Central Appalachian Basin (SECARB)

Transcription

1 Central Appalachian Basin (SECARB) Presented to: Coal-Seq VI April 10, 2008 Nino Ripepi and Michael Karmis Virginia Tech Michael J. Miller and J. Matthew Conrad Marshall Miller and Associates

2 Acknowledgement This material is based upon work supported by the Department of Energy National Energy Technology Laboratory under DE FC26 04NT42590 This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference herein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or imply its endorsement, recommendation, or favoring by the United States Government or any agency thereof. The views and opinions of authors expressed herein do not necessarily state or reflect those of the United States Government or any agency thereof.

3 SECARB Coal Group Team Southern States Energy Board Virginia Center for Coal and Energy Research Virginia Tech Marshall Miller and Associates, Inc. Geological Survey of Alabama University of Alabama Southern Company Kentucky Geological Survey Advanced Resources International Eastern Coal Council

4 SECARB Coal Projects Contributing Partners Alawest Alpha Natural Resources AMVEST Buckhorn Coal CCP2 Project CDX Gas CNX Gas CONSOL Energy Cumberland Resources Corporation Dart Oil & Gas Denbury Resources Dominion E&P Dominion Resources Eastman Chemical EPRI Equitable Production Institute for Clean Energy Technology (MSU) International Coal Group GeoMet McJunkin Appalachian Norfolk Southern Natural Resource Partners Oak Ridge National Laboratory Penn Virginia Pine Mountain Oil & Gas Piney Land Pocahontas Land RMB Earth Science Consultants Univ. British Columbia

5 SECARB Coal Projects CO 2 ECBM recovery: - Unmineable coals can provide sequestration and add economic value - At least 1,000 MMT CO 2 of feasible capacity in the targeted areas Two Field Validation Sites: - Central Appalachian Basin, G 2-A - Black Warrior Basin, G 2-B - Inject 1,000 tons of CO 2 at each site G 2-A G 2-B

6 SECARB Coal Group Phase II Project Tasks Regional Characterization and Site Selection Reservoir Modeling Core Hole Drilling and Evaluation Pilot Preparation and Risk Analysis Pilot Project Operations Interpretation and Assessment Public Outreach Technology Transfer

7 Central Appalachian Field Test Progress Overview Finalized Sequestration and ECBM Assessment for Central Appalachian Basin Developed a suite of geologic maps for sequestration and ECBM analysis Selected a donated CNX Gas well for field test Finalized indemnification and operating agreements with CNX Gas and Buckhorn Coal Company Conducted required safety training from CNX Gas Completed and submitted NEPA Questionnaire Working with EPA and Virginia Department of Mines, Minerals and Energy on permitting requirements UIC Permit Application Corehole Permitting

8 Study Area CBM Fields Horizontal CBM CBM FIELDS Vertical CBM Lincoln Wayne Johnson Mingo Martin Logan WV Magoffin Floyd Pike Fayette Boone KY Slab Fork Field Loup Creek Raleigh Field Summers Wyoming McDowell Welch Field Mercer Knott VA Oakwood Buchanan Field Dickenson Letcher Nora Wise Field Bradshaw Field Giles Bland Tazewell Pulaski Harlan Buck Knob Field Russell CBM Target Area Wythe Smyth Lee Scott Carroll Washington Grayson 0 Scale in Miles

9 Norton Formation Lee Formation Pocahontas Formation Kennedy Aily Raven Jawbone Tiller Upper Seaboard Greasy Creek Middle Seaboard Lower Seaboard Upper Horsepen Middle Horsepen War Creek Lower Horsepen Pocahontas No. 9 Pocahontas No. 8 Pocahontas No. 7 Pocahontas No. 6 Pocahontas No. 5 Pocahontas No. 4 Pocahontas No. 3 Pocahontas No. 2 Pocahontas No. 1 Central Appalachian Basin Generalized Stratigraphic Column Prospective Coalbeds For Carbon Sequestration

10 Evaluation Criteria Carbon Sequestration and ECBM Potential Thickness, rank and gas content of coals developed for CBM production Areas where CBM production has been established (higher expected carbon dioxide injectivity and existing infrastructure) Excludes deep mine areas (potential leakage of injected carbon dioxide because of subsidence)

11 Evaluated Sequestration Area

12 Sequestration Potential Phase II Study Areas Storage capacity in all non-mining areas Storage only in developed CBM areas 23.1 Tcf (1,341 MMt) 6.86 Tcf (398 MMt) West Virginia portion of study area has 8.88 Tcf total storage capacity and 1.49 Tcf storage capacity in CBM development areas.

13 Enhanced CBM Potential Phase II Study Areas ECBM potential in all non-mining areas ECBM only in developed CBM areas 2.49 Tcf 0.79 Tcf West Virginia portion of study area has 0.80 Tcf total ECBM potential and 0.14 Tcf ECBM potential in CBM development areas.

14 The Russell County, VA Field Test

15 CNX Gas Field Test Location

16 Virginia Pilot Test Site

17 Offset CBM Wells

18 DEPTH GR DENSITY ** * * LEE FORMATION POCAHONTAS FORMATION LEE FORMATION INJECTION TEST NET COAL: 8.2 FEET Proposed Injection Zones Well BD * LEGEND COAL SANDSTONE SHALE INJECTION ZONE PERFORATED ZONE * * * POCAHONTAS FORMATION INJECTION TEST NET COAL: 6.4 FEET

19 Injection Well Production History 1, Gas Production Water Production 1 Mar-02 Sep-02 Mar-03 Sep-03 Mar-04 Sep-04 Mar-05 Sep-05 Mar-06 Sep-06 Mar-07 Sep-07 Month 0.1 Gas Production, Mcfd Water Production, bbls/d

20 Pilot Area Gas Composition Well No. Methane (%) Nitrogen (%) CO 2 (%) Oxygen (%) Ethane (%) Propane (%) Btu Content BC BC BD BD BE BE BD BE Average

21 Model 3D View: Thickness ICBM SP052107

22 History Match Results Gas Rate (Mscfd), Water Rate (Bbld) Days Gas Actual Water Actual Gas Sim Water Sim ICBM SP052107

23 Injection Test Plume Model Growth of the CO 2 plume was modeled in all test layers (coal seams) The plume growth was essentially radial in all layers As expected, the growth is largest in the most permeable layer, the Pocahontas No. 3 coal seam Radial growth occurs to approximately 550 feet from injection well BD-114

24 CO 2 Plume Pocahontas No. 3 Percent CO 2 Saturation 1020 feet Injection Well 0% 0%-10% 10%-20% 20%-30% 30%-40% 40%-50% 50%-60% 60%-70% 70%-80% 80%-90% 90%-100% Scale In Feet

25 Test Schedule Site selection (Complete): 04/07 12/07 Approvals and Permitting: 02/08 07/08 Soil Gas Monitoring: 03/08 09/09 Coring: 04/08 06/08 Formation testing: 05/08 06/08 Install injection equipment: 07/08 08/08 Injection testing: 08/08 01/09 Site closure: 06/09 09/09

26 Core Hole Testing Geophysical logs: gamma ray, caliper, density, neutron, induction, temperature Desorption testing to determine current methane gas content Methane, nitrogen, and carbon dioxide adsorption isotherms Petrographic analyses of core samples Injection-falloff tests of Lee and Pocahontas formation injection intervals

27 Measurement, Monitoring and Verification Monitor CO 2 soil flux levels near the injection well Monitor pressure and gas composition at core holes Monitor casing pressures and gas and water production rates at adjacent CBM wells Monitor ambient CO 2 levels

28 Current Issues NEPA and DOE operational approval Core hole permitting and change in requirements Class V injection permit (EPA Region 3) and timing issues Core rig and service vendor availability