HomeMy WebLinkAboutBALDWIN, ROBERT UNIT 2 - Well Abandonment Report - Kerr McGee - 1/10/2024Casing Type Size of
Hole
Size of
Casing
Grade Wt/Ft Csg/Liner
Top
Setting
Depth
Sacks Cmt Cmt Btm Cmt Top Status
SURF 12+1/2 8+5/8 J-55 24 0 584 400 584 0 VISU
1ST 7+7/8 5+1/2 N-80 17 0 8032 375 8032 6142 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:
1350Estimated Depth:NoYesCasing to be pulled:
Other
Mechanical ProblemsProduction Sub-economicDryReason for Abandonment:
-104.90035040.172350 Longitude:
GPS Data:
Only Complete the Following Background Information for Intent to Abandon
2.3 11/02/2006GPS 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 4 Section:QtrQtr:
2 Well Number:
NWNW
County:WELD
Location:
ROBERT E BALDWIN UNITWell Name:
05-123-14801-00API 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:
47120OGCC Operator Number:
robbie.revas@state.co.usEmail:
Tel:(720) 661-7242Name:Revas, Robbie For "Intent" 24 hour notice required,
COGCC contact:
12/12/2023
Date Received:
Document Number:
DE ET OE ES
403622460
Formation Perf. Top Perf. Btm Abandoned Date Method of Isolation Plug Depth
CODELL 7371 7394
J SAND 7806 7860
Total: 2 zone(s)
Current and Previously Abandoned Zones
Type of Well Abandonment Report:
Page 1 of 5Date Run: 1/4/2024 Doc [#403622460] Well Name: ROBERT E BALDWIN UNIT 2
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 Depth3960
CICR Depth7435
sacks cmt on top.withCIBP #5: Depth
sacks cmt on top.withsacks cmt on top. CIBP #4: Depth90with300CIBP #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.534ft. to1350sacks half in. half out surface casing fromSet330
sacks. Leave at least 100 ft. in casing75ft. with1900Perforate and squeeze at
sacks. Leave at least 100 ft. in casing170ft. with4500Perforate and squeeze at
sacks. Leave at least 100 ft. in casing90ft. withPerforate and squeeze at 7165
ft. ft. tosks cmt fromSet
ft. 0ft. to300sks cmt fromSet90
ft. 1475ft. to1900sks cmt fromSet50
ft. 3700ft. to3960sks cmt fromSet30
ft. 7050ft. to7135sks cmt from10Set
sacks cmt on top.7310 with 4sacks cmt on top. CIBP #2: Depth4with7720CIBP #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: 1/4/2024 Doc [#403622460] Well Name: ROBERT E BALDWIN UNIT 2
7/3/2024Expiration Date:
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:1/4/2024
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:12/12/2023 Email:lorena_ruiz@oxy.com
CONDITIONS OF APPROVAL, IF ANY:
Page 3 of 5Date Run: 1/4/2024 Doc [#403622460] Well Name: ROBERT E BALDWIN UNIT 2
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 (3960'), operator must wait a
sufficient time to confirm static conditions.
3) After placing plug at 3960’ 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 1350’ 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 534’ or shallower and
provide at least 10 sx plug at the surface.
6) 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.
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 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.
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.
COA's provided by the operator as Best Management Practices under Technical Detail /
Comments:
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: 1/4/2024 Doc [#403622460] Well Name: ROBERT E BALDWIN UNIT 2
Attachment List
Att Doc Num Name
403622460 WELL ABANDONMENT REPORT (INTENT)
403622501 PROPOSED PLUGGING PROCEDURE
403622502 WELLBORE DIAGRAM
403644277 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
01/04/2024
Engineer 1) Deepest Water Well within 1 mile = 390’.
2) Fox Hills Bottom- 292’, per SB5.
01/04/2024
OGLA OGLA review complete.12/29/2023
Permit Confirmed as-drilled well location.
Production reporting up-to-date.
No other forms in process.
Confirmed productive intervals docnum: 79624.
Reviewed WBD and procedure.
Pass.
12/14/2023
Total: 4 comment(s)
General Comments
Page 5 of 5Date Run: 1/4/2024 Doc [#403622460] Well Name: ROBERT E BALDWIN UNIT 2
OCCIDENTAL PETROLEUM CORPORATION
Please contact your area engineer with any questions concerning this procedure.
12/11/2023
PLUG and ABANDONMENT PROCEDURE
BALDWIN, ROBERT UNIT 2 API: 05-123-14801
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 03/03/14. 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.
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
10
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 6158'. **Barrier Management** Fluid will be the
only barrier while NU BOP. Stop and review JSA.
11 TOOH and SB 7135' of 2-3/8" tbg. LD remaining 2-3/8" tbg and packer.
12 MIRU WL. PU and RIH with (5-1/2", 17#) gauge ring to 7760'. POOH.
13 PU and RIH with (5-1/2", 17#) CIBP and set at +/- 7750' . POOH. RIH and dump 4 sx cement on CIBP. POOH.
14 PU and RIH with (5-1/2", 17#) CIBP and set at +/- 7310' . POOH. RIH and dump 4 sx cement on CIBP. POOH.
15 NIO INJECTION SQUEEZE
16 PU and RIH with one 4', 3-1/8'' deep penetrating perf gun wth 4 spf. Shoot squeeze holes at 7165'. POOH. RDMO WL.
17 PU and TIH with (5-1/2", 17#) CICR on 2-3/8" tbg. Set CICR at 7135'.
18
MIRU cementers. Make sure the tubing annulus is loaded with water then attempt to establish injection max pressure 6160 psi with
water. If it won't inject then sting out, load tubing with cement a bbl short of EOT then sting back in, in the next step. Max
pressure is 3400 psi with tubing full of cement unless pressure is applied to annulus.
19
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 2 bbls. Volume is based on 30' in the casing below the CICR, cement squeezed into formation, and 85' on top of
the CICR. Collect wet and dry samples of cement to be left on rig. RDMO cementers.
20 Pull out of cement and reverse clean with 2x bottoms up. TOOH, SB 3960' of 2-3/8" tbg. LD remaining tbg.
21 SUSSEX ROLL-OVER
22 MIRU WL. PU and RIH with two 4', 3-1/8'' perf guns with 4 spf. Shoot 16 squeeze holes at 4500' and 16 squeeze holes at 3900'.
RDMO WL.
23 PU and TIH with (5-1/2", 17#) packer on 2-3/8" tbg. Set packer at 3960'.
24 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.
25
Pump 43 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.
26 Release packer. TOOH, SB 2-3/8" tbg. LD packer.
27 PU and TIH with (5-1/2", 17#) CICR on 2-3/8" tbg. Set CICR at 3960'.
28
MIRU cementers. Pump 10 bbls (min) of pre-flush, followed by 5 bbls fresh water spacer. Pump Sussex Squeeze: 200 sx (42.4 bbl or
238 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 6 bbls. Volume is based on 540' in the casing below the CICR, 600' 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.
29 Pull out of cement. TOOH to 3200’. Reverse circulate a minimum of 2 bottoms up.
30 TOOH and SB 1350' of 2-3/8" tbg. LD stinger, and remaining tbg.
31 UPPER PIERRE BALANCED CIRCULATION PLUG
32 MIRU WL. PU and RIH with one 4', 3-1/8'' perf gun with 4 spf. Shoot 16 squeeze holes at 1900'. RDMO WL.
33 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.
34 Pump 27 bbls of 160F HSF (0.5 gals/bbl or 1.5 lbs/bbl) and let soak for ~2 hours.
35 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.
36
MIRU cementers. Pump Squeeze: 125 sx (27 bbl or 152 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 425' in the casing-hole annulus
with 25% excess, and 425' in the casing. Displace cement with Water to 1475'. Collect wet and dry samples of cement to be left on
rig. RDMO Cementers.
37 Leave valves open to allow cement to balance between the production and surface casing.
38 TIH with 2-3/8" tubing and tag cement top to verify TOC inside production casing. TOOH and SB 1350' of tubing.
39 CUT AND PULL CASING
40 PU and TIH with mechanical cutter on 2-3/8" tbg. Cut 5-1/2", 17# casing at 1350'. TOOH and LD cutter.
41 Attempt to establish circulation with biocide treated fresh water. Circulate in 50 bbls of HSF and displace to the cut. Soak for 1+ hr
then circulate out. This will cover all remaining HSF needs for this well.
42 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.
43 Install BOP on casing head with 5-1/2", 17# pipe rams. **Barrier Management** Fluid will be the only barrier while NU BOP. Stop
and review JSA.
44 TOOH and LD all 5-1/2", 17# casing. Remove 5-1/2", 17# pipe rams and install 2-3/8" pipe rams.
45 SHOE PLUG
46 TIH with 2-3/8" tubing to 1350'. Establish circulation to surface with biocide treated fresh water.
47 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.
48 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.
49 COA: Verify and document that all pressure and fluid migration has been eliminated prior to placing the SC shoe plug at 1350'. If
there is evidence of pressure or fluid migration, contact Engineering.
50
MIRU cementers. Pump 10 bbls (min) of pre-flush, followed by 5 bbls fresh water spacer. Pump Surface Casing Shoe Plug: Pump 330
sx (71.2 bbl or 400 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 766' in 7.875" bit size open hole with 25% excess factor. 204' in the 8-5/8", 24#
surface casing with no excess. The plug is designed to cover 1350'-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.
51 COA: If cement was not circulated to surface, then WOC 4 hours. Tag TOC. TOC must be 534' or shallower. If tag is too deep or
there is evidence of pressure or fluid migration, contact Engineering.
52 Pull out of cement. TOOH to 300'. Circulate tbg clean with fresh water. TOOH & SB 300' of tubing. WOC 4 hours.
53 Note: Plug can be tagged after a 4 hour WOC, but must have a 6 hour WOC prior to pressure testing.
54 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.
55 SURFACE PLUG
56 MIRU WL. PU and RIH with (8-5/8", 24#) CIBP and set at 300'. POOH. RDMO WL.
57 TIH with 2-3/8" tubing to 300' .
58
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.
59 TOOH and 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.
60 Instruct cementing and wireline contractors to e-mail copies of all job logs/job summaries to DJVendors@oxy.com within 24 hours
of completion of the job.
61 Supervisor submit paper copies of all invoices, logs, and reports to Well Services Engineering Specialist.
62 Excavation crew to notify One Call to clear excavation area around wellhead and for flow lines.
63 Excavate hole around surface casing enough to allow welder to cut casing a minimum 5’ below ground level.
64 Welder cut casing minimum 5' below ground level.
65 Spot weld on steel marker plate. Marker should contain Well name, Well number, legal location (1/4 1/4 descriptor) and API
number.
66 Obtain marker plate GPS location data and provide to GPS Teams page and Oxy GIS database.
67 If applicable, abandon flow lines per Rule 1105. File electronic Form 42 and/or Form 44 once abandonment is complete.
68 Back fill hole with fill. Clean location, and level.
69 Submit Form 6 Subsequent Report to CECMC ensuring to provide 'As performed' WBD identifying operations completed.
API: 05-123-14801 CREATED BY:G. MACAULEY DATE:Dec 11, 2023
WELL NAME: BALDWIN, ROBERT UNIT 2 ELEVATION: 4875 QTRQTR:NWNW
COUNTY:WELD GROUND LEVEL: 4865 SEC:4
LATITUDE:40.1723519 MD:8030 TWN:2N
LONGITUDE:-104.9003626 PBMD:7985 RNG:67W
Existing DATUM: RKB Proposed
KB=10'
Hole Size/Depth 12-1/4" / 599'90 sx cmt to surface
1.21 yld
Deepest water well in 1 mile - 390'300'
330 sx 534'TOC
1.21 yld
400 Sx Cmt
Surface Casing 8-5/8", 24#, J-55 set @ 584'
1350'BOC
1350'Cut casing
Upper Pierre Aquifer Base 1405'
1.21 yld 1475'TOC in csg
50 sx 1475'TOC behind csg
In Csg
75 sx
Sqz'd 1900'Perfs/BOC
30 sx 3700'TOC in csg
Sussex Productive in 1 mile 3900'Perfs/TOC
Top 4232'3960'
Base 4452'170 sx
Shannon Base 4814' - NOT productive in 1 mile 1.19 yld 4500'Perfs/BOC
TOC (from CBL)6142'
10 sx 7050'TOC in csg
Niobrara Top 7115'7135'
90 sx 7165'Perfs/BOC
New Cement
Existing Cement
4 sx New CICR
7310'Existing CICR
Codell Perfs 7371' - 7394'New CIBP
4 sx Existing CIBP
J Sand Perfs 7806' - 7860'7750'Treated Water
375 Sx Cmt 7885'Brine
Production Casing 5-1/2", 17#, N-80 set @ 8032'Mud
Hole Size/Depth 7-7/8" / 8030'Sand Plug