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: duguid@battelle.org

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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

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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