Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout220-0481. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Swap
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 13,150 feet N/A feet
true vertical 3,799 feet N/A feet
Effective Depth measured 13,148 feet 6,645 feet
true vertical 3,799 feet 3,970 feet
Perforation depth Measured depth See Schematic feet
True Vertical depth See Schematic feet
Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 / EUE 8rd 6,440' 3,961'
Packers and SSSV (type, measured and true vertical depth)7" x 9-5/8" BOT SLZXP N/A See Above N/A
12. Stimulation or cement squeeze summary: N/A
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title: Wells Manager Contact Phone:
324-184
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
31
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Ryan Lewis
ryan.lewis@hilcorp.com
303-906-5178
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
490
Gas-Mcf
MD
114'
280
Size
114'
1,725'
398 32048
397 331315
389
measured
TVD
7-5/8"
4-1/2"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
220-048
50-029-23678-00-00
3800 Centerpoint Dr, Suite 1400
Anchorage, AK 99503
3. Address:
Hilcorp Alaska LLC
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0025509, ADL0025515
MILNE POINT / SCHRADER BLUFF OIL
MILNE PT UNIT L-60
Plugs
Junk measured
Length
Liner Screens
6,654'
6,505'
Casing
Conductor
3,970'
3,799'
6,654'
13,150'
4,765'
2,063'Surface
Surface
Tie-Back
20"
9-5/8"
9-5/8"
114'
2,063'
4,790psi
8,540psi
6,870psi
5,750psi
6,890psi
9,020psi
6,828' 3,968'
Burst
NA
Collapse
NA
4,760psi
3,090psi
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Grace Christianson at 1:42 pm, Dec 05, 2024
Digitally signed by Taylor
Wellman (2143)
DN: cn=Taylor Wellman (2143)
Date: 2024.12.05 13:02:55 -
09'00'
Taylor Wellman
(2143)
WCB 2-12-2025
DSR-12/16/24
RBDMS JSB 121224
_____________________________________________________________________________________
Revised by: TDF 12/2/2024
SCHEMATIC
Milne Point Unit
Well: MPU L-60
Last Completed: 10/31/2024
PTD: 220-048
TD =13,150’(MD) /TD =3,799’ (TVD)
4
20”
Orig. KB Elev.: 50.77’ / GL Elev.: 16.6’
7-5/8”7
8&9
10
4
9-5/8”
1
2
3
16
See
Screen/
Solid
Liner
Detail
PBTD =13,148’ (MD) / PBTD = 3,799’ (TVD)
10-3/4”‘ES’
Cementer @
±2,588’ MD
5&6
4-1/2”
Shoe @
13,150’
11
13
1214
15
3-1/2”CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor 129.5# / X56 / Weld N/A Surface 114’ N/A
9-5/8" Surface 47 / L-80 / TXP 8.679 Surface 2,063’ 0.0758
9-5/8” Surface 40 / L-80 / TXP 8.525 2,063’ 6,828’ 0.0758
7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,654’ 0.0459
4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,645’ 13,150’ 0.0149
TUBING DETAIL
3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 Surface 6,440’ 0.0087
OPEN HOLE / CEMENT DETAIL
Conductor ±270 ft3
12-1/4"Stg 1 – Lead – 565 sx / Tail – 400 sx
Stg 2 – Lead – 664 sx / Tail – 270 sx
8-1/2” Cementless Screens Liner in 8-1/2” hole
WELL INCLINATION DETAIL
KOP @ 353’
Max Hole Angle = 94° @ 7,064’ MD
TREE & WELLHEAD
Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing
Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs
GENERAL WELL INFO
API: 50-029-23678-00-00
Completion Date: 6/28/2020
ESP Completion by ASR1: 10-31-2024
4-1/2” SOLID LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
36 6,671’ 3,970’ 8,146’ 3,934’
3 8,231’ 3,933’ 8,355’ 3,932’
3 8,439’ 3,930’ 8,561’ 3,926’
3 11,357’ 3,824’ 11,479’ 3,824’
JEWELRY DETAIL
No. Top MD Item ID
1 230’ GLM #2: 3.5" x 1" Patco GLM W/ BK-OV 2.867”
2 5,337’ GLM #1: 3.5" x 1" Patco GLM W/ BK-DGLV 2.867”
3 5,804’ 2.813” XN Nipple, 2.75” No Go 2.750”
4 6,340’ Ported Discharge Head w/ Sub: PMP 513 &513/538PX PRESS PORT
5 6,341’ Pump #2: 538PMSXD FLEX27 82 FER H6
6 6,359’ Pump #1: 538PMSXD FLEX27 135 FER H6
7 6,387’ Gas Separator & Intake: 538GM2T HV E V X MT HS FER/GPXARCINT
8 6,393’ Upper Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC
9 6,400’ Lower Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC
10 6,407’ Motor: MT 562XP S CS 450/3135/88_18R FER
11 6,435 Intake Sensor: Gauge E7 MW 456 400 BAR 150C AFL
12 6,438’ Centralizer: Bottom @ 6,440’
13 6,645’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8” (TVD 3970’) 6.190”
14 6,656’ 7-5/8” Tieback Assy. 6.190”
15 6,667’ 7” H563 x 4.5” Hyd 625 XO 3.850”
16 13,150’ Shoe 3.950”
4-1/2” SCREEN LINER DETAIL
Jts Top
(MD)Top (TVD) Btm (MD) Btm (TVD)
2 8,146’ 3,934’ 8,231’ 3,933’
2 8,355’ 3,932’ 8,439’ 3,930’
67 8,561’ 3,926’ 11,357’ 3,824’
39 11,479’ 3,824’ 13,108’ 3,799’
Well Name Rig API Number Well Permit Number Start Date End Date
MP L-60 ASR#1 50-029-23678-00-00 220-048 10/29/2024 11/1/2024
Accept rig 10:00 10/29/2024. Fill stack and test BOPE 250/2500psi. Test #1 - Good. Perform passing tests 1 - 7 per procedure.
Perform choke bleed-off, PVT alarm test and accumulator drawdown. Pull CTS/BPV. Install 3-1/2" NSCT landing joint w/ TIW
and kelly hose. Line up through gas buster. BOLDS. Pull hanger offseat w/ 52k, 61k PUW. POOH w/ 3-1/2", 9.3#,L, EUE ESP
completion while maintaining 2x displacement F/6,409' - T/ 4,794'
No operations to report.
10/26/2024 - Saturday
No operations to report.
10/29/2024 - Tuesday
10/27/2024 - Sunday
No operations to report.
10/28/2024 - Monday
10/25/2024 - Friday
No operations to report.
10/23/2024 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
No operations to report.
10/24/2024 - Thursday
No operations to report.
Well Name Rig API Number Well Permit Number Start Date End Date
MP L-60 ASR#1 & WH 50-029-23678-00-00 220-048 10/29/2024 11/1/2024
No operations to report.
No operations to report.
11/2/2024 - Saturday
No operations to report.
11/5/2024 - Tuesday
11/3/2024 - Sunday
No operations to report.
11/4/2024 - Monday
11/1/2024 - Friday
WELLHEAD: BOP stack removed, PU tree/adapter. New RX54 gasket, seal subs and pull umbilical from penn. Set tree/adapter,
torque to spec and test hgr void to 500/5000 (PASS). Bled of pressure and pull Bpv with dry rod, NO PRESSURE. WELL
SECURED.
10/30/2024 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
Continue POOH w/ 3-1/2", 9.3#,L, EUE ESP completion while maintaining 2x displacement F/ 4,794' Begin L/D ESP equipment.
OOH W/ ESP. All clamps and equipment accounted for. P/U and service ESP Equipment. Install discharge head. Test ESP cable.
good test. Begin RIH W/ 3.5" EUE and ESP T/ 3,071' Testing ESP every 1000' maintaining 2x displacement.
10/31/2024 - Thursday
Cont. RIH w/ ESP assy. on 9.3# 3-1/2" L-80 EUE tubing F/ 3,071' T/ 6,407' Testing ESP every 1000' maintaining 2x
displacement. P/U M/U Hanger w/ FOSV and kelly hose attached. Orientate hanger as per well head rep. Complete Hanger
splice. Land Hanger with ESP umbilical. RILDS. Install BPV. Remove source water from pits & RDMO. Rig Release 18:00 10-31-
2024. WELLHEAD: MU tbg hgr to LJ and comp. string, install ESP penn. and Centralift MU splice. Five ft hgr into profile RKB
15.90' RILDS and pull LJ. Set 3" Bpv from floor. SB for RD.
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: 12/05/2024
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20241205
Well API #PTD #Log Date Log
Company Log Type AOGCC
ESet
AN 15(GRANITE PT
ST 18742 15) 50733200700000 167082 11/18/2024 AK E-LINE Perf
BRU 221-26 50283202010000 224098 10/24/2024 AK E-LINE Perf
BRU 233-23T 50283202000000 224088 10/21/2024 AK E-LINE Perf
BRU 233-23T 50283202000000 224088 10/30/2024 AK E-LINE Perf
BRU 241-23 50283201910000 223061 11/8/2024 AK E-LINE Perf
BRU 241-26 50283201970000 224068 11/12/2024 AK E-LINE Plug/Perf
END 2-72 50029237810000 224016 10/16/2024 HALLIBURTON COILFLAG
END 2-72 50029237810000 224016 10/18/2024 HALLIBURTON COILFLAG
MGS-ST 17595-05 50733100710000 165038 10/6/2024 AK E-LINE CBL
MPU F-109 50029235960000 218014 10/28/2024 READ CaliperSurvey
MPU J-02 50029220710000 190096 11/16/2024 READ CaliperSurvey
MPU J-47 50029238010000 224120 11/9/2024 READ LeakPointSurvey
MPU D-01 50029206640000 181144 10/23/2024 AK E-LINE TubingPunch
MPU F-02 50029226730000 196070 11/18/2024 READ CaliperSurvey
MPU I-08 50029228210000 197192 10/22/2024 AK E-LINE TubingPunch
MPU I-08 50029228210000 197192 10/26/2024 HALLIBURTON JETCUT
MPU L-60 50029236780000 220048 10/26/2024 HALLIBURTON MFC24
MRU M-25 50733203910000 187086 11/15/2024 AK E-LINE Plug
NCIU A-21 50883201990000 224086 11/9/2024 AK E-LINE Perf
NCIU A-21 50883201990000 224086 10/19/2024 AK E-LINE Perf
NCIU A-21 50883201990000 224086 10/30/2024 AK E-LINE Perf
NCIU A-21 50883201990000 224086 10/30/2024 AK E-LINE Plug/Perf
PBU 06-07A 50029202990100 224043 9/30/2024 HALLIBURTON RBT
PBU 14-41A 50029222900100 224076 11/8/2024 HALLIBURTON RBT
PBU H-36A 50029226050100 200025 10/26/2024 HALLIBURTON RBT
PCU 02A 50283200220100 224110 11/24/2024 AK E-LINE Perf
Please include current contact information if different from above.
T39808
T39809
T39810
T39810
T39811
T39812
T39813
T39813
T39814
T39815
T39816
T39817
T39818
T39819
T39820
T39820
T39821
T39822
T39823
T39823
T39823
T39823
T39824
T39825
T39826
T39827
MPU L-60 50029236780000 220048 10/26/2024 HALLIBURTON MFC24
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.12.05 14:52:46 -09'00'
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap
2.Operator Name: 4.Current Well Class:5.Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number): 10. Field:
MILNE POINT
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
13,150 NA
Casing Collapse
Conductor NA
Surface 4,760psi
Surface 3,090psi
Tie-Back 4,790psi
Liner Screens 8,540psi
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
7" x 9-5/8" BOT SLZXP Liner Top Packer and NA 6,645' MD / 3,970' TVD and NA
NA
6,654
6,828
6,654
4-1/2"
See Schematic
303-906-5178
ryan.lewis@hilcorp.com
Wells Manager
April 19, 2024
13,1506,505
3-1/2"
3,799
Perforation Depth MD (ft):
See Schematic
3,9707-5/8"
20"
9-5/8"
114
9-5/8"4,765
2,063
NA
6,870psi
114
1,725
3,968
114
2,063
9.3# / L-80
TVD Burst
6,409
6,890psi
MD
5,750psi
Hilcorp Alaska, LLC
Length Size
Proposed Pools:
3,799 13,148 3,799 1,093
SCHRADER BLUFF OIL Same
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025509, ADL0025515
220-048
C.O. 477.05 MILNE PT UNIT L-60
3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23678-00-00
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
9,020psi
Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft):
Ryan Lewis
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
No
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 10:04 am, Mar 27, 2024
Digitally signed by Taylor
Wellman (2143)
DN: cn=Taylor Wellman (2143)
Date: 2024.03.27 09:43:19 -
08'00'
Taylor Wellman
(2143)
324-184
BOPE test to 2500 psi.
MGR28MAR24
1,093
10-404
SFD 3/28/2024 DSR-4/12/24JLC 4/12/2024
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.04.12 14:14:38
-08'00'04/12/24
RBDMS JSB 041624
Well: MPL-60
PTD: 220-048
API: 50-029-23678-00-00
Well Name:MPL-60 API Number:50-029-23678-00-00
Current Status:Producer Rig:ASR #1
Estimated Start Date:4/19/2024 Estimated Duration:5 days
Regulatory Contact:Tom Fouts Permit to Drill Number:220-048
First Call Engineer:Ryan Lewis (303) 906-5178 (M)
Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M)
Current Bottom Hole Pressure: 1,490 psi @ 3,970’ TVD 01/29/2024 |7.2 PPGE
Max Potential Surface Pressure: 1,093 psi Gas Column Gradient (0.1 psi/ft)
Max Angle: 90.0° Sail Angle from 6,700’ MD
Brief Well Summary:
MPU L-60 was drilled and completed in June 2020 as a Schrader NB producer with an ESP completion. The ESP
has not failed but shows significant wear on the pumps and resulting BHP.
Objectives:
Pull ESP completion, run new ESP completion.
Notes Regarding Wellbore Condition:
x Casing test to 1,000 psi passed 6/28/2020.
Pre-Rig Procedure (Non Sundried Work)
Fullbore
1. MIT-OA to 1,500 psi for the ESP casing test.
Slickline
1. RU slickline, pressure test PCE to 250psi low / 2,500psi high.
2. Drift and tag with sample bailer.
3. Caliper from 6,315’ to surface.
4. Attempt to pull dummy valve from GLM at 5,736’ MD and leave open.
5. Pull GLV and set dummy valve in upper GLM at 198’ MD.
6. RDMO.
Coiled Tubing (Contingency)
1. Pressure test PCE to 250 psi low / 2,500 psi high.
2. PU 1.75” jet nozzle.
3. Jet down to discharge head at 6,315’ MD.
4. Following best practices in PE manual, pump gel sweeps to clean up tubing.
5. Chase gel out of hole.
6. PU tubing punch.
7. RIH and tag discharge head.
8. Pump down ball to fire tubing punch.
9. Confirm circulation by pumping down backside of coil.
10. Freeze protect tubing as POOH.
11. RDMO.
Well: MPL-60
PTD: 220-048
API: 50-029-23678-00-00
Pumping & Well Support
1. Clear and level pad area in front of well. Spot rig mats and containment.
2. RD well house and flowlines. Clear and level area around well.
3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank.
4. Pressure test lines to 3,000 psi.
5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing
to 500 barrel returns tank.
6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR
arrival.
7. RD Little Red Services and reverse out skid.
8. Set BPV. ND tree. NU BOPE.
Brief RWO Procedure (Begin Sundried Work)
1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank.
2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing
and casing.
a. If needed, kill well with produced water prior to setting CTS.
3. Test BOPE to 250 psi low/ 2,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each
ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests.
a. Perform test per ASR 1 BOP Test Procedure
b. Notify AOGCC 24 hours in advance of BOP test.
c. Confirm test pressures per the Sundry conditions of approval.
d. Test VBR rams on 3-1/2” test joint.
e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test.
4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the
returns tank. Kill well with produced water as needed. Pull BPV.
a. If indications show pressure underneath BPV, lubricate out BPV.
5. Call out Centrilift for ESP pull.
6. MU landing joint or spear, BOLDS, PU on the tubing hanger.
a. Tubing hanger is a FMC 11"x 3-1/2" Gen 6 HGR, 3-1/2" NSCT Top & BTM.
b. 2020 tubing PU weight on Doyon 14 recorded as 96 kip, their blocks weigh 40 kip = 56 kip
expected. Slack off weight recorded as 25 kip.
c. 3-1/2” L-80 EUE yield is 207 kip.
7. Confirm hanger free, lay down tubing hanger.
8. POOH and lay down the 3-1/2” tubing.
a. Confirm with Engineer on how much tubing to re-use based on caliper.
b. Keep ported discharge head and centralizer for future use.
c. Note any sand or scale inside or on the outside of the ESP on the morning report.
d. Recorded Clamp Totals:
i. Canon Clamps: 109
Well: MPL-60
PTD: 220-048
API: 50-029-23678-00-00
ii. Flat guard clamps: 3
iii. Protectolizers: 5
iv. Seal Clamps: 4
v. Pump Clamps: 9
9. Lay Down ESP.
10. RIH with new 3-1/2” 9.3# L-80 ESP completion to +/- 6,400’ and obtain string weights.
a. Check electrical continuity every 1000’.
b. Note PU and SO weights on tally.
c. Install ESP clamps per Baker, and cross coupling clamps every other joint
Nom. Size Length Item Lb/ft Material Notes
5.85 2 Centralizer 4 ~6,400’
4.5 2 Intake Sensor 30
5.62 34 Motor - 300HP 80
5.62 34 Motor - 300HP 80
5.2 7 Lower Tandem Seal 38
5.2 7 Upper Tandem Seal 38
5.2 8 Gas Separator 52
5.38 10 GINPSHH 45
5.38 57 Pumps – 93 stage Flex-47 45
5.38 57 Pumps – 93 stage Flex-47 45
1 Ported Discharge Head 13 L-80
3-1/2" 10 3-1/2" EUE 8rd Pup Jt 9.3 L-80
3-1/2" 30 3-1/2" EUE 8rd L-80 9.3 L-80
3-1/2"10 3-1/2" EUE 8rd Pup Jt 9.3 L-80
3-1/2"2 XN-nipple 2.813" / 2.75" No-Go 9.3 L-80
3-1/2"10 3-1/2" EUE 8rd Pup Jt 9.3 L-80
3-1/2" 60 3-1/2" EUE 8rd Jt 9.3 L-80
3-1/2"10 3-1/2" EUE 8rd Pup Jt 9.3 L-80
3-1/2"8 3-1/2" x 1-1/4" GLM, DV installed 9.3 L-80
3-1/2"10 3-1/2" EUE 8rd Pup Jt 9.3 L-80
3-1/2" 5,810 3-1/2" EUE 8rd Jt 9.3 L-80
3-1/2"10 3-1/2" EUE 8rd Pup Jt 9.3 L-80
3-1/2"8 3-1/2" x 1-1/4" GLM, 1/4" OV 9.3 L-80 ~200 MD
3-1/2"10 3-1/2" EUE 8rd Pup Jt 9.3 L-80
3-1/2" 150 3-1/2" EUE 8rd Jt 9.3 L-80
3-1/2" 10 Space out pup 9.3 L-80
3-1/2" 30 Tubing Hanger with full joint 9.3 L-80
11. Land tubing hanger. Use extra caution to not damage cable.
12. Lay down landing joint.
Well: MPL-60
PTD: 220-048
API: 50-029-23678-00-00
13. Set BPV.
14. RDMO ASR.
Post-Rig Procedure:
Well Support
1. RD mud boat. RD BOPE house. Move to next well location.
2. RU crane. ND BOPE, set CTS plug, and NU tree.
3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV.
4. RD crane. Move 500 bbl returns tank and rig mats to next well location.
5. RU well house and flowlines.
Attachments:
1. Current Wellbore Schematic
2. Proposed Wellbore Schematic
3. BOPE Schematic
_____________________________________________________________________________________
Revised by: TDF 1/17/2024
SCHEMATIC
Milne Point Unit
Well: MPU L-60
Last Completed: 6/28/2020
PTD: 220-048
TD =13,150’(MD) /TD =3,799’ (TVD)
4
20”
Orig. KB Elev.: 50.77’ / GL Elev.: 16.6’
7-5/8”
7
8/9
1
0
4
9-5/8”
1
2
3
16
See
Screen/
Solid
Liner
Detail
PBTD =13,148’ (MD) /PBTD =3,799’ (TVD)
10-3/4” ‘ES’
Cementer @
±2,588’ MD
5/6
4-1/2”
Shoe @
13,150’
11
13
1214
15
3-1/2”CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor 129.5# / X56 / Weld N/A Surface 114’ N/A
9-5/8" Surface 47 / L-80 / TXP 8.679 Surface 2,063’ 0.0758
9-5/8” Surface 40 / L-80 / TXP 8.525 2,063’ 6,828’ 0.0758
7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,654’ 0.0459
4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,645’ 13,150’ 0.0149
TUBING DETAIL
3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 Surface 6,409’ 0.0087
OPEN HOLE / CEMENT DETAIL
Conductor ±270 ft3
12-1/4"Stg 1 – Lead – 565 sx / Tail – 400 sx
Stg 2 – Lead – 664 sx / Tail – 270 sx
8-1/2” Cementless Screens Liner in 8-1/2” hole
WELL INCLINATION DETAIL
KOP @ 353’
Max Hole Angle = 94° @ 7,064’ MD
TREE & WELLHEAD
Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing
Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs
GENERAL WELL INFO
API: 50-029-23678-00-00
Completion Date: 6/28/2020
4-1/2” SOLID LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
36 6,671’ 3,970’ 8,146’ 3,934’
3 8,231’ 3,933’ 8,355’ 3,932’
3 8,439’ 3,930’ 8,561’ 3,926’
3 11,357’ 3,824’ 11,479’ 3,824’
JEWELRY DETAIL
No. Top MD Item ID
1 198’ GLM: 3-1/2” w/ 1-1/4” Dummy Valve w/ BK Latch 2.909”
2 5,736’ GLM: 3-1/2” w/ 1-1/4” Dummy Valve w/ BK Latch 2.907”
3 5,795’ 2.813” XN Nipple, 2.75” no go 2.760”
4 6,315’ Discharge Head: B/O PMP 513
5 6,317’ Upper Tandem Pump: 93 Flex47 M FER
6 6,339’ Lower Tandem Pump: 93 Flex47 M FER
7 6,361’ Gas Avoider: Gas Master Extreme 538GS
8 6,366’ Upper Tandem Seal: GSB3DB H6 SB/AB PFSA
9 6,372’ Lower Tandem Seal: GSB3DB H6 SB/AB PFSA
10 6,379’ Motor: 562 XP – 400hp / 2785V / 88A
11 6,405’ Sensor, Zenith
12 6,407’ Centralizer: Bottom @ 6,409’
13 6,645’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8” (TVD 3970’) 6.190”
14 6,656’ 7-5/8” Tieback Assy. 6.190”
15 6,667’ 7” H563 x 4.5” Hyd 625 XO 3.850”
16 13,150’ Shoe 3.950”
4-1/2” SCREEN LINER DETAIL
Jts Top
(MD)Top (TVD) Btm (MD) Btm (TVD)
2 8,146’ 3,934’ 8,231’ 3,933’
2 8,355’ 3,932’ 8,439’ 3,930’
67 8,561’ 3,926’ 11,357’ 3,824’
39 11,479’ 3,824’ 13,108’ 3,799’
_____________________________________________________________________________________
Revised by: DH 2/12/2024
PROPOSED
Milne Point Unit
Well: MPU L-60
Last Completed: 6/28/2020
PTD: 220-048
TD =13,150’(MD) /TD =3,799’ (TVD)
4
20”
Orig. KB Elev.: 50.77’ / GL Elev.: 16.6’
7-5/8”
7
8/9
10
4
9-5/8”
1
2
3
16
See
Screen/
Solid
Liner
Detail
PBTD =13,148’ (MD) /PBTD =3,799’ (TVD)
10-3/4” ‘ES’
Cementer @
±2,588’ MD
5/6
4-1/2”
Shoe @
13,150’
11
13
1214
15
3-1/2”CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor 129.5# / X56 / Weld N/A Surface 114’ N/A
9-5/8" Surface 47 / L-80 / TXP 8.679 Surface 2,063’ 0.0758
9-5/8” Surface 40 / L-80 / TXP 8.525 2,063’ 6,828’ 0.0758
7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,654’ 0.0459
4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,645’ 13,150’ 0.0149
TUBING DETAIL
3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 Surface ±6,400’ 0.0087
OPEN HOLE / CEMENT DETAIL
Conductor ±270 ft3
12-1/4"Stg 1 – Lead – 565 sx / Tail – 400 sx
Stg 2 – Lead – 664 sx / Tail – 270 sx
8-1/2” Cementless Screens Liner in 8-1/2” hole
WELL INCLINATION DETAIL
KOP @ 353’
Max Hole Angle = 94° @ 7,064’ MD
TREE & WELLHEAD
Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing
Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs
GENERAL WELL INFO
API: 50-029-23678-00-00
Completion Date: 6/28/2020
4-1/2” SOLID LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
36 6,671’ 3,970’ 8,146’ 3,934’
3 8,231’ 3,933’ 8,355’ 3,932’
3 8,439’ 3,930’ 8,561’ 3,926’
3 11,357’ 3,824’ 11,479’ 3,824’
JEWELRY DETAIL
No. Top MD Item ID
1 ±203’ GLM: 3-1/2” w/ 1-1/4” OV ±2.909”
2 ±6,041’ GLM: 3-1/2” w/ 1-1/4” Dummy Valve ±2.907”
3 ±6,129’ 2.813” XN Nipple, 2.75” No Go ±2.760”
4 ±6,181’ Ported Discharge Head
5 ±6,182’ Upper Tandem Pump
6 ±6,239’ Lower Tandem Pump
7 ±6,306’ Gas Separator
8 ±6,314’ Upper Tandem Seal
9 ±6,321’ Lower Tandem Seal
10 ±6,328’ Motors – 2 x 300HP
11 ±6,396’ Intake Sensor
12 ±6,398’ Centralizer: Bottom @ ±6,400’
13 6,645’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8” (TVD 3970’) 6.190”
14 6,656’ 7-5/8” Tieback Assy. 6.190”
15 6,667’ 7” H563 x 4.5” Hyd 625 XO 3.850”
16 13,150’ Shoe 3.950”
4-1/2” SCREEN LINER DETAIL
Jts Top
(MD)Top (TVD) Btm (MD) Btm (TVD)
2 8,146’ 3,934’ 8,231’ 3,933’
2 8,355’ 3,932’ 8,439’ 3,930’
67 8,561’ 3,926’ 11,357’ 3,824’
39 11,479’ 3,824’ 13,108’ 3,799’
Milne Point
ASR Rig 1 BOPE
2023
11” BOPE
4.48'
4.54'
2.00'
CIW-U
4.30'
Hydril GK
11" - 5000
VBR or Pipe Rams
Blind11'’- 5000
DSA, 11 5M X 7 1/16 5M (If Needed)
2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves
HCRManualManualHCR
Stripping Head
2-7/8” x 5” VBR
Hilcorp Alaska, LLC Post Office Box 244027
Anchorage, AK 99524-4027
3800 Centerpoint Drive
Suite 1400
Anchorage, AK 99503
Phone: 907/777-8547
September 29, 2023
Mr. Mel Rixse
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Milne Point Conductor Annulus Corrosion Inhibitor Treatments 6/9 to 9/27/2023
Dear Mr. Rixse,
Enclosed please a copy of a spreadsheet with a list of thirteen Milne Point wells that were treated
with corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than
water “grease-like” filler displaces water to prevent external casing corrosion that could result in
a surface casing leak. The attached spreadsheets include the well names, field, API and PTD
numbers, treatment dates and volumes.
If you have any additional questions, please contact me at 907-777-8406 or
dhorner@hilcorp.com.
Sincerely,
Darci Horner
Regulatory Tech
Hilcorp Alaska, LLC
Digitally signed by Darci Horner
(c-100048)
DN: cn=Darci Horner (c-100048)
Date: 2023.09.29 09:45:20 -
08'00'
Darci Horner
(c-100048)
Well Field API PTD
Initial Top
of Cement
(ft.)
Volume of
Cement
Pumped
(bbls)
Final Top of
Cement (ft.)
Cement
Pump Date
Corrosion
Inhibitor
Fill Volume
(gal)
Final CI Top
(ft.)
Corrosion
Inhibitor
Treatment
Date
Comments
MPB-35 MPU 50029237240000 2220850 14' 0 14' N/A 50 surface 9/27/2023 Drilled Sept/Oct 2022.
MPB-39 MPU 50029237470000 2230120 1'6" 0 1'6" N/A 10 surface 6/10/2023 Drilled Mar 2023.
MPI-20 MPU 50029236790000 2200490 10' 1 1 7/2/2023 5 surface 9/27/2023 Completed Apr 8, 2021.
MPI-29 MPU 50029237080000 2220060 6' 0.5 3 7/2/2023 15 surfce 9/27/2023
Drilled in March 2022. Completeted
on 4/30/22.
MPL-60 MPU 50029236780000 2200480 1' 0 1' N/A 10 surface 6/26/2023 Drilled in 2020.
MPL-62 MPU 50029236850000 2200590 1' 0 1' N/A 10 surface 6/26/2023 Drilled in 2020.
MPM-13 MPU 50029236380000 2190870 20' 3.5 2' 8/2/2023 10 surface 9/27/2023 Drilled in 2019.
MPM-27 MPU 50029237160000 2220490 2' 0 2' N/A 20 surface 6/11/2023 Monobore. Drilled June 2022.
MPM-30 MPU 50029237300000 2221180 1' 0 1' N/A 10 surface 6/11/2023 Drilled in Oct 2022.
MPM-43 MPU 50029236710000 2200200 1' 0 1' N/A 10 surface 6/11/2023 Drilled in 2020.
MPM-62 MPU 50029237440000 2230060 1' 0 1' N/A 10 surface 6/11/2023 Completed May 2023.
MPS-45 MPU 50029236930000 2210420 1' 0 1' N/A 10 surface 6/12/2023 Drilled in June 2021.
MPS-47 MPU 50029236960000 2210470 4' 0 4' N/A 20 surface 6/12/2023 Drilled in August 2021.
Notes:
The 4" conductor outlets are any where from 1 to 3' down from the top of the conductor
Surface Casing by Conductor Annulus Cement Top Job and Fill Coat Corrosion Inhibitor (CI) Applications
Cement to surface means cement is up to the 4" outlets below the wellhead. From the 4" outlets up to the top of conductor was filled with Fill Coat #7
Initial top of cement footage measurement was taken from the 4" outlet down to the TOC
RBDMS JSB 100323
MPL-60 MPU 50029236780000 2200480 1'0 1'N/A 10 surface 6/26/2023 Drilled in 2020.
DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23678-00-00Well Name/No. MILNE PT UNIT L-60Completion Status1-OILCompletion Date6/28/2020Permit to Drill2200480OperatorHilcorp Alaska, LLCMD13150TVD3799Current Status1-OIL10/15/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, AGR, ABG, DGR, EWR, ADR MD & TVD, PB1/PB2/PB3NoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF10/5/2020 Electronic File: MPU L-60 Geosteering End of Well Report.pdf34042EDDigital DataDF10/5/2020 Electronic File: MPU L-60 Post-Well Geosteering X-Section Summary (redrill).pdf34042EDDigital DataDF10/5/2020 Electronic File: MPU L-60 Redrill Geosteering Log.emf34042EDDigital DataDF10/5/2020 Electronic File: MPU L-60 Redrill Geosteering Log.pdf34042EDDigital DataDF10/5/2020 Electronic File: MPU L-60 Redrill Geosteering Log.tif34042EDDigital Data0 0 2200480 MILNE PT UNIT L-60 LOG HEADERS34042LogLog Header ScansDF10/6/20206820 13112 Electronic Data Set, Filename: MPU L-60 ADR Quadrants All Curves.las34043EDDigital DataDF10/6/2020 Electronic File: MPU L-60 LWD Final TVD.cgm34043EDDigital DataDF10/6/2020 Electronic File: MPU L-60_Definitive Survey Report.pdf34043EDDigital DataDF10/6/2020 Electronic File: MPU L-60_DSR.txt34043EDDigital DataDF10/6/2020 Electronic File: MPU L-60_GIS.txt34043EDDigital DataDF10/6/2020 Electronic File: MPU L-60 LWD Final MD.emf34043EDDigital DataDF10/6/2020 Electronic File: MPU L-60 LWD Final TVD.emf34043EDDigital DataDF10/6/2020 Electronic File: MPU_L-60_Geosteering.dlis34043EDDigital DataThursday, October 15, 2020AOGCCPage 1 of 5PB1PB2PB3
DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23678-00-00Well Name/No. MILNE PT UNIT L-60Completion Status1-OILCompletion Date6/28/2020Permit to Drill2200480OperatorHilcorp Alaska, LLCMD13150TVD3799Current Status1-OIL10/15/2020UICNoDF10/6/2020 Electronic File: MPU_L-60_Geosteering.ver34043EDDigital DataDF10/6/2020 Electronic File: MPU L-60 LWD Final MD.pdf34043EDDigital DataDF10/6/2020 Electronic File: MPU L-60 LWD FInal TVD.pdf34043EDDigital DataDF10/6/2020 Electronic File: MPU L-60 LWD Final MD.tif34043EDDigital DataDF10/6/2020 Electronic File: MPU L-60 LWD Final TVD.tif34043EDDigital DataDF122 13150 Electronic Data Set, Filename: MPU L-60 LWD Final.las34043EDDigital Data0 0 2200480 MILNE PT UNIT L-60 PB1 LOG HEADERS34045LogLog Header ScansDF10/5/2020122 8372 Electronic Data Set, Filename: MPU L-60PB1 LWD Final.las34045EDDigital DataDF10/5/20206820 8334 Electronic Data Set, Filename: MPU L-60PB1 ADR Quadrants All Curves.las34045EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB1 LWD Final MD.cgm34045EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB1 LWD Final TVD.cgm34045EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB1_Definitive Survey Report.pdf34045EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB1_DSR.txt34045EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB1_GIS.txt34045EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB1 LWD Final MD.emf34045EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB1 LWD Final TVD.emf34045EDDigital DataDF10/5/2020 Electronic File: MPU_L-60PB1_Geosteering.dlis34045EDDigital DataDF10/5/2020 Electronic File: MPU_L-60PB1_Geosteering.ver34045EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB1 LWD Final MD.pdf34045EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB1 LWD Final TVD.pdf34045EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB1 LWD Final MD.tif34045EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB1 LWD Final TVD.tif34045EDDigital DataDF10/5/2020122 11798 Electronic Data Set, Filename: MPU L-60PB2 LWD Final.las34047EDDigital DataThursday, October 15, 2020AOGCCPage 2 of 5MPU L-60 LWDFinal.lasMPU L-60PB1LWD Final.las: MPU L-60PB2LWD Final.las
DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23678-00-00Well Name/No. MILNE PT UNIT L-60Completion Status1-OILCompletion Date6/28/2020Permit to Drill2200480OperatorHilcorp Alaska, LLCMD13150TVD3799Current Status1-OIL10/15/2020UICNoDF10/5/20206820 11761 Electronic Data Set, Filename: MPU L-60PB2 ADR Quadrants All Curves.las34047EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB2 LWD Final MD.cgm34047EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB2 LWD Final TVD.cgm34047EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB2_Definitive Survey Report.pdf34047EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB2_DSR.txt34047EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB2_GIS.txt34047EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB2 LWD Final MD.emf34047EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB2 LWD Final TVD.emf34047EDDigital DataDF10/5/2020 Electronic File: MPU_L-60PB2_Geosteering.dlis34047EDDigital DataDF10/5/2020 Electronic File: MPU_L-60PB2_Geosteering.ver34047EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB2 LWD Final MD.pdf34047EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB2 LWD Final TVD.pdf34047EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB2 LWD Final MD.tif34047EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB2 LWD Final TVD.tif34047EDDigital Data0 0 2200480 MILNE PT UNIT L-60 PB2 LOG HEADERS34047LogLog Header Scans0 0 2200480 MILNE PT UNIT L-60 PB3 LOG HEADERS34048LogLog Header ScansDF10/5/2020122 13130 Electronic Data Set, Filename: MPU L-60PB3 LWD Final.las34048EDDigital DataDF10/5/20206820 13092 Electronic Data Set, Filename: MPU L-60PB3 ADR Quadrants All Curves.las34048EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB3 LWD Final MD.cgm34048EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB3 LWD Final TVD.cgm34048EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB3_Definitive Survey Report.pdf34048EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB3_DSR.txt34048EDDigital DataThursday, October 15, 2020AOGCCPage 3 of 5MPU L-60PB3 LWD Final.las
DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23678-00-00Well Name/No. MILNE PT UNIT L-60Completion Status1-OILCompletion Date6/28/2020Permit to Drill2200480OperatorHilcorp Alaska, LLCMD13150TVD3799Current Status1-OIL10/15/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:6/28/2020Release Date:6/2/2020DF10/5/2020 Electronic File: MPU L-60PB3_GIS.txt34048EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB3 LWD Final MD.emf34048EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB3 LWD Final TVD.emf34048EDDigital DataDF10/5/2020 Electronic File: MPU_L-60PB3_Geosteering.dlis34048EDDigital DataDF10/5/2020 Electronic File: MPU_L-60PB3_Geosteering.ver34048EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB3 LWD Final MD.pdf34048EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB3 LWD Final TVD.pdf34048EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB3 LWD Final MD.tif34048EDDigital DataDF10/5/2020 Electronic File: MPU L-60PB3 LWD Final TVD.tif34048EDDigital DataThursday, October 15, 2020AOGCCPage 4 of 5
DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23678-00-00Well Name/No. MILNE PT UNIT L-60Completion Status1-OILCompletion Date6/28/2020Permit to Drill2200480OperatorHilcorp Alaska, LLCMD13150TVD3799Current Status1-OIL10/15/2020UICNoComments:Compliance Reviewed By:Date:Thursday, October 15, 2020AOGCCPage 5 of 510/15/2020M. Guhl
David Douglas Hilcorp Alaska, LLC
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 or fax to 907 777-8510.
Received By: Date:
DATE 10/05/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU L-60, MPU L-60PB1, MPU L-60PB2, MPU L-60PB3
(PTD 220-048)
FINAL LWD LOGS (23JJUN2020):
EWR-M5, AGR, ADR, DGR, ABG, WELLBORE PROFILE (MD/TVD)
AND DEFINITIVE DIRECTIONAL SURVEY
Final CD Main Folders:
Subfolders:
Received by the AOGCC 10/05/2020
PTD: 2200480
E-Set:34043
Abby Bell 10/06/2020
David Douglas Hilcorp Alaska, LLC
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 or fax to 907 777-8510.
Received By: Date:
DATE 10/05/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU L-60 (PTD 220-048)
FINAL GEOSTEERING LOGS, EOW REPORTS (15JUN2020):
Final GEOSTEERING CD:
Received by the AOGCC 10/05/2020
PTD: 2200480
E-Set:34042
Abby Bell 10/06/2020
David Douglas Hilcorp Alaska, LLC
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 or fax to 907 777-8510.
Received By: Date:
DATE 10/05/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU L-60, MPU L-60PB1, MPU L-60PB2, MPU L-60PB3
(PTD 220-048)
FINAL LWD LOGS (23JJUN2020):
EWR-M5, AGR, ADR, DGR, ABG, WELLBORE PROFILE (MD/TVD)
AND DEFINITIVE DIRECTIONAL SURVEY
Final CD Main Folders:
Subfolders:
Abby Bell 10/06/2020
Received by the AOGCC 10/05/2020
PTD: 2200480
E-Set:34045
David Douglas Hilcorp Alaska, LLC
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 or fax to 907 777-8510.
Received By: Date:
DATE 10/05/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU L-60, MPU L-60PB1, MPU L-60PB2, MPU L-60PB3
(PTD 220-048)
FINAL LWD LOGS (23JJUN2020):
EWR-M5, AGR, ADR, DGR, ABG, WELLBORE PROFILE (MD/TVD)
AND DEFINITIVE DIRECTIONAL SURVEY
Final CD Main Folders:
Subfolders:
Received by the AOGCC 10/05/2020
PTD: 2200480
E-Set:34047
Abby Bell 10/06/2020
David Douglas Hilcorp Alaska, LLC
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 or fax to 907 777-8510.
Received By: Date:
DATE 10/05/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU L-60, MPU L-60PB1, MPU L-60PB2, MPU L-60PB3
(PTD 220-048)
FINAL LWD LOGS (23JJUN2020):
EWR-M5, AGR, ADR, DGR, ABG, WELLBORE PROFILE (MD/TVD)
AND DEFINITIVE DIRECTIONAL SURVEY
Final CD Main Folders:
Subfolders:
Received by the AOGCC 10/05/2020
PTD: 2200480
E-Set:34048
Abby Bell 10/06/2020
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test
2. Operator Name:6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address:7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section):8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 16.6' BF:
Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone-4
TPI:x- y- Zone-4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth:x- y- Zone-4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" X-56 114'
L-80 1725'
L-80 3968'
7-5/8"L-80 3970'
4-1/2"L-80 3799'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production:Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
9-5/8"12-1/4"
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Uncemented TiebackTieback
TUBING RECORD
Uncemented Screen Liner
Liner Top Packer
6409'3-1/2" 9.3# L-80
SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
6645'13150'
Stg 2 L - 664 sx / T - 270 sx
3970'
Driven
13.5#
Surface 2063'Stg 1 L - 565 sx / T - 400 sx
8-1/2"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
6/28/2020
3185' FSL, 4924' FEL, Sec. 08, T13N, R10E, UM, AK
2669' FNL, 1015' FEL, Sec. 19, T13N, R10E, UM, AK
220-048
Milne Point Field, Schrader Bluff Oil Pool
50.77'
13148' / 3799'
HOLE SIZE AMOUNT
PULLED
16.6'
50-029-23678-00-00
MPU L-60
544957 6031375
1677' FNL, 5044' FEL, Sec. 17, T13N, R10E, UM, AK
CEMENTING RECORD
6026513
SETTING DEPTH TVD
6020234
BOTTOM TOP
Surface
Surface
CASING WT. PER
FT.GRADE
29.7#
544884
543694
TOP
SETTING DEPTH MD
Surface
Surface
Per 20 AAC 25.283 (i)(2) attach electronic information
40#
6654'
1725'
Surface
DEPTH SET (MD)
6645' / 3970'
PACKER SET (MD/TVD)
129.5#
47#
114'
2063'6828'
Gas-Oil Ratio:Choke Size:Water-Bbl:
PRODUCTION TEST
TBD
Date of Test:
Flow Tubing
Oil-Bbl:
suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,
caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation
record. Acronyms may be used. Attach a separate page if necessary
ESP
4-1/2" Screen Liner 6/26/20
***Please see attached Schematic for detail***
ROP, AGR, ABG, DGR, EWR, ADR MD & TVD
PB1: ROP, AGR, ABG, DGR, EWR, ADR MD & TVD
PB2: ROP, AGR, ABG, DGR, EWR, ADR MD & TVD
PB3: ROP, AGR, ABG, DGR, EWR, ADR MD & TVD
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl:Water-Bbl:
6/23/2020
6/3/2020
ADL 025509, 025515
88-002
2366' / 1893'
N/AN/A
None
13150' / 3799'
G
s d 1
0 p
d P
l
L
(att
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By Samantha Carlisle at 9:27 am, Jul 17, 2020
RBDMS HEW 7/21/2020
Completion Date
6/28/2020
HEW
DSR-7/21/2020DLB 07/21/2020
SFD 7/31/2020
G
MGR16OCT2020
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
18'18'
2384'1911'
Top of Productive Interval 6751'3968'
1580'1434'
2767'2129'
5007'3464'
6219'3946'
6751'3968'
SB NB 6751' 3968'
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Joe Lastufka
Contact Email:joseph.lastufka@hilcorp.com
Authorized Contact Phone: (907)227-8496
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Authorized Name: Monty Myers
Authorized Title: Drilling Manager
Permafrost - Base
29. GEOLOGIC MARKERS (List all formations and markers encountered):FORMATION TESTS
Permafrost - Top
SB NB
SV1
Ugnu LA3
SV5
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
NAME
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Formation at total depth:
SB NA
Plugback Summary, Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report
Signature w/Date:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
INSTRUCTIONS
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
N
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
7.16.202Digitally 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: 2020.07.16 15:36:01 -08'00'
Monty M
Myers
PB1
TD 8372' MD / 3976' TVD
KOP 7510' MD / 3949' TVD
Date 6/12/2020
PB2
TD 11798' MD / 3780' TVD
KOP 11150' MD / 3844' TVD
Date 6/13/2020
PB3
TD 13130' MD / 3811' TVD
KOP 7070' MD / 3962' TVD
Date 6/15/2020
MPU L-60 OH Sidetrack Summary
PTD: 220-048 / API: 50-029-23678-70-00
PTD: 220-048 / API: 50-029-23678-71-00
PTD: 220-048 / API: 50-029-23678-72-00
_____________________________________________________________________________________
Edited By: JNL 7-16-2020
Proposed Schematic
Milne Point Unit
Well: MPU L-60
Last Completed: 6/28/2020
PTD: 220-048
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor 129.5# / X56 / Weld N/A Surface 114’ N/A
9-5/8" Surface 47 / L-80 / TXP 8.679 Surface 2,063’ 0.0758
9-5/8” Surface 40 / L-80 / TXP 8.525 2,063’ 6,828’ 0.0758
7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,654’ 0.0459
4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,645’ 13,150’ .0149
TUBING DETAIL
3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 Surface 6,409’ 0.0087
OPEN HOLE / CEMENT DETAIL
Conductor ±270 ft3
12-1/4" Stg 1 – Lead – 565 sx / Tail – 400 sx
Stg 2 – Lead – 664 sx / Tail – 270 sx
8-1/2” Cementless Screens Liner in 8-1/2” hole
WELL INCLINATION DETAIL
KOP @ 353’
Max Hole Angle = 94° @ 7,064’ MD
TREE & WELLHEAD
Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing
Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs
GENERAL WELL INFO
API: 50-029-23678-00-00
Completion Date: 6/28/2020
4-1/2” SOLID LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
36 6671’ 3970’ 8146’ 3934’
3 8231’ 3933’ 8355’ 3932’
3 8439’ 3930’ 8561’ 3926’
3 11357’ 3824’ 11479’ 3824’
JEWELRY DETAIL
No. Top MD Item ID
1 198’ GLM: 3-1/2” w/ 1-1/4” Dummy Valve w/ BK Latch 2.909”
2 5,736’ GLM: 3-1/2” w/ 1-1/4” Dummy Valve w/ BK Latch 2.907”
3 5,795’ 2.813” XN Nipple, 2.75” no go 2.760”
4 6,315’ Discharge Head: B/O PMP 513
5 6,317’ Upper Tandem Pump: 93 Flex47 M FER
6 6,339’ Lower Tandem Pump: 93 Flex47 M FER
7 6,361’ Gas Avoider: Gas Master Extreme 538GS
8 6,366’ Upper Tandem Seal: GSB3DB H6 SB/AB PFSA
9 6,372’ Lower Tandem Seal: GSB3DB H6 SB/AB PFSA
10 6,379’ Motor: 562 XP – 400hp / 2785V / 88A
11 6,405’ Sensor, Zenith
12 6,407’ Centralizer: Bottom @ 6,409’
13 6,645’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8” (TVD 3970’) 6.190”
14 6,656’ 7-5/8” Tieback Assy. 6.190”
15 6,667’ 7” H563 x 4.5” Hyd 625 XO 3.850”
16 13,150’ Shoe 3.950”
4-1/2” Screens LINER DETAIL
Jts Top
(MD) Top (TVD) Btm (MD) Btm (TVD)
2 8146’ 3934’ 8231’ 3933’
2 8355’ 3932’ 8439’ 3930’
67 8561’ 3926’ 11357’ 3824’
39 11479’ 3824’ 13108’ 3799’
Activity Date Ops Summary
6/1/2020 R/D on M-45. Rig released at 17:30. See M-45 report for details;PJSM, Skid rig floor into moving position, move Rig off M-45 and around well header to
entrance of pad.
P/U rig matts and clear area behind Well head. Send annular preventer to L-Pad.;L/D matts on access road. Install Rig moving booster system. Trouble shoot
booster remote controls.
Move Rig from Moose pad, down access road toward L-Pad.
SimOps: Spot Rig matts around L-60 and position components behind Well head in prep for rig moving in.
6/2/2020 Continue to move Rig from Moose pad, turn onto L-Pad access road moving on rig mats, arrive at L-Pad 12:00
Loaders removing rig mats off L-Pad and M-Pad access roads;Stage rig just past L-Pad entrance, PJSM, remove front and rear boosters, remove front star
war bracing. Finish removing mats from access roads,
Perform pre-pad inspection with DSO and review diverter line placement.;Walk Rig onto matts and into position to move over L-60. Set MPD choke house
into place. Move Rig over Well and spot.;Level and shim Rig.
Skid floor into drilling position.;Hook up lines to Rig floor. Spot 3rd party shacks, Install stair landings.
Start R/U diverter system and Riser. Change out diverter knife valve. Work on Rig acceptance checklist.
Start loading shed w/ 5" DP.
6/3/2020 Spot rock washer, water pump house, MWD and MI shacks. R/U knife valve and diverter line. Inspect saver sub and grabber dies, service top drive, perform
derrick inspection, work on acceptance checklist. Function test rig ESDs. Rig on high line power at 10:05;Level rig with stand of drill pipe. Load HWDP into
shed along with BHA, tighten and function drag chain, install 90' mouse hole, flush MP pop off lines.;Load pits w/ 580 bbls 8.7+ ppg spud mud. Continue to
install diverter line. Spot cement silos. Put company mans camp on hi-line power. Build up and mat DS front of rig f/ super access to ODS Electrician tested
Rig gas alarms. Load 5'' DP into shed. Rig Accepted @ 18:00.;Rack back stand of drill pipe. M/U one three stand of HWDP w/ jars and rack in derrick.
Mobilize BHA components to the rig floor.;Function test annular diverter on 5" drill pipe - 18 sec. knife valve opening, 26 sec. annular closing.
Test accumulator - 3000 PSI system pressure, 1800 PSI after closure, 200 PSI recharge in 38 sec, full recharge in 160 sec, 6 nitrogen bottle avg of 2100
PSI.;382' total diverter line, one 22° target Tee, 376' from outside Rig. 76' from closest ignition source (end flowline lights). AOGCC representative Lou
Laubenstein waived witness of the diverter test at 07:09 on 03 June 2020.;Hold pre spud meeting, Review rig evacuation plan with all parties. M/U 12 1/4''
Kymera bit and mud motor. M/U stand HWDP and Kelly up, RIH and tag up @ 64’. Flood stack and lines, test lines to 3500 psi from TopDrive IBOP to mud
pumps, good, completing last item on acceptance checklist.;Clean out conductor t/ 114’, spud Well and drill to 124’ with water, displace to spud mud on the fly.
Drill t/ 130’ 420 GPM, 320 psi. 40 RPM, 0k Tq PU/SO/ROT = 50k. When flowline packed off with sand and gravel. Pull bit into conductor at 114'.;Clear
flowline and jet clean. Troubleshoot flow indicator paddle not reading flow. Totco Rep called out. Check connections at paddle and junction box in Pits. Re-
calibrate sensor. Flow indicator fixed. SimOps; Process drillpipe in shed. Clean drip pan under floor.;Drill to 220' pumping 400 gpm, 475 psi, 40 rpm, 3k Tq.
Circulate BU and Pump out of hole one stand, pull next stand on elevators. Pull bit to surface, inspect and clean same. All three cones locked up with
gravel.;PJSM, M/U DM collar and scribe RFO from motor. Continue M/U MWD tools, scribe to UBHO. Adjust UBHO to motor as per DD. Plug in, Initialize and
upload MWD.
6/4/2020 Initialize and upload MWD, RIH w/ 3 NMFCs, XO to 177', M/U std HW and TD, wash/ream to 220'. R/U Gyro while uploading MWD.;Drill 12-1/4" hole f/ 220' t/
457', (456’ TVD) 237' drilled, 52.6'/hr AROP. 425 GPM, 680 PSI, 40 RPM, 1-3K TQ, 1-5K WOB MW 9 ppg in / 9.1 ppg out, vis 300 in /out, 9.67 ECD. 66K PU
/ 66K SO / 66K ROT Kick off @ 272', build 3°/100'.;Gyro survey every connection.;Drill 12-1/4" hole f/ 457' t/ 1080', (1226’ TVD) 623' drilled, 103.8'/hr AROP.
500 GPM, 1220 PSI, 60 RPM, 4-8k Tq, 3k WOB MW 9.1 ppg in / 9.1 ppg out, vis 177 in / 160 out, 10.09 ECD. Max Gas - 2u 88K PU / 85K SO / 87K ROT
Build 3°/100' to 550' then 4°/100.;Gyro survey every connection to 634' until clean MWD survey, keep on standby to 928' then release Gyro.;Drill 12-1/4"
hole f/ 1080' t/ 1648', (1480’ TVD) 568' drilled, 94.6'/hr AROP. 500 GPM, 1270 PSI, 60 RPM, 4-8k Tq, 8k WOB MW 9.1+ ppg in / 9.2+ ppg out, vis 212 in /
260 out, 10.33 ECD. Max Gas - 5u 91K PU / 84K SO / 89K ROT Target 4°/100' Build.;Drill 12-1/4" hole f/ 1648' t/ 2475', (1963’ TVD) 827' drilled, 137.83'/hr
AROP. 500 GPM, 1350 PSI, 80 RPM, 6k Tq, 10-15k WOB MW 9.3 ppg in / 9.5 ppg out, vis 140 in / 180 out, 10.11 ECD. Max Gas - 83u 107K PU / 81K SO /
94K ROT Target 4°/100' Build t/ 1810’ where 53.70° tangent started.;Last survey @ 2411.67' MD / 1926.07' TVD, 55.80° inc, 180.25° azm, 4.40' from plan,
3.03’ High, 3.19' right. Base Permafrost @ 2,384’ md / 1,911’ tvd;Daily losses = 0 bbls, Cumulative losses = 0 bbls
H2O from B-Pad Creek: 775 bbls Daily/ 1,390 bbls Total
H2O from 6-Mile: 575 bbls Daily/ 575 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 0 bbls Total
Cuttings/mud/cement to MPU G&I: 1,383 bbls Daily / 1,383 bbls Total
6/5/2020 Drill 12-1/4" hole f/ 2475' t/ 3214', (2394’ TVD) 739' drilled, 123.16'/hr AROP. 548 GPM, 1730 PSI, 80 RPM, 7-8k Tq, 10-14k WOB MW 9.1 ppg in / 9.2 ppg
out, vis 109 in / 98 out, 10.16 ECD. Max Gas 102u 123K PU / 88K SO / 103K ROT Hold 53.70° tangent.;Pump 30 bbl hi vis sweep at 2547', back 500 stokes
late with 10% increase, pump another sweep at 3100', back 400 stks late, 10% increase.;Drill 12-1/4" hole f/ 3214' t/ 4080', (2910’ TVD) 866' drilled, 144.3'/hr
AROP. 550 GPM, 1680 PSI, 80 RPM, 10k Tq, 3-5k WOB MW 9.2 ppg in / 9.3 ppg out, vis 124 in / 127 out, 10.0 ECD. Max Gas 75u 144K PU / 95K SO /
114K ROT Hold 53.70° tangent.;Ugnu MP_UG4 @ 3228' MD / 2402' TVD. Pump 30 bbl hi vis sweep at 3595', back 1200 stks late with 50% increase.;Drill 12-
1/4" hole f/ 4080' t/ 4641', (3247’ TVD) 561' drilled, 93.5'/hr AROP. 550 GPM, 1890 PSI, 80 RPM, 13k Tq, 10-24k WOB. MW 9.1 ppg in / 9.2 ppg out, vis 158
in / 129 out, 10.29 ECD. Max Gas 43u. 153K PU / 96K SO / 112K ROT. Hold 53.70° tangent.;Pump 30 bbl hi vis sweep at 4163', back 1700 stks late with no
observed increase.;Drill 12-1/4" hole f/ 4641' t/ 5259', (3611’ TVD) 618' drilled, 103'/hr AROP. 550 GPM, 1820 PSI, 80 RPM, 14k Tq, 10-15k WOB MW 9.3
ppg in / 9.3+ ppg out, vis 101 in / 162 out, 10.16 ECD. Max Gas 174u 175K PU / 100K SO / 126K ROT Hold 53.70° tangent.;Ugnu LA3 5007' MD / 3464' TVD.
Last survey @ 5173.58' MD / 3561.52' TVD, 54.06° inc, 179.82° azm, 1.81' from plan, 1.75’ High, 0.49' left.;Daily losses = 0 bbls, Cumulative losses = 0 bbls
H²O from B-Pad Creek: 980 bbls Daily/ 2,370 bbls Total
H²O from 6-Mile: 0 bbls Daily/ 575 bbls Total;H²O from A-Pad: 300 bbls Daily/ 300 bbls Total
H²O from Dewatering: 290 bbls Daily/ 290 bbls Total
Cuttings/mud/cement to MPU G&I: 1,930 bbls Daily / 3,313 bbls Total
50-029-23678-00-00API #:
Well Name:
Field:
County/State:
MP L-60
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
Job Name:2011920D MPU L-60 Drilling
6/6/2020 Drill 12-1/4" hole f/ 5259' t/ 5839', (3883’ TVD) 580' drilled, 96.6'/hr AROP. 545 GPM, 1980 PSI, 80 RPM, 17k Tq, 18k WOB MW 9.2 ppg in / 9.3 ppg out, vis
90 in / 240 out, 10.17 ECD. Max Gas 153u 185K PU / 91K SO / 126K ROT.;Hold 53.70° tangent to 5300', start 4 deg turn and build. Pump 30 bbl hi vis sweep
@ 5400', 1900 stks late w/30% increase.;Drill 12-1/4" hole f/ 5839' t/ 6325', (3951' TVD) 486' drilled, 81'/hr AROP. 550 GPM, 2180 PSI, 80 RPM, 18k Tq, 20-
25k WOB MW 9.2 ppg in / 9.3 ppg out, vis 137 in / 300+ out, 10.26 ECD. Max Gas 105u 178K PU / 84K SO / 121K ROT.;Continue 4° turn and build, then
maintain 85.8°- 86.6° tangent section f/ 6287' Pump 30 bbl hi vis sweep @ 6072', 1800 stks late w/25% increase Drilled Fault A @ 6115' MD, 15' throw DTN
Top of SB_NA @ 6224' MD / 3946' TVD.;Drill 12-1/4" hole f/ 6325' t/ 6641', (3971' TVD) 316' drilled, 52.6'/hr AROP. 460 GPM, 1590 PSI, 80 RPM, 17k Tq, 15-
25k WOB MW 9.2 ppg in / 9.2+ ppg out, vis 87 in / 142 out, 10.26 ECD. Max Gas 149u 174K PU / 84K SO / 116K ROT.;Continue pump tangent section t/
6579'. Start build, targeting 92°. Max DL of 0.86° through tangent Build to 92.5° and appear to deflect off the NB cap. Drop angle to 89° and TD section @
6840'.;Drill 12-1/4" hole f/ 6641’ t/ 6840', (3968' TVD) 199' drilled, 56.85'/hr AROP. 540 GPM, 1860 PSI, 80 RPM, 15k Tq, 15-25k WOB MW 9.2+ ppg in / 9.3
ppg out, vis 67 in / 240 out, 9.99 ECD. Max Gas 345u 175K PU / 80K SO / 120K ROT.;Build to 92.5° @ 6695 and appear to deflect off the NB cap. Drop
angle to 89° and TD section @ 6840' MD / 3968’, 1-2’ TVD into the SB_NB sand. Top of NB @ 6751’ MD / 3968’ TVD.;Pump Hi-Vis sweep w/ nut plug
marker & circulate hole clean while BROOH f/ 6840’ t/ 6660'. 550 GPM, 1770 PSI, 80 RPM, 14K TQ. Sweep return was not observed at surface. Final YP =
22. Max gas 290u.;Last survey @ 6800.39' MD / 6967.58' TVD, 89.70° inc, 189.74° azm, 10.14’ from plan, 7.00' high, 7.34' right. Projection to TD 6840' MD /
3968' TVD, 7.75' from plan, 5.16' high, 5.78' right.;Trip in hole f/ 6660' t/ 6840’. Perform 5 min. flow check - static. PJSM for BROOH.;Daily (midnight) losses =
0 bbls, Cumulative losses = 0
H2O from B-Pad Creek: 330 bbls Daily/ 2,700 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 1,285 bbls Daily/ 1,875 bbls Total
Cuttings/mud/cement to MPU G&I: 2,082 bbls Daily / 5,395 bbls Total
6/7/2020 BROOH f/ 6840' t/ 4165' at 5/10 min. stand, 550 GPM, 1730 PSI, 80 RPM, 13K TQ, slow down as needed to cleanup slides and slight packing off issues.
150K PU / 90K SO / 115K ROT, max gas 123u.;BROOH f/ 4165' t/ 740' at 5/10 min. stand, 550 GPM, 1250 PSI, 80 RPM, 5K TQ, slow down as needed to
cleanup slides and slight packing off issues. Pull slow to let well clean up before pulling through permafrost @ 2384’. CBU while pulling last std slow 85K PU /
80K SO / 83K ROT, max gas 104u.;Monitor Well 10 min – Static - Hold PJSM on L/D BHA POOH on elevators f/ 740. Lay down excess HWDP, rack back 1
std w/ jars & L/D drill collars to 85'.;Read MWD tools - retrieved all data. L/D BHA #1 f/ 85'. Bit graded: 1-2-CT-A-F-2-ER-TD. 37 bbls lost on trip out of
hole.;Clear rig floor and mobilize casing equipment to the rig floor. R/U 9-5/8" Volant CRT, spiders, bail extensions and elevators. PJSM for running casing.
3.5 BPH static losses.;M/U 9-5/8" casing shoe track: round nose float shoe, jt#1, Baker-Loc jt#2, float collar, jt#3 w/ bypass baffle installed to 121'. Pump thru
shoe track to check floats - good. M/U baffle adapter & jt#4 to 163'. Torqued all connections to 21,000 ft/lbs w/ Volant tool & Baker-Loc first 4
connections.;Two 9-5/8" x 12-1/4" centralizer & 4 stop rings on shoe joint, 1 free floating centralizer on Baker-Loc joint, 1 centrailizer w/ 2 stop rings on the
float collar and baffle adapter joints.;Run 9-5/8" 40# L-80 TXP-BTC casing f/ 163' t/ 1160'. Torque to 21,000 ft/lbs with the Volant tool. Install 9-5/8" x 12-1/4"
bowspring centralizers on jts #5-25 then every other joint Fill casing on the fly & top off every 10 joints. 6.6 BPH loss rate.;Daily (midnight) losses = 37 bbls,
Cumulative losses = 37
H2O from B-Pad Creek: 400 bbls Daily/ 3,100 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 580 bbls Daily/ 2,455 bbls Total
Cuttings/mud/cement to MPU G&I: 861 bbls Daily / 6,256 bbls Total
6/8/2020 Run 9-5/8" 40# L-80 TXP-BTC casing f/ 1160' t/ 2650'. Torque to 21,000 ft/lbs with the Volant tool. Install 9-5/8" x 12-1/4" bow spring centralizer on every
other jt f/ jt 27 to 49, then 1 every 3rd jt Fill casing on the fly & top off every 10 joints. 2 BPH loss rate.;CBU at 2650', stage pump to 5 bpm, 150 psi, work
string 20'. 4 bbl losses.;Continue to run 9-5/8" 40# L-80 TXP-BTC casing f/ 2650' t/ 4227' @ jt 106'. Torque to 21,000 ft/lbs with the Volant tool. Install 1-9-5/8"
x 12-1/4" bow spring centralizer every 3rd joint to jt 103 then every jt to 106 Fill casing on the fly & top off every 10 joints. 2-3 BPH loss rate.;Baker lock/M/U
ESC tool w/ pup above and below to 4250', verify 6 pins set @ 2593 psi, Cont to run 9-5/8" 40# L-80 TXP-BTC casing f/ 4250' to 4764' @ jt 119 Install 1
centralize on ea jt to jt 115, then 1 centralizer every 3rd jt. Fill casing on the fly & top off every 10 joints. 2-3 BPH loss rate.;Run 9-5/8" 47# L-80 TXP-BTC
casing f/ 4764' t/ 6813' @ joint 50. TQ to 24,000 ft/lbs with the Volant tool. ensure pipe count, M/U 20' pup, wash to depth @ 6830'. Install 1 centralizer every
3rd jt. Fill casing on the fly & top off every 10 joints. 41 bbl losses running casing. PU 320k, SO 120k.;C/O Volant cup, stage pump f/ 2 bpm, 250 psi, to 6 bpm,
340 psi. Start rotary w/ torque limit set at 20K, 5 RPM when reciprocating. Reciprocate 30', cementers rigging up. Condition mud for cement job. Circulated a
total of 1.5x bottoms up.;Cementers finished rigging up and filled cement water tank w/ 75° PJSM. Blow down top drive & R/U cement lines. Pre-treat mud in
pit #4. Pump 50 bbls of pre-treated mud, 6 BPM, 130 PSI. 5 bbls losses while circulating.;Pump 5 bbls water. Pressure test lines to 1000 PSI low / 4000 PSI
high. Bleed down and line up to well. Mix and pump 60 bbl tuned spacer w/ 4# red dye & 5# Pol-E-Flake in 1st 10 bbls, 3.7 BPM, 200 PSI. Mix & Pump 236
bbl 12 ppg Lead cmt ( 565 sx ), 4.75 BPM, 315 PSI.;Mix & Pump 82 bbl 15.8 ppg tail cmt. ( 400 sx ) 3.5 BPM, 390 PSI. Chase with 20 bbl fresh water. Rig
displace with 282 bbl 9.4 ppg spud mud at 6 BPM, 190 PSI. - Experienced cavitation with Pump #1, swap to Pump #2 with 108 stks pumped. HES pump 80
bbl 9.4 ppg tuned spacer, 4.6 BPM, 250 PSI.;Rig displace at 6 BPM, 540 PSI. 126 bbl 1248 stks, 4040 stks total, equaling calc plus ½ the shoe track volume.
Did not bump plugs. Consult engineers and pump 2 more barrels with no success of bump.;Discuss possibility that no fluid was pumped when first 10.8 bbls
displaced, experienced pump cavitation. Decision made to pump until plugs bump. Pump 8.7 more bbls – and bump plugs successfully with 15.35 bbls (152
stks) over calculated pumped. 750 psi final lift. Hold 500 over at 1250 for 5 min;Bleed down and check Floats. Good. Pressure up and open ES cmt tool at
2500 psi. Cement in place at 01:27. 20 bbls loss during cement job. *** Notified AOGCC of upcoming BOP test at 18:50 on 08 June 2020 ***;Pol-E-Flake seen
at shakers at opening. Circulate hole clean through ES cementer at 2593'. Displace out 60 bbl spacer, trace cmt and 70 bbl chase spacer. Thick interface
and moderate clabbored mud on both sides of spacers. Send all to rockwasher, 268 bbls total dumped.;Take mud returns back to pits. Circulate 4x bottoms
up. Clean returns. Shut down and flush all surface equipment in black water. Cycle annular three times in black water and flush same.;Circ at 6 bpm, 420 psi
while waiting on cmt and preparing for second stage. Work pipe f/ 125K t/ 225K every 30 min.;Daily (midnight) loss = 46 bbl, Cumulative loss = 83 bbl
H²O from B-Pad Creek: 270 bbl Daily/3,370 bbl Total
H²O from 6-Mile: 0 bbl / 575 bbl Total
H²O from A-Pad: 0 bbl / 2,455 bbl Total
H²O from G&I Source H²O: 370 bbl / 370 bbl Total
Cutting/mud/cmt to MPU G&I: 548 bbl / 6,804 bbl Total
6/9/2020 Circ thru ESC at 2593' 6 bpm, 420 psi while waiting on cmt and preparing for second stage. Hold PJSM @ 9AM with all parties involved.;Break out volant tool,
clean dies and re-dope cup. Perform 2nd stage cement job through ES cementer at 2593'. Pump 5 bbls of water. Mix & pump 60 bbls of 10.0 ppg Tuned
spacer w/ 4# red dye & 5# Pol-E-Flake in 1st 10 bbls, 4 BPM, 280 PSI.;Mix & pump 348 bbls 10.7 ppg Arctic CEM lead cement (664 sks), 6 BPM, 940 PSI
ICP, 4.5 BPM 650 PSI FCP. Observed spacer at 230 bbls and good cement back @ 342 bbls of lead pumped. Mix & pump 56 bbls of 15.8 ppg tail cement
(270 sks), 3.7 BPM, 620 PSI. Drop closing plug. Pump 20 bbls of water.;Displace w/ #2 rig pump with 170.48 bbls 9.4 ppg spud mud. 6 BPM, 680 PSI ICP,
1020 PSI FCP. 340 PSI final lift. Slow to 3 BPM, 800 PSI for last 10 bbls pumped. Plug bumped at 1688 stks . 246 bbls of cement to surface. CIP at
12:55.;Pressure up & shifting ESC closed at 1680 PSI. Pressure held good, bleed off to verify cementer closed. No flow back - good. 3 bbl losses during
cement job.;Drain stack to the cellar. L/D Volant CRT. Disconnect knife valve accumulator lines. Function annular and flush w/ black water. Rig vac fluid out of
casing to cellar level. Disconnect & begin N/D diverter line.;Back out speed head LDS on diverter adapter, hoist stack. Install 9-5/8" casing slips and set with
130K on slips. Cut 9-5/8" casing (47# Jt 50 = 41.46' - 17.39' = 24.07' left in hole). Set stack down. N/D annular & diverter tee, remove from cellar. Sim-ops:
clean pits.;N/U FMC slip lock head and test Cahn seal to 600 PSI for 5 min & 3800 PSI for 10 min - good tests. N/U casing and tubing spools. Sim-ops: clear
rig floor of casing equipment and service break Volant CRT.;N/U BOP stack with 11"x13-5/8" adapter spool. Install kill line, MPD hard line and trip
nipple.;Install lower test plug w/ 3-1/2" test joint. Flood stack, trip nipple leaking. Drain stack, L/D test joint, remove clamp, clean trip nipple connection and re-
clamp. Fill stack w/ no leaks. Perform BOP shell test, good.;Test BOP equipment to 250 PSI low / 3000 PSI high. Tests held for 5 min each & charted.
AOGCC inspector Adam Earl waived witness at 13:49 on 9 June 2020. All tests performed with fresh water against a test plug. 1. Annular on 3.5" test joint,
choke valves 1, 12, 13, 14, kill Demco & 3.5" FOSV;2. Lower 3.5"x6" VBR on 3.5" test joint & 3.5" dart valve 3. Upper 4.5"x7" VBR on 5" test joint, choke
valves 9, 11, HCR kill & 5" FOSV #1 4. Choke valves 5, 8, 10 & manual kill 5. Choke valves 4, 6, 7 & 5" dart valve 6. Choke valve 2 & upper IBOP Test
continues into next report period.;Daily losses = 8 bbls, Cumulative losses = 54 bbls.
H2O from B-Pad Creek: 290 bbls Daily/ 3,660 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 0 bbls Daily/ 2,455 bbls Total
H2O from G&I Source Water: 300 bbls Daily/ 670 bbls Total;Cuttings/mud/cement to MPU G&I: 1,325 bbls Daily / 8,129 bbls Total
6/10/2020 Continue testing BOPE, #7- HCR choke & lower IBOP, #8- Manual choke, # 9-Lower 3.5" x 6" VBR on 5" test joint, # 10- Blind rams & choke valve 3, #11 -
Manual choke A, #12- Manual choke B
Test to 250/3000 psi 5 min ea, Charted.;Perform Accumulator test: 3000 PSI sys pressure, 1600 PSI after closure, 200 PSI recovery in 40 sec, full recovery
in 199 sec, 6 N2 bottle avg = 2017 PSI.
Rig electrician tested rig gas alarms
No failures;Blow down choke & kill lines. Pull test plug and L/D test joint. Install 9-1/16" I.D. long wear ring;PJSM, C/O saver sub, inspect and C/O grabber
dies. C/O draworks drum clutch actuator.
Simops: load tools to rig floor;PJSM, M/U cleanout BHA #2, 8 1/2'' mill tooth bit, 1.5 deg mud motor, 3- NMFCs and HW jar stand to 216', TIH on elevators to
2502', M/U TD, wash down 300 gpm, tag ESC plug on depth @ 2585';Drill ESC and plug f/ 2585' to 2591', 430 gpm, 850 psi, 40 rpm, 3-6k torque, 4-7k wob,
ream 3 times, pass thru with pump off and no rotary, no issues,
PU 55K, SO 73K, ROT 79K;M/U next stand tag at 2597', wash and ream down to 2790' 450 gpm, 40 rpm, 4-6k TQ cleaning up junk f/ Drilling ESC, wash to
2884';TIH on elvators from 2884' to 6310' then single in the hole to 6595';Wash down with singles from 6595' to 6675' where cement was tagged with 10K.
Drill cement f/ 6675' t/ 6695' w/ 420 GPM, 910 PSI, 40 RPM, 17K TQ, 3-5K WOB.
Circulate bottoms up while reciprocating f/ 6671' t/ 6600'.
200K PU / 73K SO, 118K ROT.;R/U test equipment. Pressure test 9-5/8" casing to 2500 PSI for 30 minutes on chart - good test.
Blow down choke & kill lines. R/D test equipment.;Slip & cut 66' of drilling line.;Drill 9-5/8" shoe track w/ 445 GPM, 1180 PSI, 40 RPM, 17K TQ.
Drill cement f/ 6695' t/ 6706', baffle adapter on depth f/ 6706' t/ 6709' w/ 5-7K WOB, then cement to float collar at 6747' t/ 6749'.
Drill cement f/ 6749' to shoe at 6826' to 6828' w/ 7-10K WOB, then cleanout rathole to 6840'.;Reamed baffle adapter, float collar and shoe 3x times each then
pass through without difficulty.;Drill 8-1/2" production hole f/ 6840' t/ 6860', 450 GPM, 1350 PSI, 40 RPM, 17K TQ, 11K WOB.;Rack a stand back to 6787'.
Circulate wellbore clean until 9.3 ppg MW in/out, 1.5 bottoms up at 450 GPM, 1230 PSI, 40 RPM, 16K TQ, 152u max gas.;R/D test equpment and purge
choke and kill lines.
Perform FIT to 12.0 ppg EMW with 9.3 ppg MW at 3968' TVD. Pressure up to 558 PSI, 1.4 bbls pumped, 1.0 bbls bled back.
R/D test equipment and blow down lines.;Perform 5 min. flow check - static. POOH on elevators f/ 6787' t/ 6310', good displacement. Pump 25 bbls 10.8 ppg
dry job. Blow down top drive.
POOH on elevators f/ 6310' t/ 2121'.;Daily losses = 0 bbls, Cumulative losses = 54 bbls.
H2O from B-Pad Creek: 150 bbls Daily/ 3,810 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 0 bbls Daily/ 2,455 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 670 bbls Total;Cuttings/mud/cement to MPU G&I: 57 bbls Daily / 8,186 bbls Total
Perform 2nd stage cement job
6/11/2020 POOH on elevators f/ 2121' to 216', rack back jar stand and FC stand, L/D cleanout BHA 2, 8 1/2'' MT bit grade= 1-2-CT-S-E-1-WT-BHA,
Correct displacement;Install split master bushing, Load tools to rig floor,;PJSM. M/U 8-1/2" NOV SK616M-J1D bit, NBS, 7600 Geo-Pilot, MWD w/ ADR, DGR,
PWD & directional to 84'. Test & initialize MWD tools. M/U 8-1/2" roller reamer, float sub, 3 NMFCs & 2nd float sub t/ 185'. RIH w/ HWDP & jar stand to 280'
Note: corrosion ring installed at top NMFCs,;M/U stand DP and TD, shallow test MWD. Pressure test Geo-Span to 3000 psi.
Simops: Pressure test MPD lines to 250/ 1300 psi-good;Troubleshoot low air pressure to draworks drum clutch, mechanic dialed in air pressure adjustment on
drum clutch actuator, tested good.;TIH to 2200', Fill drill pipe, break in Geo-Pilot seals. Continue to TIH to 6623', Fill pipe every 2000';PJSM, Remove trip
nipple, install RCD bearing, no leaks. TIH to 6848', M/U TD, wash to bottom @ 6860';PJSM, Pump 30 bbl hi vis spacer then displace 475 bbls new 8.8 ppg
Flo-Pro mud w/ 1.5% screen kleen and .5% lube added, 300 GPM, 860 PSI, 50 RPM, 17K TQ,
In spud mud PU 225K, SO 75K, ROT 114K / In Flo-Pro mud PU 177K, SO 88K, ROT 120K, 10K TQ.
Obtain new SPRs;Drill 8-1/2" production lateral f/ 6860' t/ 7320' (3956' TVD), 460' drilled, 83.64'/hr AROP.
500 GPM, 1430 PSI, 100 RPM, 14K TQ, 101-12K WOB.
8.9 ppg MW, 45 vis, 10.35 ECD, 251u max gas.
150K PU / 84K SO / 111K ROT.;Drill 8-1/2" production lateral f/ 7320' t/ 7877' (3953' TVD), 557' drilled, 92.83'/hr AROP.
500 GPM, 1520 PSI, 100 RPM, 13K TQ, 5-13K WOB.
9.0 ppg MW, 44 vis, 10.56 ECD. 346u max gas.
145K PU / 80K SO / 106K ROT.;MPD full open chokes while drilling w/ 60 PSI line friction, close chokes on connections with 36 PSI max build.
Last survey @ 7729.13' MD / 3949.92' TVD, 88.95° inc, 190.12 azm, 7.77' from plan, 7.69' low & 1.16' right.
0 bbls daily losses, 0 bbls cumulative lateral losses.;H2O from B-Pad Creek: 420 bbls Daily/ 4,230 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 0 bbls Daily/ 2,455 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 670 bbls Total
Cuttings/mud/cement to MPU G&I: 746 bbls Daily / 8,932 bbls Total
6/12/2020 Drill 8-1/2" lateral f/ 7877' t/ 8372' (3976' TVD), 485' drilled, 90'/hr AROP.
491 GPM, 1720 PSI, 80 RPM, 14K TQ, 15K WOB.
9.0 ppg MW, 44 vis, 10.64 ECD. 461u max gas.
146K PU / 75K SO / 105K ROT.
Pump 30 bbl hi vis sweep @ 7990', back on time w/ 50% increase;Target 88° moving down section to confirm base of the NB-sand, target 86°, investigate
the zone below NB base as per Geo, Decision made to pull back and OH sidetrack @ 7530'
NB base logged at 7712' MD / 3950' TVD, NC sand at 8107' MD / 3954' TVD and NC base at 8207' MD / 3961';BROOH 8372' to 7510' pumping 500 gpm,
1650 psi, 80 rpm, 10k torque;Set 100% deflection at 180L & trough f/ 7510' t/ 7540' 2 times w/ 500 GPM, 1600 PSI, 120 RPM, 10K TQ. ABI drop from 90.22°
to 89.08° at 1.14° separation. Time drill at 50'/hr f/ 7540' to 7610',
BR to 7510', pass thru side track point w/ pumps off/ no rotary, good;Drill 8-1/2" lateral f/ 7610' t/ 7896' (3942' TVD), 286' drilled, 143'/hr AROP.
500 GPM, 1700 PSI, 120 RPM, 10K TQ, 15K WOB.
9.0 ppg MW, 45 vis, 10.74 ECD. 441u max gas.
140K PU / 83K SO / 110K ROT.
Target 94°;Drill 8-1/2" lateral f/ 7896' t/8400' (3932' TVD) 504' drilled, 84'/hr AROP.
500 GPM, 1740 PSI, 120 RPM, 8K TQ, 5-15K WOB.
9.0 ppg MW, 44 vis, 10.64 ECD, 577u max gas.
138K PU / 82K SO / 112K ROT.
Performed 290 bbls dump & dilute at 7989', reduced MBT from 7.5 to 5.5#/bbl.;Drilled out the top of NB sand f/ 7935' t/ 8160'.;Drill 8-1/2" lateral f/ 8400' t/
9133' (3903' TVD) 733' drilled, 122.17'/hr AROP.
500 GPM, 1640 PSI, 100 RPM, 9K TQ, 5-9K WOB.
8.9 ppg MW, 42 vis, 10.48 ECD, 445u max gas.
145K PU / 75K SO / 107K ROT.
Targeting 92.5°.;8561' pump hi vis sweep, back on time w/ 100% increase.
8561' begin holding 100 PSI back pressure on connections.
Perform 290 bbl dump & dilute at 8977'.
Drilled 20 concretions for a total thickness of 87' (4.0% of the lateral).;Last survey @ 8968.39' MD / 3913.46' TVD, 92.54° inc, 191.10° azm, 17.86' from plan,
14.34' low and 10.66' right.;H2O from B-Pad Creek: 850 bbls Daily/ 5,080 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 0 bbls Daily/ 2,455 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 670 bbls Total
Cuttings/mud/cement to MPU G&I: 1,115 bbls Daily / 10,047 bbls Total
6/13/2020 Drill 8-1/2" lateral f/ 9133' t/ 9983' (3871' TVD) 850' drilled, 141.66'/hr AROP.
500 GPM, 1580 PSI, 100 RPM, 11K TQ, 5-15K WOB.
8.8+ ppg MW, 42 vis, 10.76 ECD, 504u max gas.
153K PU / 65K SO / 105K ROT.
Maintain NB-Sand, Targeting 92-92.5°.;Pump 30 bbl hi vis sweep @ 9513', back on time with 200% increase.
MPD holding 140 psi during connections, line pressure drilling at 70 psi;Drill 8-1/2" lateral f/ 9983' t/ 10751' (3857' TVD) 768' drilled, 128'/hr AROP.
500 GPM, 1780 PSI, 120 RPM, 14K TQ, 5-15K WOB.
8.8 ppg MW, 43 vis, 10.83 ECD, 464u max gas.
160K PU / 55K SO / 112K ROT.
Maintain NB-Sand, Targeting 91.5- 92.5°.;Pump 30 bbl hi vis sweep @ 10572', back 400 stks late with no increase.
MPD holding 140 psi during connections, hold 75-100 psi back pressure drilling.;Drill 8-1/2" lateral f/ 10751' t/ 11330' (3838' TVD) 579' drilled, 96.5'/hr AROP.
500 GPM, 1980 PSI, 110 RPM, 14K TQ, 5-15K WOB.
8.9 ppg MW, 44 vis, 11.08 ECD, 418u max gas.
150K PU / 57K SO / 105K ROT.
Attempt to reaquire NB-Sand, Targeting 94°.;MPD holding 140 psi during connections, hold 70 psi back pressure drilling.;Drill 8-1/2" lateral f/ 11330' t/ 11798'
(3779' TVD) 468' drilled, 104'/hr AROP.
500 GPM, 2020 PSI, 100 RPM, 14K TQ, 7-13K WOB.
9.0 ppg MW, 47 vis, 11.42 ECD, 266u max gas.
150K PU / 52K SO / 100K ROT.
Exited top of NB at 11230' MD / 3838' TVD.;Continue drilling to verify wellbore position, increasing inclination to 96.5°.
Entered NA at 11535' MD / 3810' TVD and exited the top of NA at 11770' MD / 3783'.
The decision was made to pull back & sidetrack at 11150'.
Pumped high vis sweep at 11605', back on time w/ 100% increase.;MPD holding 140 psi during connections, hold 70 psi back pressure drilling.
Projection to TD of PB2 - 11798' MD / 3779.60' TVD, 96.75° inc, 192.47° azm, 23.22' from plan, 21.24' high and 9.39' left.
Drilled 27 concretions for a total thickness of 118' (2.4% of the lateral).;Obtain final survey. BROOH f/ 11798' t/ 11133' pumping 500 GPM, 1950 PSI, 80
RPM, 12K TQ.
MPD holding 140 psi during connections, hold 70 psi back pressure BROOH.;H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 930 bbls Daily/ 3,385 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 670 bbls Total
Cuttings/mud/cement to MPU G&I: 1,343 bbls Daily / 11,390 bbls Total;0 bbls daily losses, 0 bbls cumulative lateral losses.
6/14/2020 Set 100% deflection at 180L, trough f/ 11150' to 11180' at 100 fph, with ABI 93.8° , observe .5° drop, P/U to 11145' and trough 2x at 30 fph 500 gpm, 2000
psi, 120 rpm, 13k tq. w/ ABI @ 93.22°
Time drill at 30 fph to 11190', then 50 fph to 11226' w/ 2.7° drop f/ old wellbore @ 2' separation.;Geo later reported crossing unexpected fault #1 before PB-2
@ 11229' MD with 7' throw DTN
11200' perform 290 bbl dump and dilute w/ 290 bbls new FP mud, lowering MBT from 7 to 5.5.;Drill 8-1/2" lateral f/ 11229' t/11321 ' (3842' TVD) 95' drilled
507 GPM, 1830 PSI, 100 RPM, 12K TQ, 10K WOB.
8.9 ppg MW, 43 vis, 10.76 ECD, 270u max gas.
150K PU / 65K SO / 106K ROT.
Target 91°;We re-crossed Fault #1 @11,229’ md (7’ DTS throw)
MPD holding 140 psi during connections, hold 70 psi back pressure drilling;Drill 8-1/2" lateral f/ 11321' t/12000 ' (3816' TVD) 679' drilled, 113.17'/hr AROP.
500 GPM, 2000 PSI, 110 RPM, 15K TQ, 5-15K WOB.
9.0 ppg MW, 44 vis, 11.3 ECD, 438u max gas.
160K PU / 48K SO / 110K ROT.
Re-entered good NB-Sand @ 11394’, currently targeting 91.5°;Pump 30 bbl hi vis sweep @ 11607', back 100 stks late w/ 100% increase.
MPD holding 140 psi during connections, hold 70 psi back pressure drilling;Drill 8-1/2" lateral f/ 12000' t/ 12555' (3812' TVD) 555' drilled, 92.5'/hr AROP.
500 GPM, 1960 PSI, 110 RPM, 16K TQ, 5-15K WOB.
9.0 ppg MW, 44 vis, 11.05 ECD, 450u max gas.
170K PU / no SO / 110K ROT.
Perform 290 bbls new mud dilution @ 12413', dropped MPT from 7 to 5.5#/bbl
Target 90° inclination.;Lost slack of weight at 12369'
MPD holding 140 psi during connections, hold 70 psi back pressure drilling;Drill 8-1/2" lateral f/ 12555' t/ 13035' (3807' TVD) 480' drilled, 80'/hr AROP.
500 GPM, 1980 PSI, 100 RPM, 16K TQ, 2-12K WOB.
8.9 ppg MW, 42 vis, 11.15 ECD, 395u max gas.
175K PU / no SO / 98K ROT.
Pumped high vis sweep at 12558', back 400 stks late w/ 20% increase.
Target 91° inclination.;Concretion drilled slow f/ 12773' t/ 12783' @ 7'/hr.
MPD holding 140 psi during connections, hold 70 psi back pressure drilling
Drilled 45 concretions for a total thickness of 194' (3.2% of the lateral).
0 bbls daily losses, 0 bbls cumulative lateral losses.;Last survey at 12869.99' MD / 3815.20' TVD, 90.62° inc, 191.86° azm, 22.46' from plan, 22.45' low and
0.75' left.;H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 910 bbls Daily/ 4,295 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 670 bbls Total
6/15/2020 Drill 8-1/2" lateral f/ 13035' t/ 13130' (3810' TVD) at TD in the NB-sand
500 GPM, 2010 PSI, 100 RPM, 17K TQ,5K WOB.
8.9 ppg MW, 43 vis, 11.05 ECD, 439u max gas.
175K PU / no SO / 100K ROT.;Final survey 21.03' low & 7.49' right of plan, pump 30 bbl hi vis sweep cleaning up the wellbore, 500 gpm, 1960 psi, 100 rpm,
16k torque, sweep back 600 stks late w/ 20% increase, circulate total 4 BU, rack std back each BU to 12750'
48 concretions were drilled for a total footage of 206’ (3.3%);Ream to bottom (no slack off weight) f/ 12750' t/ 13130'.
300 gpm, 1020 PSI, 40 RPM, 14k Torque.;PJSM for displacing. Pump SAPP pill treatment, 30 bbl hi vis spacer, 3- 20 bbl SAPP pills with 50 bbl seawater
spacers, chase with 300 bbls seawater 6 bpm, 780 psi, 40 rpm, 17-19k torque.;Displace w/ 1060 bbls 8.45 ppg, 3% lubed vissed brine 270 gpm, 900 ICP, 780
FCP, 40 RPM, 15k torque, dump 193 bbls interface to rock washer, divert clean returns to pits
In mud 175K PU / no SO / 100K ROT. 17k tq
In brine 165K PU / 48K SO / 106K ROT. 12k tq.
Max gas during displacement 745u at spacer;MPD initially started with 70 psi on full open choke w/ 8.9 ppg mud, hold 180 psi w/ 8.45 ppg brine, ECD 10.5
ppg. Reciprocate pipe 90'
Perform PST, 1st & 2nd tests failed. Review test procedure w/ completions engineer.
3rd test passed after the shakers w/ 6, 6.5 & 7 sec. times.;Grease wash pipe while monitoring pressure build w/ MPD.
Trap 60 PSI, built to 120 PSI in 4 min. Bled down to 80 PSI, built to 120 PSI in 4 min.
8.5 ppg MW out + 0.6 ppg (120 trapped pressure) = 9.1 ppg EMW.
Obtain new SPRs.
26 bbls lost while circulating.;BROOH f/ 13130' t/ 11323' 450 GPM, PSI, 100 RPM, TQ, 175K PU / 60K SO / 115K ROT.
Attempted 500 GPM, but blinding off screens.
Lay down stands in the mousehole, mark joints for hard band and inspection.
MPD hold 160 PSI on connections w/ 65 PSI with chokes full open.
26 bbls lost while BROOH.;BROOH f/ 11323' t/ 7902', 450 GPM, 1080 PSI, 100 RPM, 13K TQ, 150K PU / 80K SO / 115K ROT.
Lay down stands in the mousehole, mark joints for hard band and inspection.
MPD hold 120-160 PSI on connections w/ 65 PSI with chokes full open.
30 bbls lost while BROOH.;52 bbls daily (midnight) losses, 52 bbls cumulative lateral losses.;H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 680 bbls Daily/ 4,975 bbls Total
H2O from G&I Source Water: 200 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 1,938 bbls Daily / 14,906 bbls Total
6/16/2020 BROOH f/ 7902' t/ 6818', 450 GPM, 1150 PSI, 100 RPM, 16K TQ @ 5 min/stand.
Laying down 5" drill pipe, separate joints for inspection and hard banding.
150K PU / 80K SO / 115K ROT. 10.00 ECD, max gas 421u.;Pump 25 bbl high vis sweep, 500 GPM, 1400 PSI, 60 RPM, 4K TQ, reciprocate 90'.
Sweep 50 stks late w/ 25% increase. Circulate a total of 2.4 bottom up.
8177 stks. Max gas 170u.;Shut off pumps and bleed off pressure. Close MPD choke and monitor pressure build.
Built 55 PSI in 13 min. with 8.8 ppg MW = 9.1 ppg static.
Decision to weight up to 9.3 ppg for 0.2 ppg trip margin.;Weight up lubricated brine from 8.7 to 9.3 ppg over 3 circulations with oilfield salt, 440 GPM, 950 PSI,
60 RPM, 3K TQ. Reciprocate 90'.
PST test passed: 6, 6.5 & 7 seconds on first weight up circulation.;Monitor pressure with MPD. Choke closed for 5 min. - 0 PSI. Open up choke for 5 min. then
close again for 5 min.- 0 PSI. Open choke, monitor well - static.;PJSM, remove MPD RCD and install trip nipple.;POOH laying down 5" drill pipe f/ 6818' t/
6342'. Separate joints for inspection and hard banding. 2.5 bbl losses.;Possible COVID-19 exposure: One employee here at Doyon 14 was notified that he
was exposed to someone whom tested positive for COVID-19. The PUI (Person Under Investigation) has been quarantined to private camp & PCR tested.
The test will ship to Anchorage, but could take 72 hours for results.;Shut down to clean / disinfect entire rig (doghouse, rig floor, derrick house, rock washer,
pipe shed, bathrooms, computers), all vehicles on location, offices in camp, dining room and all common areas in camp. Move other employee out of PUI's
room and clean bedroom.;Until that time, we will presume personnel in this camp have been exposed and take appropriate measures. Continue to maintain
social distancing, disinfect hands and wear gloves. All personnel on location will have their temperature tested twice a day, before and after their shift.
17 bbl losses;POOH laying down 5" drill pipe f/ 6342' t/ 2087'. Separate joints for inspection and hard banding. 17.4 bbl losses.;Drop 2.45" drift. POOH
racking back drill pipe f/ 2087' t/ 280'. Perform flow check - static. L/D 2 HWDP, jars & 3 non-mag flex drill collars t/ 93' Read MWD tools - good data.
Drift landed in jars. Corrosion ring recovered from BHA. L/D BHA from 93'. Bit graded: 2-2-CT-N-X-I-ER-TD. Clear rig floor.;R/U Doyon double stack tongs,
change elevators. Remove split bushings and install master bushings with inserts.
M/U safety joint w/ XO, 5" drill pipe joint, 5" FOSV & XO handling sub. 2.5 bbl losses.;M/U 4-1/2" H625 x BTC XO joint w/ round nose shoe to 42'. Two 7.5"
OD centralizers w/ 4 stop rings.
Run 4-1/2" RGL ProMesh 250u screens to 167'.
7.5" OD centralizer & 2 stop rings on each screen. Torque to 9600 ft/lbs w/ Doyon double stack tongs.;Daily (midnight) losses = 78 bbls, Cumulative losses for
lateral = 130 bbls.
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total;H2O from L-Pad Lake: 65 bbls Daily/ 65 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 125 bbls Daily/ 5,100 bbls Total
H2O from G&I Source Water: 200 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 502 bbls Daily / 15,408 bbls Total
6/17/2020 Run 4-1/2"13.5# L-80 TSH 625 liner f/ 167' t/ 6436' as per tally. 109 total RGL Pro-Mesh 250u screens w/ 109 each 7-1/2" centralizers w/ 2 stop rings each.;46
total 4-1/2" solid joints w/ 42 each 7-1/2" centralizers. 108K PU / 84K SO. Torque to 9600 ft/lbs w/ Doyon double stack tongs.
9.6 bbls losses.;M/U Baker SLZXP liner top packer f/ 6436' t/ 6472'. Break down 5" safety joint and change out handling equipment to 5" drill pipe.
1 bbl losses.;RIH w/ 4-1/2" liner on 5" drill pipe f/ 6472' t/ 8196'. Liner took 15K at 7773', P/U, set down 5K, P/U then went down w/ 15K.
Pumped 3 BPM, 180 PSI to ensure clear flow path and obtained torque readings at 6790' inside the 9-5/8" casing, 112K PU / 88K SO, 10 RPM = 4K TQ, 20
RPM = 5K TQ.;RIH w/ 4-1/2" liner w/ 5" HWDP singles f/ 8196' t/ 8371' where the liner took 20K weight. Unable to work past.
TD of plug back #1 was 8372', so suspected in the plugged back wellbore.
1.25 bbl losses.;POOH on elevators f/ 8371' t/ 7425'. 122K PU / 91K SO / 98K ROT.
Rotate liner past sidetrack point (S/T @ 7510') f/ 7425' t/ 7650', 20 RPM, 4K TQ.
TIH f/ 7650' t/ 8371', tagged same mark w/ 20K.
5.34 bbls losses.;POOH on elevators f/ 8371' t/ 7330'. TIH f/ 7330' t/ 7500' at 30'/min.
Work pipe in 5' increments quickly f/ 7500' t/ 7585'.
TIH f/ 7585' t/ 8371', tagged same mark w/ 20K.
Contact drilling engineer, will laydown liner & remove centralizers from 1st 5 joints and bend shoe joint.
3.5 bbls losses.;POOH on elevators f/ 8371' t/ 6472'. R/U Doyon casing tongs. L/D Baker SLZXP liner top packer to 6435'. Inspected packer, looked
good.;Change elevators & M/U 5" drill pipe safety joint. POOH laying down 4-1/2" screen liner f/ 6435' t/ 2872'.
9.5 bbls losses.;Daily (midnight) losses = 44 bbls, Total losses for production interval = 174 bbls.
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total;H2O from L-Pad Lake: 85 bbls Daily/ 150 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 125 bbls Daily/ 5,100 bbls Total
H2O from G&I Source Water: 200 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 57 bbls Daily / 15,465 bbls Total
6/18/2020 Laydown 4-1/2" screen liner f/ 2872' t/ surface. Pressure wash clay off bottom 10 screens. Vacuum mud out of shoe joint.
Utilize Doyon double stack tongs. Threads in good condition.;Slip & cut 71' of drilling line. Service top drive, brakes and calibrate block height.;M/U 4-1/2"
round nose shoe w/ bent joint (8" offset 16' from shoe), blanks joint then two screens with centralizers removed t/ 165'.
Run 4-1/2" 13.5# L-80 TSH 625 liner f/ 165' t/ 6433'. Torque to 9600 ft/lbs with Doyon double stack tongs.;48 blank joints (including shoe XO joint) ran with 46
each 7-1/2" OD centralizers & 46 stop rings.
107 RGL Pro-Mesh 250u screens ran with 105 each 7-1/2" OD centralizers & 210 stop rings.;M/U Baker SLZXP liner top packer to 6470'. Then RIH w/ 1 stand
of 5" drill pipe to 6565'.
Pump 3 BPM, 160 PSI to ensure flow path is clear.;RIH w/ 4-1/2" liner on 5" drill pipe and HWDP f/ 6565' t/ 7510'.
Rotate liner 120°R and lock top drive brake to orient shoe bent joint to sidetrack.
Continue TIH and tag bottom at 8372' w/ 20K three times, still in plugged back wellbore- attempt #1.;POOH f/ 8372' t/ 7510'. Pipe was @ 90°R, 30° less.
Orient pipe to 180°.
TIH f/ 7510' t/ 8372' and tag bottom w/ 20K two times, still in plugged back wellbore- attempt #2.;POOH f/ 8372' t/ 7510'. Pipe was at 180°. Orient pipe to 270°.
TIH f/ 7510' t/ 8372' and tag bottom w/ 20K again, still in plugged back wellbore - attempt #3.;POOH f/ 8372' t/ 7460'. Pipe was at 270°. Orient pipe to 0°.
TIH f/ 7460' t/ 8372' and tag bottom w/ 20K again, still in plugged back wellbore - attempt #4.;POOH f/ 8372' t/ 7503'. Pipe was at 0°. Rotate 15 RPM, 4K TQ f/
7503' t/ 7609', did not see any torque or weight increases over the sidetrack interval.
TIH f/ 7609' t/ 8372' and tag bottom w/ 20K again, still in plugged back wellbore - attempt #5.;POOH f/ 8372' t/ 7422'. Orient pipe to 90°. Begin TIH for attempt
#6;47 bbls daily losses, 221 cumulative production interval losses.
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total;H2O from L-Pad Lake: 0 bbls Daily/ 150 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 0 bbls Daily/ 5,100 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 0 bbls Daily / 15,465 bbls Total
6/19/2020 TIH f/ 7415' with pipe oriented 90°R and tagged 8372' again w/ 20K - attempt #6.
*** Notified AOGCC of upcoming BOP test due to change of scope at 06:26 on 19 June 2020 ***;POOH f/ 8372' t/ 7415' and orient pipe 45¯R. TIH f/ 7415'
and tagged 8372' again w/ 20K - attempt #7.;POOH f/ 8372' t/ 7415' and orient pipe 45°L. TIH f/ 7415' and tagged 8372' again w/ 20K- attempt #8.
Decision made to POOH, laydown liner and re-drill the lateral.;POOH f/ 8372' t/ 6468' racking back HWDP and drill pipe. L/D Baker SLZXP to 6433'. R/U
casing tongs & L/D safety joint.;Service rig.;Swap to 4-1/2" elevators & L/D 4-1/2" screen liner f/ 6433'. Pressure wash screens and add salt to trip tank to
maintain 9.3 ppg.
36 bbls losses laying down liner - 2.67 BPH avg.;Clean & clear rig floor of casing equipment.
Sim-ops: service choke manifold.;Pull wear bushing. Flush lines with fresh water. Install test plug & 3-1/2" test joint. R/U test equipment & fill lines. Perform a
shell test against annular, 250 low / 3000 high - good test.;Perform BOP test before redrilling the lateral. AOGCC representative Matthew Herrera waived
witness at 12:50 on 19 June 2020.
All tests performed with fresh water, 250 PSI low & 3000 PSI high, held for 5 minutes each & charted.;1) Annular on 3.5" test joint, choke valves 1, 12, 13, 14,
kill line Demco & 3.5" FOSV
2) 3.5" x 6" upper VBR on 3.5" test joint & 3.5" dart valve
3) 4" x 7" upper VBR on 4.5" test joint, choke valves 9, 11, HCR kill & 5" FOSV #1;4) 4" x 7" upper VBR on 5" test joint, choke valves 5, 8, 10, manual kill, 5"
FOSV #2;Daily (midnight) losses = 49 bbls, Cumulative losses = 270 bbls.
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total;H2O from L-Pad Lake: 390 bbls Daily/ 540 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 35 bbls Daily/ 5,135 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 157 bbls Daily / 15,622 bbls Total
6/20/2020 Finish testing BOP equipment.
5) Choke valves 4, 6, 7 & 5" dart valve.
6) Choke valve 2 & upper IBOP
7) HCR choke & lower IBOP
8) Manual choke valve
9) 3.5" x 6" lower VBR on 5" test joint
10) Blind rams & choke valve 3
11) Hydraulic choke A
12) Manual choke B;Accumulator draw down test: 3000 PSI system pressure, 1650 PSI after closure, 200 PSI recovery in 45 sec., full recovery in 190 sec., 6
nitrogen bottles average 2141 PSI
Test rig gas, flow & PVT alarms - good.;R/D test equipment, pull test joint and test plug. Install 9-1/8" ID wear bushing.;L/D two stands of 5" HWDP from the
derrick. Mobilize BHA components to the rig floor. Remove master bushings & install split bushings.
M/U BHA#4 (Geo-Pilot rotary steerable w/ MWD) to 93'. Test & initialize MWD tools. M/U 3 flex drill collars, 2 joints HWDP, jars and 6 joints 5" drill pipe to
310'.;Jars were cocking and firing while TIH. Decision made to trip out and change out jars.
Sim-ops: Pressure test MPD equipment & lines to 250 PSI low / 1300 PSI high - good tests.;Attempt to shallow pulse test MWD, high pressure: 2400 PSI @
425 GPM. Check surface equipment - good. POOH to bit & found Geo-Pilot paperwork in plastic bag down in the bit box.
M/U bit & trip in hole to 311'. P/U new jars while TIH. Perform shallow pulse test - good. 770 PSI @ 450 GPM.;Continue to single in the hole f/ 311' t/ 5991'.
TIH out of the derrick f/ 5991' t/ 6753'.;PJSM. Slip and cut 46' of drilling line.;PJSM. Remove trip nipple and install MPD RCD. Fill lines.;TIH on elevators f/
6753' t/ 7627' where the assembly took 25K. P/U and set down 45K repeatedly working down to 7630', 7635' then finally 7637'.
Decision made to displace earlier than 7800'. Rack back stand to 7610'.
150K PU / 85K SO;Pump 25 bbl high vis spacer then displace wellbore to new 8.8 ppg Flo-Pro NT mud, 360 GPM, 970 PSI, 60 RPM, 7K TQ, 10.20 ECD
1939u max gas on bottoms up from the shoe. MPD began holding back pressure of 80 to 110 PSI at bottoms up.
Take returns to the pits. Observe heavy sand briefly then diminished;150K PU / 85K SO / 115K ROT
ABI data during displacement:
At 7592', Current = 90.67°, PB1 = 89.61°, final wellbore = 88.81°
At 7605', Current = 89.96°, PB1 = 89.7°, final wellbore = 89.34°
All indications show that the liner & this drilling assembly entered PB1;MPD hold 120 PSI on pumps off. Line up pump to provide backpressure.
POOH f/ 7610' t/ 7134'. Obtain baseline ABI readings while pumping up f/ 7134' t/ 7070', 420 GPM, 1100 PSI, 120 RPM, 7K TQ.
Prepare MWD computers for sidetrack & verify pipe count.;Daily (midnight) losses = 37.9 bbls, Cumulative lateral losses = 307.9 bbls
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total;H2O from L-Pad Lake: 145 bbls Daily/ 685 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
6/21/2020 Perform openhole sidetrack at 7070'. 100% Geo-Pilot deflection at 180°. Trough f/ 7070' t/ 7100' at 50-75'/hr then control drill f 7100' t/ 7132'. Drop 2.11° from
old wellpath (93.57° to 91.46°).
500 GPM, 1080 PSI, 120 RPM, 8K TQ. 150K PU / 90K SO / 110K ROT.;Slide assembly through sidetrack point without pumps. Entered sidetrack the first
time then the plugged back well on the second.
Ream f/ 7070' t/ 7132' four times, 500 GPM, 1300 PSI, 120 RPM, 7K TQ. Slide through sidetrack point with no pumps twice and entered correct wellbore each
time.;Drill 8-1/2" production lateral f/ 7132' t/ 7335' (3953' TVD), 203' drilled, 81.2'/hr AROP.
405 GPM, 1030 PSI, 100 RPM, 6K TQ, 8K WOB.
140K PU / 94K SO / 115K ROT.
8.9 ppg MW, 43 vis, 10.09 ECD, 190u max gas.
MPD hold 100 PSI on connections, 80 PSI while drilling.;Drill 8-1/2" production lateral f/ 7335' t 8086' (3934' TVD), 751' drilled, 125.17'/hr AROP.
450 GPM, 1330 PSI, 100 RPM, 8K TQ, 11-15K WOB.
141K PU / 94K SO / 114K ROT.
9.0 ppg MW, 43 vis, 10.41 ECD, 576u max gas.
MPD hold 160 PSI on connections, 55 PSI while drilling.;Drill 8-1/2" production lateral f/ 8086' t/ 8525' (3928' TVD), 439' drilled, 87.8'/hr AROP.
445 GPM, 1450 PSI, 100 RPM, 8K TQ, 14-15K WOB.
135K PU / 95K SO / 108K ROT.
9.0 ppg MW, 44 vis, 10.54 ECD, 314u max gas.
MPD hold 160 PSI on connections, 55 PSI while drilling.;High vis sweep @ 8173' back on time with 50% increase observed. 21:00 MBT was 5#/bbl.;Geologist
unable to see drilling and logging data. Data exchange to computer receiving data from Sperry stopped. Attempt to restart exchange unsuccessful.
Attempt to repair database unsuccessful. Delete database and restart data exchange solved the issue.;Drill 8-1/2" production lateral f/ 8525' t/ 9236' (3898'
TVD) 711' drilled, 118.5'/hr AROP.
400-450 GPM, 1170-1440 PSI, 100 RPM, 8K TQ, 7-8K WOB.
145K PU / 80K SO / 108K ROT.
9.0 MW, 44 vis, 10.51 ECD, 323u max gas.
MPD hold 170 PSI on connections, 55 PSI while drilling.;High vis sweep at 9034', back 100 strokes late w/ 50% increase. 03:00 MBT was 6.5#/bbl.
Drilled 15 concretions for a total thickness of 64' (2.8% of the lateral).
Last survey @ 9155.15' MD / 3901.86' TVD, 91.85° inc, 192.41° azm, 17.93' from plan, 0.66' left, 17.92' left.;Daily (midnight, including fluid left in sidetrack)
losses = 211 bbls, Cumulative lateral losses = 518.9
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls;H2O from L-Pad Lake: 640 bbls Daily/ 1,325 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 75 bbls Daily/ 5,210 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 57 bbls Daily / 15,679 bbls Total
6/22/2020 Drill 8-1/2" production lateral f/ 9236' t/ 9986' (3860' TVD) 750' drilled, 125'/hr AROP.
445 GPM, 1330 PSI, 100 RPM, 10K TQ, 2K WOB.
150K PU / 75K SO / 110K ROT.
8.95 ppg MW, 41 vis, 10.24 ECD, 487u max gas.;Drill 8-1/2" production lateral f/ 9986' t/ 10842' (3845' TVD) 856' drilled, 142.67'/hr AROP.
450 GPM, 1450 PSI, 100 RPM, 12K TQ, 5-15K WOB.
155K PU / 70K SO / 116K ROT.
8.9 ppg MW, 40 vis, 10.42 ECD, 419u max gas.;High vis sweep at 10073' not seen at shakers.;Drill 8-1/2" production lateral f/ 10842' t/ 11414' (3818' TVD)
572' drilled, 95.33'/hr AROP.
450 GPM, 1540 PSI, 100 RPM, 13K TQ, 5-15K WOB.
155K PU / 65K SO / 110K ROT.
9.0 ppg MW, 41 vis, 10.8 ECD, 392u max gas.;High vis sweep at 11033' back 1300 strokes late with 100% increase.
Fault #1 at 11280' with 7-9' DTS throw, back in NB sand at 11485'.;Drill 8-1/2" production lateral f/ 11414' t/ 11753' (3816' TVD) 339' drilled, 56.5'/hr AROP.
450 GPM, 1770 PSI, 100 RPM, 12K TQ, 3-15K WOB.
156K PU / 70K SO / 100K ROT.
9.0 ppg MW, 45 vis, 10.87 ECD, 243u max gas.
Perform 290 bbl dump and dilute at 11725';Last survey at 11629.97' MD / 3820.86' TVD, 91.67° inc, 188.34° azm, 11.54' from plan, 8.66' high and 7.63' left.
Drilled 33 concretions for a total thickness of 139' (2.8% of the lateral).
Holding 170 PSI on connections and 55 PSI line pressure while drilling.;Daily (midnight) losses = 0 bbls, cumulative lateral losses = 518.9 bbls.
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total;H2O from L-Pad Lake: 640 bbls Daily/ 1,325 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 1,330 bbls Daily/ 6,540 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 1,400 bbls Daily / 18,274 bbls Total
6/23/2020 Drill 8-1/2" production lateral f/ 11753' t/ 12370' (3811' TVD) 617 drilled, 102.8’/hr AROP.
450 GPM, 1660 PSI, 100 RPM, 14K TQ, 16K WOB.
158K PU / 50K SO / 105K ROT.
9.0 ppg MW, 44 vis, 10.96 ECD, 537u max gas.
High vis sweep at 12080', 1900 stk late, 25% increase;Drill 8-1/2" production lateral f/ 12370' t/ 13150' (3798' TVD) @ TD in the NB-sand.
780’ drilled, 130’/hr AROP.
450 GPM, 1680 PSI, 100 RPM, 14K TQ, 5-15K WOB.
165K PU / 40K SO / 110K ROT.
9.0 ppg MW, 43 vis, 11.24 ECD, 605u max gas.;Final survey 7.88' low & 9.14' left of plan.
Pump 30 bbl hi vis sweep cleaning up the wellbore, 450 gpm, 1690 psi, 100 rpm, 14k torque, sweep back 1400 stks late w/ 10% increase, circulate total 4 BU,
rack std back each BU to 12875';Ream to bottom (no slack off weight) f/ 12875' t/ 13150'.
Work through tight hole f/ 12960’ t/ 13150’.
300-450 gpm, 1450-2000 PSI, 40-130 RPM, 14-21k Torque.
Pull back up t/ 12960’ and wash/ream down t/ 13150’, 30 RPM, 150 GPM with no issues.
PJSM for displacing.;PJSM for displacing. Pump SAPP pill treatment, 30 bbl hi vis spacer, 3- 20 bbl SAPP pills with 50 bbl seawater spacers, chase with 264
bbls seawater 8 bpm, 1420 psi, 40 rpm, 15k torque.;Displace w/ 1067 bbls 8.45 ppg, 3% lubed vissed brine 350 gpm, 1275 ICP, 1075 FCP, 40 RPM, 15k
torque, dump 25 bbls interface to pit 2, divert clean returns to pits.
A significant amount of sand returns with the lubed brine to surface.
Max gas during displacement 2352u with seawater spacer;In mud 165K PU / no SO / 110K ROT. 15k tq
In brine 175K PU / 55K SO / 111K ROT. 12k tq.
100 bbls loss during displacement.;MPD initially started with 55 psi on full open choke w/ 9.0 ppg mud, hold 170 psi w/ 8.45 ppg brine, ECD 10.5 ppg.
Reciprocate pipe 90'
Circulate 300 bbls after lubed brine to surface then perform PST, 2x pre shakers tests failed. Test after the shakers passed w/ 5.5 sec. 3 times.;Monitor
pressure build w/ MPD.
Trap 60 PSI, built to 140 PSI in 4 min. Bled down to 60 PSI, built to 120 PSI in 4 min.
8.5 ppg MW out + 0.6 ppg (120 trapped pressure) = 9.1 ppg EMW.
Obtain new SPRs;Continue circulate to clean sand for passing PST 350 GPM, 40 RPM.
4 bbl/hr loss rate.;Daily (midnight) losses =144 bbls, cumulative lateral losses = 663 bbls.
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total
H2O from L-Pad Lake: 640 bbls Daily/ 1,325 bbls Total;H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 790 bbls Daily/ 7,330 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 1,810 bbls Daily / 20,084 bbls Total
6/24/2020 Continue circulating bottoms up. 350 GPM, 910 psi. 40 RPM, 11k Tq. Work string 95'
Consistent sand across all three shakers.
Perform PST. Failed with sample from before shakers, Passed with sample after shakers.;BROOH f/ 13150' t/ 10747' 500 GPM, 1500 psi, 100 RPM, 12k Tq,
175k PU / 55k SO / 111k ROT.
Lay down stands in the mousehole, mark joints for hard band and inspection.
MPD hold 170 PSI on connections w/ 62 PSI with chokes full open. ECD = 10.14
8 BPH losses;BROOH f/ 10747' t/ 7040' 500 GPM, 1250psi, 100 RPM, 8k Tq, 150k PU / 95k SO / 117k ROT.
Lay down stands in the mousehole, mark joints for hard band and inspection.
MPD hold 160 PSI on connections w/ 55 PSI with chokes full open. ECD = 10.17;RIH w/ no pumps & rotation f/ 7040’ t/ 7134’. ST point @ 7070’
Engage pumps and obtain ABI of 91.48° at 7130’. Original ST inclination = 91.11°. PB1 inclination = 93.66°.
Good indication assembly entered into sidetracked wellbore.
Stop pumps and pull t/ 7040'. No issues.;BROOH next std f/ 7040' t/ 6920’ 500 gpm, 1150 psi, 100 RPM, 9k Tq.
Pull BHA though shoe f/ 6940' t/ 6816’ with no rotary, 500 gpm, 1100 psi.
69 bbls loss on BROOH;Pump 2x 30 bbl high vis sweep, 500 GPM, 1220 PSI, 30 RPM, 4K TQ, reciprocate 90'.
Both sweeps on time w/ 10% increase. Circulate a total of 2.6 bottom up.
Sand cleaned up significantly after each sweep with minimal sand on shakers after second one.
9042 stks. Max gas 133u.;Shut down and record MPD pressure while obtaining PST. Both samples, pre and post shakers, passed with 3x 4.5 sec tests
5 min shut in MPD pressures: 122psi, 70psi & 60 psi.
Weight up surface volume to 9.3;Weight up lubricated brine from 8.8+ to 9.3 ppg with oilfield salt over 1.4 circulations, 340 GPM, 600 PSI, 30 RPM, 3K TQ.
Reciprocate 90'.;Monitor pressure with MPD Choke closed for 5 min. - 19 PSI.
Open up choke monitor well 5 BPH initial flow reducing to 1.5 BPH in 30 min and static after 57 min
Hold PJSM on removing MPD bearing while monitor flow.;Remove MPD RCD and install trip nipple.
Check for leaks - Good;POOH laying down 5" drill pipe f/ 6816' t/ 2623'.
Separate joints for inspection and hard banding.
4.5 bbl losses.;Daily (midnight) losses = 225 bbls, cumulative lateral losses = 888 bbls.
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total
H2O from L-Pad Lake: 0 bbls Daily/ 1,325 bbls Total;H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 325 bbls Daily/ 7,655 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 1,782 bbls Daily / 21,866 bbls Total
6/25/2020 POOH laying down 5" drill pipe f/ 2623' t/ 2086'. Separate joints for inspection and hard banding.;Drop 2.34" drift. POOH racking back drill pipe f/ 2086' t/ 278'.
Flow check - static. L/D 2 HWDP, jars, float sub, 3 NM flex drill collars, 2nd float sub & 3 pt reamer t/ 81' Read MWD tools - good data.
Drift landed in top of collars. L/D BHA from 81'. Bit graded: 2-2-BT-A-X-I-CT-TD.
Clear rig Floor;R/U Doyon double stack tongs, change elevators. Remove split bushings and install master bushings with inserts.;M/U 4-1/2" H625 x BTC XO
joint w/ round nose shoe to 42'. Two 7.5" OD centralizers w/ 4 stop rings.
Run 4-1/2" RGL ProMesh 250u screens to 6479'.
7.5" OD centralizer & 2 stop rings on each screen, except jts # 1 & 3. Torque to 9600 ft/lbs w/ Doyon double stack tongs.;110 total RGL Pro-Mesh 250u
screens w/ 108 7-1/2" centralizers w/ 2 stop rings each.
45 total 4-1/2" solid joints w/ 41 each 7-1/2" centralizers. 107K PU / 83K SO.
11 bbls losses.;Change out handling equipment to 5" drill pipe.
M/U Baker 7"x9-5/8" SLZXP liner top packer w/ 7.38" seal bore & 7"x9-5/8" hyd setting tool w/ 8x 1/2" 15% brass set screws, 2648' PSI shear pressure to
6515'.
RIH w/ 3 stand of 5" drill pipe to 6790'.;Circulate to verify flow path at 3 & 4 BPM (150 & 320 PSI), obtain torque inside the 9-5/8" casing at 10 & 20 RPM, both
4k Tq.
115k PU / 86k SO / 94k ROT. Blow down top drive.;RIH w/ 4-1/2" liner on 5" drill pipe f/ 6790' t/ 8229'. RIH w/ 4-1/2" liner w/ 5" HWDP singles f/ 8229’ t/
8383’. Past PB1 depth @ 8372’, with no issues.;Run 4-1/2" liner w/ 5" HWDP singles f/ 8383' t/ 13123'
RIH with double 5” DP & Tag btm at 13150'.
Set liner in tension. Drop 0.906" ball.
255k PU / 150k SO.
14 bbls loss;Pump ball down with 30 bbl high vis sweep and land ball on seat at 68.3 bbl.
Pressure up and saw packer set at 2880 psi.
Pressure up to 4000 with mud pumps and line up test pump. Pressure up to 4378 psi & shear neutralizer tool. Pressure bled to 0.;P/U & verify free, 220k
Good. Test back side to 1500 psi for 10 min, Good.
Pump at 2 bpm & pull out of liner top. Hold 150-220 psi while pulling out.
Bring pumps to 10 bpm when pressure dumped.
Continue pulling running tool up above LT, bring pumps up to 14.3 bpm 1550 psi.;Daily (midnight) losses = 38 bbls, cumulative lateral losses = 926 bbls.
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total
H2O from L-Pad Lake: 0 bbls Daily/ 1,325 bbls Total;H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 90 bbls Daily/ 7,745 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 285 bbls Daily / 22,151 bbls Total
6/26/2020 Circulate out sweep and additional BU. 14 bpm 1600 psi. Considerable sand back and 75% increase with sweep, cleaning up good by next bottoms up.;Line
up and pump spacer and displace the well to clean 9.3 ppg brine at 8 bpm, 751 psi. Dump 100 bbl interface. Reciprocate string 90’. 220k PU / 175k SO
Monitor well. Static. Blow down TopDrive.;PJSM, POOH & L/D HWDP F/ 6645' T/ 1713'. Lay down 5" DP and liner running tool.
Total of 16 bbls loss during TOH;Make up stack washer and flush BOP stack clean. Drain BOP stack, pull wear bushing & install test plug and pull both 30’ &
90’ mouse holes.;PJSM, Change out upper pipe rams from 4-1/2”x7” VBR, t/ 7-5/8” Rams;Swap to completion @ 18:00.
See completion report #1 for details.;Daily (midnight) losses = 34 bbls, cumulative lateral losses = 960 bbls.
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total
H2O from L-Pad Lake: 50 bbls Daily/ 1,375 bbls Total;H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 0 bbls Daily/ 7,745 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 971 bbls Daily / 23,122 bbls Total
btm at 13150'.
Activity Date Ops Summary
6/26/2020 Refer to final drilling report for details.,Change out upper pipe rams from 4-1/2”x7” VBR t/ 7-5/8” SBR and test 250psi 5min, 3000psi 5 m
Rig down test equipment, blow down lines and install both mouseholes.,Perform dummy run w/ 7-5/8" hanger.
Rig up 7-5/8" Handling Equipment,PJSM. P/U Baker bullet seal assy w/ 8.27" O.D. locator to 17'. Run 7-5/8" 29.7# L-80 Hydril 521 liner
Torque to 10,100 ft/lbs with Doyon double stack tongs.
16 bbls lost while running liner.,Daily (midnight) losses = 34 bbls, cumulative lateral losses = 960 bbls.
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total
H2O from L-Pad Lake: 50 bbls Daily/ 1,375 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 0 bbls Daily/ 7,745 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 971 bbls Daily / 23,122 bbls Total
6/27/2020 PJSM. P/U Baker bullet seal assy w/ 8.27" O.D. locator to 17'. Run 7-5/8" 29.7# L-80 Hydril 521 liner F/ 5831' T/ 6645'. Sting in to seals
out. Close annular Pressure up on back side to 300 psi to verify. Good.
L/D 4 joints and change out Joint 165 with 167. Make up one space out pump 2.87 under joint 166 and make up landing joint. RIH & lan
up/dn 175/120,PJSM, R/U to reverse circ corrosion inhibited brine and diesel. Test lines to 2000 psi. Close annular & Pressure up on b
300 psi. P/U until pressure dumps + 6''. Pump 79 bbl 9.3 1% concor 303 followed by 45 bbl diesel. Land hanger. FCP 530 and 300 ps
back side.,Bleed down and blow down surface equipment. R/D circ equipment. L/D landing joint. R/U to run pack off. Run and land pac
Test void to 250/3000 psi.,Purge lines in cellar with water. Test lines to 2000 psi. Good. Line up on back side and pressure test with dies
for 30 min. Good. Flush lines with water and blow down to cuttings tank.,PJSM, Spot ESP spooler, R/U Doyon 3.5 handling equipment
ESP equipment. Hang sheave in derrick. Run ESP cable to rig floor.,Pick up, Make up & service ESP/Motor and seal assembly.
Connect ESP cable, 100' control line discharge, to motor and gauge assembly. Install 6x bolt on clamps to motor assembly connections,
motor cannon clamps.
Perform tests on ESP cable. Good test
Make up last Centrilift pump, P/U and install 8x pump clamps onto the pump assembly.,RIH with ESP on 3-1/2" 9.3# L-80 EUE Tubing f/
Install cannon clamp every connection for first 10 jts. Install cannon clamp every other connection from jt #10 and above & below GLM b
Test cable connection every 1000’.
Losses @ 2 BPH,RIH with ESP on 3-1/2" 9.3# L-80 EUE Tubing f/ 2023' to 5817'.
Install cannon clamp every other connection.
Test cable connection every 1000’.
Losses @ 2 BPH,Daily (midnight) losses = 30 bbls, cumulative lateral losses = 956 bbls.
H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls Total
H2O from L-Pad Lake: 50 bbls Daily/ 1,375 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 75 bbls Daily/ 7,820 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 114 bbls Daily / 23,236 bbls Total
Job Name:2011920C MPU L-60 Completion
Well Name:
Field:
County/State:
MP L-60
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
50-029-23678-00-00API #:
6/28/2020 RIH with ESP on 3-1/2" 9.3# L-80 EUE Tubing f/ 5817' to 6375'.
Install cannon clamp every other connection.
Test cable connection every 1000’.
30 bbls total losses running tubing,M/U 3-1/2" x 11" FMC tubing hanger and 5" landing joint. Terminate ESP cable. Drain BOP Stack & b
surface lines.
Land 3-1/2" tubing on tubing hanger with BPV installed at 5060' & RILS.
96K PU / 65K SO, 25K on hanger,Clear rig floor of tubing equipment. L/D landing joint. Remove mouseholes and trip nipple.,N/D BOPE
wellhead, conduct final OHM, MEGG & Sensor checks,.
N/U tree. Well head rep test hanger void to 500 psi low for 5 min, 5000 psi high for 10 min.
Test tree with diesel to 250 and 5000 psi. 5 min ea. charted.
R/D test equipment, drain tree and pull BPV w/dart.,R/U to reverse circulate, test surface lines, pump 88 bbls diesel down I/A, ICP 3 bp m
FCP 1 bpm, 1000 psi.
Bullhead 23 bbls diesel down tubing, ICP 1.2 bpm, 1490 psi. FCP 1.1 bpm, 1500 psi.
Flush and blow down lines. Rig down.,Rig released at 18:00. See L-59 report for details,H2O from B-Pad Creek: 0 bbls Daily/ 5,080 bbls
H2O from L-Pad Lake: 50 bbls Daily/ 1,425 bbls Total
H2O from 6-Mile: 0 bbls Daily/ 575 bbls Total
H2O from A-Pad: 75 bbls Daily/ 7,820 bbls Total
H2O from G&I Source Water: 0 bbls Daily/ 870 bbls Total
Cuttings/mud/cement to MPU G&I: 497 bbls Daily / 23,733 bbls Total
26 June, 2020
Milne Point
M Pt L Pad
MPU L-60
MPU L-60
500292367800
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Milne Point, ACT, MILNE POINT
Alaska Zone 04
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
usft
+E/-W
+N/-S
Position Uncertainty
usft
usft
usftGround Level:
MPU L-60
usft
usft
0.00
0.00
6,031,375.87
544,958.07
16.60Wellhead Elevation:17.00 usft0.50
70° 29' 47.712 N
149° 37' 56.519 W
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
MPU L-60
Model NameMagnetics
IFR 6/25/2020 15.98 80.92 57,375.00000000
Phase:Version:
Audit Notes:
Design MPU L-60
1.0 ACTUAL
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:7,064.13
191.510.000.0033.77
From
(usft)
Survey Program
DescriptionTool NameSurvey (Wellbore)
To
(usft)
Date 6/26/2020
Survey Date
3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing100.00 634.00 MPU L-60PB1 E-Line Gyro (MPU L-60PB 06/02/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa698.08 6,800.39 MPU L-60PB1 MWD+IFR2+MS+Sag (1) 06/05/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,872.52 7,064.13 MPU L-60PB1 MWD+IFR2+MS+Sag (2) 06/12/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa7,070.00 13,081.34 MPU L-60 MWD+IFR2+MS+Sag (5) (MP 06/19/2020
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
33.77 0.00 0.00 33.77 0.00 0.00-17.00 6,031,375.87 544,958.07 0.00 0.00 UNDEFINED
100.00 0.38 77.11 100.00 0.05 0.2149.23 6,031,375.92 544,958.28 0.57 -0.09 3_Gyro-GC_Csg (1)
166.00 0.42 73.38 166.00 0.17 0.66115.23 6,031,376.04 544,958.73 0.07 -0.30 3_Gyro-GC_Csg (1)
260.00 0.64 127.56 259.99 -0.05 1.41209.22 6,031,375.82 544,959.48 0.55 -0.23 3_Gyro-GC_Csg (1)
353.00 3.65 156.88 352.92 -3.09 2.98302.15 6,031,372.79 544,961.07 3.34 2.44 3_Gyro-GC_Csg (1)
447.00 5.42 167.49 446.62 -10.18 5.12395.85 6,031,365.72 544,963.25 2.08 8.96 3_Gyro-GC_Csg (1)
540.00 5.99 173.71 539.16 -19.29 6.60488.39 6,031,356.62 544,964.79 0.90 17.59 3_Gyro-GC_Csg (1)
634.00 9.61 178.61 632.28 -32.02 7.33581.51 6,031,343.90 544,965.59 3.91 29.91 3_Gyro-GC_Csg (1)
698.08 13.20 183.37 695.08 -44.67 7.03644.31 6,031,331.25 544,965.37 5.79 42.37 3_MWD+IFR2+MS+Sag (2)
794.57 17.61 191.41 788.10 -69.99 3.49737.33 6,031,305.91 544,961.98 5.07 67.89 3_MWD+IFR2+MS+Sag (2)
888.90 22.54 181.62 876.69 -102.08 0.15825.92 6,031,273.80 544,958.84 6.31 100.00 3_MWD+IFR2+MS+Sag (2)
6/26/2020 11:30:34AM COMPASS 5000.15 Build 91E Page 2
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
983.85 26.66 178.74 963.01 -141.59 0.11912.24 6,031,234.30 544,959.03 4.52 138.72 3_MWD+IFR2+MS+Sag (2)
1,079.96 30.55 180.36 1,047.37 -187.59 0.43996.60 6,031,188.31 544,959.63 4.13 183.73 3_MWD+IFR2+MS+Sag (2)
1,175.04 34.96 178.80 1,127.32 -239.01 0.851,076.55 6,031,136.89 544,960.36 4.72 234.04 3_MWD+IFR2+MS+Sag (2)
1,270.65 37.37 179.10 1,204.50 -295.42 1.881,153.73 6,031,080.50 544,961.73 2.53 289.10 3_MWD+IFR2+MS+Sag (2)
1,364.86 40.21 179.20 1,277.92 -354.43 2.751,227.15 6,031,021.50 544,962.96 3.02 346.75 3_MWD+IFR2+MS+Sag (2)
1,460.15 42.70 178.84 1,349.33 -417.50 3.831,298.56 6,030,958.45 544,964.43 2.63 408.34 3_MWD+IFR2+MS+Sag (2)
1,555.42 46.52 178.04 1,417.15 -484.36 5.671,366.38 6,030,891.60 544,966.67 4.05 473.49 3_MWD+IFR2+MS+Sag (2)
1,650.79 48.88 177.13 1,481.33 -554.83 8.651,430.56 6,030,821.15 544,970.08 2.57 541.95 3_MWD+IFR2+MS+Sag (2)
1,743.54 52.60 177.37 1,540.01 -626.55 12.091,489.24 6,030,749.46 544,973.95 4.02 611.54 3_MWD+IFR2+MS+Sag (2)
1,840.35 55.15 177.68 1,597.08 -704.67 15.471,546.31 6,030,671.38 544,977.80 2.65 687.41 3_MWD+IFR2+MS+Sag (2)
1,934.99 55.02 178.02 1,651.25 -782.22 18.381,600.48 6,030,593.85 544,981.18 0.33 762.82 3_MWD+IFR2+MS+Sag (2)
2,031.00 54.89 178.37 1,706.38 -860.78 20.851,655.61 6,030,515.31 544,984.13 0.33 839.31 3_MWD+IFR2+MS+Sag (2)
2,126.38 53.27 176.81 1,762.34 -937.95 24.091,711.57 6,030,438.17 544,987.83 2.15 914.28 3_MWD+IFR2+MS+Sag (2)
2,221.81 53.29 178.13 1,819.40 -1,014.37 27.471,768.63 6,030,361.79 544,991.67 1.11 988.49 3_MWD+IFR2+MS+Sag (2)
2,316.92 57.09 179.23 1,873.68 -1,092.42 29.251,822.91 6,030,283.75 544,993.92 4.11 1,064.62 3_MWD+IFR2+MS+Sag (2)
2,411.67 55.80 180.25 1,926.05 -1,171.38 29.611,875.28 6,030,204.81 544,994.76 1.63 1,141.91 3_MWD+IFR2+MS+Sag (2)
2,507.29 55.09 180.87 1,980.29 -1,250.12 28.851,929.52 6,030,126.07 544,994.47 0.91 1,219.23 3_MWD+IFR2+MS+Sag (2)
2,603.36 56.56 177.49 2,034.26 -1,329.57 30.001,983.49 6,030,046.63 544,996.11 3.29 1,296.85 3_MWD+IFR2+MS+Sag (2)
2,697.92 53.69 175.94 2,088.33 -1,407.01 34.432,037.56 6,029,969.23 545,001.00 3.32 1,371.85 3_MWD+IFR2+MS+Sag (2)
2,793.54 53.91 176.65 2,144.80 -1,484.01 39.412,094.03 6,029,892.27 545,006.45 0.64 1,446.30 3_MWD+IFR2+MS+Sag (2)
2,888.47 54.00 177.21 2,200.66 -1,560.66 43.532,149.89 6,029,815.66 545,011.03 0.49 1,520.59 3_MWD+IFR2+MS+Sag (2)
2,983.50 54.99 177.93 2,255.85 -1,637.95 46.802,205.08 6,029,738.40 545,014.77 1.21 1,595.67 3_MWD+IFR2+MS+Sag (2)
3,079.17 52.69 177.07 2,312.30 -1,715.11 50.162,261.53 6,029,661.26 545,018.60 2.51 1,670.61 3_MWD+IFR2+MS+Sag (2)
3,174.56 52.82 177.85 2,370.03 -1,790.97 53.532,319.26 6,029,585.43 545,022.42 0.67 1,744.27 3_MWD+IFR2+MS+Sag (2)
3,269.72 52.68 178.22 2,427.63 -1,866.67 56.122,376.86 6,029,509.75 545,025.48 0.34 1,817.93 3_MWD+IFR2+MS+Sag (2)
3,364.29 52.68 179.32 2,484.97 -1,941.86 57.742,434.20 6,029,434.58 545,027.55 0.93 1,891.29 3_MWD+IFR2+MS+Sag (2)
3,458.77 52.51 179.57 2,542.36 -2,016.91 58.472,491.59 6,029,359.55 545,028.73 0.28 1,964.68 3_MWD+IFR2+MS+Sag (2)
3,554.71 52.51 180.16 2,600.75 -2,093.03 58.652,549.98 6,029,283.44 545,029.37 0.49 2,039.24 3_MWD+IFR2+MS+Sag (2)
3,649.98 52.61 180.98 2,658.67 -2,168.67 57.892,607.90 6,029,207.80 545,029.07 0.69 2,113.51 3_MWD+IFR2+MS+Sag (2)
3,745.44 53.69 181.13 2,715.92 -2,245.04 56.492,665.15 6,029,131.43 545,028.13 1.14 2,188.63 3_MWD+IFR2+MS+Sag (2)
3,840.84 54.52 178.98 2,771.85 -2,322.32 56.422,721.08 6,029,054.16 545,028.53 2.02 2,264.36 3_MWD+IFR2+MS+Sag (2)
3,935.17 54.68 180.08 2,826.50 -2,399.21 57.052,775.73 6,028,977.29 545,029.62 0.97 2,339.57 3_MWD+IFR2+MS+Sag (2)
4,030.90 54.61 175.90 2,881.91 -2,477.20 59.792,831.14 6,028,899.31 545,032.83 3.56 2,415.46 3_MWD+IFR2+MS+Sag (2)
4,125.94 54.60 175.47 2,936.96 -2,554.46 65.612,886.19 6,028,822.10 545,039.13 0.37 2,490.00 3_MWD+IFR2+MS+Sag (2)
4,221.12 52.58 176.24 2,993.45 -2,630.85 71.162,942.68 6,028,745.75 545,045.13 2.22 2,563.75 3_MWD+IFR2+MS+Sag (2)
4,316.52 52.77 176.55 3,051.29 -2,706.57 75.933,000.52 6,028,670.08 545,050.36 0.33 2,636.99 3_MWD+IFR2+MS+Sag (2)
4,411.39 54.24 176.78 3,107.72 -2,782.70 80.363,056.95 6,028,593.98 545,055.25 1.56 2,710.71 3_MWD+IFR2+MS+Sag (2)
4,506.35 51.96 176.72 3,164.73 -2,858.51 84.673,113.96 6,028,518.20 545,060.01 2.40 2,784.13 3_MWD+IFR2+MS+Sag (2)
4,602.01 51.60 177.71 3,223.91 -2,933.58 88.323,173.14 6,028,443.17 545,064.12 0.90 2,856.96 3_MWD+IFR2+MS+Sag (2)
4,697.12 54.33 178.55 3,281.19 -3,009.45 90.793,230.42 6,028,367.32 545,067.05 2.96 2,930.81 3_MWD+IFR2+MS+Sag (2)
6/26/2020 11:30:34AM COMPASS 5000.15 Build 91E Page 3
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
4,792.82 54.71 179.27 3,336.74 -3,087.37 92.273,285.97 6,028,289.42 545,069.00 0.73 3,006.87 3_MWD+IFR2+MS+Sag (2)
4,887.60 53.14 178.17 3,392.55 -3,163.95 93.973,341.78 6,028,212.86 545,071.17 1.90 3,081.57 3_MWD+IFR2+MS+Sag (2)
4,982.84 53.23 178.81 3,449.62 -3,240.17 95.983,398.85 6,028,136.66 545,073.64 0.55 3,155.86 3_MWD+IFR2+MS+Sag (2)
5,077.61 54.54 178.91 3,505.48 -3,316.71 97.503,454.71 6,028,060.13 545,075.62 1.38 3,230.55 3_MWD+IFR2+MS+Sag (2)
5,173.58 54.06 179.82 3,561.48 -3,394.64 98.373,510.71 6,027,982.22 545,076.96 0.92 3,306.74 3_MWD+IFR2+MS+Sag (2)
5,268.22 53.86 179.77 3,617.16 -3,471.16 98.643,566.39 6,027,905.70 545,077.69 0.22 3,381.68 3_MWD+IFR2+MS+Sag (2)
5,364.17 60.08 181.10 3,669.44 -3,551.56 98.003,618.67 6,027,825.31 545,077.54 6.59 3,460.59 3_MWD+IFR2+MS+Sag (2)
5,459.22 60.62 181.05 3,716.46 -3,634.15 96.453,665.69 6,027,742.72 545,076.49 0.57 3,541.82 3_MWD+IFR2+MS+Sag (2)
5,554.68 61.21 182.68 3,762.86 -3,717.53 93.733,712.09 6,027,659.34 545,074.27 1.62 3,624.06 3_MWD+IFR2+MS+Sag (2)
5,649.60 63.83 184.38 3,806.66 -3,801.56 88.533,755.89 6,027,575.28 545,069.58 3.18 3,707.45 3_MWD+IFR2+MS+Sag (2)
5,744.95 66.70 187.03 3,846.56 -3,887.72 79.903,795.79 6,027,489.09 545,061.48 3.93 3,793.59 3_MWD+IFR2+MS+Sag (2)
5,840.36 71.54 188.97 3,880.56 -3,975.96 67.483,829.79 6,027,400.78 545,049.58 5.42 3,882.54 3_MWD+IFR2+MS+Sag (2)
5,935.36 75.85 189.68 3,907.22 -4,065.91 52.703,856.45 6,027,310.75 545,035.35 4.59 3,973.63 3_MWD+IFR2+MS+Sag (2)
6,030.62 81.09 189.73 3,926.26 -4,157.88 36.973,875.49 6,027,218.70 545,020.18 5.50 4,066.89 3_MWD+IFR2+MS+Sag (2)
6,125.82 84.57 190.55 3,938.14 -4,250.84 20.343,887.37 6,027,125.64 545,004.12 3.75 4,161.30 3_MWD+IFR2+MS+Sag (2)
6,221.25 85.99 191.54 3,945.99 -4,344.18 2.123,895.22 6,027,032.20 544,986.46 1.81 4,256.40 3_MWD+IFR2+MS+Sag (2)
6,316.31 85.87 190.77 3,952.74 -4,437.21 -16.223,901.97 6,026,939.07 544,968.68 0.82 4,351.22 3_MWD+IFR2+MS+Sag (2)
6,411.30 86.67 190.94 3,958.92 -4,530.30 -34.073,908.15 6,026,845.89 544,951.40 0.86 4,446.00 3_MWD+IFR2+MS+Sag (2)
6,506.87 86.49 191.30 3,964.62 -4,623.91 -52.473,913.85 6,026,752.18 544,933.57 0.42 4,541.40 3_MWD+IFR2+MS+Sag (2)
6,602.06 88.03 192.31 3,969.17 -4,716.98 -71.923,918.40 6,026,659.00 544,914.68 1.93 4,636.47 3_MWD+IFR2+MS+Sag (2)
6,695.79 92.05 192.74 3,969.10 -4,808.46 -92.253,918.33 6,026,567.41 544,894.91 4.31 4,730.17 3_MWD+IFR2+MS+Sag (2)
6,791.44 89.82 189.90 3,967.54 -4,902.22 -111.023,916.77 6,026,473.55 544,876.71 3.77 4,825.79 3_MWD+IFR2+MS+Sag (2)
6,800.39 89.70 189.74 3,967.58 -4,911.04 -112.543,916.81 6,026,464.72 544,875.24 2.23 4,834.73 3_MWD+IFR2+MS+Sag (2)
6,872.52 90.74 190.38 3,967.30 -4,982.06 -125.143,916.53 6,026,393.63 544,863.07 1.69 4,906.84 3_MWD+IFR2+MS+Sag (3)
6,968.50 90.99 191.35 3,965.86 -5,076.31 -143.233,915.09 6,026,299.29 544,845.56 1.04 5,002.80 3_MWD+IFR2+MS+Sag (3)
7,064.13 93.77 193.08 3,961.88 -5,169.68 -163.443,911.11 6,026,205.80 544,825.91 3.42 5,098.33 3_MWD+IFR2+MS+Sag (3)
7,070.00 93.76 193.05 3,961.50 -5,175.38 -164.773,910.73 6,026,200.09 544,824.62 0.54 5,104.18 3_MWD+IFR2+MS+Sag (4)
7,157.39 91.36 191.55 3,957.60 -5,260.67 -183.363,906.83 6,026,114.70 544,806.54 3.24 5,191.47 3_MWD+IFR2+MS+Sag (4)
7,252.84 91.42 188.59 3,955.28 -5,354.62 -200.053,904.51 6,026,020.67 544,790.43 3.10 5,286.85 3_MWD+IFR2+MS+Sag (4)
7,347.95 91.05 185.86 3,953.23 -5,448.94 -212.003,902.46 6,025,926.28 544,779.05 2.90 5,381.66 3_MWD+IFR2+MS+Sag (4)
7,443.63 91.24 187.04 3,951.32 -5,543.99 -222.753,900.55 6,025,831.17 544,768.88 1.25 5,476.95 3_MWD+IFR2+MS+Sag (4)
7,539.46 91.98 190.20 3,948.62 -5,638.69 -237.103,897.85 6,025,736.40 544,755.10 3.39 5,572.61 3_MWD+IFR2+MS+Sag (4)
7,634.57 91.73 191.54 3,945.55 -5,732.04 -255.033,894.78 6,025,642.95 544,737.74 1.43 5,667.66 3_MWD+IFR2+MS+Sag (4)
7,728.98 91.67 191.58 3,942.74 -5,824.50 -273.943,891.97 6,025,550.39 544,719.39 0.08 5,762.03 3_MWD+IFR2+MS+Sag (4)
7,824.96 91.30 191.69 3,940.26 -5,918.47 -293.293,889.49 6,025,456.31 544,700.61 0.40 5,857.97 3_MWD+IFR2+MS+Sag (4)
7,918.20 91.36 192.04 3,938.09 -6,009.70 -312.463,887.32 6,025,364.98 544,681.99 0.38 5,951.19 3_MWD+IFR2+MS+Sag (4)
8,014.10 91.18 192.22 3,935.97 -6,103.43 -332.603,885.20 6,025,271.13 544,662.42 0.27 6,047.06 3_MWD+IFR2+MS+Sag (4)
8,109.34 91.11 191.17 3,934.06 -6,196.67 -351.903,883.29 6,025,177.79 544,643.68 1.10 6,142.28 3_MWD+IFR2+MS+Sag (4)
8,205.04 89.82 191.19 3,933.29 -6,290.55 -370.463,882.52 6,025,083.81 544,625.70 1.35 6,237.97 3_MWD+IFR2+MS+Sag (4)
8,299.01 91.11 192.04 3,932.53 -6,382.59 -389.383,881.76 6,024,991.66 544,607.34 1.64 6,331.93 3_MWD+IFR2+MS+Sag (4)
6/26/2020 11:30:34AM COMPASS 5000.15 Build 91E Page 4
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
8,395.37 90.80 192.77 3,930.92 -6,476.69 -410.073,880.15 6,024,897.45 544,587.21 0.82 6,428.27 3_MWD+IFR2+MS+Sag (4)
8,490.68 91.79 192.97 3,928.77 -6,569.58 -431.303,878.00 6,024,804.44 544,566.55 1.06 6,523.53 3_MWD+IFR2+MS+Sag (4)
8,585.74 93.03 192.85 3,924.77 -6,662.15 -452.523,874.00 6,024,711.75 544,545.90 1.31 6,618.47 3_MWD+IFR2+MS+Sag (4)
8,680.69 93.40 192.72 3,919.44 -6,754.60 -473.503,868.67 6,024,619.19 544,525.48 0.41 6,713.25 3_MWD+IFR2+MS+Sag (4)
8,774.97 92.53 190.62 3,914.57 -6,846.81 -492.543,863.80 6,024,526.88 544,507.00 2.41 6,807.40 3_MWD+IFR2+MS+Sag (4)
8,869.52 91.85 190.77 3,910.95 -6,939.64 -510.073,860.18 6,024,433.95 544,490.03 0.74 6,901.87 3_MWD+IFR2+MS+Sag (4)
8,959.88 92.29 191.72 3,907.69 -7,028.21 -527.683,856.92 6,024,345.28 544,472.95 1.16 6,992.17 3_MWD+IFR2+MS+Sag (4)
9,060.17 91.36 191.55 3,904.49 -7,126.39 -547.903,853.72 6,024,246.99 544,453.34 0.94 7,092.40 3_MWD+IFR2+MS+Sag (4)
9,155.15 91.85 192.41 3,901.83 -7,219.26 -567.603,851.06 6,024,154.01 544,434.19 1.04 7,187.34 3_MWD+IFR2+MS+Sag (4)
9,250.89 93.34 194.29 3,897.50 -7,312.31 -589.683,846.73 6,024,060.84 544,412.68 2.50 7,282.93 3_MWD+IFR2+MS+Sag (4)
9,346.21 93.46 196.13 3,891.85 -7,404.13 -614.653,841.08 6,023,968.88 544,388.27 1.93 7,377.88 3_MWD+IFR2+MS+Sag (4)
9,440.51 93.40 195.27 3,886.20 -7,494.75 -640.123,835.43 6,023,878.12 544,363.35 0.91 7,471.76 3_MWD+IFR2+MS+Sag (4)
9,535.79 93.03 192.46 3,880.86 -7,587.10 -662.913,830.09 6,023,785.64 544,341.12 2.97 7,566.80 3_MWD+IFR2+MS+Sag (4)
9,631.40 91.54 188.96 3,877.05 -7,680.95 -680.663,826.28 6,023,691.70 544,323.94 3.98 7,662.30 3_MWD+IFR2+MS+Sag (4)
9,726.31 91.79 189.26 3,874.29 -7,774.62 -695.683,823.52 6,023,597.94 544,309.49 0.41 7,757.09 3_MWD+IFR2+MS+Sag (4)
9,821.55 92.66 189.17 3,870.59 -7,868.56 -710.923,819.82 6,023,503.92 544,294.82 0.92 7,852.18 3_MWD+IFR2+MS+Sag (4)
9,916.19 91.61 189.74 3,867.07 -7,961.85 -726.463,816.30 6,023,410.55 544,279.85 1.26 7,946.69 3_MWD+IFR2+MS+Sag (4)
10,010.74 92.04 191.94 3,864.05 -8,054.66 -744.233,813.28 6,023,317.64 544,262.64 2.37 8,041.18 3_MWD+IFR2+MS+Sag (4)
10,106.08 91.67 193.87 3,860.97 -8,147.54 -765.513,810.20 6,023,224.65 544,241.92 2.06 8,136.44 3_MWD+IFR2+MS+Sag (4)
10,200.71 90.87 195.50 3,858.87 -8,239.05 -789.493,808.10 6,023,133.00 544,218.50 1.92 8,230.90 3_MWD+IFR2+MS+Sag (4)
10,297.02 90.93 194.64 3,857.36 -8,332.04 -814.533,806.59 6,023,039.87 544,194.02 0.90 8,327.01 3_MWD+IFR2+MS+Sag (4)
10,392.38 90.06 192.81 3,856.53 -8,424.66 -837.153,805.76 6,022,947.12 544,171.96 2.12 8,422.29 3_MWD+IFR2+MS+Sag (4)
10,487.31 92.35 192.69 3,854.54 -8,517.23 -858.103,803.77 6,022,854.44 544,151.58 2.42 8,517.17 3_MWD+IFR2+MS+Sag (4)
10,582.56 92.78 192.94 3,850.27 -8,610.01 -879.203,799.50 6,022,761.54 544,131.04 0.52 8,612.30 3_MWD+IFR2+MS+Sag (4)
10,678.27 91.48 192.25 3,846.72 -8,703.35 -900.063,795.95 6,022,668.09 544,110.75 1.54 8,707.92 3_MWD+IFR2+MS+Sag (4)
10,773.37 92.17 192.83 3,843.69 -8,796.13 -920.703,792.92 6,022,575.19 544,090.68 0.95 8,802.96 3_MWD+IFR2+MS+Sag (4)
10,867.85 91.30 192.54 3,840.83 -8,888.26 -941.433,790.06 6,022,482.94 544,070.50 0.97 8,897.37 3_MWD+IFR2+MS+Sag (4)
10,962.91 90.68 189.15 3,839.18 -8,981.60 -959.313,788.41 6,022,389.51 544,053.19 3.62 8,992.40 3_MWD+IFR2+MS+Sag (4)
11,057.95 92.41 190.01 3,836.62 -9,075.28 -975.123,785.85 6,022,295.75 544,037.94 2.03 9,087.35 3_MWD+IFR2+MS+Sag (4)
11,153.32 92.66 190.03 3,832.40 -9,169.10 -991.703,781.63 6,022,201.84 544,021.94 0.26 9,182.59 3_MWD+IFR2+MS+Sag (4)
11,249.31 93.03 191.98 3,827.64 -9,263.20 -1,010.003,776.87 6,022,107.63 544,004.21 2.07 9,278.45 3_MWD+IFR2+MS+Sag (4)
11,345.03 90.62 190.13 3,824.59 -9,357.09 -1,028.343,773.82 6,022,013.65 543,986.43 3.17 9,374.11 3_MWD+IFR2+MS+Sag (4)
11,440.24 90.25 188.15 3,823.87 -9,451.08 -1,043.473,773.10 6,021,919.57 543,971.88 2.12 9,469.23 3_MWD+IFR2+MS+Sag (4)
11,534.47 90.87 188.59 3,822.95 -9,544.30 -1,057.183,772.18 6,021,826.28 543,958.73 0.81 9,563.31 3_MWD+IFR2+MS+Sag (4)
11,629.97 91.67 188.34 3,820.83 -9,638.74 -1,071.243,770.06 6,021,731.77 543,945.25 0.88 9,658.66 3_MWD+IFR2+MS+Sag (4)
11,725.31 91.42 188.52 3,818.26 -9,733.01 -1,085.213,767.49 6,021,637.42 543,931.85 0.32 9,753.82 3_MWD+IFR2+MS+Sag (4)
11,820.26 90.68 190.98 3,816.52 -9,826.57 -1,101.283,765.75 6,021,543.78 543,916.34 2.71 9,848.70 3_MWD+IFR2+MS+Sag (4)
11,915.39 89.88 190.54 3,816.05 -9,920.02 -1,119.043,765.28 6,021,450.23 543,899.15 0.96 9,943.82 3_MWD+IFR2+MS+Sag (4)
12,010.34 91.18 190.61 3,815.18 -10,013.36 -1,136.473,764.41 6,021,356.80 543,882.29 1.37 10,038.76 3_MWD+IFR2+MS+Sag (4)
12,106.00 90.50 191.19 3,813.77 -10,107.28 -1,154.563,763.00 6,021,262.78 543,864.77 0.93 10,134.40 3_MWD+IFR2+MS+Sag (4)
6/26/2020 11:30:34AM COMPASS 5000.15 Build 91E Page 5
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
12,200.85 90.50 192.12 3,812.95 -10,200.17 -1,173.723,762.18 6,021,169.79 543,846.18 0.98 10,229.24 3_MWD+IFR2+MS+Sag (4)
12,294.39 90.74 192.31 3,811.93 -10,291.58 -1,193.513,761.16 6,021,078.26 543,826.94 0.33 10,322.77 3_MWD+IFR2+MS+Sag (4)
12,390.20 90.06 189.64 3,811.27 -10,385.63 -1,211.743,760.50 6,020,984.12 543,809.28 2.88 10,418.57 3_MWD+IFR2+MS+Sag (4)
12,486.70 90.19 189.68 3,811.05 -10,480.76 -1,227.943,760.28 6,020,888.90 543,793.66 0.14 10,515.01 3_MWD+IFR2+MS+Sag (4)
12,582.21 91.55 191.14 3,809.60 -10,574.69 -1,245.193,758.83 6,020,794.88 543,776.98 2.09 10,610.49 3_MWD+IFR2+MS+Sag (4)
12,676.90 91.73 190.04 3,806.89 -10,667.72 -1,262.593,756.12 6,020,701.75 543,760.15 1.18 10,705.13 3_MWD+IFR2+MS+Sag (4)
12,772.90 90.93 187.50 3,804.67 -10,762.57 -1,277.223,753.90 6,020,606.83 543,746.09 2.77 10,800.98 3_MWD+IFR2+MS+Sag (4)
12,868.04 90.81 186.86 3,803.22 -10,856.95 -1,289.113,752.45 6,020,512.38 543,734.77 0.68 10,895.84 3_MWD+IFR2+MS+Sag (4)
12,962.56 91.79 187.12 3,801.08 -10,950.74 -1,300.613,750.31 6,020,418.53 543,723.84 1.07 10,990.04 3_MWD+IFR2+MS+Sag (4)
13,058.13 90.06 190.14 3,799.53 -11,045.20 -1,314.943,748.76 6,020,324.00 543,710.08 3.64 11,085.46 3_MWD+IFR2+MS+Sag (4)
13,081.34 90.56 190.81 3,799.41 -11,068.02 -1,319.163,748.64 6,020,301.15 543,706.00 3.60 11,108.67 3_MWD+IFR2+MS+Sag (4)
13,150.00 90.56 190.81 3,798.74 -11,135.46 -1,332.043,747.97 6,020,233.64 543,693.53 0.00 11,177.32 PROJECTED to TD
Approved By:Checked By:Date:
6/26/2020 11:30:34AM COMPASS 5000.15 Build 91E Page 6
Chelsea Wright Digitally signed by Chelsea Wright
Date: 2020.06.26 08:33:10 -08'00'Benjamin Hand Digitally signed by Benjamin Hand
Date: 2020.06.26 08:40:44 -08'00'
24 June, 2020
Milne Point
M Pt L Pad
MPU L-60PB1
500292367870
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB1 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB1 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Milne Point, ACT, MILNE POINT
Alaska Zone 04
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
usft
+E/-W
+N/-S
Position Uncertainty
usft
usft
usftGround Level:
MPU L-60
usft
usft
0.00
0.00
6,031,375.87
544,958.07
16.60Wellhead Elevation:17.00 usft0.50
70° 29' 47.712 N
149° 37' 56.519 W
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
MPU L-60PB1
Model NameMagnetics
IFR 6/25/2020 15.98 80.92 57,375.00000000
Phase:Version:
Audit Notes:
Design MPU L-60PB1
1.0 ACTUAL
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:33.77
191.510.000.0033.77
From
(usft)
Survey Program
DescriptionTool NameSurvey (Wellbore)
To
(usft)
Date 6/20/2020
Survey Date
3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing100.00 634.00 MPU L-60PB1 E-Line Gyro (MPU L-60PB 06/02/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa698.08 6,800.39 MPU L-60PB1 MWD+IFR2+MS+Sag (1) 06/05/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,872.52 8,301.40 MPU L-60PB1 MWD+IFR2+MS+Sag (2) 06/12/2020
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
33.77 0.00 0.00 33.77 0.00 0.00-17.00 6,031,375.87 544,958.07 0.00 0.00 UNDEFINED
100.00 0.38 77.11 100.00 0.05 0.2149.23 6,031,375.92 544,958.28 0.57 -0.09 3_Gyro-GC_Csg (1)
166.00 0.42 73.38 166.00 0.17 0.66115.23 6,031,376.04 544,958.73 0.07 -0.30 3_Gyro-GC_Csg (1)
260.00 0.64 127.56 259.99 -0.05 1.41209.22 6,031,375.82 544,959.48 0.55 -0.23 3_Gyro-GC_Csg (1)
353.00 3.65 156.88 352.92 -3.09 2.98302.15 6,031,372.79 544,961.07 3.34 2.44 3_Gyro-GC_Csg (1)
447.00 5.42 167.49 446.62 -10.18 5.12395.85 6,031,365.72 544,963.25 2.08 8.96 3_Gyro-GC_Csg (1)
540.00 5.99 173.71 539.16 -19.29 6.60488.39 6,031,356.62 544,964.79 0.90 17.59 3_Gyro-GC_Csg (1)
634.00 9.61 178.61 632.28 -32.02 7.33581.51 6,031,343.90 544,965.59 3.91 29.91 3_Gyro-GC_Csg (1)
698.08 13.20 183.37 695.08 -44.67 7.03644.31 6,031,331.25 544,965.37 5.79 42.37 3_MWD+IFR2+MS+Sag (2)
794.57 17.61 191.41 788.10 -69.99 3.49737.33 6,031,305.91 544,961.98 5.07 67.89 3_MWD+IFR2+MS+Sag (2)
888.90 22.54 181.62 876.69 -102.08 0.15825.92 6,031,273.80 544,958.84 6.31 100.00 3_MWD+IFR2+MS+Sag (2)
983.85 26.66 178.74 963.01 -141.59 0.11912.24 6,031,234.30 544,959.03 4.52 138.72 3_MWD+IFR2+MS+Sag (2)
6/24/2020 5:41:24PM COMPASS 5000.15 Build 91E Page 2
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB1 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB1 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
1,079.96 30.55 180.36 1,047.37 -187.59 0.43996.60 6,031,188.31 544,959.63 4.13 183.73 3_MWD+IFR2+MS+Sag (2)
1,175.04 34.96 178.80 1,127.32 -239.01 0.851,076.55 6,031,136.89 544,960.36 4.72 234.04 3_MWD+IFR2+MS+Sag (2)
1,270.65 37.37 179.10 1,204.50 -295.42 1.881,153.73 6,031,080.50 544,961.73 2.53 289.10 3_MWD+IFR2+MS+Sag (2)
1,364.86 40.21 179.20 1,277.92 -354.43 2.751,227.15 6,031,021.50 544,962.96 3.02 346.75 3_MWD+IFR2+MS+Sag (2)
1,460.15 42.70 178.84 1,349.33 -417.50 3.831,298.56 6,030,958.45 544,964.43 2.63 408.34 3_MWD+IFR2+MS+Sag (2)
1,555.42 46.52 178.04 1,417.15 -484.36 5.671,366.38 6,030,891.60 544,966.67 4.05 473.49 3_MWD+IFR2+MS+Sag (2)
1,650.79 48.88 177.13 1,481.33 -554.83 8.651,430.56 6,030,821.15 544,970.08 2.57 541.95 3_MWD+IFR2+MS+Sag (2)
1,743.54 52.60 177.37 1,540.01 -626.55 12.091,489.24 6,030,749.46 544,973.95 4.02 611.54 3_MWD+IFR2+MS+Sag (2)
1,840.35 55.15 177.68 1,597.08 -704.67 15.471,546.31 6,030,671.38 544,977.80 2.65 687.41 3_MWD+IFR2+MS+Sag (2)
1,934.99 55.02 178.02 1,651.25 -782.22 18.381,600.48 6,030,593.85 544,981.18 0.33 762.82 3_MWD+IFR2+MS+Sag (2)
2,031.00 54.89 178.37 1,706.38 -860.78 20.851,655.61 6,030,515.31 544,984.13 0.33 839.31 3_MWD+IFR2+MS+Sag (2)
2,126.38 53.27 176.81 1,762.34 -937.95 24.091,711.57 6,030,438.17 544,987.83 2.15 914.28 3_MWD+IFR2+MS+Sag (2)
2,221.81 53.29 178.13 1,819.40 -1,014.37 27.471,768.63 6,030,361.79 544,991.67 1.11 988.49 3_MWD+IFR2+MS+Sag (2)
2,316.92 57.09 179.23 1,873.68 -1,092.42 29.251,822.91 6,030,283.75 544,993.92 4.11 1,064.62 3_MWD+IFR2+MS+Sag (2)
2,411.67 55.80 180.25 1,926.05 -1,171.38 29.611,875.28 6,030,204.81 544,994.76 1.63 1,141.91 3_MWD+IFR2+MS+Sag (2)
2,507.29 55.09 180.87 1,980.29 -1,250.12 28.851,929.52 6,030,126.07 544,994.47 0.91 1,219.23 3_MWD+IFR2+MS+Sag (2)
2,603.36 56.56 177.49 2,034.26 -1,329.57 30.001,983.49 6,030,046.63 544,996.11 3.29 1,296.85 3_MWD+IFR2+MS+Sag (2)
2,697.92 53.69 175.94 2,088.33 -1,407.01 34.432,037.56 6,029,969.23 545,001.00 3.32 1,371.85 3_MWD+IFR2+MS+Sag (2)
2,793.54 53.91 176.65 2,144.80 -1,484.01 39.412,094.03 6,029,892.27 545,006.45 0.64 1,446.30 3_MWD+IFR2+MS+Sag (2)
2,888.47 54.00 177.21 2,200.66 -1,560.66 43.532,149.89 6,029,815.66 545,011.03 0.49 1,520.59 3_MWD+IFR2+MS+Sag (2)
2,983.50 54.99 177.93 2,255.85 -1,637.95 46.802,205.08 6,029,738.40 545,014.77 1.21 1,595.67 3_MWD+IFR2+MS+Sag (2)
3,079.17 52.69 177.07 2,312.30 -1,715.11 50.162,261.53 6,029,661.26 545,018.60 2.51 1,670.61 3_MWD+IFR2+MS+Sag (2)
3,174.56 52.82 177.85 2,370.03 -1,790.97 53.532,319.26 6,029,585.43 545,022.42 0.67 1,744.27 3_MWD+IFR2+MS+Sag (2)
3,269.72 52.68 178.22 2,427.63 -1,866.67 56.122,376.86 6,029,509.75 545,025.48 0.34 1,817.93 3_MWD+IFR2+MS+Sag (2)
3,364.29 52.68 179.32 2,484.97 -1,941.86 57.742,434.20 6,029,434.58 545,027.55 0.93 1,891.29 3_MWD+IFR2+MS+Sag (2)
3,458.77 52.51 179.57 2,542.36 -2,016.91 58.472,491.59 6,029,359.55 545,028.73 0.28 1,964.68 3_MWD+IFR2+MS+Sag (2)
3,554.71 52.51 180.16 2,600.75 -2,093.03 58.652,549.98 6,029,283.44 545,029.37 0.49 2,039.24 3_MWD+IFR2+MS+Sag (2)
3,649.98 52.61 180.98 2,658.67 -2,168.67 57.892,607.90 6,029,207.80 545,029.07 0.69 2,113.51 3_MWD+IFR2+MS+Sag (2)
3,745.44 53.69 181.13 2,715.92 -2,245.04 56.492,665.15 6,029,131.43 545,028.13 1.14 2,188.63 3_MWD+IFR2+MS+Sag (2)
3,840.84 54.52 178.98 2,771.85 -2,322.32 56.422,721.08 6,029,054.16 545,028.53 2.02 2,264.36 3_MWD+IFR2+MS+Sag (2)
3,935.17 54.68 180.08 2,826.50 -2,399.21 57.052,775.73 6,028,977.29 545,029.62 0.97 2,339.57 3_MWD+IFR2+MS+Sag (2)
4,030.90 54.61 175.90 2,881.91 -2,477.20 59.792,831.14 6,028,899.31 545,032.83 3.56 2,415.46 3_MWD+IFR2+MS+Sag (2)
4,125.94 54.60 175.47 2,936.96 -2,554.46 65.612,886.19 6,028,822.10 545,039.13 0.37 2,490.00 3_MWD+IFR2+MS+Sag (2)
4,221.12 52.58 176.24 2,993.45 -2,630.85 71.162,942.68 6,028,745.75 545,045.13 2.22 2,563.75 3_MWD+IFR2+MS+Sag (2)
4,316.52 52.77 176.55 3,051.29 -2,706.57 75.933,000.52 6,028,670.08 545,050.36 0.33 2,636.99 3_MWD+IFR2+MS+Sag (2)
4,411.39 54.24 176.78 3,107.72 -2,782.70 80.363,056.95 6,028,593.98 545,055.25 1.56 2,710.71 3_MWD+IFR2+MS+Sag (2)
4,506.35 51.96 176.72 3,164.73 -2,858.51 84.673,113.96 6,028,518.20 545,060.01 2.40 2,784.13 3_MWD+IFR2+MS+Sag (2)
4,602.01 51.60 177.71 3,223.91 -2,933.58 88.323,173.14 6,028,443.17 545,064.12 0.90 2,856.96 3_MWD+IFR2+MS+Sag (2)
4,697.12 54.33 178.55 3,281.19 -3,009.45 90.793,230.42 6,028,367.32 545,067.05 2.96 2,930.81 3_MWD+IFR2+MS+Sag (2)
4,792.82 54.71 179.27 3,336.74 -3,087.37 92.273,285.97 6,028,289.42 545,069.00 0.73 3,006.87 3_MWD+IFR2+MS+Sag (2)
6/24/2020 5:41:24PM COMPASS 5000.15 Build 91E Page 3
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB1 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB1 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
4,887.60 53.14 178.17 3,392.55 -3,163.95 93.973,341.78 6,028,212.86 545,071.17 1.90 3,081.57 3_MWD+IFR2+MS+Sag (2)
4,982.84 53.23 178.81 3,449.62 -3,240.17 95.983,398.85 6,028,136.66 545,073.64 0.55 3,155.86 3_MWD+IFR2+MS+Sag (2)
5,077.61 54.54 178.91 3,505.48 -3,316.71 97.503,454.71 6,028,060.13 545,075.62 1.38 3,230.55 3_MWD+IFR2+MS+Sag (2)
5,173.58 54.06 179.82 3,561.48 -3,394.64 98.373,510.71 6,027,982.22 545,076.96 0.92 3,306.74 3_MWD+IFR2+MS+Sag (2)
5,268.22 53.86 179.77 3,617.16 -3,471.16 98.643,566.39 6,027,905.70 545,077.69 0.22 3,381.68 3_MWD+IFR2+MS+Sag (2)
5,364.17 60.08 181.10 3,669.44 -3,551.56 98.003,618.67 6,027,825.31 545,077.54 6.59 3,460.59 3_MWD+IFR2+MS+Sag (2)
5,459.22 60.62 181.05 3,716.46 -3,634.15 96.453,665.69 6,027,742.72 545,076.49 0.57 3,541.82 3_MWD+IFR2+MS+Sag (2)
5,554.68 61.21 182.68 3,762.86 -3,717.53 93.733,712.09 6,027,659.34 545,074.27 1.62 3,624.06 3_MWD+IFR2+MS+Sag (2)
5,649.60 63.83 184.38 3,806.66 -3,801.56 88.533,755.89 6,027,575.28 545,069.58 3.18 3,707.45 3_MWD+IFR2+MS+Sag (2)
5,744.95 66.70 187.03 3,846.56 -3,887.72 79.903,795.79 6,027,489.09 545,061.48 3.93 3,793.59 3_MWD+IFR2+MS+Sag (2)
5,840.36 71.54 188.97 3,880.56 -3,975.96 67.483,829.79 6,027,400.78 545,049.58 5.42 3,882.54 3_MWD+IFR2+MS+Sag (2)
5,935.36 75.85 189.68 3,907.22 -4,065.91 52.703,856.45 6,027,310.75 545,035.35 4.59 3,973.63 3_MWD+IFR2+MS+Sag (2)
6,030.62 81.09 189.73 3,926.26 -4,157.88 36.973,875.49 6,027,218.70 545,020.18 5.50 4,066.89 3_MWD+IFR2+MS+Sag (2)
6,125.82 84.57 190.55 3,938.14 -4,250.84 20.343,887.37 6,027,125.64 545,004.12 3.75 4,161.30 3_MWD+IFR2+MS+Sag (2)
6,221.25 85.99 191.54 3,945.99 -4,344.18 2.123,895.22 6,027,032.20 544,986.46 1.81 4,256.40 3_MWD+IFR2+MS+Sag (2)
6,316.31 85.87 190.77 3,952.74 -4,437.21 -16.223,901.97 6,026,939.07 544,968.68 0.82 4,351.22 3_MWD+IFR2+MS+Sag (2)
6,411.30 86.67 190.94 3,958.92 -4,530.30 -34.073,908.15 6,026,845.89 544,951.40 0.86 4,446.00 3_MWD+IFR2+MS+Sag (2)
6,506.87 86.49 191.30 3,964.62 -4,623.91 -52.473,913.85 6,026,752.18 544,933.57 0.42 4,541.40 3_MWD+IFR2+MS+Sag (2)
6,602.06 88.03 192.31 3,969.17 -4,716.98 -71.923,918.40 6,026,659.00 544,914.68 1.93 4,636.47 3_MWD+IFR2+MS+Sag (2)
6,695.79 92.05 192.74 3,969.10 -4,808.46 -92.253,918.33 6,026,567.41 544,894.91 4.31 4,730.17 3_MWD+IFR2+MS+Sag (2)
6,791.44 89.82 189.90 3,967.54 -4,902.22 -111.023,916.77 6,026,473.55 544,876.71 3.77 4,825.79 3_MWD+IFR2+MS+Sag (2)
6,800.39 89.70 189.74 3,967.58 -4,911.04 -112.543,916.81 6,026,464.72 544,875.24 2.23 4,834.73 3_MWD+IFR2+MS+Sag (2)
6,872.52 90.74 190.38 3,967.30 -4,982.06 -125.143,916.53 6,026,393.63 544,863.07 1.69 4,906.84 3_MWD+IFR2+MS+Sag (3)
6,968.50 90.99 191.35 3,965.86 -5,076.31 -143.233,915.09 6,026,299.29 544,845.56 1.04 5,002.80 3_MWD+IFR2+MS+Sag (3)
7,064.13 93.77 193.08 3,961.88 -5,169.68 -163.443,911.11 6,026,205.80 544,825.91 3.42 5,098.33 3_MWD+IFR2+MS+Sag (3)
7,158.78 93.65 192.57 3,955.76 -5,261.77 -184.413,904.99 6,026,113.59 544,805.50 0.55 5,192.75 3_MWD+IFR2+MS+Sag (3)
7,254.38 90.68 191.57 3,952.15 -5,355.18 -204.383,901.38 6,026,020.07 544,786.10 3.28 5,288.27 3_MWD+IFR2+MS+Sag (3)
7,349.77 90.81 192.53 3,950.91 -5,448.46 -224.293,900.14 6,025,926.69 544,766.75 1.02 5,383.65 3_MWD+IFR2+MS+Sag (3)
7,445.00 90.62 193.16 3,949.72 -5,541.30 -245.463,898.95 6,025,833.73 544,746.15 0.69 5,478.84 3_MWD+IFR2+MS+Sag (3)
7,539.33 90.68 191.21 3,948.65 -5,633.49 -265.373,897.88 6,025,741.42 544,726.80 2.07 5,573.16 3_MWD+IFR2+MS+Sag (3)
7,634.60 89.45 189.99 3,948.54 -5,727.13 -282.903,897.77 6,025,647.69 544,709.84 1.82 5,668.41 3_MWD+IFR2+MS+Sag (3)
7,729.13 88.95 190.12 3,949.86 -5,820.20 -299.403,899.09 6,025,554.53 544,693.91 0.55 5,762.90 3_MWD+IFR2+MS+Sag (3)
7,825.35 90.44 191.53 3,950.37 -5,914.70 -317.473,899.60 6,025,459.93 544,676.41 2.13 5,859.11 3_MWD+IFR2+MS+Sag (3)
7,920.45 90.87 191.59 3,949.29 -6,007.87 -336.523,898.52 6,025,366.66 544,657.92 0.46 5,954.20 3_MWD+IFR2+MS+Sag (3)
8,015.66 88.46 191.21 3,949.84 -6,101.19 -355.343,899.07 6,025,273.24 544,639.67 2.56 6,049.40 3_MWD+IFR2+MS+Sag (3)
8,111.17 85.98 191.14 3,954.48 -6,194.77 -373.833,903.71 6,025,179.55 544,621.75 2.60 6,144.79 3_MWD+IFR2+MS+Sag (3)
8,206.75 86.48 192.08 3,960.76 -6,288.19 -393.023,909.99 6,025,086.03 544,603.12 1.11 6,240.16 3_MWD+IFR2+MS+Sag (3)
8,301.40 84.13 191.61 3,968.51 -6,380.51 -412.383,917.74 6,024,993.60 544,584.32 2.53 6,334.49 3_MWD+IFR2+MS+Sag (3)
8,372.00 84.13 191.61 3,975.73 -6,449.30 -426.523,924.96 6,024,924.73 544,570.60 0.00 6,404.71 PROJECTED to TD
6/24/2020 5:41:24PM COMPASS 5000.15 Build 91E Page 4
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB1 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB1 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
Approved By:Checked By:Date:
6/24/2020 5:41:24PM COMPASS 5000.15 Build 91E Page 5
Chelsea Wright Digitally signed by Chelsea Wright
Date: 2020.06.24 14:49:09 -08'00'Benjamin Hand Digitally signed by Benjamin Hand
Date: 2020.06.26 08:34:17 -08'00'
24 June, 2020
Milne Point
M Pt L Pad
MPU L-60PB2
500292367871
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB2 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB2 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Milne Point, ACT, MILNE POINT
Alaska Zone 04
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
usft
+E/-W
+N/-S
Position Uncertainty
usft
usft
usftGround Level:
MPU L-60
usft
usft
0.00
0.00
6,031,375.87
544,958.07
16.60Wellhead Elevation:17.00 usft0.50
70° 29' 47.712 N
149° 37' 56.519 W
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
MPU L-60PB2
Model NameMagnetics
IFR 6/25/2020 15.98 80.92 57,375.00000000
Phase:Version:
Audit Notes:
Design MPU L-60PB2
1.0 ACTUAL
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:7,445.00
191.510.000.0033.77
From
(usft)
Survey Program
DescriptionTool NameSurvey (Wellbore)
To
(usft)
Date 6/20/2020
Survey Date
3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing100.00 634.00 MPU L-60PB1 E-Line Gyro (MPU L-60PB 06/02/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa698.08 6,800.39 MPU L-60PB1 MWD+IFR2+MS+Sag (1) 06/05/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,872.52 7,445.00 MPU L-60PB1 MWD+IFR2+MS+Sag (2) 06/12/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa7,510.00 11,727.69 MPU L-60PB2 MWD+IFR2+MS+Sag (3) 06/12/2020
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
33.77 0.00 0.00 33.77 0.00 0.00-17.00 6,031,375.87 544,958.07 0.00 0.00 UNDEFINED
100.00 0.38 77.11 100.00 0.05 0.2149.23 6,031,375.92 544,958.28 0.57 -0.09 3_Gyro-GC_Csg (1)
166.00 0.42 73.38 166.00 0.17 0.66115.23 6,031,376.04 544,958.73 0.07 -0.30 3_Gyro-GC_Csg (1)
260.00 0.64 127.56 259.99 -0.05 1.41209.22 6,031,375.82 544,959.48 0.55 -0.23 3_Gyro-GC_Csg (1)
353.00 3.65 156.88 352.92 -3.09 2.98302.15 6,031,372.79 544,961.07 3.34 2.44 3_Gyro-GC_Csg (1)
447.00 5.42 167.49 446.62 -10.18 5.12395.85 6,031,365.72 544,963.25 2.08 8.96 3_Gyro-GC_Csg (1)
540.00 5.99 173.71 539.16 -19.29 6.60488.39 6,031,356.62 544,964.79 0.90 17.59 3_Gyro-GC_Csg (1)
634.00 9.61 178.61 632.28 -32.02 7.33581.51 6,031,343.90 544,965.59 3.91 29.91 3_Gyro-GC_Csg (1)
698.08 13.20 183.37 695.08 -44.67 7.03644.31 6,031,331.25 544,965.37 5.79 42.37 3_MWD+IFR2+MS+Sag (2)
794.57 17.61 191.41 788.10 -69.99 3.49737.33 6,031,305.91 544,961.98 5.07 67.89 3_MWD+IFR2+MS+Sag (2)
888.90 22.54 181.62 876.69 -102.08 0.15825.92 6,031,273.80 544,958.84 6.31 100.00 3_MWD+IFR2+MS+Sag (2)
6/24/2020 5:41:58PM COMPASS 5000.15 Build 91E Page 2
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB2 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB2 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
983.85 26.66 178.74 963.01 -141.59 0.11912.24 6,031,234.30 544,959.03 4.52 138.72 3_MWD+IFR2+MS+Sag (2)
1,079.96 30.55 180.36 1,047.37 -187.59 0.43996.60 6,031,188.31 544,959.63 4.13 183.73 3_MWD+IFR2+MS+Sag (2)
1,175.04 34.96 178.80 1,127.32 -239.01 0.851,076.55 6,031,136.89 544,960.36 4.72 234.04 3_MWD+IFR2+MS+Sag (2)
1,270.65 37.37 179.10 1,204.50 -295.42 1.881,153.73 6,031,080.50 544,961.73 2.53 289.10 3_MWD+IFR2+MS+Sag (2)
1,364.86 40.21 179.20 1,277.92 -354.43 2.751,227.15 6,031,021.50 544,962.96 3.02 346.75 3_MWD+IFR2+MS+Sag (2)
1,460.15 42.70 178.84 1,349.33 -417.50 3.831,298.56 6,030,958.45 544,964.43 2.63 408.34 3_MWD+IFR2+MS+Sag (2)
1,555.42 46.52 178.04 1,417.15 -484.36 5.671,366.38 6,030,891.60 544,966.67 4.05 473.49 3_MWD+IFR2+MS+Sag (2)
1,650.79 48.88 177.13 1,481.33 -554.83 8.651,430.56 6,030,821.15 544,970.08 2.57 541.95 3_MWD+IFR2+MS+Sag (2)
1,743.54 52.60 177.37 1,540.01 -626.55 12.091,489.24 6,030,749.46 544,973.95 4.02 611.54 3_MWD+IFR2+MS+Sag (2)
1,840.35 55.15 177.68 1,597.08 -704.67 15.471,546.31 6,030,671.38 544,977.80 2.65 687.41 3_MWD+IFR2+MS+Sag (2)
1,934.99 55.02 178.02 1,651.25 -782.22 18.381,600.48 6,030,593.85 544,981.18 0.33 762.82 3_MWD+IFR2+MS+Sag (2)
2,031.00 54.89 178.37 1,706.38 -860.78 20.851,655.61 6,030,515.31 544,984.13 0.33 839.31 3_MWD+IFR2+MS+Sag (2)
2,126.38 53.27 176.81 1,762.34 -937.95 24.091,711.57 6,030,438.17 544,987.83 2.15 914.28 3_MWD+IFR2+MS+Sag (2)
2,221.81 53.29 178.13 1,819.40 -1,014.37 27.471,768.63 6,030,361.79 544,991.67 1.11 988.49 3_MWD+IFR2+MS+Sag (2)
2,316.92 57.09 179.23 1,873.68 -1,092.42 29.251,822.91 6,030,283.75 544,993.92 4.11 1,064.62 3_MWD+IFR2+MS+Sag (2)
2,411.67 55.80 180.25 1,926.05 -1,171.38 29.611,875.28 6,030,204.81 544,994.76 1.63 1,141.91 3_MWD+IFR2+MS+Sag (2)
2,507.29 55.09 180.87 1,980.29 -1,250.12 28.851,929.52 6,030,126.07 544,994.47 0.91 1,219.23 3_MWD+IFR2+MS+Sag (2)
2,603.36 56.56 177.49 2,034.26 -1,329.57 30.001,983.49 6,030,046.63 544,996.11 3.29 1,296.85 3_MWD+IFR2+MS+Sag (2)
2,697.92 53.69 175.94 2,088.33 -1,407.01 34.432,037.56 6,029,969.23 545,001.00 3.32 1,371.85 3_MWD+IFR2+MS+Sag (2)
2,793.54 53.91 176.65 2,144.80 -1,484.01 39.412,094.03 6,029,892.27 545,006.45 0.64 1,446.30 3_MWD+IFR2+MS+Sag (2)
2,888.47 54.00 177.21 2,200.66 -1,560.66 43.532,149.89 6,029,815.66 545,011.03 0.49 1,520.59 3_MWD+IFR2+MS+Sag (2)
2,983.50 54.99 177.93 2,255.85 -1,637.95 46.802,205.08 6,029,738.40 545,014.77 1.21 1,595.67 3_MWD+IFR2+MS+Sag (2)
3,079.17 52.69 177.07 2,312.30 -1,715.11 50.162,261.53 6,029,661.26 545,018.60 2.51 1,670.61 3_MWD+IFR2+MS+Sag (2)
3,174.56 52.82 177.85 2,370.03 -1,790.97 53.532,319.26 6,029,585.43 545,022.42 0.67 1,744.27 3_MWD+IFR2+MS+Sag (2)
3,269.72 52.68 178.22 2,427.63 -1,866.67 56.122,376.86 6,029,509.75 545,025.48 0.34 1,817.93 3_MWD+IFR2+MS+Sag (2)
3,364.29 52.68 179.32 2,484.97 -1,941.86 57.742,434.20 6,029,434.58 545,027.55 0.93 1,891.29 3_MWD+IFR2+MS+Sag (2)
3,458.77 52.51 179.57 2,542.36 -2,016.91 58.472,491.59 6,029,359.55 545,028.73 0.28 1,964.68 3_MWD+IFR2+MS+Sag (2)
3,554.71 52.51 180.16 2,600.75 -2,093.03 58.652,549.98 6,029,283.44 545,029.37 0.49 2,039.24 3_MWD+IFR2+MS+Sag (2)
3,649.98 52.61 180.98 2,658.67 -2,168.67 57.892,607.90 6,029,207.80 545,029.07 0.69 2,113.51 3_MWD+IFR2+MS+Sag (2)
3,745.44 53.69 181.13 2,715.92 -2,245.04 56.492,665.15 6,029,131.43 545,028.13 1.14 2,188.63 3_MWD+IFR2+MS+Sag (2)
3,840.84 54.52 178.98 2,771.85 -2,322.32 56.422,721.08 6,029,054.16 545,028.53 2.02 2,264.36 3_MWD+IFR2+MS+Sag (2)
3,935.17 54.68 180.08 2,826.50 -2,399.21 57.052,775.73 6,028,977.29 545,029.62 0.97 2,339.57 3_MWD+IFR2+MS+Sag (2)
4,030.90 54.61 175.90 2,881.91 -2,477.20 59.792,831.14 6,028,899.31 545,032.83 3.56 2,415.46 3_MWD+IFR2+MS+Sag (2)
4,125.94 54.60 175.47 2,936.96 -2,554.46 65.612,886.19 6,028,822.10 545,039.13 0.37 2,490.00 3_MWD+IFR2+MS+Sag (2)
4,221.12 52.58 176.24 2,993.45 -2,630.85 71.162,942.68 6,028,745.75 545,045.13 2.22 2,563.75 3_MWD+IFR2+MS+Sag (2)
4,316.52 52.77 176.55 3,051.29 -2,706.57 75.933,000.52 6,028,670.08 545,050.36 0.33 2,636.99 3_MWD+IFR2+MS+Sag (2)
4,411.39 54.24 176.78 3,107.72 -2,782.70 80.363,056.95 6,028,593.98 545,055.25 1.56 2,710.71 3_MWD+IFR2+MS+Sag (2)
4,506.35 51.96 176.72 3,164.73 -2,858.51 84.673,113.96 6,028,518.20 545,060.01 2.40 2,784.13 3_MWD+IFR2+MS+Sag (2)
4,602.01 51.60 177.71 3,223.91 -2,933.58 88.323,173.14 6,028,443.17 545,064.12 0.90 2,856.96 3_MWD+IFR2+MS+Sag (2)
4,697.12 54.33 178.55 3,281.19 -3,009.45 90.793,230.42 6,028,367.32 545,067.05 2.96 2,930.81 3_MWD+IFR2+MS+Sag (2)
6/24/2020 5:41:58PM COMPASS 5000.15 Build 91E Page 3
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB2 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB2 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
4,792.82 54.71 179.27 3,336.74 -3,087.37 92.273,285.97 6,028,289.42 545,069.00 0.73 3,006.87 3_MWD+IFR2+MS+Sag (2)
4,887.60 53.14 178.17 3,392.55 -3,163.95 93.973,341.78 6,028,212.86 545,071.17 1.90 3,081.57 3_MWD+IFR2+MS+Sag (2)
4,982.84 53.23 178.81 3,449.62 -3,240.17 95.983,398.85 6,028,136.66 545,073.64 0.55 3,155.86 3_MWD+IFR2+MS+Sag (2)
5,077.61 54.54 178.91 3,505.48 -3,316.71 97.503,454.71 6,028,060.13 545,075.62 1.38 3,230.55 3_MWD+IFR2+MS+Sag (2)
5,173.58 54.06 179.82 3,561.48 -3,394.64 98.373,510.71 6,027,982.22 545,076.96 0.92 3,306.74 3_MWD+IFR2+MS+Sag (2)
5,268.22 53.86 179.77 3,617.16 -3,471.16 98.643,566.39 6,027,905.70 545,077.69 0.22 3,381.68 3_MWD+IFR2+MS+Sag (2)
5,364.17 60.08 181.10 3,669.44 -3,551.56 98.003,618.67 6,027,825.31 545,077.54 6.59 3,460.59 3_MWD+IFR2+MS+Sag (2)
5,459.22 60.62 181.05 3,716.46 -3,634.15 96.453,665.69 6,027,742.72 545,076.49 0.57 3,541.82 3_MWD+IFR2+MS+Sag (2)
5,554.68 61.21 182.68 3,762.86 -3,717.53 93.733,712.09 6,027,659.34 545,074.27 1.62 3,624.06 3_MWD+IFR2+MS+Sag (2)
5,649.60 63.83 184.38 3,806.66 -3,801.56 88.533,755.89 6,027,575.28 545,069.58 3.18 3,707.45 3_MWD+IFR2+MS+Sag (2)
5,744.95 66.70 187.03 3,846.56 -3,887.72 79.903,795.79 6,027,489.09 545,061.48 3.93 3,793.59 3_MWD+IFR2+MS+Sag (2)
5,840.36 71.54 188.97 3,880.56 -3,975.96 67.483,829.79 6,027,400.78 545,049.58 5.42 3,882.54 3_MWD+IFR2+MS+Sag (2)
5,935.36 75.85 189.68 3,907.22 -4,065.91 52.703,856.45 6,027,310.75 545,035.35 4.59 3,973.63 3_MWD+IFR2+MS+Sag (2)
6,030.62 81.09 189.73 3,926.26 -4,157.88 36.973,875.49 6,027,218.70 545,020.18 5.50 4,066.89 3_MWD+IFR2+MS+Sag (2)
6,125.82 84.57 190.55 3,938.14 -4,250.84 20.343,887.37 6,027,125.64 545,004.12 3.75 4,161.30 3_MWD+IFR2+MS+Sag (2)
6,221.25 85.99 191.54 3,945.99 -4,344.18 2.123,895.22 6,027,032.20 544,986.46 1.81 4,256.40 3_MWD+IFR2+MS+Sag (2)
6,316.31 85.87 190.77 3,952.74 -4,437.21 -16.223,901.97 6,026,939.07 544,968.68 0.82 4,351.22 3_MWD+IFR2+MS+Sag (2)
6,411.30 86.67 190.94 3,958.92 -4,530.30 -34.073,908.15 6,026,845.89 544,951.40 0.86 4,446.00 3_MWD+IFR2+MS+Sag (2)
6,506.87 86.49 191.30 3,964.62 -4,623.91 -52.473,913.85 6,026,752.18 544,933.57 0.42 4,541.40 3_MWD+IFR2+MS+Sag (2)
6,602.06 88.03 192.31 3,969.17 -4,716.98 -71.923,918.40 6,026,659.00 544,914.68 1.93 4,636.47 3_MWD+IFR2+MS+Sag (2)
6,695.79 92.05 192.74 3,969.10 -4,808.46 -92.253,918.33 6,026,567.41 544,894.91 4.31 4,730.17 3_MWD+IFR2+MS+Sag (2)
6,791.44 89.82 189.90 3,967.54 -4,902.22 -111.023,916.77 6,026,473.55 544,876.71 3.77 4,825.79 3_MWD+IFR2+MS+Sag (2)
6,800.39 89.70 189.74 3,967.58 -4,911.04 -112.543,916.81 6,026,464.72 544,875.24 2.23 4,834.73 3_MWD+IFR2+MS+Sag (2)
6,872.52 90.74 190.38 3,967.30 -4,982.06 -125.143,916.53 6,026,393.63 544,863.07 1.69 4,906.84 3_MWD+IFR2+MS+Sag (3)
6,968.50 90.99 191.35 3,965.86 -5,076.31 -143.233,915.09 6,026,299.29 544,845.56 1.04 5,002.80 3_MWD+IFR2+MS+Sag (3)
7,064.13 93.77 193.08 3,961.88 -5,169.68 -163.443,911.11 6,026,205.80 544,825.91 3.42 5,098.33 3_MWD+IFR2+MS+Sag (3)
7,158.78 93.65 192.57 3,955.76 -5,261.77 -184.413,904.99 6,026,113.59 544,805.50 0.55 5,192.75 3_MWD+IFR2+MS+Sag (3)
7,254.38 90.68 191.57 3,952.15 -5,355.18 -204.383,901.38 6,026,020.07 544,786.10 3.28 5,288.27 3_MWD+IFR2+MS+Sag (3)
7,349.77 90.81 192.53 3,950.91 -5,448.46 -224.293,900.14 6,025,926.69 544,766.75 1.02 5,383.65 3_MWD+IFR2+MS+Sag (3)
7,445.00 90.62 193.16 3,949.72 -5,541.30 -245.463,898.95 6,025,833.73 544,746.15 0.69 5,478.84 3_MWD+IFR2+MS+Sag (3)
7,510.00 90.66 191.82 3,948.99 -5,604.76 -259.523,898.22 6,025,770.19 544,732.48 2.06 5,543.83 3_MWD+IFR2+MS+Sag (4)
7,539.68 88.65 192.52 3,949.17 -5,633.77 -265.783,898.40 6,025,741.15 544,726.40 7.17 5,573.50 3_MWD+IFR2+MS+Sag (4)
7,634.60 90.07 192.59 3,950.23 -5,726.41 -286.413,899.46 6,025,648.39 544,706.33 1.50 5,668.40 3_MWD+IFR2+MS+Sag (4)
7,729.69 93.09 191.74 3,947.61 -5,819.32 -306.443,896.84 6,025,555.38 544,686.86 3.30 5,763.44 3_MWD+IFR2+MS+Sag (4)
7,825.08 92.97 191.28 3,942.57 -5,912.66 -325.443,891.80 6,025,461.93 544,668.42 0.50 5,858.69 3_MWD+IFR2+MS+Sag (4)
7,920.45 92.53 191.65 3,937.99 -6,006.02 -344.383,887.22 6,025,368.47 544,650.05 0.60 5,953.95 3_MWD+IFR2+MS+Sag (4)
8,015.45 91.05 191.51 3,935.03 -6,099.03 -363.443,884.26 6,025,275.35 544,631.56 1.56 6,048.90 3_MWD+IFR2+MS+Sag (4)
8,110.85 89.26 190.43 3,934.77 -6,192.69 -381.593,884.00 6,025,181.59 544,613.97 2.19 6,144.29 3_MWD+IFR2+MS+Sag (4)
8,205.96 88.65 190.45 3,936.50 -6,286.21 -398.823,885.73 6,025,087.98 544,597.31 0.64 6,239.37 3_MWD+IFR2+MS+Sag (4)
8,301.82 91.92 192.51 3,936.03 -6,380.13 -417.903,885.26 6,024,993.95 544,578.81 4.03 6,335.21 3_MWD+IFR2+MS+Sag (4)
6/24/2020 5:41:58PM COMPASS 5000.15 Build 91E Page 4
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB2 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB2 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
8,397.06 92.11 193.51 3,932.68 -6,472.87 -439.323,881.91 6,024,901.10 544,557.94 1.07 6,430.36 3_MWD+IFR2+MS+Sag (4)
8,492.11 91.18 194.41 3,929.95 -6,565.07 -462.243,879.18 6,024,808.77 544,535.58 1.36 6,525.28 3_MWD+IFR2+MS+Sag (4)
8,587.64 92.54 195.07 3,926.85 -6,657.40 -486.543,876.08 6,024,716.30 544,511.85 1.58 6,620.60 3_MWD+IFR2+MS+Sag (4)
8,682.51 92.04 193.26 3,923.06 -6,749.31 -509.733,872.29 6,024,624.26 544,489.21 1.98 6,715.29 3_MWD+IFR2+MS+Sag (4)
8,777.47 91.92 191.35 3,919.78 -6,842.03 -529.963,869.01 6,024,531.43 544,469.55 2.01 6,810.18 3_MWD+IFR2+MS+Sag (4)
8,872.95 91.61 190.69 3,916.83 -6,935.70 -548.203,866.06 6,024,437.66 544,451.88 0.76 6,905.61 3_MWD+IFR2+MS+Sag (4)
8,968.39 92.54 191.10 3,913.38 -7,029.36 -566.233,862.61 6,024,343.90 544,434.42 1.06 7,000.98 3_MWD+IFR2+MS+Sag (4)
9,063.46 92.47 190.94 3,909.22 -7,122.59 -584.383,858.45 6,024,250.57 544,416.83 0.18 7,095.96 3_MWD+IFR2+MS+Sag (4)
9,158.58 92.72 190.46 3,904.92 -7,215.96 -602.023,854.15 6,024,157.11 544,399.76 0.57 7,190.97 3_MWD+IFR2+MS+Sag (4)
9,253.65 91.92 190.33 3,901.07 -7,309.39 -619.163,850.30 6,024,063.58 544,383.18 0.85 7,285.95 3_MWD+IFR2+MS+Sag (4)
9,348.29 93.03 190.01 3,896.98 -7,402.46 -635.863,846.21 6,023,970.43 544,367.05 1.22 7,380.47 3_MWD+IFR2+MS+Sag (4)
9,443.25 92.78 190.68 3,892.17 -7,495.75 -652.893,841.40 6,023,877.04 544,350.59 0.75 7,475.29 3_MWD+IFR2+MS+Sag (4)
9,538.58 92.66 190.09 3,887.65 -7,589.41 -670.053,836.88 6,023,783.28 544,333.99 0.63 7,570.49 3_MWD+IFR2+MS+Sag (4)
9,633.51 91.85 190.98 3,883.91 -7,682.67 -687.403,833.14 6,023,689.94 544,317.21 1.27 7,665.33 3_MWD+IFR2+MS+Sag (4)
9,728.03 92.48 191.98 3,880.34 -7,775.23 -706.203,829.57 6,023,597.27 544,298.98 1.25 7,759.78 3_MWD+IFR2+MS+Sag (4)
9,824.36 92.23 192.54 3,876.38 -7,869.28 -726.633,825.61 6,023,503.10 544,279.11 0.64 7,856.02 3_MWD+IFR2+MS+Sag (4)
9,918.46 91.30 192.06 3,873.48 -7,961.18 -746.673,822.71 6,023,411.10 544,259.63 1.11 7,950.07 3_MWD+IFR2+MS+Sag (4)
10,013.25 91.92 192.89 3,870.82 -8,053.69 -767.143,820.05 6,023,318.47 544,239.73 1.09 8,044.81 3_MWD+IFR2+MS+Sag (4)
10,108.54 91.79 194.38 3,867.73 -8,146.25 -789.593,816.96 6,023,225.79 544,217.84 1.57 8,139.98 3_MWD+IFR2+MS+Sag (4)
10,204.23 91.55 194.39 3,864.95 -8,238.90 -813.353,814.18 6,023,133.01 544,194.64 0.25 8,235.51 3_MWD+IFR2+MS+Sag (4)
10,298.58 91.73 194.60 3,862.25 -8,330.21 -836.963,811.48 6,023,041.57 544,171.59 0.29 8,329.69 3_MWD+IFR2+MS+Sag (4)
10,394.07 89.94 193.68 3,860.85 -8,422.79 -860.283,810.08 6,022,948.86 544,148.83 2.11 8,425.06 3_MWD+IFR2+MS+Sag (4)
10,489.21 90.68 193.91 3,860.34 -8,515.18 -882.973,809.57 6,022,856.34 544,126.70 0.81 8,520.13 3_MWD+IFR2+MS+Sag (4)
10,584.77 91.42 193.03 3,858.59 -8,608.10 -905.223,807.82 6,022,763.30 544,105.01 1.20 8,615.61 3_MWD+IFR2+MS+Sag (4)
10,679.65 90.25 190.85 3,857.21 -8,700.91 -924.853,806.44 6,022,670.38 544,085.95 2.61 8,710.47 3_MWD+IFR2+MS+Sag (4)
10,774.82 90.44 189.54 3,856.63 -8,794.57 -941.693,805.86 6,022,576.63 544,069.68 1.39 8,805.61 3_MWD+IFR2+MS+Sag (4)
10,869.71 90.37 189.95 3,855.96 -8,888.09 -957.753,805.19 6,022,483.02 544,054.18 0.44 8,900.46 3_MWD+IFR2+MS+Sag (4)
10,965.82 92.54 192.25 3,853.52 -8,982.36 -976.253,802.75 6,022,388.65 544,036.26 3.29 8,996.52 3_MWD+IFR2+MS+Sag (4)
11,060.72 92.66 192.13 3,849.22 -9,075.02 -996.263,798.45 6,022,295.87 544,016.80 0.18 9,091.32 3_MWD+IFR2+MS+Sag (4)
11,155.79 94.08 191.29 3,843.63 -9,167.95 -1,015.533,792.86 6,022,202.84 543,998.11 1.73 9,186.22 3_MWD+IFR2+MS+Sag (4)
11,250.79 94.14 190.47 3,836.82 -9,261.00 -1,033.413,786.05 6,022,109.69 543,980.79 0.86 9,280.97 3_MWD+IFR2+MS+Sag (4)
11,345.82 95.14 189.96 3,829.13 -9,354.22 -1,050.213,778.36 6,022,016.39 543,964.55 1.18 9,375.66 3_MWD+IFR2+MS+Sag (4)
11,441.22 95.51 189.20 3,820.28 -9,447.88 -1,066.023,769.51 6,021,922.64 543,949.31 0.88 9,470.59 3_MWD+IFR2+MS+Sag (4)
11,538.15 96.88 189.49 3,809.82 -9,542.96 -1,081.663,759.05 6,021,827.47 543,934.24 1.44 9,566.89 3_MWD+IFR2+MS+Sag (4)
11,633.27 96.37 191.28 3,798.84 -9,635.90 -1,098.703,748.07 6,021,734.45 543,917.78 1.94 9,661.35 3_MWD+IFR2+MS+Sag (4)
11,727.69 96.75 192.47 3,788.06 -9,727.69 -1,118.003,737.29 6,021,642.55 543,899.03 1.32 9,755.15 3_MWD+IFR2+MS+Sag (4)
11,798.00 96.75 192.47 3,779.79 -9,795.86 -1,133.073,729.02 6,021,574.29 543,884.37 0.00 9,824.96 PROJECTED to TD
Approved By:Checked By:Date:
6/24/2020 5:41:58PM COMPASS 5000.15 Build 91E Page 5
Chelsea Wright Digitally signed by Chelsea Wright
Date: 2020.06.24 14:50:54 -08'00'Benjamin Hand Digitally signed by Benjamin Hand
Date: 2020.06.26 08:37:48 -08'00'
24 June, 2020
Milne Point
M Pt L Pad
MPU L-60PB3
500292367872
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB3 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB3 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Milne Point, ACT, MILNE POINT
Alaska Zone 04
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
usft
+E/-W
+N/-S
Position Uncertainty
usft
usft
usftGround Level:
MPU L-60
usft
usft
0.00
0.00
6,031,375.87
544,958.07
16.60Wellhead Elevation:17.00 usft0.50
70° 29' 47.712 N
149° 37' 56.519 W
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
MPU L-60PB3
Model NameMagnetics
IFR 6/25/2020 15.98 80.92 57,375.00000000
Phase:Version:
Audit Notes:
Design MPU L-60PB3
1.0 ACTUAL
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:11,060.72
191.510.000.0033.77
From
(usft)
Survey Program
DescriptionTool NameSurvey (Wellbore)
To
(usft)
Date 6/20/2020
Survey Date
3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing100.00 634.00 MPU L-60PB1 E-Line Gyro (MPU L-60PB 06/02/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa698.08 6,800.39 MPU L-60PB1 MWD+IFR2+MS+Sag (1) 06/05/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,872.52 7,445.00 MPU L-60PB1 MWD+IFR2+MS+Sag (2) 06/12/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa7,510.00 11,060.72 MPU L-60PB2 MWD+IFR2+MS+Sag (3) 06/12/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa11,150.00 13,059.16 MPU L-60PB3 MWD+IFR2+MS+Sag (4) 06/15/2020
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
33.77 0.00 0.00 33.77 0.00 0.00-17.00 6,031,375.87 544,958.07 0.00 0.00 UNDEFINED
100.00 0.38 77.11 100.00 0.05 0.2149.23 6,031,375.92 544,958.28 0.57 -0.09 3_Gyro-GC_Csg (1)
166.00 0.42 73.38 166.00 0.17 0.66115.23 6,031,376.04 544,958.73 0.07 -0.30 3_Gyro-GC_Csg (1)
260.00 0.64 127.56 259.99 -0.05 1.41209.22 6,031,375.82 544,959.48 0.55 -0.23 3_Gyro-GC_Csg (1)
353.00 3.65 156.88 352.92 -3.09 2.98302.15 6,031,372.79 544,961.07 3.34 2.44 3_Gyro-GC_Csg (1)
447.00 5.42 167.49 446.62 -10.18 5.12395.85 6,031,365.72 544,963.25 2.08 8.96 3_Gyro-GC_Csg (1)
540.00 5.99 173.71 539.16 -19.29 6.60488.39 6,031,356.62 544,964.79 0.90 17.59 3_Gyro-GC_Csg (1)
634.00 9.61 178.61 632.28 -32.02 7.33581.51 6,031,343.90 544,965.59 3.91 29.91 3_Gyro-GC_Csg (1)
698.08 13.20 183.37 695.08 -44.67 7.03644.31 6,031,331.25 544,965.37 5.79 42.37 3_MWD+IFR2+MS+Sag (2)
794.57 17.61 191.41 788.10 -69.99 3.49737.33 6,031,305.91 544,961.98 5.07 67.89 3_MWD+IFR2+MS+Sag (2)
6/24/2020 5:42:27PM COMPASS 5000.15 Build 91E Page 2
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB3 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB3 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
888.90 22.54 181.62 876.69 -102.08 0.15825.92 6,031,273.80 544,958.84 6.31 100.00 3_MWD+IFR2+MS+Sag (2)
983.85 26.66 178.74 963.01 -141.59 0.11912.24 6,031,234.30 544,959.03 4.52 138.72 3_MWD+IFR2+MS+Sag (2)
1,079.96 30.55 180.36 1,047.37 -187.59 0.43996.60 6,031,188.31 544,959.63 4.13 183.73 3_MWD+IFR2+MS+Sag (2)
1,175.04 34.96 178.80 1,127.32 -239.01 0.851,076.55 6,031,136.89 544,960.36 4.72 234.04 3_MWD+IFR2+MS+Sag (2)
1,270.65 37.37 179.10 1,204.50 -295.42 1.881,153.73 6,031,080.50 544,961.73 2.53 289.10 3_MWD+IFR2+MS+Sag (2)
1,364.86 40.21 179.20 1,277.92 -354.43 2.751,227.15 6,031,021.50 544,962.96 3.02 346.75 3_MWD+IFR2+MS+Sag (2)
1,460.15 42.70 178.84 1,349.33 -417.50 3.831,298.56 6,030,958.45 544,964.43 2.63 408.34 3_MWD+IFR2+MS+Sag (2)
1,555.42 46.52 178.04 1,417.15 -484.36 5.671,366.38 6,030,891.60 544,966.67 4.05 473.49 3_MWD+IFR2+MS+Sag (2)
1,650.79 48.88 177.13 1,481.33 -554.83 8.651,430.56 6,030,821.15 544,970.08 2.57 541.95 3_MWD+IFR2+MS+Sag (2)
1,743.54 52.60 177.37 1,540.01 -626.55 12.091,489.24 6,030,749.46 544,973.95 4.02 611.54 3_MWD+IFR2+MS+Sag (2)
1,840.35 55.15 177.68 1,597.08 -704.67 15.471,546.31 6,030,671.38 544,977.80 2.65 687.41 3_MWD+IFR2+MS+Sag (2)
1,934.99 55.02 178.02 1,651.25 -782.22 18.381,600.48 6,030,593.85 544,981.18 0.33 762.82 3_MWD+IFR2+MS+Sag (2)
2,031.00 54.89 178.37 1,706.38 -860.78 20.851,655.61 6,030,515.31 544,984.13 0.33 839.31 3_MWD+IFR2+MS+Sag (2)
2,126.38 53.27 176.81 1,762.34 -937.95 24.091,711.57 6,030,438.17 544,987.83 2.15 914.28 3_MWD+IFR2+MS+Sag (2)
2,221.81 53.29 178.13 1,819.40 -1,014.37 27.471,768.63 6,030,361.79 544,991.67 1.11 988.49 3_MWD+IFR2+MS+Sag (2)
2,316.92 57.09 179.23 1,873.68 -1,092.42 29.251,822.91 6,030,283.75 544,993.92 4.11 1,064.62 3_MWD+IFR2+MS+Sag (2)
2,411.67 55.80 180.25 1,926.05 -1,171.38 29.611,875.28 6,030,204.81 544,994.76 1.63 1,141.91 3_MWD+IFR2+MS+Sag (2)
2,507.29 55.09 180.87 1,980.29 -1,250.12 28.851,929.52 6,030,126.07 544,994.47 0.91 1,219.23 3_MWD+IFR2+MS+Sag (2)
2,603.36 56.56 177.49 2,034.26 -1,329.57 30.001,983.49 6,030,046.63 544,996.11 3.29 1,296.85 3_MWD+IFR2+MS+Sag (2)
2,697.92 53.69 175.94 2,088.33 -1,407.01 34.432,037.56 6,029,969.23 545,001.00 3.32 1,371.85 3_MWD+IFR2+MS+Sag (2)
2,793.54 53.91 176.65 2,144.80 -1,484.01 39.412,094.03 6,029,892.27 545,006.45 0.64 1,446.30 3_MWD+IFR2+MS+Sag (2)
2,888.47 54.00 177.21 2,200.66 -1,560.66 43.532,149.89 6,029,815.66 545,011.03 0.49 1,520.59 3_MWD+IFR2+MS+Sag (2)
2,983.50 54.99 177.93 2,255.85 -1,637.95 46.802,205.08 6,029,738.40 545,014.77 1.21 1,595.67 3_MWD+IFR2+MS+Sag (2)
3,079.17 52.69 177.07 2,312.30 -1,715.11 50.162,261.53 6,029,661.26 545,018.60 2.51 1,670.61 3_MWD+IFR2+MS+Sag (2)
3,174.56 52.82 177.85 2,370.03 -1,790.97 53.532,319.26 6,029,585.43 545,022.42 0.67 1,744.27 3_MWD+IFR2+MS+Sag (2)
3,269.72 52.68 178.22 2,427.63 -1,866.67 56.122,376.86 6,029,509.75 545,025.48 0.34 1,817.93 3_MWD+IFR2+MS+Sag (2)
3,364.29 52.68 179.32 2,484.97 -1,941.86 57.742,434.20 6,029,434.58 545,027.55 0.93 1,891.29 3_MWD+IFR2+MS+Sag (2)
3,458.77 52.51 179.57 2,542.36 -2,016.91 58.472,491.59 6,029,359.55 545,028.73 0.28 1,964.68 3_MWD+IFR2+MS+Sag (2)
3,554.71 52.51 180.16 2,600.75 -2,093.03 58.652,549.98 6,029,283.44 545,029.37 0.49 2,039.24 3_MWD+IFR2+MS+Sag (2)
3,649.98 52.61 180.98 2,658.67 -2,168.67 57.892,607.90 6,029,207.80 545,029.07 0.69 2,113.51 3_MWD+IFR2+MS+Sag (2)
3,745.44 53.69 181.13 2,715.92 -2,245.04 56.492,665.15 6,029,131.43 545,028.13 1.14 2,188.63 3_MWD+IFR2+MS+Sag (2)
3,840.84 54.52 178.98 2,771.85 -2,322.32 56.422,721.08 6,029,054.16 545,028.53 2.02 2,264.36 3_MWD+IFR2+MS+Sag (2)
3,935.17 54.68 180.08 2,826.50 -2,399.21 57.052,775.73 6,028,977.29 545,029.62 0.97 2,339.57 3_MWD+IFR2+MS+Sag (2)
4,030.90 54.61 175.90 2,881.91 -2,477.20 59.792,831.14 6,028,899.31 545,032.83 3.56 2,415.46 3_MWD+IFR2+MS+Sag (2)
4,125.94 54.60 175.47 2,936.96 -2,554.46 65.612,886.19 6,028,822.10 545,039.13 0.37 2,490.00 3_MWD+IFR2+MS+Sag (2)
4,221.12 52.58 176.24 2,993.45 -2,630.85 71.162,942.68 6,028,745.75 545,045.13 2.22 2,563.75 3_MWD+IFR2+MS+Sag (2)
4,316.52 52.77 176.55 3,051.29 -2,706.57 75.933,000.52 6,028,670.08 545,050.36 0.33 2,636.99 3_MWD+IFR2+MS+Sag (2)
4,411.39 54.24 176.78 3,107.72 -2,782.70 80.363,056.95 6,028,593.98 545,055.25 1.56 2,710.71 3_MWD+IFR2+MS+Sag (2)
4,506.35 51.96 176.72 3,164.73 -2,858.51 84.673,113.96 6,028,518.20 545,060.01 2.40 2,784.13 3_MWD+IFR2+MS+Sag (2)
4,602.01 51.60 177.71 3,223.91 -2,933.58 88.323,173.14 6,028,443.17 545,064.12 0.90 2,856.96 3_MWD+IFR2+MS+Sag (2)
6/24/2020 5:42:27PM COMPASS 5000.15 Build 91E Page 3
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB3 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB3 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
4,697.12 54.33 178.55 3,281.19 -3,009.45 90.793,230.42 6,028,367.32 545,067.05 2.96 2,930.81 3_MWD+IFR2+MS+Sag (2)
4,792.82 54.71 179.27 3,336.74 -3,087.37 92.273,285.97 6,028,289.42 545,069.00 0.73 3,006.87 3_MWD+IFR2+MS+Sag (2)
4,887.60 53.14 178.17 3,392.55 -3,163.95 93.973,341.78 6,028,212.86 545,071.17 1.90 3,081.57 3_MWD+IFR2+MS+Sag (2)
4,982.84 53.23 178.81 3,449.62 -3,240.17 95.983,398.85 6,028,136.66 545,073.64 0.55 3,155.86 3_MWD+IFR2+MS+Sag (2)
5,077.61 54.54 178.91 3,505.48 -3,316.71 97.503,454.71 6,028,060.13 545,075.62 1.38 3,230.55 3_MWD+IFR2+MS+Sag (2)
5,173.58 54.06 179.82 3,561.48 -3,394.64 98.373,510.71 6,027,982.22 545,076.96 0.92 3,306.74 3_MWD+IFR2+MS+Sag (2)
5,268.22 53.86 179.77 3,617.16 -3,471.16 98.643,566.39 6,027,905.70 545,077.69 0.22 3,381.68 3_MWD+IFR2+MS+Sag (2)
5,364.17 60.08 181.10 3,669.44 -3,551.56 98.003,618.67 6,027,825.31 545,077.54 6.59 3,460.59 3_MWD+IFR2+MS+Sag (2)
5,459.22 60.62 181.05 3,716.46 -3,634.15 96.453,665.69 6,027,742.72 545,076.49 0.57 3,541.82 3_MWD+IFR2+MS+Sag (2)
5,554.68 61.21 182.68 3,762.86 -3,717.53 93.733,712.09 6,027,659.34 545,074.27 1.62 3,624.06 3_MWD+IFR2+MS+Sag (2)
5,649.60 63.83 184.38 3,806.66 -3,801.56 88.533,755.89 6,027,575.28 545,069.58 3.18 3,707.45 3_MWD+IFR2+MS+Sag (2)
5,744.95 66.70 187.03 3,846.56 -3,887.72 79.903,795.79 6,027,489.09 545,061.48 3.93 3,793.59 3_MWD+IFR2+MS+Sag (2)
5,840.36 71.54 188.97 3,880.56 -3,975.96 67.483,829.79 6,027,400.78 545,049.58 5.42 3,882.54 3_MWD+IFR2+MS+Sag (2)
5,935.36 75.85 189.68 3,907.22 -4,065.91 52.703,856.45 6,027,310.75 545,035.35 4.59 3,973.63 3_MWD+IFR2+MS+Sag (2)
6,030.62 81.09 189.73 3,926.26 -4,157.88 36.973,875.49 6,027,218.70 545,020.18 5.50 4,066.89 3_MWD+IFR2+MS+Sag (2)
6,125.82 84.57 190.55 3,938.14 -4,250.84 20.343,887.37 6,027,125.64 545,004.12 3.75 4,161.30 3_MWD+IFR2+MS+Sag (2)
6,221.25 85.99 191.54 3,945.99 -4,344.18 2.123,895.22 6,027,032.20 544,986.46 1.81 4,256.40 3_MWD+IFR2+MS+Sag (2)
6,316.31 85.87 190.77 3,952.74 -4,437.21 -16.223,901.97 6,026,939.07 544,968.68 0.82 4,351.22 3_MWD+IFR2+MS+Sag (2)
6,411.30 86.67 190.94 3,958.92 -4,530.30 -34.073,908.15 6,026,845.89 544,951.40 0.86 4,446.00 3_MWD+IFR2+MS+Sag (2)
6,506.87 86.49 191.30 3,964.62 -4,623.91 -52.473,913.85 6,026,752.18 544,933.57 0.42 4,541.40 3_MWD+IFR2+MS+Sag (2)
6,602.06 88.03 192.31 3,969.17 -4,716.98 -71.923,918.40 6,026,659.00 544,914.68 1.93 4,636.47 3_MWD+IFR2+MS+Sag (2)
6,695.79 92.05 192.74 3,969.10 -4,808.46 -92.253,918.33 6,026,567.41 544,894.91 4.31 4,730.17 3_MWD+IFR2+MS+Sag (2)
6,791.44 89.82 189.90 3,967.54 -4,902.22 -111.023,916.77 6,026,473.55 544,876.71 3.77 4,825.79 3_MWD+IFR2+MS+Sag (2)
6,800.39 89.70 189.74 3,967.58 -4,911.04 -112.543,916.81 6,026,464.72 544,875.24 2.23 4,834.73 3_MWD+IFR2+MS+Sag (2)
6,872.52 90.74 190.38 3,967.30 -4,982.06 -125.143,916.53 6,026,393.63 544,863.07 1.69 4,906.84 3_MWD+IFR2+MS+Sag (3)
6,968.50 90.99 191.35 3,965.86 -5,076.31 -143.233,915.09 6,026,299.29 544,845.56 1.04 5,002.80 3_MWD+IFR2+MS+Sag (3)
7,064.13 93.77 193.08 3,961.88 -5,169.68 -163.443,911.11 6,026,205.80 544,825.91 3.42 5,098.33 3_MWD+IFR2+MS+Sag (3)
7,158.78 93.65 192.57 3,955.76 -5,261.77 -184.413,904.99 6,026,113.59 544,805.50 0.55 5,192.75 3_MWD+IFR2+MS+Sag (3)
7,254.38 90.68 191.57 3,952.15 -5,355.18 -204.383,901.38 6,026,020.07 544,786.10 3.28 5,288.27 3_MWD+IFR2+MS+Sag (3)
7,349.77 90.81 192.53 3,950.91 -5,448.46 -224.293,900.14 6,025,926.69 544,766.75 1.02 5,383.65 3_MWD+IFR2+MS+Sag (3)
7,445.00 90.62 193.16 3,949.72 -5,541.30 -245.463,898.95 6,025,833.73 544,746.15 0.69 5,478.84 3_MWD+IFR2+MS+Sag (3)
7,510.00 90.66 191.82 3,948.99 -5,604.76 -259.523,898.22 6,025,770.19 544,732.48 2.06 5,543.83 3_MWD+IFR2+MS+Sag (4)
7,539.68 88.65 192.52 3,949.17 -5,633.77 -265.783,898.40 6,025,741.15 544,726.40 7.17 5,573.50 3_MWD+IFR2+MS+Sag (4)
7,634.60 90.07 192.59 3,950.23 -5,726.41 -286.413,899.46 6,025,648.39 544,706.33 1.50 5,668.40 3_MWD+IFR2+MS+Sag (4)
7,729.69 93.09 191.74 3,947.61 -5,819.32 -306.443,896.84 6,025,555.38 544,686.86 3.30 5,763.44 3_MWD+IFR2+MS+Sag (4)
7,825.08 92.97 191.28 3,942.57 -5,912.66 -325.443,891.80 6,025,461.93 544,668.42 0.50 5,858.69 3_MWD+IFR2+MS+Sag (4)
7,920.45 92.53 191.65 3,937.99 -6,006.02 -344.383,887.22 6,025,368.47 544,650.05 0.60 5,953.95 3_MWD+IFR2+MS+Sag (4)
8,015.45 91.05 191.51 3,935.03 -6,099.03 -363.443,884.26 6,025,275.35 544,631.56 1.56 6,048.90 3_MWD+IFR2+MS+Sag (4)
8,110.85 89.26 190.43 3,934.77 -6,192.69 -381.593,884.00 6,025,181.59 544,613.97 2.19 6,144.29 3_MWD+IFR2+MS+Sag (4)
8,205.96 88.65 190.45 3,936.50 -6,286.21 -398.823,885.73 6,025,087.98 544,597.31 0.64 6,239.37 3_MWD+IFR2+MS+Sag (4)
6/24/2020 5:42:27PM COMPASS 5000.15 Build 91E Page 4
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB3 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB3 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
8,301.82 91.92 192.51 3,936.03 -6,380.13 -417.903,885.26 6,024,993.95 544,578.81 4.03 6,335.21 3_MWD+IFR2+MS+Sag (4)
8,397.06 92.11 193.51 3,932.68 -6,472.87 -439.323,881.91 6,024,901.10 544,557.94 1.07 6,430.36 3_MWD+IFR2+MS+Sag (4)
8,492.11 91.18 194.41 3,929.95 -6,565.07 -462.243,879.18 6,024,808.77 544,535.58 1.36 6,525.28 3_MWD+IFR2+MS+Sag (4)
8,587.64 92.54 195.07 3,926.85 -6,657.40 -486.543,876.08 6,024,716.30 544,511.85 1.58 6,620.60 3_MWD+IFR2+MS+Sag (4)
8,682.51 92.04 193.26 3,923.06 -6,749.31 -509.733,872.29 6,024,624.26 544,489.21 1.98 6,715.29 3_MWD+IFR2+MS+Sag (4)
8,777.47 91.92 191.35 3,919.78 -6,842.03 -529.963,869.01 6,024,531.43 544,469.55 2.01 6,810.18 3_MWD+IFR2+MS+Sag (4)
8,872.95 91.61 190.69 3,916.83 -6,935.70 -548.203,866.06 6,024,437.66 544,451.88 0.76 6,905.61 3_MWD+IFR2+MS+Sag (4)
8,968.39 92.54 191.10 3,913.38 -7,029.36 -566.233,862.61 6,024,343.90 544,434.42 1.06 7,000.98 3_MWD+IFR2+MS+Sag (4)
9,063.46 92.47 190.94 3,909.22 -7,122.59 -584.383,858.45 6,024,250.57 544,416.83 0.18 7,095.96 3_MWD+IFR2+MS+Sag (4)
9,158.58 92.72 190.46 3,904.92 -7,215.96 -602.023,854.15 6,024,157.11 544,399.76 0.57 7,190.97 3_MWD+IFR2+MS+Sag (4)
9,253.65 91.92 190.33 3,901.07 -7,309.39 -619.163,850.30 6,024,063.58 544,383.18 0.85 7,285.95 3_MWD+IFR2+MS+Sag (4)
9,348.29 93.03 190.01 3,896.98 -7,402.46 -635.863,846.21 6,023,970.43 544,367.05 1.22 7,380.47 3_MWD+IFR2+MS+Sag (4)
9,443.25 92.78 190.68 3,892.17 -7,495.75 -652.893,841.40 6,023,877.04 544,350.59 0.75 7,475.29 3_MWD+IFR2+MS+Sag (4)
9,538.58 92.66 190.09 3,887.65 -7,589.41 -670.053,836.88 6,023,783.28 544,333.99 0.63 7,570.49 3_MWD+IFR2+MS+Sag (4)
9,633.51 91.85 190.98 3,883.91 -7,682.67 -687.403,833.14 6,023,689.94 544,317.21 1.27 7,665.33 3_MWD+IFR2+MS+Sag (4)
9,728.03 92.48 191.98 3,880.34 -7,775.23 -706.203,829.57 6,023,597.27 544,298.98 1.25 7,759.78 3_MWD+IFR2+MS+Sag (4)
9,824.36 92.23 192.54 3,876.38 -7,869.28 -726.633,825.61 6,023,503.10 544,279.11 0.64 7,856.02 3_MWD+IFR2+MS+Sag (4)
9,918.46 91.30 192.06 3,873.48 -7,961.18 -746.673,822.71 6,023,411.10 544,259.63 1.11 7,950.07 3_MWD+IFR2+MS+Sag (4)
10,013.25 91.92 192.89 3,870.82 -8,053.69 -767.143,820.05 6,023,318.47 544,239.73 1.09 8,044.81 3_MWD+IFR2+MS+Sag (4)
10,108.54 91.79 194.38 3,867.73 -8,146.25 -789.593,816.96 6,023,225.79 544,217.84 1.57 8,139.98 3_MWD+IFR2+MS+Sag (4)
10,204.23 91.55 194.39 3,864.95 -8,238.90 -813.353,814.18 6,023,133.01 544,194.64 0.25 8,235.51 3_MWD+IFR2+MS+Sag (4)
10,298.58 91.73 194.60 3,862.25 -8,330.21 -836.963,811.48 6,023,041.57 544,171.59 0.29 8,329.69 3_MWD+IFR2+MS+Sag (4)
10,394.07 89.94 193.68 3,860.85 -8,422.79 -860.283,810.08 6,022,948.86 544,148.83 2.11 8,425.06 3_MWD+IFR2+MS+Sag (4)
10,489.21 90.68 193.91 3,860.34 -8,515.18 -882.973,809.57 6,022,856.34 544,126.70 0.81 8,520.13 3_MWD+IFR2+MS+Sag (4)
10,584.77 91.42 193.03 3,858.59 -8,608.10 -905.223,807.82 6,022,763.30 544,105.01 1.20 8,615.61 3_MWD+IFR2+MS+Sag (4)
10,679.65 90.25 190.85 3,857.21 -8,700.91 -924.853,806.44 6,022,670.38 544,085.95 2.61 8,710.47 3_MWD+IFR2+MS+Sag (4)
10,774.82 90.44 189.54 3,856.63 -8,794.57 -941.693,805.86 6,022,576.63 544,069.68 1.39 8,805.61 3_MWD+IFR2+MS+Sag (4)
10,869.71 90.37 189.95 3,855.96 -8,888.09 -957.753,805.19 6,022,483.02 544,054.18 0.44 8,900.46 3_MWD+IFR2+MS+Sag (4)
10,965.82 92.54 192.25 3,853.52 -8,982.36 -976.253,802.75 6,022,388.65 544,036.26 3.29 8,996.52 3_MWD+IFR2+MS+Sag (4)
11,060.72 92.66 192.13 3,849.22 -9,075.02 -996.263,798.45 6,022,295.87 544,016.80 0.18 9,091.32 3_MWD+IFR2+MS+Sag (4)
11,150.00 93.99 191.34 3,844.04 -9,162.29 -1,014.393,793.27 6,022,208.51 543,999.21 1.73 9,180.44 3_MWD+IFR2+MS+Sag (5)
11,156.71 93.72 191.09 3,843.59 -9,168.85 -1,015.693,792.82 6,022,201.94 543,997.94 5.48 9,187.14 3_MWD+IFR2+MS+Sag (5)
11,251.63 91.61 190.68 3,839.17 -9,261.96 -1,033.603,788.40 6,022,108.73 543,980.61 2.26 9,281.94 3_MWD+IFR2+MS+Sag (5)
11,346.63 90.93 191.04 3,837.07 -9,355.23 -1,051.493,786.30 6,022,015.36 543,963.28 0.81 9,376.91 3_MWD+IFR2+MS+Sag (5)
11,441.69 90.19 190.74 3,836.14 -9,448.58 -1,069.453,785.37 6,021,921.92 543,945.89 0.84 9,471.96 3_MWD+IFR2+MS+Sag (5)
11,536.99 91.92 191.33 3,834.38 -9,542.10 -1,087.693,783.61 6,021,828.30 543,928.22 1.92 9,567.24 3_MWD+IFR2+MS+Sag (5)
11,631.79 93.77 192.25 3,829.68 -9,634.78 -1,107.033,778.91 6,021,735.52 543,909.44 2.18 9,661.92 3_MWD+IFR2+MS+Sag (5)
11,727.37 92.41 190.12 3,824.53 -9,728.40 -1,125.543,773.76 6,021,641.79 543,891.49 2.64 9,757.35 3_MWD+IFR2+MS+Sag (5)
11,822.39 91.92 187.34 3,820.94 -9,822.24 -1,139.953,770.17 6,021,547.88 543,877.65 2.97 9,852.18 3_MWD+IFR2+MS+Sag (5)
11,913.71 91.42 187.57 3,818.27 -9,912.75 -1,151.803,767.50 6,021,457.30 543,866.36 0.60 9,943.23 3_MWD+IFR2+MS+Sag (5)
6/24/2020 5:42:27PM COMPASS 5000.15 Build 91E Page 5
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU L-60
MPU L-60PB3 Survey Calculation Method:Minimum Curvature
MPU L-60 Actual RKB @ 50.77usft
Design:MPU L-60PB3 Database:NORTH US + CANADA
MD Reference:MPU L-60 Actual RKB @ 50.77usft
North Reference:
Well MPU L-60
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
12,013.11 90.19 187.79 3,816.88 -10,011.25 -1,165.083,766.11 6,021,358.74 543,853.67 1.26 10,042.40 3_MWD+IFR2+MS+Sag (5)
12,108.02 89.01 189.26 3,817.54 -10,105.10 -1,179.153,766.77 6,021,264.81 543,840.17 1.99 10,137.17 3_MWD+IFR2+MS+Sag (5)
12,203.46 91.06 190.68 3,817.48 -10,199.09 -1,195.673,766.71 6,021,170.73 543,824.22 2.61 10,232.57 3_MWD+IFR2+MS+Sag (5)
12,298.49 90.37 191.25 3,816.30 -10,292.38 -1,213.743,765.53 6,021,077.34 543,806.71 0.94 10,327.59 3_MWD+IFR2+MS+Sag (5)
12,393.79 91.61 192.46 3,814.65 -10,385.63 -1,233.323,763.88 6,020,983.99 543,787.71 1.82 10,422.87 3_MWD+IFR2+MS+Sag (5)
12,488.37 90.43 191.56 3,812.97 -10,478.12 -1,252.993,762.20 6,020,891.39 543,768.59 1.57 10,517.43 3_MWD+IFR2+MS+Sag (5)
12,584.93 89.76 189.18 3,812.81 -10,573.10 -1,270.373,762.04 6,020,796.32 543,751.79 2.56 10,613.96 3_MWD+IFR2+MS+Sag (5)
12,680.37 90.25 189.52 3,812.80 -10,667.27 -1,285.883,762.03 6,020,702.06 543,736.85 0.62 10,709.33 3_MWD+IFR2+MS+Sag (5)
12,775.24 88.15 190.88 3,814.12 -10,760.62 -1,302.683,763.35 6,020,608.62 543,720.62 2.64 10,804.16 3_MWD+IFR2+MS+Sag (5)
12,869.99 90.62 191.86 3,815.14 -10,853.50 -1,321.353,764.37 6,020,515.64 543,702.51 2.80 10,898.90 3_MWD+IFR2+MS+Sag (5)
12,964.64 90.81 191.87 3,813.96 -10,946.12 -1,340.813,763.19 6,020,422.91 543,683.61 0.20 10,993.54 3_MWD+IFR2+MS+Sag (5)
13,059.16 91.18 192.90 3,812.32 -11,038.42 -1,361.083,761.55 6,020,330.49 543,663.90 1.16 11,088.03 3_MWD+IFR2+MS+Sag (5)
13,130.00 91.18 192.90 3,810.86 -11,107.46 -1,376.893,760.09 6,020,261.37 543,648.51 0.00 11,158.83 PROJECTED to TD
Approved By:Checked By:Date:
6/24/2020 5:42:27PM COMPASS 5000.15 Build 91E Page 6
Chelsea Wright Digitally signed by Chelsea Wright
Date: 2020.06.24 14:52:57 -08'00'Benjamin Hand Digitally signed by Benjamin Hand
Date: 2020.06.26 08:30:15 -08'00'
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
1
2
1
1
1
103
1
1
1
49
1
X Yes No X Yes No 8.5
Fluid Description:
Liner hanger Info (Make/Model): Liner top Packer?: Yes No
Liner hanger test pressure:X Yes No
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg)Rate (bpm):Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp: X Yes No
Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg)Rate (bpm):Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp: X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns?Yes X No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Post Job Calculations:
Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped:
Cmt returned to surface: Calculated cement left in wellbore:
OH volume Calculated: OH volume actual: Actual % Washout:
Casing (Or Liner) Detail
Shoe
Casing Cut Joint
10 3/4 50.0
435.02 16375.31SECOND STAGERig
12:55
Cement to surface
Rotate Csg Recip Csg Ft. Min.PPG9.4
Shoe @ 68028 FC @ Top of Liner6,745.99
Floats Held
415.29 722
247 475
Spud Mud
CASING RECORD
County State Alaska Supv.D. Yessak/ J. Vanderpool
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP L-60 Date Run 8-Jun-20
Setting Depths
Component Size Wt.Grade THD Make Length Bottom Top
TXP BTC-SR Innovex 1.62 6,828.08 6,826.46
24.07 55.64 31.579 5/8 47.0 L-80 TXP BTC-SR Tenaris
Csg Wt. On Hook:320,000 Type Float Collar:Innovex No. Hrs to Run:13.5
9.4 6
1680
10
10.7 348 4
98
750
Bump Plug?FIRST STAGE10Tuned Spacer 60
15.8
1020
3.7
9.4 6 190.49/191.5
505.95/503.4
1250
1
Rig
15.8 82
Bump press
Cement to surface
Bump Plug?
Y
1:27 6/9/2020 2,588
2588.33
6,828.086,840.00
CEMENTING REPORT
Csg Wt. On Slips:130,000
Spud Mud
Tuned Spacer
664 2.94
Stage Collar @
60
Bump press
99.5
246
ES Cementer Closure OK
56
12 236
33.77 RKB to CHF
Type of Shoe:Innovex Casing Crew:Doyon
No. Jts. Delivered 185 No. Jts. Run 169 16
Length Measurements W/O Threads
Ftg. Delivered Ftg. Run Ftg. Returned
Ftg. Cut Jt.24.07 Ftg. Balance
3.5
Arctic CEM lead
Type
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 79.17 6,826.46 6,747.29
Float Collar 10 3/4 50.0 TXP BTC-SR Innovex 1.30 6,747.29 6,745.99
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 39.22 6,745.99 6,706.77
Baffle Adapter 10 3/4 50.0 TXP BTC-SR HES 1.59 6,706.77 6,705.18
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 4,104.37 6,705.18 2,600.81
Pup Joint 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 9.66 2,600.81 2,591.15
ES Cementer 10 3/4 TXP BTC-SR HES 2.82 2,591.15 2,588.33
Pup Joint 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 10.64 2,588.33 2,577.69
Casing 9 5/8 47.0 L-80 TXP BTC-SR Tenaris 2,522.05 2,577.69 55.64
Lead Cement 565 2.35
Premium G 400 1.16
4.75
Premium G 270 1.17
6/9/2020 38
Spud Mud
Cement to surface
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, Schrader Bluff Oil Pool, MPU L-60
Hilcorp Alaska, LLC
Permit to Drill Number: 220-048
Surface Location: 3185' FSL, 4924' FEL, Sec. 8, T13N, R10E, UM, AK
Bottomhole Location: 2636' FSL, 1048' FEL, Sec. 19, T13N, R10E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced development well.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Jeremy M. Price
Chair
DATED this ___ day of June, 2020.
Sincerely,
2
1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address:6. Proposed Depth: 12. Field/Pool(s):
MD: 13,129' TVD: 3,790'
4a. Location of Well (Governmental Section):7. Property Designation:
Surface:
Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date:
Total Depth:9. Acres in Property: 14. Distance to Nearest Property:
4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 50.3 15. Distance to Nearest Well Open
Surface: x-544957 y- 6031375 Zone-4 16.6 to Same Pool: 130' to MPU L-47
16. Deviated wells:Kickoff depth: 280 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 92 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
Conductor 20" 81# A-53 Weld 114' Surface Surface 114' 114'
9-5/8" 47# L-80 TXP 2,000' Surface Surface 2,000' 1,685'
9-5/8" 40# L-80 TXP 4,502' 2,000' 1,685' 6,502' 3,970'
8-1/2" 4-1/2" 13.5# L-80 Hydril 625 6,777' 6,352' 3,957' 13,129' 3,790'
Tieback 7-5/8" 29.7# L-80 Hydril 521 6,352' Surface Surface 6,352' 3,957'
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
TVD
Hydraulic Fracture planned?Yes No
20. Attachments:Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name:
Contact Email:
Contact Phone:
Date:
Permit to Drill API Number: Permit Approval
Number:50- Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Sr Pet Eng Sr Pet Geo Sr Res Eng
GL / BF Elevation above MSL (ft):
5/21/2020
See cover letter for other
requirements.
Perforation Depth MD (ft):
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Perforation Depth TVD (ft):
Commission Use Only
Effect. Depth MD (ft):
Authorized Signature:
Surface
Production
Liner
Casing
Intermediate
Length
Cementless Screen Liner
Tieback Assy.
~270 ft3
Stg 1 L - 1222 ft3 / T - 458 ft3
Effect. Depth TVD (ft):
Conductor/Structural
5077
1748
Total Depth MD (ft):Total Depth TVD (ft):
Cement Quantity, c.f. or sacks
Cement Volume MDSize
Plugs (measured):
(including stage data)
022224484
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
Stg 2 L - 1937 ft3 / T - 314 ft3
1390
1529' FNL, 276' FWL, Sec 17, T13N, R10E, UM, AK
2636' FSL, 1048' FEL, Sec 19, T13N, R10E, UM, AK
LONS 88-002
Specifications
MPU L-60
Milne Point Field
Schrader Bluff Oil Pool
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
Hilcorp Alaska, LLC
3185' FSL, 4924' FEL, Sec 8, T13N, R10E, UM, AK ADL025509 / ADL025515
12-1/4"
4939' to nearest unit boundary
6/10/2020
Authorized Name: Monty Myers
Authorized Title: Drilling Manager
Joe Engel
jengel@hilcorp.com
777-8395
18. Casing Program:Top - Setting Depth - Bottom
s N
ype of W
L
l R
L
1b
S
Class:
os N s No
s N o
D s
s
s
D
84
o
well is p
G
S
S
20
S S
S
s No s No
S
G
y E
S
s No
s
Form 10-401 Revised 3/2020 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Samantha Carlisle at 8:44 am, May 22, 2020
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: 2020.05.21 16:30:20 -08'00'
Monty M
Myers
SFD 5/26/2020
(NB sand)
220-048
DSR-5/26/2020
50-029-23678-00-00
gls 6/1/20
* 3000 psi BOPE test
0
6/2/2020
06/02/2020
Milne Point Unit
(MPU) L-60
Drilling Program
Version 1
5/20/2020
Table of Contents
1.0 Well Summary ...................................................................................................................... 2
2.0 Management of Change Information .................................................................................... 3
3.0 Tubular Program: ................................................................................................................ 4
4.0 Drill Pipe Information: ......................................................................................................... 4
5.0 Internal Reporting Requirements ......................................................................................... 5
6.0 Planned Wellbore Schematic ................................................................................................ 6
7.0 Drilling / Completion Summary ............................................................................................ 7
8.0 Mandatory Regulatory Compliance / Notifications ............................................................... 8
9.0 RU and Preparatory Work ................................................................................................. 10
10.0 NU 21-1/4” 2M Diverter System.......................................................................................... 11
11.0 Drill 12-1/4” Hole Section ................................................................................................... 13
12.0 Run 9-5/8” Surface Casing.................................................................................................. 16
13.0 Cement 9-5/8” Surface Casing ............................................................................................ 22
14.0 ND Diverter, NU BOPE, & Test.......................................................................................... 27
15.0 Drill 8-1/2” Hole Section ..................................................................................................... 28
16.0 Run 4-1/2” Screen Liner ..................................................................................................... 33
17.0 Run 7” Tieback ................................................................................................................... 37
18.0 Run Upper Completion....................................................................................................... 40
19.0 Doyon 14 Diverter Schematic.............................................................................................. 42
20.0 Doyon 14 BOP Schematic ................................................................................................... 43
21.0 Wellhead Schematic............................................................................................................ 44
22.0 Days Vs Depth .................................................................................................................... 45
23.0 Formation Tops & Information .......................................................................................... 46
24.0 Anticipated Drilling Hazards .............................................................................................. 47
25.0 Doyon 14 Layout................................................................................................................. 50
26.0 FIT Procedure .................................................................................................................... 51
27.0 Doyon 14 Choke Manifold Schematic ................................................................................. 52
28.0 Casing Design ..................................................................................................................... 53
29.0 8-1/2” Hole Section MASP .................................................................................................. 54
30.0 Spider Plot (NAD 27) (Governmental Sections) .................................................................. 55
31.0 Surface Plat (As Staked) (NAD 27) ..................................................................................... 56
32.0 Schrader Bluff Nb Sand Offset MW vs TVD Chart ............................................................ 57
Page 2
Milne Point Unit
L-60 SB Producer
Drilling Procedure
1.0 Well Summary
Well MPU L-60
Pad Milne Point “L” Pad
Planned Completion Type ESP on 3-1/2 tubing
Target Reservoir(s) Schrader Bluff NB Sand
Planned Well TD, MD / TVD 13,129’ MD / 3,790’ TVD
PBTD, MD / TVD 13,119’ MD / 3,790’ TVD
Surface Location (Governmental) 3185' FSL, 4924' FEL, Sec 8, T13N, R10E, UM, AK
Surface Location (NAD 27) X= 544957, Y= 6031375
Top of Productive Horizon
(Governmental) 1529' FNL, 276' FWL, Sec 17, T13N, R10E, UM, AK
TPH Location (NAD 27) X= 544922 Y= 6026661
BHL (Governmental) 2636' FSL, 1048' FEL, Sec 19, T13N, R10E, UM, AK
BHL (NAD 27) X= 543660, Y= 6020260
AFE Number 2011920
AFE Drilling Days 19
AFE Completion Days 4
AFE Drilling Amount $3,256,154
AFE Completion Amount $2,094,452
AFE Facility Am ount $302,000
Maximum Anticipated Pressure
(Surface) 1,390 psig
Maximum Anticipated Pressure
(Downhole/Reservoir) 1,748 psig
Work String 5” 19.5# S-135 NC 50
D14 KB Elevation above MSL: 33.7 ft + 16.6 ft = 50.3 ft
GL Elevation above MSL: 16.6 ft
BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams
Page 3
Milne Point Unit
L-60 SB Producer
Drilling Procedure
2.0 Management of Change Information
Page 4
Milne Point Unit
L-60 SB Producer
Drilling Procedure
3.0 Tubular Program:
Hole
Section
OD (in) ID
(in)
Drift
(in)
Conn OD
(in)
Wt
(#/ft)
Grade Conn Burst
(psi)
Collapse
(psi)
Tension
(k-lbs)
Cond 20” 19.25” - - - X-52 Weld
12-1/4” 9-5/8” 8.835” 8.679” 10.625” 40.0 L-80 TXP 5,750 3,090 916
9-5/8” 8.681” 8.525” 10.625” 47 L-80 TXP 6,870 4,750 1,086
Tieback 7-5/8” 6.875” 6.750” 7.625 29.7 L-80 Hyd 521 6,890 4,790 683
8-1/2” 4-1/2”
Screens 3.920 3.795 4.714 13.5 L-80 Hydril 625 9,020 8,540 279
4.0 Drill Pipe Information:
Hole
Section
OD
(in)
ID (in) TJ ID
(in)
TJ OD
(in)
Wt
(#/ft)
Grade Conn M/U
(Min)
M/U
(Max)
Tension
(k-lbs)
Surface &
Production
5” 4.276” 3.250” 6.625” 19.5 S-135 DS50 36,100 43,100 560klb
5” 4.276” 3.250” 6.625” 19.5 S-135 NC50 30,730 34,136 560klb
All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery).
Note: tapered 9 5/8" string for subsidence mitigation. gls
Page 5
Milne Point Unit
L-60 SB Producer
Drilling Procedure
5.0 Internal Reporting Requirements
5.1 Fill out daily drilling report and cost report on WellEz.
x Report covers operations from 6am to 6am
x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left
of the data entry area – this will not save the data entered, and will navigate to another data entry.
x Ensure time entry adds up to 24 hours total.
x Try to capture any out of scope work as NPT. This helps later on when we pull end of well
reports.
x Enter the MD and TVD depths EVERY DAY whether you are making hole or not.
5.2 Afternoon Updates
x Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp,
jengel@hilcorp.com and cdinger@hilcorp.com
5.3 Intranet Home Page Morning Update
x Submit a short operations update each morning by 7am on the company intranet homepage. On
weekend and holidays, ensure to have this update in before 5am.
5.4 EHS Incident Reporting
x Health and Safety: Notify EHS field coordinator.
x Environmental: Drilling Environmental Coordinator
x Notify Drilling Manager & Drilling Engineer on all incidents
x Submit Hilcorp Incident report to contacts above within 24 hrs
5.5 Casing Tally
x Send final “As -Run” Casing tally t o mmyers@hilcorp,com jengel@hilcorp.com and
cdinger@hilcorp.com
5.6 Casing and Cement report
x Send casing and cement report for each string of casing to mmyers@hilcorp.com
jengel@hilcorp.com and cdinger@hilcorp.com
5.7 Hilcorp Milne Point Contact List:
Title Name Work Phone Cell Phone Email
Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com
Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengel@hilcorp.com
Completion Engineer Ian Toomey 907.777.8434 907.903.3987 itoomey@hilcorp.com
Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com
Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com
Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com
EHS Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com
Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com
Page 6
Milne Point Unit
L-60 SB Producer
Drilling Procedure
6.0 Planned Wellbore Schematic
40x 47 # casing
MIT-IA 1000 psi
Page 7
Milne Point Unit
L-60 SB Producer
Drilling Procedure
7.0 Drilling / Completion Summary
MPU L-60 is a grassroots producer planned to be drilled in the Schrader Bluff NB sand. L-60 is part of a
multi well program targeting the Schrader Bluff sand on L-Pad.
The directional plan is a catenary well path build, 12-1/4” hole with 9-5/8” surface casing set into the top of
the Schrader Bluff NB sand. An 8-1/2” lateral section will then be drilled. A 4-1/2” screen liner will be run
in the open hole section and the well produced with an ESP assembly.
The Doyon 14 will be used to drill and complete the wellbore
Drilling operations are expected to commence approximately June 10, 2020, pending rig schedule.
Surface casing will be run to 6,502’ MD / 3,790’ TVD and cemented to surface via a 2 stage primary cement
job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed,
necessary remedial action will then be discussed with AOGCC authorities.
All cuttings & mud generated during drilling operations will be hauled to the Milne Point “B” pad G&I facility .
General sequence of operations:
1. MIRU Doyon 14 to well site
2. NU & Test 21-1/4” Diverter and 16” diverter line
3. Drill 12-1/4” hole to TD of surface hole section. Run and cement 9-5/8” surface casing
4. ND diverter, NU wellhead, NU 13-5/8” 5M BOP & Test
5. Drill 8-1/2” lateral to well TD.
6. Run 6-5/8 ” production liner
7. Run 7-5/8” tieback
8. Run Upper Completion
9. ND BOP, NU Tree, RDMO
Reservoir Evaluation Plan:
1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res
2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering)
MPU L-60 is a grassroots producer planned to be drilled in the Schrader Bluff NB sand.
Page 8
Milne Point Unit
L-60 SB Producer
Drilling Procedure
8.0 Mandatory Regulatory Compliance / Notifications
Regulatory Compliance
Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations,
specific regulations are listed below. If additional clarity or guidance is required on how to comply with
a specific regulation, do not hesitate to contact the Anchorage Drilling Team.
x BOPs shall be tested at (2) week intervals during the drilling and completion of MPU L-60. Ensure
to provide AOGCC 24 hrs notice prior to testing BOPs.
x The initial test of BOP equipment will be to 250/3,000 psi & subsequent tests of the BOP equipment
will be to 250/3,000 psi for 5/5 min (annular to 50% rated WP, 2 ,500 psi on the high test for initial
and subsequent tests). Confirm that these test pressures match those specified on the APD.
x If the BOP is used to shut in on the well in a well control situation or control fluid flow from the
well bore, AOGCC is to be notified and we must test all BOP components utilized for well control
prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP
test.
x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program
and drilling fluid system”.
x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and
completion: blowout prevention equipment and diverter requirements”.
o Ensure the diverter vent line is at least 75’ away from potential ignition sources
x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office.
AOGCC Regulation Variance Requests:
No variances are requested at this time.
Page 9
Milne Point Unit
L-60 SB Producer
Drilling Procedure
Summary of Doyon 14 BOP Equipment & Test Requirements
Hole Section Equipment Test Pressure (psi)
12 1/4” x 21-1/4” 2M Diverter w/ 16” Divert er Line Function Test Only
For Reference
x 13-5/8” x 5M Hydril “GK” Annular BOP
x 13-5/8” x 5M Hydril MPL Double Gate
o Blind ram in btm cavity
x Mud cross w/ 3” x 5M side outlets
x 13-5/8” x 5M Hydril MPL Single ram
x 3-1/8” x 5M Choke Line
x 3-1/8” x 5M Kill line
x 3-1/8” x 5M Choke manifold
x Standpipe, floor valves, etc
N/A
N/A
Primary closing unit: NL Shaffer, 6 station, 3,000 psi, 180 gallon accumulator unit.
Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air
pump, and emergency pressure is provided by bottled nitrogen.
The remote closing operator panels are located in the doghouse and on accumulator unit.
Required AOGCC Notifications:
x Well control event (BOPs utilized to shut in the well to control influx of formation fluids).
x 24 hours notice prior to spud.
x 24 hours notice prior to testing BOPs.
x 24 hours notice prior to casing running & cement operations.
x Any other notifications required in APD.
Regulatory Contact Information:
AOGCC
Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Ema il: jim.regg@alaska.gov
Guy Schwartz / Petroleum Engineer / (O): 907-793-1226 / (C): 907-301-4533 / Ema il: guy.schwartz@alaska.gov
Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Ema il: Victoria.loepp@alaska.gov
Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Ema il: melvin.rixse@alaska.gov
Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov
Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html
Notification / Emergency Phone: 907-793-1236 (During normal Business Hours)
Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours)
Page 10
Milne Point Unit
L-60 SB Producer
Drilling Procedure
9.0 RU and Preparatory Work
9.1 L-60 will utilize a newly set 20” conductor on L-Pad. Ensure to review attached surface plat and
make sure rig is over appropriate conductor.
9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor.
9.3 Install landing ring.
9.4 Insure (2) 4 ” nipples are installed on opposite sides of the conductor with ball valves on each.
9.5 Level pad and ensure enough room for layout of rig footprint and RU.
9.6 Rig mat footprint of rig.
9.7 MIRU Doyon 14. Ensure rig is centered over conductor to prevent any wear to BOPE or
wellhead.
9.8 Mud loggers WILL NOT be used on either hole section.
9.9 Mix spud mud for 12-1/4” surface hole section. Ensure mud temperatures are cool (<80q F).
9.10 Ensure 6 ” liners in mud pumps .
x Continental EMSCO FB-1600 mud pumps are rated at 4,665 psi, 462 GPM @ 110 SPM @
95% volumetric efficiency.
Page 11
Milne Point Unit
L-60 SB Producer
Drilling Procedure
10.0 NU 21-1/4” 2M Diverter System
10.1 NU 21-1/4” Hydril MSP 2M Diverter System (Diverter Schematic attached to program).
x NU 16-3/4” 3M x 21-1/4” 2M DSA on 16-3/4” 3M wellhead.
x NU 21-1/4” diverter “T”.
x Knife gate, 16” diverter line.
x Ensure diverter RU complies with AOGCC reg 20.AAC.25.035(C).
x Diverter line must be 75 feet from nearest ignition source
x Place drip berm at the end of diverter line.
10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on
the same circuit so that knife gate opens prior to annular closure.
10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the
vent line tip. “Warning Zone” must include:
x A prohibition on vehicle parking
x A prohibition on ignition sources or running equipment
x A prohibition on staged equipment or materials
x Restriction of traffic to essential foot or vehicle traffic only.
N U 21-1/4” Hydril MSP 2M Diverter System
10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on aa
Page 12
Milne Point Unit
L-60 SB Producer
Drilling Procedure
10.4 Rig & Diverter Orientation:
x May change on location
Page 13
Milne Point Unit
L-60 SB Producer
Drilling Procedure
11.0 Drill 12-1/4 ” Hole Section
11.1 PU 12-1/4” directional drilling assembly:
x Ensure BHA components have been inspected previously.
x Drift and caliper all components before MU. Visually verify no debris inside components
that cannot be drifted.
x Ensure TF offset is measured accurately and entered correctly into the MWD software.
x Be sure to run a UBHO sub for wireline gyro
x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics
calculations and recommended TFA is attached below.
x Drill string will be 5”, 19.5#, S-135, NC50.
x Run a solid float in the surface hole section.
11.2 Begin drilling out from 20” conductor at reduced flow rates to avoid broaching the conductor.
x Consider using a trash bit to clean out conductor to mitigate potential damage from debris in
conductor.
11.3 Drill 12-1/4 ” hole section to section TD, in the Schrader NB sand. Confirm this setting depth
with the Geologist and Drilling Engineer while drilling the well.
x Monitor the area around the conductor for any signs of broaching. If broaching is observed,
Stop drilling (or circulating) immediately notify Drilling Engineer.
x Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6°/ 100.
x Hold a safety meeting with rig crews to discuss:
x Conductor broaching ops and mitigation procedures.
x Well control procedures and rig evacuation
x Flow rates, hole cleaning, mud cooling, etc.
x Pump sweeps and maintain mud rheology to ensure effective hole cleaning.
x Keep mud as cool as possible to keep from washing out permafrost.
x Pump at 400-600 GPM. Monitor shakers closely to ensure shaker screens and return lines
can handle the flow rate.
x Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if
packoffs, increase in pump pressure or changes in hookload are seen
x Slow in/out of slips and while tripping to keep swab and surge pressures low
x Ensure shakers are functioning properly. Check for holes in screens on connections.
x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea
gravel, clay balling or packing off.
x Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 ppg
minimum at TD (pending MW increase due to hydrates).
x Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand
drilled.
x Gas hydrates have not been seen on L-Pad. However, be prepared for them. In MPU they
have been encountered typically around 2,100-2,400’ TVD (just below permafrost). Be
prepared for hydrates:
Page 14
Milne Point Unit
L-60 SB Producer
Drilling Procedure
x Gas hydrates can be identified by the gas detector and a decrease in MW or ECD
x Monitor returns for hydrates, checking pressurized & non-pressurized scales
x Do not stop to circulate out gas hydrates – this will only exacerbate the problem by washing
out additional permafrost. Attempt to control drill (150 FPH MAX) through the zone
completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to
prevent mud from belching over the bell nipple. Consider adding Lecithin to allow the gas to
break out.
x Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well.
MW will not control gas hydrates, but will affect how gas breaks out at surface.
x Surface Hole AC:
x There are no wells with a clearance factor of <1.0
11.4 12-1/4” hole mud program summary:
x Density: Weighting material to be used for the hole section will be barite. Additional barite
or spike fluid will be on location to weight up the active system (1) ppg above highest
anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with
9.2+ ppg.
Depth Interval MW (ppg)
Surface – Base Permafrost 8.9+
Base Permafrost - TD 9.2+ (For Hydrates if need based on offset wells)
MW can be cut once ~500’ below hydrate zone
x PVT System: MD Totco PVT will be used thro ughout the drilling and completion phase.
Remote monitoring stations will be available at the driller’s console, Co Man office,
Toolpusher office, and mud loggers office.
x Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system
with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all
times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue.
x Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM
(10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while
drilling the surface interval to prevent losses and strengthen the wellbore.
x Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are
recommended to reduce the incidence of bit balling and shaker blinding when penetrating the
high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A.
Maintain the pH in the 8.5 – 9.0 range with caustic soda. Daily additions of ALDACIDE G /
X-CIDE 207 MUST be made to control bacterial action.
x Casing Running: Reduce system YP with DESCO as required for running casing as allowed
(do not jeopardize hole conditions). Run casing carefully to minimize surge and swab
pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with
the cementers to see what YP value they have targeted).
g
Depth Interval MW (ppg)p
Sur face – Base Permafrost –8.9+
Base Permafrost - TD 9.2+ (For
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Drilling Procedure
System Type: 8.8 – 9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud
Properties:
Section Density Viscosity Plastic Viscosity Yield Point API FL pH Temp
Surface 8.8 – 9.8 75-175 20 - 40 25-45 <10 8.5 – 9.0 70 F
System Formulation: Gel + FW spud mud
Product- Surface hole Size Pkg ppb or (% liquids)
M-I Gel 50 lb sx 25
Soda Ash 50 lb sx 0.25
PolyPac Supreme UL 50 lb sx 0.08
Caustic Soda 50 lb sx 0.1
SCREENCLEEN 55 gal dm 0.5
11.5 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity.
11.6 RIH to bottom, proceed to BROOH to HWDP
x Pump at full drill rate (400-600 GPM), and maximize rotation.
x Pull slowly, 5 –10 ft/minute, adjust as dictated by hole conditions
x Monitor well for any signs of packing off or losses.
x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay
balling.
x If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until
parameters are restored.
11.7 TOOH and LD BHA
11.8 No open hole logging program planned.
y
8.8 – 9.8–
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Drilling Procedure
12.0 Run 9-5/8 ” Surface Casing
12.1 RU and pull wearbushing.
12.2 RU Weatherford 9-5/8” casing running equipment (CRT & Tongs)
x Ensure 9-5/8” TXP x DS50 XO on rig floor and M/U to FOSV.
x Use BOL 2000 thread compound. Dope pin end only w/ paint brush.
x RU of CRT if hole conditions require.
x RU a fill up tool to fill casing while running if the CRT is not used.
x Ensure all casing has been drifted to 8.750” on the location prior to running.
x Top 2000’ of casing from surface 47# drift 8.525”min
x Be sure to count the total # of joints on the location before running.
x Keep hole covered while RU casing tools.
x Record OD’s, ID’s, lengths, SN’s of all components with vendor & model info.
12.3 PU shoe joint, visually verify no debris inside joint.
12.4 Continue MU & thread locking 120’ shoe track assembly consisting of:
9-5/8” Float Shoe
1 joint – 9-5/8” TXP , 2 Centralizers 10’ from each end w/ stop rings
1 joint – 9-5/8” TXP, 1 Centralizer mid joint w/ stop ring
9-5/8” Float Collar with Stage Cemen ter Bypass Baffle ‘Top Hat’
1 joint – 9-5/8” TXP, 1 Centralizer mid joint with stop ring
9-5/8” HES Baffle Adaptor
x Ensure bypass baffle is correctly installed on top of float collar.
x Ensure proper operation of float equipment while picking up.
x Ensure to record S N’s of all float equipment and stage tool components.
This end up.
Bypass Baffle
g p
To p 2000’ of casing from surface 47# drift 8.525”min
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Drilling Procedure
12.5 Float equipment and Stage tool equipment drawings:
2500 ft
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Drilling Procedure
12.6 Continue running 9-5/8 ” surface casing
x Fill casing while r unning using fill up line on rig floor.
x Use BOL 2000 thread compound. Dope pin end only with paint brush.
x Centralization:
x 1 centralizer every joint to ~1,000’ MD from shoe
x 1 centralizer every 2 joints to ~2,000’ above shoe (Top of Lowest Ugnu)
x Verify depth of lowest Ugnu water sand for isolation with Geologist
x Utilize a collar clamp until weight is sufficient to keep slips set properly.
x Break circulation prior to reaching the base of the permafrost if casing run indicates poor
hole conditions.
x Any packing off while running casing should be treated as a major problem. It is preferable
to POH with casing and condition hole than to risk not getting cement returns to surface.
12.7 Install the Halliburton Type H ES-II Stage tool so that it is positioned at least 100’ TVD below
the permafrost (~ 2,500’ MD). (Halliburton ESIPC with packer element may be used).
x Install centralizers over couplings on 5 joints below and 5 joints above stage tool.
x Do not place tongs on ES cementer, this can cause damaged to the tool.
x Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3 ,300
psi.
x ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at ~ 2,080 psi, and the tool
to open at ~ 3,000 psi. Reference ESIPC Procedure.
9-5/8” 40# L-80 TXP Make Up Torques:
Casing OD Minimum Optimum Maximum
9-5/8” 18,860 ft-lbs 20,960 ft-lbs 23,060 ft-lbs
9-5/8” 47# L-80 TXP MUT:
Casing OD Minimum Optimum Maximum
9-5/8” 21,440 ft-lbs 2,3820 ft-lbs 26,200 ft-lbs
H ES-II Stage tool so that it is positioned at least 100’ TVD below yp
the permafrost (~ 2,500’ MD).
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Drilling Procedure
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Drilling Procedure
12.8 Continue running 9-5/8” surface casing
x Fill casing while r unning using fill up line on rig floor.
x Use BOL 2000 thread compound. Dope pin end only with paint brush.
x Centralization:
x 1 centralizer every 2 joints to base of conductor
12.9 The last 2000’ of 9-5/8” will be 47#, from 2000’ to Surface
x Ensure drifted to 8.525” min
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12.10 Watch displacement carefully and avoid surging the hole. Slow down running speed if
necessary.
12.11 Slow in and out of slips.
12.12 PU landing joint and MU to casing string. Position the casing shoe ±10’ from TD. Strap the
landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference
when getting the casing on depth.
12.13 Lower casing to setting depth. Confirm measurements.
12.14 Have slips staged in cellar, along with necessary equipment for the operation.
12.15 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement
job. Ensure adequate amounts of cold MU water are available to achieve this. If possible
reciprocate casing string while conditioning mud.
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Drilling Procedure
13.0 Cement 9-5/8 ” Surface Casing
13.1 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for
volume gained during cement job. Ensure adequate cement displacement volume available as
well. Ensure mud & water can be delivered to the cementing unit at acceptable rates.
x How to handle cement returns at surface. Ensure vac trucks are on standby and ready to
assist.
x Which pumps will be utilized for displacement, and how fluid will be fed to displacement
pump.
x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks.
x Positions and expectations of personnel involved with the cementing operation.
i. Extra hands in the pits to strap during the cement job to identify any losses
x Review test reports and ensure pump times are acceptable.
x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor.
13.2 Document efficiency of all possible displacement pumps prior to cement job.
13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will
help ensure any debris left in the cement pump or treating iron will not be pumped downhole.
13.4 RU cement line (if not already done so). Company Rep to witness loading of the top and bottom
plugs to ensure done in correct order.
13.5 Fill surface cement lines with water and pressure test.
13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer.
13.7 Drop bottom plug (flexible bypass plug) – HEC rep to witness. Mix and pump cement per below
calculations for the 1st stage, confirm actual cement volumes with cementer after TD is reached.
13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead &
tail, TOC brought to stage tool.
Estimated 1st Stage Total Cement Volume:
Section Calculation Vol (bbl) Vol (ft3)
12-1/4" OH x 9-5/8"
Casing (5,502' - 2,500') x .0558 bpf x 1.3 = 217.7 1222.3
Total Lead 217.7 1222.3
12-1/4" OH x 9-5/8"
Casing (6,502' - 5,502') x .0558 bpf x 1.3 = 72.5 407
9-5/8" Shoe Track 120' x .0758 bpf = 9.1 51.09
Total Tail 81.6 458LeadTail
394 sx
1 st stage
520 sx
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Drilling Procedure
Cement Slurry Design (1st Stage Cement Job):
13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch
reciprocation PU and SO weights, if the hole gets “sticky”, cease pipe reciprocation and continue
with the cement job.
13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of
mud pits, spotting water across the HEC stage cementer.
x Ensure volumes pumped and volumes returned are documented and constant communication
between mud pits, HEC Rep and HES Cementers during the entire job.
13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very
accurate using 0.0625 BPS (5” liners) for the Quattro pump output. To operate the stage tool
hydraulically, the plug must be bumped.
13.11 Displacement calculation:
6,382’ x .0758 BPF = 483.7 bbls
80 bbls of tuned spacer to be left behind stage tool
13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any
point during the job. Be prepared to pump out fluid from cellar. Have black water available to
contaminate any cement seen at surface.
13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over
displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling
Engineer.
13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening
plug is available if needed. This is the back-up option to open the stage tool if the plugs are not
bumped.
13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats
are holding. If floats do not hold, pressure up string to final circulating pressure and hold until
cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating
pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened.
Lead Slurry Tail Slurry
Density 12.0 lb/gal 15.8 lb/gal
Yield 2.35 ft3/sk 1.16 ft3/sk
Mixed Water 13.92 gal/sk 4.98 gal/sk
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Drilling Procedure
13.16 Increase pressure to 3,300 psi to open circulating ports in stage collar. Slightly higher pressure
may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns
to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation
for the 2 nd stage of the cement job.
13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker
bypass line to the cuttings tank. Have black water available and vac trucks ready to assist.
Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact
with the cement.
Increase pressure to 3,300 psi to open circulating ports in stage collar.
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Drilling Procedure
Second Stage Surface Cement Job:
13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive
strength. Try to maintain flow rate through stage tool until 2 nd stage is ready. Hold pre-job safety
meeting.
x Past wells have seen pressure increase while circulating through stage tool after reduced rate
13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing
head.
13.20 Fill surface lines with water and pressure test.
13.21 Pump remaining 60 bbls of 10.5 ppg tuned spacer.
13.22 Mix and pump cement per below recipe for the 2nd stage.
13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail).
Job will consist of lead & tail, TOC bro ught to surface. However cement will continue to be
pumped until clean spacer is observed at surface.
Estimated 2nd Stage Total Cement Volume:
Section Calculation Vol (bbl) Vol (ft3)
20" Conductor x 9-5/8" Casing (110') x .26 bpf x 1 = 28.6 161
12-1/4" OH x 9-5/8" Casing (2000' - 110') x .0558 bpf x 3 = 316.4 1776.3
Total Lead 345 1937
12-1/4" OH x 9-5/8" Casing (2500' - 2000') x .0558 bpf x 2 = 55.8 314
Total Tail 55.8 314LeadTail
Cement Slurry Design (2nd stage cement job):
Lead Slurry Tail Slurry
System Permafrost L
Density 10.7 lb/gal 15.8 lb/gal
Yield 4.41 ft3/sk 1.17 ft3/sk
Mixed Water 22.02 gal/sk 5.08 gal/sk
268 sx
440 sx
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Drilling Procedure
13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail.
13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out
of mud pits.
13.26 Displacement calculation:
2,500’ x .0758 BPF = 190 bbls mud
13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side
outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out
fluid from cellar. Have black water available to retard setting of cement.
13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should
circulate approximately 100 - 150 bbls of cement slurry to surface.
13.29 Land closing plug on stage collar and pressure up to 1,000 –1,500 psi to ensure stage tool closes.
Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool
has closed. Slips will be set as per plan to allow full a nnulus for returns during surface cement
job. Set slips
13.30 Make initial cut on 9-5/8” final joint. LD cut joint. Make final cut on 9-5/8”. Dress off stump.
Install 9-5/8” wellhead. If transition nipple is welded on, allow to cool as per schedule.
Ensure to report the following on wellez:
x Pre flush type, volume (bbls) & weight (ppg)
x Cement slurry type, lead or tail, volume & weight
x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration
a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight
& type of displacing fluid
b. Note if casing is reciprocated or rotated during the job
c. Calculated volume of displacement , actual displacement volume, whether plug bumped &
bump pressure, do floats hold
d. Percent mud returns during job, if intermittent note timing during pumping of job. Final
circulating pressure
e. Note if pre flush or cement returns at surface & volume
f. Note time cement in place
g. Note calculated top of cement
h. Add any comments which would describe the success or problems during the cement job
Send final “As-Run” casing tally & casing and cement report to jengel@hilcorp.com and
cdinger@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC.
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Drilling Procedure
14.0 ND Diverter, NU BOPE, & Test
14.1 ND the diverter T, knife gate, diverter line & N U 11” x 13-5/8” 5M casing spool.
14.2 NU 13-5/8” x 5M BOP as follows:
x BOP configuration from top down: 13-5/8” x 5M annular / 13 -5/8” x 5M double gate / 13-
5/8” x 5M mud cross / 13-5/8” x 5M single gate
x Double gate ram should be dressed with 2-7/8” x 5” VBRs in top cavity, blind ram in
bottom cavity.
x Single ram can be dressed with 4-1/2” x 7” VBRs
x NU bell nipple, install flowline.
x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to
mud cross).
x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual
valve
14.3 RU MPD RCD and related equipment.
14.4 Run 5” BOP test plug.
14.5 Test BOP to 250/3,000 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min.
x Test with 5” test joint
x Confirm test pressures with PTD
x Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure
is trapped underneath test plug
x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech
14.6 RD BOP test equipment
14.7 Dump and clean mud pits, send spud mud to G&I pad for injection.
14.8 Mix 8.9 ppg FloPro fluid for production hole.
14.9 Set wearbushing in wellhead.
14.10 If needed, rack back as much 5” DP in derrick as possible to be used while drilling the hole
section.
14.11 Ensure 6” liners in mud pumps.
initial BOP test
3000 psi
Test BOP to 250/3,000 psi for 5/5 min.
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15.0 Drill 8-1/2” Hole Section
15.1 MU 8-1/2” Cleanout BHA (Milltooth Bit & 1.22° PDM).
x Decision may be made to drill out with RSS. If so MU RSS BHA
15.2 TIH with 8-1/2” cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out
stage tool.
15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report.
15.4 RU and PT casing to 2,500 psi for 30 minutes charted. Ensure to record volume / pressure
(every ¼ bbl) and plot on FIT graph. AOGCC reg is 50% of burst = 5,750 / 2 = ~2,875 psi, but
max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume
pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as
per AOGCC Industry Guidance Bulletin 17-001.
15.5 Drill out shoe track and 20’ of new formation.
15.6 CBU and condition mud for FIT.
15.7 Conduct FIT to 12.0 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT.
Document incremental volume pumped (and subsequent pressure) and volume returned.
15.8 POOH and LD Cleanout BHA.
15.9 PU 8-1/2” directional BHA.
x 8-1/2” Bit Jetting: 6each 14/32nds
x Ensure BHA components have been inspected previously.
x Drift and caliper all components before MU. Visually verify no debris inside components
that cannot be drifted.
x Ensure TF offset is measured accurately and entered correctly into the MWD software.
x Ensure MWD is RU and operational.
x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics
calculations and recommended TFA is attached below.
x Drill string will be 5”, 19.5#, S-135, DS50 & NC50.
x Run a ported float in the production hole section.
15.10 8-1/2” hole section mud program summary:
x Density: Weighting material to be used for the hole section will be calcium carbonate.
Additional calcium carbonate will be on location to weight up the active system (1) ppg
above highest anticipated MW.
MIT casing
FIT 12 ppg Conduct FIT to 12.0 ppg EMW.
RU and PT casing to 2,500 psi for 30 minutes
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Drilling Procedure
x Solids Concentration: It is imperative that the solids concentration be kept low while
drilling the production hole section. Keep the shaker screen size optimized and fluid running
to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are
running the finest screens possible.
x Rheology: Keep viscosifier additions to an absolute minimum (N-VIS). Data suggests
excessive viscosifier concentrations can decrease return permeability. Do not pump high vis
sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8-1/2” (hole diameter) for sufficient
hole cleaning
x Run the centrifuge continuously while drilling the production hole, this will help with solids
removal.
x Dump and dilute as necessary to keep drilled solids to an absolute minimum.
x MD Totco PVT will be used thro ughout the drilling and completion phase. Remote
monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher
office.
System Type: 8.9 – 9.5 ppg FloPro drilling fluid
Properties:
Interval Density PV YP LSYP Total Solids MBT HPHT Hardness
Production 8.9-9.5 15-25 - ALAP 15 - 30 4-6 <10% <8 <11.0 <100
System Formulation:
Product- production Size Pkg ppb or (% liquids)
Busan 1060 55 gal dm 0.095
FLOTROL 55 lb sx 6
CONQOR 404 WH (8.5 gal/100 bbls) 55 gal dm 0.2
FLO-VIS PLUS 25 lb sx 0.7
KCl 50 lb sx 10.7
SMB 50 lb sx 0.45
LOTORQ 55 gal dm 1.0
SAFE-CARB 10 (verify) 50 lb sx 10
SAFE-CARB 20 (verify) 50 lb sx 10
Soda Ash 50 lb sx 0.5
y
8.9-9.5
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Drilling Procedure
15.11 TIH with 8-1/2” directional assembly to bottom.
15.12 Install MPD RCD.
15.13 Displace wellbore to 8.9 ppg Flo Pro drilling fluid
15.14 Begin drilling 8-1/2 ” hole section, o n-bottom staging technique:
x Tag bottom and begin drilling with 100 - 120 RPMs at bit. Allow WOB to stabilize at 5-8K.
x Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations
x If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to PU
off bottom and restart on bottom staging technique. If stick slip continues, consider adding
0.5% lubes
15.14 Drill 8-1/2” hole section to section TD per Geologist and Drilling Engineer.
x Flow Rate: 350-550 GPM, target min. AV’s 200 FPM, 385 GPM
x RPM: 120+
x Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly
wet to maximize solids removal efficiency. Check for holes in screens on every connection.
x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low
x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex:
concretion deflection
x Monitor Torque and Drag with pumps on every 5 stands
x Monitor ECD, pump pressure & hookload trends for hole cleaning indication
x Surveys can be taken more frequently if deemed necessary.
x Good drilling and tripping practices are vital for avoidance of differential sticking. Make
every effort to keep the drill string moving whenever possible and avoid st opping with the
BHA across the sand for any extended period of time.
x Use ADR to stay in section. Reservoir plan is to stay in NB/NC sand.
x Limit maximum instantaneous ROP to < 250 FPH. The sands will drill faster than this, but
when concretions are hit when drilling this fast, cutter damage can occur.
x Target ROP is as fast as we can clean the hole without having to backream connections
x Schrader Bluff Concretions: 5-10% of lateral
x MPD will be utilized to monitor pressure build up on connections.
x 8-1/2” Lateral A/C :
x There are no wells with a clearance factor < 1.0
15.15 Reference: Open hole sidetracking practice:
x If a known fault is coming up, put a slight “kick-off ramp” in wellbore ahead of the fault so
we have a nice place to low side.
x Attempt to lowside in a fast drilling interval where the wellbore is headed up.
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x Orient TF to low side and dig a trough with high flowrates for the first 10 feet, working
string back and forth. Trough for approximately 30 minutes.
x Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the
openhole sidetrack is achieved.
15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ GPM) and rotation (120+ RPM). Pump
tandem sweeps if needed
x Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a
consistent stream, circulate more if necessary
x If seepage losses are seen while drilling, consider reducing MW at TD to 9.0 ppg minimum
x Decision may be made to leave mud in the lateral and BROOH. This is TBD based upon hole
conditions and M-44 results.
15.17 Mix and pump 40 bbl 10 ppb SAPP pill. Line up to a closed loop system and circulate three SAP
pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter
cake and calcium carbonate. Circulate the well clean.
x Losses during the cleanup of the wellbore are a good indication that the mud filter cake is
being removed, including an increase in the loss rate.
15.18 Displace 1.5 OH + Liner volume with viscosified brine.
x Proposed brine blend (aiming for an 8 on the 6 RPM reading) -
KCl: 7.1bbp for 2%
NaCl: 60.9 ppg for 9.4 ppg
Lotorq: 1.5%
Lube 776: 1.5%
Soda Ash: as needed for 9.5pH
Busan 1060: 0.42 ppb
Flo-Vis Plus: 1.25 ppb
x Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further
discussion needed prior to BROOH.
15.19 Monitor the returned fluids carefully while displacing to brine. After 4 (or more) BU, Perform
production screen test (PST). The brine has been properly conditioned when it will pass the
production screen test (x3 350 ml samples passing through the screen in the same amount of
time which will indicate no plugging of the screen). Reference PST Test Procedure
15.20 BROOH with the drilling assembly to the 9-5/8” casing shoe
x Circulate at full drill rate (less if losses are seen, 350 GPM).
x Rotate at maximum rpm that can be sustained.
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Drilling Procedure
x Pulling speed 5 – 10 min/stand (slip to slip time, not including connections), adjust as
dictated by hole conditions.
x If back reaming operations are commenced, continue back reaming to the shoe
15.21 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while
BROOH.
15.22 CBU minimum two times at 9-5/8” shoe and clean casing with high vis sweeps.
15.23 Monitor well for flow / monitor for pressure build up with MPD. Increase fluid weight if
necessary
x Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to
determine if well is breathing, treat all flow as an influx until proven otherwise
15.24 POOH and LD BHA.
15.25 Continue to POOH and stand back BHA if possible. Rabbit DP on TOOH, ensure rabbit
diameter is sufficient for future ball drops.
15.26 Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any
additional logging runs conducted.
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16.0 Run 4-1/2” Screen Liner
16.1 Confirm VBR’s have been tested on 4 -1/2” and 5” test joints to 250/3,000 psi.
16.2 Well control preparedness : In the event of an influx of formation fluids while running the 4-
1/2” production screens, the following well control response procedure will be followed:
x PU & MU the 5” safety joint (with 4 -1/2” crossover installed on bottom, TIW valve in open
position on top, 4-1/2” handling joint above TIW). This joint shall be fully MU and available
prior to running the first joint of 4-1/2” screen.
x Slack off and position the 5” DP across the BOP, shut in ram or annular on 5” DP. Close
TIW valve.
x Proceed with well kill operations.
16.3 If an inner string is ran, Well control preparedness : In the event of an influx of formation
fluids while running the 2-3/8” inner string inside the 4-1/2” production screens:
x PU & MU the 5” safety joint (with 4 -1/2” x 2-3/8” triple connect crossover installed on
bottom, TIW valve in open position on top, 2-3/8” handling joint above TIW). MU 2-3/8”
and then 4-1/2” to triple connect.
x This joint shall be fully MU with crossovers prior to running the first joint of wash pipe.
x Slack off and position the 5” DP across the BOP, shut in ram or annular on 5” DP. Close
TIW valve. Proceed with well kill operations.
16.4 RU 4-1/2” screen running equipment.
x Ensure 4-1/2” x NC-50 crossover is on rig floor and MU to FOSV.
x Ensure all casing has been drifted on the deck prior to running.
x Be sure to count the total # of joints on the deck before running.
x Keep hole covered while RU casing tools.
x Record OD’s, ID’s, lengths, SN’s of all components w/ vendor & model info.
16.5 Run 4-1/2” screen production liner –Reference screen handling and running procedure.
x Use Best O Life 2000 AG thread compound. Dope pin end only with paint brush. Wipe off
excess. Thread compound will plug the screens.
x Utilize a collar clamp until weight is sufficient to keep slips set properly.
x Run packoff and float shoe on bottom.
x 4-1/2” Screens should auto –fill, top off with completion brine if needed
x Swell packers will not be required on this completion unless the well is drilled out of zone
x If needed, install swell packers as per the lower completion tally.
x Remove protective packaging on swell packers just prior to picking up
x Do not place tongs or slips on the packer element
4-1/2”, 13.5 #, L-80, Hydril 625 Torque
OD Minimum Optimum Operating Torque
p
” triple connect crossover t
If an inner string is ran, Well control preparednes s : In
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Drilling Procedure
4-1/2” 8,000 ft-lbs 9,600 ft-lbs 12,800 ft-lbs
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16.6. Ensure to run enough liner to provide for approx 15 0’ overlap inside 9-5/8” casing. Ensure
hanger/packer will not be set in a 9-5/8” connection.
x AOGCC regulations require a minimum 100’ overlap between the inner and outer strings as
per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8” connection.
16.7. Before picking up Baker SLZXP liner hanger / packer assembly, count the # of joints on the pipe
deck to make sure it coincides with the pipe tally.
16.8. MU Baker SLZXP liner top packer to 4-1/2” liner.
16.9. Inner string may or not be ran, depending on out of zone excursion and condition of lateral. Have
2-3/8” inner string available if needed.
16.10. Note: PU, SO, ROT and torque of liner. Run liner in the hole one stand and pump through liner
hanger to ensure a clear flow path exists.
16.11. RIH with liner on ALL 5” HWDP no faster than 30 ft/min –this is to prevent buckling the liner
and drill string and weight transfer to get liner to bottom with minimal rotation. Watch
displacement carefully and avoid surging the hole or buckling the liner. Slow down running
speed if necessary.
x Ensure 5” HWDP has been drifted
x There is no inner string planned to be run, as opposed to previous wells. The DP should auto
fill. Monitor FL and if filling is required due to losses/surging.
16.12. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe
depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to
bottom.
16.13. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10,
& 20 RPM.
16.14. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure
shoe enters correct hole.
16.15. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in
tension.
16.16. Rig up to pump down the work string with the rig pumps.
16.17. Break circulation. Begin circulating at ~1 BPM and monitor pump pressures. Do not exceed
1,600 psi while circulating. Pusher tool is set at 2,100 psi with 5% shear screws but it should be
discussed before exceeding 1,600 psi. Note all losses. Confirm all pressures with Baker.
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Drilling Procedure
16.18. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill
pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger.
16.19. Shut down pumps. Drop setting ball (ball seat now located in HRDE setting tool and not at the
WIV) down the workstring and pump slowly (1-2 BPM). Slow pump before the ball seats. Do
not allow ball to slam into ball seat.
16.20. Continue pressuring up to 2,700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes.
Slack off 20K lbs on the SZXP liner hanger/packer to ensure the HRDE setting tool is in
compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,500 psi
to release the HRDE running tool.
16.21. Bleed DP pressure to 0 psi. Pick up to expose rotating dog sub and set down 50K without
pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20
RPM and set down 50K again.
16.22. PU to neutral weight, close BOP and test annulus to 1 ,500 psi for 10 minutes charted.
16.23. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If
packer did not test, rotating dog sub can be used to set packer. If running tool cannot be
hydraulically released, apply LH torque to mechanically release the setting tool.
16.24. PU pulling running tool free of the packer and displace with at max rate to wash the liner top.
Pump sweeps as needed.
16.25. POOH. LD and inspect running tools. If setting of liner hanger/packer proceeded as planned,
LD DP on the TOOH.
Note: Once running tool is LD, swap to the completion AFE.
16.26. MU 3-1/2” wash tool and RIH with remaining DP out of derrick to liner top.
16.27. Wash through liner top at max rate and circulate hole clean. Pump sweeps around. Displace well
to clean filtered brine after no solids are returned.
16.28. POOH and LD remaining 5” HWDP
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Drilling Procedure
17.0 Run 7-5/8 ” Tieback
17.1 RU and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder
to be used for tie-back space out calculation.
17.2 Confirm pipe rams been tested with 7-5/8” test joint to 250/3,000 psi.
17.3 RU 7-5/8” casing handling equipment.
x Ensure XO to DP made up to FOSV and ready on rig floor.
x Rig up computer torque monitoring service.
x String should stay full while running, RU fill up line and check as appropriate.
17.4 PU 7-5/8” tieback seal assembly and set in rotary table. Ensure seal assembly has (4) 1” holes
above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8” x 7-5/8”
annulus.
17.5 M/U first joint of 7-5/8” to seal assembly.
17.6 Run 7-5/8”, 29.7#, L-80, H521 tieback to position seal assembly two joints above tieback sleeve.
Record up & down weights.
7-5/8” 29.7# H521 MU Torque
OD Minimum Optimum Maximum Yield Torque
7-5/8” 8,100 10,400 14,700 53,000
Confirm pipe rams been tested with 7-5/8” test joint to 250/3,000 psi.
17.3 RU
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Drilling Procedure
17.7 MU 7-5/8” to DP crossover.
17.8 MU stand of DP to string, and MU top drive.
17.9 Break circulation at 1 BPM and begin lowering string.
17.10 Note seal assembly entering tieback sleeve with a pressure increase, stop pumping and bleed off
pressure, leave standpipe bleed off valve open.
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Drilling Procedure
17.11 Continue lowering string and land out on no-go. Set down 5 – 10K and mark the pipe as “NO -
GO DEPTH”.
17.12 PU string & remove unnecessary 7-5/8 ” joints.
17.13 Space out with pups as needed to leave the no-go 1ft above fully no-go position when the casing
hanger is landed. Ensure one full joint is below the casing hanger.
17.14 PU and MU the 7-5/8” casing hanger with landing joint.
17.15 Ensure circulation is possible through 7-5/8 ” string.
17.16 RU and circulation corrosion inhibited brine in the 9-5/8” x 7-5/8” annulus.
17.17 With seals stabbed into the tieback sleeve, spot diesel freeze protection from ~2,500’ TVD to
surface in 9-5/8” x 7-5/8” annulus by reverse circulating through the holes in the seal assembly.
Ensure annular pressure are limited to prevent collapse of the 7-5/8” casing (verify collapse
pressure of the 7-5/8” tie back assembly).
17.18 SO and land hanger. Confirm the hanger has seated properly in the wellhead. Make note of
actual weight on the hanger in the morning report.
17.19 Back out landing joint. MU packoff running tool and install packoff on bottom of landing joint.
Set tubing hanger packoff and RILDS. PT void to 3,000 psi for 10 minutes.
17.20 R/D casing running tools.
17.21 PT 9-5/8” x 7-5/8” annulus to 1 ,000 psi for 30 minutes charted.
MIT annulus PT 9-5/8” x 7-5/8” annulus to 1”,000 psi for 30 minutes charted.
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Drilling Procedure
18.0 Run ESP Upper Completion
18.1 RU spooler with ESP power cable and heat trace.
18.2 Verify the ESP components as per Centrilift. Verify that the length of the motor lead flat cable
will place the splice between the discharge head and the 10’ handling pup collar. A Centrilift rep
shall be on the rig floor at all times during the running of the ESP.
18.3 Makeup new ESP assembly with new motor lead extension, seal section and motor.
18.4 Run the 3-1/2” ESP Completion as noted below.
The completion includes two 3/8” capillary tube from surface to the centralizer on the motor.
The capillary tube will be secured to the tubing with Cannon clamps.
Function test the capillary tube every ~2,000’ by pumping ~2 gallons of hydraulic oil through the
check valves. Record the pressure at each testing point
18.5 M/U ESP assy and RIH to setting depth. Confirm tally with Operations Engineer
i. Ensure appropriate well control crossovers on rig floor and ready.
ii. Monitor displacement from wellbore while RIH.
x Centrilift ESP Assembly with bottom of assembly @ predetermined depth
x 10’ 3-1/2”9.3#, L-80 Pup Joint
x 1 joint 3-1/2”9.3#, L-80 EUE 8rd tubing
x 3-1/2” “XN” nipple (2.813” packing bore / 2.75” No -Go ID)
x 3 joints 3-1/2” 9.3#, L-80 EUE 8rd tubing
x 10’ 3-1/2”9.3#, L-80 Pup Joint
x GLM 3-1/2” x 1” GLM w/ dummy installed
x 10’ 3-1/2”9.3#, L-80 Pup Joint
x 3-1/2” 9.3#, L-80 EUE 8rd tubing
x 10’ 3-1/2”9.3#, L-80 Pup Joint
x GLM 3-1/2” x 1” w/ SO @ ~140’ MD
x 10’ 3-1/2”9.3#, L-80 Pup Joint
x 3 joints 3-1/2” 9.3#, L-80 EUE 8rd tubing
x Tubing Hanger
o Check the conductivity of electric cable every 2,000’ and every new splice
while running in hole.
o Use Cannon clamps on every joint to secure the capillary tube.
o The make up torque values for 3-1/2 ” L-80 9.3# EUE 8rd tubing are:
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Drilling Procedure
Minimum: 2350 ft-lb, Optimum: 3100 ft-lb, and maximum: 3910 ft-lb.
o The 3-1/2” L-80 9.3# EUE 8rd tubing performance properties are:
Body Yield: 159,000#, Burst: 10,160 psi, Collapse: 10, psi.
18.6 Fill tubing while splicing cable, mid-cable splices and tubing hanger splices. After tubing is full,
break circulation by pumping 10 bbls down the tubing to clear any debris.
18.7 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with
band/clamp summary.
18.8 MU tubing hanger and landing joint. Splice ESP power cable and terminate control lines. Test
cable. Install a brass-shipping cap on the ESP penetrator.
18.9 Land tubing with extreme care to minimize damaging the ESP penetrator, pigtail and alignment
pin.
18.10 RILDS and test hanger. LD landing joint.
18.11 Install BPV and N/D BOP.
18.12 N/U tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. Terminate
the cap strings.
18.13 Circulate diesel freeze protection down 3-1/2” x 7-5/8” annulus (Volume sho uld equal capacity
of tubing to 2500’ + tubing annulus to 2500’). Connect IA to tree and allow diesel freeze protect
to “U-tube” into position. Note – this may be done post-rig.
18.14 Pull BPV. Set TWC. Test tree to 250 psi low / 5000 psi high. Pull TWC. Set BPV.
18.15 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over
with valve alignment as per operations personnel.
18.16 RDMO Doyon 14
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Drilling Procedure
19.0 Doyon 14 Diverter Schematic
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Drilling Procedure
20.0 Doyon 14 BOP Schematic
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Drilling Procedure
21.0 Wellhead Schematic
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22.0 Days Vs Depth
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23.0 Formation Tops & Information
L-Pad Data Sheet Formation Description (Closest & Most Analogous MPU Pad to Moose Pad)
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24.0 Anticipated Drilling Hazards
12-1/4” Hole Section:
Lost Circulation
Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost
circulation. For minor seepage losses, consider adding small amounts of calcium carbonate.
Gas Hydrates
Gas hyrates have not been seen on Moose pad. However, be prepared for them. Remember that hydrate
gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates,
but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come
out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching.
Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate
formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud
circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized
mud scale. The non-pressurized scale will reflect the actual mud cut weight. Add 1.0 – 2.0 ppb
Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to
remove hydrates from the system.
Hole Cleaning:
Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize
solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs
to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is
critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to
avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide
intervals. Do not out drill our ability to clean the hole.
Anti-Collison:
Take directional surveys every stand, take additional surveys if necessary. Continuously monitor
proximity to offset wellbores and record any close approaches on AM report. Well Specific:
x There are no wells with a clearance factor <1.0
Wellbore stability (Permafrost, running sands and gravel, conductor broaching):
Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of
time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH
speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and
swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching.
Maintain mud parameters and increase MW to combat running sands and gravel formations.
H2S:
Treat every hole section as though it has the potential for H2S. No H2S events have been documented
on drill wells on this pad.
Anti-Collison:
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Drilling Procedure
1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during
drilling operations.
2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements
of 20 AAC 25.066.
3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a
detailed mitigation procedure can be developed.
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Drilling Procedure
8-1/2” Hole Section:
Hole Cleaning:
Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up
with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor
ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe
rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe
moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation
after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of > 300
gpm
Lost Circulation:
Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost
circulation. For minor seepage losses, consider adding small amounts of calcium carbonate.
Faulting:
There is at least (1) fault that will be crossed while drilling the well. There could be others and the
throw of these faults is not well understood at this point in time. When a known fault is coming up,
ensure to put a “ramp” in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed,
we’ll need to either drill up or down to get a look at the LWD log and determine the throw and then
replan the wellbore.
H2S:
Treat every hole section as though it has the potential for H2S. No H2S events have been documented
on drill wells on this pad.
1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during
drilling operations.
2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements
of 20 AAC 25.066.
3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a
detailed mitigation procedure can be developed.
Abnormal Pressures and Temperatures:
Reservoir pressures are expected to be normal. Abnormal (offset injection) pressure has been seen on M-
Pad. Utilize MPD to mitigate any abnormal pressure seen.
Anti-Collision
Take directional surveys every stand, take additional surveys if necessary. Continuously monitor
drilling parameters for signs of magnetic interference with another well. Reference A/C report in
directional plan. Well Specific:
x There are no wells with a clearance factor < 1.0
surveys every stand,
Anti-Collision
Take directional
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Drilling Procedure
25.0 Doyon 14 Layout
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26.0 FIT Procedure
Formation Integrity Test (FIT) and
Leak-Off Test (LOT) Procedures
Procedure for FIT:
1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe).
2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe.
3. Close the blowout preventer (ram or annular).
4. Pump down the drill stem at 1/4 to 1/2 bpm.
5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs.
drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe.
6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes.
Record time vs. pressure in 1-minute intervals.
7. Bleed the pressure off and record the fluid volume recovered.
The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at
least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick
tolerance in case well control measures are required.
Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of
stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid;
at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure
monitored as with an FIT.
Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental
volume pumped and returned during test.
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Drilling Procedure
27.0 Doyon 14 Choke Manifold Schematic
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28.0 Casing Design
12-1/4"Mud Density:9.2 ppg
8-1/2"Mud Density:9.2 ppg
Mud Density:
1390 psi (see attached M ASP determination & calculation)
1390 psi (see attached M ASP determination & calculation)
Collapse Calculation:
Section Calculation
1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress
1234
9-5/8"4-1/2"
06,502
03,970
6,502 13,129
3,970 3,790
6,502 6,627
40 12.6
L-80 L-80
DWC H625
260,080 83,500
260,080 83,500
916 279
3.52 3.34
1,961 1,872
3,090 8,540
1.58 4.56
1,390 1,390
5,750 9,020
4.14 6.49
Weight w/o Bouyancy Factor (lbs)
Min strength Tension (1000 lbs)
DESIGN BY: Joe Engel
Hole Size
Casing Section
Collapse Resistance w/o tension (Psi)
Worst case safety factor (Burst)
MASP:
Production Mode
Minimum Yield (psi)
Weight (ppf)
MASP (psi)
Worst Case Safety Factor (Tension)
Collapse Pressure at bottom (Psi)
Worst Case Safety Factor (Collapse)
Length
Top (TVD)
Tension at Top of Section (lbs)
Design Criteria:
Hole Size
Grade
Connection
Calculation & Casing Design Factors
Calculation/Specification
Casing OD
Bottom (MD)
Bottom (TVD)
Top (MD)
MASP:
Drilling Mode
MASP:
Hole Size
DATE: 5.21.2020
WELL: MPU L-60
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Drilling Procedure
29.0 8-1/2” Hole Section MASP
MD TVD
Planned Top: 6502 3970
Planned TD: 13129 3790
Anticipated Formations and Pressures:
Formation TVD TVDss Est Pressure Oil/Gas/Wet PPG Grad
Schrader Bluff NB Sand 3,970 3,928 1747 Oil 8.46 0.440
Offset Well Mud Densities
Well MW range Top (TVD) Bottom (TVD) Date
MPU L-52 8.8-9.35 Surface 3952 2017
MPU L-51 8.9-9.3 Surface 3930 2017
MPU L-53 9-9.25 Surface 3891 2017
MPU J-27 9-9.3 Surface 3666 2015
MPU J-28 9-9.3 Surface 3617 2015
MPI - 19 9 - 9.3 ppg Surface 4,079 2004
MPI - 18 9 - 10 ppg Surface 3,848 2011
MPI - 17 9 - 9.5 ppg Surface 3,864 2004
Assumptions:
1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW.
3. Calculations assume full evacuation of wellbore to gas
Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface:
3970 (ft) x 0.78(psi/ft)= 3097
3097(psi) - [0.1(psi/ft)*3970(ft)]= 2700 psi
MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff NB sand)
3970 (ft) x 0.45(psi/ft)= 1787.0 psi
1787(psi) - 0.1(psi/ft)*3970(ft) 1390.0 psi
Summary:
1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation
of entire wellbore to gas at 0.1 psi/ft.
2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg.
Maximum Anticipated Surface Pressure Calculation
8-1/2" Hole Section
MPU L-60
Milne Point Unit
ok
1787(psi) -
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Drilling Procedure
30.0 Spider Plot (NAD 27) (Governmental Sections)
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31.0 Surface Plat (As Staked) (NAD 27)
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32.0 Schrader Bluff Nb Sand Offset MW vs TVD Chart
19 May, 2020
Plan: MPU L-60 wp08
Milne Point
M Pt L Pad
Plan: MPU L-60
MPU L-60
0750150022503000375045005250True Vertical Depth (1500 usft/in)-750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 14250Vertical Section at 191.51° (1500 usft/in)MPI-L-60 wp01 ToeMPI-L-60 wp01 Heel9 5/8" x 12 1/4"6 5/8" x 8 1/2"5001000150020002500300035004000450050005500600065007 0 00
750 0
80 00
85 0 0
9 0 00
950 0
1 0 0 0 0
10 5 0 0
11 0 00
11 5 0 0
12000
12500
1300013129MPU L-60 wp08Start Dir 3º/100' : 280' MD, 280'TVDStart Dir 4º/100' : 550' MD, 549.1'TVDEnd Dir : 1690.05' MD, 1501.71' TVDStartDir4º/100':5313.11'MD,3646.51'TVDEndDir:6151.98'MD,3939.8'TVDStartDir3º/100':6501.98'MD,3970.3'TVDEndDir:6735.88'MD,3976.42'TVDStartDir3º/100':11735.88'MD,3801.92'TVDEndDir:11830.88'MD,3799.91'TVDTotalDepth:13129.14'MD,3790.3'TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Pedal CurveWarning Method: Error RatioWELL DETAILS: Plan: MPU L-6016.60+N/-S +E/-WNorthingEastingLatittudeLongitude0.000.006031375.57544957.70 70° 29' 47.709 N 149° 37' 56.530 WSURVEY PROGRAMDate: 2020-05-06T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool33.70 900.00 MPU L-60 wp08 (MPU L-60) 3_Gyro-GC_Csg900.00 6501.98 MPU L-60 wp08 (MPU L-60) 3_MWD+IFR2+MS+Sag6501.98 13129.14 MPU L-60 wp08 (MPU L-60) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU L-60, True NorthVertical (TVD) Reference:MPU L-60 as-staked RKB @ 50.30usftMeasured Depth Reference:MPU L-60 as-staked RKB @ 50.30usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt L PadWell:Plan: MPU L-60Wellbore:MPU L-60Design:MPU L-60 wp08CASING DETAILSTVD TVDSS MD SizeName3970.30 3920.00 6501.98 9-5/8 9 5/8" x 12 1/4"3790.30 3740.00 13129.14 6-5/8 6 5/8" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 33.70 0.00 0.00 33.70 0.00 0.00 0.00 0.00 0.002 280.00 0.00 0.00 280.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 280' MD, 280'TVD3 550.00 8.10 178.35 549.10 -19.05 0.55 3.00 178.35 18.55 Start Dir 4º/100' : 550' MD, 549.1'TVD4 1690.05 53.70 178.34 1501.71 -588.95 17.06 4.00 -0.01 573.71 End Dir : 1690.05' MD, 1501.71' TVD5 5313.11 53.70 178.34 3646.51 -3507.73 101.69 0.00 0.00 3416.90 Start Dir 4º/100' : 5313.11' MD, 3646.51'TVD6 6151.98 85.00 191.51 3939.80 -4277.19 25.93 4.00 24.25 4186.00 End Dir : 6151.98' MD, 3939.8' TVD7 6501.98 85.00 191.51 3970.30 -4618.84 -43.64 0.00 0.00 4534.66 MPI-L-60 wp01 Heel Start Dir 3º/100' : 6501.98' MD, 3970.3'TVD8 6735.88 92.00 192.00 3976.42 -4847.62 -91.25 3.00 4.01 4768.34 End Dir : 6735.88' MD, 3976.42' TVD9 11735.88 92.00 192.00 3801.92 -9735.38 -1130.17 0.00 0.00 9765.11 Start Dir 3º/100' : 11735.88' MD, 3801.92'TVD10 11830.88 90.42 189.62 3799.91 -9828.66 -1147.99 3.00 -123.54 9860.07 End Dir : 11830.88' MD, 3799.91' TVD11 13129.14 90.42 189.62 3790.30 -11108.60 -1365.04 0.00 0.00 11157.59 MPI-L-60 wp01 Toe Total Depth : 13129.14' MD, 3790.3' TVD
-12000
-11250
-10500
-9750
-9000
-8250
-7500
-6750
-6000
-5250
-4500
-3750
-3000
-2250
-1500
-750
0
750
South(-)/North(+) (1500 usft/in)-6000 -5250 -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500
West(-)/East(+) (1500 usft/in)
MPI-L-60 wp01 Heel
MPI-L-60 wp01 Toe
9 5/8" x 12 1/4"
6 5/8" x 8 1/2"
10 00
1 50 0
1 75 0
2000
2250
2500
2750
300 0
3250
3 500
3750
3790
MPU L-60 wp08
Start Dir 3º/100' : 280' MD, 280'TVD
Start Dir 4º/100' : 550' MD, 549.1'TVD
End Dir : 1690.05' MD, 1501.71' TVD
Start Dir 4º/100' : 5313.11' MD, 3646.51'TVD
End Dir : 6151.98' MD, 3939.8' TVD
Start Dir 3º/100' : 6501.98' MD, 3970.3'TVD
End Dir : 6735.88' MD, 3976.42' TVD
Start Dir 3º/100' : 11735.88' MD, 3801.92'TVD
End Dir : 11830.88' MD, 3799.91' TVD
Total Depth : 13129.14' MD, 3790.3' TVD
CASING DETAILS
TVD TVDSS MD Size Name
3970.30 3920.00 6501.98 9-5/8 9 5/8" x 12 1/4"
3790.30 3740.00 13129.14 6-5/8 6 5/8" x 8 1/2"
Project: Milne Point
Site: M Pt L Pad
Well: Plan: MPU L-60
Wellbore: MPU L-60
Plan: MPU L-60 wp08
WELL DETAILS: Plan: MPU L-60
16.60
+N/-S +E/-W Northing Easting Latittude Longitude
0.00 0.00 6031375.57 544957.70 70° 29' 47.709 N 149° 37' 56.530 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: MPU L-60, True North
Vertical (TVD) Reference:MPU L-60 as-staked RKB @ 50.30usft
Measured Depth Reference:MPU L-60 as-staked RKB @ 50.30usft
Calculation Method:Minimum Curvature
Project:
Company:
Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Standard Proposal Report
Well:
Wellbore:
Plan: MPU L-60
MPU L-60
Survey Calculation Method:Minimum Curvature
MPU L-60 as-staked RKB @ 50.30usft
Design:MPU L-60 wp08
Database:NORTH US + CANADA
MD Reference:MPU L-60 as-staked RKB @ 50.30usft
North Reference:
Well Plan: MPU L-60
True
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Milne Point, ACT, MILNE POINT
Alaska Zone 04
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Site Position:
From:
Site
Latitude:
Longitude:
Position Uncertainty:
Northing:
Easting:
Grid Convergence:
M Pt L Pad, TR-13-10
usft
Map usft
usft
°0.34Slot Radius:"0
6,029,799.28
544,529.55
0.00
70° 29' 32.230 N
149° 38' 9.412 W
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
usft
+E/-W
+N/-S
Position Uncertainty
usft
usft
usftGround Level:
Plan: MPU L-60
usft
usft
0.00
0.00
6,031,375.57
544,957.70
16.60Wellhead Elevation:usft0.50
70° 29' 47.709 N
149° 37' 56.530 W
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
MPU L-60
Model NameMagnetics
BGGM2020 9/6/2020 15.92 80.89 57,379.99852396
Phase:Version:
Audit Notes:
Design MPU L-60 wp08
PLAN
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:33.70
191.510.000.0033.70
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
Tool Face
(°)
+N/-S
(usft)
Measured
Depth
(usft)
Vertical
Depth
(usft)
Dogleg
Rate
(°/100usft)
Build
Rate
(°/100usft)
Turn
Rate
(°/100usft)
Plan Sections
TVD
System
usft
0.000.000.000.000.000.0033.700.000.0033.70 -16.60
0.000.000.000.000.000.00280.000.000.00280.00 229.70
178.350.003.003.000.55-19.05549.10178.358.10550.00 498.80
-0.010.004.004.0017.06-588.951,501.71178.3453.701,690.05 1,451.41
0.000.000.000.00101.69-3,507.733,646.51178.3453.705,313.11 3,596.21
24.251.573.734.0025.93-4,277.193,939.80191.5185.006,151.98 3,889.50
0.000.000.000.00-43.64-4,618.843,970.30191.5185.006,501.98 3,920.00
4.010.212.993.00-91.25-4,847.623,976.42192.0092.006,735.88 3,926.12
0.000.000.000.00-1,130.17-9,735.383,801.92192.0092.0011,735.88 3,751.62
-123.54-2.50-1.663.00-1,147.99-9,828.663,799.91189.6290.4211,830.88 3,749.61
0.000.000.000.00-1,365.04-11,108.603,790.30189.6290.4213,129.14 3,740.00
5/19/2020 4:19:31PM COMPASS 5000.15 Build 91E Page 2
Project:
Company:
Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Standard Proposal Report
Well:
Wellbore:
Plan: MPU L-60
MPU L-60
Survey Calculation Method:Minimum Curvature
MPU L-60 as-staked RKB @ 50.30usft
Design:MPU L-60 wp08
Database:NORTH US + CANADA
MD Reference:MPU L-60 as-staked RKB @ 50.30usft
North Reference:
Well Plan: MPU L-60
True
Measured
Depth
(usft)
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
Map
Northing
(usft)
Map
Easting
(usft)
+N/-S
(usft)
Planned Survey
Vertical
Depth
(usft)
TVDss
usft
DLS
-16.60
Vert Section
33.70 0.00 33.70 0.00 0.000.00 544,957.706,031,375.57-16.60 0.00 0.00
100.00 0.00 100.00 0.00 0.000.00 544,957.706,031,375.5749.70 0.00 0.00
200.00 0.00 200.00 0.00 0.000.00 544,957.706,031,375.57149.70 0.00 0.00
280.00 0.00 280.00 0.00 0.000.00 544,957.706,031,375.57229.70 0.00 0.00
Start Dir 3º/100' : 280' MD, 280'TVD
300.00 0.60 300.00 -0.10 0.00178.35 544,957.706,031,375.47249.70 3.00 0.10
400.00 3.60 399.92 -3.77 0.11178.35 544,957.836,031,371.80349.62 3.00 3.67
500.00 6.60 499.51 -12.65 0.36178.35 544,958.146,031,362.92449.21 3.00 12.32
550.00 8.10 549.10 -19.05 0.55178.35 544,958.366,031,356.53498.80 3.00 18.55
Start Dir 4º/100' : 550' MD, 549.1'TVD
600.00 10.10 598.47 -26.95 0.78178.35 544,958.646,031,348.63548.17 4.00 26.25
700.00 14.10 696.23 -47.90 1.38178.34 544,959.376,031,327.69645.93 4.00 46.66
800.00 18.10 792.29 -75.61 2.18178.34 544,960.346,031,299.98741.99 4.00 73.66
900.00 22.10 886.18 -109.96 3.18178.34 544,961.546,031,265.64835.88 4.00 107.11
1,000.00 26.10 977.44 -150.77 4.36178.34 544,962.976,031,224.85927.14 4.00 146.86
1,100.00 30.10 1,065.64 -197.84 5.72178.34 544,964.626,031,177.791,015.34 4.00 192.72
1,200.00 34.10 1,150.33 -250.94 7.26178.34 544,966.486,031,124.701,100.03 4.00 244.45
1,300.00 38.10 1,231.11 -309.83 8.97178.34 544,968.546,031,065.831,180.81 4.00 301.81
1,400.00 42.10 1,307.59 -374.20 10.83178.34 544,970.796,031,001.481,257.29 4.00 364.51
1,500.00 46.10 1,379.39 -443.75 12.85178.34 544,973.236,030,931.951,329.09 4.00 432.26
1,600.00 50.10 1,446.16 -518.13 15.00178.34 544,975.846,030,857.591,395.86 4.00 504.72
1,690.05 53.70 1,501.71 -588.95 17.06178.34 544,978.326,030,786.791,451.41 4.00 573.71
End Dir : 1690.05' MD, 1501.71' TVD
1,700.00 53.70 1,507.60 -596.97 17.29178.34 544,978.606,030,778.771,457.30 0.00 581.52
1,800.00 53.70 1,566.80 -677.53 19.63178.34 544,981.426,030,698.241,516.50 0.00 659.99
1,900.00 53.70 1,626.00 -758.09 21.96178.34 544,984.246,030,617.701,575.70 0.00 738.47
2,000.00 53.70 1,685.20 -838.65 24.30178.34 544,987.076,030,537.161,634.90 0.00 816.94
2,100.00 53.70 1,744.40 -919.21 26.63178.34 544,989.896,030,456.621,694.10 0.00 895.41
2,200.00 53.70 1,803.59 -999.78 28.97178.34 544,992.716,030,376.091,753.29 0.00 973.89
2,300.00 53.70 1,862.79 -1,080.34 31.31178.34 544,995.546,030,295.551,812.49 0.00 1,052.36
2,400.00 53.70 1,921.99 -1,160.90 33.64178.34 544,998.366,030,215.011,871.69 0.00 1,130.84
2,500.00 53.70 1,981.19 -1,241.46 35.98178.34 545,001.186,030,134.471,930.89 0.00 1,209.31
2,600.00 53.70 2,040.39 -1,322.02 38.31178.34 545,004.006,030,053.941,990.09 0.00 1,287.79
2,700.00 53.70 2,099.59 -1,402.58 40.65178.34 545,006.836,029,973.402,049.29 0.00 1,366.26
2,800.00 53.70 2,158.79 -1,483.14 42.99178.34 545,009.656,029,892.862,108.49 0.00 1,444.74
2,900.00 53.70 2,217.98 -1,563.70 45.32178.34 545,012.476,029,812.322,167.68 0.00 1,523.21
3,000.00 53.70 2,277.18 -1,644.26 47.66178.34 545,015.306,029,731.782,226.88 0.00 1,601.69
3,100.00 53.70 2,336.38 -1,724.83 49.99178.34 545,018.126,029,651.252,286.08 0.00 1,680.16
3,200.00 53.70 2,395.58 -1,805.39 52.33178.34 545,020.946,029,570.712,345.28 0.00 1,758.64
3,300.00 53.70 2,454.78 -1,885.95 54.66178.34 545,023.766,029,490.172,404.48 0.00 1,837.11
3,400.00 53.70 2,513.98 -1,966.51 57.00178.34 545,026.596,029,409.632,463.68 0.00 1,915.59
3,500.00 53.70 2,573.18 -2,047.07 59.34178.34 545,029.416,029,329.102,522.88 0.00 1,994.06
3,600.00 53.70 2,632.37 -2,127.63 61.67178.34 545,032.236,029,248.562,582.07 0.00 2,072.54
3,700.00 53.70 2,691.57 -2,208.19 64.01178.34 545,035.066,029,168.022,641.27 0.00 2,151.01
3,800.00 53.70 2,750.77 -2,288.75 66.34178.34 545,037.886,029,087.482,700.47 0.00 2,229.49
5/19/2020 4:19:31PM COMPASS 5000.15 Build 91E Page 3
Project:
Company:
Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Standard Proposal Report
Well:
Wellbore:
Plan: MPU L-60
MPU L-60
Survey Calculation Method:Minimum Curvature
MPU L-60 as-staked RKB @ 50.30usft
Design:MPU L-60 wp08
Database:NORTH US + CANADA
MD Reference:MPU L-60 as-staked RKB @ 50.30usft
North Reference:
Well Plan: MPU L-60
True
Measured
Depth
(usft)
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
Map
Northing
(usft)
Map
Easting
(usft)
+N/-S
(usft)
Planned Survey
Vertical
Depth
(usft)
TVDss
usft
DLS
2,759.67
Vert Section
3,900.00 53.70 2,809.97 -2,369.31 68.68178.34 545,040.706,029,006.952,759.67 0.00 2,307.96
4,000.00 53.70 2,869.17 -2,449.87 71.02178.34 545,043.526,028,926.412,818.87 0.00 2,386.44
4,100.00 53.70 2,928.37 -2,530.44 73.35178.34 545,046.356,028,845.872,878.07 0.00 2,464.91
4,200.00 53.70 2,987.57 -2,611.00 75.69178.34 545,049.176,028,765.332,937.27 0.00 2,543.39
4,300.00 53.70 3,046.76 -2,691.56 78.02178.34 545,051.996,028,684.802,996.46 0.00 2,621.86
4,400.00 53.70 3,105.96 -2,772.12 80.36178.34 545,054.826,028,604.263,055.66 0.00 2,700.34
4,500.00 53.70 3,165.16 -2,852.68 82.70178.34 545,057.646,028,523.723,114.86 0.00 2,778.81
4,600.00 53.70 3,224.36 -2,933.24 85.03178.34 545,060.466,028,443.183,174.06 0.00 2,857.29
4,700.00 53.70 3,283.56 -3,013.80 87.37178.34 545,063.286,028,362.653,233.26 0.00 2,935.76
4,800.00 53.70 3,342.76 -3,094.36 89.70178.34 545,066.116,028,282.113,292.46 0.00 3,014.24
4,900.00 53.70 3,401.95 -3,174.92 92.04178.34 545,068.936,028,201.573,351.65 0.00 3,092.71
5,000.00 53.70 3,461.15 -3,255.48 94.38178.34 545,071.756,028,121.033,410.85 0.00 3,171.18
5,100.00 53.70 3,520.35 -3,336.05 96.71178.34 545,074.586,028,040.503,470.05 0.00 3,249.66
5,200.00 53.70 3,579.55 -3,416.61 99.05178.34 545,077.406,027,959.963,529.25 0.00 3,328.13
5,300.00 53.70 3,638.75 -3,497.17 101.38178.34 545,080.226,027,879.423,588.45 0.00 3,406.61
5,313.11 53.70 3,646.51 -3,507.73 101.69178.34 545,080.596,027,868.863,596.21 0.00 3,416.90
Start Dir 4º/100' : 5313.11' MD, 3646.51'TVD
5,400.00 56.88 3,695.98 -3,579.14 102.68180.04 545,082.016,027,797.473,645.68 4.00 3,486.67
5,500.00 60.57 3,747.89 -3,664.58 101.24181.86 545,081.096,027,712.033,697.59 4.00 3,570.68
5,600.00 64.28 3,794.17 -3,753.10 97.04183.54 545,077.436,027,623.493,743.87 4.00 3,658.26
5,700.00 68.01 3,834.60 -3,844.27 90.11185.13 545,071.056,027,532.293,784.30 4.00 3,748.98
5,800.00 71.75 3,869.00 -3,937.66 80.48186.63 545,061.996,027,438.863,818.70 4.00 3,842.41
5,900.00 75.51 3,897.18 -4,032.79 68.21188.07 545,050.296,027,343.663,846.88 4.00 3,938.08
6,000.00 79.27 3,919.01 -4,129.22 53.33189.46 545,036.006,027,247.153,868.71 4.00 4,035.54
6,100.00 83.04 3,934.38 -4,226.47 35.94190.81 545,019.206,027,149.813,884.08 4.00 4,134.30
6,151.98 85.00 3,939.80 -4,277.19 25.93191.51 545,009.506,027,099.043,889.50 4.00 4,186.00
End Dir : 6151.98' MD, 3939.8' TVD
6,200.00 85.00 3,943.98 -4,324.06 16.39191.51 545,000.246,027,052.113,893.68 0.00 4,233.83
6,300.00 85.00 3,952.70 -4,421.68 -3.49191.51 544,980.956,026,954.383,902.40 0.00 4,333.45
6,400.00 85.00 3,961.41 -4,519.29 -23.37191.51 544,961.676,026,856.663,911.11 0.00 4,433.07
6,501.98 85.00 3,970.30 -4,618.84 -43.64191.51 544,942.006,026,757.003,920.00 0.00 4,534.66
Start Dir 3º/100' : 6501.98' MD, 3970.3'TVD - 9 5/8" x 12 1/4"
6,600.00 87.93 3,976.34 -4,714.66 -63.33191.72 544,922.896,026,661.073,926.04 3.00 4,632.49
6,700.00 90.93 3,977.34 -4,812.53 -83.81191.92 544,903.006,026,563.103,927.04 3.00 4,732.47
6,735.88 92.00 3,976.42 -4,847.61 -91.25192.00 544,895.786,026,527.973,926.12 3.00 4,768.34
End Dir : 6735.88' MD, 3976.42' TVD
6,800.00 92.00 3,974.18 -4,910.30 -104.57192.00 544,882.846,026,465.213,923.88 0.00 4,832.41
6,900.00 92.00 3,970.69 -5,008.05 -125.35192.00 544,862.656,026,367.343,920.39 0.00 4,932.35
7,000.00 92.00 3,967.20 -5,105.81 -146.13192.00 544,842.476,026,269.473,916.90 0.00 5,032.29
7,100.00 92.00 3,963.71 -5,203.56 -166.90192.00 544,822.286,026,171.603,913.41 0.00 5,132.22
7,200.00 92.00 3,960.22 -5,301.32 -187.68192.00 544,802.106,026,073.733,909.92 0.00 5,232.16
7,300.00 92.00 3,956.73 -5,399.07 -208.46192.00 544,781.916,025,975.863,906.43 0.00 5,332.09
7,400.00 92.00 3,953.24 -5,496.83 -229.24192.00 544,761.736,025,877.993,902.94 0.00 5,432.03
7,500.00 92.00 3,949.75 -5,594.58 -250.02192.00 544,741.546,025,780.133,899.45 0.00 5,531.96
7,600.00 92.00 3,946.26 -5,692.34 -270.80192.00 544,721.366,025,682.263,895.96 0.00 5,631.90
5/19/2020 4:19:31PM COMPASS 5000.15 Build 91E Page 4
Project:
Company:
Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Standard Proposal Report
Well:
Wellbore:
Plan: MPU L-60
MPU L-60
Survey Calculation Method:Minimum Curvature
MPU L-60 as-staked RKB @ 50.30usft
Design:MPU L-60 wp08
Database:NORTH US + CANADA
MD Reference:MPU L-60 as-staked RKB @ 50.30usft
North Reference:
Well Plan: MPU L-60
True
Measured
Depth
(usft)
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
Map
Northing
(usft)
Map
Easting
(usft)
+N/-S
(usft)
Planned Survey
Vertical
Depth
(usft)
TVDss
usft
DLS
3,892.47
Vert Section
7,700.00 92.00 3,942.77 -5,790.09 -291.58192.00 544,701.186,025,584.393,892.47 0.00 5,731.83
7,800.00 92.00 3,939.28 -5,887.85 -312.35192.00 544,680.996,025,486.523,888.98 0.00 5,831.77
7,900.00 92.00 3,935.79 -5,985.60 -333.13192.00 544,660.816,025,388.653,885.49 0.00 5,931.70
8,000.00 92.00 3,932.30 -6,083.36 -353.91192.00 544,640.626,025,290.783,882.00 0.00 6,031.64
8,100.00 92.00 3,928.81 -6,181.11 -374.69192.00 544,620.446,025,192.913,878.51 0.00 6,131.58
8,200.00 92.00 3,925.32 -6,278.87 -395.47192.00 544,600.256,025,095.043,875.02 0.00 6,231.51
8,300.00 92.00 3,921.83 -6,376.62 -416.25192.00 544,580.076,024,997.173,871.53 0.00 6,331.45
8,400.00 92.00 3,918.34 -6,474.38 -437.02192.00 544,559.886,024,899.303,868.04 0.00 6,431.38
8,500.00 92.00 3,914.85 -6,572.13 -457.80192.00 544,539.706,024,801.433,864.55 0.00 6,531.32
8,600.00 92.00 3,911.36 -6,669.89 -478.58192.00 544,519.516,024,703.563,861.06 0.00 6,631.25
8,700.00 92.00 3,907.87 -6,767.64 -499.36192.00 544,499.336,024,605.693,857.57 0.00 6,731.19
8,800.00 92.00 3,904.38 -6,865.40 -520.14192.00 544,479.146,024,507.823,854.08 0.00 6,831.12
8,900.00 92.00 3,900.89 -6,963.15 -540.92192.00 544,458.966,024,409.953,850.59 0.00 6,931.06
9,000.00 92.00 3,897.40 -7,060.91 -561.70192.00 544,438.776,024,312.083,847.10 0.00 7,030.99
9,100.00 92.00 3,893.91 -7,158.66 -582.47192.00 544,418.596,024,214.213,843.61 0.00 7,130.93
9,200.00 92.00 3,890.42 -7,256.42 -603.25192.00 544,398.406,024,116.343,840.12 0.00 7,230.86
9,300.00 92.00 3,886.93 -7,354.17 -624.03192.00 544,378.226,024,018.473,836.63 0.00 7,330.80
9,400.00 92.00 3,883.44 -7,451.93 -644.81192.00 544,358.036,023,920.603,833.14 0.00 7,430.74
9,500.00 92.00 3,879.95 -7,549.69 -665.59192.00 544,337.856,023,822.743,829.65 0.00 7,530.67
9,600.00 92.00 3,876.46 -7,647.44 -686.37192.00 544,317.666,023,724.873,826.16 0.00 7,630.61
9,700.00 92.00 3,872.97 -7,745.20 -707.15192.00 544,297.486,023,627.003,822.67 0.00 7,730.54
9,800.00 92.00 3,869.48 -7,842.95 -727.92192.00 544,277.296,023,529.133,819.18 0.00 7,830.48
9,900.00 92.00 3,865.99 -7,940.71 -748.70192.00 544,257.116,023,431.263,815.69 0.00 7,930.41
10,000.00 92.00 3,862.50 -8,038.46 -769.48192.00 544,236.926,023,333.393,812.20 0.00 8,030.35
10,100.00 92.00 3,859.01 -8,136.22 -790.26192.00 544,216.746,023,235.523,808.71 0.00 8,130.28
10,200.00 92.00 3,855.52 -8,233.97 -811.04192.00 544,196.556,023,137.653,805.22 0.00 8,230.22
10,300.00 92.00 3,852.03 -8,331.73 -831.82192.00 544,176.376,023,039.783,801.73 0.00 8,330.15
10,400.00 92.00 3,848.54 -8,429.48 -852.60192.00 544,156.186,022,941.913,798.24 0.00 8,430.09
10,500.00 92.00 3,845.05 -8,527.24 -873.37192.00 544,136.006,022,844.043,794.75 0.00 8,530.03
10,600.00 92.00 3,841.56 -8,624.99 -894.15192.00 544,115.816,022,746.173,791.26 0.00 8,629.96
10,700.00 92.00 3,838.07 -8,722.75 -914.93192.00 544,095.636,022,648.303,787.77 0.00 8,729.90
10,800.00 92.00 3,834.58 -8,820.50 -935.71192.00 544,075.446,022,550.433,784.28 0.00 8,829.83
10,900.00 92.00 3,831.09 -8,918.26 -956.49192.00 544,055.266,022,452.563,780.79 0.00 8,929.77
11,000.00 92.00 3,827.60 -9,016.01 -977.27192.00 544,035.076,022,354.693,777.30 0.00 9,029.70
11,100.00 92.00 3,824.11 -9,113.77 -998.04192.00 544,014.896,022,256.823,773.81 0.00 9,129.64
11,200.00 92.00 3,820.62 -9,211.52 -1,018.82192.00 543,994.706,022,158.953,770.32 0.00 9,229.57
11,300.00 92.00 3,817.13 -9,309.28 -1,039.60192.00 543,974.526,022,061.083,766.83 0.00 9,329.51
11,400.00 92.00 3,813.64 -9,407.03 -1,060.38192.00 543,954.336,021,963.213,763.34 0.00 9,429.44
11,500.00 92.00 3,810.15 -9,504.79 -1,081.16192.00 543,934.156,021,865.353,759.85 0.00 9,529.38
11,600.00 92.00 3,806.66 -9,602.54 -1,101.94192.00 543,913.966,021,767.483,756.36 0.00 9,629.32
11,700.00 92.00 3,803.17 -9,700.30 -1,122.72192.00 543,893.786,021,669.613,752.87 0.00 9,729.25
11,735.88 92.00 3,801.92 -9,735.37 -1,130.17192.00 543,886.546,021,634.493,751.62 0.00 9,765.11
Start Dir 3º/100' : 11735.88' MD, 3801.92'TVD
11,800.00 90.94 3,800.28 -9,798.25 -1,142.62190.40 543,874.476,021,571.553,749.98 3.00 9,829.20
5/19/2020 4:19:31PM COMPASS 5000.15 Build 91E Page 5
Project:
Company:
Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Standard Proposal Report
Well:
Wellbore:
Plan: MPU L-60
MPU L-60
Survey Calculation Method:Minimum Curvature
MPU L-60 as-staked RKB @ 50.30usft
Design:MPU L-60 wp08
Database:NORTH US + CANADA
MD Reference:MPU L-60 as-staked RKB @ 50.30usft
North Reference:
Well Plan: MPU L-60
True
Measured
Depth
(usft)
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
Map
Northing
(usft)
Map
Easting
(usft)
+N/-S
(usft)
Planned Survey
Vertical
Depth
(usft)
TVDss
usft
DLS
3,749.61
Vert Section
11,830.88 90.42 3,799.91 -9,828.66 -1,147.99189.62 543,869.296,021,541.113,749.61 3.00 9,860.07
End Dir : 11830.88' MD, 3799.91' TVD
11,900.00 90.42 3,799.40 -9,896.80 -1,159.54189.62 543,858.156,021,472.903,749.10 0.00 9,929.15
12,000.00 90.42 3,798.66 -9,995.39 -1,176.26189.62 543,842.026,021,374.223,748.36 0.00 10,029.09
12,100.00 90.42 3,797.92 -10,093.98 -1,192.98189.62 543,825.906,021,275.543,747.62 0.00 10,129.04
12,200.00 90.42 3,797.18 -10,192.57 -1,209.70189.62 543,809.786,021,176.873,746.88 0.00 10,228.98
12,300.00 90.42 3,796.44 -10,291.16 -1,226.42189.62 543,793.666,021,078.193,746.14 0.00 10,328.92
12,400.00 90.42 3,795.70 -10,389.75 -1,243.14189.62 543,777.546,020,979.513,745.40 0.00 10,428.87
12,500.00 90.42 3,794.96 -10,488.34 -1,259.86189.62 543,761.426,020,880.833,744.66 0.00 10,528.81
12,600.00 90.42 3,794.22 -10,586.93 -1,276.57189.62 543,745.306,020,782.153,743.92 0.00 10,628.75
12,700.00 90.42 3,793.48 -10,685.52 -1,293.29189.62 543,729.186,020,683.473,743.18 0.00 10,728.69
12,800.00 90.42 3,792.74 -10,784.11 -1,310.01189.62 543,713.066,020,584.793,742.44 0.00 10,828.64
12,900.00 90.42 3,792.00 -10,882.70 -1,326.73189.62 543,696.946,020,486.113,741.70 0.00 10,928.58
13,000.00 90.42 3,791.26 -10,981.29 -1,343.45189.62 543,680.826,020,387.433,740.96 0.00 11,028.52
13,100.00 90.42 3,790.52 -11,079.88 -1,360.17189.62 543,664.706,020,288.753,740.22 0.00 11,128.47
13,129.14 90.42 3,790.30 -11,108.60 -1,365.04189.62 543,660.006,020,260.003,740.00 0.00 11,157.59
Total Depth : 13129.14' MD, 3790.3' TVD
Target Name
- hit/miss target
- Shape
TVD
(usft)
Northing
(usft)
Easting
(usft)
+N/-S
(usft)
+E/-W
(usft)
Tar gets
Dip Angle
(°)
Dip Dir.
(°)
MPI-L-60 wp01 Heel 3,970.30 6,026,757.00 544,942.00-4,618.84 -43.640.00 0.00
-plan hits target center
- Point
MPI-L-60 wp01 Toe 3,790.30 6,020,260.00 543,660.00-11,108.60 -1,365.040.00 0.00
-plan hits target center
- Point
Vertical
Depth
(usft)
Measured
Depth
(usft)
Casing
Diameter
(")
Hole
Diameter
(")Name
Casing Points
9 5/8" x 12 1/4"3,970.306,501.98 9-5/8 12-1/4
6 5/8" x 8 1/2"3,790.3013,129.14 6-5/8 8-1/2
5/19/2020 4:19:31PM COMPASS 5000.15 Build 91E Page 6
Project:
Company:
Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt L Pad
Halliburton
Standard Proposal Report
Well:
Wellbore:
Plan: MPU L-60
MPU L-60
Survey Calculation Method:Minimum Curvature
MPU L-60 as-staked RKB @ 50.30usft
Design:MPU L-60 wp08
Database:NORTH US + CANADA
MD Reference:MPU L-60 as-staked RKB @ 50.30usft
North Reference:
Well Plan: MPU L-60
True
Measured
Depth
(usft)
Vertical
Depth
(usft)
+E/-W
(usft)
+N/-S
(usft)
Local Coordinates
Comment
Plan Annotations
280.00 280.00 0.00 0.00 Start Dir 3º/100' : 280' MD, 280'TVD
550.00 549.10 -19.05 0.55 Start Dir 4º/100' : 550' MD, 549.1'TVD
1,690.05 1,501.71 -588.95 17.06 End Dir : 1690.05' MD, 1501.71' TVD
5,313.11 3,646.51 -3,507.73 101.69 Start Dir 4º/100' : 5313.11' MD, 3646.51'TVD
6,151.98 3,939.80 -4,277.19 25.93 End Dir : 6151.98' MD, 3939.8' TVD
6,501.98 3,970.30 -4,618.84 -43.64 Start Dir 3º/100' : 6501.98' MD, 3970.3'TVD
6,735.88 3,976.42 -4,847.61 -91.25 End Dir : 6735.88' MD, 3976.42' TVD
11,735.88 3,801.92 -9,735.37 -1,130.17 Start Dir 3º/100' : 11735.88' MD, 3801.92'TVD
11,830.88 3,799.91 -9,828.66 -1,147.99 End Dir : 11830.88' MD, 3799.91' TVD
13,129.14 3,790.30 -11,108.60 -1,365.04 Total Depth : 13129.14' MD, 3790.3' TVD
5/19/2020 4:19:31PM COMPASS 5000.15 Build 91E Page 7
19 May, 2020Milne PointM Pt L PadPlan: MPU L-60MPU L-60MPU L-60 wp08Reference Design: M Pt L Pad - Plan: MPU L-60 - MPU L-60 - MPU L-60 wp08Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Well Coordinates: 6,031,375.57 N, 544,957.70 E (70° 29' 47.71" N, 149° 37' 56.53" W)Datum Height: MPU L-60 as-staked RKB @ 50.30usftScan Range: 33.70 to 6,501.98 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.00Scan Range: 33.70 to 6,501.98 usft. Measured Depth.0- 6500 ft
Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU L-60 - MPU L-60 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 33.70 to 6,501.98 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt L Pad - Plan: MPU L-60 - MPU L-60 - MPU L-60 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt L PadMPL-01 - MPL-01 - MPL-01233.92 33.70 232.35 39.40 149.02933.70Centre Distance Pass - MPL-01 - MPL-01 - MPL-01234.40 308.70 230.48 313.51 59.767308.70Ellipse Separation Pass - MPL-01 - MPL-01 - MPL-01312.66 908.70 301.89 900.62 29.022908.70Clearance Factor Pass - MPL-01 - MPL-01A - MPL-01A233.92 33.70 232.35 39.40 149.02933.70Centre Distance Pass - MPL-01 - MPL-01A - MPL-01A234.40 308.70 230.48 313.51 59.767308.70Ellipse Separation Pass - MPL-01 - MPL-01A - MPL-01A312.66 908.70 301.89 900.62 29.022908.70Clearance Factor Pass - MPL-02 - MPL-02 - MPL-02134.59 33.70 133.17 39.40 95.26933.70Centre Distance Pass - MPL-02 - MPL-02 - MPL-02134.83 333.70 131.58 339.27 41.382333.70Ellipse Separation Pass - MPL-02 - MPL-02 - MPL-02167.30 808.70 160.21 806.46 23.593808.70Clearance Factor Pass - MPL-02 - MPL-02A - MPL-02A134.59 33.70 133.17 39.40 95.26933.70Centre Distance Pass - MPL-02 - MPL-02A - MPL-02A134.83 333.70 131.58 339.27 41.382333.70Ellipse Separation Pass - MPL-02 - MPL-02A - MPL-02A167.30 808.70 160.21 806.46 23.593808.70Clearance Factor Pass - MPL-02 - MPL-02AL1 - MPL-02AL1134.59 33.70 133.17 39.40 95.26933.70Centre Distance Pass - MPL-02 - MPL-02AL1 - MPL-02AL1134.83 333.70 131.58 339.27 41.382333.70Ellipse Separation Pass - MPL-02 - MPL-02AL1 - MPL-02AL1167.30 808.70 160.21 806.46 23.593808.70Clearance Factor Pass - MPL-02 - MPL-02AL2 - MPL-02AL2134.59 33.70 133.17 39.40 95.26933.70Centre Distance Pass - MPL-02 - MPL-02AL2 - MPL-02AL2134.83 333.70 131.58 339.27 41.382333.70Ellipse Separation Pass - MPL-02 - MPL-02AL2 - MPL-02AL2167.30 808.70 160.21 806.46 23.593808.70Clearance Factor Pass - MPL-02 - MPL-02APB1 - MPL-02APB1134.59 33.70 133.17 39.40 95.26933.70Centre Distance Pass - MPL-02 - MPL-02APB1 - MPL-02APB1134.83 333.70 131.58 339.27 41.382333.70Ellipse Separation Pass - MPL-02 - MPL-02APB1 - MPL-02APB1167.30 808.70 160.21 806.46 23.593808.70Clearance Factor Pass - MPL-02 - MPL-02APB2 - MPL-02APB2134.59 33.70 133.17 39.40 95.26933.70Centre Distance Pass - MPL-02 - MPL-02APB2 - MPL-02APB2134.83 333.70 131.58 339.27 41.382333.70Ellipse Separation Pass - MPL-02 - MPL-02APB2 - MPL-02APB2167.30 808.70 160.21 806.46 23.593808.70Clearance Factor Pass - MPL-03 - MPL-03 - MPL-03182.56 33.70 181.15 38.40 129.23133.70Centre Distance Pass - MPL-03 - MPL-03 - MPL-03183.42 258.70 180.62 262.00 65.508258.70Ellipse Separation Pass - MPL-03 - MPL-03 - MPL-03240.26 808.70 233.14 788.00 33.779808.70Clearance Factor Pass - MPL-04 - MPL-04 - MPL-0414.16 308.37 10.99 314.18 4.461308.37Centre Distance Pass - 19 May, 2020-16:18COMPASSPage 2 of 8
Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU L-60 - MPU L-60 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 33.70 to 6,501.98 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt L Pad - Plan: MPU L-60 - MPU L-60 - MPU L-60 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPL-04 - MPL-04 - MPL-0414.27 333.70 10.91 339.50 4.243333.70Ellipse Separation Pass - MPL-04 - MPL-04 - MPL-0415.34 383.70 11.60 389.40 4.104383.70Clearance Factor Pass - MPL-05 - MPL-05 - MPL-0573.27 308.44 70.18 314.70 23.763308.44Centre Distance Pass - MPL-05 - MPL-05 - MPL-0573.36 333.70 70.09 339.96 22.423333.70Ellipse Separation Pass - MPL-05 - MPL-05 - MPL-0587.82 583.70 82.62 587.16 16.875583.70Clearance Factor Pass - MPL-06 - MPL-06 - MPL-0638.87 593.77 33.59 598.11 7.357593.77Centre Distance Pass - MPL-06 - MPL-06 - MPL-0638.93 608.70 33.53 612.96 7.202608.70Ellipse Separation Pass - MPL-06 - MPL-06 - MPL-0640.47 658.70 34.64 662.29 6.941658.70Clearance Factor Pass - MPL-11 - MPL-11 - MPL-11135.21 33.70 133.64 34.40 86.19633.70Centre Distance Pass - MPL-11 - MPL-11 - MPL-11135.22 58.70 133.61 59.24 83.60258.70Ellipse Separation Pass - MPL-11 - MPL-11 - MPL-11170.92 658.70 166.16 643.15 35.862658.70Clearance Factor Pass - MPL-12 - MPL-12 - MPL-12104.18 484.56 100.97 484.07 32.503484.56Centre Distance Pass - MPL-12 - MPL-12 - MPL-12104.33 533.70 100.84 533.00 29.868533.70Ellipse Separation Pass - MPL-12 - MPL-12 - MPL-12123.81 808.70 118.52 802.82 23.398808.70Clearance Factor Pass - MPL-15 - MPL-15 - MPL-15156.31 108.70 154.30 106.35 77.471108.70Centre Distance Pass - MPL-15 - MPL-15 - MPL-15156.34 133.70 154.25 130.97 74.742133.70Ellipse Separation Pass - MPL-15 - MPL-15 - MPL-15201.80 758.70 196.14 741.16 35.666758.70Clearance Factor Pass - MPL-15 - MPL-15PB1 - MPL-15PB1156.31 108.70 154.30 106.35 77.471108.70Centre Distance Pass - MPL-15 - MPL-15PB1 - MPL-15PB1156.34 133.70 154.25 130.97 74.742133.70Ellipse Separation Pass - MPL-15 - MPL-15PB1 - MPL-15PB1201.80 758.70 196.14 741.16 35.666758.70Clearance Factor Pass - MPL-34 - MPL-34 - MPL-34207.76 33.70 206.35 34.28 147.06833.70Centre Distance Pass - MPL-34 - MPL-34 - MPL-34207.97 283.70 205.85 284.10 98.071283.70Ellipse Separation Pass - MPL-34 - MPL-34 - MPL-34277.75 883.70 272.86 869.50 56.757883.70Clearance Factor Pass - MPL-35 - MPL-35 - MPL-3511.24 554.10 6.28 553.54 2.264554.10Centre Distance Pass - MPL-35 - MPL-35 - MPL-3511.25 558.70 6.25 558.13 2.249558.70Ellipse Separation Pass - MPL-35 - MPL-35 - MPL-3511.56 583.70 6.36 583.02 2.222583.70Clearance Factor Pass - MPL-35 - MPL-35A - MPL-35A11.24 554.10 6.28 554.34 2.264554.10Centre Distance Pass - MPL-35 - MPL-35A - MPL-35A11.25 558.70 6.25 558.93 2.249558.70Ellipse Separation Pass - MPL-35 - MPL-35A - MPL-35A11.56 583.70 6.36 583.82 2.222583.70Clearance Factor Pass - MPL-35 - MPL-35APB1 - MPL-35APB111.24 554.10 6.28 554.34 2.264554.10Centre Distance Pass - 19 May, 2020-16:18COMPASSPage 3 of 8
Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU L-60 - MPU L-60 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 33.70 to 6,501.98 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt L Pad - Plan: MPU L-60 - MPU L-60 - MPU L-60 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPL-35 - MPL-35APB1 - MPL-35APB111.25 558.70 6.25 558.93 2.249558.70Ellipse Separation Pass - MPL-35 - MPL-35APB1 - MPL-35APB111.56 583.70 6.36 583.82 2.222583.70Clearance Factor Pass - MPL-35 - MPL-35APB2 - MPL-35APB211.24 554.10 6.28 554.34 2.264554.10Centre Distance Pass - MPL-35 - MPL-35APB2 - MPL-35APB211.25 558.70 6.25 558.93 2.249558.70Ellipse Separation Pass - MPL-35 - MPL-35APB2 - MPL-35APB211.56 583.70 6.36 583.82 2.222583.70Clearance Factor Pass - MPL-35 - MPL-35APB3 - MPL-35APB311.24 554.10 6.28 554.34 2.264554.10Centre Distance Pass - MPL-35 - MPL-35APB3 - MPL-35APB311.25 558.70 6.25 558.93 2.249558.70Ellipse Separation Pass - MPL-35 - MPL-35APB3 - MPL-35APB311.56 583.70 6.36 583.82 2.222583.70Clearance Factor Pass - MPL-36 - MPL-36 - MPL-3644.75 328.51 41.43 329.07 13.471328.51Centre Distance Pass - MPL-36 - MPL-36 - MPL-3645.00 383.70 41.26 384.68 12.039383.70Ellipse Separation Pass - MPL-36 - MPL-36 - MPL-3651.52 533.70 46.62 534.00 10.513533.70Clearance Factor Pass - MPL-36 - MPL-36L1 - MPL-36L144.75 328.51 41.43 329.07 13.471328.51Centre Distance Pass - MPL-36 - MPL-36L1 - MPL-36L145.00 383.70 41.26 384.68 12.039383.70Ellipse Separation Pass - MPL-36 - MPL-36L1 - MPL-36L151.52 533.70 46.62 534.00 10.513533.70Clearance Factor Pass - MPL-36 - MPL-36L1 PB1 - MPL-36L1 PB144.75 328.51 41.43 329.07 13.471328.51Centre Distance Pass - MPL-36 - MPL-36L1 PB1 - MPL-36L1 PB145.00 383.70 41.26 384.68 12.039383.70Ellipse Separation Pass - MPL-36 - MPL-36L1 PB1 - MPL-36L1 PB151.52 533.70 46.62 534.00 10.513533.70Clearance Factor Pass - MPL-36 - MPL-36PB1 - MPL-36PB144.75 328.51 41.43 329.07 13.471328.51Centre Distance Pass - MPL-36 - MPL-36PB1 - MPL-36PB145.00 383.70 41.26 384.68 12.039383.70Ellipse Separation Pass - MPL-36 - MPL-36PB1 - MPL-36PB151.52 533.70 46.62 534.00 10.513533.70Clearance Factor Pass - MPL-37 - MPL-37 - MPL-37104.26 33.70 102.42 20.88 56.46433.70Centre Distance Pass - MPL-37 - MPL-37 - MPL-37104.31 58.70 102.40 45.49 54.45158.70Ellipse Separation Pass - MPL-37 - MPL-37 - MPL-37136.42 808.70 129.36 799.75 19.324808.70Clearance Factor Pass - MPL-37 - MPL-37A - MPL-37A104.26 33.70 102.42 30.08 56.46433.70Centre Distance Pass - MPL-37 - MPL-37A - MPL-37A104.31 58.70 102.40 54.69 54.45158.70Ellipse Separation Pass - MPL-37 - MPL-37A - MPL-37A136.42 808.70 129.36 808.95 19.324808.70Clearance Factor Pass - MPL-40 - MPL-40 - MPL-40102.84 33.70 101.43 33.99 72.71833.70Centre Distance Pass - MPL-40 - MPL-40 - MPL-40103.18 133.70 101.24 133.30 53.199133.70Ellipse Separation Pass - MPL-40 - MPL-40 - MPL-40126.21 808.70 118.99 791.58 17.475808.70Clearance Factor Pass - MPL-45 - MPL-45 - MPL-45415.99 33.70 414.42 34.15 265.31533.70Centre Distance Pass - 19 May, 2020-16:18COMPASSPage 4 of 8
Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU L-60 - MPU L-60 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 33.70 to 6,501.98 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt L Pad - Plan: MPU L-60 - MPU L-60 - MPU L-60 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPL-45 - MPL-45 - MPL-45606.71 6,501.98 375.08 7,244.50 2.6196,501.98Clearance Factor Pass - MPL-46 - MPL-46 - MPL-46224.10 33.70 222.68 30.89 158.31433.70Centre Distance Pass - MPL-46 - MPL-46 - MPL-46225.10 283.70 221.46 278.39 61.750283.70Ellipse Separation Pass - MPL-46 - MPL-46 - MPL-46585.76 5,708.70 514.79 7,739.95 8.2535,708.70Clearance Factor Pass - MPL-46 - MPL-46 PB1 - MPL-46 PB1224.10 33.70 222.68 30.89 158.31433.70Centre Distance Pass - MPL-46 - MPL-46 PB1 - MPL-46 PB1225.10 283.70 221.46 278.39 61.750283.70Ellipse Separation Pass - MPL-46 - MPL-46 PB1 - MPL-46 PB1585.76 5,708.70 514.61 7,739.95 8.2345,708.70Clearance Factor Pass - MPL-47 - MPL-47 - MPL-47328.07 474.16 322.03 501.00 54.291474.16Centre Distance Pass - MPL-47 - MPL-47 - MPL-47328.31 508.70 321.88 535.85 51.041508.70Ellipse Separation Pass - MPL-47 - MPL-47 - MPL-47830.20 6,501.98 745.63 8,692.06 9.8176,501.98Clearance Factor Pass - MPL-47 - MPL-47 PB1 - MPL-47 PB1328.07 474.16 322.03 501.00 54.291474.16Centre Distance Pass - MPL-47 - MPL-47 PB1 - MPL-47 PB1328.31 508.70 321.88 535.85 51.041508.70Ellipse Separation Pass - MPL-47 - MPL-47 PB1 - MPL-47 PB1830.20 6,501.98 745.45 8,692.06 9.7976,501.98Clearance Factor Pass - MPL-48 - MPL-48 - MPL-48181.78 6,357.22 140.89 8,315.34 4.4466,357.22Centre Distance Pass - MPL-48 - MPL-48 - MPL-48187.87 6,408.70 136.62 8,335.38 3.6666,408.70Ellipse Separation Pass - MPL-48 - MPL-48 - MPL-48225.33 6,501.98 154.37 8,372.48 3.1766,501.98Clearance Factor Pass - MPL-48 - MPL-48PB1 - MPL-48PB1194.52 33.70 193.10 30.89 137.41433.70Centre Distance Pass - MPL-48 - MPL-48PB1 - MPL-48PB1195.17 308.70 191.23 305.59 49.587308.70Ellipse Separation Pass - MPL-48 - MPL-48PB1 - MPL-48PB1267.71 933.70 256.51 916.82 23.897933.70Clearance Factor Pass - MPL-48 - MPL-48PB2 - MPL-48PB2194.52 33.70 193.10 30.89 137.41433.70Centre Distance Pass - MPL-48 - MPL-48PB2 - MPL-48PB2195.17 308.70 191.23 305.59 49.587308.70Ellipse Separation Pass - MPL-48 - MPL-48PB2 - MPL-48PB21,548.09 5,683.70 1,445.07 6,627.00 15.0275,683.70Clearance Factor Pass - MPL-48 - MPL-48PB3 - MPL-48 PB3181.78 6,357.22 140.72 8,315.34 4.4276,357.22Centre Distance Pass - MPL-48 - MPL-48PB3 - MPL-48 PB3187.87 6,408.70 136.45 8,335.38 3.6546,408.70Ellipse Separation Pass - MPL-48 - MPL-48PB3 - MPL-48 PB3225.33 6,501.98 154.20 8,372.48 3.1686,501.98Clearance Factor Pass - MPL-50 - MPL-50 - MPL-50124.11 1,342.18 115.25 1,440.96 14.0021,342.18Centre Distance Pass - MPL-50 - MPL-50 - MPL-50124.31 1,358.70 115.21 1,457.48 13.6681,358.70Ellipse Separation Pass - MPL-50 - MPL-50 - MPL-50158.28 1,558.70 144.38 1,649.58 11.3821,558.70Clearance Factor Pass - Plan: MPU L-59i - MPU L-59i - MPU L-59i wp07655.87 258.70 653.40 259.10 264.697258.70Centre Distance Pass - Plan: MPU L-59i - MPU L-59i - MPU L-59i wp07655.88 283.70 653.29 284.10 253.948283.70Ellipse Separation Pass - Plan: MPU L-59i - MPU L-59i - MPU L-59i wp07793.47 6,501.98 660.22 6,989.50 5.9556,501.98Clearance Factor Pass - 19 May, 2020-16:18COMPASSPage 5 of 8
Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU L-60 - MPU L-60 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 33.70 to 6,501.98 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt L Pad - Plan: MPU L-60 - MPU L-60 - MPU L-60 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningPlan: MPU L-61i - MPU L-61i - MPU L-61 wp05508.17 258.70 505.70 257.30 205.041258.70Centre Distance Pass - Plan: MPU L-61i - MPU L-61i - MPU L-61 wp05508.18 283.70 505.59 282.30 196.682283.70Ellipse Separation Pass - Plan: MPU L-61i - MPU L-61i - MPU L-61 wp05766.57 6,501.98 630.24 8,001.45 5.6236,501.98Clearance Factor Pass - Plan: MPU L-62 - MPU L-62 - MPU L-61 wp04119.70 283.70 117.14 283.66 46.641283.70Centre Distance Pass - Plan: MPU L-62 - MPU L-62 - MPU L-61 wp04119.79 308.70 117.12 308.69 44.809308.70Ellipse Separation Pass - Plan: MPU L-62 - MPU L-62 - MPU L-61 wp041,552.16 6,501.98 1,415.72 7,126.16 11.3756,501.98Clearance Factor Pass - Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool33.70 900.00 MPU L-60 wp08 3_Gyro-GC_Csg900.00 6,501.98 MPU L-60 wp08 3_MWD+IFR2+MS+Sag6,501.98 13,129.14 MPU L-60 wp08 3_MWD+IFR2+MS+SagEllipse error terms are correlated across survey tool tie-on points.Separation is the actual distance between ellipsoids.Calculated ellipses incorporate surface errors.Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).Distance Between centres is the straight line distance between wellbore centres.All station coordinates were calculated using the Minimum Curvature method.19 May, 2020-16:18COMPASSPage 6 of 8
0.001.002.003.004.00Separation Factor0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650Measured Depth (700 usft/in)MPL-45No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU L-60 NAD 1927 (NADCON CONUS)Alaska Zone 0416.60+N/-S +E/-W Northing Easting Latittude Longitude0.000.006031375.57544957.70 70° 29' 47.709 N 149° 37' 56.530 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU L-60, True NorthVertical (TVD) Reference:MPU L-60 as-staked RKB @ 50.30usftMeasured Depth Reference:MPU L-60 as-staked RKB @ 50.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-05-06T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 900.00 MPU L-60 wp08 (MPU L-60) 3_Gyro-GC_Csg900.00 6501.98 MPU L-60 wp08 (MPU L-60) 3_MWD+IFR2+MS+Sag6501.98 13129.14 MPU L-60 wp08 (MPU L-60) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650Measured Depth (700 usft/in)MPL-04MPL-05MPL-06MPL-12MPL-35MPL-36MPL-37MPL-40NO GLOBAL FILTER: Using user defined selection & filtering criteria33.70 To 13129.14Project: Milne PointSite: M Pt L PadWell: Plan: MPU L-60Wellbore: MPU L-60Plan: MPU L-60 wp08Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3970.30 3920.00 6501.98 9-5/8 9 5/8" x 12 1/4"3790.30 3740.00 13129.14 6-5/8 6 5/8" x 8 1/2"
19 May, 2020Milne PointM Pt L PadPlan: MPU L-60MPU L-60MPU L-60 wp08Reference Design: M Pt L Pad - Plan: MPU L-60 - MPU L-60 - MPU L-60 wp08Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Well Coordinates: 6,031,375.57 N, 544,957.70 E (70° 29' 47.71" N, 149° 37' 56.53" W)Datum Height: MPU L-60 as-staked RKB @ 50.30usftScan Range: 6,501.98 to 13,129.14 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.006500-13130 ftScan Range: 6,501.98 to 13,129.14 usft. Measured Depth.
Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU L-60 - MPU L-60 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 6,501.98 to 13,129.14 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt L Pad - Plan: MPU L-60 - MPU L-60 - MPU L-60 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt L PadMPL-45 - MPL-45 - MPL-45442.518,626.98139.009,365.001.4588,626.98Clearance FactorPass - MPL-45 - MPL-45 - MPL-45441.988,648.60139.699,365.001.4628,648.60Centre DistancePass - MPL-46 - MPL-46 - MPL-461,206.79 6,501.98 1,116.12 8,069.46 13.3106,501.98Clearance Factor Pass - MPL-46 - MPL-46 PB1 - MPL-46 PB11,206.79 6,501.98 1,115.95 8,069.46 13.2856,501.98Clearance Factor Pass - MPL-47 - MPL-47 - MPL-47184.23 7,410.25 138.94 9,110.16 4.0677,410.25Centre Distance Pass - MPL-47 - MPL-47 - MPL-47188.09 7,451.98 137.37 9,127.62 3.7097,451.98Ellipse Separation Pass - MPL-47 - MPL-47 - MPL-47224.80 7,551.98 154.62 9,169.36 3.2037,551.98Clearance Factor Pass - MPL-47 - MPL-47 PB1 - MPL-47 PB1184.23 7,410.25 138.77 9,110.16 4.0527,410.25Centre Distance Pass - MPL-47 - MPL-47 PB1 - MPL-47 PB1188.09 7,451.98 137.20 9,127.62 3.6967,451.98Ellipse Separation Pass - MPL-47 - MPL-47 PB1 - MPL-47 PB1224.80 7,551.98 154.45 9,169.36 3.1957,551.98Clearance Factor Pass - MPL-48 - MPL-48 - MPL-48225.33 6,501.98 154.37 8,372.48 3.1766,501.98Clearance Factor Pass - MPL-48 - MPL-48PB3 - MPL-48 PB3225.33 6,501.98 154.20 8,372.48 3.1686,501.98Clearance Factor Pass - MPL-50 - MPL-50 - MPL-50192.96 8,551.07 140.75 10,244.35 3.6968,551.07Centre Distance Pass - MPL-50 - MPL-50 - MPL-50198.61 8,601.98 139.31 10,264.37 3.3498,601.98Ellipse Separation Pass - MPL-50 - MPL-50 - MPL-50237.75 8,701.98 158.76 10,304.88 3.0108,701.98Clearance Factor Pass - Plan: MPU L-59i - MPU L-59i - MPU L-59i wp07732.31 11,763.20 511.88 12,249.67 3.32211,763.20Centre Distance Pass - Plan: MPU L-59i - MPU L-59i - MPU L-59i wp07733.18 11,826.98 511.34 12,313.44 3.30511,826.98Ellipse Separation Pass - Plan: MPU L-59i - MPU L-59i - MPU L-59i wp07771.67 13,126.98 520.31 13,607.87 3.07013,126.98Clearance Factor Pass - Plan: MPU L-61i - MPU L-61i - MPU L-61 wp05744.47 13,129.14 491.92 14,628.35 2.94813,129.14Clearance Factor Pass - Plan: MPU L-62 - MPU L-62 - MPU L-61 wp041,425.42 13,129.14 1,172.39 13,728.20 5.63313,129.14Clearance Factor Pass - M Pt Moose PadMPU M-10 - MPU M-10 - MPU M-10256.32 9,276.98 107.64 13,461.11 1.7249,276.98Clearance Factor Pass - MPU M-10 - MPU M-10 - MPU M-10229.35 9,326.98 102.06 13,481.58 1.8029,326.98Ellipse Separation Pass - MPU M-10 - MPU M-10 - MPU M-10194.63 9,460.52 138.39 13,537.05 3.4609,460.52Centre Distance Pass - MPU M-10 - MPU M-10PB1 - MPU M-10PB1956.21 8,701.98 754.00 12,630.00 4.7298,701.98Clearance Factor Pass - MPU M-10 - MPU M-10PB1 - MPU M-10PB1866.48 9,001.98 700.76 12,630.00 5.2299,001.98Ellipse Separation Pass - MPU M-10 - MPU M-10PB1 - MPU M-10PB1857.77 9,124.55 709.84 12,630.00 5.7999,124.55Centre Distance Pass - 19 May, 2020-16:20COMPASSPage 2 of 6
Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU L-60 - MPU L-60 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 6,501.98 to 13,129.14 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt L Pad - Plan: MPU L-60 - MPU L-60 - MPU L-60 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPU M-10 - MPU M-10PB2 - MPU M-10PB2778.62 8,851.98 582.07 12,820.00 3.9618,851.98Clearance Factor Pass - MPU M-10 - MPU M-10PB2 - MPU M-10PB2708.14 9,076.98 544.14 12,820.00 4.3189,076.98Ellipse Separation Pass - MPU M-10 - MPU M-10PB2 - MPU M-10PB2697.84 9,197.35 554.57 12,820.00 4.8719,197.35Centre Distance Pass - MPU M-10 - MPU M-10PB3 - MPU M-10PB3240.76 9,251.98 85.47 13,459.08 1.5509,251.98Clearance Factor Pass - MPU M-10 - MPU M-10PB3 - MPU M-10PB3212.80 9,301.98 81.63 13,476.60 1.6229,301.98Ellipse Separation Pass - MPU M-10 - MPU M-10PB3 - MPU M-10PB3181.01 9,421.32 122.89 13,518.11 3.1149,421.32Centre Distance Pass - MPU M-11 - MPU M-11 - MPU M-11241.8810,151.9846.0414,021.171.23510,151.98Clearance FactorPass - MPU M-11 - MPU M-11 - MPU M-11226.9010,176.9844.3414,030.461.24310,176.98Ellipse SeparationPass - MPU M-11 - MPU M-11 - MPU M-11179.66 10,324.83 109.80 14,083.28 2.57210,324.83Centre Distance Pass - MPU M-12 - MPU M-12 - MPU M-12235.8111,076.9824.8214,590.041.11811,076.98Clearance FactorPass - MPU M-12 - MPU M-12 - MPU M-12181.17 11,242.08 102.27 14,655.70 2.29611,242.08Centre Distance Pass - MPU M-12 - MPU M-12PB2 - MPU M-12PB2235.8111,076.9824.7014,590.041.11711,076.98Clearance FactorPass - MPU M-12 - MPU M-12PB2 - MPU M-12PB2181.17 11,242.08 102.14 14,655.70 2.29211,242.08Centre Distance Pass - MPU M-13 - MPU M-13i - MPU M-13164.34 12,158.23 87.34 14,384.94 2.13412,158.23Centre Distance Pass - MPU M-13 - MPU M-13i - MPU M-13225.2212,326.988.8414,452.001.04112,326.98Clearance FactorPass - MPU M-14 - MPU M-14 - MPU M-14269.8912,851.9850.1514,679.841.22812,851.98Clearance FactorPass - MPU M-14 - MPU M-14 - MPU M-14255.5212,876.9849.2114,690.951.23912,876.98Ellipse SeparationPass - MPU M-14 - MPU M-14 - MPU M-14202.74 13,048.35 120.05 14,765.49 2.45213,048.35Centre Distance Pass - MPU M-15i - MPU M-15 - MPU M-15i756.07 13,129.14 475.74 14,688.09 2.69713,129.14Clearance Factor Pass - Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool33.70 900.00 MPU L-60 wp08 3_Gyro-GC_Csg900.00 6,501.98 MPU L-60 wp08 3_MWD+IFR2+MS+Sag6,501.98 13,129.14 MPU L-60 wp08 3_MWD+IFR2+MS+Sag19 May, 2020-16:20COMPASSPage 3 of 6
Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU L-60 - MPU L-60 wp08Ellipse error terms are correlated across survey tool tie-on points.Separation is the actual distance between ellipsoids.Calculated ellipses incorporate surface errors.Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).Distance Between centres is the straight line distance between wellbore centres.All station coordinates were calculated using the Minimum Curvature method.19 May, 2020-16:20COMPASSPage 4 of 6
0.001.002.003.004.00Separation Factor6750 7125 7500 7875 8250 8625 9000 9375 9750 10125 10500 10875 11250 11625 12000 12375 12750 13125 13500Measured Depth (750 usft/in)MPL-45MPU L-61 wp05MPU M-10No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU L-60 NAD 1927 (NADCON CONUS)Alaska Zone 0416.60+N/-S +E/-W Northing Easting Latittude Longitude0.000.00 6031375.57 544957.7070° 29' 47.709 N149° 37' 56.530 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU L-60, True NorthVertical (TVD) Reference:MPU L-60 as-staked RKB @ 50.30usftMeasured Depth Reference:MPU L-60 as-staked RKB @ 50.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-05-06T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 900.00 MPU L-60 wp08 (MPU L-60) 3_Gyro-GC_Csg900.00 6501.98 MPU L-60 wp08 (MPU L-60) 3_MWD+IFR2+MS+Sag6501.98 13129.14 MPU L-60 wp08 (MPU L-60) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6750 7125 7500 7875 8250 8625 9000 9375 9750 10125 10500 10875 11250 11625 12000 12375 12750 13125 13500Measured Depth (750 usft/in)NO GLOBAL FILTER: Using user defined selection & filtering criteria33.70 To 13129.14Project: Milne PointSite: M Pt L PadWell: Plan: MPU L-60Wellbore: MPU L-60Plan: MPU L-60 wp08Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name3970.30 3920.00 6501.98 9-5/8 9 5/8" x 12 1/4"3790.30 3740.00 13129.14 6-5/8 6 5/8" x 8 1/2"
WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:MILNE PT UNIT L-60Initial Class/TypeDEV / PENDGeoArea890Unit11328On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2200480MILNE POINT, SCHRADER BLFF OIL - 525140NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberYes Milne Point Schrader Bluff Oil Pool (525140), governed by CO 477, amended by CO 477.05.4 Well located in a defined poolYes CO 477.05 specifies: “There are no restrictions as to well spacing except that no pay shall5 Well located proper distance from drilling unit boundaryYes be opened in a well closer than 500 feet from the exterior boundary of the affected area.”6 Well located proper distance from other wellsYes As planned, well conforms to spacing requirements.7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes conductor set at 114 ft18 Conductor string providedNA ( 9 5/8 will be tapered 40 lb x 47 lb)19 Surface casing protects all known USDWsYes 9 5/8" will be fully cemented … 2 stage with ES at 2500 ft20 CMT vol adequate to circulate on conductor & surf csgNo lateral will have slotted liner. Not cemented.21 CMT vol adequate to tie-in long string to surf csgYes (running a 7 5/8" tie back for extra annulis)22 CMT will cover all known productive horizonsYes BTC supplied23 Casing designs adequate for C, T, B & permafrostYes Rig Doyon 14 has steel pits.24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes No issues with anti collision26 Adequate wellbore separation proposedYes Doyon 14 has 16 " diverter. Map of layout is provided.27 If diverter required, does it meet regulationsYes Max form pressure = 1790 psi (8.5 ppg ) will drill with 8.9-9.5 ppg mud )28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MASP = 1390 psi will test BOPE to 3000 psi (annular to 2500 psi)30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)Yes None observed in offset wells. Rig will have functioning, automatic detectors.35 Permit can be issued w/o hydrogen sulfide measuresYes Hydrates or geo-pressure not expected from drilling of offset wells.36 Data presented on potential overpressure zonesNA Planned mud program appears adequate to control operator's forecast formation pressures.37 Seismic analysis of shallow gas zonesNA Managed Pressure Drilling will be used to monitor and mitigate any abnormal pressure encountered.38 Seabed condition survey (if off-shore)NA Other mitigation measures are discussed in drilling hazards section on pages 47-49.39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate5/26/2020ApprGLSDate6/1/2020ApprSFDDate5/26/2020AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJMP 6/2/2020dts 6/1/2020JLC 6/1/2020
