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Alaska Oil and Gas Conservation Commission
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Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 5/08/2025
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20250508
Well API #PTD #Log Date Log
Company Log Type AOGCC
E-Set#
BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf
BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf
IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP
PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF
SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP
PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM
END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG
END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL
END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40
MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL
NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT
PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT
PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT
PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG
PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG
PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT
PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT
PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF
PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF
PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF
Please include current contact information if different from above.
T40372
T40373
T40374
T40375
T40376
T40377
T40378
T40379
T40379
T40380
T40381
T40382
T40383
T40384
T40385
T40386
T40387
T40388
T40389
T40390
PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.05.08 12:42:44 -08'00'
7. Property Designation (Lease Number):
1. Operations
Performed:
2. Operator Name:
3. Address:
4. Well Class Before Work:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
Susp Well Insp
Install Whipstock
Mod Artificial Lift Perforate New Pool
Perforate
Plug Perforations
Coiled Tubing Ops
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well Other:
Change Approved Program
Operations shutdown
11. Present Well Condition Summary:
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
16. Well Status after work:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
OIL GAS
WINJ WAG GINJ
WDSPL
GSTOR Suspended SPLUG
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
PBU 14-33B
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
223-067
50-029-21002-02-00
13914
Surface
Intermediate
Liner
Liner
Liner
9011
2744
11345
390
590
2951
13899
13-3/8"
9-5/8"
7"
3-1/2" x 3-3/16"
2-3/8"
9005
28 - 2772
26 - 11371
11070 - 11460
11062 - 11652
10963 - 13914
28 - 2698
26 - 8527
8349 - 8577
8344 - 8733
8279 - 9011
None
2670
4760
7020
10540
11780
None
4930
6870
8160
10160
11200
13770 - 13830
4-1/2" 12.6# L-80 24 - 11124
8958 - 8979
Conductor 81 20" 29 - 110 29 - 110 1490 470
4-1/2" Baker SB-3A , 11009 , 8310
No SSSV Installed
11009
8310
Bo York
Operations Manager
Jerry Lau
Jerry.Lau@hilcorp.com
907.564.5280
PRUDHOE BAY, PRUDHOE OIL
Total Depth
Effective Depth
measured
true vertical
feet
feet
feet
feet
measured
true vertical
measured
measured
feet
feet
feet
feet
measured
true vertical
Plugs
Junk
Packer
Measured depth
True Vertical depth
feet
feet
Perforation depth
Tubing (size, grade, measured and true vertical depth)
Packers and SSSV
(type, measured and true vertical depth)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Exploratory Development Service StratigraphicDaily Report of Well Operations
Copies of Logs and Surveys Run
Electronic Fracture Stimulation Data
Sundry Number or N/A if C.O. Exempt:
ADL 0028311 , 0028312
24 - 8383
108
405
7912
8480
335
1031
1925
920
249
292
N/A
13b. Pools active after work:PRUDHOE OIL
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Sr Pet Eng: Sr Pet Geo:
Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Sr Res Eng:
Due Within 30 days of Operations
By Gavin Gluyas at 10:30 am, Feb 20, 2025
Digitally signed by Bo York
(1248)
DN: cn=Bo York (1248)
Date: 2025.02.19 16:55:12 -
09'00'
Bo York
(1248)
DSR-2/20/25JJL 2/27/25
ACTIVITYDATE SUMMARY
1/21/2025
LRS CTU #1, 1.5" Coil, 0.134" WT. Job Objective: Drift, RPM, CBL GR/CCL, &
Adperfs
Travel to DS14. MIRU CTU. M/U NS MHA w/1.75" drift. FP flowline to manifold
building w/90bbls diesel. RIH. Load well with 190bbls safelube, cap with 6bbls 60/40
and 6bbls diesel. Dry drift down to 13,934CTM. POOH
***Continue on WSR 1/22/25***
1/22/2025
LRS CTU #1, 1.5" Coil, 0.134" WT. Job Objective: Drift, RPM, CBL GR/CCL, &
Adperfs
Finish POOH w/ 1.75" DJN Drift. MU Baker Atlas RPM Tool. RIH to Flag. 13,896'
CTM. Log up 20 fpm to 11,500' CTM 1st logging pass. RIH to Flag 13,896' CTM.
2nd logging Pass up 20 fpm. Flag @ 13,729.83' Atlas Box. Log up 20 fpm 11,500'
CTM. POOH. BD Baker Atlas RPM Tools. Verify Data Good - standby for data get
processed. PT MHA 3500 psi. MU HES gamma/CCL RIH.
***Job continued 1/23/25***
1/23/2025
LRS CTU #1, 1.5" Coil, 0.134" WT. Job Objective: Drift, RPM, CBL GR/CCL, &
Adperfs ***Job continued from 1/22/25***
RIH w/ HES gamma/CCL memory logging tool. Tag bottom. Perform tie in log, flag
coil 13719 CTM. POOH. Good data at surface, -7' correction. MU HES 1.56"
Millennium Perf Guns (24' loaded). RIH to flag & Corr Depth. Perforate 13,770' -
13,794'. POOH. BD HES spent perf guns. RDMO.
***Job Complete***
Daily Report of Well Operations
PBU 14-33B
7. Property Designation (Lease Number):
1. Operations
Performed:
2. Operator Name:
3. Address:
4. Well Class Before Work:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
Susp Well Insp
Install Whipstock
Mod Artificial Lift Perforate New Pool
Perforate
Plug Perforations
Coiled Tubing Ops
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well Other:
Change Approved Program
Operations shutdown
11. Present Well Condition Summary:
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
16. Well Status after work:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
OIL GAS
WINJ WAG GINJ
WDSPL
GSTOR Suspended SPLUG
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
PBU 14-33B
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
223-067
50-029-21002-02-00
13914
Surface
Intermediate
Liner
Liner
Liner
9011
2744
11345
390
590
2951
13899
13-3/8"
9-5/8"
7"
3-1/2" x 3-3/16"
2-3/8"
9005
28 - 2772
26 - 11371
11070 - 11460
11062 - 11652
10963 - 13914
28 - 2698
26 - 8527
8349 - 8577
8344 - 8733
8279 - 9011
None
2670
4760
7020
10540
11780
None
4930
6870
8160
10160
11200
13800 - 13830
4-1/2" 12.6# L-80 24 - 11124
8969 - 8979
Conductor 81 20" 29 - 110 29 - 110 1490 470
4-1/2" Baker SB-3A Packer 11009, 8310
11009
8310
Bo York
Operations Manager
Jerry Lau
Jerry.Lau@hilcorp.com
907.564.5280
PRUDHOE BAY, PRUDHOE OIL
Total Depth
Effective Depth
measured
true vertical
feet
feet
feet
feet
measured
true vertical
measured
measured
feet
feet
feet
feet
measured
true vertical
Plugs
Junk
Packer
Measured depth
True Vertical depth
feet
feet
Perforation depth
Tubing (size, grade, measured and true vertical depth)
Packers and SSSV
(type, measured and true vertical depth)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Exploratory Development Service StratigraphicDaily Report of Well Operations
Copies of Logs and Surveys Run
Electronic Fracture Stimulation Data
Sundry Number or N/A if C.O. Exempt:
ADL 0028311 , 0028312
24 - 8383
N/A
N/A
328
464
1019
914
1601
2265
1527
1650
345
245
N/A
13b. Pools active after work:PRUDHOE OIL
No SSSV Installed
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Sr Pet Eng: Sr Pet Geo:
Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Sr Res Eng:
Due Within 30 days of Operations
By Grace Christianson at 1:25 pm, Nov 08, 2023
Digitally signed by Bo York
(1248)
DN: cn=Bo York (1248)
Date: 2023.11.08 12:38:01 -
09'00'
Bo York
(1248)
RBDMS JSB 111623
DSR-11/15/23WCB 3-14-2024
ACTIVITY DATE SUMMARY
10/10/2023
LRS CTU #1, 1.5" Blue Coil, Job Scope: Perforate
MIRU. BOPs function tested upon installation. Freeze protect flowline with 4 bbl of
60/40. RIH with 1.75" drift BHA.
***Job in Progress***
10/11/2023
LRS CTU #1, 1.50" Blue Coil. Job Scope: Perforate
Continue RIH with 1.75" drift BHA and tag PBTD at ~ 13888' CTM. POOH and MU 1-
11/16" HES GR/CCL toolstring. RIH and log from PBTD to ~ 12700' at 50 FPM. Paint
yellow flag at 13797'. POOH and confirm good data (+7' correction). RIH with 1.56" x
30' GeoRazor, 6 SPF, 60 degree phase gun and perforate 13800' - 13830'. POOH
and complete FP of the tubing. RDMO CTU.
***Job Complete***
Daily Report of Well Operations
PBU 14-33B
()
perforate 13800' - 13830'. POOH
Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 10/27/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20231027
Well API #PTD #Log Date Log
Company Log Type AOGCC Eset#
PBU 06-08C 50029203000300 223068 10/1/2023 BAKER MRPM
PBU 14-33B 50029210020200 223067 9/17/2023 BAKER MRPM
PBU B-14A 50029203490100 209059 9/6/2023 BAKER SPN
PBU JX-02A 50029214550100 194154 9/19/2023 BAKER SPN
PBU L2-24 50029213460000 185090 9/2/2023 BAKER SPN
Please include current contact information if different from above.
T38106
T38107
T38108
T38109
T38110
10/27/2023
PBU 14-33B 50029210020200 223067 9/17/2023 BAKER MRPM
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.10.27
15:14:18 -08'00'
Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 10/10/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20231010
Well API #PTD #Log Date Log
Company Log Type AOGCC Eset#
PBU 06-08C 50029203000300 223068 10/2/2023 HALLIBURTON RBT
PBU 14-33B 50029210020200 223067 9/17/2023 HALLIBURTON RBT
Please include current contact information if different from above.
T38046
T38047
10/11/2023
PBU 14-33B 50029210020200 223067 9/17/2023 HALLIBURTON RBT
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.10.11
09:32:17 -08'00'
David Douglas Hilcorp North Slope, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Hilcorp North Slope, LLC
Date: 10/05/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: PBU 14-33B
PTD: 223-067
API: 50-029-21002-02-00
FINAL LWD FORMATION EVALUATION LOGS (09/07/2023 to 09/12/2023)
Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs)
Pressure While Drilling (PWD)
Final Definitive Directional Surveys
SFTP Transfer - Data Folders:
Please include current contact information if different from above.
PTD: 223-067
T38040
10/6/2023
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.10.06
09:05:17 -08'00'
3-1/2"x3-3/16"
By Grace Christianson at 3:00 pm, Oct 05, 2023
Completed
9/17/2023
JSB
RBDMS JSB 101123
GDSR-11/2/23
Drilling Manager
10/04/23
Monty M
Myers
Digitally signed by Bo York
(1248)
DN: cn=Bo York (1248)
Date: 2023.10.04 17:20:55 -
08'00'
Bo York
(1248)
Activity Date Ops Summary
9/5/2023 On location with rig. Complete and sign off location condition report with Drill Site Operator. Remove jeeps. Spot both modules over well. Accept rig at 03:30. Safe
out rig. R/U cellar. R/U PUTZ.
9/6/2023 Continue MIRU Ops Checklist. NU MPD Line and BOPE. Fluid pack surface lines and test Gas alarms. Test BOPs as per AOGCC and Hilcorp Req. Test is witness
waived by AOGCC Inspector Adam Earl. All tests 250 / 3500 psi. Test 1: IRV, Stripper, C7, C9, C10, C11 - Pass. Test 2: Blind / Shear, R2, BL2, C15 - Pass. Test
3: Annular (2-3/8"), TIW1, B1, B4 - B1 F/P (Grease). Test 4: Upper 2" Pipe / Slip, TIW2, B2, B3 - Pass. Test 5: Lower 2" Pipe / Slip, C5, C6, C8, TV2 - Pass. Test 6:
Choke A, Choke C - Pass. Test 7: 2-3/8" Pipe / Slip, C1, C4, TV1 - Pass. Test 8: C2, C3 - Pass. Drawdown test - Good. Test PDLs, good. Install floats in UQC.
Inspect packoffs, some rubber seen on CT connector. PT floats, packoffs together, good. Sequence valve on 2-3/8" Pipe / Slip rams is leaking, change it out.
Function test 2-3/8" rams, good. PT riser break. Circ MeOH across top then open well, 90 psi. Bleed off then shut in, very slight pressure build. Circ 10 bbls MeOH
to end of CT. Skid injector back. M/U BHA #1 in PDL - Whipstock. RIH and close 2-3/8" rams. M/U injector. RIH BHA #1. Set pump and slackoff trips close for
whipstock.
9/7/2023 Continue RIH w/WS BHA. Log tie in from 11410'. Can't tie in to gamma, gamma is pegged out possibly from scale and it looks like it started at ~4000'. PUH and log
CCL from 10800' (above GLM #1) to 11300' (below TOL & X-Nipple from 14-33A completion). Displace well with Hot KCl then swap to mud. TOL from 14-33A at
11,046', CNL used for WS placement shows TOL at 11,055'. Correct depth +9'. Continue swapping well over to mud then RIH and log CCL to verify we are on
depth with collars to set the WS. Well swapped to mud, PUH to 11400' and log CCL to a light tag at the CIBP. Tag CIBP at 11664', 16' shallower, verify collars with
CCL Log. +6.5' correction to get on depth with the collars in the setting area. PUH to set WS. On depth at 11645' (TOWS) 11656.2' bit depth,. PU WT = 38k, PU to
34k and stop. Close the EDC and pressure up to set WS. Setting tool sheared at 3200psi, set down 5.3k WOB with no movement. Open EDC and POOH for milling
BHA. OOH, flow check well. Good no flow, remove injector and LD the WS Setting BHA. RIH with the Milling BHA. Tie-in depth (CCL) from 10950' correct +7'. Up
wt 11600' is 37k. Close EDC. Ease down, dry tag WS 11658'. P/U and start milling. Discuss depth with ODE, will finish window and do another tie-in. Mill 2.74"
window from 11657.5' to 11661.8'. 1.82 / 1.83 bpm In / Out. 8.98 / 8.98 ppg. ECD = 9.65 ppg on open choke. Drill rathole from 11662.5' to 11672'. 5 bbls lo/hi vis
sweeps. Confirm formation in samples. Conduct reaming passes, no motor work seen. Dry drift is clean. Pick up to 11430' ream up 2 ft/min to clean scale to get a
GR tie-in. Log down past old RA, correct -5'. RIH tag 11654' at min rate, and 1 bpm. Go to 1.5 bpm and wash through tag rathole 11667' puts TOW at 11652.5'
BOW at 11656.8'. Try to dry drift window tag 11654'. Close EDC conduct additional reaming passes 6x. Getting MW at 11653' TOW going down. Dry drift is clean.
Open EDC, POOH.
9/8/2023 Continue POOH with the milling BHA. OOH, shut down pump, IA x TBG communication IAP = 517psi, bled down to 447psi,flow check well. LD the milling BHA,
gauge mills 2.74" Go - 2.73" No Go. MU a nozzle and Jet BOP Stack. MU the build BHA. RIH with build BHA. Log tie in to Sag & RA Marker. No correction??? RIH,
tag in the window, PU, RIH and tag bottom on depth. Drill 3.25" lateral from 11,667'. Free spin: 3160 psi, 1.80 bpm. Rate: 1.75 bpm in, 1.91 bpm out. Circ pressure:
3345. Mud weight: 8.96 ppg in, 8.97 ppg out, Window ECD: 9.65 ppg. ROP: 88 fph, WOB: 1.1 K. Drill 3.25" lateral from 11,850' to 11861'. Free spin: 3160 psi,
1.80 bpm. Rate: 1.98 bpm in, 2.03 bpm out. Circ pressure: 3309. Mud weight: 8.97 ppg in, 8.97 ppg out, Window ECD: 9.68 ppg. ROP: 10 fph, WOB: 1.7 K. Drill
to TD of build 11861'. Pump 5 bbls lo/hi vis. Wiper trip to window, clean. Jog below window pull through 0.4 bpm see -4k DWOB 11665' about 8' below window.
Jog above window open EDC. POOH keep 9.8# ECD at window. Undeploy BHA #3 - Build. Bit is 4-4. Pressure deploy BHA #4 - Lateral Drilling. After M/U UQC the
Coiltrak tool doesn't test. Undeploy BHA #4. P/U new upper section. Deploy BHA #4 - Lateral Drilling. RIH BHA #4 keep 9.8# ECD at window. Tie-in depth from
11425' correct -1'. Close EDC. Pass window see 1.2k DWOB 11653' push past. Log RA. RIH to bottom. Drill 3.25" lateral from 11861'. 1.83 / 1.80 bpm In / Out.
8.97 / 8.99 ppg. Pcirc 2900 - 3100 psi. Window ECD = 9.83 ppg w/ 73 psi WHP. ROP 30-40 ft/hr w/ 1-3k DWOB.
9/9/2023 11980' lost 100% returns for ~30 seconds then slowly started coming back. Drill 3.25" lateral from 11,990'. Free spin: 3160 psi, 1.80 bpm. Rate: 1.86 bpm in, 1.77
bpm out loss rate = 5.4. Circ pressure: 3268. Mud weight: 8.99 ppg in, 8.95 ppg out, Window ECD: 9.69 ppg. ROP: 48 fph, WOB: 1.45 K. ~12280' ROP slowing
down might be at he fault. Free spin: 3160 psi, 1.85 bpm. Rate: 1.88 bpm in, 1.77 bpm out loss rate = 5.4. Circ pressure: 3356. Mud weight: 8.98 ppg in, 8.99 ppg
out, Window ECD: 9.79 ppg. ROP: 35 fph, WOB: 1.78 K. Drilled 450', pull wiper to the window. Jog at the window, Pull through window, open EDC and chase
cuttings up to the TOL. Circ a bottoms up while tying in, correct depth +5', close EDC and RIH to continue drilling. Back on bottom drilling. Free spin: 3213 psi, 1.93
bpm. Rate: 1.88 bpm in, 1.77 bpm out loss rate = 5.4. Circ pressure: 3356. Mud weight: 8.98 ppg in, 8.99 ppg out, Window ECD: 9.79 ppg. ROP: 35 fph, WOB:
1.78 K. 12462' 5 bbls lo/hi vis. 150' wiper from 12500' clean up/down. Drill 3.25" lateral from 12500'. 1.88 / 1.79 bpm Pcirc 3040 - 3240 psi. 8.96 / 9.02 ppg.
Window ECD = 9.83 ppg w/ open choke. 12536', 12630' 5 bbls lo/hi vis. 150' wiper from 12650' clean up/down. Drill 3.25" lateral from 12650'. 1.83 / 1.79 bpm
Pcirc 3080 - 3190 psi. 8.97 / 9.01 ppg. Window ECD = 9.82 ppg w/ open choke. 12730' 5 bbls lo/hi vis. Drill to 12761' no further progress. Not much motor work.
POOH for bit. Pump 5 bbls lo/hi vis.
9/10/2023 Continue POOH at 7700'. OOH, shut down pumps holding 330psi WHP to maintain 9.8 ECD at the window. PUD the BHA. Bit grade = 5-5-RO. Change out bits
and add an Agitator. PD BHA, with new HYC 3.25" Bi-Center Bit and Agitator. BHA deployed. Shallow hole test Agitator, good test, RIH. Tie in, correct depth -2',
RIH. Pass through the window, a little WOB. Continue drilling 3.25" lateral from 12757''. Free spin: 3980 psi, 1.82 bpm, Circ pressure: 4136 psi. Rate: 1.82 bpm in,
1.77 bpm out loss rate = 3.0 bph. Mud weight: 8.98 ppg in, 8.99 ppg out, Window ECD: 9.79 ppg. ROP: 40 fph, WOB: 1.64 K. 12802' losing returns. 12809' 100%
losses. 12814' loss rate at 0.2 bpm. 12824' 1.2 bpm. 12833' losses back to 0.2 bpm. 12854' lost rate at 0.5 bpm. 12860', loss rate consistent at 0.5 bpm, PUH to
12750' above the loss zones. PU to 12750' is clean still losing 0.5 bpm, RIH to continue drilling. 12950' pull 150' wiper trip. Drill 3.25" lateral from 13000'. 1.82 /
1.63 bpm Pcirc 3800 - 4100 psi. 8.97 / 9.06 ppg. Window ECD = 9.83 ppg w/ open choke. 150' wiper from 13100' is clean up/down. Drill 3.25" lateral from 13100'.
1.82 / 1.62 bpm Pcirc 3800 - 4200 psi. 8.98 / 9.05 ppg. Window ECD = 9.84 ppg w/ open choke. 13160', 13230' 5 bbls lo/hi vis. Wiper to window from 13250'. Jog
below 12350' shale and pull through, 4k overpull adjust rate and POOH speed. Jog below window, pull through. Jog above window, open EDC jet tubing 2.5 / 2.2
bpm until clean. Tie-in depth correct +5'. Close EDC pass window. RIH to bottom 0.3 bpm set down at 12330' shale PU and run past. Once past shale pump 1.8
bpm briefly to check Pann, ok. Continue to bottom. Drill 3.25" lateral from 13252'. 1.80 / 1.70 bpm Pcirc 4020 - 4240 psi. 8.99 / 9.02 ppg. Window ECD = 9.86 ppg
w/ open choke. 13360' 5 bbls lo/hi vis. 150' wiper from 13400' clean up/down. Drill 3.25" lateral from 13400'. 1.83 / 1.68 bpm Pcirc 3960 - 4240 psi. 8.99 / 9.07
ppg. Window ECD = 9.86 ppg w/ open choke.
50-029-21002-02-00API #:
Well Name:
Field:
County/State:
PBE 14-33B
Prudhoe Bay East
Hilcorp Energy Company Composite Report
, Alaska
9/7/2023Spud Date:
9/11/2023 Continue drilling 3.25" lateral at 13535'. Free spin: 4240 psi, 1.83 bpm. Rate: 1.83 bpm in, 1.68 bpm out. Circ pressure: 4305. Mud weight: 9.00 ppg in, 9.02 ppg
out, Window ECD: 9.75 ppg. ROP: 70 fph, WOB: 1.4 k. Drilling 3.25" lateral at 13680'. Free spin: 4949 psi, 2.0 bpm. Rate: 2.0 bpm in, 1.93 bpm out. Circ
pressure: 4305. Mud weight: 9.01 ppg in, 9.05 ppg out, Window ECD: 9.96 ppg. ROP: 22 fph, WOB: 2.3 k. Drilled to 13705' and not able to make any progress.
PU and spud bit into bottom, 5.3k WOB no stall with very little motor work. POOH for bit. Seeing some light over pulls at shales - 13206', 12850'. Jog below shale at
12370', pull through to 12270' at a reduced rate. POOH pump 2.6 bpm. Test agitator near surface, good. Pressure undeploy BHA #5 - Lateral Drilling bit is 6-2
cored out. Pressure deploy BHA #6 - Lateral Drilling w/ 2.74" x 3.25" HCC bit. Keep 9.8# ECD at window. RIH BHA #6. Tie-in depth from 11425' correct -4'. Close
EDC. Pass window go to 0.4 bpm. Mostly clean to bottom, some DWOB spikes through shales 12860', 13400'. Drill 3.25" lateral from 13706'. Free spin: 4250 psi,
1.84 bpm. Rate: 1.81 bpm in, 1.75 bpm out. Pcirc 4250 - 4400 psi. Mud weight: 9.00 ppg in, 9.00 ppg out, Window ECD: 9.95 ppg. 13775' 5 bbls lo/hi vis. 150'
wiper trip from 13850' clean up/down. Drill 3.25" lateral from 13850'. Free spin: 4260 psi, 1.82 bpm. Rate: 1.78 bpm in, 1.71 bpm out. Pcirc 4250 - 4500 psi. Mud
weight: 9.00 ppg in, 9.00 ppg out, Window ECD: 9.95#. 13880' 5 bbls lo/hi vis. Call TD at 13914' have met Geologic objectives. Wiper to window. Slight DWOB at
12850' shale. Jog below 12360' shale pull through 1 bpm clean. Jog below window and pull through. Getting Stator Rubber at the shaker, change out motor during
trip to the swab.
9/12/2023 Continue POOH at 8000'. OOH, PUD the BHA, swap motors and PD BHA. RIH, log tie in, correct depth -4', close the EDC and RIH to tag corrected TD. 12292' little
bobble in WT at the beginning of the shale from 12290' - 12370'. Set down 2k WOB at 12857' stacked then popped through still showing 1k WOB, 12900' PUH to
12800' then run back through. Still stacking WT, bring pumps up to back ream 15' section. RIH at min rate, light tag but clean after that, continue RIH. Tag TD on
depth, PU and start liner pill with beads down the coil. POOH laying in liner pill. Lay in 9.8 KWF from 12250' to the window. Above the window, open the EDC and
lay in KWF to the TOL. Displace KWF to surface. POOH. Flag pipe Yellow 10772.3' bit depth (10700' EOP). White 8472.2' bit depth (8400' EOP). At surface, good
10 min no-flow. Inspect 30' of CT, good. L/D BHA #7 - Lateral Drilling bit is 3-2. Function test BOPs, good. Remove UQC and boot cable. M/U 1 jt PH-6 pump 231'
slack out. Install CT connector, pull test 50k. Install swivel, PT CTC and swivel to 6k, good. Remove test plate. Install nozzle, pump 7/8" drift ball around and
recover. Skid injector back, prep rig floor for liner. M/U 2-3/8" liner as per approved tally. During M/U 3 jts w/ damaged box are found, replace.
9/13/2023 Continue M/U 2-3/8" liner jt 31 of 70. Fill every 10 jts. M/U all 70 jts of 2-3/8" liner. M/U X-nipple, deployment sleeve, BCTLRT, 7/8" disconnect and 6 jts of PH6
tubing. M/U swivel to BOT external connector. RIH with 2-3/8" liner BHA. Correct -1.5' @ window flag. Circulate out KWF from 11,650'. In Rate = 1.5 bpm, Out Rate
= 1.5 bpm. In MW = 9.1 ppg, Out MW = 9.89 ppg. Drilling mud circulated back to surface. PUW @ 11,622' = 40k, RIW = 20k. RIH through window clean. Tag @
12,850'. PUH and begin working liner. Unable to pass 12,850' at different pump rates and speeds. Pump 20 bbls LVT. In Rate = 1.5 bpm, Out Rate = 1.5 bpm. In
MM = 6.94 ppg, Out MM = 9.1 ppg. With 3 bbls LVT out of liner, RIH past 12,850' trouble spot. Tag 13,906'. Establish PUW = 48k, RIW = 14k. 13,893' break over
depth. Pump 3/4" ball to activate liner release tool. Ball on seat shears out at 4183 psi. Pick up to verify release, up wt 7k less. Swap well to KCl. PJSM w/ HES, BTT
and Nabors crew for pumping cmt. Pump liner cmt job, on slight losses. HES load CT w/ 20.3 bbls cmt displace w/ rig. 3 bbls remaining in CT P/U to side exhaust.
Set down launch LWP bumps 11.4 bbls (11.5 calculated). Check floats, good. 17.3 bbls behind pipe. CIP 23:36. P/U slow wash liner top area. Returns now 1:1.
Increase rate to 2.5 bpm circ excess cmt out. Good 10 min no-flow. POOH pump 3 bpm. At surface good 10 min no-flow. Skid back, L/D 6 jts PH-6 and running
tools. Recover 3/4" ball. Tools have functioned normally.
9/14/2023 M/U and RIH with nozzle BHA. Jet stack and flush surface lines at max rate. Pump eline slack into reel. Cut 256' for 1.7% slack. M/U Nabors CTC. Pull test to 40k.
Good. Pump eline slack forward. M/U BHI UQC. PT connector to 3500 psi. M/U and RIH with 2.53" nozzle BHA. PJSM with LRS pumping crew. Freeze protect well
from 2600' MD with diesel. POOH. OOH - secure well with 0 psi on tubing. Pressure test under swab and confirm leak tight. Blow down coil. Change pack offs.
Remove BOPs install tree cap and test. Release rig at 19:00.
ACTIVITYDATE SUMMARY
9/14/2023 (CTD) Pumped 54 bbls of 90* Diesel to freeze protect for CDR2
9/15/2023
T/I/O=0/0/0. Post CDR2. RU CIW lubricator and set 5" Gray "K" BPV #613 @95"
through CDR tree. LTT Passed. RD 5x7" FMC CDR Tree and installed 5x7 FMC 120
upper production tree with baker c actuator. Torqued flanges to API spec. RU CIW
lubricator and Gray pulling tool. Pressure tested tree against MV to 500 / 5000 psi.
Passed. Pulled 5" BPV @ 125". RD lubricator and installed tree cap. PT to 500 psi.
Pass. ***Job Complete*** Final WHP's 0/0/0.
9/15/2023
LRS CTU #1 - 1.50" Blue Coil
Job Objective: RPM, CBL, Initial Perfs
MIRU CTU. Make up Drift BHA with 1.75" DJN.
...Continued on WSR 9-16-23...
9/16/2023
LRS CTU #1 - 1.50" Blue Coil ***Cont. from WSR 9-15-23***
Job Objective: RPM, CBL, Initial Perfs
RIH with Drift BHA. PT liner lap to 1500 psi, Pass, lost 10 psi in 7 minutes wtih zero
loss for the last 3 minutes. Drift to TD tag at 13872'. POOH while swapping the well to
seawater and safelube. RIH with Baker RPM toolstring to 13860'. Log up at 20 FPM
to 11500'. Make 2nd Pass from TD tag at 13868' to11500'. POOH.
...Continued on WSR 9-17-23...
9/17/2023
LRS CTU #1 - 1.50" Blue Coil
Job Objective: Post CTD RPM, CBL, Initial Perfs
POOH with RPM logging BHA and confirm good data. Make up HES RBT Cement
Bond log BHA and RIH. Log from TD at 13873' CTM to 10600' at 50 FPM. Paint a
yellow flag at 13600'. Circulate tubing to diesel to underbalance well. POOH and
confirm good data with +29' correction, Corrected PBTD of 13.898' Make up 20' of
1.56" Geo Razor perf guns and RIH. Tie-in to PBTD and perforate 13810-13830'.
POOH. All Shots Fired. Complete weekly BOP test.
***Job Complete***
9/18/2023
T/I/O=0/0/0 (Assist Slickline) TFS UNIT 3 Pumped 7 BBLS total of diesel for brush
and flush and to pressure TBG to 300 PSI
***Job continued on 9/19/23***
9/18/2023
***WELL S/I ON ARRIVAL***
B&F TOP OF LINER @ 10,968 MD.
CLEAN DRIFT W/ DUMMY 45KB & PTSA (TATTLE TALES GOOD).
***WSR CONTINUED ON 9-19-23***
9/19/2023
***Job continued from 9/18/23*** TFS unit 3 (Assist SL) Pumped 20 BBLS to
pressure up TBG and IA for CMIT-TxIA. **PASS** @2500/2290/50.
Initial pressures 2500/2300/50
1st 15 min pressures 2500/2290/50
2nd 15 min pressures 2500/2290/50
WHPS=150/0/50
9/19/2023
***WSR CONTINUED FROM 9-18-23***
SET 4 1/2" NS MONOPAK LTP ASSY W/ PTSA (2.31" RSG PLUG INSTALLED) IN
DEP SLEEVE @ 10,964' MD.
T-BIRD TO CMIT 2250 PSI (PASS).
***WELL S/I ON DEPARTURE***
9/20/2023
***WELL S/I UPON ARRIVAL (PATCH TBG)***
CORRELATION PASS (+15 CORR)
***CONTINUED ON 9/21/23***
Daily Report of Well Operations
PBU 14-33B
Daily Report of Well Operations
PBU 14-33B
9/21/2023
***WSR CONTINUED FROM 9/20/23***
SET BAKER ONE TRIP PATCH FROM 10,244 TO 10,269', ELEMENT TO
ELEMENT. TOP OF PATCH @ 10,242' ELMD (OAL=31.26', MIN ID 2.45", MAX OD
3.70")
***WELL TURNED OVER TO DSO, S/I UPON DEPARTURE***
9/21/2023
T/I/O 0/205/0 Temp=S/I (TFS Unit 4 conduct MIT-T)
****MIT-T PASSED**** Max Applied Pressure=2500. Target Pressure=2250. Pumped
1 bbls of Diesel down TBG to reach Max applied pressre of 2490. 1st 15 min TBG
lost 116 psi. 2nd 15 min TBG lost 35 psi. TBG lost 151 psi in a 30 min test.
Returned 1.2 bbls. Tag hung on MV. DSO Notified of well status upon TFS
departure.
Final WHPS= 0/215/0
9/21/2023
***WELL S/I ON ARRIVAL***
R/U SLICKLINE.
***CONTINUED ON 9-22-23***
9/22/2023
***WSR CONTINUED FROM 9-21-23***
PULLED RK-DGLV FROM STA# 4 @ 9127' MD.
MADE 3 ATTEMPTS @ PULLING ST#3 @ 8,084' MD (stripping dogs & pieces of f/n)
**DECISION MADE TO SKIP ST#3 AND LEAVE DUMMIED OFF**
PULLED RK-DGLV FROM ST#2 @ 5,797' MD
PULLED RK-DGLV FROM ST#1 3,009' MD
SET RK-LGLV IN ST#1 @ 3,009' MD
SET RK-LGLV IN ST#2 @ 5,797' MD
SET RK-OGLV IN ST#4 @ 9,127' MD
RAN 2 7/8" GR W/ EQ PRONG TO 10,967' SLM (NO SIGNS OF EQUALIZATION).
RAN 10' x 1.75" PUMP BAILER TO 10,968' SLM (Trace amounts of metal fines,
metal marks on bottom).
***WSR CONTINUED ON 9-23-23***
*****NOTE: ST#3 (8084' MD) HAS A STRIPPED FISH NECK******
9/23/2023
***WSR CONTINUED FROM 9-22-23***
PULLED 2.31" RSG PLUG FROM 10,968' SLM.
***WELL S/I ON DEPARTURE***
WELL NAME
Date :
Shoe @ :FC @ :Top Liner @ :
Type:
Type :
Type :
Type :
Type :
XYes No
Yes X No Yes X No
X Yes No X Yes No
Date :
Volume lost during displacement (bbls) :
Density (ppg) : 8.4 Volume pumped (bbls) : 5
14-33B CEMENT REPORT
13-Sep-23 Hole Size :3.25 Casing Size :2.375
Lead Slurry
Class G Cement Volume (bbls): 20.3 15.7
Yield : 1.236 Sacks : 92.2 Mixing / Pumping Rate (bpm) : 1.5
Density (ppg) :
Tail Slurry
Volume (bbls) : Density (ppg) :
Yield : Sacks : Mixing / Pumping Rate (bpm) :
Post Flush (Spacer)
1.5 ppb Geovis Density (ppg) : 8.4 Rate (bpm) :
Bump press :
Volume : 150
Displacement :
1.5 ppb Geovis Density (ppg) : 8.4 Rate (bpm) : 1.5 Volume (actual / calculated) : 150
1.5
Method Used To Determine TOC : Calculated
4200
Casing Rotated? Reciprocated? % Returns during job : 85%
Cement returns to surface? Spacer returns? Vol to Sur : 4
FCP (psi) : 3800 Pump used for disp : GD Plug Bumped?
Cement In Place At : 23:36 9/13/2023 Estimated TOC : 10,963
3.00
Remarks:
FI
R
S
T
S
T
A
G
E
13914 13911, 13901 10963
Preflush (Spacer)
1% KCl
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Monty M. Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK, 99503
Re: Prudhoe Bay, Prudhoe Oil Pool, PBU 14-33B
Hilcorp Alaska, LLC
Permit to Drill Number: 223-067
Surface Location: 78' FNL, 1267' FEL, Sec. 09, T10N, R14E, UM, AK
Bottomhole Location: 544' FSL, 81' FEL, Sec. 03, T10N, R14E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above-referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this ___ day of August 2023. 28
Brett W.
Huber, Sr.
Digitally signed by Brett
W. Huber, Sr.
Date: 2023.08.28
15:42:10 -08'00'
1a.
Contact Name:Ryan Ciolkosz
Contact Email:ryan.ciolkosz@hilcorp.comAuthorized Name: Monty Myers
Authorized Title:Drilling Manager
Authorized Signature:
Contact Phone:907-244-4357
Approved by:COMMISSIONER
APPROVED BY
THE COMMISSION Date:
21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated
from without prior written approval.
Drill
Type of Work:
Redrill 5
Lateral
1b.Proposed Well Class:Exploratory - Gas
5
Service - WAG
5
1c. Specify if well is proposed for:
Development - Oil Service - Winj
Multiple Zone Exploratory - Oil
Gas Hydrates
Geothermal
Hilcorp North Slope, LLC Bond No. 107205344
11.Well Name and Number:
PBU 14-33B
TVD:13757'8959'
12. Field/Pool(s):
PRUDHOE BAY, PRUDHOE OILMD:
ADL 028312 & 028311
77-043 November 1, 2023
4a.
Surface:
Top of Productive Horizon:
Total Depth:
78' FNL, 1267' FEL, Sec. 09, T10N, R14E, UM, AK
2379' FSL, 248' FEL, Sec. 03, T10N, R14E, UM, AK
Kickoff Depth:11645 feet
Maximum Hole Angle: 115 degrees
Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Downhole:Surface:3319 2425
17.Deviated wells:16.
Surface: x-y- Zone -675175 5940262 4
10. KB Elevation above MSL:
GL Elevation above MSL:
feet
feet
69.0'
38.97'
15.Distance to Nearest Well
Open to Same Pool:
Cement Quantity, c.f. or sacks
MD
Casing Program:
11048'8335'
19.PRESENT WELL CONDITION SUMMARY
Liner
81 1800# Poleset
13879 8875 11680, 11815, 13405 11680 8761 None
29 - 110
Surface 2500sx Fondu, 500 sx PF C
8772 - 8893
Seabed Report Drilling Fluid Program 5 20 AAC 25.050 requirements
Shallow Hazard Analysis
5
Commission Use Only
See cover letter for other
requirements:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No
H2S measures Yes No
Spacing exception req'd: Yes No
Mud log req'd: Yes No
Directional svy req'd: Yes No
Inclination-only svy req'd: Yes No
Other:
Date:
Address:
Location of Well (State Base Plane Coordinates - NAD 27):
4.6#
2744
11692 - 13835
50-029-21002-02-00
26 - 11371
131 sx Class G
Intermediate
Conductor/Structural
Single Zone
Service - Disp
No YesPost initial injection MIT req'd:
No Yes 5
Diverter Sketch
Comm.
TVD
API Number:
MD
Sr Pet Geo
500 sx Class G, 25 Bbls PF C
544' FSL, 81' FEL, Sec. 03, T10N, R14E, UM, AK
Time v. Depth Plot 5 5 Drilling Program
19000'
(To be completed for Redrill and Re-Entry Operations)
20"
13-3/8"
9-5/8"
Hyd 511
11345
2816 8344 - 8876
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
Stratigraphic Test
Development - Gas Service - Supply
Coalbed Gas
Shale Gas
2.Operator Name:5.Bond Blanket 5 Single Well
3.
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
6. Proposed Depth:
7. Property Designation (Lease Number):
8. DNR Approval Number:13.Approximate spud date:
9.Acres in Property: 14. Distance to Nearest Property:
Location of Well (Governmental Section):
4b.
5120
880'
18.Specifications Top - Setting Depth - Bottom
Casing Weight Grade TVDHole Coupling Length TVD (including stage data)
Total Depth MD (ft): Total Depth TVD (ft):
Plugs (measured):Effect. Depth MD (ft): Effect. Depth TVD (ft):Junk (measured):
Casing Length Size MD
29 - 110
28 - 2772 28 - 2698
390 7"400 sx Class G 11070 - 11460 8349 - 8577
Liner 11062 - 13878
Perforation Depth MD (ft):Perforation Depth TVD (ft):
20. Attachments Property Plat BOP Sketch
Permit to Drill
Number:
Permit Approval
Date:
Reentry
Hydraulic Fracture planned?
Sr Pet Eng Sr Res Eng
26 - 8527
Cement Volume
Comm.
13757'8959'82 sx Class G3-1/4"2-3/8"13Cr80 2709'
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g))
3-1/2"x3-3/16"x2-7/8"
7.18.2023
By Grace Christianson at 9:01 am, Jul 19, 2023
Drilling Manager
07/18/23
Monty M
Myers
Variance to 20 AAC 25.112(i) Approved for alternate plug
placement with fully cemented liner with upcoming sidetrack.
2425
DSR-7/19/23A.Dewhurst 21 AUG 2023MGR01AUG2023
BOPE test to 3500 psi.
223-067
*&:
08/28/23
08/28/23
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.08.28 15:41:57 -08'00'
To: Alaska Oil & Gas Conservation Commission
From: Ryan Ciolkosz
Drilling Engineer
Date: July 18, 2023
Re: 14-33B Permit to Drill
Approval is requested for drilling a CTD sidetrack lateral from well 14-33A with the Nabors
CDR2 Coiled Tubing Drilling.
Proposed plan for 14-33B Producer:
Prior to drilling activities, SL will pull the tubing patch at 10244' MD, drift for whipstock, and E-line will
set a 3-1/4" whipstock. Coil will mill window pre-rig. If unable to set the whipstock or mill the window
pre-rig, the rig will perform that work.
A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE
and kill the well. If unable to set whipstock pre-rig, the rig will set the 3-1/4" whipstock. A single string
2.74" window + 10' of formation will be milled. The well will kick off drilling in Ivishak Zone 4. The lateral
will continue in Zone 4, 3 and 2 to TD. The proposed sidetrack will be completed with a 2-3/8” 13CR
solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to
post rig). This completion will completely isolate and abandon the parent Ivishak perfs.
This Sundry covers plugging the existing perforations via cement squeeze, liner cement job or liner top packer, if
the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)).
The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is
attached for reference.
Pre-Rig Work - (Estimated to start in July 2023):
Pre-Rig Work
1SLPull Tubing Patch, Dummy WS drift to 11680' MD.
2ELSet Whipstock at 11,645' MD
3 Service Coil
Mill Window if unit is available
4 Valve Shop
Pre-CTD tree work (install sarber spool, PT swab, leak-tight master)
5 Valve Shop
Bleed wellhead pressures down to zero.
6 Valve Shop
Bleed production, flow and GL lines down to zero and blind flange.
7 Opearations
Remove wellhouse and level pad.
Rig Work
1 MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,425 psi).
2 Mill 2.74” Window. (If not done pre-rig)
3 Drill build section: 3.25" OH, ~214' (32 deg DLS planned).
4 Drill production lateral: 3.25" OH, ~1898' (12 deg DLS planned).
5 Run 2-3/8” 13Cr liner
6 Pump primary cement job: 18.1 bbls, 15.3 ppg Class G, TOC at TOL*.
7 Freeze protect well to a min 2,200' TVD.
8 Close in tree, RDMO.
Post-Rig Work
Sundry 323-
PTD 223-0XX
1 Valve Shop
Valve & tree work
2 Slickline
Set LTP* (if necessary). Set TBG patch. MIT-IA, Set live GLVs.
3 Service Coil
Post rig perforate (~30’) and RPM.
* Approved alternate plug placement per 20 AAC 25.112(i)
Managed Pressure Drilling:
Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole
pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface
pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying
annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or
fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of
the WC choke.
Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will
be accomplished utilizing 3” (bighole) & 2-3/8” (slimhole) pipe/slip rams (see attached BOP configurations). The
annular preventer will act as a secondary containment during deployment and not as a stripper.
Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements
while drilling and shale behavior. The following scenario is expected:
MPD Pressure at the Planned Window (11645’ MD - 8726’ TVD)
Pumps On Pumps Off
A Target BHP at Window (ppg)4,447 psi 4,447 psi
9.8
B Annular friction - ECD (psi/ft)408 psi 0 psi
0.035
C Mud Hydrostatic (ppg)3,902 psi 3,902 psi
8.6
B+C Mud + ECD Combined 4,310 psi 3,902 psi
(no choke pressure)
A-(B+C)Choke Pressure Required to Maintain 137 psi 545 psi
Target BHP at window and deeper
Operation Details:
Reservoir Pressure:
x The reservoir pressure is expected to be 3319psi at 8940’ TVDSS (7.1 ppg equivalent).
x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2425 psi.
x A min EMW of 8.4 ppg for this well will be 585 psi over-balance to the reservoir.
Mud Program:
x Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain
constant BHP.
Disposal:
x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4.
x Fluids >1% hydrocarbons or flammables must go to GNI.
x Fluids >15% solids by volume must go to GNI.
x Fluids with solids that will not pass through 1/4” screen must go to GNI.
x Fluids with PH >11 must go to GNI.
Hole Size:
x 3.25” hole for the entirety of the production hole section.
Liner Program:
x 2-3/8”, 4.6#, 13CR solid/cemented liner: 11048’ MD – 13,757’ MD (2709’ liner)
x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary
x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole.
Well Control:
x BOP diagram is attached. MPD and pressure deployment is planned.
x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi.
x The annular preventer will be tested to 250 psi and 2,500 psi.
x A X-over shall be made up to a 2” safety joint including a TIW valve for all tubulars ran in hole.
x 2” safety joint will be utilized while running solid or slotted liner. The desire is to keep the same standing
orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre-
installed TIW valve). When closing on a 2” safety joint, 2 sets of pipe/slip rams will be available, above
and below the flow cross providing better well control option.
Directional:
x Directional plan attached. Maximum planned hole angle is 115°. Inclination at kick off point is 13°.
x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
x Distance to nearest property line – 19,000’
x Distance to nearest well within pool – 880’
Logging:
x MWD directional and Gamma Ray will be run through the entire open hole section.
x Real time bore pressure to aid in MPD and ECD management.
Perforating:
x ~30’ perforated post rig – See future perf sundry.
x 1-11/16” Perf Guns at 6 spf
x If post rig extended perforating with service coil is not an option, the well will be perforated with the rig or
post rig under this PTD.
x The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely
in the Ivishak pool.
Anti-Collision Failures:
x All wells pass AC with WP05.
Hazards:
x DS-14 is an H2S pad. H2S reading on 14-33A: 20 ppm on 04/25/2022.
x Max H2S recorded on DS-14: 140 ppm.
x One fault crossings expected.
x Medium lost circulation risk.
Ryan Ciolkosz CC: Well File
Drilling Engineer (907-244-4357) Joseph Lastufka
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$
3
Well Date
Quick Test Sub to Otis -1.1 ft
Top of 7" Otis 0.0 ft
Distances from top of riser
Excluding quick-test sub
Top of Annular 2.75 ft
C L Annular 3.40 ft
Bottom Annular 4.75 ft
CL Blind/Shears 6.09 ft
CL 2.0" Pipe / Slips 6.95 ft B3 B4
B1 B2
Kill Line Choke Line
CL 2-3/8" Pipe / Slip 9.54 ft
CL 2.0" Pipe / Slips 10.40 ft
TV1 TV2
T1 T2
Flow Tee
Master
Master
LDS
IA
OA
LDS
Ground Level
3" LP hose open ended to Flowline
CDR2-AC BOP Schematic
CDR2 Rig's Drip Pan
Fill Line from HF2
Normally Disconnected
3" HP hose to Micromotion
Hydril 7 1/16"
Annular
Blind/Shear
2.0" Pipe/Slips
2 3/8" Pipe/Slips
2 3/8" Pipe/Slips
7-1/16"
5k Mud
Cross
2.0" Pipe/Slips
2-3/8" Pipe /
Slip
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME: ______________________________________
PTD: _____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD: __________________________ POOL: ____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in no greater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
223-067
PRUDHOE OIL
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28
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k
w
i
l
l
o
c
c
u
r
w
i
t
h
o
u
t
o
p
e
r
a
t
i
o
n
s
h
u
t
d
o
w
n
Ye
s
H
2
S
i
s
p
o
s
s
i
b
l
e
.
W
i
l
l
r
e
q
u
i
r
e
m
o
n
i
t
o
r
i
n
g
.
33
I
s
p
r
e
s
e
n
c
e
o
f
H
2
S
g
a
s
p
r
o
b
a
b
l
e
NA
34
M
e
c
h
a
n
i
c
a
l
c
o
n
d
i
t
i
o
n
o
f
w
e
l
l
s
w
i
t
h
i
n
A
O
R
v
e
r
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
No
D
S
1
4
w
e
l
l
s
a
r
e
H
2
S
-
b
e
a
r
i
n
g
.
H
2
S
m
e
a
s
u
r
e
s
a
r
e
r
e
q
u
i
r
e
d
.
35
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
/
o
h
y
d
r
o
g
e
n
s
u
l
f
i
d
e
m
e
a
s
u
r
e
s
Ye
s
R
e
s
e
r
v
o
i
r
e
x
p
e
c
t
e
d
t
o
b
e
7
.
1
p
p
g
e
q
u
i
v
a
l
e
n
t
.
M
i
n
i
m
u
m
E
M
W
o
f
8
.
4
p
p
g
p
l
a
n
n
e
d
.
M
P
D
t
o
b
e
e
m
p
l
o
y
e
d
.
36
D
a
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
S
e
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
S
e
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
C
o
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
8/
2
1
/
2
0
2
3
Ap
p
r
MG
R
Da
t
e
8/
1
0
/
2
0
2
3
Ap
p
r
AD
D
Da
t
e
8/
1
8
/
2
0
2
3
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
Pu
b
l
i
c
Co
m
m
i
s
s
i
o
n
e
r
Da
t
e
*&
:
