Construction Details for ADM CCS#1 Page G1of 5 

Permit Number: IL-115-6A-0002 

ATTACHMENT G: CONSTRUCTION DETAILS 

Facility name: Archer Daniels Midland, CCS#1 Well 

IL-115-6A-0002 

Facility contact: Mr. Mark Burau, Plant Manager 

4666 Faries Parkway, Decatur, IL 

(217) 424-5750, mark.burau@adm.com

Well location: Decatur, Macon County, IL; 

39o

52’ 37.06469” N, 88 o 53’ 36.25685” W 

This document provides details of the construction of CCS#1 and describes the pre-injection logs 

and tests performed prior to commencement of injection at the well under a permit issued by 

Illinois Environmental Protection Agency (IEPA Permit No.: UIC-012-ADM).

 Open hole diameters and intervals

Name Depth Interval (feet)

Open Hole

Diameter

(inches

)

Comment

Surface 0-355 26 To bedrock

Intermediate 355-5,339 17 1⁄2 To primary seal

Long 5,339-7,236 12 1⁄4 To total depth

 Casing Specifications 

Name

Depth 

Interval 

(feet)

Outside 

Diameter 

(inches)

Inside 

Diameter 

(inches)

Weight

(lb/ft)

Grade

(API)

Design

Coupling 

(Short or 

Long 

Threaded)

Thermal

Conductivity

@ 77 ° F 

(BTU/ft.hr.°F)

Surface

1

0-355 20 19.124 94 H40 Short 29

Intermediate2

0-5,339 13 3/8 12.515 54.5/68 J55 Buttress29

Long

3

(carbon) 0- 5,272 9 5/8 8.835 40.0 N80

Long

31

Long

3

(chrome)

5,272 - 7,219 9 5/8 8.681 47.0

Chrome

alloy

JFE Bear 13

Note 1: Surface casing is 355 ft of 20 inch casing. After drilling a 26" hole to approximately 355' into the 

bedrock below the shallow groundwater, 20", 94 ppf, H40, short thread and coupling (STC) casing were set 

and cemented to surface. Coupling outside diameter is ~21 inches. 

Note 2: Intermediate casing: 5,339 ft of 13 3/8 inch casing. After a shoe test or formation integrity test 

(FIT) was performed, a 17 1/2" hole was drilled to 5339' into the Eau Claire, the primary seal to the Mt.

Simon. 13-3/8", 54.5 and 68 ppf, J55, long thread and coupling (LTC) and buttress thread and coupling 

(BTC) were cemented to surface. Coupling outside diameter is ~14 3/8 inches. 

Note 3: Long string casing: 0-5,272 ft of 9 5⁄8 inch, N80 casing; 5272' - 7219' of 9 5⁄8 inch, chrome alloy 

(e.g., 
Construction Details for ADM CCS#1 Page G2of 5 

Permit Number: IL-115-6A-0002 

13Cr80). After a shoe test was performed and the integrity of the casing was tested, a 12 1⁄4" hole was 

drilled to approximately 7219' through the Mt. Simon, where the long string casing was run and 

specially cemented. Coupling outside diameter is 10 5⁄8 inches for N-80 and 10.485 inches for the chrome 

alloy (e.g., 13Cr80). 

 Tubing Specifications

Name

Depth 

Interval 

(feet)

Outside 

Diameter 

(inches)

Inside 

Diameter 

(inches)

Weight

(lb/ft)

Grade

(API)

Design 

Coupling 

(Short or 

Long 

Thread)

Burst 

strength 

(psi)

Collapse 

strength 

(psi)

Injection 

tubing

1,2,3 0-6,363 4 1⁄2 3.963 12.6

Chrome

alloy

JFE BEAR 8,960 7,820

Note 1: Maximum allowable suspended weight based on joint strength of injection tubing. Specified yield

strength (weakest point) on tubular and connection is 306,000 lbs. 

Note 2: Weight of injection tubing string (axial load) in air (dead weight) is 79,539 lbs. 

Note 3: Thermal conductivity of tubing @ 77°F is 13 BTU / ft.hr.°F.

The injection well was plugged back from the bottom with at least 80 feet of cement or a greater 

amount sufficient to prevent the injection fluid from coming in contact with the Precambrian 

granite basement. The figure below is a well construction schematic for CCS#1. 
Construction Details for ADM CCS#1 Page G3of 5 

Permit Number: IL-115-6A-0002 

 
Construction Details for ADM CCS#1 Page G4of 5 

Permit Number: IL-115-6A-0002 

Pre-Injection Testing 

Deviation Checks 

The subsurface and surface design (casing, cement, and wellhead designs) exceeds minimum 

requirements to sustain the integrity of the caprock to ensure that the CO2 remains in the Mt. 

Simon. The final well design met strength and CO2 compatibility requirements. 

The wellbore trajectory of each of the deep wells for the Illinois Basin-Decatur Project 

(injection, verification, and geophysical wells) was tracked. The wells were drilled to an 

inclination standard that eliminated the risk of interception with adjacent wellbores and surveyed 

at least every 1,000 feet of depth to ensure compliance. Wells were held to less than 5 degree 

inclination.

Tests and Logs 

The following testing and logging was performed. 

During Drilling 

Each open hole section (prior to setting each casing string) was logged with multiple suites to 

fully characterize the geologic formations (reservoirs and seals). Wireline resistivity, elemental 

capture spectroscopy, spontaneous potential (SP), gamma ray (GR), photoelectric factor and bulk 

density, and caliper logs were run. Sonic and compensated neutron porosity logs were also 

included on the intermediate and TD run. The TD run also included magnetic resonance, microimaging (dipmeter and fracture ID), formation pressure and rotary cores. 

For the injection well, 90 feet of whole core were obtained for the Eau Claire and the Mt. Simon. 

12 sidewall cores were taken in the Eau Claire formation and 1 sidewall core was taken in the 

granite formation below the Mt. Simon. 

A Cement Bond Log (CBL) with radial capability and/or Ultrasonic Cement Imaging logs was 

run on all casings strings with a possible exception for the surface casing. Due to the large 

surface casing size, a cement bond log with radial imaging was not possible; however, a 

conventional CBL and temperature log was run. The cement bond logs showed some isolated 

areas with channels or microannuli; however, they did not appear to be continuous or to 

compromise zonal isolation. The successful circulation of cement to the surface indicates an 

intact cement sheath. 

During and After Casing Installation 

A baseline reservoir saturation tool (RST) and temperature log were run; these will be compared 

with multiple passes during and after injection for detailed knowledge of where the CO2 has 

moved vertically. Careful monitoring of the top of the Mt. Simon Sandstone formation, as well 

as the porous zones above the seal, was used to confirm the integrity of the completion. 

Ultrasonic Cement Imaging logs with radial capability were run on the intermediate and long 

string casings. Ultrasonic Imaging logs provided casing thickness and internal radius baseline 

measurements in addition to cement evaluation data. Casing internal diameters were baselined by 

running a multi-finger caliper (MFC) log in the long string casing prior to the well completion. 
Construction Details for ADM CCS#1 Page G5of 5 

Permit Number: IL-115-6A-0002 

Based on previous analysis and results in the area, stimulation via hydraulic fracturing of the 

injection zone was not required. The perforations were acidized using 15 percent hydrochloric 

acid to reduce formation damage caused by drilling. A dynamic underbalanced perforating 

technique was used. 

After the well was cased, three pressure fall-off tests were performed to provide data for the 

reservoir modeling. Since injectivity testing is best analyzed in a single-phase fluid environment, 

the gauges were placed near a perforated interval, and then fluid was injected for a period and the 

pressure fall-off was measured. A total of three pressure fall-off tests were conducted. The first 

involved injection for 2 hours and monitoring for 19.5 hours; the second involved injection for 5 

hours and monitoring for 45 hours; the last test involved injection for 13 hours and monitoring 

for 105 hours. Also at this time, a step rate test was performed to determine the fracture gradient. 

The well was perforated between 6,976 - 6,978, 6,982 -7,012, and 7,025.5 – 7,050.5 feet. 

Demonstration of Mechanical Integrity 

Cement and system mechanical integrity were verified after construction with cement imaging 

logs with a radial capability (UltraSonic Imaging Tool, USIT). Furthermore, mechanical integrity 

was confirmed by pressure testing the casing (750 psig) prior to perforating, and after the packer 

was installed, the tubing/casing annulus was pressure tested. All tests were recorded. The 

pressure drop during the pressure test was 5 psi over an hour, resulting in a passed test. As 

mentioned above, a baseline reservoir saturation tool (RST) log was run. Repeat RST logs can be 

run if anomalous temperature data indicates a need for further analysis. Careful monitoring with 

temperature data across the top of the Mt. Simon Sandstone formation, as well as the porous 

zones above the seal, were used (along with data from the verification well) to confirm the 

integrity of the completion. 

Below is a summary of the MITs and pressure fall-off tests that were performed: 

Requirement Test Description Program Period

MIT - Internal Annulus Pressure Test Prior to operation

MIT - External Temperature Log Prior to operation

Testing prior to 

operating Pressure Fall-off Test Prior to operation