Central Appalachian Basin Unconventional (Coal/Organic Shale)

39 Pages·2015·12.75 MB·English

Central  Appalachian  Basin  Unconventional  
(Coal/Organic  Shale)  Reservoir  Small-­Scale  
CO2  Injection  Test
Project  Number:  DE-­FE0006827
Nino  Ripepi
Michael  Karmis
Virginia  Center  for  Coal  and  Energy  Research  at  
Virginia  Tech
U.S.  Department  of  Energy
National  Energy  Technology  Laboratory
Carbon  Storage  R&D  Project  Review  Meeting
Developing  the  Technologies  and  Building  the  
Infrastructure  for  CO Storage
2
August  21-­23,  2012
Presentation  Outline
• Project  Objectives  and  Background
• Shale  CO Injection  Test  in  Morgan  County,  Tennessee
2
• Coalbed  Methane  CO Injection  Test  in  Buchanan  
2
County,  Virginia
• Conclusions
2
Project  Overview:    
Goals  and  Objectives
¬ Objectives:
§ Inject  up  to  20,000  metric  tons  of  CO2  into 3  vertical  CBM  wells
over  a  one-­year  period  in  Central  Appalachia
§ Perform  a  small  (approximately  400-­500  metric  tons)      Huff  and  
Puff  test  in  a  horizontal  shale  gas  well
¬ Goals
§ Test  the  storage  potential  of  unmineable coal  seams  and  shale  reservoirs
§ Learn  about  adsorption  and  swelling  behaviors  (methane  vs.  CO2)
§ Test  the  potential  for  enhanced  coalbed  methane  (ECBM)    and  enhanced  gas  
(EGR)  production  and  recovery
¬ Major  tasks:
§ Phase  I:  site  characterization,  well  coring,  injection  design
§ Phase  II:  site  preparation,  injection  operations
§ Phase  III:  post-­injection  monitoring,  data  analysis,  reservoir  modeling
Research  Partners
1,2,3,4,5
• Virginia  Center  for  Coal  and  Energy  Research  (Virginia  Tech)
2,3
• Cardno
1,4
• Gerald  Hill,  Ph.D.
1,5
• Southern  States  Energy  Board
3
• Virginia  Dept.  of  Mines,  Minerals  and  Energy
1 Project  management
3
• Geological  Survey  of  Alabama 2 Operations
• Sandia  Technologies 3 3 Research
• Det Norske  Veritas (DNV) 4 4  Risk  management
2,3 5 Outreach
• Consol Energy  (Research  Group)
Industrial  Partners Collaborators
• Schlumberger
• Consol Energy  (CNX  Gas)
• Global  Geophysical  Services
• Harrison-­Wyatt,  LLC
• Oak  Ridge  National  Laboratory
• Emory  River,  LLC
• University  of  Tennessee
• Dominion  Energy
• University  of  Virginia
• Alpha  Natural  Resources
• Southern  Illinois  University
4
• Flo-­CO2
• Oklahoma  State  University
Project  Schedule
Phase
 I Phase
 II Phase
 III
(10/1/11
 – 3/31/13) (4/1/13
 – 9/30/15) 12
 months
 (TBD)
•Characterization
  •Site
 preparation
  •Site
 closure

– Drill
 char.
 Well – Conversion
 of
  – Conversion
 of
 injection

production
 wells and
 monitor
 wells
– Core
 sample
 analysis
– Drill
 monitor
 wells – Site
 restoration
– Modeling
– Baselines
 for
 monitoring – Install
 additional
  •Post-­‐injection

monitor
 stations
•Injection
 design characterization
•CO injection period
2 – Data
 analysis
 and

•Monitoring
 design
(3/18/14
 -­‐ 3/31/14)
 -­‐ Shale interpretation
– Well
 locations
(7/02/15
 -­‐ 6/30/16) -­‐ CBM – Post-­‐injection

– Geophysical
 surveys
monitoring
•Monitoring

• Go/no
 go
 1:
 permits,
 access – Reservoir
  modeling
– Atmosphere
(12
 months)
– Assessing
 enhanced

• Go/no
 go
 2:
 characterization – Surface
recovery
  for

(18
 months)
– Reservoir commercialization
Ongoing:
 CO Injections,
 Reservoir
 Modeling,
 Monitoring,
  Education/Outreach
2
5
Previous  Experience  in  Huff  and  Puff  Test  
in  Russell  County,  Virginia  (2009)
Production  curve  for  huff-­and-­puff  test  well,  
• 1000-­ton  CO injection
2
Russell  County,  Virginia,  2009
• Stacked  coal  reservoir
• Evidence  of  preferential  
Post  CO Injection  EUR  =  471  
2   adsorption:  elevated  N
MMcf
2
and  CH
4
n,  
o
oductimonth • Enhanced  CH recovery  
Prcf/ 4
s  M
a Pre  CO Injection  EUR  =  319  MMcf
G 2
at  two  offset  wells,  no  
CO breakthrough
2
Shut-­in  Period  with  CO Injection
2
mid  November    ‘08  –mid  May  ‘09 • 30%  CO in  flowback
2
over  5  years
• EUR  of  test  well  has  
6
increased  by  48  percent
Shale  CO Injection  Test  (510  tons)
2
Morgan  County,  Tennessee
• Horizontal  well  in  Chattanooga  Shale  
formation,  drilled  in  2009
• Legacy  producing  gas  well  permitted  under  
TDEC
• 510  tons  for  “huff  and  puff”  injection  test
• Injection  period:  March  18-­31,  2014  (14  days)
• Shut-­in  period:  March  31-­ July  29,  2014                  
(~4  months)
• Flowback period:  July  29,  2014-­ present          
(~12  months)
7
• Current  status:  post-­injection  monitoring
Shale  CO Injection  Test  in  Morgan  County,  Tennessee
2
Monitoring,  Verification,  and  Accounting  (MVA)
MVA  Overview:
• Gas  and  water  sampling
– Commenced:  4/2013
– Injection  Well:  HW-­1003
– 13  Offset  Monitoring  Wells
HW-­1003
• 3  Horizontal  /  10  Vertical
• 11  In-­zone  /  2  Out-­of-­zone
• Perfluorocarbon  tracer  study
• Surface  water  sampling
0 ½  mi 1  mi 2  mi
Monitor  for:
• Injection  Phase:  %  Composition,  Tracer  Arrival
• Soaking  Phase:  Pressure,  %  Composition
8
• Flowback Phase:  Flowrate,  %  Composition,  Tracers
Shale  CO Injection  Test  in  Morgan  County,  Tennessee
2
Operations  Overview
Storage
Vessel
Injection
Skid
Propane Heater
HW-1003
9
Shale  CO Injection  Test  in  Morgan  County,  Tennessee
2
Operations  Overview
Tracer Injection
Tee
Storage
Check valve
Check valve
Vessel
Injection
Skid
CO
2
Inlet
Ball valve
Propane Heater
Gate
valve
HW-1003
10