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David Dempsey Hilcorp Alaska, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.dempsey2@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 09/27/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20220927
Well API #PTD #Log Date Log
Company
Log
Type AOGCC Eset#
END 3 31 500292283800 197227 12/13/2021 Baker CH RPM
PBU 01-14A 500292028101 209129 7/29/2022 Baker CH SPN
PBU 01-15B 500292028702 213190 8/2/2022 Baker CH SPN
PBU 01-31 500292162600 186132 7/6/2022 Baker CH SPN
PBU 06-04B 500292017902 216092 5/5/2021 Baker CH RPM
PBU 06-16A 500292046001 212139 5/3/2021 Baker CH RPM
PBU 06-21C 500292080203 221088 6/28/2022 Baker CH MRPM
PBU 15-49C 500292265103 215129 8/13/2022 Baker CH MRPM
PBU H-05B 500292010602 209100 6/29/2022 Baker CH SPN
PBU H-26A 500292148701 214205 7/10/2022 Baker CH SPN
PBU H-35A 500292260001 214045 7/4/2022 Baker CH SPN
PBU H-38 500292340200 208167 7/19/2022 Baker CH SPN
PBU P1-06A 500292269502 222009 7/17/2022 Baker CH MRPM
PBU P2-43 500292325000 205024 8/5/2022 Baker CH SPN
PBU U-09B 500292114402 214063 8/12/2022 Baker CH SPN
PBU W-26A 500292196401 199081 7/23/2022 Baker CH SPN
Please include current contact information if different from above.
T37052
T37053
T37054
T37055
T37056
T37057
T37058
T37059
T37060
T37061
T37062
T37063
T37064
T37065
T37066
T37067
PBU 06-21C 500292080203 221088 6/28/2022 Baker CH MRPM
Kayla Junke
Digitally signed by
Kayla Junke
Date: 2022.09.29
16:24:46 -08'00'
3-1/4"x2-7/8"
4
By Meredith Guhl at 12:09 pm, Jul 21, 2022
Completed
6/29/2022
JSB
RBDMS JSB 072622
GDSR-8/1/22MGR30AUG2022
7.21.2022
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2022.07.21 10:28:56 -08'00'
Monty M
Myers
Activity Date Ops Summary
6/8/2022
Install jeeps for road travel. Move both rig modules off L1 to DS-06. Off L1 left on West Dock, right on Spine past Central checkpoint and Deadhorse, past West
checkpoint to DS-06. Both modules arrive on DS-06. SimOps with Drill Site Operator and Coil Unit. Spot and set down both modules over well. Connect PUTZ. RU
cellar and steam lines. Move Shop building from L1 to DS 6. Spot bleed tank, LVT pup and auxiliary equipment. Open well and confirm 2500 psi on tubing. Bleed
off and RD tree flange. NU BOP's.
6/9/2022 Install nozzle, circ reel full of fresh water. Install CT risers. Grease choke valves. Install spill deflector around CT riser. Get RKBs. Complete valve checklist. Flush
surface lines with fresh water. Get good shell test. Test BOPs 250 / 3500 psi as per Hilcorp and AOGCC regs. Test witness is waived by AOGCC Inspector Bob
Noble. Test 1 IRV, Packoff, C7, C9, C10, C11 Pass. Test 2 Blind / Shear, R2, BL2, C15. Test 3 Annular (2-3/8"), TIW1, B1, B4 Pass. Test 4 Upper 2-3/8" Pipe /
Slips, TIW2, B2, B3 Pass Test 5 Lower 2-3/8" Pipe / Slips, C5, C6, C8, TV2 Pass Test Choke A, Choke B Pass. Drawdown Test On Accumulator. Record all
closing times. Record N2 bottle pressure. Test 7 Upper 2-3/8" Pipe/Slips, C1, C4, TV1 Pass. Test 8 3" Pipe/Slips, C2, C3 Pass. Install BHI floats and test. R/U PDL
and record measurements for max pressure deploy length. Pressure test PDL. Pump 10 bbls 60/40 methanol and test MPD line to 3500 psi. Open master. T/I/O =
2468, 89, 53. Begin pumping bullhead kill schedule @ 5 bpm and 2478 psi. -10 bbls 60/40 methanol. 271 bbl 1% KCL. T/I/O = 90 , 1141, 363 while swapping to
vis pill. 43 bbl High Vis pill. 102 bbls PowerPro mud. Shut down pumping and monitor well, T/I/O = 27, 748, 606. Fill hole after 15 minutes with .3 bbls. Fill hole after
15 minutes .9 bbls. Flush stack and blow down line to Return . Rig Injector back and prep to MU window milling assembly MU BOT/BHI window milling BHA #1. 2
7/8" BOT Xtreme Motor and 3.79" NG reamer and 3.80" NG reamer. Displace fresh water in coil to Return Tank. RIH with BHA #1. Pump Rate In = .90 bpm Pump
Rate Out = 1.45 bpm. IA = 567 psi, OA = 524 psi. Tag @ GLM 3652'. Run past and pull back through. Run back in hole and did not tag. Resume RIH.
6/10/2022 Continue RIH. Tie-in depth correct -41'. Close EDC, tag whipstock at 9057'. Pick up and start milling window from 9056.4'. Continue milling window from 9056.4'.
PVT shows +3.5 bbls, P/U for 10 min pumps off flowcheck, static. Check pits, PVT gain caused by agitators. Continue milling 9056.9'. 8.59 ppg In / Out. 2.49 / 2.46
bpm. Bleed OA from 800 to 500 psi. Mill window from 9059.1'. 8.57 / 8.58 ppg In / Out. 2.78 / 2.77 bpm In / Out. Window ECD 9.55#. Bleed OA to 300 psi. Bleed IA
to 1000 psi. Mill window from 9062.9'. 8.56 / 8.57 ppg In / Out. 2.77 / 2.79 bpm In / Out. Window ECD 9.61#. IA 1157 psi, OA 732 psi. Mill window from 9065.01'.
8.56 / 8.57 ppg In / Out. 2.78 / 2.80 bpm In / Out. Window ECD 9.61#. IA 1244 psi, OA 393 psi. Appears mill has exited, continue dressing with reamer. Mill 10' of
rat hole to 9075' Geologist confirmed formation sand in bottoms up sample. Backream window at 1 fpm. Multiple passes reaming past 9057' until no motor work
seen. Dry drift clean. Pump 10 bbl High/Low vis sweep off bottom. POOH for lateral BHA. 8.56 / 8.57 ppg In / Out. 2.77 / 2.38 bpm In / Out. Window ECD 9.51#. IA
1330 psi, OA 523 psi. OOH. Flow check well and confirm no flow. LD window milling BHA. Window mill and string reamer both 3.79" No-go and 3,80" Go MU
nozzle and jet BOP stack. Flush and blow down choke lines. MU Build BHA with 3.0 deg AKO. M/U injector, test QTS.
6/11/2022 RIH BHA #2 Build BHA. Slow through all jewelry. Pump 1 bpm / 1200 psi through open EDC. Tie-in depth from 8720'. Correct -41'. Close EDC Up wt at 9000' is
46k. Log down from 8995' to 9050 to capture Sag marker. Correct another +6'. Pass window 10 ft/min 180R, 0 pump no issues. Tag end rat hole at 9081'. Get up wt
+ 2', bring pumps on. Drill from 9081'. 2.80 / 2.80 bpm In / Out. MW 8.55 / 8.58 ppg. Window ECD 9.50 ppg. Control drill until NBInc is off the tray. Drill from 9138'.
2.80 / 2.81 bpm In / Out. MW 8.56 / 8.57 ppg. Window ECD 9.55 ppg. ROP is 20 - 40 ft/hr with 2-3k DWOB. 9150' 10 bbls lo / hi vis. 90' wiper from 9200' is 47k up
wt, clean up and down. Drill from 9200'. 2.79 / 2.77 bpm In / Out. MW 8.57 / 8.57 ppg. Window ECD 9.56 ppg. ROP is 40 - 50 ft/hr with 2-3k DWOB. 9270' 10 bbls
lo / hi vis. Drill to TD build 9311'. Dynamic flow check on bottom is good. Clean pass to window. Jog below window and pull through 0.5 bpm. Jog above window
and open EDC. 10 bbls lo / hi vis sweeps. Pump 3.0 bpm. Tie-in depth, correct +2'. Pull up log CCL across liner top area. POOH. 2.97 / 2.41 bpm In / Out. MW
8.54 / 8.63 ppg. Window ECD 9.56 ppg. OOH. Flow check well and confirm no flow. L/D build BHA. Bit 1-1. M/U lateral BHA w/1..1° motor and 3.75" x 4.25" HYC
TCC bi-center bit RIH with BHA #3. Shallow test agitator and confirm working. 1.24/ 1.74 bpm In / Out. MW 8.59 / 8.60 ppg Log tie-in from 9030'. Correct - 37'.
Close EDC and RIH through window. Begin drilling lateral from 9309'. 3.01/ 2.99 bpm In / Out. MW 8.59 / 8.60 ppg. Window ECD 9.62 ppg. ROP is 40 - 60 ft/hr
with 2-3k DWOB. IA = 989, OA = 286. Continue drilling lateral from 9430' into Zone 3. Slowing ROP and increasing chert with multiple stalls. 2.99/ 2.97 bpm In /
Out. MW 8.58 / 8.61 ppg. Window ECD 9.64 ppg. ROP is 40 - 50 ft/hr with 2-3k DWOB. IA = 1470, OA = 588. Drilling lateral from 9459' and cross suspected fault
with 20 - 60 bph loss rate. 2.96/ 2.72 bpm In / Out. MW 8.56 / 8.61 ppg. Window ECD 9.58 ppg. ROP is 10 - 30 ft/hr with 2-3.5 k DWOB. IA = 1551 OA = 674.
6/12/2022 Drill from 9470'. 2.97 / 2.71 bpm In / Out. MW 8.56 / 8.57 ppg. Window ECD 9.58 ppg. ROP is 10 - 20 ft/hr with 2-3k DWOB. 170' wiper from 9480' is 44k clean
Stall at 9542' up wt is 49k. Drill from 9542'. 3.01 / 2.97 bpm In / Out. MW 8.56 / 8.60 ppg. Window ECD 9.63 ppg. ROP is 15 - 20 ft/hr with 2-4k DWOB. 10 bbls lo /
hi vis at 9580' Drill from 9608' to 9750'. 3.05 / 2.96 bpm In / Out. MW 8.56 / 8.60 ppg. Window ECD 9.61 ppg. 100' wiper at 9610' is 50k, clean pass. Some diff
sticking off bottom, in Zone 2 now. 9710' 10 bbls lo / hi vis sweeps Wiper trip to window from 9750'. 3.04 / 2.72 bpm In / Out. MW 8.56 / 8.58 ppg. Window ECD
9.61 ppg. Pump High/Low Vis sweep from window depth. Jet across tray. Log tie-in from 9010' @ 5 fpm. No correction. RIH to resume drilling Drill ahead from
9750'. 2.96 / 2.92 bpm In / Out. MW 8.57/ 8.59 ppg. Window ECD 9.61 ppg. ROP is 15 - 20 ft/hr with 2-4k DWOB. Drill ahead from 9819'. 2..96 / 2.99 bpm In / Out.
MW 8.55/ 8.61 ppg. Window ECD 9.73 ppg. ROP slowing to 10 - 15 ft/hr with 2-6k DWOB as we drill into Zone 3. Drill ahead from 9860'. 3.01 / 2.99 bpm In / Out.
MW 8.55/ 8.63 ppg. Window ECD 9.77 ppg. ROP slowing to 10 - 15 ft/hr with 2-6k DWOB as we drill into Zone 3. Pumping 10 bbl High/Low vis sweeps Drill past
9861' and encounter 100% losses. PU and regain partial returns. Still 60 bph loss rate. 2.97 / 2.77 bpm In / Out. MW 8.54/ 8.61 ppg. Window ECD 9.74 ppg. Drill
ahead from 9869' and losses down to ~ 10 bph. Drill past 9871' and have repeated stalls. POOH for new bit. 2.85 / 2.81 bpm In / Out. MW 8.54/ 8.58 ppg. Window
ECD 9.72 ppg.
Spud Date:
API #:50-029-20802-03-00
Well Name:
Field:
County/State:
PBE 06-21C
Prudhoe Bay East
Hilcorp Energy Company Composite Report
, Alaska
6/10/2022
Mill window from 9062.9'. 8.56 / 8.57
6/13/2022 POOH for bit. On 10 - 15 bbl/hr losses on bottom. Jog below window. Pull through window 0.5 bpm nothing seen. Jog above window and open EDC. Pump 3.5 bpm
keep 9.65# ECD on well. Tag stripper and space out. Undeploy BHA #3. Keep 9.65# ECD at window. Bit is 3-3. Change out lower section of BHA and lay down.
Function test BOPs. Check CT for thin spots, within specs. Inspect and change packoffs, PT is good. Purge choke and out MM with air, open and clean Deploy BHA
#4. PT choke body and 1502 connection to C13, good. RIH BHA #4. Keep 9.65# ECD at window. Shallow hole test agitator is good Log tie-in from 9030' @ 5 fpm
Correct -33.5'. In Rate = .93 bpm, Out Rate .98 bpm. 8.62 ppg In, 8.62 ppg Out. ECD = 9.64 ppg. RIH and drill ahead from 9870'. In Rate = 3.0 bpm, Out Rate 2.92
bpm. 8.61 ppg In, 8.59 ppg Out. ECD = 9.77 ppg. IA = 453, OA = 86. Circ pressure = 3795 psi. ROP 25 - 35 fph. Drill past 9917' and encounter ~ 90 bph losses.
PUW = 47k and clean. Drill to 9934' and have full returns. In Rate = 2.91 bpm, Out Rate 2.59 bpm. 8.59 ppg In, 8.62 ppg Out. ECD = 9.76 ppg. IA = 692, OA =
152. Circ pressure = 4003 psi. ROP 25 - 35 fph. Wiper trip from 10030' and resume drilling. In Rate = 2.94 bpm, Out Rate 2.91 bpm. 8.57 ppg In, 8.65 ppg Out.
ECD = 9.74 ppg. IA = 956, OA = 247. Circ pressure = 3933 psi. 25 - 35 fph POOH from 10085' for new bit after ROP fell off. In Rate = 3.03 bpm, Out Rate 2.75
bpm. 8.58 ppg In, 8.61 ppg Out. ECD = 9.69 ppg. IA = 1184, OA = 365. Jog below window, pull through and open EDC. Chert returns. Pump sweep and continue
with bottoms up circ.
6/14/2022 Choke has plugged off during trip OOH. Pump 10 bbls lo / hi vis sweeps, jog back to the window. Resume POOH keep 9.65# ECD on well. Test agitator at 500',
working Tag up and space out. Undeploy BHA #4. Bit is 7-2. Purge choke with air, check above CTC for wear spots. Deploy BHA #5. NOV bit with 3D cutters and
Pesiak 1 deg motor RIH BHA #5. Hold 9.65# ECD at window. Tie-in depth from 9030' correct -34'. Close EDC. Pump 1 bpm through motor above window,
parameters look normal. Shut off pump and pass window, nothing seen. RIH to bottom at 0.5 bpm. At 9460' pick up slowly go to full rate to check parameters. 2.85 /
2.70 bpm @ 3870 psi. 1200 psi differential. Continue RIH 0.5 bpm. Get parameters again just off bottom Go to 1 bpm, ease down and find bottom. See about 500
lbs DWOB then bring pump up to 2.8 bpm. Drill from 10085'. Go on full losses for about 15 bbls then returns come back to 30 bbl/hr loss rate. Stall at 10088' up wt
62k Continue drilling, slow ROP. Frequent pickups when ROP goes to 0. Slowly work back down to 10091' at full drilling rate with out seeing any WOB. Drill ahead
from 10091'. 2.88 / 2.73 bpm @ 4118 psi. MM IN 8.58 ppg, MM Out = 8.59 ppg. WOB = .5 - 1k. ROP = 20 - 40 fph. Drilling ahead from 10150' to 10235' with
improving ROP. 2.96 / 2.79 bpm @ 4337 psi. MM IN 8.56 ppg, MM Out = 8.60 ppg. WOB = 1 - 2.5 k. ROP = 30 - 50 fph. Wiper trip from 10235' PUW = 49k. Drill
ahead with 2.5k WOB. 2.93 / 2.67 bpm @ 3946 psi. MM In 8.56 ppg, MM Out = 8.63 ppg. IA = 1150', OA = 369. ECD = 9.74. Drill ahead from 10300' with 1.5 -
2.5k WOB. 2.95/ 2.92 bpm @ 4526 psi. MM In 8.58 ppg, MM Out = 8.62 ppg. IA = 1287', OA = 448. ECD = 9.80. ROP ~ 25 fph Drill ahead from 10356' with 1.5 -
2.5k WOB. 2.97 / 2.92 bpm @ 4526 psi. MM In 8.58 ppg, MM Out = 8.62 ppg. IA = 1349, OA = 485. ECD = 9.98. ROP ~ 25 - 60 fph. Pump 10 bbl lo/hi vis sweep
Drill ahead from 10368' with 1.5 - 2.5k WOB and several stalls. 2.92 / 2.91 bpm @ 4229 psi. MM In 8.59 ppg, MM Out = 8.64 ppg. IA = 1344, OA = 499. ECD =
9.84. ROP ~ 25 - 40 fph.
6/15/2022 Drill from 10378'. 2.94 / 2.90 bpm @ 4300 psi. MM IN 8.58 ppg, MM Out = 8.64 ppg. WOB = 1 - 3 k. ROP = 10 - 30 fph. Stall at 10394' up wt 52k. 150' wiper from
10394' clean up and down. 10403' 10 bbls lo / hi vis sweeps. Continue drilling at 10394' Drill from 10450'. 2.86 / 2.79 bpm @ 4800 psi. MM IN 8.61 ppg, MM Out =
8.64 ppg. WOB = 1 - 3 k. ROP = 20 - 40 fph then goes < 10 fph. Drill to 10506'. 10 bbls lo / hi vis sweeps POOH for low ROP < 10 ft/hr average. Clean pass to
window. Jog below window and pull through clean. Jog above window and trap pressure, open EDC. Jet whipstock tray. Pump 10 bbls lo / hi vis. Pump 3.5 bpm
Tag up and space out. Undeploy BHA #5. Bit graded 7-4 Inspect coil and find significant gouging ~ 7' from CTC. Cut coil and inspect remaining coil. Install Nabors
internal CTC. Pull test connector to 50k. MU BHI connector. Cut 10' of coil. Cut 10' of eline Test BHI connector - Good. PT CTC to 3500 psi - Good. PT and chart
BHA floats to 3500 psi - Good. MU and pressure deploy BHA #6. Lateral BHA with 2 7/8" ULS Motor with 1.1 degree bend and 3.75" x 4.25" HCC Bi-Center bit. RIH
with BHA #6 - Lateral BHA. In Rate = 1.11, Out Rate 1.61. MM In = 8.63, MM Out = 8.66. IA 220, OA 92 Log tie-in from 9030' @ 3 fpm. Correct -36' and RIH. Take
weight briefly @ 9812' and pass by RIH and Drill ahead from 10,509' to 10590'. In Rate = 2.97, Out Rate 2.73. MM In = 8.63, MM Out = 8.65. Circ pressure = 3935,
ECD 9.88. ROP 60 - 80 fph. IA 220, OA 92.
6/16/2022 Drilling at 10590'. MW 8.65 / 8.69 ppg In / Out. 2.83 / 2.74 bpm In / Out. ROP 40 - 50 fph with 1 - 3k DWOB. 150' wiper at 10650' clean up and down. 10670' 10
bbls lo / hi vis Drilling at 10751'. Stack wt pickup is 72k, pull 100' wiper trip clean. MW 8.67 / 8.71 ppg In / Out. 2.86 / 2.77 bpm In / Out. ROP 50 - 60 fph with 1 - 3k
DWOB. 150' wiper at 10799' clean up and down. 10876' 10 bbls lo / hi vis. Drilling at 10895'. MW 8.68 / 8.72 ppg In / Out. 2.83 / 2.79 bpm In / Out. ROP 50 - 60
fph with 1 - 3k DWOB. Differential sticking coming off bottom Drill to 10925' stacking wt. Wiper to window pump 10 bbls lo / hi vis sweeps. 6k overpull 9670', 9460'.
Jog below window then pull through 0.5 bpm nothing seen. Jog above window and open EDC. Log tie-in correct +2'. Pump 10 bbls lo / hi vis sweeps to clean tubing
pump 1.5 x B/U until tubing clear. Purge MPD choke with air. Troubleshoot choke hydraulics. Close EDC. Pass window 0 pump 180R nothing seen. RIH to bottom
clean pass. Drilling at 10925'. MW 8.67 / 8.67 ppg In / Out. 2.87 / 2.86 bpm In / Out. ROP 50 - 60 fph with 1 - 3k DWOB. 150' wiper at 11100' clean up and down.
Drilling at 11100'. MW 8.49 / 8.73 ppg In / Out. 2.85 / 2.87 bpm In / Out. ROP 100 - 110 fph with 1 - 3k DWOB. IA = 1503, OA = 568 Drilling at 11246' with slowing
ROP. MW 8.70/ 8.54 ppg In / Out. 2.83 / 2.77 bpm In / Out. ROP 6 - 8 fph with 3 -5k DWOB. IA = 1523, OA = 604 Attempting to drill from 11271' with frequent
stalls. MW 8.66/ 8.65 ppg In / Out. 2.96/ 2.772bpm In / Out. Circ pressure = 4225. IA = 1607, OA = 682 POOH from 11271' to inspect BHA after unable to see any
reactive torque during pressure spikes. Suspect possible BHA/bit failure. Pump 10 bbl lo/hi vis sweep off bottom. Overpull @ 10120'. RIH and come back through
with 2k overpull. Overpull @ 9595'. RIH come back through clean. Jog below window. Pull through window - clean. Open EDC and pump at max rate across
window. Pump additional 10 bbl lo/hi vis sweep. Recip slowly at window and pump additional bottoms up.
6/17/2022 Continue POOH pump 3.2 bpm through open EDC. Start dragging around 8600' run back in pump 10 bbls lo / hi vis sweeps around followed by 80 bbls new mud
at 4.3 bpm. Continue POOH still some drag but no packing off See 2k overpull at 3580'. Stop and try to RIH, push down 5k to pop free. Continue POOH Tag up and
space out. Undeploy BHA #6. During undeploy FVS leaks. Strip injector back down and M/U QTS. Bleed off and do a 10 min flowcheck, good no flow. Pull BHA out
w/ tugger. Bit is 7-1. Some debris found in FVS. Close swab go back on MP keep 9.7# on well M/U BHA #7 in PDL. NOV bit, no agitator, new FVS, re-run motor.
Check 20' of CT above connector for damage, nothing seen Deploy BHA #7 M/U LQC and UQC, tool doesn't test. Strip up and break BHI tools, troubleshoot.
Undeploy tools, M/U new toolstring in PDL. Deploy BHA #8. FVS not holding, some debris in them. Open rams and winch it into PDL, close swab. C/O floats in
FVS. Deploy BHA #8. RIH with BHA #8. Log tie-in from 9040' @ 3 fpm. Correct -37'. Close EDC and RIH past window. RIH while displacing to new drilling mud. In
Rate .74, Out Rate .93. MM In = 8.64, MM Out = 8.64. IA 359, OA 93. Tag and run past 10920'. Drill ahead from 11272'. In Rate 2.95, Out Rate 2.95. MM In = 8.69,
MM Out = 8.65. Circ pressure = 4150. ECD = 9.98 TD called by town Geo @ 11385'. POOH to condition well and log tie-in. In Rate 2.87, Out Rate 2.71. MM In =
8.66, MM Out = 8.63. Circ pressure = 3645. ECD = 9.66. Jog below window. Pull through the window clean. Log tie-in from 9010' @ 3 fpm. Correct - 1.5'. RIH to
confirm TD. Tag 10992' and work past. Confirm TD @ 11,385 with 1.6k WOB. POOH pumping 10 bbl lo/hi vis sweep. 53k PUW off bottom. In Rate 2.76, Out Rate
2.54. MM In = 8.64, MM Out = 8.60. Slight over pull at 11072', 10187'. RBIH and pull through clean.
Confirm TD @ 11,385 with 1.6k WOB. POOH pumping 10 bbl lo/hi vis sweep. 53k PUW off bottom. In Rate 2.76, Out Rate
2.54. MM In
6/18/2022 Continue wiper to window. 10 bbls lo / hi vis sweeps at 9800'. Jog below window and pull through 0.5 bpm, nothing seen. Jog above window and open EDC, jet
tray. POOH pump 3.9 bpm. Drag seen again at 8860' run back in pump sweeps around Continue wiper to surface. Tag stripper, reset depth. RIH back to window.
Pump 10 bbls 9.7# weighted sweep around while tie-in depth. Correct -37.5' Pump 9.7# sweep around 3.5 bpm pull wiper trip from window back to 8750'. No extra
drag seen. Pump sweep to surface, brings back little additional material. Close EDC and pass window, RIH. 2k wt bobble at 10493'. A few 2-3k bobbles through
10850 - 10950' shale zone. Start bead pill. Tag TD 11385' circ liner pill to bit followed by 9.75# brine. Lay in liner pill from 11385' to 9700'. Lay in 9.75# brine from
9700'. Reduce pump to pull through window, nothing seen. Open EDC, finish laying in 9.7# to surface. Continue displacing well to 9.7 ppg brine KWF to surface.
Paint yellow flag at 8700' bit depth. Confirm 9.7 ppg brine KWF at surface. Flow check well and confirm well overbalanced. POOH. Rate In = .94 bpm, Rate Out =
.53 bpm. MM In = 9.7 ppg, MM Out = 9.68 ppg. IA 359, OA 129. ECD = 9.88. Paint white flag @ 6400' bit depth. OOH - Lost ~9 bbls on trip out of hole. Flow check
well and confirm no flow. Inspect coil above CTC and find coil in good condition. L/D BHA #8 Bit graded 6-3 Terminate and boot eline. Pump eline slack forward
and hear eline moving. Recover and cut total of 279' of eline. Rig up to pump drift ball through reel. Pump and recover 7/8" drift ball. Prep to swap BOP rams.
LOTO Koomey. PT swab and master, good. Open BOP doors and swap rams from 3" pipe/slip to 2-3/8" x 3-1/2" VBR's. Fill hole with 3.5 bbls every hour.
6/19/2022 Continue remove 3" P/S rams and install 2-3/8" x 3-1/2" VBR. Button up ram doors. Function test BOPs. Continue fill well ~3 bbl/hr. Shell test BOPs. Grease tree
valves and stack valves. Get good shell test 250 / 3500 psi. Test VBRs with 2-3/8" and 3-1/2" and chart, good. Pressure test QTS break. Prep for liner. Inspect and
grease top drive. Observe fluid in stack, falling slowly. Confirm pipe count and tally with Driller, TP, and Baker rep. MU 3-1/2" x 2-7/8" liner as per tally. D1 drill with
McGrath crew and AAR. Continue MU liner Continue MU 3-1/2" x 2-7/8" liner per tally. MU WellTec packer and Baker Thru Tubing SELRT. MU 6 jts PH6 . MU
injector and MU to well RIH with liner BHA @ 60 fpm per WellTec representative pumping minimum rate. Pump Rate In = .5 bpm, Out Rate = .74. MM In = 9.75,
MM Out = 9.67. IA 42, OA = 41. Stop at white flag 9022.67 - 8991.85' -30.82 correction. Set depth to 8991.85'. PUW 48k , SOW 30k. Displace 9.7 ppg brine with
8.6 ppg drilling mud while slowly reciprocating above window. In Rate = 1.01 bpm , Out Rate = .98 bpm. MW In = 8.6, MW Out = 9.74. Circ pressure = 1403 psi.
Drilling mud back to surface. Drop rate to 0.4 bpm and RIH to TD. RIH weight 29k. Work through the following depths 10313' to 10370', 10507', 10527'. 48k PUW -
clean. Continue working liner from 10885, 10911'. PUW = 52 - 57k. Continue working liner from 10958'. PUW 52 - 57k. Hold additional WHP 300 - 400 psi and
continue to work liner to bottom. 11130' = 59k PUW. 11316' - 58k PUW. Continue working liner to TD.
6/20/2022 Tag at TD 11385'. Pick up and repeat, same depth. Get up wt 54k. Launch 3/4" ball with 1000 psi, is heard rolling. Goes on seat at 39 bbls, shears out at 4200 psi.
New up wt is 40k, repeat. Swap well to 1% KCl. Move fluids around in pits to prep for cement job. With KCl all the way around 2 bpm = 1200 psi ~ 3 bbl/hr loss rate.
Load exhaust pill onto rig PJSM with rig crew, Welltec hand and HES cementers. Troubleshoot In MM. HES pump 3 bbls into CT then PT lines, cmt wet at 13:55.
Load 31.1 bbls cmt into reel. Shut down and pump exhaust back to HES Continue displacement with rig pump. At 73.4 bbls cmt at shoe, zero out MM. Shut down at
86.1 leaving 3 bbls in CT. Get up wt + 16' then set down 14' higher. P/U 2' then pump 3 bbls cmt + 3 bbls exhaust. Set back down, launch LWP with 3100 psi.
Lands at 14.7 bbls away at 2400 psi. Bleed coil and check floats, ok. Total of 25.1 bbls cmt behind pipe. Pressure up to set packer. Takes 2.4 bbls to go from 1800
to 4900 psi. Get to 4900 and bleeding off. Have held 4500 psi for ~15 min. Discuss results with ODE. Bleed off pressure to 2200 psi and unsting from liner top.
Pump excess cement + exhausted cement to surface, POOH. Continue POOH. In Rate 3.0 bpm, Out Rate 2.64 bpm. In MM 8.42, Out MM 8.33. Circ pressure
1550. IA = 409, OA = 161. Reverse jog at surface. Flow check well. Confirm no flow. L/D Baker Liner Running Tools and confirm tools functioned MU swizzel stick
BHA with 2.5" nozzle and BOT check valves. Jet BOP' stack with GeoVis sweep. R/U Thunderbird pump truck and PT to 4000 psi. RIH and freeze protect well from
2500' with 40 bbls diesel and 50/50 methanol cap. POOH. Close swab and master. Flush and inspect all cement lines. R/U Halliburton N2 pump. Pump 30 bbl MI
corrosion inhibitor pill followed by 10 bbl 50/50 MeOH. PT pump line to 4000 psi. Blow down coil with N2. 1500 scf for 20 minutes. Cycle and grease tree vales with
grease crew. Rig injector back. L/D nozzle BHA Nabors begin RDMO check list. Begin R/D cellar. LTT on swab and master. N/D BOP's.
6/21/2022 LTT on swab and master valve. Work through RDMO checklists. Remove BOPs install tree cap, test is good. Release rig at 11:00.
Tag at TD 11385'.
ACTIVITYDATE SUMMARY
6/22/2022
** MIT T ** T/I/O= 15/40/57 MIT T to 2000 psi. ( PASSED) Pumped 2.6 bbls crude
down TBG to 2000 psi. Lost 35 psi. 1st 15 min lost 9 psi 2nd 15 min. Bled 2.4 bbls to
starting pressures. FWHP's = 15/40/57 Tag hung on MV DSO notified of results.
6/22/2022
T/I/O=Vac/0/0. Post CDR2. ND 4" CDR tree and NU 4" CIW production tree, Torque
flanges to API spec. Pressure tested tree against MV to 300/5000 psi fro 5 min ea.
Passed. Connected production and AL piping. Torqued flanges to API spec. Installed
tree work platforms and set wellhouse. ***Job Complete***
6/22/2022
***WELL S/I ON ARRIVAL*** (Perforating)
SET 4 1/2" X-CATCHER IN X-NIPPLE AT 8,663' SLM / 8,676' MD.
PULL BK-DGLV'S FROM ST #2 (7,797' MD) & ST #3 (6,894' MD).
***JOB IN PROGRESS, CONTINUED ON 6/23/22 WSR***
6/23/2022
***CONTINUED FROM 6/22/22 WSR*** (Perforating)
PULL BK-DGLV'S FROM ST #4 (5,668' MD) & ST #5 (3,652' MD).
SET BK-LGLV'S AT ST #5 (3,652' MD), ST #4 (5,668' MD), & ST #3 (6,894' MD).
SET BK-OGLV AT ST #2 (7,797' MD).
PULL EMPTY 4-1/2" X-CATCHER SUB FROM 8,676' MD.
DRIFT TO 9,407' SLM (Dogleg) W/ 2.00" x 34' DUMMY GUN (2.29" swell rings),
2.31" SWAGE.
DRIFT TO DEVIATION AT 9,523' SLM W/ 2.30" G-RING (No issues going by
dogleg).
***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS***
6/25/2022
CTU#6 1.5" CT
Job Objective: Drift/RPM log/ Perf
MIRU CTU. CT tractor issue resolved, but then delay with T-bar, issue also resolved
then continue rig up. Discuss time required for combining drift and RPM with OE and
having only daylight crew. Decision to run drift and perform BOP test then RPM log.
MU SLB drift BHA. RIH w/ SLB CTC 1.5"x.1', DFCV 1.5"x1', Stinger 1.5"x 5.6',
Stinger 1.5"x5', XO 175"x.25', Nozzle 2.3"x.6'. OAL 12.55'. Tag bottom at 11360' PU
and circ out well to 1% KCL w/SL, POOH, FP well from 2500' with diesel. At surface
shut in well. Start BOP test. Shut down for night (daylight only crew).
***Job Continued on 6/26/22***
6/26/2022
CTU#6 1.5" CT Job Objective: Drift/RPM log/Perf
Complete weekly BOP test. MU TBird CTC and MHA, Pull test to 20k, Pressure test
to 4k, RPM tool software issues. Discuss timing with OE and Geo. Logging interval
shortened to accomodate time constraints. MU RPM tools, Stab on well. PT QTS
4000 psi, Open well and RIH with TB CTC 1.66"x .15', MHA 1.66"x1.75' , XO
2.13"x0.2' + Baker Atlas RPM BHA XO 2.13"x1.29, Battery 1.72"x6.37', PSI switch
1.72"x 2.6', CCL/Temp 1.38"x2.94', Comm 1.69"x1.49', GR 1.69"x2.17', RPM
1.70"x4.48', RPM C detector 1.70"x9.40', RPM Source1.70"x4.70' GR 1.69"x2.17',
BN1.69"x.75' OAL 39.97'. RIH and perform 2 logging passes (11350-10900 and
11350-8700). POOH keeping well full with diesel for freeze protect.
***Job Continued on 6/27/22***
Daily Report of Well Operations
PBU 06-21C
Daily Report of Well Operations
PBU 06-21C
6/27/2022
CTU#6 1.5" CT Job Objective: Drift/RPM Log/Perf
At surface, shut swab and SSV. Blow down, bleed off, unstab and break off tools.
Check for data and set injector head/lubricator on deck for night. NO data recovered.
Wait on OE decision. Back on location 0900, change packoffs, re-head, then MU
RPM tools. RIH with TBird CTC 1.66"x.15, MHA 1.66" x 1.75', XO 1.69"x .2'+
Baker Atlas RPM BHA (XO 2.13"x1.29, Battery 1.72"x6.37', PSI switch 1.72"x 2.6',
CCL/Temp 1.38"x2.94', Comm 1.69"x1.49', GR 1.69"x2.17', RPM 1.70"x4.48', RPM C
detector 1.70"x9.40', RPM Source1.70"x4.70' GR 1.69"x2.17', BN1.69"x.75' OAL
39.97'. Tag PBTD at 11349.6e/11350 m. PU 50' paint (ORANGE) flag. Tools turn
on, RIH to bottom tag same sport 11349.6. Wait on Baker for base line. POOH at
20'/min to log 1st pass of liner. RIH from 8850', POOH at 20'/min to log 2nd pass of
liner. OUt of liner (logging interval), POOH at 80'/min.
***Job Continued on 6/28/22***
6/28/2022
CTU#6 1.5" CT Job Objective: Drift/RPM Log/Perf
At surface, shut swab and SSV. Blow down, bleed off, unstab and break off tools.
Check for data and set injector head/lubricator on deck for night. Return to location
at 11am. Waiting on logs and perf interval selection. OE has SLB re-configure guns.
MU 30' of SLB 2" guns (6 spf, 60 degree) and RIH, Tag PBTD 11,353' ctm / 11,364'
PBTD. PU wt back at 11349', +15' correction to PBTD. Correct counter to bottom
shot. PUH and Perforate interval 11,279' MD - 11,290' MD and 11,301' MD - 11,306'
MD. Pooh w/guns. FP tubing w/24 bbls of diesel. Secure well, rig down for the night.
*** Job Continued on 6/29/22***
6/29/2022
CTU#6 1.5" CT Job Objective: Drift/ RPM log/ Perf
M/U 30' of SLB 2" guns (6 spf, 60 degree) and RIH. Tagged PBTD at 11353' ctm /
11,364' PBTD. PU and get weight back 11,350' ctm = +14' correction to PBTD.
Correct counter to bottom shot. PUH and Perforate interval 11,161' MD - 11,172' MD
and 11,183' MD - 11,188' MD. Pooh w/guns. On surface w/BHA, lay down guns.
RDMO CTU6.
***Job Completed, Pad Op to pop well***
and Perforate interval 11,279' MD - 11,290' MD and 11,301' MD - 11,306'
MD.
Perforate interval 11,161' MD - 11,172' MD
and 11,183' MD - 11,188' MD.
(p g) g
11349', +15' correction to PBTD.
WELL NAME
Date :
Shoe @ :FC @ :Top Liner @ :
Type:
Type :
Type :
Type :
Type :
XYes No
Yes X No Yes X No
XYes No Yes No
Date :
Volume lost during displacement (bbls) : 3.00
Remarks:
FI
R
S
T
S
T
A
G
E
11385 11371 / 11382 8911
Preflush (Spacer)
1% KCl
Cement In Place At : 18:00 6/20/2022 Estimated TOC : 8,911
Method Used To Determine TOC : Calculated based on losses
4900
Casing Rotated? Reciprocated? % Returns during job : 89
Cement returns to surface? Spacer returns? Vol to Sur : 5
FCP (psi) : 2400 Pump used for disp : Rig Pump(GD) Plug Bumped? Bump press :
Volume :
Displacement :
Geovis Density (ppg) : 8.4 Rate (bpm) : 1.5 Volume (actual / calculated) : 200
Post Flush (Spacer)
Density (ppg) : Rate (bpm) :
Tail Slurry
Volume (bbls) : Density (ppg) :
Yield : Sacks : Mixing / Pumping Rate (bpm) :
15.3
Yield : 1.23 Sacks : 142 Mixing / Pumping Rate (bpm) : 1.5 / 2.5
Density (ppg) :
Lead Slurry
Class G Volume (bbls): 31.1
Density (ppg) : 8.4 Volume pumped (bbls) : 100
06-21C CEMENT REPORT
20-Jun-22 Hole Size :4.25"Casing Size :2-7/8" x 3-1/2"
3.00
89
X
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: 07/11/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: PBU 06-21C
PTD: 222-088
API: 50-029-20802-03-00
FINAL LWD FORMATION EVALUATION LOGS (06/10/2022 to 06/18/2022)
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:221-088
T36746
Kayla Junke
Digitally signed by
Kayla Junke
Date: 2022.07.12
10:27:51 -08'00'
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Date: 2022.04.27
14:49:50 -08'00'
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7. If perforating:
1. Type of Request:
2. Operator Name:
3. Address:
4. Current Well Class:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Property Designation (Lease Number):10. Field/Pool(s):
Abandon
Suspend
Plug for Redrill Perforate New Pool
Perforate
Plug Perforations
Re-enter Susp Well
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well
Other:
Change Approved Program
Operations shutdown
What Regulation or Conservation Order governs well spacing in thes pool?
Will planned perforations require a spacing exception?Yes No
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD):
PRESENT WELL CONDITION SUMMARY
Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft):
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
12. Attachments:
14. Estimated Date for
Commencing Operations:
13. Well Class after proposed work:
15. Well Status after proposed work:
16. Verbal Approval:
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal.
Proposal Summary Wellbore schematic
BOP SketchDetailed Operations Program
OIL
GAS
WINJ
WAG
GINJ
WDSPL
GSTOR
Op Shutdown
Suspended
SPLUG
Abandoned
ServiceDevelopmentStrastigraphicExploratory
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
AOGCC USE ONLY
Commission Representative:
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Location ClearanceMechanical Integrity TestBOP TestPlug Integrity
Other:
Post Initial Injection MIT Req'd?
Spacing Exception Required?Yes
Yes No
No Subsequent Form Required:
Approved By:Date:
APPROVED BY
THE AOGCCCOMMISSIONER
PBU 06-21C
CTU Extended Perf
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400,
Anchorage, AK 99503
221-088
50-029-20802-03-00
ADL 0028311
~11289
Surface
Intermediate
Liner
Liner
Liner
~8948
2479'
7266'
5938
247
2359
TBD
13-3/8"
9-5/8"
7"
4-1/2"
3-1/2" x 3-1/4" x 2-7/8"
TBD
29 - 2511
27 - 7293
3032 - 8970
8808 - ~9055
~8930 - ~11289
2380
29 - 2511
27 - 7091
3032 - 8852
8451 - ~8648
~8550 - ~8948
none
2670
4760
5410
7500
none
5380
6870
7240
8430
None 4-1/2" 12.6#13Cr80 24 - 8813None
Conductor 80'20" 29 - 109 29 - 109 1490 470
4-1/2" Baker S-3
No SSSV Installed
8736
8393
Date:
Bo York
Operations Manager
Ryan Thompson
Ryan.Thompson@hilcorp.com
(907) 564-5280
Prudhoe Bay Field, Prudhoe Oil Pool
6/1/2022
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng
Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval.
By Samantha Carlisle at 1:22 pm, Nov 23, 2021
321-604
Digitally signed by Bo York
DN: cn=Bo York, c=US, o=HIlcorp
Alaska LLC, ou=Alaska North
Slope, email=byork@hilcorp.com
Date: 2021.11.23 11:21:40 -09'00'
Bo York
10-404
MGR26NOV21
X
DSR-11/23/21DLB 11/24/2021
dts 11/30/2021
11/30/21
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2021.11.30 11:24:35
-09'00'
RBDMS HEW 12/1/2021
Extended Add Perf
06-21C
PTD: 221-088
Well Name: 06-21C API Number: 50-029-20802-03-00
Current Status: Shut In Rig: CTU & Surface
Deployed TCP Guns
Estimated Start Date: 6/1/22 Estimated Duration: 2 Days
Regulatory Contact: Carrie Janowski Permit to Drill Number: 221-088
First Call Engineer: Ryan Thompson 907-564-5280 / 907-301-1240
Second Call Engineer: Dave Bjork 907-564-4672 / 907-440-0331
Expected Bottom Hole Pressure: 3260 psi @ 8,800’ TVD 7.2 PPGE
Max. Anticipated Surface Pressure: 2380 psi (Based on 0.1 psi/ft. gas gradient)
Last SI WHP: 2430 psi (06-21B) (Taken on 10/21/20)
Min ID: 2.31” ID @ LTP (Installed if necessary)
Max Angle: 102° Deg @ 10000’ MD
Tie in Log: Baker RPM to be run on Service coil post CTD
Brief Well Summary:
Well 06-21B is planned to be CTD sidetracked in Spring 2022 into the GDWFI of the Ivishak formation.
Objective:
The intent of this program is to perform the post CTD work to get the well on production.
Cerberus Modelling suggests achieving target depth with a 250’ gun run.
Extended Add Perf
06-21C
PTD: 221-088
Slickline
1. If CTD rig is unable to obtain a passing LTT, set Liner Top Packer in deployment sleeve at ~8900’.
2. MIT-T to 2500 psi.
3. Set KO GLV’s.
Note: Drilling mud weights/ECDs will be used to estimate mud weight needed for this perf job. If pressure is seen
immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up
through the same port that opened to shear the firing head.
Coil Tubing
1. MIRU Coiled Tubing Unit and spot ancillary equipment.
2. MU and RIH with ~2.3” nozzle, drift to PBTD. At PBTD, perform flow check and circulate 8.4 ppg 1% KCl
KWF as needed.
a. Post CTD wellbore is planned to have 1% KCL from TD to 2200’ and FP fluid from 2200’ to
surface.
b. Note the well should be a closed system at this point as no perfs have been added.
3. Run RPM log to determine perf depths.
4. POOH and confirm good data.
5. Contact OE/Geo to verify perf depths.
6. Freeze protect tubing as needed. Prepare for deployment of TCP guns.
7. Pickup safety joint and TIW valve and space out before MU guns. Review well control steps with crew
prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety
joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the
working platform for quick deployment if necessary.
8. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.
06-21C Add perf Schedule
Perf Interval Perf
Length
Gun
Length
Weight of
Gun (lbs)
at 5.58 ppf
Comments
Run 1 TBD ~100 ~250’ 1395 lbs Final lengths TBD at conclusion
of RPM
9. RIH with perf gun and tie-in. Pickup and perforate intervals per Perf Schedule above. POOH.
a. Note any tubing pressure change in WSR.
10. POOH. Stop at surface to reconfirm well is dead and hole is full.
a. Recalculate KWF weight as necessary and bullhead kill the well
11. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown
of TCP gun string.
12. RDMO CTU.
13. FP well.
*See note above regarding kill methods if pressure observed at
surface after perforating.
Standing orders flow chart included with this sundry request.
*
Maintain continuous hole fill taking returns to tank until lubriator connection is re-established.
MU PCE.
Extended Add Perf
06-21C
PTD: 221-088
Attachments:
1. As-built Schematic
2. Proposed Schematic
3. Coil Tubing BOPE Schematic
4. Equipment Layout Diagram
5. Standing Orders for Open Hole Well Control during Perf Gun Deployment
Extended Add Perf
06-21C
PTD: 221-088
As-built Schematic
Extended Add Perf
06-21C
PTD: 221-088
Proposed Schematic
Extended Add Perf
06-21C
PTD: 221-088
Coiled Tubing BOPs
Extended Add Perf
06-21C
PTD: 221-088
Equipment Layout Diagram
Extended Add Perf
06-21C
PTD: 221-088
Standing Orders for Open Hole Well Control during Perf Gun Deployment
Standing Orders for Service Coiled Tubing Operations While Deploying Extended Length
Perforating BHA
WELL BEGINS FLOWING DURING OPEN HOLE DEPLOYMENT
Pull BHA above
blind/shear rams, and
close blind/shears.
Space out BHA with
safety joint above slip
bowl, set hand slips
Install safety joint with
open TIW
Can BHA be pulled above
blind/shear rams in a single
pick?
Pull hand slips
YES NO
Begin Notifications
Close Upper Pipe/Slip
Ram
Close TIW
Close choke valves, monitor
and record SIWHP
Close choke line.
Monitor and record
SIWHP
Lower safety joint and
space out over BOP, set
hand slips
Begin Notifications
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 Myers
Drilling Manager
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400
Anchorage, AK, 99503
Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-21C
Hilcorp North Slope, LLC
Permit to Drill Number: 221-088
Surface Location: 467' FSL, 960' FEL, Sec. 02, T10N, R14E, UM, AK
Bottomhole Location: 1313' FNL, 2592' FEL, Sec. 11, 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 well logs
run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment
of this well.
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,
Jeremy M. Price
Chair
DATED this ___ day of October, 2021.
Jeremy
Price
Digitally signed by
Jeremy Price
Date: 2021.10.22
09:57:28 -08'00'
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address:6. Proposed Depth:12. Field/Pool(s):
MD: 11,289' TVD: 8,948'
4a. Location of Well (Governmental Section):7. Property Designation:
Surface:
Top of Productive Horizon:8.DNR Approval Number:13.Approximate Spud Date:
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL (ft): 65.73' 15.Distance to Nearest Well Open
Surface: x-686026 y- 5941066 Zone- 4 37.0' to Same Pool: 10'
16.Deviated wells: Kickoff depth: 9,055 feet 17.Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 102 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
4-1/4"3-1/2"x3-1/4"9.3#/6.6# 13Cr80 STL/TCII 2,389' 8,900' 8,526' 11,289' 8,948'
x2-7/8" /6.5# /STL
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
None
TVD
109'
2,511'
7,091'
3,032' - 8,852'
8,451' - 8,923'
Hydraulic Fracture planned? Yes No
20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name: Trevor Hyatt
Monty Myers Contact Email:trevor.hyatt@hilcorp.com
Drilling Manager Contact Phone:777-8396
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
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 Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
April 1, 2022
21,100'
8,808' - 11,733'
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Surface
Perforation Depth TVD (ft):
GL / BF Elevation above MSL (ft):
Perforation Depth MD (ft):
2,479'
1900# Poleset 109'
2,511'13-3/8" 2259 sx Fondu, 400 sx PF 'C'
Effect. Depth MD (ft): Effect. Depth TVD (ft):
Authorized Title:
Authorized Signature:
4-1/2"
7,293'
324 sx LiteCrete, 165 sx Class 'G'
375 sx Class 'G'
Liner
Liner
7,266'
5,938'
2,925'
Intermediate
Authorized Name:
8,972' - 11,640'
Conductor/Structural 20"80'
11,735'8,923'
LengthCasing
9,360', 10,990', 11,312'
Cement Volume MDSize
Plugs (measured):
(including stage data)
174 sx Class 'G'
9,360' 8,837'
2560
18.Casing Program: Top - Setting Depth - BottomSpecifications
3,260
Total Depth MD (ft): Total Depth TVD (ft):
107205344
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
2,380
622' FSL, 2519' FEL, Sec. 02, T10N, R14E, UM, AK
1313' FNL, 2592' FEL, Sec. 11, T10N, R14E, UM, AK
72-019
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
Hilcorp North Slope, LLC
467' FSL, 960' FEL, Sec. 02, T10N, R14E, UM, AK ADL 028311
PBU 06-21C
Prudhoe Bay Field
Prudhoe Oil Pool
Cement Quantity, c.f. or sacks
Commission Use Only
See cover letter for other
requirements.50-029-20802-03-00
8,854' - 8,919'
500 sx Class 'G', 50 BBls Class 'G'
3,032' - 8,970'7"
9-5/8"
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
10.19.2021
By Samantha Carlisle at 10:09 am, Oct 19, 2021
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2021.10.19 09:47:40 -08'00'
Monty M
Myers
DLB
X
X
221-088
BOPE test to 3500 psi.
Variance to 20 AAC 25.112(i) Approved for alternate plug placement.
X
X
Not included
MGR19OCT2021 DLB 10/20/2021
X
X
X
DLB
X
DSR-10/19/21
dts 10/21/2021 JLC 10/22/2021
10/22/21
Jeremy Price Digitally signed by Jeremy Price
Date: 2021.10.22 09:57:45 -08'00'
To: Alaska Oil & Gas Conservation Commission
From: Trevor Hyatt
Drilling Engineer
Date: October 19, 2021
Re: PBU 06-21C Permit to Drill
Approval is requested for drilling a CTD sidetrack lateral from well PBU 06-21B with the
Nabors CDR2 Coiled Tubing Drilling.
Proposed plan for 06-21C Producer:
See 06-21B Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to
drift for whipstock and MIT-IA / MIT-OA. A 4-1/2" Whipstock will be set pre-rig with E-line in the 4-1/2" liner. The
parent Sag perforations will remain open. Service Coil will mill the XN-nipple and a single string window in the 4-
1/2” liner (if scheduling needs arise, the rig will mill the window).
A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the
well. The well will kick off drilling in the Shublik, build through the Ivishak and land in Zone 2. The lateral will build
back up to Zone 4 and drop to Zone 3 at TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-
7/8” 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will completely isolate
and abandon the parent Sag perforations.
The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is
attached for reference.
Pre-Rig Work:
x Reference 06-21B Sundry submitted in concert with this request for full details.
x General work scope of Pre-Rig work:
1.Slickline: Dummy WS drift
2.Fullbore: MIT-IA and MIT-OA
3. E-line: Set Whipstock
4.Service Coil: Mill XN Nipple and Window
Rig Work - (Estimated to start in April 2022):
1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,380 psi
a.Give AOGCC 24hr notice prior to BOPE test
b. Test against swab and master valves (No TWC)
c. Load pits with drilling fluid
d.Open well and ensure zero pressure
2.Only if not done pre-rig - Mill 3.80” single string window (out of 4-1/2”) plus 10’ of rathole.
a. Top of window (whipstock pinch point) at 9,055’ MD.
b.Hold 9.8 ppg MPD while milling window
3.Drill – Build & Lateral
a.3” BHA with GR/RES / Bi-center Bit (4.25”)
b.35° DLS build section – 270’ MD / Planned TD 9,325’ MD
c. 12° DLS lateral section – 1,964’ MD / Planned TD 11,289’ MD
d.Drill with a constant bottom hole pressure for entire sidetrack
e.Pressure deployment will be utilized
f.After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run
g.No flow test prior to laying down drilling BHA. Assure well is dead prior to picking up liner.
PTD221-088
Sundry 321-548
4. Run and Cement Liner
a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner
b. Run 3-1/2”x3-1/4”x2-7/8” 13Cr solid liner to TD
c. Swap well over to KCl
d.Cement Liner with 36 bbls - 15.3 ppg Class G cement (TOC to TOL)*
e.Freeze protect well from ~2200’ MD (min)
f. RDMO
Post Rig:
1. V: Valve & tree work
2.S: Set LTP* (if necessary) and set live GLVs
3.C: Post rig perforate (~100’) and RPM Log
* 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 (9,055’ MD - 8,648’ TVD)
Pumps On Pumps Off
A Target BHP at Window (ppg)4,412 psi 4,412 psi
9.81
B Annular friction - ECD (psi/ft)543 psi 0 psi
0.06
C Mud Hydrostatic (ppg)3,867 psi 3,867 psi
8.6
B+C Mud + ECD Combined 4,411 psi 3,867 psi
(no choke pressure)
A-(B+C)Choke Pressure Required to Maintain 1 psi 544 psi
Target BHP at window and deeper
gg
Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom holegp g q py p
pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface DLBpressure. C
py
Operation Details:
Reservoir Pressure:
x The maximum reservoir pressure is expected to be 3,260 psi at 8,800’ TVD (7.1 ppg equivalent).
x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,380 psi.
Mud Program:
x Drilling: Minimum MW of 8.4 ppg KCL with Geovis for drilling. Managed pressure used to maintain
constant BHP.
x KWF will be stored on location. The tankage will contain 1.5 wellbore volumes of KWF to exceed the
maximum possible BHP to be encountered as the lateral is drilled. Adjust with real time BHP monitoring.
x Completion: A minimum MW 8.4 ppg KWF to be used for liner deployment. Will target 9.8 ppg to match
managed pressure target.
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 4.25” hole for the entirety of the production hole section.
Liner Program (E-26B):
x 3-1/2”, 9.3#, 13Cr solid/cemented liner: 8,900’ MD – 8,930’ MD (30’ liner)
x 3-1/4”, 6.6#, 13Cr solid/cemented liner: 8,930’ MD – 9,400’ MD (470’ liner)
x 2-7/8”, 6.5#, 13Cr solid/cemented liner: 9,400’ MD – 11,289’ MD (1,889’ 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 2-3/8” 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 3,500 psi.
x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations.
x An X-over shall be made up to a 2-3/8” safety joint including a TIW valve for all tubulars ran in hole.
x Exemption request to 20 AAC 25.036 - Liner rams in the BOPE. A 2-3/8” safety joint will be utilized while
running 2-7/8”, 3-1/4”, 3-1/2” 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 2-3/8” 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 102°. Inclination at kick off point is 40°.
x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
x Distance to nearest property line – 21,100’
x Distance to nearest well within pool – 10’
Logging:
x MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section.
x Real time bore pressure to aid in MPD and ECD management.
Perforating:
x ~100’ perforated post rig (See future perforating sundry request – if extended perforating is used)
g
Drilling:
DLBconstant BHP.
g Minimum MW of 8.4 ppg KCL with Geovis for drilling. Managed pressure used to maintain
Anti-Collision Failures:
x No failures for 06-21C WP02
Hazards:
x PBU DS 06 is an H2S pad. The highest recorded H2S on the pad was from 06-09 (395 ppm) in 1987.
Last recorded H2S on 06-21B was 12 ppm in 2020
x Two fault crossings expected.
x Medium lost circulation risk.
Trevor Hyatt CC: Well File
Drilling Engineer Joseph Lastufka
907-223-3087
DLB
Last recorded H2S on 06-21B was 12 ppm in 2020
PBU DS 06 is an H2S pad. The highest recorded H2S on the pad was from 06-09 (395 ppm) in 1987.pg
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7700787580508225840085758750892591009275True Vertical Depth (350 usft/in)-350 -175 0 175 350 525 700 875 1050 1225 1400 1575 1750 1925 2100 2275 2450 2625 2800 2975Vertical Section at 222.51° (350 usft/in)06-21C Polygon800085009000945206-2190009500950306-21A800085009000950010000
1 0 5 0 0
110001 1 5 0 0
1 17 3 5
06-21B2 7/8" x 4 1/4"95001 0 0 0 0
1 0 5 0 01100011289 06-21C WP02KOP : Start Dir 9º/100' : 9055' MD, 0'TVD : 180° RT TFStart Dir 35º/100' : 9075' MD, 15.49'TVDStart Dir 12º/100' : 9325' MD, 217.68'TVDTotal Depth : 11288.61' MD, 46.12' TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: 06-21Ground Level: 37.00+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.005941065.63686025.55 70° 14' 38.1886 N 148° 29' 50.5454 WSURVEY PROGRAMDate: 2019-10-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool91.73 7291.73 1 : Camera based gyro multisho (06-21) 3_CB-Film-GMS7293.00 7722.56 06-21B Srvy 1 Inc+Trend (06-21B) 3_MWD_Interp Azi (BP INC+Trend)7820.36 8910.37 06-21B Srvy 2 MWD+IFR+MS (06-21B) 3_MWD (BP MWD+IFR+MS-WOCA)9020.17 9055.00 06-21B Srvy 3 MWD+IFR+MS (06-21B) 3_MWD (BP MWD+IFR+MS-WOCA)9055.00 11288.61 06-21C WP02 (06-21C) 3_MWDREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well 06-21, True NorthVertical (TVD) Reference:RT @ 65.73usft (06-21B)Measured Depth Reference:RT @ 65.73usft (06-21B)Calculation Method: Minimum CurvatureProject:Prudhoe BaySite:06Well:06-21Wellbore:06-21CDesign:06-21C WP02CASING DETAILSTVD TVDSS MD SizeName8948.11 8882.38 11288.61 2-7/8 2 7/8" x 4 1/4"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 9055.00 40.14 338.73 8647.94 131.14 -1549.21 0.00 0.00 950.16 KOP : Start Dir 9º/100' : 9055' MD, 0'TVD : 180° RT TF2 9075.00 38.34 338.73 8663.43 142.93 -1553.80 9.00 180.00 944.57 Start Dir 35º/100' : 9075' MD, 15.49'TVD3 9325.00 52.79 188.08 8881.11 109.95 -1606.61 35.00 -157.00 1004.57 Start Dir 12º/100' : 9325' MD, 217.68'TVD4 9638.61 90.00 181.99 8979.50 -180.94 -1630.48 12.00 -10.00 1235.135 9838.61 101.73 160.91 8958.86 -376.27 -1601.51 12.00 -60.00 1359.546 9888.61 101.67 167.03 8948.71 -423.30 -1588.00 12.00 90.00 1385.087 10163.61101.39 200.73 8892.16 -687.94 -1606.01 12.00 87.00 1592.338 10438.61 99.54 167.21 8840.79 -953.62 -1624.22 12.00 -90.001800.499 10688.61 88.56 195.24 8822.82 -1200.06 -1629.92 12.00 110.001986.0010 10938.61 78.89 166.64 8850.70 -1445.59 -1634.53 12.00 -110.00 2170.1111 11138.61 71.78 190.36 8901.99 -1637.31 -1628.85 12.00 110.002307.6012 11288.61 72.70 171.48 8948.11 -1779.38 -1631.07 12.00 -90.00 2413.83 Total Depth : 11288.61' MD, 46.12' TVD
-1950
-1800
-1650
-1500
-1350
-1200
-1050
-900
-750
-600
-450
-300
-150
0
150
300
450
South(-)/North(+) (300 usft/in)-2550 -2400 -2250 -2100 -1950 -1800 -1650 -1500 -1350 -1200 -1050 -900 -750 -600 -450
West(-)/East(+) (300 usft/in)
06-21C Polygon
550057506000625065006750700072507500775082508750918706-219000909506-21A77508 0 0 0
8 2 5 0
8 5 0 0
8 7 5 0 06-21B2 7/8" x 4 1/4"
8 9 4 8
0 6 -2 1 C W P 0 2
KOP : Start Dir 9º/100' : 9055' MD, 0'TVD : 180° RT TF
Start Dir 35º/100' : 9075' MD, 15.49'TVD
Start Dir 12º/100' : 9325' MD, 217.68'TVD
Total Depth : 11288.61' MD, 46.12' TVD
CASING DETAILS
TVD TVDSS MD Size Name
8948.11 8882.38 11288.61 2-7/8 2 7/8" x 4 1/4"
Project: Prudhoe Bay
Site: 06
Well: 06-21
Wellbore: 06-21C
Plan: 06-21C WP02
WELL DETAILS: 06-21
Ground Level: 37.00
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00 5941065.63 686025.55 70° 14' 38.1886 N 148° 29' 50.5454 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well 06-21, True North
Vertical (TVD) Reference:RT @ 65.73usft (06-21B)
Measured Depth Reference:RT @ 65.73usft (06-21B)
Calculation Method:Minimum Curvature
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0.001.002.003.004.00Separation Factor9150 9300 9450 9600 9750 9900 10050 10200 10350 10500 10650 10800 10950 11100 11250 11400 11550 11700 11850Measured Depth (300 usft/in)06-0406-16A06-2106-21A06-21BNo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:06-21 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 37.00+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005941065.63 686025.5570° 14' 38.1886 N 148° 29' 50.5454 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well 06-21, True NorthVertical (TVD) Reference:RT @ 65.73usft (06-21B)Measured Depth Reference:RT @ 65.73usft (06-21B)Calculation Method: Minimum CurvatureSURVEY PROGRAMDate: 2019-10-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool91.73 7291.73 1 : Camera based gyro multisho (06-21) 3_CB-Film-GMS7293.00 7722.56 06-21B Srvy 1 Inc+Trend (06-21B) 3_MWD_Interp Azi (BP INC+Trend)7820.36 8910.37 06-21B Srvy 2 MWD+IFR+MS (06-21B) 3_MWD (BP MWD+IFR+MS-WOCA)9020.17 9055.00 06-21B Srvy 3 MWD+IFR+MS (06-21B) 3_MWD (BP MWD+IFR+MS-WOCA)9055.00 11288.61 06-21C WP02 (06-21C) 3_MWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)9150 9300 9450 9600 9750 9900 10050 10200 10350 10500 10650 10800 10950 11100 11250 11400 11550 11700 11850Measured Depth (300 usft/in)NO GLOBAL FILTER: Using user defined selection & filtering criteria9055.00 To 11288.61Project: Prudhoe BaySite: 06Well: 06-21Wellbore: 06-21CPlan: 06-21C WP02Ladder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name8948.11 8882.38 11288.61 2-7/8 2 7/8" x 4 1/4"
Well Bighole 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 6.0 ft
Top of Annular Element 6.7 ft
Bottom Annular 8.0 ft
CL Blind/Shears 9.3 ft
CL 2-3/8" Pipe/Slips 10.1 ft
B1 B2 B3 B4 Choke Line
Kill Line
CL 3" Pipe/Slips 12.6 ft
CL 2-3/8" Pipe/Slips 13.4 ft
CL of Top Swab 16.0 ft
Swab Test Pump Hose
T1 T2
Swab 1
CL of Flow Cross 17.4 ft
Master
CL of Master 18.8 ft
LDS
IA
OA
LDS
Ground Level
CDR2-AC 4 Ram BOP Schematic 15-Jan-21
CDR2 Rig's Drip Pan
7-1/16" 5k Flange X 7" Otis Box
Hydril 7 1/16"
Annular
2-3/8" Pipe/Slips
7-1/16"
5k Mud
Cross
2-3/8"Pipe/Slips
Blind/Shear
7-1/16"
5 Mud
Cross
3" Pipe/Slips
Revised 2/2015
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
No. _____________, API No. 50-_______________________.
Production should continue to be reported as a function of the original
API number stated above.
Pilot Hole
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both
well name (_______________________PH) and API number
(50-_____________________) from records, data and logs acquired for
well (name on permit).
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of
a conservation order approving a spacing exception.
(_____________________________) as 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' sample intervals from below the permafrost or from where
samples are first caught and 10' 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
well ( ) until after ( )
has designed and implemented a water well testing program to provide
baseline data on water quality and quantity.
(________________________) must contact the AOGCC to obtain
advance approval of such 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 (_______________________________) 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 well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this
well.
PBU 06-21C
X
Prudhoe Bay Prudhoe Oil
X
221-088
X
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