HomeMy WebLinkAboutADAM FARM 1-4 - Well Abandonment Report - Oxy - 7/19/2024Casing History
Subsequent Report of Abandonment
Details:
If yes, explain details below
If yes, explain details below
Yes NoWellbore has Uncemented Casing leaks:
NoYesFish in Hole:
1200Estimated Depth:NoYesCasing to be pulled:
Other
Mechanical ProblemsProduction Sub-economicDryReason for Abandonment:
-105.00407640.171292 Longitude:
GPS Data:
Only Complete the Following Background Information for Intent to Abandon
2.4 11/09/2009GPS Quality Value:Date of Measurement:
Latitude:
Type of GPS Quality Value:
90750Field Number:Field Name:WATTENBERG
Federal, Indian or State Lease Number:
Meridian:668W Range:Township:2N 4 Section:QtrQtr:
1-4 Well Number:
SWNE
County:WELD
Location:
ADAM FARMWell Name:
05-123-30569-00API Number
This form is to be submitted as an Intent to Abandon whenever an abandonment is planned on a borehole. After the
abandonment is complete, this form shall again be submitted as a Subsequent Report of the actual work completed. The
approved intent shall be valid for six months after the approval date, after that period, a new intent will be required.
Attachments required with the Intent to Abandon are wellbore diagrams of the current configuration and the proposed
configuration with plugs set.
A Subsequent Report of Abandonment shall indicate the actual work completed. Attachments required with a Subsequent
Report are a wellbore diagram showing plugs that were set and casing remaining in the hole, the job summaries from all
plugging contractors used, including wireline and cementing (third party verification) and any logs that may have been run
during abandonment.
State of Colorado
Energy & Carbon Management Commission
1120 Lincoln Street, Suite 801, Denver, Colorado 80203 Phone: (303) 894-2100 Fax: (303) 894
-2109
WELL ABANDONMENT REPORT
FORM
6
Rev
11/20
Notice of Intent to Abandon
lorena_ruiz@oxy.comEmail:
Fax:
(970) 336-3535Phone:
Zip:80217-
3779
COState:DENVER
P O BOX 173779
Contact Name:
City:
Lorena Ruiz
Address:
KERR MCGEE OIL & GAS ONSHORE LPName of Operator:
47120ECMC Operator Number:
robbie.revas@state.co.usEmail:
Tel:(720) 661-7242Name:Revas, Robbie For "Intent" 24 hour notice required,
ECMC contact:
06/26/2024
Date Received:
Document Number:
DE ET OE ES
403693866
Formation Perf. Top Perf. Btm Abandoned Date Method of Isolation Plug Depth
CODELL 7513 7529
NIOBRARA 7252 7392
Total: 2 zone(s)
Current and Previously Abandoned Zones
Type of Well Abandonment Report:
Page 1 of 4Date Run: 7/1/2024 Doc [#403693866] Well Name: ADAM FARM 1-4
Technical Detail/Comments:
Eagle Buffer:
This planned location is located within a bald eagle buffer. Operations will need to be completed outside the timing windows of 12/1 –
7/31 (eagle nest) and/or 11/15 – 3/15 (winter night roost). The eagle nest buffer window can be shortened if the nest has been
confirmed fledge for the year by CPW. If work, is planned during either window, HSE will consult with CPW prior to operations
beginning. CPW CONSULTATION HAS BEEN COMPLETED.
NoYesFlowline/Pipeline has been abandoned per Rule 1105
Type of Cement and Additives Used:
*Cementing Contractor:*Wireline Contractor:
Cut and Cap Date:
inch casingft. of
Additional Plugging Information for Subsequent Report Only
Casing Recovered:
Plug Tagged: Plug Type:
Plug Tagged:CASINGPlug Type:
Plug Tagged:CASINGPlug Type:
Plug Tagged:CASINGPlug Type:
Plug Tagged:CASING
Plug Tagged:
(Cast Iron Cement Retainer Depth)
CICR Depth
CICR Depth
1360
4188
CICR Depth7222
sacks cmt on top.withCIBP #5: Depth
sacks cmt on top.withsacks cmt on top. CIBP #4: DepthwithCIBP #3: Depth
Set sacks in mouse holeSetsacks in rat hole
NoYesAbove Ground Dry-Hole Marker:Cut four feet below ground level, weld on plate
90Set sacks at surface
ft.924ft. to1250sacks half in. half out surface casing fromSet160
sacks. Leave at least 100 ft. in casing135ft. with1390Perforate and squeeze at
sacks. Leave at least 100 ft. in casing95ft. with4218Perforate and squeeze at
sacks. Leave at least 100 ft. in casing95ft. withPerforate and squeeze at 7252
ft. ft. tosks cmt fromSet
ft. 0ft. to300sks cmt fromSet90
ft. 1300ft. to1360sks cmt fromSet5
ft. 4125ft. to4188sks cmt fromSet5
ft. 7160ft. to7222sks cmt from5Set
sacks cmt on top.withsacks cmt on top. CIBP #2: Depth90with300CIBP #1: Depth
Plug Type:
NOTE: Two(2) sacks cement
required on all CIBPs.
Plugging Procedure for Intent and Subsequent Report
Casing Type Size of
Hole
Size of
Casing
Grade Wt/Ft Csg/Liner
Top
Setting
Depth
Sacks Cmt Cmt Btm Cmt Top Status
SURF 12+1/4 8+5/8 J-55 24 0 974 325 974 0 VISU
1ST 7+7/8 4+1/2 I-80 11.6 0 8108 204 8108 6686 CBL
Stage
Tool
5217 559 5248 1255 CBL
JENKINS, STEVE
Based on the information provided herein, this Well Abandonment Report (Form 6) complies with ECMC Rules and applicable
orders and is hereby approved.
ECMC Approved:Date:7/1/2024
I hereby certify all statements made in this form are, to the best of my knowledge, true, correct, and complete.
Signed:Print Name:Lorena Ruiz
Title:Regulatory Tech Date:6/26/2024 Email:lorena_ruiz@oxy.com
Surface Plug Setting Date:
Number of Days from Setting Surface Plug
to Capping or Sealing the Well:
Page 2 of 4Date Run: 7/1/2024 Doc [#403693866] Well Name: ADAM FARM 1-4
12/31/2024Expiration Date:
COA Type Description
FLOWLINE AND SITE CLOSURE
1) Consistent with Rule 911.a, a Form 27 must be approved prior to cut and cap,
conducting flowline abandonment, or removing production equipment. Allow 30 days for
Director review of the Form 27; include the Form 27 document number on the Form 44
for offsite flowline abandonment (if applicable) and on the Form 6 Subsequent.
2) Properly abandon flowlines per Rule 1105. If flowlines will be abandoned in place,
include with the Form 27: pressure test results conducted in the prior 12 months as well
as identification of any document numbers for a ECMC Spill/Release Report, Form 19,
associated with the abandoned line.
For Wells with known Bradenhead pressures:
1) Provide 2 business day notice of plugging MIRU via electronic Form 42, and provide
48 hours Notice of Plugging Operations, prior to mobilizing for plugging operations via
electronic Form 42. These are 2 separate notifications, required by Rules 408.e and
408.I.
2) After placing the shallowest hydrocarbon isolating plug (1360'), operator must wait a
sufficient time to confirm static conditions.
3) After placing plug at 1360’ assure that all fluid migration has been eliminated by
monitoring the well for a minimum of 8 hours before proceeding to the next plug. If at
any time after placing this plug there is evidence of pressure or of fluid migration,
contact ECMC engineering before continuing operations.
4) Prior to placing the 1250’ plug: verify that all fluid migration (liquid or gas) has been
eliminated. If evidence of fluid migration or pressure remains, contact ECMC Engineer
for an update to plugging orders.
5) After isolation has been verified, pump plug and displace. If cement is not circulated
to surface, shut-in, WOC 4 hours then tag plug – must be at 924’ or shallower and
provide at least 10 sx plug at the surface.
6) After surface plug and prior to cap, verify isolation by either a 15 minute bubble test
or 15 minute optical gas imaging recording. If there is indication of flow contact ECMC
Engineering. Provide a statement on the 6SRA which method was used and what was
observed. Retain records of final isolation test for 5 years.
7) With the Form 6 SRA operator must provide written documentation which positively
affirms each COA has been addressed.
Operator shall implement measures to control venting, to protect health and safety, and
to ensure that vapors and odors from well plugging operations do not constitute a
nuisance or hazard to public welfare.
Prior to starting plugging operations a Bradenhead test shall be performed if there has
not been a reported Bradenhead test within the 60 days immediately preceding the start
of plugging operations.
1) If, before opening the Bradenhead valve, the beginning pressure is greater than 25
psi, sampling is required.
2) If pressure remains at the conclusion of the test, or if any liquids were present during
the test, sampling is required.
The Form 17 shall be submitted within 10 days of the test. Sampling shall comply with
Operator Guidance - Bradenhead Testing and Reporting Instructions. If samples are
collected, copies of all final laboratory analytical results shall be provided to the ECMC
within three (3) months of collecting the samples.
This oil and gas location is within a CPW-mapped bald eagle roost or communal roost
Rule 309.e.(1) consultation habitat. CPW may choose to consult on this planned P&A to
develop site specific measures to avoid, minimize, and mitigate impacts to wildlife prior
to conducting the work. Please note that non-emergency plugging and abandonment
(PA) activities should not take place from November 15 to March 15. CPW consultation
has occurred.
Due to proximity to a wetland, surface water and expected shallow groundwater,
operator will use secondary containment for all tanks and other liquid containers.
Operator will implement stormwater BMPs and erosion control measures as needed to
prevent sediment and stormwater runoff from entering the wetland and surface water.
CONDITIONS OF APPROVAL, IF ANY LIST
Page 3 of 4Date Run: 7/1/2024 Doc [#403693866] Well Name: ADAM FARM 1-4
Operator committed to the following Best Management Practices under the Technical
Detail/ Comments section on the Submit Tab:
This planned location is located within a bald eagle buffer. Operations will need to be
completed outside the timing windows of 12/1 – 7/31 (eagle nest) and/or 11/15 – 3/15
(winter night roost). The eagle nest buffer window can be shortened if the nest has been
confirmed fledge for the year by CPW. If work, is planned during either window, HSE
will consult with CPW prior to operations beginning. CPW CONSULTATION HAS BEEN
COMPLETED.
7 COAs
ATTACHMENT LIST
Att Doc Num Name
403693866 WELL ABANDONMENT REPORT (INTENT)
403693932 PROPOSED PLUGGING PROCEDURE
403693933 WELLBORE DIAGRAM
403837630 OTHER
403842030 FORM 6 INTENT SUBMITTED
Total Attach: 5 Files
User Group Comment Comment Date
Engineer 1) Deepest Water Well within 1 mile = 700’.
2) Fox Hills Bottom- N/A, per SB5.
07/01/2024
OGLA Location Assessment Specialist (LAS) review complete. Well is not nearby RBUs. Task
passed.
07/01/2024
Permit selected PDOP from dropdown box
Verified as drilled lat/long
Verified completed intervals - 12330569(2), 12330569
Verified production reporting
pass
02/22/2024
Total: 3 comment(s)
General Comments
Page 4 of 4Date Run: 7/1/2024 Doc [#403693866] Well Name: ADAM FARM 1-4
OCCIDENTAL PETROLEUM CORPORATION
Please contact your area engineer with any questions concerning this procedure.
2/15/2024
PLUG and ABANDONMENT PROCEDURE
ADAM FARM 1-4 API: 05-123-30569
Step Description
1 Review Previous Open Wells Reports/Well History. If you have questions or concerns, contact Foreman/Engineer.
2 COA: Provide 48 hour notice to Colorado ECMC prior to rig up per request on approved Form 6 (e.g. call field coordinator, submit
Form 42, etc.).
3 Notify Automation Removal Group at least 24 hours prior to rig move. Request they catch and remove plunger, isolate production
equipment, and remove any automation prior to rig MIRU.
4 MIRU Slickline. Pull production equipment and tag bottom. Record tag depth, casing/tubing pressures and fluid level in Open Wells.
Directional Survey was run on 06/24/17. RDMO Slickline.
5 Prepare location for base beam equipped rig. Install perimeter fence as needed.
6 COA: Verify Form 17 (State Bradenhead Test) has been run within 60 days of RU.
7
Refer to the Rockies Well Services Guidelines document whenever rigging up BOP and WL, or whenever tripping in or out of the
well. Consult with Foreman/Engineer before deviating from these guidelines. All cement jobs (excluding injections squeezes)
must be pumped at 4-6 BPM. All cement plugs pumped through tubing must use the Diverter tool. Final top-out can be pumped
between 2-4 BPM.
8
Upon RU, check and record bradenhead pressure. If bradenhead valve is not accessible, re-plumb so that valve is above GL. Blow
down bradenhead and leave open during working hours. Re-check pressure each day and input value in the "Casing press." box in
Open Wells.
9
MIRU WO rig. Verify BOP and wellhead rating, inspect for appropriate API standards, pressure test BOP. Kill well as necessary using
biocide treated fresh water. ND WH. NU BOP. Unland tbg. **Barrier Management** Fluid will be the only barrier while NU BOP.
Stop and review JSA.
10 TOOH and SB 7222' of 2-3/8" tbg. LD remaining 2-3/8" tbg.
11 MIRU WL. PU and RIH with (4-1/2", 11.6#) gauge ring to 7262'. POOH.
12 Niobrara Injection Squeeze
13 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 7222'.
14 Establish an injection rate with treated water. Record rate and pressure results and report them to the Foreman/Engineer. Plugging
orders may change based on results. When 1 bpm is achieved, record pressure and successful test has been completed.
15 Note: Do not exceed 40 bbls of cement on injection squeezes.
16
MIRU cementers. Pump Niobrara Injection Squeeze: 100 sx (27.1 bbl or 152 cf) of the Niobrara Cement blend: Class G with 0.4%
B547 Gas Block (Latex) and 0.4% D255 FLA (Fluid Loss) and 35% D066 Silica Flour and 0.2% D800 (Retardant) and 0.3% D065
(Dispersant). Underdisplace by 1 bbls. Volume is based on 30' in the casing below the CICR, cement squeezed into formation, and
62' on top of the CICR. Collect wet and dry samples of cement to be left on rig. RDMO cementers.
17 Pull out of cement. TOOH, SB 4188' of 2-3/8" tbg. LD remaining tbg.
18 Sussex Injection Squeeze
19 PU and RIH with one 4', 3-1/8'' deep penetrating perf gun wth 4 spf. Shoot squeeze holes at 4218'. POOH. RDMO WL.
20 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 4188'.
21 Establish an injection rate with treated water. Record rate and pressure results and report them to the Foreman/Engineer. Plugging
orders may change based on results. When 1 bpm is achieved, record pressure and successful test has been completed.
22 If gas is present, consider swabbing and venting before pumping injection squeeze.
23 Note: Do not exceed 40 bbls of cement on injection squeezes.
24
MIRU cementers. Pump Sussex Squeeze: 100 sx (21.2 bbl or 119 cf) of the Sussex AGM: Class G with 0.4% B547 Gas Block (Latex)
and 2% D053 Expansion (Gyp) and 0.25% D255 FLA (Fluid Loss)0.3% D065 (Dispersant). Underdisplace by 1 bbls. Volume is based
on 30' in the casing below the CICR, cement squeezed into formation, and 63' on top of the CICR. Collect wet and dry samples of
cement to be left on rig. RDMO Cementers.
25 TOOH and SB 1360' of 2-3/8" tbg. LD stinger, and remaining tbg.
26 Upper AGM Injection Squeeze
27 MIRU WL. PU and RIH with one 4', 3-1/8'' deep penetrating perf gun wth 4 spf. Shoot squeeze holes at 1390'. POOH. RDMO WL.
28 PU and TIH with (4-1/2", 11.6#) packer on 2-3/8" tbg. Set packer at 1360'.
29 Establish an injection rate with treated water. Record rate and pressure results and report them to the Foreman/Engineer. Plugging
orders may change based on results. When 1 bpm is achieved, record pressure and successful test has been completed.
30 Release packer. TOOH, SB 2-3/8" tbg. LD packer.
31 If gas is present, consider swabbing and venting before pumping injection squeeze.
32 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 1360'.
33 Note: Do not exceed 40 bbls of cement on injection squeezes.
34
MIRU cementers. Pump Squeeze: 140 sx (30.2 bbl or 170 cf) of the Upper AGM blend: Class G with 0.4% B547 Gas Block (Latex) and
1.5% S001 CC (Calcium Chloride) and 4% D053 Expansion (Gyp). Underdisplace by 1 bbls. Volume is based on 30' in the casing
below the CICR, cement squeezed into formation, and 60' on top of the CICR. Collect wet and dry samples of cement to be left on
rig. RDMO Cementers.
35 Pull out of cement. TOOH to 1200’. Reverse circulate a minimum of 2 hole volume after cementing to ensure no cement is left in
the tbg or annulus.
36 TOOH and SB 1250' of 2-3/8" tbg. LD stinger, and remaining tbg.
37 COA: WOC 8 hours. If there is evidence of pressure or fluid migration, contact Engineering as there will need to be additional
remediation attempts before the SC shoe plug.
38 SC Shoe Stub Plug
39 PU and TIH with mechanical cutter on 2-3/8" tbg. Cut 4-1/2", 11.6# casing at 1200'. TOOH and LD cutter.
40 Attempt to establish circulation with biocide treated fresh water.
41 ND BOP. ND TH. Un-land casing. Rig max pull shall be 100,000#. Max pull over string weight shall be 50,000#. If unable to unland,
contact Foreman/Engineer. **Barrier Management** Fluid will be the only barrier while unlanding casing. Stop and review JSA.
42 Install BOP on casing head with 4-1/2", 11.6# pipe rams. **Barrier Management** Fluid will be the only barrier while NU BOP. Stop
and review JSA.
43 TOOH and LD all 4-1/2", 11.6# casing. Remove 4-1/2", 11.6# pipe rams and install 2-3/8" pipe rams.
44 TIH with diverter tool on 2-3/8" tubing to 1250'. Establish circulation to surface with biocide treated fresh water.
45 Initiate circulation at low rate monitoring returns for fluid. Add mud thinner to hydrate/clean mud. Slowly increase circulation rate
to 4-6 BPM using mud thinner and gel polymer sweeps as needed.
46 Pump 35 bbls of 160F HSF (0.5 gals/bbl or 1.5 lbs/bbl) and let soak for ~2 hours.
47 Continue circulating at 4-6 BPM if possible. If returns show hydrocarbons or a 1 hr build-up shows pressure, swab and vent well and
clean open tank. Circulate clean fluid before pumping cement.
48 COA: Verify and document that all pressure and fluid migration has been eliminated prior to placing the SC shoe plug at 1250'. If
there is evidence of pressure or fluid migration, contact Engineering.
49
MIRU cementers. Pump 10 bbls (min) of pre-flush, followed by 5 bbls fresh water spacer. Pump Surface Casing Shoe Plug: Pump 160
sx (34.5 bbl or 194 cf) of the Upper AGM blend: Class G with 0.4% B547 Gas Block (Latex) and 1.5% S001 CC (Calcium Chloride) and
4% D053 Expansion (Gyp). Volume is based on 50' in 4-1/2", 11.6# production casing with no excess. 226' in 7.875" bit size open
hole with 50% excess factor. 204' in the 8-5/8", 24# surface casing with no excess. The plug is designed to cover 1250'-770'.
Collect wet and dry samples of cement to be left on rig. RDMO Cementers. Notify engineering if circulation is ever lost during job.
50 COA: If cement was not circulated to surface, then WOC 4 hours. Tag TOC. TOC must be 924' or shallower. If tag is too deep or
there is evidence of pressure or fluid migration, contact Engineering.
51 Pull out of cement. TOOH to 370'. Forward circulate tbg clean with fresh water. TOOH & SB 300' of tubing. WOC 4 hours.
52 Note: Plug can be tagged after a 4 hour WOC, but must have a 6 hour WOC prior to pressure testing.
53 ND 7-1/16" BOP. NU 9" or 11" BOP. RIH with bit and scraper. Clean csg and tag TOC. Circulate Clean. POOH. PT casing to 500 psi.
Contact engineering if test fails.
54 Surface Plug
55 MIRU WL. PU and RIH with (8-5/8", 24#) CIBP and set at 300'. POOH. RDMO WL.
56
TIH with diverter tool on 2-3/8" tubing to 300'. Either swab well down or use rig air to remove water from well. (Note: Do not
exceed 175 psi if using rig air). If either methods cannot be performed, contact engineering to discuss excess cement volume for top
out plug.
57
DO NOT PUMP WATER AHEAD OF CEMENT. MIRU Cementers. Pump Surface Plug: Pump 90 sx (19.4 bbl or 109 cf) of the Surface
AGM blend: Class G with 0.4% B547 Gas Block (Latex) and 2% S001 CC (Calcium Chloride) and 4% D053 Expansion (Gyp). Volume
based on 300’ inside 8-5/8", 24# surface casing with no excess. Cement will be from 300' to surface. Verify and document cement
to surface. Collect wet and dry samples of cement to be left on rig.
58 TOOH and remove diverter tool. Insert ~5' of 2-3/8" Tbg. Circulate FW to clean Csg & Csg Valves. LD final joint of 2-3/8" Tbg. RDMO
cementers. ND BOP. Install night cap. RDMO WO rig.
59 Instruct cementing, tools and wireline contractors to e-mail copies of all job logs/job summaries to rscDJVendors@oxy.com within
24 hours of completion of the job.
60 Supervisor submit paper copies of all invoices, logs, and reports to Well Services Engineering Specialist.
61 Excavation crew to notify One Call to clear excavation area around wellhead and for flow lines.
62 Excavate hole around surface casing enough to allow welder to cut casing a minimum 5’ below ground level.
63 Welder cut casing minimum 5' below ground level.
64 Spot weld on steel marker plate. Marker should contain Well name, Well number, legal location (1/4 1/4 descriptor) and API
number.
65 Obtain GPS location data as per ECMC Rule 215 and provide to GPS Teams page and Oxy GIS database.
66 Properly abandon flow lines per Rule 1105. File electronic Form 42 and/or Form 44 once abandonment is complete.
67 Back fill hole with fill. Clean location, and level.
68 Submit Form 6 Subsequent Report to ECMC ensuring to provide 'As performed' WBD identifying operations completed.
API: 05-123-30569 CREATED BY:H. MKRTCHIAN DATE:Feb 15, 2024
WELL NAME: ADAM FARM 1-4 ELEVATION: 4899 QTRQTR:SWNE
COUNTY:WELD GROUND LEVEL: 4884 SEC:4
LATITUDE:40.1712852 MD:8125 TWN:2N
LONGITUDE:-105.0040662 PBMD:8088 RNG:68W
Existing DATUM: RKB Proposed
KB=15'
Hole Size/Depth 12-1/4" / 1006'90 sx cmt to surface
1.21 yld
Deepest water well in 1 mile - 700'300'
325 Sx Cmt
Surface Casing 8-5/8", 24#, J-55 set @ 974'160 sx 924'TOC
1.21 yld
Upper Pierre Aquifer Base 1095'1200'Cut casing
1250'BOC
TOC (from CBL)1255'
5 sx 1300'TOC in csg
1360'
135 sx 1390'Perfs/BOC
5 sx 4125'TOC in csg
Sussex NOT productive in 1 mile 4188'
Top 4218'95 sx 4218'Perfs/BOC
Base 4439'
Shannon Base 4801' - NOT productive in 1 mile
559 Sx Cmt: Stage 2 - DV Tool @ 5217'
BOC (from CBL)5248'
TOC (from CBL)6686'
5 sx 7160'TOC in csg
Niobrara Top 7249'7222'
Niobrara Perfs 7252' - 7392'95 sx 7252'Perfs/BOC
New Cement
Codell Perfs 7513' - 7529'Existing Cement
New CICR
Existing CICR
New CIBP
Existing CIBP
Treated Water
204 Sx Cmt Brine
Production Casing 4-1/2", 11.6#, I-80 set @ 8108'Mud
Hole Size/Depth 7-7/8" / 8125'Sand Plug