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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: 8/7/2024
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20240807
Well API #PTD #Log Date Log
Company Log Type AOGCC Eset#
END 2-72 50029237810000 224016 6/27/2024 HALLIBURTON COILFLAG
END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON RBT
END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON TEMP
END 2-74 50029237850000 224024 7/20/2024 HALLIBURTON MFC
MPU B-24 50029226420000 196009 7/16/2024 HALLIBURTON MFC
MPU E-19A 50029227460100 224010 6/22/2024 HALLIBURTON COILFLAG
NS-10 50029229850000 200182 7/18/2024 HALLIBURTON MFC
NS-10 50029229850000 200182 7/18/2024 HALLIBURTON TEMP
NS-32 50029231790000 203158 7/16/2024 HALLIBURTON MFC
NS-32 50029231790000 203158 7/15/2024 HALLIBURTON TEMP
PBU H-13A 50029205590100 209044 7/23/2024 HALLIBURTON RBT
PBU L-246 50029237650000 223078 7/23/2024 HALLIBURTON IPROF
PBU R-26B 50029215470100 210025 7/5/2024 HALLIBURTON RBT
PBU R-36 50029225220000 194144 6/21/2024 HALLIBURTON RBT
PBU V-216 50029232160000 204130 7/11/2024 HALLIBURTON IPROF
PBU V-217 50029233340000 206162 7/11/2024 HALLIBURTON IPROF
Please include current contact information if different from above.
T39365
T39365
T39365
T39366
T39367
T39368
T39369
T39369
T39370
T39370
T39371
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T39375
T39376
MPU E-19A 50029227460100 224010 6/22/2024 HALLIBURTON COILFLAG
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.08.07 13:19:30 -08'00'
5-1/2"x4-1/2"
By Grace Christianson at 2:11 pm, Jun 25, 2024
Completed
5/27/2024
JSB
RBDMS JSB 070224
G
DSR-7/17/24MGR16DEC2025
Drilling Manager
06/24/24
Monty M
Myers
Digitally signed by Taylor
Wellman (2143)
DN: cn=Taylor Wellman (2143)
Date: 2024.06.25 12:26:24 -
08'00'
Taylor Wellman
(2143)
_____________________________________________________________________________________
Revised By: JNL 6/24/2024
SCHEMATIC
Milne Point Unit
Well: MPE-19A
Last Completed: 5/27/2024
PTD: 224-010
TD =10,200’ (MD) / TD =6,993’ (TVD)
20”
Orig. KB Elev.: 58.55’/ GL Elev.: 24.5’
7”
2a
5b
9-5/8”
1a
9-5/8” Howco ‘ES’
Cementer @ 1,296’
PBTD = 10,179’ (MD) / PBTD =6,993’ (TVD)
TOC 5,000’ MD
Leak below
4,640’ MD
3a
4a
6b
7b/8b/9b
7569’-2.7” DPY
SLV
3-1/2” x 7” WS
7889’ MD
CASING DETAIL
Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF
20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355
9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759
7” Intermediate 26 / L-80 / BTC 6.151 Surface 7,896’ 0.0383
5-1/2” Scab Liner 17 / L-80 / Hyd 511 4.892 Surface 7,611’ 0.0232
4-1/2” Scab Liner 12.6 / L-80 / TXP 3.958 7,611’ 7,760’ 0.0152
2-3/8” Liner 4.7 / L-80 / H511 1.995 7,569’ 10,200’ 0.0039
TUBING DETAIL
3-1/2” Tubing 9.3 / L-80 / EUE 2.992 Surface 7,609’ 0.0087
TUBING JEWELRY DETAIL (a)
No Depth Item
1a 7,482’ Viking Sliding Sleeve (Opens Down)
2a 7,539’ 5-1/2”x3-1/2” D&L Permanent Packer
3a 7,597’ X-Nipple (ID=2.813”)
4a 7,608' WLEG – Btm @ 7,609’
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
B 9175’ 9732’ 7042’ 6999’ 557 5/26/2024 Open
B 9732’ 10175’ 6999’ 6993’ 443 6/22/2024 Open
OPEN HOLE / CEMENT DETAIL
24" 250 sks of Arcticset I (Approx.)
12-1/4" 1,195 sks PF “E”, 725 sx Class G
8-1/2” 334 sks Class G
Scab Liner Lead = 50 Bbls / Tail = 40 Bbls
3-1/4” 96 sx Class G
WELL INCLINATION DETAIL
KOP @ 350’ / A KOP @ 7896’
90° Hole Angle = 8,335’
Hole Angle through perforations = 99°
TREE & WELLHEAD
Tree 2-9/16”- 5M Cameron
Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT
2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile
GENERAL WELL INFO
API: 50-029-22746-01-00
Drilled and Cased by Nabors 27E - 3/21/1997
CTD Prep by ASR – 3/14/2024
A Sidetrack: 5/27/2024
SCAB LINER JEWELRY DETAIL (b)
No Depth Item
5b 7,611’ 5-1/2”x4-1/2” XO
6b 7,658’ NCS Frac Sleeve
7b 7,718’ 7”x4-1/2” D&L Iso Packer
8b 7,597’ XN-Nipple (ID=3.725”) w/ 3-1/2” Reducer (ID=2.813”)
9b 7,756’ WLEG – Btm @ 7,760’
ACTIVITYDATE SUMMARY
5/29/2024
*** WELL S/I ON ARRIVAL***
SHIFT SSLV @ 7464' MD, SLV OPEN
PUMP 3 BBLS DSL DOWN IA
SET JET PUMP IN SSLV @ 7464' MD
*** WELL LEFT S/I ON DEPARTURE ***
6/20/2024
***WELL FLOWING ON DEPARTURE***
PULLED JET PUMP FROM 7454'SLM (7482'MD)
RAN 3-1/2" 42 BO, SHIFT SLIDING SLEEVE CLOSED AT 7450'SLM (7482'MD)
***WELL S/I ON DEPARTURE***
6/21/2024
LRS Coil Tubing Unit #1 - 1.5" 0.134 WT Coil - Job Scope: Adperf
Travel to milne point. Stand by for rig up to replace failed chicksan. MIRU. Check
valve on kill line installed backwards. Reconfigure check valve and continue w/ rig up.
***Job In Progress***
6/22/2024
LRS Coil Tubing Unit #1 - 1.5" 0.134 WT Coil - Job Scope: Adperf
***Job Continued from 21-Jun-2024***
Complete rig up and PT PCE. RIH w/ 1.5" stingers and DJN. Attempt to bullhead
down well but too tight. Down on pump and continue in hole.Tag @ 10186' CTM.
Circulate well to 1% KCL bottoms up and trip OOH circulating. At surface perform no
flow test. Had to isolate the wing back to the pit Made up scaffold. MU NS MHA and
pressure test MHA with the safety joint at the same time. Safety joint failed first test,
grease the safety joint and it passed. MU LRS 1.75 stinger and HES memory
gamma/ccl. RIH.Tag TD 10193 CTM. Log up to 9670 ctm, paint a correlation flag.Log
up to 7400'. POOH pumping pipe displacement. Test H2S/LEL monitors, pass. At
surface perform no flow checks and line up to circulate across the top. Good data
from the log, -9' correction. Hold PJSM and begin deploying guns. RIH w/ guns,
correlated to flag, tag bottom and confirm depth. PUH to bottom shot @ 10175' and
launch ball. Perofrate zone 9732' - 10175'. Trip OOH pumping displacement to keep
the hole full. At surface. Fill trip tank.
***Job in Progress***
6/23/2024
LRS Coil Tubing Unit #1 - 1.5" 0.134 WT Coil - Job Scope: Adperf
***Job Continued from 22-Jun-2024***
Flood trip tank from upright, perform no flow check. Hold PJSM and begin
undeploying guns. Undeploy all guns. Shut in well and RDMO.
***Job Complete***
6/23/2024
*** WELL S/I ON ARRIVAL ***
OPEN SSD @ 7482' MD W/ 3-1/2 42BO
RUN 2.5 MAGNET TO 7550' SLM
SET 3" 11B JET PUMP, W/ GAUGE S/N 117647 ( START 12:09 ) IN SSD @ 7482'
MD
*** WELL LEFT S/I ON DEPARTURE ***
Daily Report of Well Operations
PBU MPE-19A
WELL NAME
Date :
Shoe @ :FC @ :Top Liner @ :
Type:
Type :
Type :
Type :
Type :
Yes X No
Yes X No Yes X No
X Yes No X Yes No
Date :
Volume lost during displacement (bbls) :
Density (ppg) : 9.5 Volume pumped (bbls) : 300
MPE-19A CEMENT REPORT
24-May-24 Hole Size :3-1/4"Casing Size :2-3/8"
Lead Slurry
Class G Volume (bbls): 21.2 15.3
Yield : 1.24 Sacks : 96 Mixing / Pumping Rate (bpm) : 0.7
Density (ppg) :
Tail Slurry
Volume (bbls) : Density (ppg) :
Yield : Sacks : Mixing / Pumping Rate (bpm) :
Post Flush (Spacer)
1.5 ppb Geovis Density (ppg) : 9.5 Rate (bpm) :
Bump press :
Volume : 65
Displacement :
1.5 ppb Geovis Density (ppg) : 9.5 Rate (bpm) : 0.7 Volume (actual / calculated) : 19.9 / 21.2
1.2
Method Used To Determine TOC : Calculated
Casing Rotated? Reciprocated? % Returns during job : 94%
Cement returns to surface? Spacer returns? Vol to Sur : 4.5
FCP (psi) : 4300 Pump used for disp : GD Plug Bumped?
Cement In Place At : 22:15 5/24/2024 Estimated TOC : 7568'
1.30
Remarks:
FI
R
S
T
S
T
A
G
E
10200 10186', 10197' 7569'
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#
David Douglas Hilcorp Alaska, 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:
Date: 06/18/2024
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: MPU E-19A
PTD: 224-010
API: 50-029-22746-01-00
FINAL LWD FORMATION EVALUATION LOGS (05/18/2024 to 05/23/2024)
Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs)
Pressure While Drilling (PWD)
Final Definitive Directional Surveys
SFTP Transfer - Data Main Folders:
Please include current contact information if different from above.
224-010
T38945
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.06.19 08:14:01 -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: Milne Point Field, Kuparuk River Pool, MPU E-19A
Hilcorp Alaska, LLC
Permit to Drill Number: 224-010
Surface Location: 3711' FSL, 1812' FEL, Sec 25, T13N, R10E, UM, AK
Bottomhole Location: 928' FNL, 1026' FWL, Sec 25, T13N, R10E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this day of March 2024.
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.03.01 13:46:39
-09'00'
1
Drilling Manager
02/13/24
Monty M
Myers
By Kayla Junke at 3:59 pm, Feb 14, 2024
* BOPE test to 3500 psi.
* 1.5 wellbore volumes of KWF available on location while drilling.
50-029-22746-01-00224-010
MGR15FEB2024 A.Dewhurst 29FEB24
DSR-2/14/24*&:
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2024.03.01 13:46:54 -09'00'
03/01/24
03/01/24
To: Alaska Oil & Gas Conservation Commission
From: Ryan Ciolkosz
Drilling Engineer
Date: February 13, 2024
Re:MPU E-19A Permit to Drill
Approval is requested for drilling a CTD sidetrack lateral from well MPU E-19 with the Nabors CDR2
Coiled Tubing Drilling.
Proposed plan for MPU E-19A Producer:
See MPU E-19 Sundry request for complete pre-rig details - Prior to drilling activities, a RWO will be completed
to repair a casing leak in the 7" casing using a 5-1/2" scab casing and complete with 3-1/2" tubing (Separate
Sundry). Post RWO, screening will be conducted to drift and caliper for whipstock.
A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the
well. The rig will set a 3-1/2"x7" flow through whipstock and mill a single string 2.80" window + 10' of formation.
The well will kick off drilling and land in the Kuparuk. The lateral will continue in the Kuparuk to TD. The proposed
sidetrack will be completed with a 2-3/8” L-80 solid liner and cemented. This completion WILL abandon the parent
Kuparuk perfs. The well will be perforated post rig as part of this PTD.
The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is
attached for reference.
Pre-Rig Work: (Estimated to start in March 1st 2024)
x Reference MPU E-19 Sundry submitted in concert with this request for full details.
1. RWO : Pull tubing, run 5-1/2” Scab and 3-1/2” tubing, MIT (Separate Sundry)
2. Slickline : Drift for whipstock and Caliper
3. Valve Shop : Pre-CTD Tree Work
4. Operations : Remove wellhouse and level pad.
Rig Work: (Estimated to start in April 2024)
1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,492 psi). Give AOGCC 24hr notice
prior to BOPE test.
2. Kill Well and set 3-1/2" x 7" whipstock at 7893' - 0 deg ROHS
3. Mill 2.80” Window.
4. Drill build section: 3.25" OH, ~462' (40 deg DLS planned).
5. Drill production lateral: 3.25" OH, ~1850' (12 deg DLS planned). Swap to KWF for liner.
6. Run 2-3/8” 13Cr solid liner
7. Pump primary cement job: 25 bbls, 15.3 ppg Class G, TOC at TOL*.
8. Only if not able to do with service coil extended perf post rig – Perforate Liner
9. Freeze protect well to a min 2,200' TVDss.
10. Close in tree, RDMO.
* Approved alternate plug placement per 20 AAC 25.112(i)
Post Rig Work:
1. Valve Shop : Valve & tree work
2.Service Coil : Post rig perforate (~500’) See extended perf procedure attached
3.Slickline : Set JP
Sundry 324-084
25 bbls, 15.3 ppg Class G, T
PTD 224-010
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” (big hole) & 2-3/8” (slim hole) 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 (7893' MD -7,006' TVD)
Pumps On Pumps Off
A Target BHP at Window (ppg)4,299 psi 4,299 psi
11.8
B Annular friction - ECD (psi/ft)710 psi 0 psi
0.09
C Mud Hydrostatic (ppg)3,133 psi 3,133 psi
8.6
B+C Mud + ECD Combined 3,843 psi 3,133 psi
(no choke pressure)
A-(B+C)Choke Pressure Required to Maintain 455 psi 1,166 psi
Target BHP at window and deeper
Operation Details:
Reservoir Pressure:
x The estimated reservoir pressure is expected to be 3,200 psi at 7,000 TVD. (8.8 ppg equivalent).
x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,492 psi Give AOGCC 24hr
notice prior to BOPE test (from estimated reservoir pressure).
Mud Program:
x Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain
constant BHP.
Disposal:
x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4.
x Fluids >1% hydrocarbons or flammables must go to GNI.
x Fluids >15% solids by volume must go to GNI.
x Fluids with solids that will not pass through 1/4” screen must go to GNI.
x Fluids with PH >11 must go to GNI.
Hole Size:
x 3.25 hole for the entirety of the production hole section.
Liner Program:
x 2-3/8", 4.6#, L80 Solid: 7,533' MD – 10,205' MD (2,672' liner)
x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary.
x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole.
3,200 psi at 7,000 TVD. (8.8 ppg equivalent)
- 1.5 wellbore volumes of KWF available on location while drilling. - mgr
Well Control:
x BOP diagram is attached. MPD and pressure deployment is planned.
x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi.
x The annular preventer will be tested to 250 psi and 2,500 psi.
x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations.
x A X-over shall be made up to a 2" safety joint including a TIW valve for all tubulars ran in hole.
x 2" safety joint will be utilized while running solid or slotted liner. The desire is to keep the same standing
orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre-
installed TIW valve). When closing on a 2" safety joint, 2 sets of pipe/slip rams will be available, above
and below the flow cross providing better well control option.
Directional:
x Directional plan attached. Maximum planned hole angle is 99°. Inclination at kick off point is 31°.
x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
x Distance to nearest property line – 10,560 FT
x Distance to nearest well within pool – 1,430 FT
Logging:
x MWD directional and Gamma Ray will be run through the entire open hole section.
x Real time bore pressure to aid in MPD and ECD management.
Perforating:
x 500' perforated post rig (if done post rig – see attached perf procedure).
x 1.57" Perf Guns at 6 spf
x If post rig extended perforating with service coil is not an option, the well will be perforated with the rig or
post rig under this PTD.
x The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely
in the Kuparuk pool.
Anti-Collision Failures:
x All wells pass anti-collision against MPU E-19A WP-01.
Hazards:
x MPE is not an H2S pad. H2S reading on E-19: 2 ppm on 02/13/2014.
x Max H2S recorded on DS/Pad: 46 ppm..
x 1 fault crossings expected.
x Medium lost circulation risk.
Ryan Ciolkosz CC: Well File
Drilling Engineer (907-244-4357) Joseph Lastufka
Post-Rig Service Coil Perforating Procedure:
Coiled Tubing
Notes:
x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS
coverage is required.
x Note: The well will be killed and monitored before making up the initial perfs guns. This will provide
guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the
job. If pressure is seen immediately after perforating, it will either be killed by bullheading while
POOH or circulating bottoms up through the same port that opened to shear the firing head.
Coil Tubing
1. MIRU Coiled Tubing Unit and spot ancillary equipment.
2. MU nozzle drift BHA (include SCMT and/or RPM log as needed).
3. RIH to PBTD.
a. Displace well with weighted brine while RIH (minimum 9.0 ppg to be overbalanced).
4. POOH (and RPM log if needed) and lay down BHA.
5. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through
the brass upon POOH with guns.
6. There will be no perforations to bullhead kill the well. Well will already be loaded w/ weighted brine or KCl
per previous steps. Re-load well at WSS discretion.
7. At surface, prepare for deployment of TCP guns.
8.Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, weighted brine as needed
(minimum 9.0 ppg). Maintain continuous hole fill taking returns to tank until lubricator connection is
reestablished. Fluids man-watch must be performed while deploying perf guns to ensure the well
remains killed and there is no excess flow.
9.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps with crew
prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint
and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working
platform for quick deployment if necessary.
10. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.Max
BHA length per PTD is 500ft. Fluids man-watch must be performed while deploying perf guns to ensure
the well remains killed and there is no excess flow.
a. Perforation details
i.Perf Interval:The well will be perforated between the CTD whipstock and TD of the
newly drilled CTD well, completely in the Kuparuk pool.
ii.Perf Length:500’
iii.Gun Length:500’
iv.Weight of Guns (lbs):2300lbs (4.6ppf)
11. MU lubricator and RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate perforation
intervals (TBD). POOH.
a. Note any tubing pressure change in WSR.
12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and
stick the BHA.Confirm well is dead and re-kill if necessary before pulling to surface.
13. Pump pipe displacement while POOH.Stop at surface to reconfirm well dead and hole full.
14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown
of TCP gun string. Standing orders flow chart included with this sundry request. Ensure safety joint and
TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA.
15. Freeze protect well to 2,000’ TVD.
16. RDMO CTU.
Coiled Tubing BOPs
Standing Orders for Open Hole Well Control during Perf Gun Deployment
Equipment Layout Diagram
Well Date
Quick Test Sub to Otis -1.1 ft
Top of 7" Otis 0.0 ft
Distances from top of riser
Excluding quick-test sub
Top of Annular 2.75 ft
C L Annular 3.40 ft
Bottom Annular 4.75 ft
CL Blind/Shears 6.09 ft
CL 2.0" Pipe / Slips 6.95 ft B3 B4
B1 B2
Kill Line Choke Line
CL 2-3/8" Pipe / Slip 9.54 ft
CL 2.0" Pipe / Slips 10.40 ft
TV1 TV2
T1 T2
Flow Tee
Master
Master
LDS
IA
OA
LDS
Ground Level
3" LP hose open ended to Flowline
CDR2-AC BOP Schematic
CDR2 Rig's Drip Pan
Fill Line from HF2
Normally Disconnected
3" HP hose to Micromotion
Hydril 7 1/16"
Annular
Blind/Shear
2.0" Pipe/Slips
2 3/8" Pipe/Slips
2 3/8" Pipe/Slips
7-1/16"
5k Mud
Cross
2.0" Pipe/Slips
2-3/8" Pipe /
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$)MPU E-19A_BHL
MPU E-19A_TPH
MPU E-19A_SHL
MPU CFP
MPU E
U013N010E
Sec. 25
Sec. 24
Sec. 26
Sec. 23
ADL25518
ADL47437
MILNE POINT UNIT
E-19
E-16
B-21
E-26
E-33
E-20
E-15
B-22
B-17
B-09
B-06
B-22A
CFP-1
E-35PB1
B-22AXX
E-38 PB1
E-20AL1PB1
Map Date: 2/13/2024
Milne Point Unit
MPE-19A Well
wp02
E0 770 1,540Feet
Legend
MPU_E_19A_wp02
$)MPU E-19A_BHL
!MPU E-19A_SHL
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!Other Surface Holes (SHL)
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Other Well Paths
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MP U E-19A wp02
Top of Window - 7893'MDEnd 40dls - 8355'MD
TD - 10205'MD
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Vertical Section at 175.00° (200 usft/in)
MP
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E-19
MPU E-19A wp02
Top of Window - 7893'MD
End 40dls - 8355'MD
TD - 10205'MD
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect
1 7893.00 31.37 315.87 7006.97 2277.99 -2492.26 0.00 0.00 -2486.54
2 7913.00 33.17 315.87 7023.88 2285.66 -2499.70 9.00 0.00 -2494.82
3 8055.09 90.00 315.87 7088.76 2371.73 -2583.18 40.00 0.00 -2587.84
4 8355.00 90.00 195.91 7088.76 2311.26 -2823.75 40.00 -90.00 -2548.57
5 8535.00 90.00 174.31 7088.76 2133.04 -2839.69 12.00 -90.00 -2372.42
6 8675.00 90.00 191.11 7088.76 1993.69 -2846.28 12.00 90.00 -2234.18
7 8835.00 99.46 174.33 7075.48 1835.18 -2853.97 12.00 -60.00 -2076.94
8 8995.00 94.09 155.76 7056.44 1682.47 -2813.02 12.00 -105.00 -1921.24
9 9285.00 93.36 120.89 7037.01 1469.70 -2623.55 12.00 -90.00 -1692.76
10 9525.00 92.94 149.73 7023.53 1301.13 -2456.82 12.00 90.00 -1510.31
11 9765.00 91.62 178.52 7013.79 1072.89 -2391.94 12.00 92.00 -1277.28
12 9945.00 90.77 200.11 7010.00 896.36 -2420.91 12.00 92.00 -1103.94
13 10185.00 89.95 171.32 7008.47 660.06 -2444.57 12.00 -91.50 -870.61
14 10205.00 89.82 173.72 7008.51 640.23 -2441.96 12.00 93.00 -850.62
Project: Milne Point
Site: M Pt E Pad
Well: MPU E-19
Wellbore: MPU E-19A
Plan: MPU E-19A wp02
WELLBORE DETAILS
Parent Wellbore:MPU E-19Top of Window: 7893.00
MPU E-19A wp02
Depth From Depth To Survey/Plan Tool
209.66 7893.00 1 : MWD - Standard (MPU E-19) 3_MWD
7893.00 10205.00 MPU E-19A wp02 (MPU E-19A) 3_MWD
WELL DETAILS
Northing: 6016250.39Easting: 569332.77Lattitude: 70° 27' 17.1056 NLongitude: 149° 26' 3.1547 W
MPU E-19A wp02
SECTION DETAILS
Hilcorp Alaska, LLC
SURVEY PROGRAM
NAD 1927 (NADCON CONUS)
US State Plane 1927 (Exact solution)
Alaska Zone 04
PROJECT DETAILS REFERENCE INFORMATION
Coordinate(N/E) Reference: Well MPU E-19, True North
Vertical (TVD) Reference: KBE @ 58.55usft
Measured Depth Reference: KBE @ 58.55usft
Section (VS) Reference: Slot - (0.00N, 0.00E)
Calculation Method: Minimum Curvature
REFERENCE INFORMATION
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_____________________________________________________________________________________
Revised By: TDF 4/20/2023
SCHEMATIC
Milne Point Unit
Well: MPE-19
Last Completed: 4/12/2023
PTD: 197-037
TD =8,249’(MD) / TD = 7,310’(TVD)
20”
Slickline Tag
4/28/2002 @
8,089’ WLM
Orig. KB Elev.: 34.05’/ GL Elev.: 24.5’
7”
9-5/8”1
9-5/8” Howco ‘ES’
Cementer @ 1,296’
KUP C Sands
PBTD =8,164’ (MD) / PBTD = 7,237’(TVD)
KUP B Sands
2 & 3
TOC 5,000’ MD
Leak below
4,640’ MD
CASING DETAIL
Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF
20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355
9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759
7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383
TUBING DETAIL
2-7/8” Tubing 6.5 / L-80 / EUE 2.867 Surface 2,664’ 0.0058
JEWELRY DETAIL
No Depth Item
1 2,660’ Mule shoe pup –Btm @ 2,664’
2 8,164’ 7” Float Collar
3 8,247’ 7” Float Shoe
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open
Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open
OPEN HOLE / CEMENT DETAIL
20" Cmt w/ 250 sks of Arcticset I in 24” Hole
9-5/8" Cmt w/ 1,195 sks PF “E”, 725 sx Class “G” in 12-1/4” Hole
7” Cmt w/ 334 sks Class “G” in 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 350’
Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’
Hole Angle through perforations = 31 deg.
TREE & WELLHEAD
Tree 2-9/16”- 5M Cameron
Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT
2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile
GENERAL WELL INFO
API: 50-029-22746-00-00
Drilled and Cased by Nabors 27E - 3/21/1997
Completed with ESP by Nabors 4ES – 5/4/1997
ESP RWO w/ 4-ES – 12/3/2004
ESP RWO w/ 3S – 6/20/2008
ESP RWO w/ 4-ES – 10/17/2010
ESP RWO w/ Doyon 16 – 7/19/2012
WFD Set Lower Packer / Patch Set – 6/30/2013
ESP RWO w/ Doyon 16 – 4/11/2014
ESP RWO w/ Nordic 3 – 1/31/2015
ESP RWO w/ Nordic 3 – 12/26/2015
Install Kill String by ASR – 4-12-2023
_____________________________________________________________________________________
Revised By: TTW 1/22/2024
PROPOSED SCHEMATIC
Milne Point Unit
Well: MPE-19
Last Completed: 4/12/2023
PTD: 197-037
TD =8,249’(MD) / TD = 7,310’(TVD)
20”
Slickline Tag
4/28/2002 @
8,089’ WLM
Orig. KB Elev.: 58.55/ GL Elev.: 24.5’
7”
2a
5b
9-5/8”
1a
9-5/8” Howco ‘ES’
Cementer @ 1,296’
KUP C Sands
Whipstock set
@ 7893’
PBTD =8,164’ (MD) / PBTD = 7,237’(TVD)
KUP B Sands
2 & 3
TOC 5,000’ MD
Leak below
4,640’ MD
3a
4a6b
7b/8b/9b
CASING DETAIL
Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF
20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355
9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759
5-1/2” Scab Liner 17 / L-80 / Hyd 511 4.767 Surface ±7,700’ 0.0232
4-1/2” Scab Liner 12.6 / L-80 / TXP 4.833 ±7,700’ ±7,780’ 0.0152
7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383
TUBING DETAIL
3-1/2” Tubing 9.2 / L-80 / EUE 2.992 Surface ±7,700’ 0.0087
TUBING JEWELRY DETAIL (a)
No Depth Item
1a ±7,500’ Sliding Sleeve
2a ±7,540’ 5-1/2”x3-1/2” Permanent Packer
3a ±7,590’ X-Nipple (ID=2.813”)
4a ±7,630’ WLEG
PERFORATION DETAIL
Sands Tofp (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open
Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open
OPEN HOLE / CEMENT DETAIL
20" Cmt w/ 250 sks of Arcticset I in 24” Hole
9-5/8" Cmt w/ 1,195 sks PF “E”, 725 sx Class “G” in 12-1/4” Hole
7” Cmt w/ 334 sks Class “G” in 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 350’
Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’
Hole Angle through perforations = 31 deg.
TREE & WELLHEAD
Tree 2-9/16”- 5M Cameron
Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT
2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile
GENERAL WELL INFO
API: 50-029-22746-00-00
Drilled and Cased by Nabors 27E - 3/21/1997
Completed with ESP by Nabors 4ES – 5/4/1997
ESP RWO w/ 4-ES – 12/3/2004
ESP RWO w/ 3S – 6/20/2008
ESP RWO w/ 4-ES – 10/17/2010
ESP RWO w/ Doyon 16 – 7/19/2012
WFD Set Lower Packer / Patch Set – 6/30/2013
ESP RWO w/ Doyon 16 – 4/11/2014
ESP RWO w/ Nordic 3 – 1/31/2015
ESP RWO w/ Nordic 3 – 12/26/2015
Install Kill String by ASR – 4-12-2023
SCAB LINER JEWELRY DETAIL (b)
No Depth Item
5b ±7,635’ 5-1/2”x4-1/2” XO
6b ±7,675’ NCS Sleeve
7b ±7,725’ 7”x4-1/2” Permanent Packer
8b ±7,745’XN-Nipple (ID=3.725”) w/ 3-1/2”
Reducer (ID=2.813”)
9b ±7,755’ WLEG
_____________________________________________________________________________________
Revised By: JNL 2/6/2024
PROPOSED SCHEMATIC
Milne Point Unit
Well: MPE-19A
Last Completed: TBD
PTD: TBD
TD =10,205’ (MD) / TD = 7,009’(TVD)
20”
Orig. KB Elev.: 58.55’/ GL Elev.: 24.5’
7”
2a
5b
9-5/8”
1a
9-5/8” Howco ‘ES’
Cementer @ 1,296’
PBTD = 10,150’(MD) / PBTD = 7,008’(TVD)
TOC 5,000’ MD
Leak below
4,640’ MD
3a
4a
6b
7b/8b/9b
7533’-2.7” DPY
SLV
3-1/2” x 7”WS
7893’ MD
CASING DETAIL
Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF
20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355
9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759
5-1/2” Scab Liner 17 / L-80 / Hyd 511 4.767 Surface ±7,700’ 0.0232
4-1/2” Scab Liner 12.6 / L-80 / TXP 4.833 ±7,700’ ±7,780’ 0.0152
7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383
2-3/8” Liner 4.6 / L-80 / H511 1.901 7,533’ 10,205’ 0.0039
TUBING DETAIL
3-1/2” Tubing 9.2 / L-80 / EUE 2.992 Surface ±7,700’ 0.0087
TUBING JEWELRY DETAIL (a)
No Depth Item
1a ±7,500’ Sliding Sleeve
2a ±7,540’ 5-1/2”x3-1/2” Permanent Packer
3a ±7,590’ X-Nipple (ID=2.813”)
4a ±7,630’ WLEG
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
OPEN HOLE / CEMENT DETAIL
24" 250 sks of Arcticset I (Approx.)
12-1/4" 1,195 sks PF “E”, 725 sx Class “G”
8-1/2” 334 sks Class “G”
3-1/4” 113 sx Class G
WELL INCLINATION DETAIL
KOP @ 350’
Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’
Hole Angle through perforations = 31 deg.
TREE & WELLHEAD
Tree 2-9/16”- 5M Cameron
Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT
2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile
GENERAL WELL INFO
API: 50-029-22746-01-00
Drilled and Cased by Nabors 27E - 3/21/1997
Install Kill String by ASR – 4-12-2023
A Sidetrack: TBD
SCAB LINER JEWELRY DETAIL (b)
No Depth Item
5b ±7,635’ 5-1/2”x4-1/2” XO
6b ±7,675’ NCS Sleeve
7b ±7,725’ 7”x4-1/2” Permanent Packer
8b ±7,745’XN-Nipple (ID=3.725”) w/ 3-1/2”
Reducer (ID=2.813”)
9b ±7,755’ WLEG
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.
224-010
MPU E-19A
KUPARUK RIVER OIL POOLMILNE POINT
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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
y
)
NA
17
N
o
n
c
o
n
v
e
n
.
g
a
s
c
o
n
f
o
r
m
s
t
o
A
S
3
1
.
0
5
.
0
3
0
(
j
.
1
.
A
)
,
(
j
.
2
.
A
-
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
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
.
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
A
l
l
d
r
i
l
l
i
n
g
o
n
t
h
i
s
s
i
d
e
t
r
a
c
k
w
i
l
l
b
e
l
o
w
e
x
i
s
t
i
n
g
s
u
r
f
a
c
e
c
a
s
i
n
g
s
h
o
e
.
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
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
.
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
F
u
l
l
y
c
e
m
e
n
t
e
d
p
r
o
d
u
c
t
i
o
n
l
i
n
e
r
.
P
a
r
e
n
t
w
e
l
l
i
s
o
l
a
t
e
s
t
h
e
r
e
s
e
r
v
o
i
r
.
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
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
.
F
u
l
l
i
n
t
e
g
r
i
t
y
a
b
o
v
e
s
i
d
e
t
r
a
c
k
.
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
i
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
4
-
0
8
4
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
s
h
o
w
s
m
a
n
a
g
e
a
b
l
e
c
o
l
l
i
s
i
o
n
r
i
s
k
.
26
A
d
e
q
u
a
t
e
w
e
l
l
b
o
r
e
s
e
p
a
r
a
t
i
o
n
p
r
o
p
o
s
e
d
Ye
s
A
l
l
d
r
i
l
l
i
n
g
b
e
l
o
w
t
h
e
s
u
r
f
a
c
e
c
a
s
i
n
g
s
h
o
e
.
N
o
d
i
v
e
r
t
e
r
r
e
q
u
i
r
e
d
.
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
t
o
b
e
u
t
i
l
i
z
e
d
.
1
.
5
w
e
l
l
b
o
r
e
v
o
l
u
m
e
s
o
f
K
W
F
>
8
.
8
p
p
p
g
o
n
l
o
c
a
t
i
o
n
.
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
e
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
No
M
P
U
E
p
a
d
i
s
n
o
t
a
n
H
2
S
p
a
d
>
1
0
0
p
p
m
.
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
M
e
a
s
u
r
e
s
r
e
q
u
i
r
e
d
.
H
2
S
r
e
a
d
i
n
g
o
f
2
p
p
m
f
r
o
m
E
-
1
9
(
2
0
1
4
)
.
M
a
x
r
e
a
d
i
n
g
4
6
p
p
m
.
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
A
n
t
i
c
i
p
a
t
e
d
p
o
r
e
p
r
e
s
s
u
r
e
s
o
f
8
.
8
p
p
g
E
M
W
.
O
n
e
f
a
u
l
t
c
r
o
s
s
i
n
g
a
n
t
i
c
i
p
a
t
e
d
.
36
D
a
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
S
e
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
S
e
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
C
o
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
2/
2
9
/
2
0
2
4
Ap
p
r
MG
R
Da
t
e
3/
1
/
2
0
2
4
Ap
p
r
AD
D
Da
t
e
2/
2
9
/
2
0
2
4
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
*&
:
