HomeMy WebLinkAboutCARMA 22-36 - Well Abandonment Report - Kerr McGee - 1/29/2024Casing 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:
450Estimated Depth:NoYesCasing to be pulled:
Other
Mechanical ProblemsProduction Sub-economicDryReason for Abandonment:
-104.95542340.185672 Longitude:
GPS Data:
Only Complete the Following Background Information for Intent to Abandon
2.7 08/03/2011GPS Quality Value:Date of Measurement:
Latitude:
Type of GPS Quality Value:PDOP
90750Field Number:Field Name:WATTENBERG
Federal, Indian or State Lease Number:
Meridian:668W Range:Township:3N 36Section:QtrQtr:
22-36 Well Number:
SENW
County:WELD
Location:
CARMAWell Name:
05-123-31716-00API 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
christina_hirtler@oxy.comEmail:
Fax:
(720) 929-6301Phone:
Zip:80217-
3779
COState:DENVER
P O BOX 173779
Contact Name:
City:
Christina Hirtler
Address:
KERR MCGEE OIL & GAS ONSHORE LPName of Operator:
47120OGCC Operator Number:
craig.carlile@state.co.usEmail:
Tel:(970) 629-8279Name:Carlile, Craig For "Intent" 24 hour notice required,
COGCC contact:
12/12/2023
Date Received:
Document Number:
DE ET OE ES
403622157
Formation Perf. Top Perf. Btm Abandoned Date Method of Isolation Plug Depth
CODELL 7460 7478
J SAND 7912 7936
NIOBRARA 7194 7322
Total: 3 zone(s)
Current and Previously Abandoned Zones
Type of Well Abandonment Report:
Page 1 of 5Date Run: 12/29/2023 Doc [#403622157] Well Name: CARMA 22-36
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:CASINGPlug 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
1560
4230
CICR Depth7164
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
80Set sacks at surface
ft.400ft. to940sacks half in. half out surface casing fromSet65
sacks. Leave at least 100 ft. in casing95ft. with1590Perforate and squeeze at
sacks. Leave at least 100 ft. in casing95ft. with4260Perforate and squeeze at
sacks. Leave at least 100 ft. in casing95ft. withPerforate and squeeze at 7194
ft. 0ft. to260sks cmt fromSet80
ft. 940ft. to1000sks cmt fromSet5
ft. 1500ft. to1560sks cmt fromSet5
ft. 4170ft. to4230sks cmt fromSet5
ft. 7100ft. to7164sks cmt from5Set
sacks cmt on top.260 with 80sacks cmt on top. CIBP #2: Depth2with7900CIBP #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 J55 24 0 843 550 843 0 VISU
1ST 7+7/8 4+1/2 I80 11.6 0 8079 1035 8079 584 CBL
Surface Plug Setting Date:
Number of Days from Setting Surface Plug
to Capping or Sealing the Well:
Page 2 of 5Date Run: 12/29/2023 Doc [#403622157] Well Name: CARMA 22-36
6/28/2024Expiration Date:
Perforate and squeeze at1030ft. with 95sacks. Leave at least 100 ft. in casing 1000CICR Depth (Cast Iron Cement Retainer)
BMPs
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 COGCC Rules and applicable
orders and is hereby approved.
COGCC Approved:Date:12/29/2023
I hereby certify all statements made in this form are, to the best of my knowledge, true, correct, and complete.
Signed:Print Name:Christina Hirtler
Title:Regulatory Date:12/12/2023 Email:christina_hirtler@oxy.com
CONDITIONS OF APPROVAL, IF ANY:
Page 3 of 5Date Run: 12/29/2023 Doc [#403622157] Well Name: CARMA 22-36
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 940’ 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 793’ 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.
Due to proximity to surface water, Operator will review the stormwater program and
implement stormwater BMPs and erosion control measures as needed to prevent fine-
grained sediment and impacted stormwater runoff from entering surface water.
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.
COAs provided by Operator 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.
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.
6 COAs
Page 4 of 5Date Run: 12/29/2023 Doc [#403622157] Well Name: CARMA 22-36
Attachment List
Att Doc Num Name
403622157 WELL ABANDONMENT REPORT (INTENT)
403622195 PROPOSED PLUGGING PROCEDURE
403622197 WELLBORE DIAGRAM
403640256 FORM 6 INTENT SUBMITTED
Total Attach: 4 Files
User Group Comment Comment Date
Engineer If any changes during the plugging are needed, please email Steve Jenkins at
Steve.Jenkins@state.co.us. Since Curtis is moving over to the UIC group, I am taking
over his Intents.
Thanks,
Steve
12/29/2023
Engineer 1) Deepest Water Well within 1 mile = 50’.
2) Fox Hills Bottom- 230’, per SB5.
12/29/2023
OGLA OGLA review is complete.12/21/2023
Permit selected PDOP from dropdown box
Verified as drilled lat/long
Verified completed intervals - 400230330
Verified production reporting
pass
12/12/2023
Total: 4 comment(s)
General Comments
Page 5 of 5Date Run: 12/29/2023 Doc [#403622157] Well Name: CARMA 22-36
OCCCCIDENTAL PETROLEUM CORPORATION
Please contact yourur area engineer with any quesestitions concncerningng this procedure.e.
12/5/2023
PLUGUG and ABANDODONMENENT PROCEDURE
CACARMAMA 22-36 API:I: 05-123-31716
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 07/02/11. 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.
1010 TOOH and SB 7164' of 2-3/8" tbg. LD remaining 2-3/8" tbg.
1111 PU and RIH with (4-1/2", 11.6#) CIBP and set at +/- 7900' (collars at 7872' & 7914'). POOH. RIH and dump 2 sx cement on CIBP.
POOH.
1212 Use Existing Niobrara Perforations at 7194'.
1313 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 7164'.
1414 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.
1515 Note: Do not exceed 40 bbls of cement on injection squeezes.
1616
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, leaving 5 sx on top of CICR. Collect wet and dry samples of cement to be left on rig. RDMO
cementers.
1717 Pull tbg up to 6900' and reverse circulate 2x well volume until well is clean.
1818 Pull out of cement. TOOH, SB 4230' of 2-3/8" tbg. LD remaining tbg.
1919 PU and RIH with TWO 4', 3-1/8'' deep penetrating perf gun wth 4 spf. Shoot squeeze holes at 4260', 1590' and 1030'. POOH.
RDMO WL.
2020 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 4230'.
2121 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.
2222 If gas is present, consider swabbing and venting before pumping injection squeeze.
2323 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, leaving 5 sx on top
of CICR. Collect wet and dry samples of cement to be left on rig. RDMO Cementers.
25 Pull tbg up to 3970' and reverse circulate 2x well volume until well is clean.
26 TOOH and SB 1560' of 2-3/8" tbg. LD stinger, and remaining tbg.
27 PU and TIH with (4-1/2", 11.6#) packer on 2-3/8" tbg. Set packer at 1560'.
28 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.
29 Release packer. TOOH, SB 2-3/8" tbg. LD packer.
30 If gas is present, consider swabbing and venting before pumping injection squeeze.
31 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 1560'.
32 Note: Do not exceed 40 bbls of cement on injection squeezes.
33
MIRU cementers. Pump Squeeze: 100 sx (21.6 bbl or 121 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 1 bbls, leaving 5 sx on top of CICR. Collect wet and
dry samples of cement to be left on rig. RDMO Cementers.
34 the tbg or annulus.
35 TOOH and SB 1000' of 2-3/8" tbg. LD stinger, and remaining tbg.
36 COA: Prior to placing cement above the base of the Upper Pierre (1269'): verify that all fluid (liquid and gas) migration has been
eliminated. If evidence of fluid migration or pressure remains, contact ECMC Engineer for an update to plugging orders.
37 PU and TIH with (4-1/2", 11.6#) packer on 2-3/8" tbg. Set packer at 1000'.
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 100'.
42 Note: Do not exceed 40 bbls of cement on injection squeezes.
43
MIRU cementers. Pump Squeeze: 100 sx (21.6 bbl or 121 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 1 bbls, leaving 5 sx on top of CICR. Collect wet and
dry samples of cement to be left on rig. RDMO Cementers.
44 tbg or annulus.
45 TOOH and SB 940' of 2-3/8" tbg. LD stinger, and remaining tbg.
46 PU and TIH with mechanical cutter on 2-3/8" tbg. Tag TOC at ~ 940'. PT csg to 500 psi for 15 minutes.
47 Raise mechanical cutter on 2-3/8" tbg. Cut 4-1/2", 11.6# casing at 450'. TOOH and LD cutter.
48 Attempt to establish circulation with biocide treated fresh water.
49 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.
50 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.
51 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.
52 TIH with diverter tool on 2-3/8" tbg to 940'. Establish circulation to surface with biocide treated fresh water and circulate bottoms
up.
53 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.
54 Pump 30 bbls of 160F HSF (0.125 gals/bbl or 0.5 lbs/bbl) and let soak for ~1 hour.
55 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.
56 COA: Verify and document that all pressure and fluid migration has been eliminated prior to placing the SC shoe plug at 940'. If
there is evidence of pressure or fluid migration, contact Engineering.
57
MIRU cementers. Pump Surface Casing Shoe Plug: Pump 64 sx (15.1 bbl or 85 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 495' 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 940'-350'.
Plug length exceeds 500'. Consult with Foreman or Engineer on splitting up the plug. Collect wet and dry samples of cement to be
left on rig. RDMO Cementers.
58 COA: If cement was not circulated to surface, then WOC 4 hours. Tag TOC. TOC must be 400' or shallower. If tag is too deep or
there is evidence of pressure or fluid migration, contact Engineering.
59 Pull out of cement. TOOH to 260'. Forward circulate tbg clean with fresh water. TOOH & SB 260' of tubing. WOC 4 hours.
60 Note: Plug can be tagged after a 4 hour WOC, but must have a 6 hour WOC prior to pressure testing.
61 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.
62 MIRU WL. PU and RIH with (8-5/8", 24#) CIBP and set at 260'. POOH. RDMO WL.
63
TIH with diverter tool on 2-3/8" tubing to 260'. 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.
64
DO NOT PUMP WATER AHEAD OF CEMENT. MIRU Cementers. Pump Surface Plug: Pump 80 sx (17.3 bbl or 97 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
to surface. Collect wet and dry samples of cement to be left on rig.
65 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.
66 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.
67 Supervisor submit paper copies of all invoices, logs, and reports to Well Services Engineering Specialist.
68 Excavation crew to notify One Call to clear excavation area around wellhead and for flow lines.
69
70 Welder cut casing minimum 5' below ground level.
71 Spot weld on steel marker plate. Marker should contain Well name, Well number, legal location (1/4 1/4 descriptor) and API
number.
72 Obtain GPS location data as per ECMC Rule 215 and provide to GPS Teams page and Oxy GIS database.
73 Properly abandon flow lines per Rule 1105. File electronic Form 42 and/or Form 44 once abandonment is complete.
74 Back fill hole with fill. Clean location, and level.
75 Submit Form 6 Subsequent Report to ECMC ensuring to provide 'As performed' WBD identifying operations completed.
API: 05-123-31716 CREATED BY:A.SIMMONS DATE:Dec 5, 2023
WELL NAME: CARMA 22-36 ELEVATION: 4878 QTRQTR:SENW
COUNTY:WELD GROUND LEVEL: 4863 SEC:3636
LATITUDE:40.1856649 MD:8090 TWN:3N3N
LONGITUDE:-104.9554186 PBMD:8057 RNG:68W
Existing DATUM: RKB Proposed
KB=15'
Hole Size/Depth 12-1/4" / 858'80 sx cmt to surface
1.21 yld
Deepest water well in 1 mile - 50'260'
65 sx 400'TOC
TOC (from CBL)580'1.21 yld 450'Cut casing
550 Sx Cmt
Surface Casing 8-5/8", 24#, J-55 set @ 843'
940'BOC
5 sx 940'TOC in csg
1000'
95 sx 1030'Perfs/BOC
Upper Pierre Aquifer Base 1269'
5 sx 1500'TOC in csg
1560'
95 sx 1590'Perfs/BOC
5 sx 4170'TOC in csg
Sussex Productive in 1 mile 4230'
Top 4242'95 sx 4260'Perfs/BOC
Base 4445'
Shannon Base 4782' - NOT productive in 1 mile
5 sx 7100'TOC in csg
Niobrara Top 7187'7164'
Niobrara Perfs 7194' - 7322'95 sx 7194'Perfs/BOC
New Cement
Codell Perfs 7460' - 7478'Existing Cement
2 sx New CICR
7900'Existing CICR
J Sand Perfs 7912' - 7936'New CIBP
Existing CIBP
Treated Water
1035 Sx Cmt Brine
Production Casing 4-1/2", 11.6#, I-80 set @ 8079'Mud
Hole Size/Depth 7-7/8" / 8090'Sand Plug