MRCSP- Michigan Basin Geologic CO 2 Sequestration Field Test

Transcription

1 MRCSP- Michigan Basin Geologic CO 2 Sequestration Field Test EPA Region 5 Regional Carbon Sequestration Meeting March 21-22, 2007, Pokagon State Park, Indiana Michigan Basin- Otsego County Test Site Project Team Abed Houssari and Becky Cook Dave Barnes and Bill Harrison Dave Ball, Neeraj Gupta, Phil Jagucki, Joel Sminchak, Danielle Meggyesy, Judith Bradbury, Bob Janosy, Jackie Gerst, Diana Bacon Charlie Byrer Robert Mannes and Joe Herpst Additional Contributions by Numerous Other MRCSP Team Members 1

2 Presentation Objectives Site Description Background Geological Assessment Test Well Drilling Site characterization results Permitting Injection, MMV Plans Site Description- Otsego County Test Site The location is at Core Energy gas fields in the vicinity of a DTE gas processing plant outside of Gaylord, Michigan 2

3 Michigan Basin- Otsego County Test Site Charlton 30/31 field, S. Dover/N. Chester Township, Otsego County, Michigan Site Diagram 3

4 CO 2 Source CO 2 available from DTE Turtle Lake gas processing plant Antrim Shale gas contains 5-30% CO 2 and is removed in amine based separation process Relatively pure CO 2 (99%) stream CO 2 dried and compressed at Core Energy Chester 10 facility CO 2 periodically used for EOR floods in Niagaran Reef oil fields Michigan Basin- Otsego County Test Site Antrim gas fields, currently 10th most prolific gas play in continental U.S. 8-mile long CO2 pipeline in place for EOR 4

5 Maps of Target Formations Michigan Basin- Otsego County Test Site 5

6 Test Well Drilling Test well drilled October 30 November 22 Wireline Logging Elemental Capture Spectroscopy Platform Express LithoDensity/Caliper Compensated Neutron/GR Dipole Sonic Imager Compressional/Shear Stonely/Cross-Dipole Resistivity Log Array laterolog Formation Microimager Dual Caliper DRAFT 6

7 Core Tests 180 ft of full 3-inch core 25 rotary sidewall core plugs. Core Tests 3000 Permeability (md) Porosity (md) Amherstburg Depth (ft) DRAFT Bois Blanc Depth (ft) Bass Islands Dolomite 3500 Bass Islands Evaporite E Permeability (md) Porosity 7

8 Core Examination- Injection Target Interpretation Injection Target = Upper Bass Islands Dolomite Total Storage Interval = Upper Bass Islands-Bois Blanc Confining Layer = Amherstburg 8

9 Geology Prognosis Sedimentary rocks ~9,500 ft deep and overlie Precambrian bedrock. Primary targets Bass Islands Dolomite-Bois Blanc. Containment layers: Amherstburg-Lucas formations Michigan Basin- Otsego County Test Site 9

10 Permitting Track State-Charlton 4-30 well drilled on Oil and Gas Well permit with Michigan DEQ. Class V UIC injection permit being prepared for Region 5 EPA Permitting- Area of Review 10

11 USDWs Glacial drift is deepest USDW Glacial drift 665 deep in State-Charlton 4-30 well. No water wells within ¼-mile. Wells in are generally less than 250 ft deep. Brine geochemistry of Paleozoic rocks in MI show TDS>100,000 mg/l. Major organic shale gas play between sequestration target and USDS. Injection System Design CO 2 injection testing and monitoring- The overall plan for the Otsego County site is to inject a volume of 3,000 to 10,000 tons of CO 2 generated from nearby Antrim gas processing plant. If the larger volume is injected (10,000 tons) we hope to evaluate monitoring of the injected CO 2 with 4-D seismic and/or cross-well seismic. We are in the process of retrofitting a closed well at the site for monitoring. This site may offer the opportunity to optimize CO 2 injection operations. 11

12 Injection Fluid 99.91% CO 2 Trace CH4, C2, C3 Supercritical DRAFT Preliminary Well Design Bridge plug in Bass Is. Evap. Perforated Nickle-plated packer. 2 7/8-inch injection tubing. Dense brine interannulus fluid. Charlton 30/31 Field State Charlton #4-30 Permit No Otsego County S30 T31N R1W Injection Test Configuration 16" Driven - 72 Ft. 11 3/4" 47# - 804Ft Sx to Surf. 2 7/8" J-55 Seamless Tbg Retreivable Packer (Nickel Plated) 10 Sx Sand ± 3450 Ft. 5 1/2" Liner ± 3538 Ft. 5 1/2" 3600 Ft. 8 5/8" 32# Seamless J ' Sx DRAFT 5-1/2" 2250' 15.5# Seamless J Sx Perfs 5482' ' 7 7/8" hole TD 5800' 12

13 Plugging and Abandonment Plan Squeeze job across injection interval. Recomplete for EOR in Niagaran reef. Charlton 30/31 Field State Charlton #4-30 Permit No Otsego County S30 T31N R1W Wellbore After Plugging Cut & cap 8 5/8" and 11 3/4" w/1/2" steel plate 16" Driven - 72 Ft. 20 sx 100 sx cmt plug 11 3/4" 47# - 804Ft Sx to Surf. 176' fillup 8 5/8" cement retainer w/100 sx cmt below and 50 sx cement on top DRAFT 5 1/2" Liner ± 3538 Ft. 8 5/8" 32# Seamless J ' /2" 2250' 15.5# Seamless J Sx 5 1/2:" cement retainer w/50 sx cmt below and 50 sx on top Perfs 5462'-5486' 7 7/8" hole TD 5800' MMV Monitoring options were reviewed and a subset of options was selected based on the proposed injection system specifications and geologic setting. Complete monitoring plan and schedule will be determined after site characterization efforts are finished. Site has potential for seismic monitoring (X-well or 3D seismic) Michigan Basin Time (Months) Phase Pre-demo Active Injection Post-Injection Injection System (PVT) X X X X Health and Safety (O 2) X X X X Wireline (CMR, Nuetron/RST, PEX) X X X X X-well Sesimic (3-4 Mon. Wells) X X Reservoir Sampling (MDT) X X Well Indicator sensors (PT) X X X X X X X X 4-D Seismic (with WMU program) X X DRAFT 13

14 Time (Days) Ca Na K MMV Pressure (PSI) System Monitoring Temperature (*F) Michigan Basin Otsego County Site Gas Processing Plant Injection Test Well Antrim Gas Well Depth (ft bgs) 0 CO 2 Pipeline Niagara EOR Wells Surface CO 2 Survey 1,000 Brine Chemistry 2,000 Cross-well or 3D Seismic Monitoring Well 3,000 4,000 5,000 6,000 DRAFT Target Storage Formation Wireline 7,000 8,000 9,000 10,000 STOMPCO2 Reservoir Simulations Parameter Saturated Intrinsic Permeability Porosity Formation Thickness Rock Type Injection Rate Simulation Time Depth to bottom of formation Hydrostatic Gradient Salt Mass Fraction Temperature Coordinate System Radial Grid spacing Vertical Grid Spacing Upper and Lower Boundary Conditions Boundary Condition at R Boundary Condition at R Value 100 md 15% 100, 200, 300, 400 ft Homogeneous, isotropic Sandstone 200 metric tons/day for 2 months 1 year 3600 ft psi/ft ºF 2 dimensional cylindrical 67 nodes 100 to 400 nodes no flow ft Comments Based on mini-permeameter scan of upper Bass Islands Based on wireline logs through upper Bass Islands Total of 4 runs Total injection of 12,000 metric tons CO2 (more than planned to include safety factor) Assumes 100,000 ppm Based on geothermal gradient Radial model variable from 0.26 ft to 206 ft uniform 1 ft spacing Axis of Symmetry Hydrostatic Gradient = psi/ft 14

15 STOMPCO2 Reservoir Simulations Preliminary STOMPCO2 Reservoir Simulation Results for gas saturation, aqueous Co2, and gas pressure at times steps of 30 days, 60 days, and 365 days. Gas Saturation Aqueous CO2 30 d 60 d 365 d STOMPCO2 Reservoir Simulations Stochastic Simulations Multiple Injectors Carbonate Reservoirs Water, CO2, Salt 15

16 Timeline and Next Steps for the Michigan Basin Otsego County Test Site Permitting (in progress) Complete Monitoring Well (in progress) Injection testing and monitoring (Summer 2007) Post injection and closure 16