Logging to identify well integrity changes and flow
paths
Andrew Duguid Ph.D., P.E.
1
IEAGHG Monitoring and Modeling Network Combined Meeting.
July 6-October 8, 2016
Funded by DOE NETL [DE-FE-0001040] and [DE FE0009284]
Collaborators Robert Butsch, Schlumberger Carbon Services,
J. William Carey, Los Alamos National Lab,
Boyun Guo, University of Louisiana at Lafayette
Susan Hovorka, University of Texas at Austin
Runar Nygaard, Missouri University of Science and Technology
Well leakage risk
• Well leakage risk is a significant
consideration for CO2 storage.
Integrity Monitoring
• Logging and monitoring can
provide data to determine if there
are potential flow paths in a well
and how integrity changes over
time.
Outline
• Background
• Log examples
• Discussion
• Thoughts
3
Need for Time-Lapse Integrity Monitoring
• Time-lapse monitoring of wells may be necessary to ensure
long-term storage of CO2.
Time-lapse monitoring can be used to identify changes to cement, casing,
and cement-casing bond
Tools may include ultrasonic imaging tools, cement bond logging tools,
corrosion monitoring tools, and saturation monitoring tools
Background: Cranfield Field, Mississippi
• SECARB’s Phase II Gulf Coast Stacked
Storage Project
• Three Monitoring Wells Studied in an EOR
Setting
Samples in and above the production zone
EGL7 68 years old
CFU 31F2 and CFU 31F3 7 years old
• All wells showed good cement in places and
potential integrity issues in other places.
5
Data Collection Through Logging• Logging Tools
• USIT* ultrasonic imager tool
• Isolation Scanner* cement evaluation service
• Sonic Scanner* acoustic scanning platform
• SCMT* slim cement mapping tool
• Testing and Sampling Tools
• CHDT* cased hole dynamics tester
• MSCT* mechanical sidewall coring tool
Perforation for VIT test
Point permeability
measurement
CHDT Sample Point
Sidewall Core Sample
Fluid Sample Point
VIT Interval
Wellbore
Well Cement
Geologic Formation
LEGEND
Cranfield CFU31F2 and CFU31F3
• Monitoring Wells
Constructed in 2009 and P&A’d 2015
Very similar construction
• 7-in 26lb N80 to ~10,200ft
• 7 5/8-in Bluebox 2500 from ~10,200 to
~10,700ft
• 7-in 26lb N80 to ~10,700ft to TD
(~10,790ft)
• Electrodes and other jewelry in the well
• 12 ¼-inch bit (large cemented annulus)
• Production reservoir ~10,435ft to
~10,518ft (CFU31F2)
7
ALL DEPTHS ARE REFERENCED FROM TVDSS + 315.5' surveyed boarded location GL or lower most flange on "C" section + 18' KB (333.5')
There are 3 penetrations through the packer and 5 lines strapped to the outside of the tubing.
There are 6 lines to be mounted externally on the casing.
The tubing hanger will have 8 ea. 3/8" NPT penetrations and the wellhead will have 8 ea. 1/2" NPT penetrations
7" 26 lb/ft, N-80 grade, LT&C steel casing w/ 6.276" nominal ID and 7.656" connection OD set @ 0-10,193'
2-7/8" EUE8RD, 6.5 lb/ft, N-80 grade fiberglass lined tubing from surface to +/-10,414'. 2-7/8" Fox NU T&C, 6.5 lb/ft, 13CH80 tubing from 10,414' to 10,536'
Pressure/Temp gauge w/ 11.63" running OD on 13' casing pup joint @ 10,033' - 10,046' w/ .426" OD 7-conductor DAC cable to surface. Pressure sensor at 10,044'
LBNL proprietary casing mounted DPTS system consisting of; 2 ea. 1/4" encapsulated TEC lines w/ 8 AWG insulated heating conductors from surface to 10,197', splicing into 2 ea.1/4" encapsulated TEC lines with 3 x 18 AWG insulated heating heating conductors from 10,182' to 10,568'. 1 ea. 1/4" encapsulated TEC line with two fiber optic strands
from surface to 10,695'
2 ea. DAC/TEC splitters w/ 11.63" running OD on 7" 26 lb/ft L-80 grade casing pup joints @ 10,193-206' & 10,206-219' w/ 2 ea. .42" OD 7-conductor DAC cables to surface. Each DAC/TEC splitter has 7 ea. 1/4" encapsulated TEC single conductor lines running to ERT electrodes.
U-Tube sampler w/ 2 ea. 1/4" control lines from 10,402' to surface, U-Tube block & check valve, and 1 ea. 1/4" control line through packer with 3/4" OD x 2' long filter @ 10,450' - 452'
4.625" OD Piezo Tube Source mounted on 2-7/8" Fox NU T&C, 6.5 lb/ft, 13CH80 tubing pup joint @ 10,414-420' w/ 1/4" 16 AWG single conductor TEC electrical powerline to surface
7" LT&C 13CH80 Casing Seal Receptacle w/ 5.75" ID @ 10,441'-446.2', over wrapped with fiberglass and crossed over to 7-5/8" fiberglass.
Pressure/Temperature sensor w/ 1/4" 18 AWG single conductor TEC to surface @ 10,452'
Multiple Feed-Thru packer w/ 6 ea. 1/4" NPT penetrations @ 10,441-445'
2-7/8" Fox NU T&C, 6.5 lb/ft, 13CH80 tubing from 10,414' to 10,536'. Perforated from 10,450-484' (top half of injection interval), with re-entry guide @ 10,539'.
Tuscalusa "D & E" perforations from 10,450' to 10,518' with 0 degree phasing, 2 shots per foot, less than 1/2" entry holes
4.625" OD Piezo Tube Source mounted on 2-7/8" Fox NU T&C, 6.5 lb/ft, 13CH80 tubing pup joint @ 10,524-530' w/ 1/4" 16 AWG single conductor TEC electrical powerline to surface
7" LT&C Float Collar @ 10,693.93' - 10,695.58'
7-5/8" Bluebox 2500 Fiberglass casing w/ 6.21" nominal ID and 9.40" connection OD @ 10,223.4' - 10,693.93'
2 joints of 7" 26 lb/ft, LT&C, N-80 steel casing @ 10,695.58' - 10,772.24'
7" LT&C Float Shoe @ 10,10,772.24' - 10,774'
12-1/4" drilled hole to 10,790'
14 ea. ERT electrodes w/ 14 ea.1/4" encapsulated TEC single conductor lines running to DAC/TEC splitters. The top electrode is @ 10,381' and the bottom electrode is @ 10,570' with +/-15' spacing between electrodes
4.75" OD x 2.347" ID Side Pocket Mandrel to accept 1" OD memory gauge from 10,433'-10,441'
Cranfield Field Ella G Lees #7
8
Potential Flow Pathways:
Cemented cable (CFU31F3)
• Ultrasonic Imager Tool
Casing maps, cement maps,
solid, liquid, and gas
identification, jewelry locations
• Cemented cable for monitoring
equipment
Possible leakage path due to
poor cement or poor bond under
cable.
9
Potential Flow Pathways: Annulus EGL7 SCMT
10
Little change
No Pressure 1100 psi
• No change to log response with pressure implies that annulus did
not close. Annulus larger that 70 microns.
Potential Flow Pathways: Poor Cement Zone (EGL7)
11
2008 2013
• “Cement” material removed during cased-hole flow testing in 2013
Later analysis showed cement minerals in removed material
Constant flow rate achieved until tool plugged, Annulus aperture estimated to be 0.2 to
0.4 mm
Integrity Change: Casing Collapse? Time-Lapse Ultrasonic
Logging in Fiberglass Casing (CFU 31F3)
12
20152009
• Fiberglass
casing installed
to allow
monitoring
• Casing
degradation of
casing in the
CO2 zone.
Suggests
fiberglass may
not be
appropriate for
this application
Integrity Change: Loss of Bond in CBL Logging in Steel
Section (CFU 31F2)
13
2015200920152009
• Loss of bond in CBL track
between initial logging in 2009
and final logging in 2015
Integrity Change: Loss of Acoustic Impedance in Steel
Section (CFU 31F2)
1420152009
• Change in acoustic impedance
track between initial logging in
2009 and final logging in 2015
(over the same zone as
Integrity Change: Cement Squeeze
(EGL7)
15
• Gain of cement
due to cement
squeeze between
initial logging in
February, 2008
and reclogging in
April, 2008
Good Cement: No Change (EGL7)
16
2008 2013
Summary/Discussion
• Changes to well integrity were identifiable over a short period (5 to
6 years) in and above the CO2 zone
• Potential pathways were identified in all wells
• All of the wells still maintained overall integrity
• Short-term changes imply more study is needed to understand the
importance of changes in log response due to CO2 exposure,
general well aging, and well operations. Studies should address:
Timing or repeat surveys
Reasons to repeat
Types of surveys to repeat
How changes in time relate to actual integrity
Others?
17
Thoughts for monitoring wells
• Selection of monitoring wells and monitoring technologies
should be considered carefully to ensure that monitoring
related leakage risks are not significant to the project
Both materials and external hardware should be designed to
withstand CO2 exposure and maintain isolation.
Lines running along the casing may be difficult to cement
Casing, gauges, other special equipment need to be constructed
from CO2-resistant materials if their failure could affect overall well
integrity
18
Thank You!
Contact Information
Andrew Duguid Ph.D., P.E.
Principal Engineer
Battelle
505 King Avenue
Columbus, OH 43201
Cell: +1 614-561-4468
Email: [email protected]
19
Backup Slides
20
EGL7– CHDT
21
Approximately constant
pumping rate
CFU31F2 CHDT Testing
22
0
0.5
1
1.5
2
2.5
3
0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
0 2000 4000 6000 8000 10000 12000
Drill
Bit D
epth
(in
)
Pre
ssure
(psi)
Time (s)
CHDT test at 9535 ft
Pressure Bit Penetration
CFU31F2 Sidewall Cores
23
7,900
9,530
9,800
EGL7 Cased-Hole Sidewall Coring
3,011.27 m (9,879.5 ft)
24
3,012.64 m (9,884 ft)
2,135.42 m (7,006 ft)
Very soft
Very soft
“Normal”
EGL7 XRD: Bulk Samples
3,011.27 m (9,879.5 ft) 3,012.64 m (9,884 ft)
25
SAMPL
E
DEPTH
(m)
SiO2 CaCO3 Ca(OH)2 Ca2SiO4
Ca3(SiO4)
OCa3(SiO4)O
Ca3Al2(SiO
4)3
(Mg0.804Ca0.196)3
Al2(SiO4)3
Ca3Al2(SiO4)(
OH)8
Ca2(SiO4)6H2O
Quart
zCalcite
Portlandit
e
Dicalcium
silicateHaturite
Tricalcium
silicate
oxide
Grossular Pyrope KatoiteCalcium Silicate
Hydrate
3,011.2
71 14 16 23 6 7 6 5 5 18
3,012.6
41 6 21 6 0 0 0 8 34 25
Mechanical and Petrophysical
Properties
Sample
Depth (m)Test Fluid
Temperature
(°F)
Confining
Pressure
(psi)
Length (in) Diameter (in)Permeability
(mD)
3011.27 2% KCl 240 4400 0.582 0.936 0.000186
3012.64 2% KCl 240 4400 0.623 0.86 0.0146
Sample
Depth
Sample
Length
Sample
Diameter
Bulk
Density
Dry Bulk
Density
Grain
Density
Ambient
Porosity
Gas
Permeability
NOB
Stress
(m) (cm) (cm) (g/cc) (g/cc) (g/cc) (%) (md) (psi)
3011.27 1.478 2.37 2.25 2.134 2.668 20.02>0.01 400
3012.64 1.552 2.098 1.812 1.707 2.641 35.36 1.76 400
26
CFU 31F3 MSCT
Cores in Fiberglass
27
Above Production Interval In Production Interval
Casing Expansion (Lower Bound on Annulus)
𝜎𝑐 =𝑝𝑖𝑟𝑖
2−𝑝𝑜𝑟𝑜2
𝑟𝑜2−𝑟𝑖
2 −𝑟𝑖2𝑟𝑜
2 𝑝𝑜−𝑝𝑖
𝑟2 𝑟𝑜2−𝑟𝑖
2
Where:
sc = Circumferential stress (psi) [23,013 psi]
pi = Pressure in the well (psi) [4,550 psi]
po = Pressure outside the well (psi) [3,500 psi]
ri = Internal radius of the casing (in) [3.363 in]
ro = Outer radius of the casing (in) [7.000]
r = Radius of interest in the casing (in) [7.000]
e = Strain (in/in) [0.00079]
s = Stress (psi) [sc]
E = Young’s Modulus (psi) [29 x 106 psi]
C = Circumference (in) [21.99115]
𝜀 =𝜎
𝐸
Circumferential Hoop Stress
Hooke’s Law
𝜀 =𝞓𝐶
𝐶
Definition of Strain Circumference of a Circle
𝐶 = 2𝜋𝑟
Casing expansion = 70.55 mm (0.00278 in)
EGL7 CHDT-Based Annulus Size Estimate
0.0000000
0.0000500
0.0001000
0.0001500
0.0002000
0.0002500
0.0003000
0.0003500
0.0004000
0.0004500
0 0.000002 0.000004 0.000006 0.000008 0.00001
An
nu
lus S
ize (
m)
Flow Rate, Q, (m3/s)
Annulus Size Estimates for EGL 7
Source at 42 ft from test point
Source at 90 ft from test point
Source at 140 ft from test point
Source 330 ft from test point
Actual Flow Rate Measured
Flow Points
Calculated change in annulusbetween SCMT runs
29