HomeMy WebLinkAboutKUGEL 12-18 - Well Abandonment Report - Oxy - 6/10/2024Casing 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:
400Estimated Depth:NoYesCasing to be pulled:
Other
Mechanical ProblemsProduction Sub-economicDryReason for Abandonment:
-104.93570040.140280 Longitude:
GPS Data:
Only Complete the Following Background Information for Intent to Abandon
1.7 01/22/2010GPS Quality Value:Date of Measurement:
Latitude:
Type of GPS Quality Value:
90750Field Number:Field Name:WATTENBERG
Federal, Indian or State Lease Number:
Meridian:667W Range:Township:2N 18Section:QtrQtr:
12-18 Well Number:
SENW
County:WELD
Location:
KUGELWell Name:
05-123-14497-00API 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:
05/02/2024
Date Received:
Document Number:
DE ET OE ES
403777105
Formation Perf. Top Perf. Btm Abandoned Date Method of Isolation Plug Depth
CODELL 7494 7504
NIOBRARA 7198 7445
Total: 2 zone(s)
Current and Previously Abandoned Zones
Type of Well Abandonment Report:
Page 1 of 5Date Run: 5/13/2024 Doc [#403777105] Well Name: KUGEL 12-18
Technical Detail/Comments:
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: Plug Type:
Plug Tagged:CASINGPlug Type:
Plug Tagged:CASINGPlug Type:
Plug Tagged:CASING
Plug Tagged:
(Cast Iron Cement Retainer Depth)
CICR Depth
CICR Depth
1310
3980
CICR Depth7168
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.350ft. to700sacks half in. half out surface casing fromSet55
sacks. Leave at least 100 ft. in casing210ft. with1950Perforate and squeeze at
sacks. Leave at least 100 ft. in casing120ft. with4320Perforate and squeeze at
sacks. Leave at least 100 ft. in casing95ft. withPerforate and squeeze at 7198
ft. ft. tosks cmt fromSet
ft. ft. tosks cmt fromSet
ft. 1150ft. to1310sks cmt fromSet15
ft. 3720ft. to3980sks cmt fromSet20
ft. 6975ft. to7168sks cmt from15Set
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 0 620 445 620 0 VISU
1ST 7+7/8 4+1/2 L-80 11.6 0 7603 300 7603 6810 CBL
S.C. 1.1 5060 225 5070 4340 CBL
S.C. 1.2 1220 260 1220 440 CBL
Surface Plug Setting Date:
Number of Days from Setting Surface Plug
to Capping or Sealing the Well:
Page 2 of 5Date Run: 5/13/2024 Doc [#403777105] Well Name: KUGEL 12-18
11/12/2024Expiration Date:
Additional Plugging Information:
Perforate and squeeze at 730ft. with 95 sacks. Leave at least 100 ft. in casing 700 CICR Depth (Cast Iron Cement Retainer)
BPMs
Signage for P&As:
Prior to commencing operations, KMG will post signs in conspicuous locations. The signs will indicate plugging and abandonment
operations are being conducted, the well name, well, and the Operator’s contact information. Signs will be placed so as not to create
a potential traffic hazard.
Notifications:
Courtesy notifications will be sent to all parcel owners with building units within 1,500 feet of the location letting them know about out
plugging and abandonment operations and providing contact information for Kerr McGee's response line and online resources.
Wellbore Pressure:
In some cases, wellbore pressure drawdown operations may occur approximately 1-2 days prior to Move In Rig Up (MIRU) of the
workover rig. This is conducted to allow for reduced time that the workover rig is needed on location. These operations will be
conducted in accordance with Form 4 and/or Form 6 requirements.
Water:
Water will be placed on dirt access roads to mitigate dust as needed.
Lighting:
Operations are daylight-only; no lighting impacts are anticipated from operations.
Noise:
Operations will be in compliance with Table 423-1 requirements. Based off the rig sound signature, rig orientation will be considered
to reduce noise levels to nearby building units.
Environmental Concerns:
This location was reviewed using a desktop method to review publicly available wildlife data (including CPW & ECMC data) as well
as internal wildlife datasets and aerial imagery. All field personnel are trained to identify wildlife risks and raise concerns noticed
during operations with the KMOG Health, Safety, and Environment (HSE) department.
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.
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:5/13/2024
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:5/2/2024 Email:lorena_ruiz@oxy.com
CONDITIONS OF APPROVAL, IF ANY LIST
Page 3 of 5Date Run: 5/13/2024 Doc [#403777105] Well Name: KUGEL 12-18
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 405.e and
405.I.
2) Prior to placing the 700’ plug: verify that all fluid migration (liquid and gas) has been
eliminated. If evidence of fluid migration or pressure remains, contact ECMC Engineer
for an update to plugging orders.
3) After isolation has been verified, pump surface casing shoe plug. If cement is not
circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 570’ or shallower
and provide 10 sx plug at the surface.
4) Leave at least 100’ of cement in the wellbore for each plug without mechanical
isolation.
5) After cut 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.
6) With the Form 6 SRA operator must provide written documentation which positively
affirms each COA listed above has been addressed.
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.
Operator will implement measures to capture, combust, or control emissions 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 health, welfare and the environment. Due
to the proximity of residential building units (RBUs) all blowdown gasses will be
controlled.
Due to proximity of plugging and abandonment (P&A) operations to BUs, operator will
comply with Table 423 Maximum Permissible Noise Levels for residential land use.
Prior to initiating work, operator will install temporary sound walls, straw bales, or other
BMPs to dampen noise if necessary for compliance.
Due to close proximity to Residential Building Units (RBUs), prior to commencing
operations, at a minimum, the operator will provide an informational sheet to the
owners/occupants of the RBUs nearby and adjacent to the parcel with the well. The
sheet will include the operator's contact information and the nature, timing, and
expected duration of the P&A operations.
Page 4 of 5Date Run: 5/13/2024 Doc [#403777105] Well Name: KUGEL 12-18
Operator committed to the following Best Management Practices under the Technical
Detail/ Comments section on the Submit Tab:
Signage for P&As:
Prior to commencing operations, KMG will post signs in conspicuous locations. The
signs will indicate plugging and abandonment operations are being conducted, the well
name, well, and the Operator’s contact information. Signs will be placed so as not to
create a potential traffic hazard.
Notifications:
Courtesy notifications will be sent to all parcel owners with building units within 1,500
feet of the location letting them know about out plugging and abandonment operations
and providing contact information for Kerr McGee's response line and online resources.
Wellbore Pressure:
In some cases, wellbore pressure drawdown operations may occur approximately 1-2
days prior to Move In Rig Up (MIRU) of the workover rig. This is conducted to allow for
reduced time that the workover rig is needed on location. These operations will be
conducted in accordance with Form 4 and/or Form 6 requirements.
Water:
Water will be placed on dirt access roads to mitigate dust as needed.
Lighting:
Operations are daylight-only; no lighting impacts are anticipated from operations.
Noise:
Operations will be in compliance with Table 423-1 requirements. Based off the rig
sound signature, rig orientation will be considered to reduce noise levels to nearby
building units.
Environmental Concerns:
This location was reviewed using a desktop method to review publicly available wildlife
data (including CPW & ECMC data) as well as internal wildlife datasets and aerial
imagery. All field personnel are trained to identify wildlife risks and raise concerns
noticed during operations with the KMOG Health, Safety, and Environment (HSE)
department.
5 COAs
ATTACHMENT LIST
Att Doc Num Name
403777105 WELL ABANDONMENT REPORT (INTENT)
403777113 WELLBORE DIAGRAM
403777114 PROPOSED PLUGGING PROCEDURE
403788171 FORM 6 INTENT SUBMITTED
Total Attach: 4 Files
User Group Comment Comment Date
Engineer 1) Deepest Water Well within 1 mile = 532’.
2) Fox Hills Bottom- 328’, per SB5.
05/13/2024
OGLA Location Assessment Specialist (LAS) review complete. Well is not in a HPH and not near
surface waters or wetlands. Task passed.
05/09/2024
Permit Confirmed as-drilled well location.
Production reporting up-to-date.
No other forms in process.
Confirmed productive intervals docnum: 84357.
Reviewed WBD and procedure.
Pass.
05/08/2024
Total: 3 comment(s)
General Comments
Page 5 of 5Date Run: 5/13/2024 Doc [#403777105] Well Name: KUGEL 12-18
OCCIDENTAL PETROLEUM CORPORATION
Please contact your area engineer with any questions concerning this procedure.
3/28/2024
PLUG and ABANDONMENT PROCEDURE
KUGEL #12-18 API: 05-123-14497
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 02/19/15. 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. Release packer set at 7103'. **Barrier Management** Fluid will be the
only barrier while NU BOP. Stop and review JSA.
10 TOOH and SB 7168' of 2-3/8" tbg. LD remaining 2-3/8" tbg and packer.
11 PU and RIH with one 4', 3-1/8'' deep penetrating perf gun wth 4 spf. Shoot squeeze holes at 7198'. POOH. RDMO WL.
12 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 7168'.
13 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.
14 Note: Do not exceed 40 bbls of cement on injection squeezes.
15
MIRU cementers. Pump Niobrara Injection Squeeze: 110 sx (29.8 bbl or 168 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 3 bbls. Volume is based on 30' in the casing below the CICR, cement squeezed into formation, and
193' on top of the CICR. Collect wet and dry samples of cement to be left on rig. RDMO cementers.
16 Pull out of cement. TOOH, SB 3980' of 2-3/8" tbg. LD remaining tbg.
17 MIRU WL. PU and RIH with two 4', 3-1/8'' perf guns with 4 spf. Shoot 16 squeeze holes at 4320' and 16 squeeze holes at 3920'.
RDMO WL.
18 PU and TIH with (4-1/2", 11.6#) packer on 2-3/8" tbg. Set packer at 3980'.
19 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.
20
Pump 30 bbls of 160F HSF (0.5 gals/bbl or 1.5 lbs/bbl) and let soak for ~2 hours. 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.
21 Release packer. TOOH, SB 2-3/8" tbg. LD packer.
22 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 3980'.
23
MIRU cementers. Pump 10 bbls (min) of pre-flush, followed by 5 bbls fresh water spacer. Pump Sussex Squeeze: 140 sx (29.7 bbl or
167 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 4 bbls. Volume is based on 340' in the casing below the CICR, 400' in the casing-
hole annulus with 25% excess, and 260' on top of the CICR. Collect wet and dry samples of cement to be left on rig. RDMO
Cementers.
24 Pull out of cement. TOOH to 3220’. Reverse circulate a minimum of 2 hole volume after cementing to ensure no cement is left in
the tbg or annulus.
25 TOOH and SB 1310' of 2-3/8" tbg. LD stinger, and remaining tbg.
27 MIRU WL. PU and RIH with two 4', 3-1/8'' perf guns with 4 spf. Shoot 16 squeeze holes at 1950' and 16 squeeze holes at 1250'.
RDMO WL.
28 PU and TIH with (4-1/2", 11.6#) packer on 2-3/8" tbg. Set packer at 1310'.
29 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.
30 Pump 49 bbls of 160F HSF (0.5 gals/bbl or 1.5 lbs/bbl) and let soak for ~2 hours.
31 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.
32 Release packer. TOOH, SB 2-3/8" tbg. LD packer.
33 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 1310'.
34
MIRU cementers. Pump 10 bbls (min) of pre-flush, followed by 5 bbls fresh water spacer. Pump Squeeze: 225 sx (48.5 bbl or 273 cf)
of the Lower AGM blend: Class G with 0.4% B547 Gas Block (Latex) and 1% S001 CC (Calcium Chloride) and 4% D053 Expansion
(Gyp). Underdisplace by 2.5 bbls. Volume is based on 640' in the casing below the CICR, 700' in the casing-hole annulus with 25%
excess, and 160' 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 1050’. Reverse circulate a minimum of 2 hole volume after cementing to ensure no cement is left in
the tbg or annulus.
36 MIRU WL. PU and RIH with one 4', 3-1/8'' deep penetrating perf gun wth 4 spf. Shoot squeeze holes at 730'. POOH. RDMO WL.
37 PU and TIH with (4-1/2", 11.6#) packer on 2-3/8" tbg. Set packer at 700'.
38 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.
39 Release packer. TOOH, SB 2-3/8" tbg. LD packer.
40 If gas is present, consider swabbing and venting before pumping injection squeeze.
41 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 700'.
42 Note: Do not exceed 40 bbls of cement on injection squeezes.
43
MIRU cementers. Pump Squeeze: 95 sx (20.5 bbl or 115 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). Underdisplace by 0 bbls. Volume is based on 30' in the casing below
the CICR, cement squeezed into formation, and 0' on top of the CICR. Collect wet and dry samples of cement to be left on rig.
44 TOOH and SB 700' of 2-3/8" tbg. LD stinger, and remaining tbg.
45 PU and TIH with mechanical cutter on 2-3/8" tbg. Cut 4-1/2", 11.6# casing at 400'. TOOH and LD cutter.
46 Attempt to establish circulation with biocide treated fresh water.
47 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.
48 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.
49 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.
50 TIH to 700'. Establish circulation to surface with biocide treated fresh water and circulate bottoms up.
51 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.
52 COA: Verify and document that all pressure and fluid migration has been eliminated prior to placing the SC shoe plug at 700'. If
there is evidence of pressure or fluid migration, contact Engineering.
53
MIRU cementers. Pump Surface Casing Shoe Plug: Pump 55 sx (11.9 bbl or 67 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 is based on 300' in 4-1/2", 11.6#
production casing with no excess. 100' in the 8-5/8", 24# surface casing with no excess. The plug is designed to cover 700'-300'.
Collect wet and dry samples of cement to be left on rig. RDMO Cementers.
54 COA: If cement was not circulated to surface, then WOC 4 hours. Tag TOC. TOC must be 440' or shallower. If tag is too deep or
there is evidence of pressure or fluid migration, contact Engineering.
55 Pull out of cement. TOOH to 300'. Forward circulate tbg clean with fresh water. TOOH & SB 300' of tubing. WOC 4 hours.
56 Note: Plug can be tagged after a 4 hour WOC, but must have a 6 hour WOC prior to pressure testing.
57 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.
58 MIRU WL. PU and RIH with (8-5/8", 24#) CIBP and set at 300'. POOH. RDMO WL.
59
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.
60
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.
61 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.
62 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.
63 Supervisor submit paper copies of all invoices, logs, and reports to Well Services Engineering Specialist.
64 Excavation crew to notify One Call to clear excavation area around wellhead and for flow lines.
65 Excavate hole around surface casing enough to allow welder to cut casing a minimum 5’ below ground level.
66 Welder cut casing minimum 5' below ground level.
67 Spot weld on steel marker plate. Marker should contain Well name, Well number, legal location (1/4 1/4 descriptor) and API
number.
68 Obtain GPS location data as per ECMC Rule 215 and provide to GPS Teams page and Oxy GIS database.
69 Properly abandon flow lines per Rule 1105. File electronic Form 42 and/or Form 44 once abandonment is complete.
70 Back fill hole with fill. Clean location, and level.
71 Submit Form 6 Subsequent Report to ECMC ensuring to provide 'As performed' WBD identifying operations completed.
API: 05-123-14497 CREATED BY: C. MARTIN DATE: May 2, 2024
WELL NAME: KUGEL #12-18 ELEVATION: 4961 QTRQTR: SENW
COUNTY: WELD GROUND LEVEL: 4950 SEC: 18
LATITUDE: 40.14028 MD: 7609 TWN: 2N
LONGITUDE:-104.9357 PBMD:7581 RNG:67W
Existing DATUM: RKB Proposed
KB=11'
Hole Size/Depth 12-1/4" / 625'90 sx cmt to surface
1.21 yld
300'
350' TOC
TOC (from CBL)440'400'Cut casing
Deepest water well in 1 mile - 532'
Surface Casing 8-5/8", 24#, J-55 set @ 620'55 sx
445 Sx Cmt 1.21 yld
700'
95 sx 730' Perfs/BOC
260 sx cmt BOC (from CBL) 1220'15 sx 1150' TOC in csg
1250' Perfs/TOC
1310'
Upper Pierre Aquifer Base 1458'210 sx
1.21 yld 1950' Perfs/BOC
20 sx 3720' TOC in csg
3920' Perfs/TOC
3980'
Sussex Productive in 1 mile 120 sx
Top 4310'1.19 yld 4320'Perfs/BOC
TOC (from CBL) 4340'
Base 4520'
Shannon Base 4891' - Productive in 1 mile
225 Sx Cmt: Stage 2 - DV Tool @ 5060'
BOC (from CBL) 5070'
TOC (from CBL)6810'
15 sx 6975' TOC in csg
Niobrara Top 7184'7168'
Niobrara Perfs 7198' - 7445'95 sx 7198' Perfs/BOC
New Cement
Codell Perfs 7494' - 7504' Existing Cement
New CICR
Existing CICR
New CIBP
Existing CIBP
Treated Water
300 Sx Cmt Brine
Production Casing 4-1/2", 11.6#, L-80 set @ 7603' Mud
Hole Size/Depth 7-7/8" / 7609'Sand Plug