HomeMy WebLinkAboutGREGERSON U 12-10 JI - Well Abandonment Report - Kerr McGee - 10/16/2024Casing 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 0 684 285 684 0 VISU
1ST 7+7/8 4+1/2 I-80 11.6 0 8178 230 8178 6920 CBL
S.C. 1.1 5005 180 5008 3900 CBL
Casing 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:
1300Estimated Depth:NoYesCasing to be pulled:
Other
Mechanical ProblemsProduction Sub-economicDryReason for Abandonment:
-104.94966940.151794 Longitude:
GPS Data:
Only Complete the Following Background Information for Intent to Abandon
2.3 03/31/2010GPS 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:2N 12Section:QtrQtr:
12-10 JI Well Number:
NWSE
County:WELD
Location:
GREGERSON UWell Name:
05-123-20786-00API 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) 515-1500Phone:
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:
10/16/2024
Date Received:
Document Number:
DE ET OE ES
403960510
Formation Perf. Top Perf. Btm Abandoned Date Method of Isolation Plug Depth
J SAND 7818 7854
Total: 1 zone(s)
Current and Previously Abandoned Zones
Type of Well Abandonment Report:
Page 1 of 5Date Run: 11/4/2024 Doc [#403960510] Well Name: GREGERSON U 12-10 JI
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:CASINGPlug Type:
Plug Tagged:CASINGPlug Type:
Plug Tagged:CASINGPlug Type:
Plug Tagged:CASING
Plug Tagged:
(Cast Iron Cement Retainer Depth)
CICR Depth
CICR Depth4117
CICR Depth7074
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.634ft. to1300sacks half in. half out surface casing fromSet315
sacks. Leave at least 100 ft. in casing120ft. with2000Perforate and squeeze at
sacks. Leave at least 100 ft. in casing95ft. with4147Perforate and squeeze at
sacks. Leave at least 100 ft. in casing95ft. withPerforate and squeeze at 7104
ft. ft. tosks cmt fromSet
ft. 0ft. to300sks cmt fromSet90
ft. 1500ft. to2000sks cmt fromSet40
ft. 4055ft. to4117sks cmt fromSet5
ft. 7010ft. to7074sks cmt from5Set
sacks cmt on top.300 with 90sacks cmt on top. CIBP #2: Depth2with7730CIBP #1: Depth
Plug Type:
NOTE: Two(2) sacks cement
required on all CIBPs.
Plugging Procedure for Intent and Subsequent Report
Surface Plug Setting Date:
Number of Days from Setting Surface Plug
to Capping or Sealing the Well:
Page 2 of 5Date Run: 11/4/2024 Doc [#403960510] Well Name: GREGERSON U 12-10 JI
5/3/2025Expiration Date:
Signage for P&As:
Prior to commencing operations, Kerr McGee 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.
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:11/4/2024
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:10/16/2024 Email:lorena_ruiz@oxy.com
CONDITIONS OF APPROVAL, IF ANY LIST
Page 3 of 5Date Run: 11/4/2024 Doc [#403960510] Well Name: GREGERSON U 12-10 JI
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 (2000'), operator must wait a
sufficient time to confirm static conditions.
3) After placing plug at 2000’ 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 1300’ 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 634’ 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.
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.
3 COAs
ATTACHMENT LIST
Att Doc Num Name
403960510 WELL ABANDONMENT REPORT (INTENT)
403960514 PROPOSED PLUGGING PROCEDURE
403960515 WELLBORE DIAGRAM
403980940 FORM 6 INTENT SUBMITTED
Total Attach: 4 Files
Page 4 of 5Date Run: 11/4/2024 Doc [#403960510] Well Name: GREGERSON U 12-10 JI
User Group Comment Comment Date
Engineer 1) Deepest Water Well within 1 mile = 532’.
2) Fox Hills Bottom- 183’, per SB5.
11/04/2024
OGLA Location Assessment review complete.11/04/2024
OGLA Due to proximity to a mapped wetland and/or surface water, 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.
11/04/2024
OGLA 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.
11/04/2024
OGLA COA's provided by the operator as Best Management Practices under Technical Detail /
Comments:
Signage for P&As:
Prior to commencing operations, Kerr McGee 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.
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.
11/04/2024
Permit selected PDOP from dropdown box
Verified as drilled lat/long
Verified completed intervals - 811355
Verified production reporting
pass
10/17/2024
Total: 6 comment(s)
General Comments
Page 5 of 5Date Run: 11/4/2024 Doc [#403960510] Well Name: GREGERSON U 12-10 JI
OCCIDENTAL PETROLEUM CORPORATION
Please contact your area engineer with any questions concerning this procedure.
9/13/2024
PLUG and ABANDONMENT PROCEDURE
GREGERSON U 12-10 JI API: 05-123-20786
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.
Gyro 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. **Barrier Management** Fluid will be the only barrier while NU BOP.
Stop and review JSA.
10 TOOH and SB 7074' 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 7740'. POOH.
12 PU and RIH with (4-1/2", 11.6#) CIBP and set at +/- 7730' (no CCL coverage here). POOH. RIH and dump 2 sx cement on CIBP.
POOH.
13 Niobrara Injection Squeeze
14 PU and RIH with one 4', 3-1/8'' deep penetrating perf gun wth 4 spf. Shoot squeeze holes at 7104'. POOH. RDMO WL.
15 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 7074'.
16 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.
17 Note: Do not exceed 40 bbls of cement on injection squeezes.
18
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
64' on top of the CICR. Collect wet and dry samples of cement to be left on rig. RDMO cementers.
19 Pull out of cement. TOOH, SB 4117' of 2-3/8" tbg. LD remaining tbg.
20 Sussex Injection Squeeze
21 PU and RIH with one 4', 3-1/8'' deep penetrating perf gun wth 4 spf. Shoot squeeze holes at 4147'. POOH. RDMO WL.
22 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 4117'.
23 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.
24 If gas is present, consider swabbing and venting before pumping injection squeeze.
25 Note: Do not exceed 40 bbls of cement on injection squeezes.
26
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 62' on top of the CICR. Collect wet and dry samples of
cement to be left on rig. RDMO Cementers.
27 TOOH and SB ' of 2-3/8" tbg. LD stinger, and remaining tbg.
28 Middle Pierre Circulation Squeeze
29 MIRU WL. PU and RIH with one 4', 3-1/8'' perf gun with 4 spf. Shoot 16 squeeze holes at 2000'. RDMO WL.
30 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.
31 Pump 35 bbls of 160F HSF (0.5 gals/bbl or 1.5 lbs/bbl) and let soak for ~2 hours.
32 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.
33
MIRU cementers. Pump Squeeze: 160 sx (34.5 bbl or 194 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) down the casing. Volume is based on 500' in the casing-hole annulus
with 30% excess, and 500' in the casing. Displace cement with Water to 1500'. Collect wet and dry samples of cement to be left on
rig. RDMO Cementers.
34 Leave valves open for 10 minutes to allow cement to balance between the production and surface casing. If 2 bbls or more of
displacement fluid flows back through the production casing, shut in well to ensure TOC remains at a workable depth.
35 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.
36 TIH with 2-3/8" tubing and tag cement top to verify TOC inside production casing. TOOH and SB 1300' of tubing.
37 SC Shoe Plug
38 PU and TIH with mechanical cutter on 2-3/8" tbg. Cut 4-1/2", 11.6# casing at 1300'. TOOH and LD cutter.
39 Attempt to establish circulation with biocide treated fresh water.
40 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.
41 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.
42 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.
43 TIH with diverter tool on 2-3/8" tubing to 1300'. Establish circulation to surface with biocide treated fresh water.
44 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.
45 Pump 68 bbls of 160F HSF (0.5 gals/bbl or 1.5 lbs/bbl) and let soak for ~2 hours.
46 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.
47 COA: Verify and document that all pressure and fluid migration has been eliminated prior to placing the SC shoe plug at 1300'. If
there is evidence of pressure or fluid migration, contact Engineering.
48
MIRU cementers. Pump 10 bbls (min) of pre-flush, followed by 5 bbls fresh water spacer. Pump Surface Casing Shoe Plug: Pump 315
sx (67.9 bbl or 382 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 616' in 7.875" bit size open hole with 30% excess factor. 304' in the 8-5/8", 24#
surface casing with no excess. The plug is designed to cover 1300'-380'. 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. Notify engineering if
circulation is ever lost during job.
49 COA: If cement was not circulated to surface, then WOC 4 hours. Tag TOC. TOC must be 634' or shallower. If tag is too deep or
there is evidence of pressure or fluid migration, contact Engineering.
50 Pull out of cement. TOOH to 300'. Forward circulate tbg clean with fresh water. TOOH & SB 300' of tubing. WOC 4 hours.
51 Note: Plug can be tagged after a 4 hour WOC, but must have a 6 hour WOC prior to pressure testing.
52 Surface Plug
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 PU and RIH with (8-5/8", 24#) CIBP and set at 300'.
55
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.
56
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.
57 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.
58 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.
59 Supervisor submit paper copies of all invoices, logs, and reports to Well Services Engineering Specialist.
60 Excavation crew to notify One Call to clear excavation area around wellhead and for flow lines.
61 Excavate hole around surface casing enough to allow welder to cut casing a minimum 5’ below ground level.
62 Welder cut casing minimum 5' below ground level.
63 Spot weld on steel marker plate. Marker should contain Well name, Well number, legal location (1/4 1/4 descriptor) and API
number.
64 Obtain GPS location data as per ECMC Rule 215 and provide to GPS Teams page and Oxy GIS database.
65 Properly abandon flow lines per Rule 1105. File electronic Form 42 and/or Form 44 once abandonment is complete.
66 Back fill hole with fill. Clean location, and level.
67 Submit Form 6 Subsequent Report to ECMC ensuring to provide 'As performed' WBD identifying operations completed.
API: 05-123-20786 CREATED BY:H. MKRTCHIAN DATE:Sep 13, 2024
WELL NAME: GREGERSON U 12-10 JI ELEVATION: 4876 QTRQTR:NWSE
COUNTY:WELD GROUND LEVEL: 4860 SEC:12
LATITUDE:40.151779 MD:8200 TWN:2N
LONGITUDE:-104.94965 PBMD:8163 RNG:68W
Existing DATUM: RKB Proposed
KB=16'
Hole Size/Depth 12-1/4" / 684'90 sx cmt to surface
1.21 yld
Deepest water well in 1 mile - 532'300'
285 Sx Cmt
Surface Casing 8-5/8", 24#, J-55 set @ 684'315 sx 634'TOC
1.21 yld
1300'BOC
Upper Pierre Aquifer Base 1300'1300'Cut casing
1.21 yld 1500'TOC in csg
40 sx 1500'TOC behind csg
In Csg
120 sx
Sqz'd 2000'Perfs/BOC
TOC (from CBL)3900'
5 sx 4055'TOC in csg
Sussex Productive in 1 mile 4117'
Top 4147'95 sx 4147'Perfs/BOC
Base 4383'
Shannon Base 4750' - NOT productive in 1 mile
180 Sx Cmt: Stage 2 - DV Tool @ 5005'
BOC (from CBL)5008'
TOC (from CBL)6920'
5 sx 7010'TOC in csg
Niobrara Top 7124'7074'
95 sx 7104'Perfs/BOC
New Cement
Existing Cement
2 sx New CICR
7730'Existing CICR
J Sand Perfs 7818' - 7854'New CIBP
Existing CIBP
Treated Water
230 Sx Cmt Brine
Production Casing 4-1/2", 11.6#, I-80 set @ 8178'Mud
Hole Size/Depth 7-7/8" / 8200'Sand Plug