor consists of five stages with intercooling provided. Each stage of compression is followed by an air cooler (E-108, 110, 112 and 114) and trim coolers (E-109, 111, 113 and 115) where the carbon dioxide product is cooled to 25°C against cooling water. After each stage of cooling, the carbon dioxide is routed to knock-out drums (V-103, 104, 105 and 106) to remove condensate. At an interstage pressure of 39.5 kg/cm 2 (a), the compressed carbon dioxide is sent to a Dehydration Package (ME-100), which reduces the moisture level down to less than 50 ppm (weight basis). 3.2 Cooling Water Supplies To achieve a temperature rise of 10°C, the basic power plant requires a cooling water flow of 41500 tons per hour. After the carbon capture plant is added the steam flow to the power plant condenser is greatly diminished however the flow through the condenser is unchanged so that the temperature rise now becomes 5.28°C. The Carbon Dioxide capture plant has been specified to use outlet sea water from the power plant condenser as it does not have to reach such a low temperature to CB2005-0022_Final Report.Doc
Page 1 and 2: April 2005 Study and Estimate for C
Page 3 and 4: CO 2 Capture Study For 800 MW Power
Page 7: CO 2 Capture Study For 800 MW Power
Page 11 and 12: C.W. Users at Carbon Capture Plant
Page 19 and 20: 4.0 KEY DELIVERABLES - PFD’S, UFD
Page 33 and 34: Econamine FG Plus SM Preliminary Eq
Page 50 and 51: THE INFORMATION ON THIS DRAWING DEP
Page 52 and 53: THE INFORMATION ON THIS DRAWING DEP

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