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Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 12/06/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20231206
Well API #PTD #Log Date Log
Company Log Type AOGCC Eset#
KBU 13-8 50133203040000 177029 11/15/2023 HALLIBURTON EPX
NCIU A-17 50883201880000 223031 11/28/2023 HALLIBURTON RBT
PBU 04-46A 50029224340100 223082 11/1/2023 HALLIBURTON RBT
PBU 05-26A 50029219840100 201221 11/24/2023 HALLIBURTON PPROF
PBU 06-20B 50029207990200 223075 10/18/2023 BAKER MRPM
PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT
PBU N-07A 50029201370100 204105 10/7/2023 BAKER SPN
PBU P1-08A 50029223840100 202199 9/22/2023 BAKER SPN
PBU P2-56 50029226100000 195162 11/14/2023 BAKER SPN
PBU P2-57A 50029221830100 202214 11/1/2023 BAKER SPN
Please include current contact information if different from above.
T38205
T38206
T38207
T38208
T38209
T38210
T38211
T38212
T38213
T38214
12/6/2023
PBU 06-20B 50029207990200 223075 10/18/2023 BAKER MRPM
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.12.06
14:25:58 -09'00'
3-1/2"x3-1/4"
x2-7/8"9.2#/6.6#/6.5#
By Grace Christianson at 10:45 am, Nov 03, 2023
Completed
10/19/2023
JSB
RBDMS JSB 111723
GDSR-12/8/23
Drilling Manager
11/02/23
Monty M
Myers
Digitally signed by Bo York
(1248)
DN: cn=Bo York (1248)
Date: 2023.11.03 09:35:05 -
08'00'
Bo York
(1248)
Activity Date Ops Summary
10/5/2023 Complete moving rig over 06-20. Sat down 07:00. Work through rig up checklists. LTT master and swab. Both leaking. Grease crew serviced. LTT passed to
3500#. Wells Support RU tiger tank and pressure tested hardline. NU MPD line. Nipple up BOPE. Clear rig floor. Ream coil. Install coil connector. Test Gas Alarms.
All passed. Pull test 50k, good. M/U BHI upper quick w/ no floats. M/U nozzle get on well. Fill reel MeOH followed by fresh water. Returns at tiger tank pump
remaining MeOH out of CT. Purge CT riser w/ air to TT then returns inside. Push slack forward 3.4 bpm / 4200 psi for 1 reel volume. Skid inj back remove nozzle.
PT inner reel iron and UQC to 6800 psi, good. Inspect packoffs. Flush and fluid pack all surface lines. Test BOPs as per Hilcorp and AOGCC regulations. All tests
250 / 3500 psi. Test witness waived by AOGCC Inspector Kam Stjohn. 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 - F/P on B4. Test 4 - Upper 2-3/8" Pipe / Slip, TIW2, B2, B3 Pass. Test 5 - Lower 2-3/8" Pipe / Slip, C5, C6, C8, TV2 Pass.
Test 6 - Choke A, Choke C Pass.
10/6/2023 Test 7 - C1, C4, TV1 Pass. Test 8 - 3" Pipe / Slip, C2, C3, Pass. Accumulator Draw down. Rig down testing equipment. Install drilling risers and QTS. BHI install
floats. Stab on Injector. Reverse. Test floats and riser to 3500#. Good test. Circulate Freshwater to calibrate micromotions. Load reel with 1% SL KCL. Load MPD
line with methanol spear. 350 psi. Rate in: 3.5 to 4 bpm @ 1700- 1800 psi. Pump 215 bbls. Come offline. Let pressure fall off. Pump across top to tiger tank. Flow
check well. 12 bph loss rate. PJSM. Make up BHA#1 NSAK packer whipstock. Verify ball valves open / EDC open. Make up injector. Test QTS. RIH w/ BHA #1.
Rate: 0.82 bpm in, 1.2 bpm out. Circ pressure: 139 psi. Mud Weight: 8.37 ppg in, 8.36 ppg out. Stop at 6000' MD. Check torque on reel saddle clamps. Gamma ray
not working. Troubleshoot. Log. Scale. PU to 8380' Log tie in. Log GR from 8380' correct -8'. Log CCL from 8700' to 9450' bit depth. Log GR again near set depth
correct -3'. BHI CCL matches program CCL, no correction needed. RIH to bit depth 9374.19' P/U to 41k. Leaves TOWS 9359.96'. Close EDC pressure up setting
tool shears at 2200 psi. Set 5k down hold for 1 min, solid. Whipstock set 0R orientation TOWS 9359.96'. P/U Open EDC. Circ well to mud still on slight losses 2.9 /
2.6 bpm. Good 10 min no-flow on bottom. POOH. At surface, Good 10 min no-flow. L/D BHA #1 - Whipstock setting tools. M/U BHA #2 - Window mill and reamer.
Both 3.81" Go / 3.80" NoGo. RIH BHA #2. Log tie-in from 8550' correct -20'. Close EDC, dry tag whipstock 9360'. P/U 50k go to 2.8 bpm. Mill 3.80" window from
9360.3'. 2.65 / 2.50 bpm In / Out. MW 8.72 / 8.74 ppg, ECD = 9.86 ppg. Pcirc 3400 - 3450 psi.
10/7/2023 Mill 3.80" window from 9360.3' to 9367.3. 2.65 / 2.50 bpm In / Out. MW 8.69 / 8.71 ppg, ECD = 9.90 ppg. Pcirc 3400 - 3450 psi. Appears we exited. Mill additional
foot to get string reamer out. Mill rathole from 9367.3 to 9377'. Perform reaming passes. Dry drift. Clean. P/U open EDC. Good 10 min no-flow. POOH 3.5 bpm /
3400 psi. Good 10 min no-flow at surface. Lift inj inspect CT 40' above CTC - Good. Skid inj back L/D BHA #2 - Window mill. Mill 3.80" Go / 3.79" NoGo. Reamer
3.81" Go / 3.80" NoGo. M/U nozzle jet stack. M/U BHA #3 - Build section. RIH BHA #3. Tie-in from 9290' correct -19'. Close EDC. Pass window no issues. Go to
min rate tag end of rathole 9376'. Get up wt + 2' go to 2.9 bpm. Drill 4.25" build from 9377'. Pcirc 3250 - 3400 psi, Window ECD = 9.90#. MW 8.68 / 8.73 ppg. 2.9 /
2.7 bpm. 9420' 5 bbls lo/hi vis. 100' wiper from 9530' clean up/down 49k / 25k. Drill 4.25" build from 9530'. Pcirc 3180 - 3500 psi, Window ECD = 9.97#. MW 8.67
/ 8.80 ppg. Flow 2.9 / 2.7 bpm.
10/8/2023 Drill 4.25" build from 9600 MD to 9661'. Free spin: 3211 psi, 2.82 bpm. Rate: 2.82 bpm in, 2.70 bpm out. Circ pressure: 3211 to 3346 psi. Mud weight: 8.70 ppg in,
8.77 ppg out, Window ECD: 9.90 ppg. ROP: 25 fph, WOB: 1.9 KLBS. Wiper to window with sweeps. Pull through window without issue. Pooh. Rate: 2.82 bpm in,
2.70 bpm out. Mud weight: 8.71 ppg in, 8.78 ppg out, Window ECD: 9.80 ppg. Tag up. Space out. Pressure un-deploy. Bit 1:1. Pressure deploy BHA#4 w/ 1.1 AKO
and rerun bit. Drill 4.25" lateral. Rate: 0.36 bpm in, 0.93 bpm out. Circ pressure: 1489 psi. Mud weight: 8.74 ppg in, 8.79 ppg out, Window ECD: 9.86 ppg. Log tie
in with -22' correction. Close EDC. Drill 4.25" lateral from 9661'. Free spin: 3186 psi, 2.82 bpm (433 psi diff). Rate: 2.82 bpm in, 2.75 bpm out. Circ pressure: 3186
to 3346 psi. Mud weight: 8.73 ppg in, 8.78 ppg out, Window ECD: 9.96 ppg. ROP: 25 fph, WOB: 1.9 KLBS. 9740' 5 bbls lo/hi vis. BHA wiper from 9742' clean
up/down 52k/24k. Drill 4.25" lateral from 9742'. Free spin: 2940 psi, 2.62 bpm (390 psi diff). Rate: 2.62 bpm in, 2.51 bpm out. Circ pressure: 2940 - 3280 psi. Mud
weight: 8.72 ppg in, 8.79 ppg out, Window ECD: 9.90 ppg. ROP: 20 fph, WOB: 3-4 KLBS. 150' wiper from 9800' clean up/down 50k/25k. Drill 4.25" lateral f/ 9800'.
Free spin: 433 psi diff. 2.85 bpm in, 2.65 bpm out. Circ pressure: 3200 - 3500 psi. Mud weight: 8.73 ppg in, 8.79 ppg out, Window ECD: 9.97 ppg. ROP: 20 - 40
fph, WOB: 2-3 KLBS. 9815', 9910' 5 bbls lo/hi vis. 150' wiper from 9950' clean up/down 51k/25k. Drill 4.25" lateral f/ 9950'. Free spin: 428 psi diff. 2.83 bpm in,
2.64 bpm out. Circ pressure: 3210 - 3430 psi. Mud weight: 8.75 ppg in, 8.82 ppg out, Window ECD: 10.0 ppg. ROP: 20 - 50 fph, WOB: 2-3 KLBS.
10/9/2023 Drill 4.25" lateral f/ 10,010' to 10,100'. Free spin: 3210 psi @ 2.82 bpm (428 psi diff). 2.82 bpm in, 2.64 bpm out. Circ pressure: 3210 to 3535psi. Mud weight: 8.76
ppg in, 8.83 ppg out, Window ECD: 10.03 ppg. ROP: 20 - 50 fph, WOB: 2-3 KLBS. Wiper to window. Log tie in with +4' correction. Pump bottoms up. Shakers
cleaned up. Close EDC. Run back to bottom. Drill 4.25" lateral f/10,100' to 10230' MD. Free spin: 3245 psi @ 2.82 bpm (420 psi diff). 2.82 bpm in, 2.81 bpm out.
Circ pressure: 3245 to 3535 psi. Mud weight: 8.77 ppg in, 8.82 ppg out, Window ECD: 10.07 ppg. ROP: 20 - 50 fph, WOB: 2-3 KLBS. Drill 4.25" lateral f/ 10230'
MD to 10309' MD. Free spin: 3270 psi @ 2.82 bpm (443 psi diff). 2.80 bpm in, 2.81 bpm out. Circ pressure: 3270 to 3509 psi. Mud weight: 8.78 ppg in, 8.86 ppg
out, Window ECD: 10.04 ppg. ROP: 20 - 40 fph, WOB: 2-3 KLBS. Drill 4.25" lateral f/ 10328' MD to 10407'. Free spin: 3270 psi @ 2.82 bpm (443 psi diff). 2.82
bpm in, 2.75 bpm out. Circ pressure: 3270 to 3613 psi. Mud weight: 8.79 ppg in, 8.85 ppg out, Window ECD: 10.05 ppg. ROP: 20 - 30 fph, WOB: 1.5-3 KLBS.
POOH to check bit and motor from 10407' after slow ROP. Pull through window clean, jog and then open EDC. 3.24 bpm in, 2.47 bpm out. Circ pressure: 3226 psi.
Mud weight: 8.80 ppg in, 8.88 ppg out, Window ECD: 10.06 ppg. Flow check well and confirm no flow. LD BHA #4. Bit graded 7-2. MU and RIH with BHA #5. New
motor and new HCC 4.25" bi-center bit. RIH with BHA #5. .6 bpm in, 1.2 bpm out. Circ pressure: 1451 psi. Mud weight: 8.84 ppg in, 8.89 ppg out. Window ECD:
9.84 ppg.
10/7/2023Spud Date:
Well Name:
Field:
County/State:
PBE 06-20B
Prudhoe Bay East
Hilcorp Energy Company Composite Report
, Alaska
50-029-20799-02-00API #:
10/10/2023 RIH with 4.25 drilling BHA #5. Rate: 0.39 bpm in, 0.90 bpm out. Circ pressure: 1479 psi. Mud Weight: 8.83 ppg in, 8.87 ppg out. Window ECD: 9.9 ppg. Log down
for tie-in from 9290' MD (formation) with -23 correction. Close EDC. Run through window without issue. Drill 4.25 lateral from 10407 MD to 10481' MD. Free spin:
3546 psi, 2.82 bpm (564 psi diff). Rate: 2.82 bpm in, 2.80 bpm out. Circ pressure: 3546 to psi. Mud weight: 8.82 ppg in, 8.87 ppg out, Window ECD: 10.2 ppg.
ROP: 18-25 fph, WOB: 2-3KLBS. ROP dropped off drastically. Pooh for bit / agitator. Rate: 0.39 bpm in, 0.90 bpm out. Circ pressure: 1479 psi. Mud Weight: 8.83
ppg in, 8.87 ppg out. Window ECD: 10.09 ppg. Pump 10 bbls Lo Vis / 10 bbls HiVis. Perform flow check. 3bph loss rate. Pull BHA#5. Install agitator. Bit graded: 8-
5. Make up 4.25" Hycalog bicenter bit. Shallow test agitator. Good test. Leave EDC closed. Rih w/ BHA#6. Rate: 0.91 bpm in, 1.47 bpm out. Circ pressure: 1917
psi. Mud Weight: 8.83 ppg in, 8.88 ppg out. Window ECD: 9.76 ppg. Log down for tie-in from 9290' MD (formation) with -25' correction. Close EDC and RIH
through window clean. Tag at 9394'. Pick and RIH past. Drill 4.25 lateral from 10481' MD to 10643' MD. Free spin: 3546 psi, 2.82 bpm (564 psi diff). Rate: 2.81
bpm in, 2.72 bpm out. Circ pressure: 4424 psi. Mud weight: 8.82 ppg in, 8.88 ppg out, Window ECD: 10.27 ppg. ROP: 18-25 fph, WOB: 2-3KLBS. Drill 4.25 lateral
from 10643' MD to 10930' MD. Free spin: 3546 psi, 2.82 bpm (564 psi diff). Rate: 2.71 bpm in, 2.61 bpm out. Circ pressure: 4414 psi. Mud weight: 8.83 ppg in,
8.95 ppg out, Window ECD: 10.18 ppg. ROP: 100 - 150 fph, WOB: 2-3.4 KLBS. Wiper trip to window from 10930'. Rate: 2.83 bpm in, 2.56 bpm out. Circ pressure:
4333 psi. Mud weight: 8.87 ppg in, 8.99 ppg out. Window ECD: 10.18 ppg. Jog and pull through window clean. Open EDC and pump max rate. Tie in and correct
+1'. Drill 4.25 lateral from 10930' MD to 11084' MD. Free spin: 3546 psi, 2.82 bpm (564 psi diff). Rate: 2.76 bpm in, 2.78 bpm out. Circ pressure: 4756 psi. Mud
weight: 8.88 ppg in, 8.92 ppg out, Window ECD: 10.31 ppg. ROP: 100 - 150 fph, WOB: 2-3.4.2 KLBS.
10/11/2023 Drill 4.25 lateral from 11084' MD. Free spin: 3546 psi, 2.82 bpm (564 psi diff). Rate: 2.88 bpm in, 2.75 bpm out. Circ pressure: 4770 psi. Mud weight: 8.89 ppg in,
8.97 ppg out, Window ECD: 10.30 ppg. ROP: 70 - 100 fph, WOB: 2.3 -.4 KLBS. Drilled to 11,190' ROP <5 fph, POOH for bit. Jog below the window then pulled
through window clean. Open EDC and POOH chasing pills to surface. Test Agitator at 450', good test. Bleed off WHP. Flow check well, good No Flow, well taking
~3.5 bph. PU injector, pull the BHA and change bits, bit grade = 7-5-RO. Inspect Coil and found a flat spot on pipe at 16% wall loss, cut 17' of pipe and rehead. Pull
test CTC to 50k, good test. Pressure test to 3500 psi. MU injector to well and RIH with BHA #7. Rate: 1.05 bpm in, 1.53 bpm out. Circ pressure: 1685 psi. Mud
weight: 8.90 ppg in, 8.99 ppg out, Window ECD: 9.78 ppg. Tie in and correct -27'. Close EDC and RIH past window clean. Drill 4.25 lateral from 11190' MD to
11,320' MD. Free spin: 3546 psi, 2.82 bpm (564 psi diff). Rate: 2.86 bpm in, 2.73 bpm out. Circ pressure: 4770 psi. Mud weight: 8.90 ppg in, 9.03 ppg out, Window
ECD: 10.54 ppg. ROP: 70 - 100 fph, WOB: 2.3 -.4 KLBS. Drill 4.25 lateral from 11,320' MD to 11327' MD. Free spin: 3546 psi, 2.82 bpm (564 psi diff). Rate: 2.81
bpm in, 2.73 bpm out. Circ pressure: 4808 psi. Mud weight: 8.75 ppg in, 8.97 ppg out, Window ECD: 10.45 ppg. ROP: 5-15 fph, WOB: 2 -.4 KLBS.
10/12/2023 Drilled to 11330' <5 fph, POOH for new bit. Over pull at 11,010', RIH clean, PU and pulled 25k over at 11,000' with no WOB change, might be shale above at
10930'. See a little negative WOB pulling through at 10,890'. Jog below window, pull through window, open EDC and POOH. OOH, space out to pressure undeploy
the BHA. BHA pulled, bit grade = 7-7-RO-BT. RIH with BHA #8. Log tie in, correct depth -27' and RIH. Tag at 10923' 3.8k WOB, tag at 10930', PU pass through 1k
WOB. Stop at 10940' PU to 10915' clean, RIH set down WT at 10923' but passed through, RIH to bottom. Drill 4.25 lateral from 11330'. Free spin: 4786 psi, 2.82
bpm (1054 psi diff). Rate: 2.80 bpm in, 2.57 bpm out. Circ pressure: 4770 psi. Mud weight: 8.90 ppg in, 8.98 ppg out, Window ECD: 10.84 ppg. ROP: 20 - 45 fph,
WOB: 1.3 - 1.8 K. Drilled to 11420' Geo's called TD. Pull wiper trip to the window. Pulled 15k over at 10931', RIH then PU again, a little ratty pulling through. 10900'
RIH at min rate then pull back through at full rate. Pulled through clean. Open EDC and POOH pumping max rate. Tag surface and correct depth. RIH to confirm
TD. Rate: 1.75 bpm in, 2.18 bpm out. Circ pressure: 2382 psi. Mud weight: 8.90 ppg in, 8.96 ppg out, Window ECD: 9.81 ppg. Log tie in. Correct -29'. Close EDC
and RIH through window clean. RIH pumping min rate. Weight bobbles at 10,890', 10,929', 11,025'. Tag and confirm TD at 11,421'. Lay in liner running pill with 1.5
ppb Alpine drilling beads from 11,421' to 10,100. Lay in 9.9 ppg KWF from 10,100'. Pull through window and open EDC. Circulate 9.9 ppg KWF to surface. Flow
check well and confirm no flow. POOH from 9300'. Rate: 2.1 bpm in, 1.46 bpm out. Circ pressure: 1733 psi. Mud weight: 9.92 ppg in, 9.95 ppg out, Window ECD:
10.03 ppg. Paint yellow flag at 8400' EOP. Paint white flag at 6300' EOP. Flow check well and confirm no flow. LD BHA.
10/13/2023 BHA OOH, bit grader = 3-2-BT. Prep to pump Eline Slack out of the reel. Function test BOPE. Pump slack out. 368' of slack pumped out, cut and boot eline. Close
Master & Swab Valves and LTT to swap 3" Combi's for 2-3/8" x 3-1/2" VBRs. Good test, swap rams. RU Test Joint to test VBR's. Test VBR's for 2-7/8" & 3-1/2" -
Witness waived by Guy Cook. Test Packoffs, good PT. Load 7/8" Drift Ball and pump for BOT Disco. 7/8" Drift Ball recovered, RD nozzle BHA and prep floor to run
liner. M/U and RIH with 2-7/8" 6.4# 13Cr STL solid liner assembly. Fill every 10 jts. M/U and RIH with remaining 3-1/4" and 3-1/2" solid liner assembly. M/U X
nipple and 3.70" deployment sleeve. M/U Baker BSTLRT. M/U 2-3/8" PH6 joints for eline space out. M/U to injector. RIH with liner assembly @ 80 fpm per Baker
specialist. In Rate = .53 bpm, Out Rate = 1 bpm. In WT = 9.05 ppg, Out WT = 9.96 ppg. Correct depth at window flag. PUW = 54k. RIH through window clean. RIH
to 10,100' and circulate KWF out. In Rate = 1.71 bpm, Out Rate = 1.7 bpm. In WT = 8.94 ppg, Out WT = 9.71 ppg. Circulating psi = 2604. RIH with liner from
10,241' after well displaced back to drilling mud. Tag TD on depth with liner. Record PU weights and depths. Position reel for ball drop. Pump 3/4" ball to release
from liner.
10/14/2023 Continue circulating 3/4" ball to release from liner. Reduce rate at 80% Volume. No ball on seat at volume, increase rate. PU 20' past breakover and spud liner on
bottom. 35 bbls over volume still no ball on seat. Still no ball on seat at 3x coil volume, load and launch 2nd ball. 2nd ball launched and at the same time the first ball
landed. Pressure up and release tool sheared out at 2900psi, PU to confirm we are released. Load liner for 04-46A in PS and process. We are released, displace
coil and well to KCl. Hold PJSM with Nabors & Halliburton CMT Crew. PT CMT Line to 4500psi. CMT wet at 11:36, 5:53 min Thickening Time (17:29). Batch 35
bbls CMT, pump 29.6 bbls into the coil, shut down and displace CMT with rig pump. 81 bbls away Zero the Out MM and take returns to 1 pit. 89.2 bbls, shut down
pump, PU and side exhaust 3 bbls of CMT and 4.5 bbls of Contam Pill. Set back down and Shear out LWP, LWP bumped at volume 18.2 bbls. Held 1000psi over
for 2 min stable, bleed off to check floats. Getting flow back from floats, Pressure up to 4000psi (1500psi over) bleed off pressure, still getting flow back from liner.
Pressure up to 4000psi and dump the pressure, floats are now holding. Pressure up 1500psi, PU to pressure drop and stop then come online with pump to contam
CMT at the TOL. Did not see a pressure drop after PU 20', online with pump, RIH to contam TOL with Exhaust Pill. Stung back into TOL, PU to pressure drop and
circ at max rate PUH 250' to contam excess CMT above TOL. POOH chasing Exhaust Pill OOH. When we PU and did not see a pressure drop after 20' to contam
the CMT at the TOL, some CMT may have sloughed into the TOL. We RIH and stung back into the TOL, pumped contam but there might be some CMT in the
deployment sleeve. OOH, flow check well good. Skid back L/D 6 jts PH-6 + liner running tools. Tools have functioned normally. Recover both 3/4" balls. Break off
BTT swivel, offload. M/U nozzle + DBPV. Jet stack, flush dead legs. RIH to freeze protect well. FP well f/ 2500' w/ diesel. Tag up close MV service tree valves. Leak
tight test SV, MV 3500 psi good. Skid back remove DBPV. Pump slack back. Rig up hydraulic cutter cut 270' of CT for 1.5% slack. Dress CT and install Nabors CT
connector. Pull test 50k good. Pump slack forward. Install BHI cable head.
10/15/2023 Swap VBR's for 3" Combi Rams. Shell test door seals, good test. Blow down surface lines and coil with Big Boy Air Compressor. ND MPD Line. ND BOPE and PT
the Tree Cap. Good PT. Rig Released at 12:00 noon.
ACTIVITYDATE SUMMARY
10/16/2023
T/I/O=0/0/0. Post CDR. Perform 30 min. no flow test on tubing. Set 4" "H" TWC #436
with Dryrod. Removed 4" CIW CDR tree with MV and NU 4" CIW production tree with
New MV. Torqued flanges to spec. Pressure tested tree against TWC to 500/5000
psi. Passed. Pulled 4" "H" TWC #436 with dryrod. Installed tree cap and PT to 500
psi. Pass. Installed production piping and set timber base and wellhouse. ***Job
Complete*** Final WHP's 0/0/0.
10/17/2023
CT #9 1.75" Coil Tubing - Job Scope = Mill/Drift, RPM log, CBL and Perf
MIRU, MU BOT milling assembly w/ 2.3" 3 bladed junk mill.
***Job Continued 10/18/23***
10/18/2023
CT #9 1.75" Coil Tubing - Job Scope = Mill/Drift, RPM log, CBL and Perf
RIH w/ BOT milling assembly w/ 2.3" 3 bladed junk mill. No Cmt at LNR Top (went
right thru @ 8722' MD). Tag @ 11,414' CTM / 11,420' Mech. Displace diesel w/ slick
1% kcl out CT. Paint Yellow flag 50' off Btm 11,364' CTM / 11,370' Mech. Circ slick
1% kcl thru LNR. Perform LNR LAP Test to 1200 psi. POOH. BD BOT 2.30" milling
assembly. MU BOT shorty MHA. Program & MU Baker Atlas RPM Tools. RIH.
PBTD 11,402' MD. Pass #1, Log OOH 20 fpm to 8600'. RIH to PBTD 11,402' MD.
Pass #2, Log OOH 20 fpm to 8600'. POOH. Receive good data. Trim pipe for chrome
management.
***Continued on 10/19/23***
10/19/2023
CT #9 1.75" Coil Tubing - Job Scope: Mill/Drift, RPM log, CBL and Perf
Make up HES RBT Cement Bond log BHA and RIH. Tag TD at 11416' CTM/ 11419'
Mech. Log up at 50 fpm from TD to 8600'. Paint flag at 11000'. POOH. BD HES Mem
Tools. -10' Corr and Bond Log looks good. MU HES 2" Maxfire Guns 31.16' loaded.
RIH. Corr Depth at Flag. Perf 11,184' - 11,215.16'. POOH. FP Well 2500'. BD
Spent perf guns. RDMO CTU 9
***Job Complete***
Daily Report of Well Operations
PBU 06-20B
WELL NAME
Date :
Shoe @ :FC @ :Top Liner @ :
Type:
Type :
Type :
Type :
Type :
XYes No
Yes X No Yes X No
X Yes No X Yes No
Date :
Volume lost during displacement (bbls) :
Density (ppg) : 8.4 Volume pumped (bbls) : 200
06-20B CEMENT REPORT
14-Oct-23 Hole Size :4.25 Casing Size :2-7/8" x 3-1/2"
Lead Slurry
Class G Volume (bbls): 29.6 15.3
Yield : 1.236 Sacks : 134.5 Mixing / Pumping Rate (bpm) : 2.1
Density (ppg) :
Tail Slurry
Volume (bbls) : Density (ppg) :
Yield : Sacks : Mixing / Pumping Rate (bpm) :
Post Flush (Spacer)
1.5 ppb Geovis Density (ppg) : 8.4 Rate (bpm) :
Bump press :
Volume : 150
Displacement :
1.5 ppb Geovis Density (ppg) : 8.4 Rate (bpm) : 2.1 Volume (actual / calculated) : 18.2 / 18.2
2.1
Method Used To Determine TOC : Calculated
4000
Casing Rotated? Reciprocated? % Returns during job : 85%
Cement returns to surface? Spacer returns? Vol to Sur : 3
FCP (psi) : 3800 Pump used for disp : GD Plug Bumped?
Cement In Place At : 13:30 10/14/2023 Estimated TOC : 8,722
4.30
Remarks:
FI
R
S
T
S
T
A
G
E
11421' 11418', 11407' 8722'
Preflush (Spacer)
1% KCl
Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 11/01/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20231101
Well API #PTD #Log Date Log
Company Log Type AOGCC Eset#
BRU 241-23 50283201910000 223061 10/10/2023 AK E-LINE Perf
BRU 241-23 50283201910000 223061 10/21/2023 AK E-LINE Plug/Perf
BRU 242-04 50283201640000 212041 10/13/2023 AK E-LINE Perf/PL
KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/Perf
MPU L-62 50029236850000 220059 10/18/2023 HALLIBURTON MFC24
PBU 06-20B 50029207990200 223075 10/19/2023 HALLIBURTON RBT
PBU W-26A 50029219640100 199081 12/16/2022 AK E-LINE CBL
Please include current contact information if different from above.
T38113
T38113
T38114
T38115
T38116
T38117
T38118
11/1/2023
PBU 06-20B 50029207990200 223075 10/19/2023 HALLIBURTON RBT
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.11.01
14:36:12 -08'00'
David Douglas Hilcorp North Slope, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Hilcorp North Slope, LLC
Date: 10/25/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: PBU 06-20B
PTD: 223-075
API: 50-029-20799-02-00
FINAL LWD FORMATION EVALUATION LOGS (10/06/2023 to 10/13/2023)
Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs)
Pressure While Drilling (PWD)
Final Definitive Directional Surveys
SFTP Transfer - Data Folders:
Please include current contact information if different from above.
PTD: 223-075
T38103
10/26/2023Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.10.26
09:15:45 -08'00'
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Monty M. Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK, 99503
Re: Prudhoe Bay Field, Prudhoe Oil, PBU 06-20B
Hilcorp Alaska, LLC
Permit to Drill Number: 223-075
Surface Location: 350' FSL, 935' FEL, Sec 02, T10N, R14E, UM, AK
Bottomhole Location: 1444' FNL, 1605' FEL, Sec 12, T10N, R14E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above-referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Jessie Chmielowski
Commissioner
DATED this ___ day of September 2023. 25
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2023.09.25 12:31:01
-08'00'
Intermediate
8.14.2023Drilling Manager
08/14/23
Monty M
Myers
PBU 06-20B
By Grace Christianson at 2:30 pm, Aug 14, 2023
SFD 9/22/2023MGR16AUG2023
*
223-075 50-029-20799-02-00
*
* Attached wellbore diagram indicates 2509'
and 9252' respectively. SFD
DSR-8/14/23
* BOPE test to 3500 psi.
* Variance to 20 AAC 25.112(i) approved for alternate plug placement
when production liner placed and cemented in place.
*&:
09/25/23
09/25/23Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski
Date: 2023.09.25 12:31:15 -08'00'
To: Alaska Oil & Gas Conservation Commission
From: Trevor Hyatt
Drilling Engineer
Date: August 11, 2023
Re: PBU 06-20B Permit to Drill
Approval is requested for drilling a CTD sidetrack lateral from well PBU 06-20A with the
Nabors CDR2 Coil Tubing Drilling Rig.
Proposed plan for 06-20B Producer:
See 06-20A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to
drift for whipstock and MIT. E-line will set a 4-1/2" packer whipstock. Coil will mill XN-nipple and a single string
3.80" window + 10' of formation out of the 4-1/2" liner pre-rig. If unable to set the whipstock or mill the window, for
scheduling reasons, the rig will perform that work.
A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the
well. If unbale to mill window pre-rig, the rig will perform that work. The well will kick off drilling in Zone 4 Ivishak
and land in Zone 2. The lateral will continue in Zone 4, 3 and 2 to 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 (will be
perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak
perfs.
The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is
attached for reference.
Pre-Rig Work:
Reference 06-20A Sundry submitted in concert with this request for full details.
General work scope of Pre-Rig work:
1. Slickline: Dummy WS drift and Caliper
2. E-line: Set Whipstock*
3. Service Coil: Mill XN-nipple and Window (mill with rig if needed)
Rig Work - (Estimated to start in November 2023):
1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,460 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 at 9,360’ MD (top of whipstock = top of window/pinch point)
3. Drill – Build & Lateral
a. 3” BHA with GR/RES / Bi-center Bit (4.25”)
b. 20° DLS build section – 357’ MD / Planned TD 9,717’ MD
c. 12° DLS lateral section – 1,650’ MD / Planned TD 11,367’ 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.
PTD 223-075
p
Pressure deployment will be utilized
Sundry 323-457
4. Run and Cement Liner
a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner
b. Swap BOP rams from 3” pipe/slip (drilling) to 2-3/8”x3-1/2” VBRs (running liner) and test to 3500 psi.
c. Run 3-1/2”x3-1/4”x2-7/8” L-80 solid liner to TD
d. Swap well over to KCl
e. Cement Liner with 27 bbls - 15.3 ppg Class G cement (TOC to TOL)*
f. Only if not able to do with service coil extended perf post rig – RPM Log and Perforate well ~30’
g. Freeze protect well from ~2200’ TVD (min)
h. RDMO
Post Rig:
1. V: Valve & tree work
2. S: Set LTP* (if necessary)
3. C: Post rig RPM log and perforate (~30’) (if done post rig - see future Extended Perf Sundry)
4. T: Portable Test Separator Flowback
* 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 (9,360’ MD - 8,653’ TVD)
Pumps
On Pumps Off
A Target BHP at Window (ppg)4,410 psi 4,410 psi
9.8
B Annular friction - ECD (psi/ft)562 psi 0 psi
0.06
C Mud Hydrostatic (ppg)3,870 psi 3,870 psi
8.6
B+C Mud + ECD Combined 4,431 psi 3,870 psi
(no choke pressure)
A-(B+C)Choke Pressure Required to Maintain 0 psi 540 psi
Target BHP at window and deeper
Operation Details:
Reservoir Pressure:
The estimated reservoir pressure is expected to be 3,336 psi at 8,800’ TVD (7.3 ppg equivalent).
Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,460 psi (from estimated
reservoir pressure).
Mud Program:
Drilling: Minimum MW of 8.4 ppg KCL with Geovis for drilling. Managed pressure used to maintain
constant BHP.
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.
Completion: A minimum MW 8.6 ppg KWF to be used for liner deployment. Will target 9.8 ppg to match
managed pressure target.
Disposal:
All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4.
Fluids >1% hydrocarbons or flammables must go to GNI.
Fluids >15% solids by volume must go to GNI.
Fluids with solids that will not pass through 1/4” screen must go to GNI.
Fluids with PH >11 must go to GNI.
Hole Size:
4.25” hole for the entirety of the production hole section.
Liner Program:
3-1/2”, 9.3#, 13Cr solid/cemented liner: 9,210’ MD – 9,340’ MD (130’ liner)
3-1/4”, 6.6#, 13Cr solid/cemented liner: 9,340’ MD – 9,800’ MD (460’ liner)
2-7/8”, 6.5#, 13Cr solid/cemented liner: 9,800’ MD – 11,367’ MD (1,567’ liner)
The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary
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:
BOP diagram is attached. MPD and pressure deployment is planned.
Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi.
The annular preventer will be tested to 250 psi and 2,500 psi.
1.5 wellbore volumes of KWF will be on location at all times during drilling operations.
Solid 2-7/8” Liner Running Ram Change: Change out 3” pipe/slip rams (for drilling) to 2-3/8”x3-1/2” VBR
rams for liner run. Test VBR rams to 250 psi and 3,500 psi.
A X-over shall be made up to a 2-3/8” safety joint including a TIW valve for all tubulars ran in hole.
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:
Directional plan attached. Maximum planned hole angle is 110°. Inclination at kick off point is 30°.
Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
Distance to nearest property line – 19,000’
Distance to nearest well within pool – 930’
Logging:
MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section.
Real time bore pressure to aid in MPD and ECD management.
RPM Log prior to perforating.
(7.3 ppg equivalent)
MPD and pressure deployment is planned.
Perforating:
~30’ perforated post rig (See future perforating sundry request – if extended perforating is used)
2” perf guns, 6 SPF, 60 deg phasing
If post rig extended perforating with service coil is not an option, the well will be perforated with the rig or
post rig under this PTD.
The well will be perforated between the whipstock and TD of the newly drilled CTD well, completely in the
Ivishak pool.
Anti-Collision Failures:
WP03 has two failures. Close approach is in the target reservoir. Plan to shut in failed wells or keep
online with contingencies to have extra fluid on location and heightened awareness to shut well in if
needed.
i. 06-23A - Sidetracked/Abandoned.
ii. 06-18B wp01 - Future CTD Well.
Hazards:
PBU DS-06 is an H2S pad.
o The highest recorded H2S well on the pad was from 06-09 (395 ppm) in 1987.
o The last recorded H2S on 06-20A is 14 ppm taken 11/24/2021.
No fault crossings expected.
Low lost circulation risk.
Trevor Hyatt CC: Well File
Drilling Engineer Joseph Lastufka
907-223-3087
H2S pad.
WP03 has two failures.
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
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06-20B_TPH06-20B_SHL
ADL028311
DS6
PAD 3
U010N014E
Sec. 12
Sec. 1
Sec. 11
Sec. 2
PRUDHOE BAY UNIT
13-18
06-20
06-19
06-18
06-15
06-13
06-05
06-04
OWDW-C
06-24B
06-04B
06-04A
OWDW-SW PR121014
PR111014
PR021014
Map Date: 4/4/2023
Prudhoe Bay Unit
06-20B Well
wp03 E0 350 700
Feet
Legend
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Other Well Paths
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Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME:______________________________________
PTD:_____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD:__________________________POOL:____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in nogreater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
223-075
PBU 06-20B
PRUDHOE BAY PRUDHOE OIL
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e
g
An
n
u
l
a
r
D
i
s
p
o
s
a
l
PT
D
#
:
22
3
0
7
5
0
PR
U
D
H
O
E
B
A
Y
,
P
R
U
D
H
O
E
O
I
L
-
6
4
0
1
5
0
NA
1
P
e
r
m
i
t
f
e
e
a
t
t
a
c
h
e
d
Ye
s
E
n
t
i
r
e
W
e
l
l
l
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e
s
w
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t
h
i
n
A
D
L
0
0
2
8
3
1
1
.
2
L
e
a
s
e
n
u
m
b
e
r
a
p
p
r
o
p
r
i
a
t
e
Ye
s
3
U
n
i
q
u
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w
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l
l
n
a
m
e
a
n
d
n
u
m
b
e
r
Ye
s
P
R
U
D
H
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E
B
A
Y
,
P
R
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D
H
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E
O
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L
P
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L
-
6
4
0
1
5
,
g
o
v
e
r
n
e
d
b
y
C
O
3
4
1
J
4
W
e
l
l
l
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c
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d
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n
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d
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f
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d
p
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o
l
Ye
s
5
W
e
l
l
l
o
c
a
t
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d
p
r
o
p
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r
d
i
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t
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n
c
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f
r
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m
d
r
i
l
l
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n
g
u
n
i
t
b
o
u
n
d
a
r
y
Ye
s
6
W
e
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
o
t
h
e
r
w
e
l
l
s
Ye
s
7
S
u
f
f
i
c
i
e
n
t
a
c
r
e
a
g
e
a
v
a
i
l
a
b
l
e
i
n
d
r
i
l
l
i
n
g
u
n
i
t
Ye
s
8
I
f
d
e
v
i
a
t
e
d
,
i
s
w
e
l
l
b
o
r
e
p
l
a
t
i
n
c
l
u
d
e
d
Ye
s
9
O
p
e
r
a
t
o
r
o
n
l
y
a
f
f
e
c
t
e
d
p
a
r
t
y
Ye
s
10
O
p
e
r
a
t
o
r
h
a
s
a
p
p
r
o
p
r
i
a
t
e
b
o
n
d
i
n
f
o
r
c
e
Ye
s
11
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
c
o
n
s
e
r
v
a
t
i
o
n
o
r
d
e
r
Ye
s
12
P
e
r
m
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t
c
a
n
b
e
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s
s
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e
d
w
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h
o
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t
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d
m
i
n
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s
t
r
a
t
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v
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a
p
p
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v
a
l
Ye
s
13
C
a
n
p
e
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m
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t
b
e
a
p
p
r
o
v
e
d
b
e
f
o
r
e
1
5
-
d
a
y
w
a
i
t
NA
14
W
e
l
l
l
o
c
a
t
e
d
w
i
t
h
i
n
a
r
e
a
a
n
d
s
t
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t
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a
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t
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o
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e
d
b
y
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n
j
e
c
t
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o
n
O
r
d
e
r
#
(
p
u
t
I
O
#
i
n
c
o
m
m
e
n
t
s
)
NA
15
A
l
l
w
e
l
l
s
w
i
t
h
i
n
1
/
4
m
i
l
e
a
r
e
a
o
f
r
e
v
i
e
w
i
d
e
n
t
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
NA
16
P
r
e
-
p
r
o
d
u
c
e
d
i
n
j
e
c
t
o
r
:
d
u
r
a
t
i
o
n
o
f
p
r
e
-
p
r
o
d
u
c
t
i
o
n
l
e
s
s
t
h
a
n
3
m
o
n
t
h
s
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
NA
17
N
o
n
c
o
n
v
e
n
.
g
a
s
c
o
n
f
o
r
m
s
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o
A
S
3
1
.
0
5
.
0
3
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(
j
.
1
.
A
)
,
(
j
.
2
.
A
-
D
)
Ye
s
T
h
i
s
w
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l
l
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s
a
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n
z
o
n
e
C
T
D
s
i
d
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t
r
a
c
k
f
r
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m
a
n
e
x
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t
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n
g
w
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l
l
b
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w
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t
h
p
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s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
18
C
o
n
d
u
c
t
o
r
s
t
r
i
n
g
p
r
o
v
i
d
e
d
Ye
s
T
h
i
s
w
e
l
l
i
s
a
i
n
z
o
n
e
C
T
D
s
i
d
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t
r
a
c
k
f
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m
a
n
e
x
i
s
t
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n
g
w
e
l
l
b
o
r
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w
i
t
h
p
r
e
s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
19
S
u
r
f
a
c
e
c
a
s
i
n
g
p
r
o
t
e
c
t
s
a
l
l
k
n
o
w
n
U
S
D
W
s
Ye
s
T
h
i
s
w
e
l
l
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s
a
i
n
z
o
n
e
C
T
D
s
i
d
e
t
r
a
c
k
f
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o
m
a
n
e
x
i
s
t
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n
g
w
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l
l
b
o
r
e
w
i
t
h
p
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s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
20
C
M
T
v
o
l
a
d
e
q
u
a
t
e
t
o
c
i
r
c
u
l
a
t
e
o
n
c
o
n
d
u
c
t
o
r
&
s
u
r
f
c
s
g
Ye
s
T
h
i
s
w
e
l
l
i
s
a
i
n
z
o
n
e
C
T
D
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
e
s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
21
C
M
T
v
o
l
a
d
e
q
u
a
t
e
t
o
t
i
e
-
i
n
l
o
n
g
s
t
r
i
n
g
t
o
s
u
r
f
c
s
g
Ye
s
T
h
i
s
w
e
l
l
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s
a
i
n
z
o
n
e
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D
s
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r
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k
f
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m
a
n
e
x
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s
t
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n
g
w
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l
l
b
o
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w
i
t
h
p
r
e
s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
22
C
M
T
w
i
l
l
c
o
v
e
r
a
l
l
k
n
o
w
n
p
r
o
d
u
c
t
i
v
e
h
o
r
i
z
o
n
s
Ye
s
23
C
a
s
i
n
g
d
e
s
i
g
n
s
a
d
e
q
u
a
t
e
f
o
r
C
,
T
,
B
&
p
e
r
m
a
f
r
o
s
t
Ye
s
C
D
R
2
h
a
s
a
d
e
q
u
a
t
e
t
a
n
k
a
g
e
a
n
d
g
o
o
d
t
r
u
c
k
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n
g
s
u
p
p
o
r
t
.
24
A
d
e
q
u
a
t
e
t
a
n
k
a
g
e
o
r
r
e
s
e
r
v
e
p
i
t
Ye
s
S
u
n
d
r
y
3
2
3
-
4
5
7
25
I
f
a
r
e
-
d
r
i
l
l
,
h
a
s
a
1
0
-
4
0
3
f
o
r
a
b
a
n
d
o
n
m
e
n
t
b
e
e
n
a
p
p
r
o
v
e
d
Ye
s
H
a
l
l
i
b
u
r
t
o
n
c
o
l
l
i
s
i
o
n
s
c
a
n
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d
e
n
t
i
f
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s
1
c
l
o
s
e
a
p
p
r
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c
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t
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a
n
a
b
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n
d
o
n
e
d
w
e
l
l
.
N
o
H
S
E
r
i
s
k
.
26
A
d
e
q
u
a
t
e
w
e
l
l
b
o
r
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s
e
p
a
r
a
t
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p
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s
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d
Ye
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T
h
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s
w
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l
l
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a
n
i
n
z
o
n
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C
T
D
s
i
d
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t
r
a
c
k
f
r
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m
a
n
e
x
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s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
e
s
s
u
r
e
i
n
t
e
g
r
i
t
y
.
27
I
f
d
i
v
e
r
t
e
r
r
e
q
u
i
r
e
d
,
d
o
e
s
i
t
m
e
e
t
r
e
g
u
l
a
t
i
o
n
s
Ye
s
M
P
D
b
u
t
r
e
s
e
r
v
o
i
r
p
r
e
s
s
u
r
e
b
e
l
o
w
w
a
t
e
r
g
r
a
d
i
e
n
t
.
28
D
r
i
l
l
i
n
g
f
l
u
i
d
p
r
o
g
r
a
m
s
c
h
e
m
a
t
i
c
&
e
q
u
i
p
l
i
s
t
a
d
e
q
u
a
t
e
Ye
s
C
T
P
a
c
k
o
f
f
,
f
l
o
w
c
r
o
s
s
,
a
n
n
u
l
a
r
,
b
l
i
n
d
s
h
e
a
r
,
C
T
p
i
p
e
s
l
i
p
s
,
f
l
o
w
c
r
o
s
s
,
B
H
A
p
i
p
e
s
l
i
p
s
,
C
T
p
i
p
e
s
l
i
p
s
29
B
O
P
E
s
,
d
o
t
h
e
y
m
e
e
t
r
e
g
u
l
a
t
i
o
n
Ye
s
7
-
1
/
1
6
"
5
0
0
0
p
s
i
s
t
a
c
k
p
r
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s
s
u
r
e
t
e
s
t
e
d
t
o
3
5
0
0
p
s
i
.
30
B
O
P
E
p
r
e
s
s
r
a
t
i
n
g
a
p
p
r
o
p
r
i
a
t
e
;
t
e
s
t
t
o
(
p
u
t
p
s
i
g
i
n
c
o
m
m
e
n
t
s
)
Ye
s
F
l
a
n
g
e
d
c
h
o
k
e
a
n
d
k
i
l
l
l
i
n
e
s
b
e
t
w
e
e
n
d
u
a
l
c
o
m
b
i
'
s
w
r
e
m
o
t
e
c
h
o
k
e
31
C
h
o
k
e
m
a
n
i
f
o
l
d
c
o
m
p
l
i
e
s
w
/
A
P
I
R
P
-
5
3
(
M
a
y
8
4
)
Ye
s
32
W
o
r
k
w
i
l
l
o
c
c
u
r
w
i
t
h
o
u
t
o
p
e
r
a
t
i
o
n
s
h
u
t
d
o
w
n
Ye
s
P
B
U
D
S
6
-
p
a
d
i
s
a
n
d
H
2
S
p
a
d
>
1
0
0
p
p
m
.
M
o
n
i
t
o
r
i
n
g
w
i
l
l
b
e
r
e
q
u
i
r
e
d
.
33
I
s
p
r
e
s
e
n
c
e
o
f
H
2
S
g
a
s
p
r
o
b
a
b
l
e
NA
T
h
i
s
i
s
a
d
e
v
e
l
o
p
m
e
n
t
w
e
l
l
.
34
M
e
c
h
a
n
i
c
a
l
c
o
n
d
i
t
i
o
n
o
f
w
e
l
l
s
w
i
t
h
i
n
A
O
R
v
e
r
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
No
D
S
0
6
w
e
l
l
s
a
r
e
H
2
S
-
b
e
a
r
i
n
g
.
H
2
S
m
e
a
s
u
r
e
s
a
r
e
r
e
q
u
i
r
e
d
.
35
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
/
o
h
y
d
r
o
g
e
n
s
u
l
f
i
d
e
m
e
a
s
u
r
e
s
Ye
s
E
x
p
e
c
t
e
d
p
r
e
s
s
u
r
e
r
a
n
g
e
i
s
0
.
3
7
2
p
s
i
/
f
t
(
7
.
2
p
p
g
E
M
W
)
.
O
p
e
r
a
t
o
r
'
s
p
l
a
n
n
e
d
m
u
d
p
r
o
g
r
a
m
36
D
a
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
a
p
p
e
a
r
s
s
u
f
f
i
c
i
e
n
t
t
o
c
o
n
t
r
o
l
a
n
t
i
c
i
p
a
t
e
d
p
r
e
s
s
u
r
e
s
a
n
d
m
a
i
n
t
a
i
n
w
e
l
l
b
o
r
e
s
t
a
b
i
l
i
t
y
.
M
P
D
w
i
l
l
b
e
u
t
i
l
i
z
e
d
.
37
S
e
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
S
e
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
C
o
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
SF
D
Da
t
e
9/
2
2
/
2
0
2
3
Ap
p
r
MG
R
Da
t
e
9/
6
/
2
0
2
3
Ap
p
r
SF
D
Da
t
e
9/
2
2
/
2
0
2
3
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
Pu
b
l
i
c
Co
m
m
i
s
s
i
o
n
e
r
Da
t
e
*&:
JL
C
9
/
2
5
/
2
0
2
3
