SECARB Phase III Early Test, Cranfield, MS

Transcription

1 SECARB Phase III Early Test, Cranfield, MS GCCC Digital Publication Series #09-04 Susan D. Hovorka Timothy A. Meckel Ramón H. Treviño J. P. Nicot Jong-Won Choi Changbing Yang Jeff Paine Katherine Romanak Jiemin Lu Hongliu Zeng Masoumeh Kordi Keywords: Field study-cranfield-ms; Monitoring tracers; Monitoring-cross-well seismic; Monitoring-groundwater-USDW; Monitoring-soil gas; Monitoring-wireline logs Cited as: Hovorka, S. D., Meckel, T. A., Treviño, R. H., Nicot, J. P., Choi, J. W., Yang, C., Paine, J., Romanak, K., Lu, J., Zeng, H., and Kordi, M., SECARB Phase III Early Test, Cranfield, MS: presented at the Southern States Energy Board Stakeholders Meeting, Atlanta, Georgia, March 3, GCCC Digital Publication #09-04.

2 SECARB PHASE III EARLY TEST CRANFIELD, MS Susan D. Hovorka, Timothy A. Meckel, Ramon H. Trevino, J.P. Nicot, Jong-Won Choi, Changbing Yang, Jeff Paine, Katherine Romanak, Jiemin Lu, Hongliu Zeng, Masoumeh Kordi Gulf Coast Carbon Center, Bureau of Economic Geology, Jackson School of Geosciences, The University of Texas at Austin

3 Management of SECARB Early Test University of Texas at Austin Gulf Coast Carbon Center DRI Denbury Resources Inc Sandia Technologies LLC LBNL LLBL USGS ORNL EPA QEA U Mississippi Miss State Other SECARB tests Schlumberger Carbon Services SECARB coal seam tests Geological Survey of Alabama Virginia Tech SECARB Power Plant tests EPRI Southern Co ARI

4 Overview Background Information Phase III Design Summary

5 Upper Cretaceous Tuscaloosa-Woodbine Trend Cranfield in Mississippi Salt Basin Source of large volumes of CO 2 via pipeline Cranfield Source: Dutton and others 1993

6 Gulf Coast Stacked Storage Field Test Phase 3: $36M, 2 observation wells, multiple injectors, 1 Mt/yr MS River Natchez, MS Tuscaloosa Formation: Cranfield, MS

7 SECARB (Early) Phase III Field Test Denbury early injectors Saline aquifer within Cranfield unit Gas cap Oil ring Cranfield unit boundary Phase II study area Dedicated observation Well; + logging in producers 1+ MMT/year Sonat CO 2 pipeline from natural source Jackson Dome Phase III study area Two dedicated observation wells in brine + in producers

8 A Denbury Cranfield unit Cranfield Geometric Overview Injec tor Mon itors Produceritor Mon Moni tor Injector A Phase III Early study area Regional seal Residual Gas 10,000 ft Tuscaloosa Formation Brine 2x Normal Residual Oil A A Phase II Study area

9 Phase III Design Two Observation Wells CASSM X-well tomography ERT Joint inversion (saturation, sweep efficiency) Fluid sampling (U-tube) Thermal response Whole cores / core analyses Geomechanical Test Paired Injection / Production Downhole Microseismic & Tilt In-zone / out-of-zone activity: pressure and fluid migration Far-Field Measurements RST BHP BHT

10 Characterization W-E OBS S-N Cranfield Anticline ~ 1 mile

11 A B DAS

12 Horizontal time slice with amplitude (2272 ms) A Intersection of OWC with top of injection interval DAS B Geomechanical Test

13 Deep water table

14 Scientific and Technical Objectives &Benefits Objective (1) Sweep efficiency brine system Anticipated Benefit Well-quantified measure of how CO 2 occupies pore volumes (2) Novel effort to account for volume and energy input Add rigor to pressure measurement for storage prediction (3) Leakage though 1945 wells? Assess effectiveness of surface monitoring in a deep water table Challenge these technologies - Reliable leakage detection?

15 2 7/8 tubing U-tube sampler 1/4 SS Seismic sources/receivers BHP+ T Planned Phase III Observation Smart Well Construction Cross well array in two wells High injection volumes Far-field monitoring tilt, microseismic, P&T, chemistry, surface seismic Casing-conveyed pressure sensor ERT 20 electrodes 200 Fiberglass non-conductive casing Tuscaloosa DE Distributed temperature 100 BEG, LBNL, LLNL, USGS, ORNL, Pinnacle, QEA, Sandia Technologies

16 Planned Subsurface Measurements CFU28-F1 Obs 1 Obs m 70 m 30 m

17 Phase III Summary Currently Mid-May / Observation Well #1 Down-Dip Brine Injection Intensive Monitoring Campaign Cross well Geomechanical Far Field

18 Progress Site selection First cored well, brine samples NEPA CX Characterization Phase II EOR Received seismic data Instrumentation Soil gas baseline Start workover Site development Phase III Brine Phase III Wells May Start Phase III injection Increasing number of injectors and rate per well Injection and monitoring End phase II

19 Cranfield Mississippi

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21 CFU 29-12: New Injector Gamma Ray (API) SP (mv) Permeability to air (md) Porosity (%) ,270 10,280 Average H: 283 md V: 47 md Average H: 20.5 % V: 20.7 % INJECTION ZONE DEPTH (ft) 10,290 10,300 10,310 10,320 10,330 10,340 Data provided by DRI

22 Core Box 1 Top Chert Pebble Conglomerate Braided Stream Sharp Basal Contact Marine Mudstone Shell fragments (oyster, gastropod) and Trace fossils Bottom Lower Shoreface

23 Gakona Copper River Junction, Alaska Modern Analog Braided Stream USGS Digital Data Series DDS-21

24 CFU 29-12: New Injector Gamma Ray (API) SP (mv) Permeability to air (md) Porosity (%) ,270 10,280 Average H: 283 md V: 47 md Average H: 20.5 % V: 20.7 % INJECTION ZONE DEPTH (ft) 10,290 10,300 10,310 10,320 10,330 10,340 Data provided by DRI

25 Fluvial Depositional Environment Stratal slicing seismic interpretation Channel erosion Channel erosion Channel erosion Channel erosion Point bar Point bar Galloway 1983 Meander fluvial model Hongliu Zeng

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27 Role of Dissolution in Plume and Pressure Evolution No dissolution: volume displaced = Volume injected Volume displaced = Volume injected volume dissolved + fluid expansion In miscible CO 2 EOR, a large amount of CO2 is dissolved in oil CO 2 migration is retarded compared to brine, where dissolution is much less.

28 ,700 9,800 sp mv res Ohm-m " casing 222' 10-3/4" casing 1,825' Test adequacy of Mississippi well completions for CO 2 sequestration Monitoring Zone DEPTH (ft) 9,900 10,000 10,100 Confining system 13-Chrome Isolation packer w/ feed through 13-Chrome Selective seat nipple Pressure transducer Side Pocket Mandrel w/dummy gas valve 1/4" tubing installed between packers to Provide a conduit between isolation packers 10,200 CO 2 Injection Zone 13-Chrome Production packer w/ feed thrus Tuscaloosa perforation Pressure transducer Side Pocket Mandrel w/dummy gas valve 10,300 7" casing 10,305'

29 Preparation of the Observation Wells (and outreach)

30 Real-time monitoring via Satellite Uplink 0 Tubing data 150 Well head tubing and barometric pressure at surface Tubing Pressure (psig)

31 Phase III: Theoretical Approaches Through Commercialization Commercial Deployment by Southern Co. Toward commercialization Contingency plan Parsimonious public assurance monitoring Subsurface perturbation predicted Hypothesi s tested Field experiments CO 2 retained in-zonedocument no leakage to air-no damage to water Surface monitoring: instrument verification Groundwater program CO 2 variation over time Above-zone acoustic monitoring (CASSM) & pressure monitoring CO 2 saturation correctly predicted by flow modeling CO 2 saturation measured through time acoustic impedance + conductivity Tomography and change through time 3- D time lapse surface/ VSP seismic Dissolution and saturation measured via tracer breakthrough and chromatography Pressure (flow plus deformation) correctly predicted by model Tilt, microcosmic, pressure mapping Acoustic response to pressure change over time Theory and lab Sensitivity of tools; saturated-vadose modeling of flux and tracers Lab-based core response to EM and acoustic under various saturations, tracer behavior Advanced simulation of reservoir pressure field

32 Modeled December Distribution of CO 2 Observation well N Middle lower Tuscaloosa (model layer 11) GEM compositional simulator Jong-wan Choi and JP Nicot, BEG

33 Regional Stratigraphy of the Tuscaloosa Formation Secondary seals Above-zone Monitoring interval Seal Injection interval

34 Southeast Regional Carbon Sequestration partnership SECARB test Cranfield Unit operated by Denbury Resources Inc Mississippi River Natchez Mississippi 3,000 m depth Tuscaloosa Fm Gas cap, oil ring, downdip water leg Shut in since 1965 Strong water drive Returned to near initial pressure

35 Geomechanical Test DAS

36 DAS Geomechanical Test