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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: 09/15/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: PBU P1-23L1
PTD: 221-096
API: 50-029-22690-60-00
FINAL LWD FORMATION EVALUATION LOGS (08/21/2022 to 08/26/2022)
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:221-096
T37015
Kayla Junke Digitally signed by Kayla Junke
Date: 2022.09.15 12:59:38 -08'00'
RECEIVED by James Brooks at 3:17 pm, 9/7/2022
Completed
8/28/2022
JSB
RBDMS JSB 091422
GMGR20SEP2022DSR-9/14/22
9.7.2022
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: 2022.09.07 15:09:14 -08'00'
Monty M
Myers
Activity Date Ops Summary
8/18/2022 P1-122 & P1-24 wells shut in. Spot main & pits subs over P1-23. Subs spotted accept rig at 07:30. Notified DSO that both adjacent wells can be put back online. Start
MIRU Checklist. PT tree cap & MPD Valves to 3500psi, good PT. RU MPD Line. NU BOPE. Grease Valves on stack. MU Nozzle and stab on. Fill coil & calibrate In & Out
MM. Replace pressure transducer. Flush and fluid pack surface lines. Test BOPs, test witness is waived by AOGCC inspector Guy Cook. All tests to 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 - 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 6: Choke A, Choke C - Pass. Drawdown. Test 7: C1, C4, TV1 - Pass Test 8: 3"
Pipe/Slips, C2, C3 - Pass Rig down BOP test equipment. Swap out CT risers. Get RKBs. Put weight bar on PDL swivel for PT. Complete valve checklist. PT tiger tank
line and PDL together, good. Install floats in UQC.
8/19/2022 Install BHI Floats and test connections. Shut-Ins: P1-01 (shut in and FP) P1-21 (MI Gas DSO will notify us when shut in today). Good PT on connections bleed off and PT
the floats. Good PT on floats. MU Nozzle BHA and stab on well. Pump 10 bbls of neat meth followed by 140° 1% SLK KCl with SafeLube into the coil at max rate. Slack is
pumped forward. Coil displaced, open swab & master valves, 0 psi on well. RIH pumping at 1.5 bpm taking all returns out to the TT holding 100psi WHP. 7000' getting
gas cut fluid back. No tag at 13,011', stop at 13,060' for WT CK. PU WT = 60k, 30k RIH WT. Shut down pump and PUH to the TT. RIH dry to 13,030' clean. 300 bbls in
TT PUH to 12,800 while vac truck pulls fluid from TT, still getting gas cut returns;TT is empty, start bottoms up kill with Hot KCl. Rate In = 4.5 bpm, Rate Out = 4.19 bpm.
Circ Pressure = 2863 psi, WHP = 336 psi. Bottoms up returns are clean. 290 bbls of KCl away swap to mud. Good mud at surface, bring inside to the pits. Rate in = 1.25
bpm, Out Rate = 1.02 bpm, purge lubricator. Shut down pump and flow check well, out rate dropped right off, no breathing. Good no flow, fill the well to check for loss rate.
Well took 1.5 bbls in 10 min = 9 BPH, POOH for WS BHA;10 min flow check at surface, static. Lift off injector, remove nozzle BHA. M/U BHA #2 whiptock and setting
tools. Verify EDC open, RIH. Set electronic trips close for pump pressure and slackoff. On bottom rate 0.5 / 0.4 bpm In / Out. Tie-in depth from 12853'. Correct -34.5'. Prior
to CCL drift down to 13020', clean (No DWOB during CCL). Pick up log CCL down, no correction needed. Get to set depth and close EDC. Setting tool shears out at 3800
psi. Top Whipstock 12950' @ 30L. Set 3.3k DWOB on it, good set. Open EDC, POOH. At surface, 10 min flowcheck is good. L/D whipstock setting BHA, tools have func-
tioned normally. M/U window milling BHA. Mill 3.80" Go Reamer 3.81" Go. Drift and rattle PH-6.
8/20/2022 RIH with Window Milling BHA 12800' Log tie in. Correct Depth -58', WT CK = 61k, RIH WT = 29k. RIH to dry tag WS, tag at 12955.5'. PU, online with pumps and work
down to start milling the window. Start milling window at 12956'. In Rate = 2.72 bpm, Out Rate = 2.49 bpm. Circ Pressure = 2466 psi, IAP = 2 psi, OAP = 0 psi. MWT In =
8.62 ppg, MWT Out = 8.66 ppg, ECD = 9.84 ppg. WHP = 40 psi, WOB = 0.7k Milling window at 12958.5'. In Rate = 2.72 bpm, Out Rate = 2.63 bpm. Circ Pressure =
2558 psi, IAP = 2 psi, OAP = 0 psi. MWT In = 8.62 ppg, MWT Out = 8.64 ppg, ECD = 9.80 ppg. WHP = 43 psi, WOB = 2.8k Milling window at 12960.0'. In Rate = 2.78
bpm, Out Rate = 2.65 bpm. Circ Pressure = 2519 psi, IAP = 3 psi, OAP = 0 psi. MWT In = 8.61 ppg, MWT Out = 8.64 ppg, ECD = 9.81 ppg. WHP = 46 psi, WOB = 3.2k.
Milling window at 12962.0'. In Rate = 2.71 bpm, Out Rate = 2.64 bpm. Circ Pressure = 2629 psi, IAP = 3 psi, OAP = 0 psi. MWT In = 8.60 ppg, MWT Out = 8.64 ppg,
ECD = 9.81 ppg. WHP = 45 psi, WOB = 2.0k. 12962.5 WOB dropping off, continue 1 fph for string mill to dress the bottom of the window. 6.5' window. Milling Rat Hole at
12963.5' to 12973'. In Rate = 2.66 bpm, Out Rate = 2.64 bpm. Circ Pressure = 2634 psi, IAP = 2 psi, OAP = 0 psi. MWT In = 8.61 ppg, MWT Out = 8.63 ppg, ECD =
9.80 ppg. WHP = 41 psi, WOB = 3.5k Ream window 1 ft/min. Well on sligh losses while reaming. Pump 10 bbls lo / hi vis sweeps. Sample from 12970' is 80% formation.
Slight motor work seen at 12958' (down) and 12956' (up). Ream 5 up 4 down until motor work < 20 psi. Dry drift is clean, tag 12973' Open EDC, dynamic flow check is
good, well on ~4 bbl/hr losses. Pump 3.2 bpm / 2500 psi. Pick up log CCL across liner top area. POOH. At surface, 10 min flow check is good. Inspect 50' of CT, nothing
seen. L/D window milling BHA, mill is 3.80" go reamer 3.81" go. M/U nozzle and jet stack. Build BHA #5. Stop and fix spill deflector around CT riser. M/U BHA #5, M/U
injector. RIH. At 5100' lose communication with BHA. POOH. POOH for tool failure. At surface, pull BHA out and test UQC, good. L/D BHA.
8/21/2022 At surface remove injector and pull the BHA. Test UQC on the coil for COMMS, good test, swap out BHA for possible MWD P&C Failure. RIH with Build BHA Off NPT at
5100', continue RIH. 12830' log tie in. Correct depth -43 but Geo says he is having a hard time correlating the depth because there is so much scale. RIH and see where
we tag, tag at 12966', TD of Rat Hole should be 12973', PUH and tie in again. Correct Depth +2', RIH Tag at 12968' got weight back and tagged at 12975' PU, online with
pumps to start drilling. In Rate = 2.78 bpm, Out Rate = 2.68 bpm. Circ Pressure = 2623 psi, IAP = 2 psi, OAP = 0 psi. MWT In = 8.62 ppg, MWT Out = 8.64 ppg, ECD =
9.80 ppg. WHP = 21 psi, WOB = 2.0k Drilling build at 13,056'. In Rate = 2.7 bpm, Out Rate = 2.68 bpm. Circ Pressure = 2600 psi, IAP = 2 psi, OAP = 0 psi. MWT In =
8.61 ppg, MWT Out = 8.69 ppg, ECD = 9.79 ppg. WHP = 29 psi, WOB = 2.3k Drilling build at 13,207'. In Rate = 2.7 bpm, Out Rate = 2.65 bpm. Circ Pressure = 2725
psi, IAP = 3 psi, OAP = 0 psi. MWT In = 8.64 ppg, MWT Out = 8.72 ppg, ECD = 9.76 ppg. WHP = 29 psi, WOB = 4.65k. Build Landed at 13,300', allow pills to come out
then dynamic flow check well to POOH. Good dynamic flow check, POOH to window. Above the window, open the EDC and POOH at max rate chasing pills. Jet
whipstock tray. At surface, 10 min flow check is good. L/D BHA #5 build. Bit 1-1 in perfect shape, will re-run. M/U BHA #6 lateral RIH BHA #6 lateral drilling BHA. Tie-in
depth from 12770' correct -61'. Close EDC. Pass window 25 ft/min, 30L 0 pump nothing seen. Tag and drill from 13299'. 2.88 / 2.85 bpm In / Out 2800 psi Circ. 8.68 /
8.72 ppg. Initial ROP 50 - 60 ft/hr with 2k DWOB. 13370' 10 bbls lo / hi vis sweeps At 13428' lose returns. Pick up to window and organize fluid support and trucking for
drilling with no returns. Rig up hole fill line on rig floor. Pull through window 0.5 bpm, 30L nothing seen. Open EDC pump 1 bpm CT use hole fill line across top.
50-029-22690-60-00API #:
Well Name:
Field:
County/State:
PBE P1-23L1
Prudhoe Bay East
Hilcorp Energy Company Composite Report
, Alaska
8/20/2022Spud Date:
Milling window at 12962.0'
8/22/2022 Circulating above the window waiting on fluid support for DuoVis Light drilling mud. 2nd vac truck of 4 on location, RIH to continue drilling Back on bottom at 13433'. In
Rate = 2.71 bpm, Out Rate = 0.0 bpm. Circ Pressure = 2246 psi, IAP = 0 psi, OAP = 0 psi. MWT In = 8.64 ppg, MWT Out = 8.67 ppg, ECD = 9.23 ppg. WHP = 0 psi
wide open choke, WOB = 2.0k. Loss rate = 2.70 bpm or 162 bph. Hole fill on across to the top to keep the well full. Out rate is slowly increasing, PU past fault to 12400' to
make sure we are not packing off with cuttings. Clean pass through fault with no change in out rate. Shut off hole fill across the top verify to return rate. Out rate at 1.24
bpm. Drilling at 13610'. In Rate = 2.68 bpm, Out Rate = 1.33 bpm. Circ Pressure = 2246 psi, IAP = 0 psi, OAP = 0 psi. MWT In = 8.46 ppg, MWT Out = 8.67 ppg, ECD =
9.23 ppg. WHP = 0 psi wide open choke, WOB = 2.0k. ROP = 50-135 fph, Loss rate = 84 bpm or 162 bph. Drilled 450' to 13750', wiper trip to window. Above the
window open EDC and pump the Low & High vis pills out at the WS then chase up into the TT. Rate In = 4.5 bpm, Rate Out = 2.7 bpm, ECD = 9.35 ppg. No increase in
cuttings from pills just steady cuttings coming across the shaker, circ until clean Returns have cleaned up, close EDC, tie into RA. Correct depth -5 and RIH to continue
drilling. Back on bottom drilling at 13750'. In Rate = 2.68 bpm, Out Rate = 1.64 bpm. Circ Pressure = 2171psi, IAP = 1 psi, OAP = 0 psi. MWT In = 8.43 ppg, MWT Out =
8.44 ppg, ECD = 9.00 ppg. WHP = 0 psi wide open choke, WOB = 2.0k. ROP = 54 fph, Loss rate = 1.05 bpm or 63 bph. Drill at 13800' up wt is 75k. 2.67 / 1.67 bpm In /
Out. 8.43 / 8.48 ppg window ECD 9.03 ppg. ROP 20 - 50 ft/hr with 2-3k DWOB. 13855' pickup 79k 100' wiper is clean. 13885' 10 bbls lo / hi vis 150' wiper at 13900'
clean pass up and down. Drill from 13900'. 2.72 / 1.60 bpm In / Out. 8.43 / 8.48 ppg window ECD 9.10 ppg. ROP 100 ft/hr with 1-2k DWOB. 100' pickup at 13950' 74k
clean. Drill to 14050'. 14050' pull 150' wiper 79k clean up and down. Drill from 14050'. 2.68 / 1.70 bpm In / Out. 8.42 / 8.49 ppg window ECD 9.08 ppg. ROP 60 ft/hr with
1-2k DWOB. 14095' pickup is 72k clean. 14180' 5 bbls lo / hi vis sweeps. Drill to 14200'. Wiper trip from 14200' up wt 76k. ~3k drag around 13700' otherwise clean. Jog
below window then pull through 30L, 0.5 bpm nothing seen. Jog above window and open EDC jet whipstock tray. 4.45 / 2.76 bpm pump 10 bbls lo / hi vis sweeps around
Jet 7" casing 20 ft/min 4.45 / 2.9 bpm. Pump sweeps to surface. Correct -3'.
8/23/2022 Back on bottom at 14,200'. In Rate = 2.70 bpm, Out Rate = 1.66 bpm. Circ Pressure = 2252psi, IAP = 2 psi, OAP = 0 psi. MWT In = 8.45 ppg, MWT Out = 8.45 ppg, ECD
= 9.07 ppg. WHP = 0 psi wide open choke, WOB = 2.0k. Loss rate = 1.00 bpm or 60 bph. Increase LSRV from 20-25k up to 35k Drilling lateral at 14300'. Struggling to
keep WOB and losses are increasing from 60 bph to ~85 bph. Mix and pump 100 bbl pill with 2% Lube776 to see if it helps with weight transfer. Better WT with pill as it
was coming up the backside then back to having WT issues again. Bring system up to 2%. Drilling lateral at 14,445'. In Rate = 2.70 bpm, Out Rate = 1.67 bpm. Circ
Pressure = 2433 psi, IAP = 2 psi, OAP = 0 psi. MWT In = 8.45 ppg, MWT Out = 8.45 ppg, ECD = 9.3 ppg. WHP = 0 psi wide open choke, WOB = 0.5 - 2.5k. Loss rate =
1.00 bpm or 60 bph. Drilling lateral at 14,535'. In Rate = 2.70 bpm, Out Rate = 1.69 bpm. Circ Pressure = 2503 psi, IAP = 0 psi, OAP = 0 psi. MWT In = 8.42 ppg, MWT
Out = 8.52 ppg, ECD = 9.32 ppg. WHP = 0 psi wide open choke, WOB = 0.5 - 1.5k. Loss rate = 1.00 bpm or 60 bph Still stacking WT and struggling to keep WOB,
pump out low and high vis pills then dynamic flow check well and POOH to cleanup the 4-1/2 tubing and PU an Agitator. Good dynamic flow check, POOH. Jog below
window and pull through 30L, 0.5 bpm nothing seen. Jog above window and open EDC 4.5 / 2.9 bpm Jet whipstock tray, clean 7" 15 ft/min 2x. Pump 10 bbls lo / hi vis
sweeps. POOH 40 ft/min 4.5 bpm to clean 4-1/2" steady amount of cuttings. Tag stripper, 10 min flow check is good. L/D BHA #6 Lateral drilling bit is 1-1 balled up will re-
run. Function test BOPs. M/U BHI Strider to UQC, RIH to 200' test and record parameters. POOH L/D Strider. M/U NOV Terrapulse tool to UQC, RIH 200' test and record
parameters. POOH L/D Terrapulse. M/U BHA #7 Lateral drilling BHA w/ Strider. RIH BHA #7.
8/24/2022 Log tie in, correct depth -18', initial formation tie ins are are all over the place, RIH and log the RA to verify correction. On depth, continue RIH Tag bottom at 14575'. PU
WT = 65k, RIH WT = 25k. In Rate = 2.80 bpm, Out Rate = 1.80 bpm. Circ Pressure = 2898 psi, IAP = 0 psi, OAP = 0 psi. MWT In = 8.34 ppg, MWT Out = 8.43 ppg,
ECD = 9.42 ppg. WHP = 46 psi wide open choke, WOB = 1.0 - 2.0k. Loss rate = 1.00 bpm or 60 bph. Drilling at 14735'. In Rate = 2.74 bpm, Out Rate = 1.74 bpm. Circ
Pressure = 2953 psi, IAP = 0 psi, OAP = 0 psi. MWT In = 8.31 ppg, MWT Out = 8.46 ppg, ECD = 9.44 ppg. WHP = 29 psi wide open choke, WOB = 1.0 - 2.0k. Loss rate
= 1.00 bpm or 60 bph 14757' started losing WOB, PU and we are differentially stuck, pulled 93k 3x with no WOB change, hold 93k and pulled free. Perform 300' wiper.
Back on bottom drilled about 5' to 14762' drilled off and got diff stuck again, pull 3x at 90k, shut down pump allow out rate to stop and pulled free. PUH 300'. RIH drilled 8'
to 14770 PU while drilling off and pulled 91k. Order out a full PowerPro mud system to replace the DuoVis mud. Continue drilling with frequent PU's when WOB drills off.
Drilling at 14855'. In Rate = 2.75 bpm, Out Rate = 1.79 bpm. Circ Pressure = 2874 psi, IAP = 0 psi, OAP = 0 psi. MWT In = 8.38 ppg, MWT Out = 8.49 ppg, ECD = 9.46
ppg. WHP = 29 psi wide open choke, WOB = 1.0 - 2.0k. Loss rate = 1.00 bpm or 57 bph Drilling at 14888'. In Rate = 2.77 bpm, Out Rate = 1.83 bpm. Circ Pressure =
2822 psi, IAP = 0 psi, OAP = 0 psi. MWT In = 8.39 ppg, MWT Out = 8.49 ppg, ECD = 9.44 ppg. WHP = 17 psi wide open choke, WOB = 1.0 - 2.0k. Loss rate = 0.90
bpm or 54 bph. Drilling at 15020'. In Rate = 2.75 bpm, Out Rate = 1.87 bpm. Circ Pressure = 2852 psi, IAP = 0 psi, OAP = 0 psi. MWT In = 8.43 ppg, MWT Out = 8.49
ppg, ECD = 9.40 ppg. WHP = 14 psi wide open choke, WOB = 1.0 - 2.0k. Loss rate = 0.93 bpm or 56 bph Wiper trip from 15,100'. Lay in new PowerPro system. In Rate
= 2.85 bpm, Out Rate = 1.59 bpm. Circ Pressure = 2829 psi, IAP = 0 psi, OAP = 0 psi. MWT In = 8.42 ppg, MWT Out = 8.54 ppg, ECD = 9.67 ppg. WHP = 4 psi wide
open choke, WOB = 1.0 - 2.0k. Loss rate = 0.93 bpm or 56 bph Jog below window. Pull through pumping min rate. Open EDC and jet whipstock tray at max rate. Log tie
in from 12,735' Correct -7'. Drilling at 15,104'. In Rate = 2.76 bpm, Out Rate = 1.77 bpm. Circ Pressure = 2861 psi, IAP = 0 psi, OAP = 0 psi. MWT In = 8.46 ppg, MWT
Out = 8.49 ppg, ECD = 9.50 ppg. WHP = 7 psi wide open choke, WOB = 1.0 - 2.3k. Loss rate = 1.0 bpm or 60 bph. Drill from 15,104' to 15,125' and wipe bha length. PU
95k and coil is differentially stuck. Pump Lo/Hi vis sweep and continue to work coil. Pull 96k and shut down pump. Unable to move coil. RU LVT to spot pill. Pump 10 bbl
HiVis, 25 bbls LVT, 10 bbls LoVis pill. Pump 10 bbls of LVT out bit. Relax coil. Pump another 5 bbls out let soak for a few minutes at 93k. Work coil to 100k with no
movement. Pump 1 bbl out let soak then work pipe to 100k. Pump 1 bbl out and allow to soak while crews change out.
8/25/2022 Continue stuck pipe operations, pumped 17 bbls of 25 bbls and pulled 90k+ 15x. Just pumped 1 bbl out and allowing it to soak intension while crews change out. Pump 6
bbls out to cover almost all the OH. Work pipe to 100k 5x to 100k with no movement. Slack off to neutral weight and relax pipe. While slacking off to neutral weight the
bolts that hold the injector frame to the cart sheared off on 1 corner. Stop to replace bolts Bolts replaced and checked the other 3 brackets. PU, pulled to 95k and pulled
free. Circ the rest of the LVT out of the coil and chase up to the window, tie in while circulating LVT to surface. Above the window open EDC and POOH pumping at max
rate to clean up the tubing. Online at 4.5 bpm in and 2.78 out, WHP = 188 psi, WHP is a lot higher than it should be shut down pumps and blow down return line. Online
at 4.5 bpm in and 3.32 bpm out WHP = 52 psi, POOH cleaning up 7" and 4-1/2" tubing Tag up, reset depth, check new bolts on cart and RIH. Log tie in from 12,690' @ 5
ft/min. Correct -48.5'. Confirm on depth with log of whipstock RA tag. RIH to confirm TD and lay in liner running pill. Tag and confirm TD @ 15,120' Repeat at same
depth. Pump 53 bbls of liner running pill with 1.5 ppb Alpine Drilling Beads and appears beads packed off BHA. Pressure up coil/BHA to 6700 psi and no fluid movement.
Attempt one more time and bleed coil off. POOH keeping hole full down backside. In Rate = 1.55 bpm, Out Rate = 1.61 bpm across the top. MW In = 8.45 ppg, MW Out =
8.49 ppg. Open EDC and pump through. In Rate = 1.97, Out Rate = 1.20. OOH - PJSM. Flow check well and confirm no flow. Inspect last 25' of coil. L/D BHA #7 - Bit
graded 1-1. Found motor difficult to turn. M/U Strider and confirm packed off. M/U and RIH with BHA #8. In Rate = .94 bpm, Out Rate = 1.16 bpm. In MM = 8.48 ppg, Out
MM = 8.51. IA = 0 psi, OA = 0 psi.
8/26/2022 Continue RIH at 12500' with drilling BHA. Log tie in, correct depth -69', RIH and confirm with WS RA. We are on depth, drift to TD at min rate. Tag at 15120', PU and
retag to confirm, good tag. Dynamic Flow check well, good no flow, online pumping liner pill with beads down the coil. POOH laying in pill. Liner pill laid in, open EDC, log
RA, correct depth -11.5'. POOH at max rate painting EOP flags. TD Flag Yellow - EOP = 12500', Bit Depth = 12566.64'. Window Flag White - EOP = 10350', Bit Depth =
10416.64' OOH flow check well, good no flow, remove injector and LD the LRT's A large piece of formed rubber was found under the hood of the possum belly that looks
like the inside of a 2” HP Hose on the return side. Flush surface lines with freshwater to remove and inspect all 2" hoses on the return side. Crew found the hose that
connects in the PUTZ for the line to the shaker. Swap out hose then fluid pack to PT the surface lines RU power tongs and handling equipment and prep to run liner. MU
2 7/8" 6.5# L-80 STL slotted liner with solid bullnose. Fill hole every 10 jts. MU BOT deployment sleeve. MU remaining BHI upper BHA RIH with BHA #9 - 2 7/8" 6.5#,
STL slotted liner. Replace leaking pack offs and energizer Correct depth at window flag to 12,834'. Continue RIH @ 50 fpm and 28k coil weight.
8/27/2022 Continue RIH with liner at 14900'. Tag at 15109', PU WT 72.5k retag at same depth, hard bottom. On line with pump to release from liner, PU WT = 58k. PUH and Log
CCL to confirm TOL and lost COMMS to the tool. Check all surface lines and they are good Discuss with OE and we are good to swap well to 1% SLK KCl w/SafeLube.
15086.19' (NAD EOP 12596.06) remove liner BHA and correct to 12645.18' Well swapped to KCl In Rate = 2.53 bpm, Out Rate = 2.39 bpm. Reduce rate to 1.0 bpm, out
rate is slowly dropping off might be a little charged up, monitor returns. Out rate is slow to drop off and WHP higher than normal at 1.0 bpm, shut down pump close drilling
choke and blow down the return line Got a 2' long piece of rubber from the hose we replaced. Open back up to the well, WHP is slowly bled off to 0 psi. Flow check well,
getting a good stream of KCl at the rig floor whitey valve. Close in WV and monitor, WHP is 0 psi. Open MPD line to the well, WHP is 23 psi and slowly dropping off Verify
if well is Breathing, WHP at 12psi. Start step down bleed off procedure bleeding off in 0.5 bbls increments. Crack open choke and WHP dropped to 0psi and got 0.16 bbls
back then flow stopped, well was just charged up/breathing. Flow check well Good no flow, online with pumps, well took 1.1 bbls to fill. In and out rates stable at - 1.0 bpm
in and 0.83 bpm out. POOH 1.0 bpm in and 0.35 bpm out OOH, flow check well, good no flow. Remove injector and LD the BHA. Lost COMMS to the tool issue - Eline
pulled out of weak point. Looking down the stack to fill the hole there is a large chunk of packoff down by the swab valve, RU Vac line to fish it out. Packoff chunk retrieved,
inspect packoff Cut eline, meg and continuity test is good, boot and anchor in weak point. Install BHI Floats, MU nozzle BHA, stab on well and PT packoffs & floats Good
PT, open up to the well and RIH to 2500' TVD. Thunderbird pump unit online loading 45 bbls of diesel into the coil. 45 bbls pumped, shut down Thunderbird pump and
displace with rig pumps. Diesel at the nozzle start increasing WHP to maintain 1:1 returns. OOH service tree valves, PT Valves. Displace coil to fresh water. Jet stack and
surface lines. Pump slack forward. Re-head BHI UQC without floats. Test continuity - good 58 ohms. Mega ohms over 2000 Blow down BOP stack and surface lines. N/D
BOPE stack. RD steam lines and cellar.
8/28/2022 RD PUTZ. Continue working on RDMO checklist. Pressure test tree cap and flange with MeOH - Pass. Release rig at 1:30
to release from linerContinue RIH with liner at 14900'. Tag at 15109'
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 North Slope, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Re: Prudhoe Bay Field, Pt. McIntyre Oil Pool, PBU P1-23L1
Hilcorp North Slope, LLC
Permit to Drill Number: 221-096
Surface Location: 1370' FSL, 951' FEL, Sec. 16, T12N, R14E, UM, AK
Bottomhole Location: 2291' FNL, 1129' FEL, Sec. 09, T12N, R14E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced well.
The permit is for a new wellbore segment of existing well Permit 196-124, API 50-029-22690-00-
00. Production should continue to be reported as a function of the original API number stated
above.
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,
Jessie L. Chmielowski
Commissioner
DATED this ___ day of November, 2021. 23
Jessie L.
Chmielowski
Digitally signed by Jessie
L. Chmielowski
Date: 2021.11.23
14:15:56 -09'00'
1a.
Contact Name:Trevor Hyatt
Contact Email:trevor.hyatt@hilcorp.comAuthorized Name: Monty Myers
Authorized Title:Drilling Manager
Authorized Signature:
Contact Phone:
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
Lateral 5
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 P1-23L1
TVD:15369'8964'
12. Field/Pool(s):
Prudhoe Bay Field /
Pt. McIntyre Oil Pool
MD:
ADL 028297 & 034622
90-024 April 1, 2022
4a.
Surface:
Top of Productive Horizon:
Total Depth:
1370' FSL, 951' FEL, Sec. 16, T12N,R14E, UM, AK
1012' FNL, 478' FWL, Sec. 10, T12N, R14E, UM, AK
2291' FNL, 1129' FEL, Sec. 09, T12N, R14E, UM, AK
Kickoff Depth:12950 feet
Maximum Hole Angle: 96 degrees
Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Downhole:Surface:3750 2870
17.Deviated wells:16.
Surface: x-y- Zone -674107 5994495 4
10. KB Elevation above MSL:
GL Elevation above MSL:
feet
feet
43.1'
9.3'
15.Distance to Nearest Well Open
to Same Pool:
Cement Quantity, c.f. or sacks
MD
Casing Program:
12693'8743'
19.PRESENT WELL CONDITION SUMMARY
Production
80 260 sx Arctic Set (Approx.)
13432 9204 None 12978 8922 13041
34 - 114
Surface 1310 sx CS III, 404 sx Class 'G'
8895 - 9086
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):
6.5#L-80
4008
2-7/8"2676
12935 - 13240
50-029-22690-60-00
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
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
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.
4150
Distance to Nearest Property:
Location of Well (Governmental Section):
4b.
5120
289
18. Specifications Top - Setting Depth - Bottom
Hole Casing Weight Grade
Coupling Length TVD TVD (including stage data)
4-1/4" 15369' 8964'Uncemented Slotted Liner
(To be completed for Redrill and Re-Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft):
Plugs (measured):Effect. Depth MD (ft): Effect. Depth TVD (ft):Junk (measured):
Casing Length Size MD
20"34 - 114
9-5/8"34 - 4043 34 - 3660
13392 7"270 sx Class 'G'31 - 13423 31 - 9198
Liner
Perforation Depth MD (ft):Perforation Depth TVD (ft):
20. Attachments Property Plat BOP Sketch 55 Drilling Program 55 Time v. Depth Plot
Permit to Drill
Number:
Permit Approval
Date:
Reentry
Hydraulic Fracture planned?
Sr Pet Eng Sr Res Eng
Cement Volume
Comm.
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g))
STL
777-8396
11.15.2021
By Samantha Carlisle at 12:45 pm, Nov 15, 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: 2021.11.15 11:36:56 -09'00'
Monty M
Myers
BOPE test to 3500 psi.
MGR21NOV21
221-096
DSR-11/15/21
2870
SFD 11/17/2021dts 11/23/2021
11/23/21
11/23/21Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski
Date: 2021.11.23 14:16:27 -09'00'
To: Alaska Oil & Gas Conservation Commission
From: Trevor Hyatt
Drilling Engineer
Date: November 15, 2021
Re: PBU P1-23L1 Permit to Drill
Approval is requested for drilling a CTD sidetrack lateral from well PBU P1-23 with the
Nabors CDR2 Coiled Tubing Drilling.
Proposed plan for P1-23L1 Producer:
See P1-23 Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to
drift for whipstock, MIT, and caliper log. E-line will then set a 4-1/2"x7" flow through whipstock and mill XN nipple.
Service Coil will mill the XN-nipple (if not done with E-line) and mill a single string window in the 7” casing (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. If scheduling needs arise, the rig will mill a single string 3.80" window + 10' of formation. The well will kick off
drilling and land in the Kuparuk sands. The lateral will continue in the Kuparuk to TD. The proposed sidetrack will
be completed with a 2-7/8” L-80 slotted liner. This completion will NOT abandon the parent Kuparuk perfs.
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 P1-23 Sundry submitted in concert with this request for full details.
x General work scope of Pre-Rig work:
1. Slickline: Dummy WS drift and Caliper log
2. Fullbore: CMIT-TxIA and MIT-T
3. E-line: Set Whipstock and Mill XN Nipple
4. Service Coil: Mill 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 2,870 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 7”) plus 10’ of rathole.
a. Top of window (whipstock pinch point) at 12,950’ 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. 30° DLS build section – 298’ MD / Planned TD 13,248’ MD
c. 12° DLS lateral section – 2,121’ MD / Planned TD 15,369’ 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.
4. Run Slotted Liner
a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner
b. Run 2-7/8” L-80 slotted liner to TD
c. Swap well over to KCl
d. Freeze protect well from ~2200’ MD (min)
e. RDMO
Sundry 321-586
PTD 221-096
ppp
This completion will NOT abandon the parent Kuparuk perfs.
Post Rig:
1. V: Valve & tree work
2. S: Set live GLVs (if needed)
3. T: Portable test separator flowback
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 (12,950’ MD - 8,905’ TVD)
Pumps
On Pumps Off
A Target BHP at Window (ppg)4,538 psi 4,538 psi
9.8
B Annular friction - ECD (psi/ft)647 psi 0 psi
0.05
C Mud Hydrostatic (ppg)3,890 psi 3,890 psi
8.4
B+C Mud + ECD Combined 4,537 psi 3,890 psi
(no choke pressure)
A-(B+C)Choke Pressure Required to Maintain 1 psi 648 psi
Target BHP at window and deeper
Operation Details:
Reservoir Pressure:
x The maximum reservoir pressure is expected to be 3,750 psi at 8,800’ TVD (8.2 ppg equivalent).
x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,870 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:
x 2-7/8”, 6.5#, L-80 Slotted Liner: 12,693’ MD – 15,369’ MD (2,676’ 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 96°. Inclination at kick off point is 50°.
x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
x Distance to nearest property line – 4,150’
x Distance to nearest well within pool – 289’
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 No perforating, slotted liner.
Anti-Collision Failures:
x P1-24, P1-24L1, P1-24L1-01 fail Anticollision for P1-23L1 WP04.
o Well will remain online while drilling, risk is financial (bit trip and sidetrack). No HSE risk.
o Close approach is in the same reservoir and below production packer.
o No significant pressure change from offset producing zones.
o Pad operator will be on standby to shut well in, if needed.
o Sufficient fluid will be on location to handle expected losses (tubing volume of offset wellbore).
Hazards:
x PBU P1-pad is an H2S pad.
o The highest recorded H2S well on the pad was from P1-20 (850 ppm) in 2011.
o Last recorded H2S on P1-23 was 80 ppm in 2021
x Two fault crossings expected.
x Medium lost circulation risk.
Trevor Hyatt CC: Well File
Drilling Engineer Joseph Lastufka
907-223-3087
H2S pad.
P1-24, P1-24L1, P1-24L1-01 fail Anticollision
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7000
7250
7500
7750
8000
8250
8500
8750
9000
9250
9500
9750
10000True Vertical Depth (500 usft/in)-500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000
Vertical Section at 234.56° (500 usft/in)
P1-23 wp01 Possible Flt P1-23 wp01 Target TD
P1-23 wp01 Target 1
9
5
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100001
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13000
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P1-23
7" TOW
2 7/8" x 4 1/4"13000
1350014000145001500015369P1-23L1 wp04
KOP : Start Dir 9º/100' : 12950' MD, 8904.64'TVD : 170° LT TF
Start Dir 30º/100' : 12970' MD, 8917.57'TVD
Start Dir 12º/100' : 13247.36' MD, 9024.78'TVD
Total Depth : 15369' MD, 8964.1' TVD
Hilcorp North Slope, LLC
Calculation Method:Minimum Curvature
Error System:ISCWSA
Scan Method: Closest Approach 3D
Error Surface: Ellipsoid Separation
Warning Method: Error Ratio
WELL DETAILS: Plan: P1-23
Ground Level: 9.30
+N/-S +E/-W
Northing Easting Latitude Longitude
0.00 0.00 5994495.12 674106.94 70° 23' 26.3573 N 148° 35' 0.8324 W
SURVEY PROGRAM
Date: 2020-10-22T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
182.89 12950.00 1 : MWD - Standard (P1-23) 3_MWD
12950.00 15369.00 P1-23L1 wp04 (Plan: P1-23L1) 3_MWD
FORMATION TOP DETAILS
No formation data is available
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: P1-23, True North
Vertical (TVD) Reference:KB @ 43.10usft (ORIG KELLY BUSHING)
Measured Depth Reference:KB @ 43.10usft (ORIG KELLY BUSHING)
Calculation Method:Minimum Curvature Project:GPMA
Site:P1
Well:Plan: P1-23
Wellbore:Plan: P1-23L1
Design:P1-23L1 wp04
CASING DETAILS
TVD TVDSS MD Size
Name
8904.64 8861.54 12950.00 7 7" TOW
8964.10 8921.00 15369.00 2-7/8 2 7/8" x 4 1/4"
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 12950.00 50.60 351.22 8904.64 8232.66 1401.32 0.00 0.00 8.66 KOP : Start Dir 9º/100' : 12950' MD, 8904.64'TVD : 170° LT TF
2 12970.00 48.83 350.80 8917.57 8247.73 1398.93 9.00 -170.00 1.86 Start Dir 30º/100' : 12970' MD, 8917.57'TVD
3 13247.36 91.50 271.18 9024.78 8377.22 1209.04 30.00 -82.00 81.47 Start Dir 12º/100' : 13247.36' MD, 9024.78'TVD
4 13697.36 95.73 217.21 8994.11 8189.45 819.49 12.00 -84.00 507.72
5 13897.36 89.23 194.08 8985.33 8010.60 733.73 12.00 -105.00 681.30
6 14187.36 89.37 228.88 8989.00 7767.09 584.62 12.00 90.00 944.00
7 14397.36 90.28 203.70 8989.66 7599.18 461.33 12.00 -88.00 1141.81
8 14672.36 91.32 236.68 8985.71 7392.01 286.33 12.00 88.00 1404.51
9 14922.36 91.65 206.68 8979.08 7207.49 122.04 12.00 -89.00 1645.37
10 15197.36 91.92 239.69 8970.27 7009.83 -63.46 12.00 89.00 1911.12
11 15369.00 92.15 219.08 8964.10 6898.78 -192.97 12.00 -89.00 2081.03 Total Depth : 15369' MD, 8964.1' TVD
6600
6750
6900
7050
7200
7350
7500
7650
7800
7950
8100
8250
8400
8550
8700
8850
9000
9150
South(-)/North(+) (300 usft/in)-300 -150 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800
West(-)/East(+) (300 usft/in)
P1-23 wp01 Target 1
P1-23 wp01 Target TD
P1-23 wp01 Possible Flt
P 1 -2 3
7" TOW
2 7/8" x 4 1/4"90008
9
6
4
P
1-23
L
1
w
p04
KOP : Start Dir 9º/100' : 12950' MD, 8904.64'TVD : 170° LT TF
Start Dir 30º/100' : 12970' MD, 8917.57'TVD
Start Dir 12º/100' : 13247.36' MD, 9024.78'TVD
Total Depth : 15369' MD, 8964.1' TVD
CASING DETAILS
TVD TVDSS MD Size Name
8904.64 8861.54 12950.00 7 7" TOW
8964.10 8921.00 15369.00 2-7/8 2 7/8" x 4 1/4"
Project: GPMA
Site: P1
Well: Plan: P1-23
Wellbore: Plan: P1-23L1
Plan: P1-23L1 wp04
WELL DETAILS: Plan: P1-23
Ground Level: 9.30
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00 5994495.12 674106.94 70° 23' 26.3573 N 148° 35' 0.8324 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: P1-23, True North
Vertical (TVD) Reference: KB @ 43.10usft (ORIG KELLY BUSHING)
Measured Depth Reference:KB @ 43.10usft (ORIG KELLY BUSHING)
Calculation Method:Minimum Curvature
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0.001.002.003.004.00Separation Factor13000 13125 13250 13375 13500 13625 13750 13875 14000 14125 14250 14375 14500 14625 14750 14875 15000 15125 15250 15375Measured Depth (250 usft/in)P1-23P1-24L1-01P1-24P1-24L1P1-21No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: P1-23 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 9.30+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005994495.12674106.9470° 23' 26.3573 N148° 35' 0.8324 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: P1-23, True NorthVertical (TVD) Reference:KB @ 43.10usft (ORIG KELLY BUSHING)Measured Depth Reference:KB @ 43.10usft (ORIG KELLY BUSHING)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-10-22T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool182.89 12950.00 1 : MWD - Standard (P1-23) 3_MWD12950.00 15369.00 P1-23L1 wp04 (Plan: P1-23L1) 3_MWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)13000 13125 13250 13375 13500 13625 13750 13875 14000 14125 14250 14375 14500 14625 14750 14875 15000 15125 15250 15375Measured Depth (250 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference12950.00 To 15369.00Project: GPMASite: P1Well: Plan: P1-23Wellbore: Plan: P1-23L1Plan: P1-23L1 wp04Ladder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name8904.64 8861.54 12950.00 7 7" TOW8964.10 8921.00 15369.00 2-7/8 2 7/8" x 4 1/4"
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
2-3/8" Pipe/Slips
2 3/8" Pipe/Slips
2 3/8" Pipe/Slips
7-1/16"
5k Mud
Cross
2-3/8" Pipe/Slips
3.0" Pipe / Slip
HF
nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee
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.
196-124
221-096
Prudhoe Bay Prudhoe Bay, Pt. McIntyre Oil
PBU P1-23L1
029-22690-00-00
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