Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout219-031STATE OF ALASKA Reviewed By:
OIL AND GAS CONSERVATION COMMISSION
P.1. S u p r v
BOPE Test Report for: MILNE PT UNIT E-41 Comm
Contractor/Rig No.: Hilcorp ASR I PTD#: 2190310 DATE: 8/6/2020 Inspector Lou Laubenstein " Insp Source
Operator: Hilcorp Alaska, LLC Operator Rep: Wade hudgens Rig Rep: Jon Hoskins Inspector
Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopL01-200810085559
Type Test: INIT 320-291
Rams: Annular: Valves: NIASP:
250/2500 - 250/2500- 250/2500 - 1072 - Related Insp No:
TEST DATA
MISC. INSPECTIONS:
MUD SYSTEM:
ACCUMULATOR SYSTEM:
Upper Kelly
0 -
P/F
Lower Kelly
Visual
Alarm
Time/Pressure
1
P/F
Location Gen.:
P
Trip Tank
NA
NA
System Pressure
3050 -
- P-
Housekeeping:
P-
Pit Level Indicators
P
P
Pressure After Closure
1750 - _
_- P_ -
PTD On Location
P
Flow Indicator
P
P
200 PSI Attained
12
P
Standing Order Posted
P
Meth Gas Detector
P
P
Full Pressure Attained
50
P
Well Sign
P
H2S Gas Detector
P
P
Blind Switch Covers:
yes --
P
Drl. Rig
P
MS Mise
NA_ -
-NA
Nitgn. Bottles (avg):
4 (a�2400_
P "
Hazard Sec.
P
P/F
HCR Valves
1
ACC Misc
0
NA
Misc
NA
2
-2-1/16"
FP
Check Valve
FLOOR SAFTY VALVES:
BOP STACK:
Quantity
P/F
Upper Kelly
0 -
NA
Lower Kelly
0 _
NA
Ball Type
1
P
Inside BOP
1
P
FSV Misc
_ -0
NA__
BOP STACK:
CHOKE MANIFOLD:
Quantity
Size
P/F
Quantity
P/F
Stripper
0
-_-___-
NA_
No. Valves -_16
P
Annular Preventer
1
11" -
P
Manual Chokes 1
P
#1 Rams
1
2-7/8" x 5"
FP
Hydraulic Chokes - 1 - -
P
#2 Rams
1
Blinds
P
CH Misc 0
NA
#3 Rams
0
NA
#4 Rams
0
NA
#5 Rams
--
0
-
--
NA
INSIDE REEL VALVES:
#6 Rams
0
NA
(Valid for Coil Rigs Only)
Choke Ln. Valves
1
3-1/8"
P -
Quantity
P/F
HCR Valves
1
3-1/8"
P
Inside Reel Valves 0
NA
Kill Line Valves
2
-2-1/16"
FP
Check Valve
0
NA
BOP Misc
0
NA
Number of Failures: 2 Test Results Test Time 9.5
Remarks: Test completed with a 2-7/8" and 4.5" test joints. VBR rams failed to hold DP, rams were cycled and retested with passing
results. K2 outside kill line valve failed to hold and was replaced . �
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Convert to GL & Jet Pump
Hilcorp Alaska 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 12,994 feet N/A feet
true vertical 4,400 feet N/A feet
Effective Depth measured 12,989 feet feet
true vertical 4,400 feet feet
Perforation depth Measured depth See Schematic feet
True Vertical depth See Schematic feet
Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 / EUE 8rd 5,820' 4,285'
BOT SLZXP LT
Packers and SSSV (type, measured and true vertical depth)(2) Swell Packers See Above N/A N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13.
Prior to well operation:
Subsequent to operation:
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:
Chad Helgeson
Contact Name:
Authorized Title:Operations Manager
Contact Email:
Contact Phone:
6,301, 6,485 &
9,941
4,354, 4,361 &
4,401
777-8343
2. Operator Name
Senior Engineer: Senior Res. Engineer:
Collapse
N/A
3,090psi
4,790psi
8,540psi
Burst
N/A
5,750psi
6,890psi
9,020psi
107'
6,474'
6,309'
Surface
Tieback
20"
9-5/8"
7-5/8"
measured
6,693'Liner
Casing
Conductor
Size
Junk
Length
MILNE PT UNIT E-41
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
185
Gas-Mcf
180
Casing Pressure Tubing Pressure
25
N/A
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
320-291
231
Authorized Signature with date:
Authorized Name:
David Haakinson
dhaakinson@hilcorp.com
952
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
219-031
50-029-23622-00-00
Plugs
ADL0025518, ADL0028231, ADL0047438
5. Permit to Drill Number:
MILNE POINT / SCHRADER BLUFF OIL
3800 Centerpoint Dr, Suite 1400
Anchorage, AK 99503
3. Address:
4. Well Class Before Work:
0
Representative Daily Average Production or Injection Data
00
1,700
WINJ WAG
0
Water-Bbl
MD
107'
measured
4,362'
4,355'
4,400'
6,474'
TVD
107'
Oil-Bbl
measured
true vertical
Packer
12,994'4-1/2"
6,309'
Form 10-404 Revised 3/2020 Submit Within 30 days of Operations
Chad A Helgeson
2020.08.18
17:08:26 -08'00'
By Samantha Carlisle at 8:39 am, Aug 19, 2020
RBDMS HEW 8/19/2020
SFD 8/19/2020DSR-8/20/2020MGR30JUL2021
_____________________________________________________________________________________
Revised By: TDF 8/18/2020
SCHEMATIC
Milne Point Unit
Well: MPUE-41
Last Completed: 8/7/2020
PTD: 219-031
TD =12,994’(MD) /TD =4,400’ (TVD)
4
20”
Orig. KB Elev.: 26.5’ / GL Elev.: 21.8’
7-5/8”5
6
7
16
9-5/8”
1
2
3
17
Swell Packer @
6,485’ MDSee
Screen/Solid
Liner Detail
PBTD =12,989’ (MD) /PBTD =4,400’ (TVD)
9-5/8” ‘ES’
Cementer @
2,239’ MD
4-1/2”
Shoe @
12,994’
13
814
15
4-1/2”
Swell Packer @
9,941’ MD
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor N/A / X-52 / Weld N/A Surface 106.5’ N/A
9-5/8" Surface 40 / L-80 / TXP 8.835 Surface 6,474’ 0.0758
7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,309’ 0.0459
4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hydril 625 3.920 6,301’ 12,994’ .0149
TUBING DETAIL
4-1/2" Tubing 12.6# / L-80 / Hydril 521 3.958 Surface 6,322’ 0.0152
OPEN HOLE / CEMENT DETAIL
Conductor ±270 ft3
12-1/4"Stg 1 – Lead – 600 sx / Tail – 400 sx
Stg 2 – Lead – 440 sx / Tail – 270 sx
8-1/2” Cementless Screens Liner in 8-1/2” hole
WELL INCLINATION DETAIL
KOP @ 360’
Max Hole Angle = 93.5° @ 6,511’ MD
TREE & WELLHEAD
Tree Cameron 4-1/16” 5K
Wellhead FMC Gen V
GENERAL WELL INFO
API: 50-029-23622-00-00
Completion Date: 4/12/19
Convert to GL & Jet Pump – 8/7/2020
4-1/2”SOLID LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
5 6,327’ 4,357’ 6,545’ 4,358’
9 8,808’ 4,344’ 9,169’ 4,352’
7 9,415’ 4,366’ 9,697’ 4,384’
3 9,901’ 4,399’ 10,041’ 4,407’
JEWELRY DETAIL
No. Top MD Item ID
1 3,322’ GLM 2: KBG 4-1/2” x 1” w/ SOV @ 2,000psi 3.865
2 4,846’ GLM 1: KBG 4-1/2” x 1” w/ Dummy Valve 3.865
3 4,949’ 4-1/2" Baker Zenith Gauge Mandrel
4 4,957’ 4-1/2” HES XD Sliding Sleeve (3.813” X-Profile). CLOSED 3.813”
5 4,965’ 4-1/2" Baker Zenith Gauge Ported Sub
6 4,982’ 7-5/8" x 4-1/2" HES TNT Packer 3.875”
7 5,021’ XN Nipple, 3.725” No-GO (Loaded with RHC Plug Body) 3.725”
8 6,281’ WLEG- 6.1” OD Centralizer –Btm @ 6,322’
13 6,301’ BOT SLZXP LT Packer / Liner Hanger 7” x 9-5/8” 6.190”
14 6,309’ 7-5/8” Tieback Assy. 6.151”
15 6,322’ 7” H563 x 4.5” TSH 625 L-80 XO 3.860”
16 12,957’ 4-1/2” Drillable Packoff Sub 2.390”
17 12,989’ WIV Valve LTC BxB (1” Ball on Seat/Closed) -
4-1/2” Screens LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
56 6,545’ 4,358’ 8,808’ 4,344’
6 9,169’ 4,352’ 9,415’ 4,366’
5 9,697’ 4,384’ 9,901’ 4,399’
72 10,041’ 4,407’ 12,951’ 4,399’
Well Name Rig API Number Well Permit Number Start Date End Date
MP E-41 ASR#1 50-029-23622-00-00 219-031 8/5/2020 8/7/2020
8/7/2020 - Friday
Finish MU the HES 7-5/8" x 4-1/2" TNT Packer assembly -verified 3 start to set pins- followed by one joint of 4-1/2" tubing.
PU and MU X-Nipple assembly followed by Gauge assembly with sliding sleeve and gauge mandrel. GLM between jnt 33 and
34. Continue to RIH w/ 4.5" 12.6# 521 Thread tubing. GLM loaded with shear valve set at 2000psi @ 3,332' between jnt 70
and 71. Clamping tech wire and testing wire every 1,000'. Pumping 5 bbls per hour displacement. Well Static. Torque Turn
all threads to 4700 ft/lbs. Tag Liner top on jnt 153-12' in @ 6,323' MD Space out adding 28.79' of 4.5" 12.6# 521 Thread
Pups. Spot PKR fluid 130 BBl 1% KCL with 1% Corrosion inhibitor in the IA. PU/MU TBG landing hanger. Land tbg RILDS SO
wt. 38K, Drop Ball and Rod . BO/LD Landing Joint. Fillled tbg and pressured up tbg while charting seen packer pre set @
1,900psi continued presssuring up to 3,400psi and set packer per HES TNT Setting procedure. Bled tbg down to 2,000psi.
Pumped 22 bbls down IA and pressured up to 3,600psi. Charted for 30mis- good test. Bled down from 2,400psi to 1,500 and
seen shear valve shear, bled off tbg and IA thru shear Valve. Blow down lines and set the BPV. End of well work on E-41.
RDMO ASR 1 and associated equipment, mobe to Tent on A Pad with assistance from Roads&Pads. ND BOP Stack/NU
Production Tree, test void to 5,000psi-good test. Well ready for operations.
8/5/2020 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
Mobilize all equipment to E-41. Spot in camps, Mud boat, accumulator and pits, Begin crane operations, Nipple down the
PT. set test plug in BPV and test to 4,000PSI test good. Cont. crane operations NU BOPE, set well hut and work floor, set off
driller side stairs, lay out BOPE lines. Spot jet heater. Spot in the Rig and RU over the hole. Spotted pump and hooked up
circulating lines. Installed Kill and Choke Lines. MU Flow Spool and 6" Flowline. MU Koomey lines to stack and functioned
BOP's. Hung Sheave and Elephant Truck. Set Catwalk and pipe racks. PU BOP Testing equipment. Filled stack and preformed
good shell test 250-2,500psi. Called out AOGCC inspector after we preformed a good shell test. Waited on Inspector to
arrive before starting BOP Test. Started BOPE test made it thru 2nd test and noticed the Chart Recorder Calibration expired
on 7/20/20. Changed out Chart Recorder and started BOP Test over. Testing BOP's as following Rams 250-2,500psi, Annular
250-2,500psi, Valves 250-2,500psi. Test Gas Detection. Test is being witnessed by Lou Laubenstein.
8/6/2020 - Thursday
Testing BOP's as following Rams 250-2,500psi, Annular 250-2,500psi, Valves 250-2,500psi. Test Gas Detection. Test is being
witnessed by Lou Laubenstein. one Fail pass and had to change out the Kill Manual valve. RD BOPE Test equipment, Pull test
plug and BPV. IA static, make up Landing Jnt and BOLDS. Unland the tbg off seat at 64k up wt 58k. BO and lay down the tbg
hanger. lay down 3jnt and GLM string the cable and cap. tube to the spooler. POOH with 2-7/8" EUE tbg from 5,700'-ESP
BHA. Pumping single displacement every 15jnts. L/D and inspected ESP Assembly. Pumps and spinning freely. Clean oil in
upper and lower seals. Good electrical integrity. Minor corrosion on the cable above the discharge head. Assembly is clean
of any scale sand or other debris. Send assembly to Centrilift shop for final inspection report. L/D ESP handling tools. RD
Elephant Trunk and Cable Sheave. RD Range Land Tongs and rack. RU Doyon's Csg tongs and Power Pack. Tallied completion
jewelry and verified running order. Racked and tallied 4-1/2" 12.6# L-80 H-521 Tbg. Prepared to RIH with 4-1/2" jet pump
completion. PU 4-1/2" WLEG w/5.20" OD Muleshoe and three 6" Centralizer. Didn't like the way the Hydraulic elevators
were engaging. The elevator slips would just slide on pipe until hitting upset then grab. Tried changing out porkchop plate
on top of elevators with the same issue. Swapped out Hyd Elevators with Doyon 75 ton slip type Manual Elevators. Verified
Elevators were biting on pipe just below the upset. RIH w/ 31 Jts of 4-1/2" 12.6# L-80 H-521 Tbg and make up to optimal
torque of 4,700 ft/lbs . Filling hole at 5 bph with 8.3 source water. On Jt # 31 PU XN w/RHC Installed, 7-5/8" HES TNT Packer
at report time.
8/8/2020 - Saturday
Well Name Rig API Number Well Permit Number Start Date End Date
MP E-41 ASR#1 50-029-23622-00-00 219-031 8/5/2020 8/7/2020
Hilcorp Alaska, LLC
Weekly Operations Summary
No operations to report.
No operations to report.
No operations to report.
8/11/2020 - Tuesday
8/9/2020 - Sunday
No operations to report.
8/10/2020 - Monday
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: Convert to GL & Jet Pump
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?
Will planned perforations require a spacing exception?Yes No
9.Property Designation (Lease Number):10.Field/Pool(s):
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD):
12,994'N/A
Casing Collapse
Structural N/A
Conductor 3,090psi
Surface 4,790psi
Intermediate 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
Commission Representative: GINJ Op Shutdown Abandoned
Chad Helgeson Contact Name:
Operations Manager Contact Email:dhaakinson@hilcorp.com
Contact Phone: 777-8343
Date:
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
2-7/8"
Perforation Depth MD (ft):
See Schematic
Perforation Depth TVD (ft):
MILNE PT UNIT E-41
7/10/2020
David Haakinson
BOT SLZXP LT & (2) Swell Packers and N/A 6,301MD/ 4,354TVD, 6,485MD/ 4,361TVD & 9,941MD/ 4,401TVD and N/A
See Schematic
107' 20"
9-5/8"
7-5/8"
4-1/2"6,693'9,020psi
6,309'
5,750psi
6,890psi
4,362'
4,355'
4,400'12,994'
6,309'
1,072 N/A
107' 107'
6,474'
6.5# / L-80 / EUE 8rd
TVD Burst
5,820'
MD
N/A
Tubing Size: Tubing Grade: Tubing MD (ft):
6,474'
Length Size
4,400' 12,989' 4,400'
C.O. 477.05
PRESENT WELL CONDITION SUMMARY
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
N/A
219-031
3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23622-00-00
MILNE POINT / SCHRADER BLUFF OIL
Hilcorp Alaska LLC
COMMISSION USE ONLY
Authorized Name:
Authorized Title:
17.I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Signature:
ory
Statu
Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval.
By Jody Colombie at 3:43 pm, Jul 10, 2020
320-291
Chad A Helgeson
2020.07.10
13:47:47 -08'00'
ADL0047438ADL0025518; 0028231
DSR-7/10/2020MGR13JUL20
X
BOPE TEST TO 2500 psi.
10-404
DLB
DLB 07/10/20dts 7/13/2020
JLC 7/13/2020
Comm./2020/2020 JLC 7/1
7/14/2020
RBDMS HEW 7/16/2020
RWO: Convert to JP/GL
Well: MPU E-41
Well Name:MPU E-41 API Number: 50-029-23622-00
Current Status:Shut-in ESP Producer Pad:E-Pad
Estimated Start Date:July 24th 2020 Rig:ASR
Reg. Approval Req’d?Yes Date Reg.Approval Rec’vd:
Regulatory Contact:Tom Fouts Permit to Drill Number:219-031
First Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M)
Second Call Engineer:Ian Toomey (907) 903-3987 (M)
AFE Number:Job Type:Convert to GL/JP
Current Bottom Hole Pressure:1,185 psi @ 4,284’ TVD Downhole Gauge (7/5/2020) |5.32 PPG
Maximum Expected BHP:1,500 psi @ 4,284’ TVD 60-day PBU |6.7 PPG
MPSP:1072 psi Gas Column Gradient (0.1 psi/ft)
Max Inclination 84° @ 6,301’ MD (9-5/8” x 7-5/8” Liner Top Packer)
Max Dogleg:6.2°/100ft @ 4,294’ MD
BPV Profile:2-1/2” CIW Type H
Brief Well Summary:
MPU producer E-41 was drilled and completed as a horizontal producer in the Schrader NB sands in 2019. The
well was completed as an ESP producer and came on strong at over 1,800 BOPD. Production had declined and
leveled off at 1,500 BLPD, but recently the watercut has increased drastically from 10% to 50% from March to
May 2020. In May 2020, the ESP began to have difficulty maintaining the bottom-hole pressure target and
suffered from significant gas swings. The ESP was shut down in mid-June 2020 and appears to have been
damaged upon start-up, leading to ultimate electrical failure on 7/5/2020. Due to possible conformance issues
and the instability of the undersized ESP, the well will be converted to jet pump production.
Notes Regarding Wellbore Condition
x The 9-5/8”x7-5/8” annulus passed an MIT to 1,000 psig on 4/11/19.
o This will become OA.
x Offset Injection Support: SI 7 days prior to RWO
o E-40: Online, injecting ~1,000 BWPD
Objective:
x Pull 2-7/8” Tubing String and ESP
x Install a 4-1/2” Gas Lift/Jet Pump completion
x Obtain passing MIT-IA
Pre-Rig Procedure: Non-Sundried Operations
1. RU LRS and PT lines to 3000 psi.
2. Circulate 290 bbls of 8.3 ppg source-water down tubing while taking returns up the IA.
3. Pump 60 bbls of 8.3 ppg source-water down tubing to formation. Observe tubing and IA pressures and
pump additional fluids down tubing to formation if necessary to kill well.
a. Well is expected to go on a vacuum but have a gas head on the IA.
4. RD Little Red Services.
5. RD well house and flowlines.
6. Clear and level pad area in front of well. Spot rig mats and containment.
RWO: Convert to JP/GL
Well: MPU E-41
7. Bleed off any residual pressure and confirm well is dead. Pump additional 8.3 ppg SW as necessary to
kill well. Freeze protect tubing/casing as needed with 60/40 MeOH.
a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of
the ASR.
8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane.
9. NU BOPE house. Spot mud boat.
Brief RWO Procedure: Sundried Operations (Approved 10-403 required prior to starting)
10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank.
11. Check for pressure and if 0 psi, pull BPV. If needed, bleed off any residual pressure off tubing and
casing. If needed, kill well w/8.3 ppg source-water prior to pulling BPV.
12. Set BPV plug (converting BPV to TWC).
13. Test BOPE to 250 psi Low/ 2,500 psi High, 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. Notify AOGCC 24 hours in advance of BOP test.
b. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015.
c. Confirm test pressures per the Sundry Conditions of approval.
d. Test VBR rams on 2-7/8” and 4-1/2” test joints.
e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test.
14.Contingency: If BOPE test fails
a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via
email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to
send an inspector to witness test.
b. With stack out of the test path, test choke manifold per standard procedure
c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the
surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere
at surface.)
d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record
the pumping rate and pressure.
e. Once the BOP ram and annular tests are completed, test the remainder of the system following the
normal test procedure (floor valves, gas detection, etc.)
f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /
penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list
items, pressures and rates.
15. Bleed any pressure off casing to returns tank. Pull BPV plug and BPV. Kill well w/8.3 ppg source-water
as needed.
16. Rig up spoolers for ESP #2 RD cable and 3/8” capillary injection string.
a. Baker Hughes representative should be onsite for ESP pull.
17. MU landing joint or spear and PU on the tubing hanger.
a. The PU weight during the 2019 ESP completion was 83K lbs / SOF = 55K lbs (block wt = 35k lbs).
Mel Rixse (AOGCC)
RWO: Convert to JP/GL
Well: MPU E-41
b. If needed, circulate (long or reverse) pill with lubricant, source-water, and/or baraclean pill prior to
laying down the tubing hanger.
18. Recover the tubing hanger.
a. Inspect pulled tubing hanger for damage. Add to Wellhead Coordinator’s inventory.
Contingency (If a rolling test was conducted): MU new hanger or test plug to the
completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard
procedure.
19. POOH and lay down the 2-7/8” tubing. Lay down ESP and motor.
a. Document any damage to surface connector, cable, MLE or pothead.
b. If damage is found on electrical component outside of the pothead, the motor will be sent to Baker
Hughes in L48 for testing and possible refurbishment.
c. Send all tubing to G&I for washing and reuse.
d. Note any sand or schmoo/asphaltenes inside or on the outside of the ESP on the morning report.
e. Look for over-torqued connections from previous tubing runs.
Equipment Disposition
Tubing hanger Visually inspect on site then re-stock (Wellhead Spec. 670-3448)
Tubing & Pup joints Visually inspect on site then re-stock (Wellhead Spec. 670-3448)
3/8” Capillary Tubing Pressure Test and Re-stock, pickle with methanol.
Gas-lift Mandrels (2)Visually inspect on site then re-stock (Drill Coord. 685-1293)
XN Nipple Visually inspect on site then re-stock (Drill Coord. 685-1293)
Clamps (218)Visually inspect on site then re-stock (Baker Hughes)
ESP Centralizer Visually inspect on site then re-stock (Baker Hughes)
ESP Motor Plan to send off to L48 for testing and re-use
ESP Motor Gauge Visually inspect on site then re-stock (Baker Hughes)
ESP Pumps/Seals Junk
ESP Discharge Head Visually inspect on site then re-stock (Baker Hughes)
f. The completion has the following amount of clamps/guards/cap-string:
i. 202 Cross Collar Cannon Clamps
ii. 4 Motor Clamps
iii. 4 Seal Clamps
iv. 8 Pump Clamps
20.Contingency: If any solids or scale is seen on the tubulars or ESP. Engineer may elect to PU 7-5/8”
casing scraper BHA and TIH. If picked up:
a. RIH to ±5,000’ MD. Reciprocate pipe from ±4,980’ to ±5,010’ MD.
b. Circulate a minimum of 1.5x BU or until returns are clean. POOH.
21. RU spoolers, and call out Baker Hughes to run downhole gauges on completion.
22. PU 4-1/2” completion and deploy as per the finalized Completion Running Order. The packer will be at
±5,000’ MD.
RWO: Convert to JP/GL
Well: MPU E-41
a. WLEG @ ±6,322’ MD w/6.1” OD Rigid Centralizers on WLEG and last 3 joints
b. XN Nipple (3.725” ID) w/ RHC Plug Body at 5,015’ MD (63° inclination)
i. Confirm Ball & Rod is correct match for RHC Plug.
c. 7-5/8” x 4-1/2” Halliburton TNT packer at ±5,000’ MD
d. Baker Hughes Suction Zenith Gauge (Tubing Read)
e. 4-1/2” XD Sliding Sleeve (Closed Position)
f. Baker Hughes Discharge Gauge (Tubing Read)
g. 4-1/2” GLM @ ±4,844’ MD (Dummy Valve)
h. 4-1/2” GLM @ ±3,313’ MD (2000 psig IA to T Shear-out Valve)
i. Blast Joint Tubing Hanger
23. Record PU and SO weights prior to spacing out the WLEG to be below the 7-5/8”x 9-5/8” liner top
packer at ±6,301’ MD.
24. Reverse circulate 130 bbls of 1% KCl with 1% corrosion inhibitor down the annulus.
a. The goal is to spot corrosion inhibited fluid in the dead leg between the packer and sliding
sleeve.
25. Land tubing hanger. RILDS. Lay down landing joint. Test tubing hanger pack-off to 5,000 psig.
26. Drop the ball & rod and allow to fall on seat in the RHC plug body in the XN Nipple.
27. Increase the pressure and set packer per Halliburton set points.
28. Pressure test the tubing to 3,000 psig.
29. Bleed tubing pressure to 2,000 psig.
30. Pressure test the IA to 3,500psig for 30 min (Charted).
31. Bleed down the tubing pressure to shear out the shear out GLV from GLM at ±3,313’ MD.
32. Pump both ways (TxIA) to ensure clear path through the SOV
33. Set BPV.
Post-Rig Procedure:
34. RD mud boat. RD BOPE house. Move to next well location.
35. RU crane. ND BOPE. Pull BPV. Set TWC.
36. NU new 4-1/16” 5,000# tree. Test tubing hanger void to 500 psi low/5,000 psi high.
37. Pull TWC
38. Pump 83 bbls of diesel down the IA and U-tube to the tubing to freeze protect the well.
39. RD crane. Move 500 bbl returns tank and rig mats to next well location.
40. Replace gauge(s) if removed.
41. Turn well over to production. RU well house and flowlines.
Attachments:
1. As-built Schematic
2. Proposed Schematic
3. BOP Schematic
4. Blank RWO MOC Form
_____________________________________________________________________________________
Edited By: CJD 5-7-2019
SCHEMATIC
Milne Point Unit
Well: MPUE-41
Last Completed: 4/12/2019
PTD: 219-031
TD =12,994’(MD) / TD =4,400’ (TVD)
4
20”
Orig. KB Elev.: 26.5’ / GL Elev.: 21.8’
7-5/8”
7
8/9
10
4
16
9-5/8”
1
2
3
17
Swell Packer @
6,485’ MDSee
Screen/Solid
Liner Detail
PBTD =12,989’ (MD) / PBTD =4,400’ (TVD)
9-5/8” ‘ES’
Cementer @
2,239’ MD
5/6
4-1/2”
Shoe @
12,994’
11
13
1214
15
2-7/8”
Swell Packer @
9,941’ MD
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor N/A / X-52 / Weld N/A Surface 106.5’ N/A
9-5/8" Surface 40 / L-80 / TXP 8.835 Surface 6,474’ 0.0758
7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,309’ 0.0459
4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hydril 625 3.920 6,301’ 12,994’ .0149
TUBING DETAIL
2-7/8" Tubing 6.5 / L-80 / EUE-8rd 2.441 Surface 5,820’ 0.0058
3/8” Dual Cap String 3/8” N/A Surface 5,820’ N/A
OPEN HOLE / CEMENT DETAIL
Conductor ±270 ft3
12-1/4"Stg 1 – Lead – 600 sx / Tail – 400 sx
Stg 2 – Lead – 440 sx / Tail – 270 sx
8-1/2” Cementless Screens Liner in 8-1/2” hole
WELL INCLINATION DETAIL
KOP @ 360’
Max Hole Angle = 93.5° @ 6,511’ MD
TREE & WELLHEAD
Tree Cameron 2-9/16" 5M
Wellhead FMC Gen V
GENERAL WELL INFO
API: 50-029-23622-00-00
Completion Date: 4/12/19
4-1/2”SOLID LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
5 6,327’ 4,357’ 6,545’ 4,358’
9 8,808’ 4,344’ 9,169’ 4,352’
7 9,415’ 4,366’ 9,697’ 4,384’
3 9,901’ 4,399’ 10,041’ 4,407’
JEWELRY DETAIL
No. Top MD Item ID
1 141’ GLM: 2-7/8” x 1” Side Pocket KPMM w/DGLV 2.347”
2 5,032’ GLM : 2-7/8” x 1”***Open Pocket***2.347”
3 5,121’ XN Nipple, 2.205” no go 2.205”
4 5,732’ Discharge Head: FPDIS
5 5,733’ Upper Tandem Pump: 134 STG FLEX 17.5
6 5,756’ Lower Tandem Pump: 134 STG FLEX 17.5
7 5,780’ Gas Separator: GRS FER N AR
8 5,785’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA
9 5,792’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA
10 5,798’ Motor: CL5 XP – 250hp / 2715V / 51A
11 5,815’ Sensor, Zenith
12 5,818’ Centralizer:Bottom @ 5,820’
13 6,301’ BOT SLZXP LT Packer / Liner Hanger 7” x 9-5/8” 6.190”
14 6,309’ 7-5/8” Tieback Assy. 6.151”
15 6,322’ 7” H563 x 4.5” TSH 625 L-80 XO 3.860”
16 12,957’ 4-1/2” Drillable Packoff Sub 2.390”
17 12,989’ WIV Valve LTC BxB (1” Ball on Seat/Closed) -
4-1/2” Screens LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
56 6,545’ 4,358’ 8,808’ 4,344’
6 9,169’ 4,352’ 9,415’ 4,366’
5 9,697’ 4,384’ 9,901’ 4,399’
72 10,041’ 4,407’ 12,951’ 4,399’
_____________________________________________________________________________________
Edited By: DAH 07-09-2020
PROPOSED
Milne Point Unit
Well: MPUE-41
Last Completed: 4/12/2019
PTD: 219-031
TD =12,994’ (MD) / TD = 4,400’ (TVD)
4
20”
Orig. KB Elev.: 26.5’ / GL Elev.: 21.8’
7-5/8”5
6
7
16
9-5/8”
1
2
3
17
Swell Packer @
6,485’ MDSee
Screen/Solid
Liner Detail
PBTD =12,989’ (MD) / PBTD = 4,400’ (TVD)
9-5/8” ‘ES’
Cementer @
2,239’ MD
4-1/2”
Shoe @
12,994’
13
814
15
4-1/2”
Swell Packer @
9,941’ MD
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor N/A / X-52 / Weld N/A Surface 106.5’ N/A
9-5/8" Surface 40 / L-80 / TXP 8.835 Surface 6,474’ 0.0758
7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,309’ 0.0459
4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hydril 625 3.920 6,301’ 12,994’ .0149
TUBING DETAIL
4-1/2" Tubing 12.6# / L-80 / H-521 3.958 Surface ±6,322’ 0.0152
OPEN HOLE / CEMENT DETAIL
Conductor ±270 ft3
12-1/4"Stg 1 – Lead – 600 sx / Tail – 400 sx
Stg 2 – Lead – 440 sx / Tail – 270 sx
8-1/2” Cementless Screens Liner in 8-1/2” hole
WELL INCLINATION DETAIL
KOP @ 360’
Max Hole Angle = 93.5° @ 6,511’ MD
TREE & WELLHEAD
Tree Cameron 4-1/16” 5K
Wellhead FMC Gen V
GENERAL WELL INFO
API: 50-029-23622-00-00
Completion Date: 4/12/19
4-1/2”SOLID LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
5 6,327’ 4,357’ 6,545’ 4,358’
9 8,808’ 4,344’ 9,169’ 4,352’
7 9,415’ 4,366’ 9,697’ 4,384’
3 9,901’ 4,399’ 10,041’ 4,407’
JEWELRY DETAIL
No. Top MD Item ID
1 ±3,313’GLM: 2-7/8” x 1”Shear out Valve 3.865
2 ±4,845’GLM : 2-7/8” x 1”Dummy Valve 3.865
3 ±4,973 4-1/2” Baker Hughes Discharge Gauge (Tubing Read)
4 ±4,981 4-1/2” XD Sliding Sleeve (3.813” X-Profile). CLOSED 3.813”
5 ±4,988 4-1/2” Baker Hughes Suction Gauge (Tubing Read)
6 ±5,000’Packer 3.875”
7 ±5,040’XN Nipple, 3.725” No-GO (Loaded with RHC Plug Body) 3.725”
8 ±6,322’WLEG- 6.1” OD Centralizer
13 6,301’ BOT SLZXP LT Packer / Liner Hanger 7” x 9-5/8” 6.190”
14 6,309’ 7-5/8” Tieback Assy. 6.151”
15 6,322’ 7” H563 x 4.5” TSH 625 L-80 XO 3.860”
16 12,957’ 4-1/2” Drillable Packoff Sub 2.390”
17 12,989’ WIV Valve LTC BxB (1” Ball on Seat/Closed) -
4-1/2” Screens LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
56 6,545’ 4,358’ 8,808’ 4,344’
6 9,169’ 4,352’ 9,415’ 4,366’
5 9,697’ 4,384’ 9,901’ 4,399’
72 10,041’ 4,407’ 12,951’ 4,399’
Updated 6/30/2020
11” BOPE
3.125", 5M, Side Outlet Typ.
4.30'Hydril
11", 5M Annular BOP
Blind
3.125", 5M
HCR Valve
3.125", 5M
Gate Valve 3.125", 5M
HCR Valve
3.125", 5M
Gate Valve
Hydril 11", 5M Double
Ram BOP
Milne Point
ASR 11” BOP w/ Jacks
05/17/2017
Milne Point
ASR 11” BOP (Triple)
6/30/2020
Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: July 10th, 2020Subject: Changes to Approved Sundry Procedure for Well MP E-41Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date
Surface Casing by Conductor Annulus Fill Coat Corrosion Inhibitor (Cl) Applications
Well
Field
AN
PTD
Top of
Cement (ft.)
Corrosion
Inhibitor
Fill Volume
(gal)
Final Cl Top
(ft.)
Corrosion
Inhibitor
Treatment
Date
E-35
Milne Point
50029236150000
2181520
Surface
22.5
Topof Cond
10/24/2019
E-36
Milne Point
50029236200000
2190050
Surface
15
Top of Cond
10/24/2019
E-38
Milne Point
50029236260000
2190440
Surface
20
Top of Cond
10/24/2019
E-39
Milne Point
50029236400000/60-00
2190960
Surface
20
Top of Cond
10/24/2019
E-40
Milne Point
50029236260000
2190440
Surface
25
Top of Cond
10/25/2019
E-41
Milne Point
50029236220000
2190310
Surface
15
Top of Cond
10/24/2019
E-42
Milne Point
50029236350000/60-00
2190820
Surface
17
Top of Cond
10/25/2019
M-18
Milne Point
50029236320000
2190700
3
50
Top of Cond
10/26/2019
M-06
Milne Point
50029236460000
2191130
3
30
Top of Cond
10/26/2019
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
Notes: k7
Initial top of Cement footage measurement was taken from the 4" outlet down to the TOC
The 4" conductor outlets are any where from 1 to 3' down from the top of the conductor
6
DEC 0 6 1019
AOGCG
DATA SUBMITTAL COMPLIANCE REPORT
7/19/2019
Permit to Drill 2190310 Well Name/No. MILNE PT UNIT E-41 g1 Operator Hilcorp Alaska LLC
P07-6
0
MD 12994 TVD 4400 Completion Date 4/12/2019 P3Completion Status 1 -OIL Current Status 11-011-
REQUIRED
-OIL
REQUIRED INFORMATION
Mud Log No ./
Samples No/
DATA INFORMATION
List of Logs Obtained: ROP / ABG / DGR ! EWR / ADR 2'15" MD / P131 / PB2 / PB3/ABG / DGR / EWR / ADR 2,76" TVD/P81/PB2/PB3
Well Log Information:
Log/ Electr
Data Digital Dataset Log Log Run Interval OH/
API No. 50-029-23622-00-00
UIC No
Directional Survey Yes 1
(from Master Well Data/Logs)
Type
Med/Frmt Number Name
Scale Media No Start Stop CH
Received
Comments
ED
C
30833 Digital Data
105 12994
5/23/2019
Electronic Data Set, Filename: MPU E-41 DGR
ABG EWR ADR.Ias
ED
C
30833 Digital Data
6450 12956
5/23/2019
Electronic Data Set, Filename: MPU E-41 ADR
Quadrants All Curves.las
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41 LWD Final MD.cgm
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41 LWD Final TVD.cgm
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41—Definitive Survey
Report.pdf
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41_DSR.txt
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41_GIS.txt
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41 LWD Final MD.emf
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41 LWD Final TVD.emf
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41 Geosteering.dlis
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41 Geosteering.ver
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41 LWD Final MD.pdf
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41 LWD Final TVD.pdf
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41 LWD Final MD.tif
ED
C
30833 Digital Data
5/23/2019
Electronic File: MPU E-41 LWD Final TVD.tif
ED
C
30833 Digital Data
5/23/2019
Electronic File: EMFView3_1.zip
ED
C
30833 Digital Data
5/23/2019
Electronic File: Readme.txt
Log
C
30833 Log Header Scans
0 0
2190310 MILNE PT UNIT E-41 LOG HEADERS
AOGCC Page 1 of 5 Friday, July 19, 2019
DATA SUBMITTAL COMPLIANCE REPORT
7/19/2019
Permit to Drill 2190310 Well Name/No. MILNE PT UNIT E-41
Operator Hilcorp Alaska LLC
API No. 50-029-23622-00-00
MD
12994
TVD 4400 Completion Date 4/12/2019
Completion Status 1-0I1-
Current Status 1 -OIL UIC No
Log
C
30834 Log Header Scans
0 0
2190310 MILNE PT UNIT E-41 PB1 LOG
HEADERS
ED
C
30834 Digital Data
105 7974
5/23/2019
Electronic Data Set, Filename: MPU E41 PB1
DGR ABG EWR ADR.las
ED
C
30834 Digital Data
6450 7936
5/23/2019
Electronic Data Set. Filename: MPU E41 PB1
ADR Quadrants Ail Curves.las
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E-41 PB1 LWD Final
MD.cgm
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E-41 PB1 LWD Final
TVD.cgm
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E-41 PB1—Definitive Survey
Report.pdf
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E41PB1_OSR.txt
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E-41PB1_GIS.txt
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E-41 PBI LWD Final
MD.emf
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E-41 PB1 LWD Final
TVD.emf
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E41 1`61 Geosteering.dlis
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E-41 PB1 Geosteering.ver
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E-41 PB1 LWD Final
MD.pdf
1 ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E-41 PB1 LWD Final
TVD.pdf
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E-41 PB1 LWD Final MD.tif
ED
C
30834 Digital Data
5/23/2019
Electronic File: MPU E-41 1`61 LWD Final TVO.tif
ED
C
30834 Digital Data
5/23/2019
Electronic File: EMFView3_t.zip
ED
C
30834 Digital Data
5/23/2019
Electronic File: Readme.txt
'ED
C
30835 Digital Data
105 9458
5/23/2019
Electronic Data Set, Filename: MPU E-41 P132
DGR ABG EWR ADR.Ias
ED
C
30835 Digital Data
6450 9420
5/23/2019
Electronic Data Set, Filename: MPU E-41 PB2
ADR Quadrants All Curves.las
ED
C
30835 Digital Data
5/23/2019
Electronic File: MPU E-41 PB2 LWD Final
MD.cgm
AOGCC
Page 2 of 5
Friday, July 19, 2019
DATA SUBMITTAL COMPLIANCE REPORT
7/19/2019
Permit to Drill 2190310 Well Name/No. MILNE PT UNIT E41
Operator Hilcorp Alaska LLC
MD
12994
TVD 4400 Completion Date 4/12/2019
Completion Status 1 -OIL
ED
C
30835 Digital Data
ED
C
30835 Digital Data
5/23/2019
ED
C
30835 Digital Data
ED
C
30835 Digital Data
ED
C
30835 Digital Data
5/23/2019
ED
C
30835 Digital Data
ED
C
30835 Digital Data
ED
C
30835 Digital Data
523/2019
ED
C
30835 Digital Data
5/23/2019
ED
C
30835 Digital Data
ED
C
30835 Digital Data
ED
C
30835 Digital Data
ED
C
30835 Digital Data
ED
C
30835 Digital Data
Log
C
30835 Log Header Scans
0 0
Log
C
30836 Log Header Scans
0 0
ED
C
30836 Digital Data
105 11851
ED
C
30836 Digital Data
6450 11814
ED
C
30836 Digital Data
ED
C
30836 Digital Data
ED
C
30836 Digital Data
AOGCC Page 3 of 5
API No. 50.029-23622-00-00
Current Status 1 -OIL UIC No
5/23/2019
Electronic File: MPU E-41 PB2 LWD Final
TVO.cgm
5/23/2019
Electronic File: MPU E-41 PB2—Definitive Survey
Report.pdf
5/23/2019
Electronic File: MPU E-41PB2_DSR.txt
5/23/2019
Electronic File: MPU E-41PB2 GIS.txt
5/23/2019
Electronic File: MPU E41 PB2 LWD Final
MD.emf
5/23/2019
Electronic File: MPU E41 P132 LWD Final
TVD.emf
5/23/2019
Electronic File: MPU E-41 P132 Geosteering.dlis
5/23/2019
Electronic File: MPU E-41 P82 Geosteering.ver
5/23/2019
Electronic File: MPU E-41 P132 LWD Final
MD.pdf
5/23/2019
Electronic File: MPU E-41 PB2 LWD Final
TVD.pdf
5/23/2019
Electronic File: MPU E-41 PB2 LWD Final MD.tif
523/2019
Electronic File: MPU E-41 PB2 LWD Final TVD.tif
5/23/2019
Electronic File: EMFView3_l.zip
5/23/2019
Electronic File: Readme.txt
2190310 MILNE PT UNIT E41 PB2 LOG
HEADERS
2190310 MILNE PT UNIT E41 P133 LOG
HEADERS
5/22/2019
Electronic Data Set, Filename: MPU E41 PB3
DGR ABG EW R ADR.Ias
5/22/2019
Electronic Data Set, Filename: MPU E-41 P133
ADR Quadrants All Curves.las
5/22/2019
Electronic File: MPU E-41 PB3 LWD Final
MD.cgm
5/22/2019
Electronic File: MPU E-41 13133 LWD Final
TVD.cgm
522/2019
Electronic File: MPU E41 PB3—Definitive Survey
Report.pdf
Friday, July 19, 2019
DATA SUBMITTAL COMPLIANCE REPORT
7/19/2019
Permit to Drill 2190310 Well Name/No. MILNE PT UNIT E-41
Operator Hilcorp Alaska LLC
MD 12994 TVD 4400 Completion Date 4/12/2019 Completion Status 1-0I1-
--- — - - -- -- - --_ _. ----..
ED C 30836 Digital Data
ED C 30836 Digital Data
ED C 30836 Digital Data
ED C 30836 Digital Data
ED C 30836 Digital Data
ED C 30836 Digital Data
ED C 30836 Digital Data
ED C 30836 Digital Data
ED
C
30836 Digital Data
ED
C
30836 Digital Data
ED
C
30836 Digital Data
ED
C
30836 Digital Data
Well Cores/Samples Information:
Name
INFORMATION RECEIVED
Completion Report O
Production Test Informatiore) NA
Geologic Markers/Tops t'J
COMPLIANCE HISTORY
Completion Date: 4/12/2019
Release Date: 2/28/2019
Description
AOGCC
Interval
Start Stop Sent Received
/d 9 � 2L.�SrarYkBRL'YYIIQraiId
Current Status 1 -OIL UIC No
5/22/2019 Electronic File: MPU E-41PB3 DSR.txt
5/22/2019 Electronic File: MPU E-41PB3 GIS.txt
5/22/2019 Electronic File: MPU E-41 PB3 LWD Final
Sample
Set
Number Comments
Directional / Inclination Data �Y Mud Logs, Image Files, Digital Data Y / hlr� Core Chips Y /MIL
Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Yl/A
Daily Operations Summary Cy Cuttings Samples Y //® alyses Laboratory AnY NA
Date Comments
Page 4 of 5
Friday, July 19, 2019
MD.emf
5/22/2019
Electronic File: MPU E-41 PB3 LWD Final
TVD.emf
5/22/2019
Electronic File: MPU E-41 PB3 Geosteedng.dlis
5/22/2019
Electronic File: MPU E-41 PB3 Geosteering.ver
5/22/2019
Electronic File: MPU E-41 P83 LWD Final
MD.pdf
5/22/2019
Electronic File: MPU E-41 PB3 LWD Final
TVD.pdf
5/2212019
Electronic File: MPU E-41 PB3 LWD Final MD.tif
5/22/2019
Electronic File: MPU E-41 PB3 LWD Final TVD.tif
5/22/2019
Electronic File: EMFView3_1.zip
5/22/2019
Electronic File: Readme.txt
Sample
Set
Number Comments
Directional / Inclination Data �Y Mud Logs, Image Files, Digital Data Y / hlr� Core Chips Y /MIL
Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Yl/A
Daily Operations Summary Cy Cuttings Samples Y //® alyses Laboratory AnY NA
Date Comments
Page 4 of 5
Friday, July 19, 2019
DATA SUBMITTAL COMPLIANCE REPORT
7/19/2019
Permit to Drill 2190310 Well Name/No. MILNE PT UNIT E-41 Operator Hilcorp Alaska LLC
MD 12994 TVD 4400 Completion Date 4/12/2019 Completion Status 1-0I1- Current Status 1-0I1
Comments:
Compliance Reviewed By:
API No. 50-029-23622.00.00
UIC No
Date: 7//q/i /
AOGCC Pagc 5 45 Friday, July 19, 2019
DATE: 5/15/2019
21 9t0 1
D,.,ra Oudean Hilcorp Alaska, LLC 3 0 8 3 3
AK_GeoTech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
Fax: 907 777-8510
E-mail: doudean@hilcorp.com
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
w
F
40CD: HALLIBURTON 14 Apr 2019 FEB 2019
E-41
ROP DGR ABG EWR ADR MD & TVD
E-41 PB1
ROP DGR ABG EWR ADR MD & T Vi)
E-41 PB2
ROP DGR ABG EWR ADR MD & TVD
E-41 PB3
ROP DGR ABG EWR ADR MD & TVD
Please include current contact information if different from above.
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510
� 11.
-J
219031
30834
Debra Oudean Hilcorp Alaska, LLC
AK_GeoTech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
Har.., ab,A.. LU. Fax: 907 777-8510
E-mail: doudean@hilcorp.com
DATE: 5/15/2019
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
F
CD: HALLIBURTON 14 Apr 2019 FEB 2019
E-41 ROP DGR ABG EWR ADR MD & TVD �.
E-41 PBI ROP DGR ABG EWR ADR MD & TVu
E-41 PB2 ROP DGR ABG EWR ADR MD & TVD
E-41 PB3 ROP DGR ABG EWR ADR MD & TVD
Please include current contact information if different from above.
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510
DATE: 5/15/2019
r
Debra Oudean Hilcorp Alaska, LLC
AK_GeoTech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
Fax: 907 777-8510
E-mail: doudean@hilcorp.com
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
�+A$
MPU E-41 PB2
MPU E-41 PB3 *4)-
CD: HALLIBURTON 14 Apr 2019 FEB 2019 cr
E-41
ROP DGR ABG EWR ADR MD & TVD
E-41 PBI
ROP DGR ABG EWR ADR MD & TVD
E-41 PB2
ROP DGR ABG EWR ADR MD & TVD
E-41 P83
ROP DGR ABG EWR ADR MD & TVD
Please include current contact information if different from above.
21 9031
30835
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510
COX
0
21 9031
Debra Oudean Hilcorp Alaska, LLC 0 8 3 Z C
AK_GeoTech 3800 Centerpoint Drive, Suite 1400 V
Anchorage, AK 99503
Tele: 907 777-8337
nil.•..l %h'A.A.Lc Fax: 907 777-8510
E-mail: doudean@hilcorp.com
DATE: 5/15/2019
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
CD: HALLIBURTON 14 Apr 2019 FEB 2019
E-41 ROP DGR ABG EWR ADR MD & TVD �.
E-41 PBI ROP DGR ABG EWR ADR MD & TVV
E-41 PB2 ROP DGR ABG EWR ADR MD & TVD
E-41 PB3 ROP DGR ABG EWR ADR MD & TVD
Please include current contact information if different from above.
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
MAY 0 7 2019
WELL COMPLETION OR RECOMPLETION REPORT
A
1a. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑
1b. Well Class
20n C 25.105 20AAC 25.110
Development 0 Exploratory ❑
GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: _ 1
Service ❑ Stratigraphic Test ❑
2. Operator Name:
6. Date Comp., Susp., or
14. Permit to Drill Number / Sundry:
Hilcorp Alaska, LLC
Aband.: 4/12/2019
219-031
3. Address:
7. Date Spudded:
15. API Number:
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
March 12, 2019
50-029-23622-00-00
4a. Location of Well (Governmental Section):
8. Date TD Reached:
16. Well Name and Number: ,
Surface: . 3496' FSL, 1844' FEL, Sec 25, TI 3N, R1 OE, UM, AK
April 5, 2019
MPU E-41
Top of Productive Interval:
9. Ref Elevations: KB: 48.7'
17. Field / Pool(s): Milne Point Field
1463' FNL, 252' FEL, Sec 25, T1 3N, R1 GE, UM, AK
GL: 21.8' BF: 21.8'
Schrader Bluff Oil Pool
Total Depth:
10. Plug Back Depth MD/TVD:
18. Property Designation: . ,
566' FNL, 1188' FWL, Sec 19, T13N, Rl1 E, UM, AK
12,989' MD / 4,400' TVD
ADL025518, ADL028231, ADLO47438
4b. Location of Well (State Base Plane Coordinates, NAD 27): ,
11. Total Depth MD/TVD:
19. DNR Approval Number:
Surface: x- 569302 y- 6016034 Zone- 4
' 12,994' MD / 4,400' TVD
LONS 94-017
TPI: x- 570891 y- 6016369 Zone- 4
12. SSSV Depth MD/TVD:
20. Thickness of Permafrost MD/TVD:
Total Depth: x- 572272 y- 6022560 Zone- 4
N/A
2,068' MD / 1,795' TVD
5. Directional or Inclination Survey: Yes e (attached) No
13. Water Depth, if Offshore:
21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic and printed information per 20 AAC 25.050
1 N/A (ft MSL)
I N/A
22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days
of completion, 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
ROP/ABG/DGR/EWR/ADR 275" MD / PB1, PB2, PB3
ABG/DGR/EWR/ADR 2"/5" TVD / PB1, PB2, PB3
23. CASING, LINER AND CEMENTING RECORD
CASING
WT. PER
FT
GRADE SETTING DEPTH MD
TOP BOTTOM
SETTING DEPTH TVD
HOLE SIZE
TOP BOTTOM
AMOUNT
CEMENTING RECORD
PULLED
20"
215.5#
X-42 Surface
107'
Surface 107' 42"
±270 ft3
9-5/8"
40#
L-80 Surface
6,474'
Surface 4,362' 12-1/4"
Stg 1 L - 600 sx / T - 400 sx
Stg 2 L - 440 sx / T - 270 sx 225 bbis
7-5/8"
29.7#
L-80 Surface
6,309'
Surface 4,355' Tieback
Tieback Assy.
4-1/2"
13.5#
L-80 6,301'
12,994'
4,354' 4,400' 8-1/2"
Screens w/ Swell Pkrs
24. Open to production or injection? Yes ❑2 No ❑
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Pertd):2-7/8"
5,820' MD 6,301' MD / 4,354' TVD
**Please see attached schematic for detail** Liner Run on 4/8/19
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
COMPLETION
Was hydraulic fracturing used during completion? Yes No
14 A7
12 ZD(9
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED
VERIFIED
27. PRODUCTION TEST
Date First Production:
Method of Operation (Flowing, gas lift, etc.):
4/29/2019
ESP
Date of Test:
Hours Tested:
Production for
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Choke Size:
Gas -Oil Ratio:
5/1/2019
24
Test Period
1756
1.4
207.6
N/A
0.8
Flow Tubing
Casing Press:
Calculated
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Oil Gravity -API (torr):
Press. 215
580
24 -Hour Rate
1756
1.4
207.6
19
Form 10-407 Revised 5/2017 �^"S!A S �'_,1 CONTINU�f jN �PAGE 2 RBDMS.' —Ew MAY 0 8 201 ubmit ORIGINIAL on
28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No 0
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.
29. GEOLOGIC MARKERS (List all formations and markers encountered):
30. FORMATION TESTS
NAME
MD
TVD
Well tested? Yes ❑ No Q
If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
•
,
Permafrost - Base
2,068'
1,795'
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
6,545' SB NB
4,353'
information, including reports, per 20 AAC 25.071.
SV5
1,967'
1,722'
Sv1
3,031'
2,511'
Ugnu LA3
4,575'
3,832'
SB NA
6,174'
4,338'
SS NB
6,314'
4,355'
Formation at total depth:
Schrader Bluff
31. List of Attachments: Wellbore Schematic, Driling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report, OH Sidetrack
Summary.
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.
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: Monty Myers Contact Name: Cody Dinger
Authorized Title: Drilling Manager Contact Email: Cdlfl er hilCOr .Corn
Authorized Contact Phone: 777-8389
Signature: _— Date: • -7, Z 11
INSTRUCTIONS
General: 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.
Item 1 a: 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.
Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: 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.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: 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.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: 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).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 28: 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.
Item 30: 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.
Item 31: 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.
Form 10-407 Revised 512017 Submit ORIGINAL Only
K
corn Al.*., LLC
Ong, KB Elev.: 26.5' / GL Elev.: 21.8'
TD =12,994' (MD) /TD=4,404 (TVD)
PBTD =12,989' (MD) / PBTD= 4,400' (TVD)
Milne Point Unit
I Well: MPUE-41
SCHEMATIC Last Completed: 4/12/2019
PTD: 219-031
TREE & WELLHEAD
Tree Cameron 2-9/16" 5M
Wellhead FMC Gen V
OPEN HOLE / CEMENT DETAIL
Conductor
±270 ft3
12-1/4"
Stg 1 -Lead -600 sx/Tail-400 sx
Top
Stg 2 - Lead -440 sx / Tail - 270 sx
BPf
Cementless Screens Liner in 8-1/2" hole
CASING DETAIL
Size
Type
Wt/ Grade/ Conn
ID
Top
Btm
BPf
20"
Conductor
N/A/X-52/Weld
N/A
Surface
106.5'
N/A
9-5/8"
Surface
40/L-80/TXP
8.835
Surface
6,474'
0.0758
7-5/8"
Tieback
29.7 / L-80 / Hyd 521
6.875
Surface
6,309'
0.0459
4-1/2"
Liner 25011 Screens
13.5 / L-80 / Hydril 625
3.920
6,301'
12,994'
.0149
TUBING DETAIL
EUEEUE-8rd2 441
Surface
WELL INCLINATION DETAIL
KOP @ 360
Max Hole Angle=93.5° @ 6,511' MD
IFWFI RV DFTAII
No.
Top MD
Item
ID
1
141'
GLM: 2-7/9"x 1" Side Pocket KPMM w/DPSOV
2.347"
2
5,032'
GLM w/Dummy: 2-7/8" x 1"
2.347"
3
5,121'
XN Nipple, 2.205" no go
2.205"
4
5,732'
Discharge Head: FPDIS
9,901'
5
5,733'
Upper Tandem Pump: 134 STG FLEX 17.5
6
5,756'
Lower Tandem Pump: 134 STG FLEX 17.5
7
5,780'
Gas Separator: GRS FER N AR
8
5,785'
Upper Tandem Seal: GSB3DBUT SB/SB PFSA
9
5,792
Lower Tandem Seal: GSB3DBUT SB/SB PFSA
10
5,798'
Motor: CL5 XP- 250hp/ 2715V/ 51A
11
5,815'
Sensor, Zenith
12
5,818'
Centralizer: Bottom @ 5,820'
13
6,301'
BOT SLZXP LT Packer / Liner Hanger 7" x 9-5/8"
6.190"
14
6,309'
7-5/8" Tieback Assy.
6.151"
15
6,322'
7" H563 x 4.5" TSH 625 L-80 XO
3.860"
16
12,957'
4-1/2" Drillable Packoff Sub
2.390"
17
12,989'
WIV Valve LTC BxB (1" Ball on Seat/Closed)
-
4-1/2" SOLID LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm Btm
(MD) (TVD)
5
6,327'
4,357'
6,545'
4,358'
9
8,808'
4,344'
9,169'
4,352'
7
9,415'
4,366'
9,697'
4,384'
3
9,901'
4,399'
10,041'
4,407'
4-1/2" Screens LINER DETAIL
Jts Top Top
(M D) (TVD)
Btm Btm
(MD) (TVD)
56
6,545'
4,358'
8,808'
4,344'
6
9,169'
4,352'
9,415'
4,366'
5
9,697'
4,384'
9,901'
4,399'
72
10,041'
4,407
12,951'
4,399'
GENERAL WELL INFO
API: 50-029-23622-00-00
Completion Date: 4/12/19
Edited By: CJD 5-7-2019
MPU E-41 OH Sidetrack Summary
CGM�/ems+✓
PTD: 219-031 / API: 50-029-23622-00-00
PB1
PB2
PB3
TD
7,973' MD / 4,306' TVD
9,458' MD / 4,325' TVD
11,850' MD / 4,368' TVD
KOP
7,468' MD
7,800' MD
11,567' MD
Date
3/27/2019
3/28/19(TD Date) -4/1/19(KOP Date)
4/4/2019
CGM�/ems+✓
PTD: 219-031 / API: 50-029-23622-00-00
U
Well Name: MP E-41
Field: Milne Point
County/State: , Alaska
(LAT/LONG):
xvation (RKB): 26.4
API #:
Spud Date: 3/13/2019
Job Name: 1910939D MPE-41 Drilling
Contractor Innovation
AFE #:
Hilcorp Energy Company Composite Report
Ops Summary
Spot sub over conductor, center and level sub, Spot cattle chute. Spot pipe shed and mud module.
3/10/2019
3/11/2019
Continue spotting mud module. Spot gen module. Lower all stairs and landings. Bring steam, air, and water online. Swap to Gen power. Spot break shack and
envirovac. Hook up utilidoor interconnects. Hook up pit interconnect. Scope derrick. Spot cuttings box. Hi -line power at 11:30.;Bridle down. Work on rig
acceptance checklist. Continue hooking up interconnects. Put mud pumps together. Install elevators with 5" inserts. Change out saver sub. Fill pits with water.
Test gas alarms.;N/U Diverter: set stack on diverter T. Install knife valve and connect. Bolt up diverter pieces to catwalk. Install 4" valves on conductor. Process
5" drill pipe in shed. Move water through charge pumps, pop offs, bleeder lines, mix hopper.;Continue installing diverter line and weight block. Connect chain
and binders to stack. Change out air boots. Install riser. Energize accumulator. Process remaining 5" drill pipe. Clean and clear rig floor of unnecessary subs.
Load MWD tools into shed. Change out tong dies. Prep and inspect;pipe handling equipment. Change out grease zerts on drag chain.
3/12/2019
tighten all flanges on diverter. Collect RKB's. Post diverter signs.
Ria accented 06.00 Pickup, drift and rack back 260 joints 5" NC50 drill pipe, 16 HWDP, 1 HWDP/Jars, 2 drill collars. L/D mouse hole.;Pick up working single.
Hang top drive. Slip and cut 75" of drill line. Check brake disc gap.;Service rig; grease crown, TD, drawworks, spinners.;Test diverter system. Knife open 6
seconds, Bag close 9 seconds. Accumulator drawdown: Starting pressure 3000psi, final 2000. 200 psi recharge =19 secs, full recharge = 53 seconds. Distance
to ignition source from end of vent 80', 165' from sub, total length 17T.;Pre spud meeting. MJU bit to 1.5° bend 8" Sperrydrill motor. Stage TM, DM and UBHO
on rig floor. RIH with 1 stand HWDP.;Fill conductor and stack with water. Observe leak at 16" airboot. Change out air boot, adjust flowline rubber and tighten.
PT high pressure lines to 3000 psi.;RIH to 104' and tag up. Pickup, establish circulation 450 gpm and rotary 40 rpms. Drill out conductor to 114'. Pickup into
conductor while swapping to spud mud. Continue drilling 12-1/4" hole from 114'to 220'; 450 gpm/630 psi with 155psi diff, 40 rpms/2000 ft-Ibs.;POOH to 33' to
makeup MWD tools. No issues.;Hauled 0 bbis Fluid to MP G&I total = 0 bbis
Hauled 100 bbis H2O from L -Pad Lake total = 810 bbis {\
itis
Lost 0 bbto formation Total fluid lost= 0 bbis f✓vo
3/13/2019
P/U BHA: WU MWD tools, UBHO. Measure RFO = 179/813 = 79.26°, orientate UBHO. RIH with stand of flex collars and HWDP. Shallow pulse test. RIH and
tag fill at 190', wash down to 220'.;Drill and slide 12.25" hole F/ 220' to 307' MD. 87' Total (44' AROP) 450 gpm/710 PSI, 40 RPM/2100 ft -lbs, WOB 5K, 8.9 ppg
mud. PUW 52K, SOW 56K, ROTW 54K.;Drill and slide 12.25" hole F/ 307' to 774' MD. 46T Total (78' AROP) 450 gpm/975 PSI, 40 RPM/3500 ft -lbs on, 1700 ft -
lbs off btm, WOB 12K, ECD 9.85 ppg with 8.9 ppg mud. PUW 71 K. SOW 71 K, ROTW 73K Sliding as needed to build 4°/100'.;Drill and slide 12.25" hole F/
774' to 1283' MD. 509' Total (85' AROP) 530 gpm/1285 psi, 60rpms/4500 ft -lbs on, 2800 ft -lbs off him, WOB 12K, ECD 9.9 ppg with 8.9 ppg mud. PUW 82K,
SOW 76K, ROTW 79K Sliding as needed to build 4°/100'.;Drill and slide 12.25" hole F11283'to 1875' MD. 592' Total (99' AROP) 600 gpm/1720 psi,
80rpms/5.7Kft-lbs on, 4.5Kft-lbs off btm, WOB 8-12K, ECD 10.9 ppg with 9.2 ppg mud. PUW 88K, SOW 76K, ROTW 82K.;Hauled 750 bbls Fluid to MP G&I
total = 750 bbis
Hauled 570 bbis H2O from L -Pad Lake total = 1380 bbis
Lost 0 bbis to formation Total fluid lost= 0 bbls
3/14/2019
Drill 12.25" hole F/ 1875'to 2429' MD. 554' Total (92' AROP) 600 gpm/1920 psi, 80rpms/6.5Kft-lbs on, 6Kft-lbs off him, WOB 24K, ECD 10.49 ppg with 9.2 ppg
mud. PUW 101 K. SOW 78K, ROTW 86K. Max gas 257U. Slide as needed to hold tangent to 2512', then for 4°/100 curve. Base of Permafrost: 2068';Drill 12.25"
hole F/ 2429'to 3000' MD. 571' Total (95' AROP) 600 gpm/1850 psi, 80rpms/6.5Kft-lbs, WOB 1OK, ECD 9.93 ppg with 9.2 ppg mud. PUW 122K, SOW 85K,
ROTW 97K Max gas 1660U (SV2 @ 2666'MD12216'TVD). Backream full stands, slow pump rate on downstroke. Slide as needed for 4°/100' curve.;Drill and
slide 12.25" hole F/ 3000'to 3571' MD. 571' Total (95AROP) 600 gpm/2200 psi, 80rpms/9Kft-lbs, WOB 10K, ECD 9.95 ppg with 9.2 ppg mud. PUW 140K,
SOW 94K, ROTW 110K Max gas 342U. Backream full stands, slow pump rate on downstroke. Slide as needed for 4°/100' curve.;Drill and slide 12.25" hole F/
3571'to 4015' MD. 444' Total (74' AROP) 600 gpm/2015 psi, 80rpms/10.5Kft-lbs, WOB 5-10K, ECD 9.9 ppg with 9.2 ppg mud. PUW 155K, SOW 96K, ROTW
115K Max gas 89U. Backream full stands, slow pump rate on downstroke. Slide as needed for 4°/100' cuwe.;Hauled 1094 bbls Fluid to MP G&I total = 1844
bbis
Hauled 1170 bbis H2O from L -Pad Lake total = 2550 bbls
Lost 0 bbis to formation Total fluid lost= 0 bbis
3/15/2019
Drill 12.25" hole F/ 4015'to 4399' MD. 384' Total (64' AROP) 600 gpm/2100 psi, 80rpms/11.51<11-lbs on, 10-131(ft-lbs off btm, WOB 2-12K, ECD 10.05 ppg with
9.2 ppg mud. PUW 171 K, SOW 97K, ROTW 123K. Max gas 64U. Backream full stands, slow pumps on downstroke. Slide as needed 4°/100 curve WP04.;Drill
12.25" hole F/ 4399' to 4820' MD. 421' Total (70' AROP) 600 gpm/2050 psi, 80rpms/15.51<11-lbs on, 16Kft-lbs off btm, WOB 2-12K, ECD 9.9 ppg EMW with 9.2
ppg mud. PUW 177K, SOW 97K, ROTW 127K. Max gas 177U. Backream full stands, slow pumps on downstroke. Slide as needed 4°/100 curve
WP04.;Observed oil at shakers at 4686' (Ugnu L sands at 4575').;Drill 12.25" hole F/ 4820' to 5099' MD. 279 Total (47' AROP) 600 gpm/2050 psi,
80rpms/15.50-lbs on, 16Kft-lbs off btm, WOB 5-15K, ECD 9.9 ppg EMW with 9.2 ppg mud. PUW 187K, SOW 95K, ROTW 127K. Max gas 127U. Backream
full stands, slow pumps on downstroke. Slide (75%) for 4'/100 curve WP04.;Drill 12.25" hole F/ 5099'to 5385' MD. 286' Total (48' AROP) 600 gpm/2120 psi,
80rpms/15.51<11-lbs on, 14-191(ft-lbs off btm, WOB 8-16K, ECD 9.75 ppg EMW with 9.2 ppg mud. PUW 200K, SOW 93K, ROTW 126K. Max gas 713U.
Backream full stands, slow pumps on downstroke. Slide (75%) for 4°/100 curve WP04.;Hauled 750 bbls Fluid to MPG&I total = 2594 bbls
Hauled 1040 bbis H2O from L-Pad Lake total = 3590 bbls
Lost 0 bbis to formation Total fluid lost= 0 bbis
Distance to well plan #04: 5.58' high, 24.05 right.
3/16/2019
Drill 12.25" hole F/ 5385to 5767' MD. 382' Total (63' AROP) 600 gpm/2230 psi, 80rpms/16Kft-lbs on, 16-19Kft-lbs off him, WOB 8-20K, ECD 9.98 ppg EMW
with 9.2 ppg mud. PUW 196K, SOW 83K, ROTW 123K. Max gas 560U. Backream full stands, slow pumps on downstroke. Slide as needed for WP04.;Drill
12.25" hole F/ 5767' to 6073' MD. 306' Total (47' AROP) 600 gpm/2220 psi, 80rpms/l 71(ft-lbs on, 17-19Kft-lbs off btm, WOB 8-18K, ECD 9.8 ppg EMW with 9.2
ppg mud. PUW 205K, SOW 82K, ROTW 121 K. Max gas 640U. Backream full stands, slow pumps on downstroke. Slide as needed for WP04.;Rack back from
6073'to 5986. Install TIW and head pin. Change out wash pipe, circulate 330 gpm/1200 psi. Rig down head pin and TIW. Wash and ream down from 5985' to
6073'.;Drill 12.25" hole F/ 6073'to 6243' MD. 170' Total (48' AROP) 550 gpm/2050 psi, 80rpms/17Kft-lbs on, 17-19Kft-lbs off btm, WOB 18-20K, ECD 9.8 ppg
EMW with 9.2 ppg mud. PUW 200K, SOW 82K, ROTW 120K. Max gas 147U. Backream full stands, slow pumps on downstroke. Slide as needed for
WP04.;Drill 12.25" hole F/ 6243'to 6430' MD. 187' Total (32' AROP) 550 gpm/2180 psi, 80rpms/171(ft-lbs on, 17-20Kft-lbs off him, WOB 12-20K, ECD 10.0 ppg
EMW with 9.3 ppg mud. PUW 200K, SOW 82K, ROTW 118K. Max gas 839U. Backream full stands, slow pumps on downstroke.;Entered Schrader NB at
631 T, start building angle to land at 92'.;Hauled 750 bbis Fluid to MP G&1 total = 3344 bbis
auled 1030 bbls H2O from L-Pad Lake total = 4620 bbis
Q
st 0 bhla to formation Total fluid lost= 0 bbls
�Jv
Distance to well plan #04: 41.86', 38.32' Low, 16.84' right.
3/17/2019
Drill 12 25" hole F/ 6430' to TD at 6484' MD 54' Total (27' AROP) 550 gpm/2140 psi, 80rpms/17 -20Kft-lbs on, 17-20Kff-Ibs off btm, WOB 12-221K, ECD 10.12
ppg EMW with 9.3 ppg mud. PUW 192K, SOW 84K, ROTW 116K. Max gas 428U. Backream full stands, slow pumps on downstroke.;BROOH from 648W to
6306' above Schrader NB sands. 600 gpm/2110, 80 rpms/17-20Kft-Ibs. Max gas 396U, ECD 10.12 ppg EMW with 9.3 ppg mud. PUW 192, SOW 84K, ROTW
116K.;Circulate hole clean, Pump tandem low willow vis and high wt high vis sweep (60 bbls late 25% increase) 2 x annular volume reciprocating pipe. 600
gpm/1695 psi, 80 rpms/18-20Kft-Ibs ECD 9.8 ppg.;Attempt to RIH on elevators, unable to. Wash down from 6306'to 6484'. Flow check well, static.;PJSM
BROOH from 6484'to 6243', 600 gpm/2015 psi; 80 rpms/19-25Kft-lbs. ECD 10.4 ppg EMW. PUW 190, SOW 81K, ROTW 114K.;At 6243' hole unloaded with
gravel and packed off flowline. Jet flow line and CBU x 1.5 515 gpm/1730 psi, 80rpm/23Kft-Ibs.;Continue to BROOH from 624Y to 6150'. Significant amount of
gravel and wood overloaded drag chain and siezed. Slow pumps to 300 gpm/840 psi 30 rpms and work pipe while clearing drag chain.;Continue to BROOH
from 6150'to 4272'; 5-15fpm as hole allows. 540 gpM1660 psi, 80 rpms/17Kft-lbs. Continuously gunning flowline, still seeing significant gravel aver the shakers
but getting better.;Continue to BROOH from 4272' to 2424', hole unloaded gravel at 3954'. 15-25 fpm 580gpm/1870 psi, 80 rpms/8 - 9Kft-Ibs.;Hauled 981 bbis
Fluid to MP G&I total = 4325 bbis
Hauled 910 bbis H2O from L-Pad Lake total = 5530 bbls
Lost 0 bbis to formation Total fluid lost= 0 bbis
3/18/2019
Continue to BROOH from 2424'to 2400'. CBU 580 gpm/1660 psi 80rpms/8-11Kft-Ibs. Hole unloading gravel.;Continue to BROOH from 2400'to 1220' at 2-12
fpm as hole dictates; 570 gpm/1610 psi, 80rpms/6Kft-Ibs with torque spikes up to 20Kft-Ibs. PUW 106K, SOW 56K, ROTW 74K. Flowline packing off multiple
times with gravel, pump through bleeder to clear Iines.;Continue to BROOH from 1229to 540', 540 gpm/1287 psi, 80rpm/4500 ft-lbs. PUW 72K, SOW 55K,
ROTW 62K.;POOH on elevators from 540'to 152'.;LID BHA as per DD. Download MWD. Bit grade 3-2-CT-A-F-1-WT-TD. Clean and clear rig floor. Monitor
well on trip tank, no Iosses.;Change out wash pipe (leaking), saver sub and grabber dies. Service rig. Grease top drive, crown, blocks and spinners.;PJSM rig up
to RIH with casing. Rig up Volant tool, bail extensions, elevators. Bring up slips. Verify pipe count. Bring up centralizers to rig floor.;M/U shoe track Bakerlok
connections. WU shoe, joint, joint, Float collar. Install top hat, joint, baffle adapter. Check floats - good. Continue to RIH with 98/8" 40# L-80 TXP casing
installing centralizers as per detail to 200'.;Trouble shoot hydraulic leak on skate. Repair Ieak.;Hauled 635 bbis Fluid to MP G&I total = 4950 bbis
Hauled 990 bbis H2O from L-Pad Lake total = 6520 blots
Lost 0 bbis to formation Total fluid lost= 0 bbls
3/19/2019
944' MD. Unable to RIH on elevators at 59V MD. Start washing and rotating down at 210 GPM, 195 PSI, 12RPM,
TRO 5-81K. Max Gas 16U, P/U 65K, SLK 36K, ROT 60K.;Cont. wash and rotate 9 5/8" Csg as per tally F/944! to 1,250' MD. 210-378 GPM, 290-600 PSI, RPM
12-25, TRQ 9-16.2K, Max Gas OU. P/U 120, SLK 35K, ROT 65K. F11,189to 1,250' MD fighting high TRQ, running gravel and packing off.;Cont. wash and
rotate 9 5/8" Csg as per tally F11,250' to 1,537' MD. 294-336 GPM, 270-350 PSI, RPM 20, TRQ 11-18.2K, Max Gas OU. PIU 130, SLK 35K, ROT 71K. F/ 1,380'
to 1,537' MD fighting ledges, fight spots and slight packing off. Mostly sand and clay at shakers.;Running water at 20-30 BPH, maintain 85 Vis.;Cont. wash and
rotate 9 518" Csg as per tally F/ 1,537' to 2,484' MD. 336 GPM, 300-350 PSI, RPM 20, TRQ 11-16K, Max Gas OU. P/U 130, SLK 35K, ROT 90K. F/ 1,537'to
1,730' MD Encountering tight spots with sand at shakers. F/ 1,730' hole seems to have cleaned up W/ average ROP 12-14 FPM.;Hauled 404 bbis Fluid to MP
G&I total = 5,354 bible
Hauled 400 bbis H2O from L-Pad Lake total = 6920 blots
Cont. wash and rotate 9 5/8" Csg as per tally F/ 2,484' to 3,939 MD. 330 GPM, 455 PSI, RPM 10, TRQ 20K, Max Gas OU. P/U 235, SLK 35K, ROT 104K.;Cont.
3/20/2019
wash and rotate 9 5/8" Csg as per tally F/ 3,939' to 5,152' MD. 333 GPM, 480 PSI, RPM 7-8, TRQ 21K, Max Gas OU. P/U 295, SLK 35K, ROT 92K. Lost free
rotation at 3,939 MD.;Cont. wash and rotate 9 5/8" Csg as per tally F/ 5,152' to 6,474' MD. 333 GPM, 500-530 PSI, RPM 4, TRQ 21 K, Max Gas OU. Attempted to
reciprocate and rotate pipe on bottom pulled 325K, slacked off to 129K and parked on depth.;CBU 270 GPM, 490 PSI, Max Gas at BU 37U. Dynamic loss rate
11.2 bph at 8 BPM, reduce pump rate to 6.5 BPH. PJSM RID and L/D Weatherford Tongs and RID Bail Ext.;PJSM CIO Volant Tool due to leaking swivel. Break
Circ. to reduce YP <18 and <45 Vis running water at 20 BPH and Desco. Circ. at 6.5 BPM, 415 PSI Initial loss rate 11 BPH slowing to 6 BPH during conditioning.
Lost 29 bbls.;SIMOPS R/U Halliburton cement unit. Haul excess fluid from pits for cement job. Blow down cement Iine.;PJSM W/ all parties for the cement job.
Shut down and pump through bleeder to clear flow line. Blow down Top Drive. R/U cement line to Volant. Break Circ. at 6 bpm 500 PSI. HAL prep for PT.;Hauled
346 bible Fluid to MP G&I total = 5,700 bbis
Hauled 780 bbls H2O from L-Pad Lake total = 7,700 bbis
Lost 13 bbis to formation Total fluid lost= 13 bbis
3/21/2019
Pump I st stacie crtit HES flood lines with 5 bbis water. PT lines 1000/4500 psi - good. 60 bbis 10ppg Clean Spacer at 2 bpm/280 psi Drop Bypass plug 255
bbls Type 111112 ppg Lead cement at 5.5bpm/494 psi 82 blots Class G 15.8 ppg Tail cement at 4bpm/360 psi.;Drop closing plug. Displace cement with 20 bbis
FW (HES) 252bbis 9.5 ppg spud mud at 4 bpm/580psi, 80 b bIs FW (HES)(spotted across ESMTR) at 4 bpm/850 psi, 141.4 bbis 9.5 ppg spud mud at FCP
2bpm/1050 psi, (9 bbis over calculated). Pressure up to 1600 psi and held 5 min.;Bled back 2.5 blots. Floats held. CIP 11:44. 95%..;Using rig pump, stage
pressure up 2850 psi to open ES Cementer. Attempt to circulate through stage too. See slight returns. Stage pump to 7 bpm, work pipe and establish full returns.
CBU x 2 through Stage tool staging up to 6bpm, See Heavy gravels/ spacer/trace cemenKcontaminated mud @ surface.;Continue to circulate through stage tool
@ 2200'. See continual gravels back at shakers. Slow pump rate to 4 bpm 210 PSI and circulate while prepping for 2nd stage cmt job. Lost 132 bbls during
circulation ;PJSM for 2 nd stage cement iob. Cont. Circ at 4 BPM, 230 PSI. Blow through all lines. Flush out flow line. Halliburton pump 5 bbl H2O, low Press
1,000 PSI stall, 4,000 PSI high. C/O Lo Torque valve and retest, good. Pump 60 bbl 10.0 ppg Mud Push at 2.8 BPM, 140 PSI.;Pump 338 bbis 10.7 ppg Perm L
Lead Cement at 4 BPM, saw mud push and contaminated cement at surface. Started dumping overboard when good cement was seen at surface. Lost 37 bbis
during lead. Pump 56 bbls 15.8 ppg Tail, shut down and drop Plug. Halliburton pumped 20 bbl H20.;Rig started chasing cement at 4 BPM 530 PSI, slow pumps
to 2 BPM at 1,800 Strokes away. Bumped plug as calculated at 2,420 Stks. FCP 600 PSI. Increase Press. to 1,550 PSI ES shifted closed. Cont to Press. up to
1,940 PSI for 5 Min. Check Floats, good. CIP @ 02:47.;Flush and clean all surface Equip of cement. PJSM N/D Stack to cut 9 5/8" Csg ;Hauled 1,099 bbls Fluid
to MP G&I total = 6,799 bbis
Hauled 1,430 bbis H2O from L-Pad Lake total = 9,130 bbis
Lost 161 bbis to formation Total fluid lost = 174 bbls
3/22/2019
PJSM Remove mouse hole, open hatches, clean flow line and surface Equip of cement. Clean pits. Remove diverter section down stream of Knife Valve. R/U
Bridge Cranes to Stack. RID chains and pull riser. Unbolt Diverter Tee.;PJSM Drain Stack and raise W/ starter head. Set emergency slips as per NOS. Prep for
rough cut. SIMOPS Inspect MP 91. Inspect and fill Koomey bottles as needed. Cont. cleaning pits.;PJSM Make rough cut on 9 5/8" Csg. (Cut 30.191) Set Stack on
head. RIU Riser and M/U Johnny Whacker, flush Stack. N/D Knife Valve. N/D Stack. Remove Diverter Tee. Set back Stack. Make final out on 9 5/8" Csg.
SIMOPS Cont. cleaning pits. Check cross head on MP #1. Filter gear oil on MP #1.;Phase 2 weather condition started at 16:17.;Set 9 5/8" Slip Lock Head. Test
Void 500 PSI low and 2,400 PSI high for 10 Min. NIU Tubing Head. Install DSA.;PJSM Remove Bell Nipple, RIU P/U slings to Top Drive and mise RCD and
stage at flow box. Spot BOPE Stack on Well Head. Lower RCD onto Annular and N/U. SIMOPS Filler MP #2 gear oil. Inspect MP #2. Cont, cleaning pits.;PJSM
Cont. N/U BOPE, Remove 4" conductor valves and install caps. Hook up Choke and Kill Lines. Hook up chains and center BOPE. SIMOPS Finish cleaning pits.
On MP #2 C/O Liners, Swabs and one Wear Plate.;Hauled 2,002 bbis Fluid to MP G&I total = 8,801 bbis
Hauled 710 bbis H2O from L-Pad Lake total = 9,840 bbis
Lost 0 bbis to formation Total fluid lost= 174 bbis
3123/2019
Cont. WU BOPI L2on Ram doors and clean cavities. Take measurements of the ram cavities and ram blocks. SIMOPS C/O Liners and wear plates on MP.
F usr i�bon (fines in pits. Remove surface Equip from rig floor. 07:41 weather condition reduced to Phase i.;Cont. BOPE measurements. Close up ram doors.
Remove RCD plug and install riser. M/U Koomey lines and hard lines to RCD. SIMOPS Cont. work on MP. Remove Master Bushing and set split bushings. Cont.
flushing suction lines in pits. Misc. welding. Test Gas alarms.;PJSM Test BOPE. Perform BOPE Test W/ 5" & 4.5" Test Jim. Test Dart Valve, FOV, Annular, Upper
and lower Rams, Blind Rams Choke Manifold valves 1-15, Upper and lower IBOP, Mez Kill, Manual Choke and Kill, HCR Choke and Kill, Super and Manual
Choke. Tested to 500 PSI low and 3,000 PSI high for 5 Min;Witnessed waived by AOGCC Bob Noble. SIMOPS Cont. R/U hard lines to MPD.;Perform Koomey
draw down initial start Press. Accumulator 1,650 PSI, Annular 1,100 PSI, Final charge Press Accumulator 2,905 PSI, Annular 1,150 PSI 200 PSI in 32 Sec, full
85 Sec. 6 bottle Nitrogen average 2,383 PSI.;R/D test Equip. and UD test joint.;PJSM For testing MPD system. Drain Stack and pull Riser. Install MPD
Vcharge
t t plug and I to test. 11111 Psi low and 1,500 PSI high for 10 Min. charted. Blow down MPD Equip. Pull test plug and set Wear Bushing.;Install drip pan
nd Mouse Hole. Install 5" elevators. Stage BHA #2 tools on rig floor. Break out old Bit and sleeve. PJSM for PIU M/U BHA #2.;Hauled 171 bola Fluid to MP G&I
total = 8,972 bbis
Hauled 260 bbis H2O from L-Pad Lake total= 10,100 bbis
Lost 0 bbls to formation Total fluid lost = 174 bbis
3/24/2019
PPJSM PT mud lines to 2,000 PSI. Blow down Top Drive, Kill and Choke Line.;Trouble shoot handler rotation sensor. C/U sensor.;PJSM P/U BHA #2. P/U M/U
8.5" Smith Tricone, 6 3/4" Sperry Lobe Motor, 6 3/4" NM UBHO and 1 stand 5" HWDP to 96' MD. At 10:00 changed over to Gen power sue to Operations
performing emission tasts.;Service Rig & inspect Derrick.;Cont. RIH 5 stands 5" HWDP, 6 114" Combo Jars, 5" HWDP F/ 96'to 407' MD.;PJSM Cont. RIH BHA
#2 W/ 5" HWDP F/ 407' to 593' MD. RIH WI5" D.P. NC 50 F/ Derrick F/ 593' to 2,121' MD. Wash down to 2,225' MD 200 GPM, 260 PSI Tag cement W/ 3K
down.;Drill hard cement F/ 2,225'to 2,238' MD 300 GPM, 530 PSI, 30 RPM, TRQ 5K WOB 3-4K, Tag ES Cementer on depth 2,238' MD. Work thru multiple
times at 300 GPM, 460 PSI, 30 RPM, TRQ 5.5K, P/U 98K, SLK 70K, ROT 82K.;Cont. RIH W/ 5" D.P. on elevators F/ 2,245' to 6,311' MD. PfU 204K, SLK 90K,
Rig back on high line @ 17:35.;CBU 3X 450 GPM, 1,070 PSI, 30 RPM, TRQ 18-20K. Hole unloaded at first BU W/ heavy cement and mu contamination at
Shakers.;PJSM for Csg Test. Blow down Top Drive. RIU head pin and high Press hose to mud manifold. Fill surface lines. Pump at 0.5 BPM staging up to 2,500
PSI. Hold for 30 Min on chart. Pumped 4.65 bbis, bleed back 4.6 bbis. Blow down surface Iines.;PJSM For MPD Element. Build 1 stand 5" D.P. out of tally. Slip
MPD Element on stand as per Beyond Rep onsite. Rack back in Derrick. Drift OD 3,125".;PJSM Wash F/ 6,31 V to 6,350' MD tag W/ 3K down. 400 GPM, 980
PSI, 30 RPM, TRQ 19K. Drill hard cement and BFL Adapter F/ 6,350'to 6,360' MD. BFL Adapter on depth at 6,352' MD. 400 GPM, 1,020 PSI, 30 RPM, TRQ
19K, WOB 6-8K, P/U 204K, SLK 81 K, ROT 117K.;PJSM Cont. drilling Shoe Track F/ 6,360' to 6,393' MD 400 GPM, 1,120 PSI, 30 RPM, TRQ 18-19K, WOB 8K.
Tag FC on depth at 6,393' MD. Cont drilling F/ 6,395' to Shoe at 6,474' MD. Drill F/ 6,474' to 6,504' MD with 20' of new hole.;CBU at 450 GPM, 1,250 PSI.
Observed Max Gas at BU 826U diminished to 801J. Pump total 357 bbis. Shut down and monitor well, static.;PJSM for displacement. Rotate and reciprocate F/
6,495' to 6,439' MD. Displace Spud Mud to Baridrill N 8.9 PPG W139 bbl HiVts sweep and 463 bbis at 295 GPM, 630 PSI, 30 RPM, TRQ 10.5K. ROT 119K.
SPR at 6,436' (6,361' TVD) MP #1 32-245,48-238 MP #2 32-238, 48-282.;PJSM R/U Test Eqiup for FIT. Perform FIT to EMW 12 PPG W/ 8.9 MW 704 PSI,
Pumped 1.48 bbl, bleed back 1 bbl. RID Test Equip.;PJSM For ELine Gyro. R/U ELine.;Hauled 632 bible Fluid to MP G&I total = 9,298 bbis
Hauled 260 bbls H2O from L-Pad Lake total = 10,360 bbis
Total fluid lost on Surface = 174 bible
312512019
RN Pollard E-line w/ Scientific Drilling Gro tool 1.85" OD). RIH surveying from surface to 4,799' before losing string wt. Continue RIH pumping down E-line @
6.4 BPM, 702 psi to land depth of 6392' MD. POOH surveying F/ 6392' to surface (150-250 fpm). RID Pollard E-line equip and release.;PJSM Monitor well,
static. POOH on elevators F/ 6,439' to 593' MD. Pumped 25 bbl Dry Job. Screen down Shakers to 120's due to mud properties. PIU 60K, SLK 60K;PJSM for UD
BHA. UD 17 Jnts 5" HWDP. Rack back 2 stands of 5" HWDP including Jars. UD UBHO, Motor and Bit as per Sperry Rep onsite. Bit Grade 1 -1 -WT-A-E-I-NO-
BHA;Clean and clear rig floor, prep for P/U BHA #3.;PJSM for P/U BHA. P/U M/U 8.5" SK616-Jl D PDC Bk, 8.5" NRP, Geo Pilot 7600 XL, 6 3/4" ADR/HCIM, 6
3/4" ILS, 6 3/4" DGR, 6 3/4" DM, 6 3/4" TM, 6 3/4" FS, 2 ea 6 3/4" NM FC, 6 3/4" FS, Jar Combo and 3 5" HW DP to 274' MD.;Single BHA #3 W/5" D.P. F/ Pipe
Shed F/ 274' to 592' MD. Perform shallow hole test for MWD 400 GPM, 430 PSI. Break in Geo Pilot seals at 5,10, 20, 30, 40, 50 RPM F/ 10 Min. Cont. single in
hole 5" D.P. F/ 592'to 2,504' MD.;Hauled 805 bbis Fluid to MP G&I total= 10,103 bbis
Hauled 390 bola H2O from L-Pad Lake total = 10,750 bbis
Total fluid lost on Surface = 174 bible
326/2019
Single in hole W/5" D.P. F/ Pipe Shed F/ 2,504'to 5,115' MD. Fill D.P. every 2,000'. P/U 142K, SLK 108K.;Slip and cut drilling line. Cut 68'. Calibrate Blocks and
Elevators stops. Circ. at 3 BPM, 194 PSI.;Trouble shoot Pipe Handler. Open front lid on Top Drive and C/O Pipe Handler sensor. Grease Blocks, Crown and Top
Drive. Circ. and condition mud 125 GPM, 185 PSI.;PJSM Blow down Top Drive. RIH W/ 5" D.P. F/ Derrick F/ 5,115'to 6,262' MD, Wash down to 6,390' MD 170
GPM, 281 PSI. P/U 150K, SLK 96K.;CBU at 440 GPM, 885 PSI, reduced pump rate to 285 GPM, 460 PSI due to mud properties at Shakers. Hold PJSM for
installing Element for MPD.;Install Element to RCD as per Beyond Rep onsite. Circ. through the MPD lines staging pumps up to 500 GPM, 1,035 PSI.;PJSM
Wash down F/ 6,390' to 6,504' MD. Drill Ahead 8.5" Production hole F/ 6,504' to 7,025' MD. Total 521' (AROP 80')450 GPM, 1,105 PSI, 120 RPM, TRQ 14K to
15.5K. Max Gas 1,975U. At 6,890' MD Applied 75 PSI back pressure W/ MPD for 9.2 ppg EMW due to hole stability and BGG.;Trouble shoot internet on rig.
Close Approach to MPE-32, 76.55' Between Centers, 8.14' Between Elipses 1.12 CF at 6975' MD.;SPR @ 7,025' MD (4,342' TVD) W/ 8.9 ppg MW. MP #1 32-
200, 48-247. MP #2 32-195, 48-235.;Drill Ahead 8.5" Production hole F/ 7,025' to 7,658' MD. Total 63V (AROP 1055) 450 GPM, 1,350 PSI, 120 RPM, TRQ
15.5-16.3K, WOB 8-14, ECD 10.35 ppg Max Gas 1,7470. P/U 151 K, SLK 78K, ROT 105K.;Called operations at 7,048' MD at 00:19 to bring well E-32 on. At
7,343' MD increased MPD back Press to 92 PSI for a EMW 9.3 ppg due to 6000 BBG and Max Gas 1,4000. Crude seen at Shakers. No faults have been
crossed so far in this section. 12 concretions for a total of 42' (3.7%) have been ddlled.;Distance to Well Plan #04: 35.78', 35.28' Low, 5.94' Right ;Hauled 852
bbls Fluid to MP G&I total = 10,955 bbls
Hauled 200 bbis H2O from L -Pad Lake total = 10,950 bbls
Total fluid lost on Surface = 174 blots
327/2019
Continue drlg 8.5" lateral as per Geo F/ 7658'- T/ 7,973' MD. 450 gpm, 1350 psi on, SA 5k wob, 120 rpm, 15.5k tq on, 16k tq off (2-3% lubes). Max gas 1747u,
10.4 ECD. MPD 95-100 psi (9.4 EMW).;CBU @ 7,973' MD while waiting on decision to drill ahead or sidetrack. Circulate @ 450 gpm, 1300 psi, 120 rpm, 17.6k
tq. Decision made to pull back and sidetrack. (505' drilled in PB7).;Pump out of hole F/ 7973'- T/ 7456' MD. 170k up, 65k dn.;Sidetrack operations working F/
7456'- 7483' MD control drilling @ 25 fph w/ 100% deflection @ 160R. Had good indications of sidetrack @ 7,468' MD by ABI's and bit wt. Sidetrackw/ 2-4k
wob, 120 rpm, 450 gpm, stage up to 50 fph once ABI showed separation.;Drill Ahead 8.5" Production hole F/ 7,483' to 7,559' MD (4,344' TVD). Total 76' (AROP
50.7') 450 GPM, 1,310 PSI, 120 RPM, TRQ 16.3K, WOB 15. ECD 10.3 ppg Max Gas 188U. P/U 170K, SLK 65K, ROT 112K. Holding 100 PSI for MPD EMW
Y
9.4 ppg W/ 9.0 ppg MW.;Drill Ahead 8.5" Production hole F/ 7,559' to 8,008' MD (4,334' ND). Total 449' (AROP 74.8') 450 GPM, 1,244 PSI, 120 RPM, TRQ
17.5-18K, WOB 15. ECD 10.4 ppg Max Gas 1,558U. P/U 170K, SLK 59K, ROT 110K. Holding 100 PSI for MPD EMW 9.45 ppg W/9.0 ppg MW.;SPR @ 7,748'
MD (4,344' ND) MW 9.4 ppg MP #132-208, 48-270 MP #2 32-215, 48-265.;Drill Ahead 8.5" Production hole F/ 8,008'to 8,555' MD (4,336' TVD). Total 547'
(AROP 912) 450 GPM, 1,405 PSI, 120 RPM, TRQ 18.5K, WOB 15. ECD 10.7 ppg Max Gas 1,558U. P/U 174K, SLK 55K, ROT 104K. Holding 100 PSI for ,
MPD EMW 9.45 ppg W/9.0 ppg MW.;SPR @ 8,423' MD (4,331' TVD) MW 9.4 ppg MP #1 32-240,48-290 MP #2 32-246, 48-300.;No faults have been crossed
. 14 concretions for a total of 46' (2.3%) have been drilled in this lateral so far.;Distance to Well Plan #04: 23.95', 23.75' Low, 3.07' Left.;Hauled 286 bbls Fluid to
MP G&I total= 11,241 bbls
Hauled 520 bbls H2O from L -Pad Lake total = 11,470 bols
Total fluid lost on Surface = 174 bbls
3/28/2019
Drill Ahead 8.5" Production hole F/ 8,555'- T/ 8 992' MD. Total 437' (AROP 73') 450 GPM, 1,370 PSI, 120 RPM, TRQ 17.5K, WOE 15. ECD 10.7, P/U 174K,
SLK 55K, ROT 104K. Max Gas 1,145U. MPD @ 100 psi / 9.45 EMW (9.1 MW). Tandem lo/hi sweep @ 8805'w/ 3% lube. 50% inc (silt,sand).;Drill Ahead 8.5"
Production hole F/ 8,992'- T/ 9,458' MD. Total 465' (AROP 72') 450 GPM, 1,475 PSI, 120 RPM, TRQ 15 SK, WOB 15. ECD 10.8, P/U 174K, SLK 55K, ROT
104K. Max Gas 514U. MPD @ 100 psi / 9.65 EMW (9.2 MW).;Larce fault was Grossed at 9 343' and with AjhEQX&L23UJ1U_An unexpected wet sand stringer
�1
was drilled from 9,400'to 9,413' MD.;CBU While discussing with town plug back option. Rack back 1 stand F/ 9,45V to 9,440' MD. CBU 450 GPM, 1,440 PSI,
YV
100 RPM, TRQ 9-10K, Holding 100 PSI W/ MPD EMW 9.65 ppg. P/U 145K, SLK 80K, ROT 108K.;Pump out of hole F/ 9,440'to 8,358' MD. Encountered 10K
fy�.1
over pull, BROOH F/ 8,358'to 7,785' MD. 450 GPM, 1,350 PSI, 60 RPM, TRQ 8-10K, PIU 145K, SLK 78K, ROT 106K. Maintain 100 PSI MPD, EMW 9.65 ppg
W/ 9.2 ppg. Max Gas 145U.;SPR @ 9,440' MD ( 4,325' TVD) W/ 9.2 ppg MW MP #1 32-285,48-345 MP #2 32-285, 48-345.;Rotate and reciprocate F/ 7,785'to
7,710' MD 450 GPM, 1,330 PSI, 110 RPM, 9-10K TRQ. Max Gas 71 U. Maintain 100 PSI MPD, EMW 9.65 ppg W/ 9.2 ppg.;Shut down pumps and open MPD
and monitor returns to Shakers for 10 Min. Appeared static. Shut in MPD for 15 Min with no press build. MW 9.2 ppg. Decision was made to BROOH leaving
MPD open.;BROOH F/ 7,785'to 6,385' MD. 450 GPM, 1,150 PSI, 100 RPM, TRQ 8-14K, ECD 10.4 ppg. P/U 145K, SLK 78K, ROT 106K. Pulled through shoe
with out issue. Calc chimp 8.4 bbls, actual 8.4 bbls.;CBU at 6,385' reciprocating pipe 450 GPM, 1,100 PSI, 30 RPM, TRQ 6K, Shutdown pumps and open MPD
and monitor returns to Shakers for 15 Min. Appeared static. Shut in MPD for 15 Min with no press. build. SIMOPS PJSM for RID RCD and R/U Riser.;Hauled 635
bbis Fluid to MPG&I total= 11,876 bbls
Hauled 620 bbis H2O from L -Pad Lake total = 12,090 bible
Total fluid lost on Surface = 174 bbis
3292019
Slow doom Top Drive. Clean cellar F/ POOH. Pull RCD on stand 96 and rack back in Derrick. Install trip riser. Adjust Stack to line up hole and air up boots.;PJSM
POOH on elevators 5" D.P. F/ 6,323' to 5,432' MD. P/U 142K, SLK 82K. No Iosses.;Install FOV and WU Top Drive. Service Top Drive and work on Proximity
Sensor for Pipe Handler. SIMOPS Roll Pits thru Centrifuge. Perform FAM on Tuggem.;PJSM Set slips and hang Blocks. Check Crown sheave wobble as per
EAM. Grease Drawworks grid resistor as per EAM, need Man Lift to complete.;POOH 5" D.P. F/ 5,432'to 274' MD. P/U 115K, Calc. Disp 39, actual 48
bbls.;PJSM Rack back 5" HWDP , Jars and NM Flex Collars. Down load MWD. UD TM & DM. Rack back MWD and Geo Steer. Break out 8.5" Bit and sleeve.
Bit Graded: 3 -5 -BT -T -X -I -WT -PB. GeoPilot Wear Bands and ILS Stabilizer showed wear.;PJSM P/U 4" HT38 test joint TIW, Dart, side entry sub and NC50 X/O.
Drain Stack. Set test plug.;PJSM Test W/ 4" Test Jnt. Annular, Upper and lower Pipe Rams, 500 PSI low and 3,000 PSI high.5 Min on chart.;R/D test Equip.
Had to work test plug out due to debris. Pull test plug. Continued staging up working test plug from lower profile in wellhead. Wellhead reps onsite. Staged up to
to 65-70k overpull before working test plug free.;Load floor with liner running tools.;Hauled 288 bbls Fluid to MP G&I total = 12,164 bbls
Hauled 260 blots H2O from L -Pad Lake total = 12,350 bbls
Total fluid lost on Surface = 174 bola
313012019
Cont R/U Bring tubing Equip to rig floor. C/O Elevators, check slips and Elevator ID. Inspect test plug and found 2 small (1 cm x 1/3 cm) aluminum debris wedged
in dove seal of test ptug.;PJSM, Bring 4.5" WOT handling equip to rig floor. MN 4.5" pre -drilled shoe it. Run 309'4.5" IBT, 12.6#, L-80. (3ea) Tendeka hybrid
swell packers. M/U HES BHKA disconnect sub and xo's. Sub pinned @ 2,500 psi shear to release. (contingency- left hand backoff 2-3/8" ACME). Drift 2.39"
subs.;RIH F/ 309'- T/ 6,270' MD. Single in w/ 4.5" cmt string on 4" HT -38, S-135,14# drill pipe. Drift 3.39". P/U 103K, SLK 74K. Calc Disp 34.4 bbls, Actual
32.3 bbls. Lost 2.1.;Cont to TIH W/ 4" D.P. F/ Pipe Shed F 6,270' to 8,257' MD. At 7,500' MD Pumped a 15 bbl 10.2 ppg Dry Job due to U Tubing. Did not work.
Slow running speed to 40 FUMin. P/U 101K, SLK 65K. Went thru Shoe at 6,474' clean. Wipe thru tight spots as needed. Calc. Disp 10 bbl, actual 10 bbl.;At
8,257' MD set down 15K and attempted to work. P/U 108L, SLK 62K. Kelly up W/ Top Drive staging pumps up to 5 BPM, 635 PSI. Wash down working 25K
down W/ slight packing off at 740 PSI. Had discussion with town about cement options. Was able to work string down to 8,278' MD.;With no losses. P/U 102K,
SLK 66K. Hole geometry shows washing on build section. Decision was made to attempt to keep washing in hole.;Cont. washing 4.5" Liner on 4" D.P. F/ 8,278'
to 8,365 MD 6-6.5 BPM, 635-750 PSI, Setting down 28K, with little over pull. Slight packing off with no losses keeping max pump Press set at 750 PSI. P/U
119K, SLK 68K at 6.5 BPM.;Hauled 287 bbls Fluid to MP G&I total = 12,451 bola
Hauled 130 bbis H2O from L -Pad Lake total= 12,480 bbls
Daily loss to formation = 2.1 bbls
Total fluid loss on production = 2.1 bbls
Total fluid lost on Surface = 174 bbis
3/31/2019
Cont. working down cement liner F/ 8,278'to 9,065' MD. Setting 25-30K down, pumping at 2-7 BPM, 280-800 I. Encountered slight Press. spikes while
working pipe. No losses to formation. PIU 107K, SLK 67K.;Cont. working down cement liner F/ 9,065' [0 9,1 MD. Setting 25_30K down, pumping at 2-7 BPM,
280-800 PSI. Encountered slight Press. spikes while working pipe. No losses to formation. PIU 107K, SLK K. Obtain flow rates and string weights while
working pipe. At 5 BPM 560 PSI, PIU 116K, SLK 58K.;PJSM W/ all parties for cementing. Load BHKA dilileoinnect dart. RA-1 Halliburton Cement Head. Circ. thru
Cement Head at 3 BPM, 425 PSI. Swap over to Halliburton. Pump 5 bbis of H2O, PT 1,159 PSI low, 2, 1 Stall, 4,154 PSI high for 5 Min.;Pump 5 bbls H2O, 35
bbis 10.0 PPG Clean Spacer, 29.5 bbls 15.8 Plu erm Cement dropdart a kick out it 5 bbls - Rig fed Halliburton 9.2 ppg Mud, Halliburton
pumped 88 bbis of 9.2 ppg Mud when plug pumped on time.;Plug sheared disconnect at 2,556 PSI. Seen 25K weight loss on weight indicator. No losses. Check
for flow, static. CIP @ 22:36.;R/D Cement Head. C/O Elevators inserts. POOH F/ Top of plug at 8,845' to 8,656' MD. P/U 125K.;PJSM Install X/O to Top Drive.
/
Drop Wiper Ball, Kelly up rotate and reciprocate F/ 8,656' to 8,596' MD, stage pumps up to 7 BPM, 740 PSI. 30 RPM, TRO 5.8K, P/U 125K, SLK 86K.;Checked
fl ^/
pump rate prior to Liner set at 5 bpm, 560 PSI, after 5 bpm, 477 PSI. Good indication HBKA released from 4.5" Liner. Circ. Surf to Surf. At BU very slight
(Wf
indication of cement interface. Did not retrieve ball on Surf to Surf. Pump Dry Job and blow down Top Drive.;PJSM POOH UD 4" D.P. to Pipe Shed F/ 8,659 to
Q
6,016' MD. PIU 119K, SLK 75K. Calc Dis 14.8 bbis, Actual 14.8 bbls.;Hauled 57 bbls Fluid to MP G&I total= 12,508 bbis
Hauled 130 bbis H2O from L-Pad Lake total= 12,610 bbls
Daily loss to formation = 10 bbis
Total fluid loss on production = 10 bbis
Total fluid lost on Surface= 174 bbis
4/1/2019
Continue POOH laying down 4" HT-38 drill pipe F/ 60116- T/ surface. RIH w/ 3 aids of 4" out of derrick and POOH laying down same. B/O and UD disconnect
running sub. Hole took proper fill.;PJSM Troubleshoot Top Drive dolly extend cylinders. All hydraulics Press normal. Inspect dolly cracks. Grease Crown and
Top Drive.;PJSM Switch elevators to 5" inserts. PIU BHA #4. 8.5" SK616J1 D PDC Bit, 8.5" NRP, Geo Pilot 7600 XL, 6 3/4" ADR/HCIM, 6 3/4" ILS, 6 3/4" DGR,
6 3/4" DM, 6 3/4" TM. 6 3/4" FS, 2 as 6 314" NM FC, 6 3/4" FS, Jar Combo and 3 5" HW DP to 274' MD.;Upload MWD tool. Shallow hole test MWD tools.;PJSM
RIH BHA#4 F/ Derrick F/ 274' to 6,326 MD. Fill pipe every 3,009. Calc Disp 53 bbls, actual 53 bbls.;PJSM Slip and cut drilling line. (57') Inspect Brake
v
tolerance.;PJSM Drain Stack. Pull Bushing and Riser, reinstall Bushing and set slips. UD Raiser. WU rotating head stand and set on RCD. Attempt to Circ, thru
Beyond Equip. Blow down Top Drive and trouble shoot hard lines F/ Stack to Shakers. Found and ice plug in line. Steam and clean Iine.;Pump thru lines at 5
t
BPM, 200 PSI lines cleared.;Cont. RIH W/ 5" D.P. F/ 6,326'to 7,722' MD. Calc Disp 53 bbis, actaul 53 bbls. Wash down F/ 7,722' to 7,785' MD 450 GPM, 1,295
PSI. P/U 172K, SLK 75K, ROT 112K. SPR at 7,785' MD (4,343' TVD) MW 9.3 ppg MP #1 32-255, 48-310 MP #2 32-255, 48-312.;Perform side track operations.
Work 160. 100% deflection F/ 7 800'to 7 845' MD 450 GPM, 1,200 PSI, 120 RPM, TRQ 15-16K, ECD 10.4, P/U 172K, SLK 75K, ROT 112K.;13 concretions
jb
D
have been drilled in the motherbore section fora total of 43' (3.2%) of the lateral. 3 faults have been crossed in this lateral so far (including the 2 in PB2.;Hauled
^
- i
9
229 bbls Fluid to MP G&I total = 12,737 bbls
Hauled 260 bbis H2O from L-Pad Lake total = 12,870 bbis
Daily loss to formation = 0 bbis
Total fluid loss on production = 10 bbis
Total fluid lost on Surface = 174 bbis
4/212019
Drill 8.5" Production hole F/ 7,845'to 8,100' MD. Total 255' (AROP 42.51ph) 450 GPM, 1,380 PSI, 120 RPM, TRQ 18.8K, WOB 18, ECD 10.5 ppg, MW 9.2
ppg. Max Gas 1078U. P/U l98K, SLK 58K, ROT 106K. Shut in MPD on connections, no pressure buildup.;Drill 8.5" Production hole F/ 8,100' to 8,550' MD.
Total 450' (AROP 75fph) 475 GPM, 1,560 PSI, 120 RPM, TRO 18K, WOB 12. ECD 10.7 ppg, MW 9.2 ppg. Max Gas 1361 U. P/U 198K, SLK 61 K, ROT 107K.
Shut in MPD on connections, no pressure buildup.;Drill 8.5" Production hole F/ 8,550'to 9,185' MD. Total 635' (AROP 106fph) 475 GPM, 1,555 PSI, 120 RPM,
TRQ 20K, WOB 1OK. ECD 10.8 ppg, MW 9.2 ppg. Max Gas 1821 U. P/U 220K, SLK 44K, ROT 108K. Shut in MPD on connections, no pressure buildup.;Ddll
8.5" Production hole F/ 9,185'to 9,599' MD. Total 414' (AROP 69fph) 480 GPM, 1,618 PSI, 120 RPM, TRQ 21K, WOB 7K. ECD 10.9 ppg, MW 9.2 ppg. Max
Gas 1345U. P/U 224K, SLK 58K, ROT 107K. Shut in MPD on connections, no pressure buildup.;26 concretions have been drilled in the motherbore section for a
total of 84' (2.7) of the lateral. 2 faults have been crossed in the motherbore. Distance to Well Plan #04:108.7', 56.64'Low, 92.85' Right.;Hauled 455 bbls Fluid to
MP G&I total = 13,192 bbls
Hauled 390 bbis H2O from L-Pad Lake total = 13,260 bbis
Daily loss to formation =105 bbis
Total fluid loss on production = 115 bbis
4/3/2019
Drill 8.5" Production hole F/ 9,599'- T/ 10,140' MD. Total 541' (AROP 90 fph) 480 GPM, 1,650 PSI, 160 RPM, TRQ 16.2K, WOB 3-15K. ECD 11.1 ppg, MW
9.2 ppg. Max Gas 1078U. PIU 152K, S/O 82K, ROT 106K. Shut in MPD on connections, no pressure buildup. Increased lube F/ 1.5% to 2.25%.;Drill 8.5"
Production hole F/ 10,140'- T/10521' MD. Total 381' (AROP 64 fph) 480 GPM, 1,820 PSI, 160 RPM, TRQ 17K, WOB 18K. ECD 11.2 ppg, MW 9.2 ppg. Max
Gas 1180U. P/U 155K, S/O 72K, ROT 103K. Shut in MPD on connections, no pressure buildup.;Drill 8.5" Production hole F/ 10,521'- T/ 10,901' MD. Total 380'
(AROP 63fph) 480 GPM, 1,800 PSI, 130 RPM, TRQ 21 K. WOB 1 OK. ECD 11.2 ppg, MW 9.2 ppg. Max Gas 692U. P/U 162K, S/O 62K, ROT 105K. Shut in
MPD on connections, no pressure buildup.;Drill 8.5" Production hole F/ 10,901'- T/ 11,535' MD. Total 634' (AROP 1061ph ) 480 GPM, 1,800 PSI, 130 RPM,
TRQ 15K, WOB 8K. ECD 11.3 ppg, MW 9.2 ppg. Max Gas 1498U. P/U 152K, S/O 68K, ROT 107K. Observe seepage losses at 10,900 increasing to 20-25bph
coinciding with an increase in pressure;building on connections. Allow well to flow during connection observe flow out consistently decreasing to 12 gpm in 8
minutes, indicating wellbore breathing. Drilling with full open choke MPD system (estimated 80 psi surface friction psi w/ full open choke);35 concretions have
been drilled in the motherbore section for a total of 144' (2.9%) of the lateral.
5 faults have been crossed in the motherbore.
2,286' drilled in NB sand, 402' in NC, 122' in NO
Distance to Well Plan #04: 33.92', 33.91'Low, 0.81' Right.;Hauled 751 bbis Fluid to MP G&I total = 13,394 bbis
Hauled 520 bbls H2O from L-Pad Lake total = 13,780 bbls
Daily loss to formation = 30 bbls
Total fluid loss on production = 145 bbis
Total fluid lost on Surface = 174 bbis
4/4/2019
Drill 8.5" Production hole F/ 11,535' - T/ 11,850' MD. Total 316 (AROP 105fph) 480 GPM, 1,720 PSI, 160 RPM, TRQ 16.5K, WOB 8K. ECD 11.4 ppg, MW 9.2
ppg. Max Gas 1045U. P/U 161 K, S/O 68K, ROT 107K. Reduced MW F/ 9.35 - T/ 9.2 to minimize breathing. Continue running MPD w/ 100% open
choke.;Never Saw projected fault @ 11,500' MD Drilled out of top of zone (rD 11 762' w/ 93° Inc (Formation dip protected a 899 Decision made to pull hark to
11,567' and sidetrack.;Obtain final survey. BROOH F/ 11,850' - T/ 11,567' MD. 560 gpm, 2250 psi, 120 rpm,l5k tq. 433u btms gas from 11,850' MD.;Onent
160R w/ 100% deflection F/ 11,567'- T/ 11,596' MD. Control drill @ 160R, 20-25 fph, 450 gpm, 1,680 psi, 120 rpm, 20.4k tq.;Drill 8.5" Production hole F/
11,596'- T/ 12,050' MD, Total 454' (AROP 76fph) 450 GPM, 1,750 PSI, 150 RPM, TRQ 231, WOB 5-16K, ECD 11.3 ppg, MW 9.2 ppg. Max Gas 1124U. P/U
182K, SIO 39K, ROT 105K.;Drill 8.5" Production hole F/ 12.050'- T/ 12,350' MD. Total 300' (AROP 50fph) 450 GPM, 1,615 PSI, 150 RPM, TRQ 16.8K, WOB
(}
22K. ECD 11.2 ppg, MW 9.2 ppg. Max Gas 1116U. P/U 172K, S/O 62K, ROT 107K.;Drill 8.5" Production hole F/ 12,350'- T/ 12,853' MD. Total 503' (AROP
('
84fph) 450 GPM, 1,700 PSI, 130 RPM, TRQ 18K, WOB 12K. ECD 11.3 ppg, MW 9.25 ppg. Max Gas 1133U. P/U 180K, SIO 50K, ROT 106K.;53 concretions
have been drilled in the motherbore section for a total of 215' (3.4%) of the lateral.
5 faults have been crossed in the motherbore.
3,616' drilled in NB sand, 402' in NC, 122' in ND
Distance to Well Plan #04: 43.7', 43.7'Low, 1.87' Right.;Hauled 288 bbis Fluid to MP GM total =13,682 bbis
Hauled 910 bbls H2O from L-Pad Lake total= 14,690 bbls
Daily losso formation= 162
t/ q
Total Fluid losssonon production = 3roduction =307 bbis
Total Fluid lost on Surface = 174 bbis
4/52019
Drill 8.5" Production hole F/ 12,853'TD 1 ,994' M 14,400' TVD,. Total 141'. 450 GPM, 1,790 PSI, 140 RPM, 20K tq, 12K WOB. ECD 11.3 ppg, MW
9.25 ppg. Max Gas 623U. PIU 190K, SIO 39K, ROT 103K.;Obtain final svy. Circulate and condition @ TD Rot/Recip pipe @ 500 gpm, 2000 psi, 140 rpm, 21 k
tq, 11.5 ECD w/ max gas 622 dropping back to 40u and end of cleanup cycle. Circulate a total of 4 btms up w/ returns clean at shakers. PST pass after
shakers/fall before shakers.;Reduce pump rate to 350 gpm, 1200 psi, 40 rpm, 14.8k tq. Circulate 1 btms up then retest PST (pass). Increased lubes to 4% by
vol. 190k up, 39k do before cleanup cycle and 173k up, 69k on after cleanup cycle.
Obtain SPRs 32148 spm -#1 MP 3721475 psi, #2 MP 370/432 psi w/ 9.2 MW.;PJSM, Monitor well via MPD (Initial Flow showed 1-2 bph flow then static after 30
min). Pull RCD and install Flow nipple. Monitor well (very slight losses).;BROOH F/ 12,994'. T/ 11,630' MO. 500 gpm/1660 psi, 100 rpms/151(ft-Ibs. PUW
190K, SOW 78K, ROTW 55K;Submit AOGCC notification for upcoming BOP test via email @ 16:43 hrs ;Cont. to BROOH F/ 11,630' T/10,141'MD.
500gpm/1475psi, 130 rpms/l4.5Kft-Ibs. Observe slight packoffs and 10-15K overpull as formation transition from silt/clay to sands, adjust pulling speed and
work through.;Cont. to BROOH F/ 10,141' T/8963'MD. 500gpm/1425psi, 130 rpms/14.5Kft-Ibs. PUW 155K, SOW 90K ROTW 110K. Observe slight packoffs
and 10-15K overpull as formation transition from silt/clay to sands, adjust pulling speed and work through. Tight spot from 9061'to 9025' with 20-30K
overpull,;slight increase in torque (1-21(ft-Ibe).;56 concretions have been drilled in the motherbore section for a total of 230'(3.5%) of the lateral.
5 faults have been crossed in the motherbore.
3,766' drilled in NB sand, 402' in NC, 122' in ND
Distance to Well Plan #04: 49.6T, 49.67'Low, 0.56' Right.;Hauled 406 bbls Fluid to MPG&I total= 14,088 bbis
Hauled 520 bbls H2O from L-Pad Lake total = 15,210 bbis
Daily loss to formation = 120 bbis
Total fluid loss on production = 427 bbis
Total fluid lost on Surface = 174 bbls
4/62019
Cont. to BROOH F18,963' TI6898'MD. 500gpm/1245psi, 130 rpms/14.5Kft-Ibs. PUW 143K, SOW 93K, ROTW 107K. Observe slight packoffs and 20K overpull
as formation transition at 8029, adjust pulling speed and work through.;Continue to BROOH from 6898'to 6453'500 gpm/1245 psi, 130 rpms/14Kft-lbs. Shut
down rotary to pull BHA through shoe.;Circulate hole clean, pump tandem sweep (0% increase), 560 gpm/1490psi, 60 rpms/11.51K ftlbs. CBU x2, perform PST-
pass. PUW 139K, SOW 99K.;Service rig: grease crown, TD, Drawworks. Monitor well, static.;Pump dry job, BD top drive. POOH laying down drill pipe from
6453'.;Monitor well, static. UD BHA. Download MWD. Break bit. Bit grade 3-3-BT-A-X-I-WT-TD;Clean and clear rig floor. Pull wear bushing.;Rig up to test
BOPE. M/U test joint with TIW and dart valve. Set test plug. Fill stack and purge air.;Test BOPE's on 5" test joint 250/3000 psi. States right to witness waived
by AOGCC Matt Herrera. Rig down test joint, WU 2-7/8" test joint. No failures on 5" Test joint.;Hauled 697 bbis Fluid to MP G&I total =14,785 bbis
Hauled 520 bbis H2O from L-Pad Lake total = 15,730 bbls
Daily loss to formation = 33 bbis
Total fluid loss on production = 460 bbis
Total fluid lost on Surface = 174 bbis
4/72019
Continue testing BOPS w/ 2-7/8" & 5" test jt. 250/3000 psi w/ 5 min hold on each. Chart and record same. Test gas alarms 10/20 ppm H2S, 20/40% LEL. Test
flow alarms and PVT system (good). AOGCC Matt Herrera waived witness. R/D test equipment and blow down same. Set 9" ID wear bushing.;M/U triple
connect w/ 5"safety joint. PIU and rig up Weatherford casing for running 4.5" and stage 2-3/8" inner string handling equipment to rig floor. Svc choke manifold
and associated equipment for post BOP test.;PJSM, M/U 4.5" WIV assy and run 45'625 Wedge, 13.5#, L-80 lower screen completion as per detail F/ surface -
T/ 520' MD. 9.6k tq. Static loss rate @ 1 bph.;PJSM, M/U 4.5" WIV assy and run 4.5" 625 Wedge, 13.5#, L-80 lower screen completion as per detail F/520 - TI
6,666' MD. 9.6k tq; total 139 screens, 24 blank joints, 2 sweel packers. PUW 114K, SOW 83K. Calculated displacement.;Rig up to RIH with 2-3/8" PHS inner
string. Change out elevators, power tong dies. Install false table.;Pick up slick joint. Pick up, drift (1.77") and RIH with 2-3/8" PHIS inner sting to 6645'; NO-Go
with 7K x 2 on depth. PUW 65K, SOW 50K.;UD 1 joint, pick up 2 pup joints, swivel and space out 7.18' off No-Go (7.57'stung in). WU liner hanger and RIH 1
stand. Obtain parameters: PUW 140K, SOW 102K, ROTW 114K. 1 bpm/400psi, 2bpm/700 psi, 3 bpm/1175 psi; 5 rpms/5.21(ft-Ibs, 10rpms/6000 ft-Ibs, 20
rpms/6.5Kft-Ibs.;RIH with liner with 5" drill pipe from derrick from 6767'to 8606', drift size 2.75", fill every 15 stands.
Continue to RIH with liner from 8606'to 9082' picking up drifting and singling in the hole with HWDP. PUW 157K, SOW82K;Hauled 283 bbis Fluid to MP G&I
total = 15,069 bbis
Hauled 260 bbls H2O from L-Pad Lake total = 15,990 bbis
Daily loss to formation = 7 bbis
Total fluid loss on production = 467 bbis
Total fluid lost on Surface = 174 bbls
Continue single in the hole F/9,802'- T/ 11,080' MD w/ 5" HW DP NC50, 49.5# S-135. Drift w/ 2.75" picking up. Tag 25k @ 10,535' MD. P/U and wipe clean.
Continue running liner. Tag w/ 20k do @ 10850' MD. P/U and attempt to work past w/ 2x tags (60k dn). P/U and wash past 1 bpm, 470 psi.;Continue tripping
without issue. 117k dn, 226k up @ 11,080' MD.;Continue run liner on 5" dp out of derrick F/ 11,080'- T/ 12,994' MD. Drift out of derrick w/ 2.75". Set do 2x w/
10k on depth. Establish circulation staging up to 3 bpm, 1350 psi w/ 25% flow. 102k dn, 240k up. Reciprocate pipe while circulating. Psi set point @ 1450 as
per BOT.;Displace wellbore to 9.2 ppg Brine, pump 30 bbls high vis spacer 500 bbls brine followed by 3 x 40 bbls SAPP pill with 50 bbls brine in between pills.
Circulate closed loop once good brine is seen at surface, continue out SAPP chem train. Loss rate after SAPP pills 10 bph.;Drop 1.25" ball, pump ball on seat
(1458 strokes) and pressure up to 3100 psi, observe hydraulic running tool shear at 2650 psi. Slack off 60K and continue pressuring up to 4200 psi, to neutralize
pusher tool and release from HRDE. Pickup 6to expose dog sub (PUW2COK), slack off 50K.;Pick up to neutral weight. Rotate 20 rpms and set down 50K x2 to
verify packer set. Rig up and test packer 1500 psi for 10 minutes -good. Pick up to 12, 975' and disengage packoff.
Too of Liner at 6300.60'MD:Circulate 2-3/8yx 4.5' annular volume x 2 at 3.3 bpm 1800 psi. Blow down top drive. Monitor well, static.;Pump dry job and POOH
from 12,975'to 9250'. L/D 20joints 5" DP and all HWDP. PUW 112K, SOW 92K;Hauled 1787 bible Fluid to MP G81 total = 16,856 bbls
Hauled 130 bbls H2O from L -Pad Lake total = 16,640 bbls
Daily loss to formation = 22 bbls
Total fluid loss on production = 489 bbls
Total fluid lost on Surface = 174 bbls
Hilcorp Energy Company Composite Report
Well Name: MP E-41
Field: Milne Point
County/State: , Alaska
(LAT/LONG):
oration (RKB):
API #:
Spud Date: 311 312 01 9
Job Name: 1910939C MPE-41 Completion
Contractor
ARE #:
ARE S:
ACR%,.. @A,
; ;.. �. Ops Summary _. .
4/9/2019
POOH with liner setting tool from 9253' to 6704'MD. Rack back 5" DP L/D HWDP. L/D running tool. Inner string pup joints below setting tools bent. Loss
rate 2 ph.,Rig up Weatherford. Change out pipe handling equipment.,Continue to POOH laying down 2-3/8" inner string from 6704' to surface. Lay down
slick stick. Rig down handling equipment. Loss rete 2 bph.,M/U liner washing tool with 8.4" OD no-go. RIH to 6254', PUW 142, SOW 107. Establish
circulation at 3 bpm/65 psi. RIH and no-go on depth at 6325' (TOL 6300') with 3K down x 2, observe 30 psi pressure increase.,Circulale liner top at 6bpm/160
psi, slowly pulling out of liner top to 6285' increasing to 10 bpm/340psi. Circulate 2 x annular volume. Swap to clean 9.2 brine and displace well at 7 bpm/200
psi. Monitor well, static. Pump dry job., POOH laying down drill pipe from 6285' to 4717'. Loss rate 3 bph. PUW 140K, SOW 107K,Continue to POOH laying
down drill pipe from 4717to surface. Loss rate 2 bph.,Slip and cut drilling Iine.,Hauled 959 bbis Fluid to MP G&I total= 17,815 bbis
Hauled 0 bbis H2O from L -Pad Lake total = 16,640 bbls
Daily loss to formation = 74 bbis
Total fluid loss on production = 563 bbis
Total fluid lost on Surface = 174 bbis
4/10/2019
Continue to Slip/Cut Drill line. Check Brake Tolerance. Calibrate Blocks and Elevator Stops. Service Rig: Grease Crown, Blocks, Top Drive and Draw
works.,UD 1 jt 5" DP and 3.5" Eue Stinger with 8.1 No -Go., Pull wear bushing. Drain stack, close bind ram, remove VBR f/ upper BOP, install 7 5/8" ram, open
blind ram, R/U test equipment w/ 7 5/8" test jt, Test upper ram to 250/3000 psi 5 min ea. charted. R/D test equip. close I/A. Monitor well , static lass rate 2
bph.,R/U to run 7 5/8" casing, Setup torque turn equipment. M/U crossover to FOSV. Verify Pipe Count. Check ID & OD on all handling equipment.,Continue
R/U to run casing. P/U Hgr and Landing Jt & make Drift run, hanger landed out @ 24.28' RKB. UD Landing Jt and Csg Hgr. Monitor well on trip tank, 3 bph
loss rate., PJSM with all parties involved. P/U and run 7 518" tie back per tally, P/U tie back seal assy, 8.25" nogo locator, XO and pup, P/U and RIH w/ 7 5/8"
Wedge 521, 29.7# L-80 casing f/ 17' to 6310.2' MD. Calculated displacement 69.7 bbis, actual 18.4 bbls. Lost 51.3 bbls. Torque turn connections to optimum
@ 10,100 ft/lbs. Utilize Dog Collar clamp on every connection., Land on no go with Tag joint # 158, 36.73'in . Set down 1 O verify tag. UD jts. 158, 157. M/U
Space out pup (9.8T) and jt 158 Setting No -Go 1.40' off when landed. M/U Landing joint and Hanger. Land Hanger as per NOS Rep onsite, XO landing jt to
DP. PUW 169K, SOW 117K., Rig up to reverse circulate. Close bag and PT Annulus to 500 psi to ensure proper space out and seal engagement. Bleed
pressure to 300 psi, strip up hole until pressure dumps, exposing seal ports to annulus.,Using the Kill Line, Establish reverse circulation through ported seals
with fluid from rig pits. Line up on and pump 73 bbis Corrosion inhibited 9.2 ppg KCL 4bpm/190 psi, Line up on VAC Truck with DSL and Reverse in 60 bbis
DSL 4bpm/425psi, chase surface lines with 10 bbis Brine. Strip in hole and land out Tie back seals Assy 1.40' off no go w/ Mule Shoe @ 6308.6. (TOL @
6300.6') PU/SO 169k/117k. 82K on hanger.,Drain stack. Rig down circulating equipment. Back out landing joint. Make up pack -off running tool and pack -off.
Set pack -off. RILDS. Test pack -off 500/5000 10 minutes each - good. SimOps: begin processing 2-7/8" tubing.,Rig up test pump. Test 9-5/8" x 7-5/8"
annulus to 1000 psi for 30 minutes - good. Pumped 1 bbl, bled back 1 bbl. Rig down testing equipment.,Monitor well for 30 mins - loss rate 3.5bph. Drain
stack. Shut blinds. Bleed of accumulator. C/O UPR's from 7-5/8" SB to 2-7/8"x5.5" VBR's. Re-energize accumulator.,Pick up 2-7/8" T.I. Set test plug. Rig
up testing equipment. Test UPR's on 2-7/8" test joint 250/3000 psi. Pull test plug. UD test joint.,Hauled 57 bbis Fluid to MP G&I total = 17,872 bbis
Hauled 130 bbis H2O from L -Pad Lake total = 16,770 bbis
Daily loss to formation = 93 bbis
Total fluid loss on production = 656 bbis
Total fluid lost on Surface = 174 bbls
4/11/2019
Rig up Weatherford. Bring Cenlrilift equipment to rig floor. Hand ESP sheave and string Cap line and ESP cable. Change out pipe handling
equipment., PJSM. Pick up ESP pumps motors lower/upper tandem seals and gas seperator. Fill with oil and service. Attach ESP cable to assembly.
Install centralizer and CAP line. MEG test ESP cable- good. Loss rate 6 bph. 4- Motor Clamps, 8 pump clamps, 4 tandem seal clamps.,M/U discharge head,
bolt on discharge head. Install half clamps on pup joint. RIH with ESP assembly to 4935' on 2-7/8" 8rd EUE 6.5# L-80 tubing, installing cannon clamps on
every collar, Meg testing, and testing CAP line every 1000'. Calculated displacement = 11bbls Actual displacement = -39 bbls; 50 bible Iost.,Continue to RIH
with ESP assembly from 491 5797on 2-7/8" 8rd EUE 6.5# L-80 tubing, installing cannon clamps on every collar, Meg testing, and testing CAP line every
1009. Calculated displacement = 1.5 bbis Actual displacement = -12.5 bbis; 14 bbis lost. PUW 83K, SOW 55K. Total 202 cannon clamps, 4 motor clamps,
8 pump clamps, 4 seal clamps.,Make up hanger and landing joint. Terminate capillary line and connect to hanger. Terminate ESP and splice to lower
connector and test - good. Connect to penetrator and test - good. Drain stack and land hanger with ESP centralizer set at 5819.97. PUW 83K, SOW 55K,
20K on hanger. RILDS. Remove landing joint. Set BPV.,Hauled 58 bbis Fluid to MP G&I total = 17,930 bbis
Hauled 100 bbis H2O from L -Pad Lake total = 16,870 bbis
Daily loss to formation = 110 bbls
Total fluid loss on production = 766 bbls
Total fluid lost on Surface = 174 bbis
4/12/2019 PJSM RID BOT ESP Sheave and Equip. R/D Weatherford tools and Equip. Clear Rig Floor of Misc tools and Equip. LID Mouse hole. R/D Spooler unit.,Take
speed head out of cellar and bring in Tree. Remove Riser, R/D MPD choke line, R/D choke and kill lines. Install Gray loc plug for MPD, Pick rotating head off
stack w/blocks, take down drip pan. SIMOPS: Flush FW through stand pipe, choke and kill lines. Blow down all lines. Begin pit cleaning.,Break bolts on stack
and rack back on pedestal. Centrilift check ESP cable - good. Remove DSA, lower rotating head and set down. NIU tree.,Torque tree. Remove BPV, set
TWC. Test hanger void 500/5000 for 10 minutes- good. Test tree 500/5000 - good.,Freeze protect well. LRS PT lines 3000 psi - good. Bullhead 95 bbis
diesel down IA at 2 bpm, took 23 bbis to fill hole FCP 313 psi. Rig up on tubing, PT to 2500 psi. Bullhead 15 bbls diesel at 0.75 bpm ICP 540 psi, FCP 636
psi. SimOps: Change out saver sub.,Change out wash pipe., Disconnect interconnects. Take mud pumps apart and inspect, rotate liners. Pull rotary table,
disconnect drains. Flush oil x 2. Clean mud and debris from under table. Load S' drill pipe in shed. Final Report for E-41,Hauled 114 bbis Fluid to MP G&I
total = 18,044 bbls
Hauled 0 bbis H2O from L -Pad Lake total = 16,870 bbis
Daily loss to formation = 0 bbis
Total fluid loss on production = 766 bbls; 479 bbis drilling mud, 287 bbis 9.2 ppg brine
Hilcorp Alaska, LLC
Milne Point
M Pt E Pad
MPU E-41
500292362200
Sperry Drilling
Definitive Survey Report
08 April, 2019
HALLIBURTON
Sperry Drilling
Company: Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt E Pad
Well:
MPU E41
Wellbore:
MPU E41
Design:
MPU E41
Halliburton
Definitive Survey Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well MPU E-41
MPU E-41 Actual RKB @ 48.68usft
MPU E-41 Actual RKB @ 48.68usft
True
Minimum Curvature
NORTH US+CANADA
Project Milne Point, ACT, MILNE POINT
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Well MPU E41
Well Position +N/ -S
+E/ -W
Position Uncertainty
0.00 usft Northing:
0.00 usft Easting:
0.00 usft Wellhead Elevation:
6,016,034.09 usfl
569,302.90 usfl
0.00 usfl
Latitude:
Longitude:
Ground Level:
70° 2T 14.9809 N
149° 26 4.0913 W
21,80usft
Wellbore
MPU E41
Magnetics
Model Name
Sample Date
Declination
Dip Angle
Field Strength
Map
Map
(I
MD
(I
(nT)
TVD
BGGM2018 4/4/2019
+NIS
16.77
80.97
57,433.93302296
Design
MPU E-41
(usft)
(I
(I
(usft)
(usft)
Audit Notes:
(usft)
(ft)
(ft)
(°1100-)
(ft) Survey Tool Name
26.88
Version:
1.0
Phase:
ACTUAL
Tie On Depth:
11,527.23
Vertical Section:
569,302.90
Depth From (TVD)
+NIS
+E/ -W
Direction
31.78
166.70
(usft)
(usft)
(usft)
6,016,034.42
(I
0.23
0.39 2_MWD+IFR2+MS+Sag(1)
26.88
0.00
0.00
234.53
25.00
Survey Program Date 4/8/2019
From To
(usft) (usft) Survey (Wellbore) Tool Name Description Survey Date
166.70 6,445.25 MPU E-41PB1 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 03/09/2019
6,510.90 7,463.53 MPU E-41 PB1 MWD+IFR2+MS+Sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 03/27/2019
7,468.00 7,777.66 MPU E-41PB2 MWD+IFR2+MS+Sag (3) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 03/27/2019
7,800.00 11,527.23 MPU E-41PB3 MWD+IFR2+MS+Sag (4) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 03/27/2019
11,567.00 12,924.78 MPU E41 MWD+IFR2+MS+Sag (5) (MF 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 04/04/2019
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+NIS
+EI -W
Northing
Easting
DLS
Section
(usft)
(I
(I
(usft)
(usft)
(usft)
(usft)
(ft)
(ft)
(°1100-)
(ft) Survey Tool Name
26.88
0.00
0.00
26.88
-21.80
0.00
0.00
6,016,034.09
569,302.90
0.00
0.00 UNDEFINED
166.70
0.32
31.78
166.70
118.02
0.33
0.21
6,016,034.42
569,303.10
0.23
0.39 2_MWD+IFR2+MS+Sag(1)
234.53
0.70
25.93
234.53
185.85
0.87
0.49
6,016,034+96
569,303.38
0.56
0.99 2_MWD+IFR2+MS+Sag(1)
298.36
0.23
352.54
298.35
249.67
1.34
0.64
6,016,035.44
569,303.53
0.82
1.49 2_MWD+IFR2+MS+Sag(1)
360.02
1.96
234.46
360.00
311.32
0.85
-0.23
6,016,034.94
569,302.66
3.37
0.67 2_MWD+IFR2+MS+Sag(1)
422.85
3.44
229.11
422.76
374.08
-1.01
-2.53
6,016,033.06
569,300.38
2.39
-1.98 2_MWD+IFR2+MS+Sag(1)
483.92
5.23
217.83
483.66
434.98
-4.40
-5.63
6,016,029.63
569,297.32
3.23
-6.37 2_MWD+IFR2+MS+Sag(1)
545.26
6.80
210.08
544.66
495.98
-9.75
-9.16
6,016,024.25
569,293.83
2.88
-12.71 2_MWD+IFR2+MS+Sag(1)
607.29
8.36
201.84
606.14
557.46
-17.12
-12.68
6,016,016.86
569,290.38
3.06
-20.87 2_MWD+IFR2+MS+Sag(1)
670.20
10.22
192.00
668.23
619.55
-26.82
-15.54
6,016,007.12
569,287.61
3.88
-30.88 2_MWD+IFR2+MS+Sag(1)
4/82019 12:31:11PM
Page 2
COMPASS 5000.15 Build 91
Halliburton
Definitive Survey Report
Company:
Hilcorp Alaska, LLC
Local Co-ordinate Reference: Well MPU E-41
Project:
Milne Point
TVD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Site:
M Pt
E Pad
MD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Well:
MPU
E-41
North Reference:
True
Wellbore:
MPU
E-41
Survey Calculation
Method: Minimum
Curvature
Design:
MPU E41
Database:
NORTH US+CANADA
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N15
+EI -W
Northing
Easting
OLS
Section
(usft)
(')
(`)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft) (°1100')
(ft) Survey Tool Name
733.85
12.70
186.32
730.61
681.93
-39.30
-17.49
6,015,994.63
569,285.78
4.28
-43.01 2_MWD+IFR2+MS+Sag(1)
798.32
15.83
184.91
793.08
744.40
-55.11
-19.02
6,015,978.81
569,284.40
4.88
-57.99 2_MWD+IFR2+MS+Sag (1)
862.23
18.05
183.01
854.22
805.54
-73.69
-20.29
6,015,960.22
569,283.30
3.58
-75.36 2_MWD+IFR2+MS+Sag (1)
924.89
20.79
181.09
913.31
864.63
-94.50
-21.01
6,015,939.40
569,282.78
4,49
-94.53 2_MWD+IFR2+MS+Sag(1)
988.39
22.56
180.83
972.31
923.63
-117.95
-21.40
6,015,915.95
569,282.60
2.79
-115.95 2_MWD+IFR2+MS+Sag(1)
1,052.41
24.87
179.28
1,030.93
982.25
-143.70
-21.41
6,015,890.21
569,282.83
3.74
-139.28 2_MWD+IFR2+MS+Sag(1)
1,115.85
26.38
177.80
1,088.12
1,039.44
-171.12
-20.70
6,015,862.80
569,283.80
2.59
-163.84 2_MWD+IFR2+MS+Sag(1)
1,179.10
29.56
178.04
1,143.98
1,095.30
-200.76
-19.62
6,015,833.17
569,285.15
5.03
-190.25 2_MWD+IFR2+MS+Sag(1)
1,242.71
33.19
177.81
1,198.28
1,149.60
-233.85
-18.42
6,015,800.10
569,286.66
5.71
-219.73 2_MWD+IFR2+MS+Sag(1)
1,306.00
35.45
177.56
1,250.55
1,201.87
-269.51
-16.98
6,015,764.46
569,288.43
3.58
-251.43 2_MWD+IFR2+MS+Sag(1)
1,370,26
38.48
177.12
1,301.89
1,253.21
-308.10
-15.18
6,015,725.89
569,290.59
4.73
-285.65 2_MWD+IFR2+MS+Sag(1)
1,433.92
40.80
177.33
1,350.90
1,302.22
-348.66
-13.22
6,015,685.35
569,292.93
3.65
-321.58 2_MWD+IFR2+MS+Sag(1)
1,497.48
43.88
177.47
1,397.88
1,349,20
-391.42
-11.28
6,015,642.62
569,295.27
4.85
-359.52 2_MWD+IFR2+MS+Sag(1)
1,561.06
45.95
176.66
1,442.90
1,394.22
-436.25
-8.97
6,015,597.81
569,297.99
3,38
-399.17 2_MWD+IFR2+MS+Sag(1)
1,625.11
47.40
175.06
1,486.85
1,438.17
-482,72
-5.60
6,015,551.38
569,301.79
2.90
-439.87 2_MWD+IFR2+MS+Sag(1)
1,687.73
47.03
175.14
1,529.38
1,480,70
-528.51
-1.67
6,015,505.64
569,306.14
0.60
479.71 2_MWD+IFR2+MS+Sag(1)
1,753.03
46.93
175.71
1,573.94
1,525,26
576.10
2.13
6,015,458.09
569,310.39
0.66
-521,23 2_MWD+IFR2+MS+Sag(1)
1,816.92
46.73
175.79
1,617.65
1,568.97
-622,57
5.59
6,015,411,66
569,314.28
0.33
-561.88 2_MWD+IFR2+MS+Sag(1)
1,880.18
46.54
174.52
1,661.08
1,612.40
-668.39
9.47
6,015,365.88
569,318.59
1.49
-601.77 2_MWD+IFR2+MS+Sag(1)
1,943.18
45.72
174.45
1,704.74
1,656.06
-713.60
13.84
6,015,320.72
569,323.37
1.30
-640.90 2_MWD+IFR2+MS+Sag(1)
2,006.18
43,01
174.62
1,749,78
1,701.10
-757.44
18.03
6,015,276.92
569,327.97
4.31
-678.87 2_MWD+IFR2+MS+Sag(1)
2,070.06
43.96
175.04
1,796,13
1,747.45
-801,23
21.99
6,015,233.18
569,332.34
1.55
-716.87 2_MWD+IFR2+MS+Sag(1)
2,133.72
46.01
175.96
1,841.15
1,792.47
-846.09
25.52
6,015,188.36
569,336.28
3.38
-756.04 2_MWD+IFR2+MS+Sag(1)
2,196.96
45.11
175.87
1,885.43
1,836.75
-891.12
28.73
6,015,143.36
569,339.92
1.43
-795.50 2_MWD+IFR2+MS+Sag(1)
2,261.51
46.43
176.30
1,930.45
1,881.77
-937.27
31.89
6,015,097,25
569,343.50
2.10
-835.99 2_MWD+IFR2+MS+Sag (1)
2,325.05
46.31
176.52
1,974.30
1,925.62
-983.17
34.77
6,015,051.38
569,346.81
0.31
-876.37 2_MWD+IFR2+MS+Sag(1)
2,388.34
47.36
174.20
2,017.60
1,968.92
-1,029.17
38.51
6,015,005.42
569,350.98
3.15
-916.48 2_MWD+IFR2+MS+Sag(1)
2,451.96
46.33
174.15
2,061.11
2,012.43
-1,075.34
43,22
6,014,959.30
569,356.12
1.62
-956.34 2_MWD+IFR2+MS+Sag(1)
2,515.25
44.45
172.31
2,105.56
2,056.88
-1,120.08
48.52
6,014,914,61
569,361.83
3.62
-994.65 2 MWD+IFR2+MS+Sag(1)
2,578.72
43.20
169.58
2,151.35
2,102.67
-1,163.48
55.42
6,014,871.29
569,369.14
3.57
-1,031.06 2_MWD+IFR2+MS+Sag(1)
2,642.11
41.94
167.86
2,198.04
2,149.36
-1,205.53
63.80
6,014,829.32
569,377.91
2.71
-1,065.63 2_MWD+IFR2+MS+Sag(1)
2,705.53
40.44
165.32
2,245.76
2,19708
-1,246,15
73.47
6,014,788.80
569,387.95
3.54
-1,098.36 2_MWD+IFR2+MS+Sag(1)
2,768.83
38.55
163.15
2,294,61
2,245.93
-1,284.89
84.39
6,014,750.16
569,399.23
3.70
-1,128.86 2_MWD+IFR2+MS+Sag (1)
2,832.16
36.68
161.29
2,344.78
2,296.10
-1,321.70
96.18
6,014,713.47
569,411.36
3.45
-1,157.23 2_MWD+IFR2+MS+Sag (1)
2,895.77
34.51
159.39
2,396.50
2,347.82
-1,356.56
108.62
6,014,678.72
569,424.12
3.83
-1,183.58 2_MWD+IFR2+MS+Sag(1)
2,958.70
32.34
158.06
2,449.02
2,400.34
-1,388,87
121.19
6,014,646.54
569,436,99
3.64
-1,207.54 2_MWD+IFR2+MS+Sag(1)
3,022,80
30.60
153,80
2,503.70
2,455.02
-1,419.41
134.80
6,014,616.12
569,450.88
4.40
-1,229.48 2_MWD+IFR2+MS+Sag(1)
3,086.00
28.89
150.99
2,558.57
2,509.89
-1,447.20
149.31
6,014,588.48
569,465.65
3.49
-1,248.53 2_MWD+IFR2+MS+Sag(1)
3,149.26
28.06
145.14
2,614.19
2,565.51
-1,472.78
165.23
6,014,563.05
569,481.80
4.60
-1,264.99 2_MWD+IFR2+MS+Sag(1)
3,212.29
27.12
140.81
2,670.05
2,621.37
-1,496.08
182.78
6,014,539.91
569,499.57
3.51
-1,278.69 2_MWD+IFR2+MS+Sag(1)
4/82019 12:31:11 PM
Page
3
COMPASS 5000.15 Build 91
Halliburton
I
Definitive
Survey Report
Company:
Hilcorp Alaska, LLC
Local Coordinate Reference: Well
MPU E-41
Project:
Milne Point
TVD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Site:
M Pt E Pad
MD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Well:
MPU E-41
North Reference:
True
Wellbore:
MPU
E-41
Survey Calculation Method: Minimum
Curvature
Design:
MPU
E-41
Database:
NORTH US+CANADA
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+NIS
+E/ -W
Northing
Easting
DLS
Section
(usft)
(1)
(')
(usft)
(usft)
(usft)
(usft)
(ft)
(ft) (-Jtoo-)
(ft) Survey Tool Name
3,275.87
26.37
134.84
2,726.84
2,678.16
-1,517.28
201.95
6,014,518.90
569,518.94
4.39
-1,289.79 2_MWD+IFR2+MS+Sag(1)
3,339.66
25.86
127.75
2,784.13
2,735.45
-1,535.79
223.00
6,014,500.59
569,540.16
4.95
-1,297.67 2_MWD+IFR2+MS+Sag (1)
3,402.70
25.49
121.18
2,840.96
2,792.28
-1,551.23
245.48
6,014,485.36
569,562.78
4.55
-1,302.17 2_MWD+IFR2+MS+Sag (1)
3,466.50
24.90
114.67
2,898.70
2,850.02
-1,563.95
269.44
6,014,472.87
569,586.85
4.44
-1,303.57 2_MWD+IFR2+MS+Sag (1)
3,530.63
24.24
108.29
2,957.04
2,908.36
-1,573.71
294.21
6,014,463.33
569,611.71
4.26
-1,301.95 2_MWD+IFR2+MS+Sag(1)
3,594.08
23.52
101.73
3,015.06
2,966.38
-1,580.38
318.98
6,014,456.90
569,636.53
4.33
-1,297.53 2_MWD+IFR2+MS+Sag(1)
3,657.89
23.33
94.76
3,073.63
3,024.95
-1,584.01
344.04
6,014,453.49
569,661.63
4.35
-1,290.23 2_MWD+IFR2+MS+Sag (1)
3,721.90
22.45
89.43
3,132.60
3,083.92
-1,584.94
368.90
6,014,452.80
569,686.49
3.52
-1,280.57 2_MWD+IFR2+MS+Sag (1)
3,785.60
22.53
84.07
3,191.46
3,142.78
-1,583.56
393,20
6,014,454.40
569,710.78
3.22
-1,269.05 2_MWD+IFR2+MS+Sag (1)
3,849.10
24.60
79.54
3,249.67
3,200.99
-1,579.91
418.30
6,014,458.29
569,735.84
4.33
-1,255.13 2_MWD+IFR2+MS+Sag(1)
3,912.81
26.73
76.56
3,307.09
3,258.41
-1,574.17
445.28
6,014,464.28
569,762.76
3.91
-1,238.52 2_MWD+IFR2+MS+Sag(1)
3,977.03
28.88
72.24
3,363.90
3,315.22
-1,566.08
474.11
6,014,472.64
569,791.51
4.59
-1,219.01 2_MWD+IFR2+MS+Sag(1)
4,040.71
30.71
68.76
3,419.16
3,370.48
-1,555.49
503.91
6,014,483.50
569,821.21
3.95
-1,196.82 2_MWD+IFR2+MS+Sag(1)
4,103.85
33.11
65.28
3,472.76
3,424.08
-1,542.44
534.61
6,014,496.84
569,851.78
4.79
-1,172.02 2_MWD+IFR2+MS+Sag (1)
4,166.87
35.40
61.22
3,524.86
3,476.18
-1,526.45
566.25
6,014,513.12
569,883.27
5.13
-1,144.15 2_MWD+IFR2+MS+Sag (1)
4,230.97
37.00
55.28
3,576.60
3,527.92
-1,506.52
598.39
6,014,533.35
569,915.22
6.01
-1,112.51 2_MWD+IFR2+MS+Sag(1)
4,294.42
39.64
50.52
3,626.38
3,577.70
-1,482.76
629.72
6,014,557.39
569,946.32
6.24
-1,077.74 2_MWD+IFR2+MS+Sag (1)
4,358.31
40.49
49.48
3,675.28
3,626.60
-1,456.33
661.22
6,014,584.11
569,977.57
1.69
-1,040.47 2_MWD+IFR2+MS+Sag(1)
4,421.50
41.97
49.05
3,722.80
3,674.12
-1,429.15
692.77
6,014,611.58
570,008.87
2.38
-1,002,51 2_MWD+IFR2+MS+Sag(1)
4,484.19
44.43
47.54
3,768.50
3,719.82
-1,400.59
724.80
6,014,640.43
570,040.63
4.26
-963.09 2 MWD+IFR2+MS+Sag(1)
4,548.16
46.38
46.03
3,813.41
3,764.73
-1,369.40
757.99
6,014,671.93
570,073.52
3.48
-920.79 2_MWD+IFR2+MS+Sag (1)
4,610.88
47.71
42.55
3,856.16
3,807.48
-1,336.54
790.02
6,014,705.08
570,105.24
4.58
-877.47 2_MWD+IFR2+MS+Sag (1)
4,675.06
49.98
41.77
3,898.39
3,849.71
-1,300.72
822.45
6,014,741.20
570,137.33
3.65
-831.30 2_MWD+IFR2+MS+Sag (1)
4,738.87
52.14
39.64
3,938.49
3,889.81
-1,263.09
854.80
6,014,779.12
570,169.33
4.27
-783.53 2_MWD+IFR2+MS+Sag (1)
4,801.16
53.56
38.80
3,976.11
3,927.43
-1,224.63
886.19
6,014,817.87
570,200.36
2.52
-735.40 2_MWD+IFR2+MS+Sag (1)
4,866.10
55.24
36.77
4,013.92
3,965.24
-1,182.89
918.53
6,014,859.90
570,232.30
3.63
-683.91 2_MWD+IFR2+MS+Sag (1)
4,929.55
58.12
36.15
4,048.77
4,000.09
-1,140.25
950.03
6,014,902.83
570,263.40
4.61
-631.96 2_MWD+IFR2+MS+Sag (1)
4,993.55
61.72
34.84
4,080.84
4,032.16
-1,095.17
982.17
6,014,948.21
570,295.12
5.90
-577.51 2_MWD+IFR2+MS+Sag (1)
5,057.07
64.09
33.55
4,109.77
4,061.09
-1,048.40
1,013.94
6,014,995.27
570,326.45
4.15
-521.69 2_MWD+IFR2+MS+Sag(1)
5,121.65
66.94
31.38
4,136.54
4,087.86
-998.81
1,045.47
6,015,045.14
570,357.52
5.37
363.43 2_MWD+IFR2+MS+Sag(1)
5,184.60
70.11
29.08
4,159.58
4,110.90
-948.20
1,074.95
6,015,096.02
570,386.52
6.08
405.10 2_MWD+IFR2+MS+Sag(1)
5,248.92
71.09
26.38
4,180.95
4,132.27
-894.51
1,103.17
6,015,149.97
570,414.24
4.24
-344.51 2_MWD+IFR2+MS+Sag(1)
5,312.82
72.56
24.27
4,200.88
4,152.20
-839.63
1,129.13
6,015,205.08
570,439.69
3.89
-283.81 2_MWD+IFR2+MS+Sag(1)
5,377.20
75.37
22.37
4,218.66
4,169.98
-782.82
1,153.62
6,015,262.11
570,463.64
5.21
-221.97 2_MWD+IFR2+MS+Sag(1)
5,440.05
78.95
22.08
4,232.63
4,183.95
-726.10
1,176.79
6,015,319.04
570,486.28
5.71
-160.77 2_MWD+IFR2+MS+Sag(1)
5,504.06
80.89
21.74
4,243.83
4,195.15
-667.63
1,200.31
6,015,377.71
570,509.25
3.08
-97.85 2_MWD+IFR2+MS+Sag(1)
5,567.21
81.76
21.47
4,253.36
4,204.68
-609.59
1,223.29
6,015,435.96
570,531.69
1.44
-35.53 2_MWD+IFR2+MS+Sag(1)
5,630.75
81.78
21.51
4,262.45
4,213.77
-551.08
1,246.33
6,015,494.68
570,554.18
0.07
27.24 2_MWD+IFR2+MS+Sag(1)
5,694.14
83.55
20.99
4,270.55
4,221.87
392.48
1,269.12
6,015,553.48
570,576.42
2.91
89.97 2 MWD+IFR2+MS+Sag(1)
5,756.66
83.02
21.76
4,277.86
4,229.18
334.66
1,291.75
6,015,611.50
570,598.51
1.49
151.94 2_MWD+IFR2+MS+Sag(1)
482019 12:31:11 PM
Page 4
COMPASS 5000.15 Build 91
Halliburton
Definitive
Survey Report
Company:
Hilcorp Alaska, LLC
Local Coordinate Reference: Well
MPU E-41
Project:
Milne Point
TVD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Site:
M Pt
E Pad
MD Reference:
MPU E-41 Actual RKB @ 48.68usft
Well:
MPU
E-41
North Reference:
True
Wellbore:
MPU
E41
Survey Calculation Method: Minimum
Curvature
Design:
MPU
E-41
Database:
NORTH US+CANADA
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+NIS
+El -W
Northing
Easting
DLS
Section
(usft)
(°)
(`)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft) ('1100')
(ft) Survey Tool Name
5,820.97
83.25
21.40
4,285.54
4,236.86
-375.29
1,31523
6,015671.08
570,62144
0.66
215.68 2_MWD+IFR2+MS+Sag(1)
5,884.39
80.69
22.04
4,294.40
4,245.72
-316.96
1,338.47
6,015,729.63
570,644.13
4.16
278.37 2_MWD+IFR2+MS+Sag (1)
5,947.90
79.61
22.63
4,305.27
4,256.59
-259.08
1,362.24
6,015,787.72
570,667.37
1.93
340.87 2_MWD+IFR2+MS+Sag(1)
6,011.22
81.05
22.81
4,315.90
4,267.22
-201.50
1,386.35
6,015,845.51
570,690.94
2.29
403.24 2_MWD+IFR2+MS+Sag(1)
6,074.43
82.39
23.14
4,325.00
4,276.32
-143.91
1,410.77
6,015,903.32
570,714.81
2.18
465.75 2_MWD+IFR2+MS+Sag(1)
6,138.46
82.22
22.76
4,333.58
4,204.90
-85.48
1,435.51
6,015,961.97
570,739.01
0.65
529.16 2_MWD+IFR2+MS+Sag(1)
6,202.49
81.97
22.69
4,342.38
4,293.70
-26.99
1,460.01
6,016,020.69
570,762.96
0.41
592.53 2_MWD+IFR2+MS+Sag(1)
6,265.42
83.63
21.33
4,350.27
4,301.59
30.90
1,483.41
6,016,078.78
570,785.81
3.40
654.88 2_MWD+IFR2+MS+Sag(1)
6,328.74
84.02
19.26
4,357.08
4,308.40
89.94
1,505.24
6,016,138.01
570,807.10
3.31
717.62 2_MWD+IFR2+MS+Sag(1)
6,392.15
87.14
20.35
4,361.97
4,313.29
149.41
1,526.66
6,016,197.68
570,827.96
5.21
780.57 2_MWD+IFR2+MS+Sag(1)
6,445.25
91.49
21.03
4,362.60
4,313.92
199.07
1,545.41
6,016,247.51
570,846.25
8.29
833.50 2_MWD+IFR2+MS+Sag(1)
6,510.90
93.54
20.93
4,359.72
4,311.04
260.30
1,568.89
6,016,308.95
570,869.16
3.13
898.92 2_MWD+IFR2+MS+Sag (2)
6,575.22
93.34
21.55
4,355.86
4,307.18
320.15
1,592.15
6,016,369.00
570,891.86
1.01
962.99 2_MWD+IFR2+MS+Sag (2)
6,638.60
92.53
21.60
4,352.62
4,303.94
379.01
1,615.43
6,016,428.07
570,914.58
1.28
1,026.17 2_MWD+IFR2+MS+Sag (2)
6,702.90
91.79
21.10
4,350.20
4,301.52
438.85
1,638.82
6,016,488.12
570,937.41
1.39
1,090.30 2_MWD+IFR2+MS+Sag (2)
6,766.55
91.98
20.66
4,348.10
4,299.42
498.29
1,661.50
6,016,547.77
570,959.53
0.75
1,153.75 2_MWD+IFR2+MS+Sag (2)
6,829.16
91.98
20.81
4,345.94
4,297.26
556.81
1,683.65
6,016,606.48
570,981.14
0.24
1,216.15 2 MWD+IFR2+MS+Sag (2)
6,892.72
91.36
20.86
4,344.09
4,295.41
616.19
1,706.25
6,016,666.06
571,003.18
0.98
1,279.51 2_MWD+IFR2+MS+Sag (2)
6,956.48
90.06
20.22
4,343.30
4,294.62
675.89
1,728.61
6,016,725.96
571,024.99
2.27
1,343.07 2_MWD+IFR2+MS+Sag (2)
7,019.74
90.19
20.08
4,343.16
4,294.48
735.28
1,750.41
6,016,785.55
571,046.23
0.30
1,406.11 2_MWD+IFR2+MS+Sag (2)
7,083.36
89.32
19.65
4,343.43
4,294.75
795.11
1,772.02
6,016,845.57
571,067.28
1.53
1,469.47 2_MWD+IFR2+MS+Sag(2)
7,146.87
89.08
21.15
4,344.32
4,295.64
854.63
1,794.16
6,016,905.29
571,088.86
2.39
1,532.77 2_MWD+IFR2+MS+Sag(2)
7,210.62
89.45
22.29
4,345.14
4,296.46
913.85
1,817.75
6,016,964.72
571,111.90
1.88
1,596.41 2_MWD+IFR2+MS+Sag(2)
7,273.37
89.20
22.23
4,345.87
4,297.19
971.92
1,841.52
6,017,023.00
571,135.12
0.41
1,659.00 2 MWD+IFR2+MS+Sag(2)
7,337.00
90.19
22.27
4,346.21
4,297.53
1,030.81
1,865.61
6,017,082.11
571,158.67
1.56
1,722.64 2_MWD+IFR2+MS+Sag(2)
7,399.99
90.87
22.75
4,345.63
4,296.95
1,089.00
1,889.72
6,017,140.51
571,182.24
1.32
1,785.56 2_MWD+IFR2+MS+Sag(2)
7,463.53
91.80
22.17
4,344.15
4,295.47
1,147.70
1,913.99
6,017,199.43
571,205.95
1.72
1,849.02 2_MWD+IFR2+MS+Sag(2)
7,468.00
91.55
21.62
4,344.02
4,295.34
1,151.84
1,915.66
6,017,203.59
571,207.58
13.51
1,853.48 2_MWD+IFR2+MS+Sag(3)
7,523.45
89.81
22.77
4,343.36
4,294.68
1,203.18
1,936.60
6,017,255.12
571,228.05
3.76
1,908.86 2_MWD+IFR2+MS+Sag(3)
7,586.59
88.77
22.70
4,344.14
4,295.46
1,261.41
1,961.00
6,017,313.56
571,251.90
1.65
1,971.95 2_MWD+IFR2+MS+Sag(3)
7,650.03
89.26
22.15
4,345.23
4,296.55
1,320.04
1,985.20
6,017,372.41
571,275.55
1.16
2,035.31 2_MWD+IFR2+MS+Sag(3)
7,713.40
90.62
23.31
4,345.30
4,296.62
1,378.49
2,009.68
6,017,431.08
571,299.49
2.82
2,098.63 2_MWD+IFR2+MS+Sag(3)
7,777.66
91.92
23.82
4,343.88
4,295.20
1,437.37
2,035.37
6,017,490.20
571,324.62
2.17
2,162.85 2_MWD+IFR2+MS+Sag (3)
7,800.00
92.23
22.96
4,343.07
4,294.39
1,457.86
2,044.23
6,017,510.77
571,333.29
4.09
2,185.17 2_MWD+IFR2+MS+Sag(4)
7,839.95
90.80
23.81
4,342.01
4,293.33
1,494.52
2,060.08
6,017,547.56
571,348.80
4.16
2,225.09 2 MWD+IFR2+MS+Sag(4)
7,904.09
91.80
24.48
4,340.56
4,291.88
1,553.03
2,086.31
6,017,606.31
571,374.48
1.88
2,289.20 2_MWD+IFR2+MS+Sag (4)
7,968.25
91.86
24.95
4,338.51
4,289.83
1,611.29
2,113.13
6,017,664.81
571,400.75
0.74
2,353.34 2_MWD+IFR2+MS+Sag (4)
8,031.98
90.93
24.91
4,336.96
4,288.28
1,669.06
2,139.98
6,017,722.82
571,427.06
1.46
2,417.04 2_MWD+IFR2+MS+Sag(4)
8,096.01
89.38
24.90
4,336.78
4,288.10
1,727.13
2,166.94
6,017,781.14
571,453.48
2.42
2,481.07 2_MWD+IFR2+MS+Sag(4)
8,159.16
89.57
25.43
4,337.36
4,288.68
1,784.28
2,193.79
6,017,838.53
571,479.79
0.89
2,544.21 2_MWD+IFR2+MS+Sag(4)
4182019 12:31: 11PM
Page 5
COMPASS 5000.15 Build 91
Halliburton
Definitive
Survey Report
Company:
Hilcorp Alaska, LLC
Local Coordinate Reference: Well
MPU E41
Project:
Milne Point
TVD Reference:
MPU
E41 Actual RKB @ 48.68usft
Site:
M Pt
E Pad
MD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Well:
MPU
E-41
North Reference:
True
Wellbore:
MPU
E-41
Survey Calculation Method:
Minimum
Curvature
Design:
MPU
E-41
Database:
NORTH US+CANADA
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+Nl-S
+E/-W
Northing
Easting
DLS
Section
(usft)
(°)
(1)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft) ('1100')
(ft) Survey Tool Name
8,223.00
88.70
24.35
4,338.32
4,289.64
1,842.19
2,220.66
6,017,896.68
571,506.12
2.17
2,60805 2_MWD+IFR2+MS+Sag(4)
8,286.11
89.26
24.02
4,339.45
4,290.77
1,899.75
2,246.51
6,017,954.47
571,531.43
1.03
2,671.14 2_MWD+IFR2+MS+Sag (4)
8,350.28
89.39
23.44
4,340.20
4,291.52
1,958.49
2,272.33
6,018,013.44
571,556.70
0.93
2,735.29 2_MWD+IFR2+MS+Sag(4)
8,414.20
89.63
22.98
4,340.75
4,292.07
2,017.23
2,297.52
6,018,072.41
571,581.34
0.81
2,799.17 2 MWD+IFR2+MS+Sag(4)
8,478.27
90.69
22.35
4,340.57
4,291.89
2,076.35
2,322.21
6,018,131.76
571,605.48
1.92
2,863.19 2 MWD+IFR2+MS+Sag (4)
8,541.96
90.19
22.08
4,340.08
4,291.40
2,135.31
2,346.29
6,018,190.93
571,629.00
0.89
2,926.80 2_MWD+IFR2+MS+Sag(4)
8,605.25
89.07
21.17
4,340.49
4,291.81
2,194.15
2,369.61
6,018,249.97
571,651.78
2.28
2,989.98 2_MWD+IFR2+MS+Sag(4)
8,669.13
88.33
20.84
4,341.94
4,293.26
2,253.77
2,392.50
6,018,309.80
571,674.11
1.27
3,053.69 2_MWD+IFR2+MS+Sag(4)
8,732.55
89.39
20.57
4,343.20
4,294.52
2,313.08
2,414.92
6,018,369.31
571,695.97
1.72
3,116.92 2_MWD+IFR2+MS+Sag (4)
8,795.85
89.08
21.75
4,344.05
4,295.37
2,372.10
2,437.77
6,018,428.54
571,718.27
1.93
3,180.07 2 MWD+IFR2+MS+Sag (4)
8,859.92
88.64
23.30
4,345.32
4,296.64
2,431.27
2,462.30
6,018,487.93
571,742.25
2.51
3,244.06 2_MWD+IFR2+MS+Sag (4)
8,921.29
87.65
23.45
4,347.31
4,298.63
2,487.57
2,486.64
6,018,544.45
571,766.06
1.63
3,305.38 2_MWD+IFR2+MS+Sag (4)
8,984.92
89.21
25.25
4,349.05
4,300.37
2,545.52
2,512.86
6,018,602.63
571,791.74
3.74
3,368.97 2_MWD+IFR2+MS+Sag (4)
9,048.33
89.14
23.60
4,349.97
4,301.29
2,603.25
2,539.08
6,018,660.59
571,817.42
2.60
3,432.37 2_MWD+IFR2+MS+Sag(4)
9,113.08
89.14
23.21
4,350.94
4,302.26
2,662.66
2,564.80
6,018,720.24
571,842.58
0.60
3,497.09 2_MWD+IFR2+MS+Sag(4)
9,177.01
88.65
22.14
4,352.17
4,303.49
2,721.64
2,589.44
6,018,779.44
571,866.67
1.64
3,560.95 2_MWD+IFR2+MS+Sag(4)
9,240.71
87.03
21.32
4,354.57
4,305.89
2,780.77
2,613.00
6,018,838.78
571,889.68
2.85
3,624.50 2_MWD+IFR2+MS+Sag(4)
9,304.54
85.98
19.05
4,358.46
4,309.78
2,840.56
2,634.99
6,018,898.77
571,911.10
3.91
3,687.98 2_MWD+IFR2+MS+Sag(4)
9,368.35
86.30
17.12
4,362.76
4,314.08
2,901.08
2,654.75
6,018,959.46
571,930.30
3.06
3,751.18 2_MWD+IFR2+MS+Sag(4)
9,432.48
86.98
14.93
4,366.52
4,317.84
2,962.60
2,672.42
6,019,021.14
571,947.40
3.57
3,814.41 2_MWD+IFR2+MS+Sag(4)
9,495.88
86.54
12.32
4,370.10
4,321.42
3,024.12
2,687.33
6,019,082.78
571,961.73
4.17
3,876.46 2_MWD+IFR2+MS+Sag (4)
9,558.26
86.05
11.52
4,374.13
4,325.45
3,085.02
2,700.19
6,019,143.80
571,974.02
1.50
3,937.10 2_MWD+IFR2+MS+Sag (4)
9,622.00
85.80
9.14
4,378.66
4,329.98
3,147.57
2,711.59
6,019,206.44
571,984.84
3.75
3,998.60 2_MWD+IFR2+MS+Sag(4)
9,686.01
86.05
6.83
4,383.21
4,334.53
3,210.79
2,720.46
6,019,269.74
571,993.12
3.62
4,059.65 2_MWD+IFR2+MS+Sag(4)
9,750.48
85.99
3.35
4,387.69
4,339.01
3,274.84
2,726.16
6,019,333.84
571,998.23
5.39
4,120.11 2_MWD+IFR2+MS+Sag(4)
9,813.94
85.67
1.32
4,392.30
4,343.62
3,338.08
2,728.74
6,019,397.09
572,000.22
3.23
4,178.51 2_MWD+IFR2+MS+Sag(4)
9,877.98
85.80
1.10
4,397.07
4,348.39
3,401.93
2,730.09
6,019,460.94
572,000.97
0.40
4,236.95 2_MWD+IFR2+MS+Sag(4)
9,941.77
86.30
1.58
4,401.46
4,352.78
3,465.55
2,731.58
6,019,524.57
572,001.87
1.09
4,295.24 2_MWD+IFR2+MS+Sag(4)
10,005.58
86.85
2.34
4,405.27
4,356.59
3,529.21
2,733.76
6,019,588.24
572,003.46
1.47
4,353.86 2_MWD+IFR2+MS+Sag(4)
10,068.67
88.53
2.61
4,407.82
4,359.14
3,592.18
2,736.48
6,019,651.23
572,005.59
2.70
4,412.08 2_MWD+IFR2+MS+Sag (4)
10,132.18
88.34
3.47
4,409.55
4,360.87
3,655.58
2,739.85
6,019,714.65
572,008.37
1.39
4,470.96 2_MWD+IFR2+MS+Sag (4)
10,195.71
87.96
3.88
4,411.60
4,362.92
3,718.95
2,743.92
6,019,778.04
572,011.85
0.88
4,530.11 2_MWD+IFR2+MS+Sag (4)
10,259.26
88.21
4.63
4,413.72
4,365.04
3,782.28
2,748.63
6,019,841.42
572,015.97
1.24
4,589.51 2_MWD+IFR2+MS+Sag(4)
10,322.46
88.71
4.67
4,415.42
4,366.74
3,845.25
2,753.75
6,019,904.43
572,020.51
0.79
4,648.74 2_MWD+IFR2+MS+Sag (4)
10,385.83
91.06
4.05
4,415.55
4,366.87
3,908.44
2,758.57
6,019,967.64
572,024.73
3.84
4,708.04 2 MWD+IFR2+MS+Sag (4)
10,449.14
91.30
4.51
4,414.25
4,365.57
3,971.55
2,763.29
6,020,030.80
572,028.87
0.82
4,767.25 2_MWD+IFR2+MS+Sag(4)
10,513.36
91.86
4.19
4,412.48
4,363.80
4,035.57
2,768.16
6,020,094.85
572,033.14
1.00
4,827.32 2_MWD+IFR2+MS+Sag (4)
10,576.90
90.74
5.48
4,411.03
4,362.35
4,098.86
2,773.51
6,020,158.18
572,037.91
2.69
4,886.95 2_MWD+IFR2+MS+Sag (4)
10,640.00
90.74
6.14
4,410.22
4,361.54
4,161.63
2,779.90
6,020,221.00
572,043.71
1.05
4,946.53 2_MWD+IFR2+MS+Sag (4)
10,702.53
91.86
7.97
4,408.80
4,360.12
4,223.67
2,787.58
6,020,283.10
572,050.81
3.43
5,006.00 2_MWD+IFR2+MS+Sag (4)
4/8/2019 12:31:11 PM
Page 6
COMPASS 5000.15 Build 91
Survey
Map Map vertical
MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section
(usft) (1 (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name
10,766.74 92.04 9.83 4,406.62 4,357.94 4,287.07 2,797.51 6,020,346.58 572,060.15 2.91 5,067.66 2_MWD+IFR2+MS+Sag (4)
10,829.83 92.04 9.10 4,404.37 4,355.69 4,349.26 2,807.87 6,020,408.86 572,069.94 1.16 5,128.41 2_MWD+IFR2+MS+Sag (4)
10,893.04 93.28 9.12 4,401.44 4,352.76 4,411.60 2,817.87 6,020,471.29 572,079.35 1.96 5,189.13 2_MWD+IFR2+MS+Sag (4)
10,955.88 94.70 7.84 4,397.06 4,348.38 4,473.60 2,827.12 6,020,533.37 572,088.02 3.04 5,249.23 2_MWD+IFR2+MS+Sag(4)
11,019.06 94.27 5.94 4,392.12 4,343.44 4,536.13 2,834.67 6,020,595.96 572,094.99 3.07 5,309.10 2_MWD+IFR2+MS+Sag(4)
11,082.28 93.03 6.36 4,388.10 4,339.42 4,598.86 2,841.43 6,020,658.74 572,101.17 2.07 5,368.80 2_MWD+IFR2+MS+Sag (4)
11,145.81 92.97 6.11 4,384.77 4,336.09 4,661.92 2,848.32 6,020,721.86 572,107.47 0.40 5,428.87 2_MWD+IFR2+MS+Sag (4)
11,209.06 91.23 6.34 4,382.46 4,333.78 4,724.76 2,855.17 6,020,784.75 572,113.74 2.77 5,488.72 2_MWD+IFR2+MS+Sag (4)
11,271.94 90.18 5.89 4,381.68 4,333.00 4,787.27 2,861.87 6,020,847.32 572,119.85 1.82 5,548.21 2_MWD+IFR2+MS+Sag (4)
11,336.15 90.68 4.75 4,381.20 4,332.52 4,851.20 2,867.82 6,020,911.30 572,125.21 1.94 5,608.66 2_MWD+IFR2+MS+Sag (4)
11,399.97 91.67 3.56 4,379.89 4,331.21 4,914.84 2,872.45 6,020,974.97 572,129.24 2.43 5,668.29 2_MWD+IFR2+MS+Sag(4)
11,463.63 90.31 4.17 4,378.79 4,330.11 4,978.34 2,876.74 6,021,038.50 572,132.94 2.34 5,727.66 2_MWD+IFR2+MS+Sag(4)
11,527.23 89.57 5.48 4,378.86 4,330.18 5,041.72 2,882.09 6,021,101.92 572,137.70 2.37 5,787.36 2_MWD+IFR2+MS+Sag (4)
11,567.00 89.82 5.85 4,379.07 4,330.39 5,081.29 2,886.01 6,021,141.52 572,141.26 1.12 5,824.88 2_MWD+IFR2+MS+Sag (5)
11,590.91 89.51 6.55 4,379.21 4,330.53 5,105.06 2,888.60 6,021,165.31 572,143.62 3.20 5,847.52 2_MWD+IFR2+MS+Sag(5)
11,653.40 89.39 8.88 4,379.81 4,331.13 5,166.98 2,896.98 6,021,227.30 572,151.43 3.73 5,907.18 2_MWD+IFR2+MS+Sag(5)
11,717.31 90.32 10.35 4,379.97 4,331.29 5,229.99 2,907.66 6,021,290.40 572,161.51 2.72 5,968.80 2 MWD+IFR2+MS+Sag (5)
11,780.96 89.82 11.15 4,379.89 4,331.21 5,292.52 2,919.53 6,021,353.03 572,172.80 1.48 6,030.49 2_MWD+IFR2+MS+Sag (5)
11,844.73 90.13 10.97 4,379.92 4,331.24 5,355.11 2,931.76 6,021,415.73 572,184.45 0.56 6,092.38 2_MWD+IFR2+MS+Sag (5)
11,908.37 90.19 9.15 4,379.74 4,331.06 5,417.76 2,942.88 6,021,478.48 572,194.98 2.86 6,153.87 2_MWD+IFR2+MS+Sag (5)
11,970.16 89.26 6.38 4,380.04 4,331.36 5,478.98 2,951.23 6,021,539.76 572,202.76 4.73 6,212.88 2_MWD+IFR2+MS+Sag (5)
12,034.69 87.53 5.37 4,381.85 4,333.17 5,543.14 2,957.83 6,021,603.98 572,208.77 3.10 6,273.82 2_MWD+IFR2+MS+Sag (5)
12,098.44 87.35 3.78 4,384.69 4,336.01 5,606.62 2,962.91 6,021,667.50 572,213.26 2.51 6,333.50 2_MWD+IFR2+MS+Sag(5)
12,162.27 87.66 3.78 4,387.47 4,338.79 5,670.25 2,967.11 6,021,731.16 572,216.87 0.49 6,392.94 2_MWD+IFR2+MS+Sag (5)
12,225.61 88.90 3.65 4,389.37 4,340.69 5,733.43 2,971.22 6,021,794.37 572,220.38 1.97 6,451.94 2_MWD+IFR2+MS+Sag (5)
12,288.72 89.57 2.70 4,390.22 4,341.54 5,796.44 2,974.71 6,021,857.40 572,223.29 1.84 6,510.52 2_MWD+IFR2+MS+Sag (5)
12,352.73 88.64 1.35 4,391.22 4,342.54 5,860.40 2,976.97 6,021,921.37 572,224.96 2.56 6,569.44 2_MWD+IFR2+MS+Sag (5)
12,416.64 88.71 1.43 4,392.69 4,344.01 5,924.27 2,978.52 6,021,985.25 572,225.91 0.17 6,627.99 2 MWD+IFR2+MS+Sag (5)
12,480.61 89.57 3.93 4,393.66 4,344.98 5,988.16 2,981.51 6,022,049.15 572,228.31 4.13 6,687.15 2_MWD+IFR2+MS+Sag(5)
12,543.90 89.45 5.82 4,394.20 4,345.52 6,051.22 2,986.89 6,022,112.25 572,233.10 2.99 6,746.57 2_MWD+IFR2+MS+Sag (5)
12,606.95 89.88 7.70 4,394.57 4,345.89 6,113.82 2,994.31 6,022,174.92 572,239.94 3.06 6,806.45 2_MWD+IFR2+MS+Sag(5)
12,670.89 90.31 7.43 4,394.46 4,345.78 6,177.21 3,002.73 6,022,238.37 572,247.76 0.79 6,867.46 2_MWD+IFR2+MS+Sag(5)
12,733.97 89.38 6.38 4,394.63 4,345.95 6,239.83 3,010.31 6,022,301.06 572,254.76 2.22 6,927.41 2_MWD+IFR2+MS+Sag (5)
12,798.04 89.63 5.19 4,395.18 4,346.50 6,303.57 3,016.77 6,022,364.85 572,260.63 1.90 6,987.91 2_MWD+IFR2+MS+Sag (5)
12,858.91 88.52 4.57 4,396.17 4,347.49 6,364.21 3,021.95 6,022,425.53 572,265.24 2.09 7,045.06 2_MWD+IFR2+MS+Sag(5)
12,924.78 88.03 3.22 4,398.15 4,349.47 6,429.89 3,026.42 6,022,491.25 572,269.10 2.18 7,106.48 2_MWD+IFR2+MS+Sag(5)
12,994.00 88.03 3.22 4,400.53 4,351.85 6,498.96 3,030.31 6,022,560.34 572,272.34 0.00 7,170.72 PROJECTED to TD
" "°" Mitch Laird
Checked By: Chelsea Wrights . Mv, Approved By: -^ Date: 04-08-2019
482019 12:31:11 PM Page 7 COMPASS 5000.15 Build 91
Halliburton
Definitive Survey Report
Company:
Hilcorp Alaska, LLC
Local Co-ordinate Reference:
Well MPU E-41
Project:
Milne Point
ND Reference:
MPU E-41 Actual RKB @ 48.68usft
Site:
M Pt E Pad
MD Reference:
MPU E-41 Actual RKB @ 48.68usft
Well:
MPU E-41
North Reference:
True
Wellbore:
MPU E-41
Survey Calculation Method:
Minimum Curvature
Design:
MPU E-41
Database:
NORTH US+CANADA
Survey
Map Map vertical
MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section
(usft) (1 (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name
10,766.74 92.04 9.83 4,406.62 4,357.94 4,287.07 2,797.51 6,020,346.58 572,060.15 2.91 5,067.66 2_MWD+IFR2+MS+Sag (4)
10,829.83 92.04 9.10 4,404.37 4,355.69 4,349.26 2,807.87 6,020,408.86 572,069.94 1.16 5,128.41 2_MWD+IFR2+MS+Sag (4)
10,893.04 93.28 9.12 4,401.44 4,352.76 4,411.60 2,817.87 6,020,471.29 572,079.35 1.96 5,189.13 2_MWD+IFR2+MS+Sag (4)
10,955.88 94.70 7.84 4,397.06 4,348.38 4,473.60 2,827.12 6,020,533.37 572,088.02 3.04 5,249.23 2_MWD+IFR2+MS+Sag(4)
11,019.06 94.27 5.94 4,392.12 4,343.44 4,536.13 2,834.67 6,020,595.96 572,094.99 3.07 5,309.10 2_MWD+IFR2+MS+Sag(4)
11,082.28 93.03 6.36 4,388.10 4,339.42 4,598.86 2,841.43 6,020,658.74 572,101.17 2.07 5,368.80 2_MWD+IFR2+MS+Sag (4)
11,145.81 92.97 6.11 4,384.77 4,336.09 4,661.92 2,848.32 6,020,721.86 572,107.47 0.40 5,428.87 2_MWD+IFR2+MS+Sag (4)
11,209.06 91.23 6.34 4,382.46 4,333.78 4,724.76 2,855.17 6,020,784.75 572,113.74 2.77 5,488.72 2_MWD+IFR2+MS+Sag (4)
11,271.94 90.18 5.89 4,381.68 4,333.00 4,787.27 2,861.87 6,020,847.32 572,119.85 1.82 5,548.21 2_MWD+IFR2+MS+Sag (4)
11,336.15 90.68 4.75 4,381.20 4,332.52 4,851.20 2,867.82 6,020,911.30 572,125.21 1.94 5,608.66 2_MWD+IFR2+MS+Sag (4)
11,399.97 91.67 3.56 4,379.89 4,331.21 4,914.84 2,872.45 6,020,974.97 572,129.24 2.43 5,668.29 2_MWD+IFR2+MS+Sag(4)
11,463.63 90.31 4.17 4,378.79 4,330.11 4,978.34 2,876.74 6,021,038.50 572,132.94 2.34 5,727.66 2_MWD+IFR2+MS+Sag(4)
11,527.23 89.57 5.48 4,378.86 4,330.18 5,041.72 2,882.09 6,021,101.92 572,137.70 2.37 5,787.36 2_MWD+IFR2+MS+Sag (4)
11,567.00 89.82 5.85 4,379.07 4,330.39 5,081.29 2,886.01 6,021,141.52 572,141.26 1.12 5,824.88 2_MWD+IFR2+MS+Sag (5)
11,590.91 89.51 6.55 4,379.21 4,330.53 5,105.06 2,888.60 6,021,165.31 572,143.62 3.20 5,847.52 2_MWD+IFR2+MS+Sag(5)
11,653.40 89.39 8.88 4,379.81 4,331.13 5,166.98 2,896.98 6,021,227.30 572,151.43 3.73 5,907.18 2_MWD+IFR2+MS+Sag(5)
11,717.31 90.32 10.35 4,379.97 4,331.29 5,229.99 2,907.66 6,021,290.40 572,161.51 2.72 5,968.80 2 MWD+IFR2+MS+Sag (5)
11,780.96 89.82 11.15 4,379.89 4,331.21 5,292.52 2,919.53 6,021,353.03 572,172.80 1.48 6,030.49 2_MWD+IFR2+MS+Sag (5)
11,844.73 90.13 10.97 4,379.92 4,331.24 5,355.11 2,931.76 6,021,415.73 572,184.45 0.56 6,092.38 2_MWD+IFR2+MS+Sag (5)
11,908.37 90.19 9.15 4,379.74 4,331.06 5,417.76 2,942.88 6,021,478.48 572,194.98 2.86 6,153.87 2_MWD+IFR2+MS+Sag (5)
11,970.16 89.26 6.38 4,380.04 4,331.36 5,478.98 2,951.23 6,021,539.76 572,202.76 4.73 6,212.88 2_MWD+IFR2+MS+Sag (5)
12,034.69 87.53 5.37 4,381.85 4,333.17 5,543.14 2,957.83 6,021,603.98 572,208.77 3.10 6,273.82 2_MWD+IFR2+MS+Sag (5)
12,098.44 87.35 3.78 4,384.69 4,336.01 5,606.62 2,962.91 6,021,667.50 572,213.26 2.51 6,333.50 2_MWD+IFR2+MS+Sag(5)
12,162.27 87.66 3.78 4,387.47 4,338.79 5,670.25 2,967.11 6,021,731.16 572,216.87 0.49 6,392.94 2_MWD+IFR2+MS+Sag (5)
12,225.61 88.90 3.65 4,389.37 4,340.69 5,733.43 2,971.22 6,021,794.37 572,220.38 1.97 6,451.94 2_MWD+IFR2+MS+Sag (5)
12,288.72 89.57 2.70 4,390.22 4,341.54 5,796.44 2,974.71 6,021,857.40 572,223.29 1.84 6,510.52 2_MWD+IFR2+MS+Sag (5)
12,352.73 88.64 1.35 4,391.22 4,342.54 5,860.40 2,976.97 6,021,921.37 572,224.96 2.56 6,569.44 2_MWD+IFR2+MS+Sag (5)
12,416.64 88.71 1.43 4,392.69 4,344.01 5,924.27 2,978.52 6,021,985.25 572,225.91 0.17 6,627.99 2 MWD+IFR2+MS+Sag (5)
12,480.61 89.57 3.93 4,393.66 4,344.98 5,988.16 2,981.51 6,022,049.15 572,228.31 4.13 6,687.15 2_MWD+IFR2+MS+Sag(5)
12,543.90 89.45 5.82 4,394.20 4,345.52 6,051.22 2,986.89 6,022,112.25 572,233.10 2.99 6,746.57 2_MWD+IFR2+MS+Sag (5)
12,606.95 89.88 7.70 4,394.57 4,345.89 6,113.82 2,994.31 6,022,174.92 572,239.94 3.06 6,806.45 2_MWD+IFR2+MS+Sag(5)
12,670.89 90.31 7.43 4,394.46 4,345.78 6,177.21 3,002.73 6,022,238.37 572,247.76 0.79 6,867.46 2_MWD+IFR2+MS+Sag(5)
12,733.97 89.38 6.38 4,394.63 4,345.95 6,239.83 3,010.31 6,022,301.06 572,254.76 2.22 6,927.41 2_MWD+IFR2+MS+Sag (5)
12,798.04 89.63 5.19 4,395.18 4,346.50 6,303.57 3,016.77 6,022,364.85 572,260.63 1.90 6,987.91 2_MWD+IFR2+MS+Sag (5)
12,858.91 88.52 4.57 4,396.17 4,347.49 6,364.21 3,021.95 6,022,425.53 572,265.24 2.09 7,045.06 2_MWD+IFR2+MS+Sag(5)
12,924.78 88.03 3.22 4,398.15 4,349.47 6,429.89 3,026.42 6,022,491.25 572,269.10 2.18 7,106.48 2_MWD+IFR2+MS+Sag(5)
12,994.00 88.03 3.22 4,400.53 4,351.85 6,498.96 3,030.31 6,022,560.34 572,272.34 0.00 7,170.72 PROJECTED to TD
" "°" Mitch Laird
Checked By: Chelsea Wrights . Mv, Approved By: -^ Date: 04-08-2019
482019 12:31:11 PM Page 7 COMPASS 5000.15 Build 91
Hilcorp
Milne Point
MPtEPad
MPU E-41PB1
500292362270
Alaska, LLC
Sperry Drilling
Definitive Survey Report
08 April, 2019
HALLIBURTON
Sperry Drilling
Halliburton
Definitive Survey Report
Company:
Hilcorp Alaska, LLC
Local Co-ordinate Reference:
Well MPU E-41
Project:
Milne Point
TVD Reference:
MPU E-41 Actual RKB @ 48.68usft
Site:
M Pt E Pad
MD Reference:
MPU E-41 Actual RKB @ 48.68usft
Well:
MPU E-41
North Reference:
True
Wellbore:
MPU E -41P61
Survey Calculation Method:
Minimum Curvature
Design:
MPU E-41 PB1
Database:
NORTH US + CANADA
'reject Milne Point, ACT, MILNE POINT
Aap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Aap Zone: Alaska Zone 04 Using geodetic scale factor
Well MPU E-41
Well Position +N/ -S
+E/ -W
Position Uncertainty
Wellbore MPU E-41PB1
Magnetics Model Name
0.00 usft Northing: 6,016,034.09 usfl
0.00 usft Easting: 569,302.90 usfl
0.00 usft Wellhead Elevation: 0.00 usfl
Sample Date Declination
(I
BGGM2018 3/1/2019 16.82
Design MPU E-41PB1
Audit Notes:
Version: 1.0 Phase: ACTUAL
Vertical Section: Depth From (TVD) +N/ -S
(usfl) (usft)
26.88 0.00
Latitude: 70° 27' 14.9809 N
Longitude: 149° 26'4.0913 W
Ground Level: 21.80 usft
Dip Angle Field Strength
(°) (nT)
80.97 57,437.46943635
Tie On Depth: 26.88
+E/ -W Direction
(usft) (°)
0.00 24.64
Survey Program Date 4/8/2019
From To
(usft) (usft) Survey (Wellbore) Tool Name Description Survey Date
166.70 6,445.25 MPU E-41 PB1 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec 8 multi -station analysis +sa 03/09/2019
6,510.90 7,903.68 MPU E-41 PB1 MWD+IFR2+MS+Sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec 8 multi -station analysis +sa 03/27/2019
Survey
Map
Map
Vertical
MD
(usft)
Inc
(°)
Azi
(°)
TVD
(usft)
TVDSS
(usft)
+NIS
(usft)
+E/ -W
(usft)
Northing
(ft)
Easting
(ft)
DLS
(°1100')
Section
(ft) Survey Tool Name
26.88
0.00
0.00
26.88
-21.80
0.00
0.00
6,016,034.09
569,302.90
0.00
0.00 UNDEFINED
166.70
0.32
31.78
166.70
118.02
0.33
0.21
6,016,034.42
569,303.10
0.23
0.39 2_MWD+IFR2+MS+Sag(1)
234.53
0.70
25.93
234.53
185.85
0.87
0.49
6,016,034.96
569,303.38
0.56
0.99 2_MWD+IFR2+MS+Sag(1)
298.36
0.23
352.54
298.35
249.67
1.34
0.64
6,016,035.44
569,303.53
0.82
1.49 2_MWD+IFR2+MS+Sag(1)
360.02
1.96
234.46
360.00
311.32
0.85
-0.23
6,016,034.94
569,302.66
3.37
0.68 2_MWD+IFR2+MS+Sag(1)
422.85
3.44
229.11
422.76
374.08
-1.01
-2.53
6,016,033.06
569,300.38
2.39
-1.97 2 MWD+IFR2+MS+Sag(1)
483.92
5.23
217.83
483.66
434.98
-4.40
-5.63
6.016,029+63
569,297.32
3.23
-6.35 2_MWD+IFR2+MS+Sag(1)
545.26
6.80
210.08
544.66
495.98
-9.75
-9.16
6,016,024.25
569,293.83
2.88
-12.69 2_MWD+IFR2+MS+Sag(1)
607.29
8.36
201.84
606.14
557.46
-17.12
-12.68
6,016,016.86
569,290.38
3.06
-20.85 2_MWD+IFR2+MS+Sag(1)
670.20
10.22
192.00
668.23
619.55
-26+82
-15.54
6,016,007.12
569,287.61
3.88
-30.86 2_MWD+IFR2+MS+Sag(1)
733.85
12.70
186.32
730.61
681.93
-39.30
-17.49
6,015,994.63
569,285.78
4.28
43.02 2_MWD+IFR2+MS+Sag(1)
798.32
15.83
184.91
793.08
744.40
-55.11
-19.02
6,015,978.81
569,284.40
4.88
-58.02 2_MWD+IFR2+MS+Sag(1)
862.23
18.05
183.01
854.22
805.54
-73.69
-20.29
6,015,960.22
569,283.30
3.58
-75.44 2 MWD+IFR2+MS+Sag(1)
4WO19 12:44:26PM
Page 2
COMPASS 5000.15 Build 91
Halliburton
Definitive
Survey Report
Company:
Hilcorp Alaska,
LLC
Local Co-ordinate Reference: Well
MPU E-41
Project:
Milne Point
TVD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Site:
M Pt
E Pad
MD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Well:
MPU
E-41
North Reference:
True
Wellbore:
MPU
E41PB1
Survey Calculation Method: Minimum Curvature
Design:
MPU
E-41PB1
Database:
NORTH
US+CANADA
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/.S
+E/-W
Northing
Easting
DLS
Section
(usft)
V)
V)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft) ("1100')
(ft) Survey Tool Name
924.89
20.79
181.09
913.31
864.63
-94.50
-21.01
6,015,939.40
569,282.78
4.49
-94.66 2_MWD+IFR2+MS+Sag(1)
988.39
22.56
180.83
972.31
923.63
-117.95
-21.40
6,015,915.95
569,282.60
2.79
-116.13 2_MWD+IFR2+MS+Sag(1)
1,052.41
24.87
179.28
1,030.93
982.25
-143.70
-21.41
6,015,890.21
569,282.83
3.74
-139.54 2_MWD+IFR2+MS+Sag(1)
1,115.85
26.38
177.80
1,088.12
1,039.44
-171.12
-20.70
6,015,862.80
569,283.80
2.59
-164.17 2_MWD+IFR2+MS+Sag(1)
1,179.10
29.56
178.04
1,143.98
1,095.30
-200.76
-19.62
6,015,833.17
569,285.15
5.03
-190.66 2_MWD+IFR2+MS+Sag(1)
1,242.71
33.19
177.81
1,198.28
1,149.60
-233.85
-18.42
6,015,800.10
569,286.66
5.71
-220.24 2_MWD+IFR2+MS+Sag(1)
1,306.00
35.45
177.56
1,250.55
1,201.87
-269.51
-16.98
6,015,764.46
569,288.43
3.58
-252.04 2 MWD+IFR2+MS+Sag(1)
1,370.26
38.48
177.12
1,301.89
1,253.21
-308.10
-15.18
6,015,725.89
569,290.59
4.73
-286.38 2_MWD+IFR2+MS+Sag(1)
1,433.92
40.80
177.33
1,350.90
1,302.22
-348.66
-13.22
6,015,685.35
569,292.93
3.65
-322.43 2_MWD+IFR2+MS+Sag(1)
1,497.48
43.88
177.47
1,397.88
1,349.20
-391.42
-11.28
6,015,642.62
569,295.27
4.85
-360.48 2_MWD+IFR2+MS+Sag(1)
1,561.06
45.95
176.66
1,442.90
1,394.22
-436.25
-8.97
6,015,597.81
569,297.99
3.38
-400.27 2_MWD+IFR2+MS+Sag(1)
1,625.11
47.40
175.06
1,486.85
1,438.17
-482.72
-5.60
6,015,551.38
569,301.79
2.90
441.10 2_MWD+IFR2+MS+Sag(1)
1,687.73
47.03
175.14
1,529.38
1,480.70
-528.51
-1.67
6,015,505.64
569,306.14
0.60
481.08 2_MWD+IFR2+MS+Sag(1)
1,753.03
46.93
175.71
1,573.94
1,525.26
-576.10
2.13
6,015,458.09
569,310.39
0.66
-522.75 2_MWD+IFR2+MS+Sag(1)
1,816.92
46.73
175.79
1,617.65
1,568.97
-622.57
5.59
6,015,411.66
569,314.28
0.33
-563.55 2_MWD+IFR2+MS+Sag(1)
1,880.18
46.54
174.52
1,661.08
1,612.40
-668.39
9.47
6,015,365.88
569,318.59
1.49
-603.58 2_MWD+IFR2+MS+Sag(1)
1,943.18
45.72
174.45
1,704.74
1,656.06
-713.60
13.84
6,015,320.72
569,323.37
1.30
-642.85 2_MWD+IFR2+MS+Sag(1)
2,006.18
43.01
174.62
1,749.78
1,701.10
-757.44
18.03
6,015,276.92
569,327.97
4.31
-680.96 2_MWD+IFR2+MS+Sag(1)
2,070.06
43.96
175.04
1,796.13
1,747.45
-801.23
21.99
6,015,233.18
569,332.34
1.55
-719.10 2 MWD+IFR2+MS+Sag(1)
2,133.72
46.01
175.96
1,841.15
1,792.47
-846.09
25.52
6,015,188.36
569,336.28
3.38
-758.41 2_MWD+IFR2+MS+Sag(1)
2,196.96
45.11
175.87
1,885.43
1,836.75
-891.12
28.73
6,015,143.36
569,339.92
1.43
-798.00 2_MWD+IFR2+MS+Sag(1)
2,261.51
46.43
176.30
1,930.45
1,881.77
-937.27
31.89
6,015,097.25
569,343.50
2.10
-838.63 2_MWD+IFR2+MS+Sag(1)
2,325.05
46.31
176.52
1,974.30
1,925.62
-983.17
34.77
6,015,051.38
569,346.81
0.31
-879.15 2_MWD+IFR2+MS+Sag(1)
2,388.34
47.36
174.20
2,017.60
1,968.92
-1,029.17
38.51
6,015,005.42
569,350.98
3.15
-919.41 2_MWD+IFR2+MS+Sag(1)
2,451.96
46.33
174.15
2,061.11
2,012.43
-1,075.34
43.22
6,014,959.30
569,356.12
1.62
-959.41 2_MWD+IFR2+MS+Sag(1)
2,515.25
44.45
172.31
2,105.56
2,056.88
-1,120.08
48.52
6,014,914.61
569,361.83
3.62
-997.86 2_MWD+IFR2+MS+Sag(1)
2,578.72
43.20
169.58
2,151.35
2,102.67
-1,163.48
55.42
6,014,871.29
569,369.14
3.57
-1,034.43 2_MWD+IFR2+MS+Sag(1)
2,642.11
41.94
167.86
2,198.04
2,149.36
-1,205.53
63.80
6,014,829.32
569,377.91
2.71
-1,069.16 2_MWD+IFR2+MS+Sag(1)
2,705.53
40.44
165.32
2,245.76
2,197.08
-1,246.15
73.47
6,014,788.80
569,387.95
3.54
-1,102.05 2_MWD+IFR2+MS+Sag(1)
2,768.83
38.55
163.15
2,294.61
2,245.93
-1,284.89
84.39
6,014,750.16
569,399.23
3.70
-1,132.71 2_MWD+IFR2+MS+Sag(1)
2,832.16
36.68
161.29
2,344.78
2,296.10
-1,321.70
96.18
6,014,713.47
569,411.36
3.45
-1,161.25 2 MWD+IFR2+MS+Sag(1)
2,895.77
34.51
159.39
2,396.50
2,347.82
-1,356.56
108.62
6,014,678.72
569,424.12
3.83
-1,187.76 2_MWD+IFR2+MS+Sag(1)
2,958.70
32.34
158.06
2,449.02
2,400.34
-1,388.87
121.19
6,014,646.54
569,436.99
3.64
-1,211.88 2 MWD+IFR2+MS+Sag(1)
3,022.80
30.60
153.80
2,503.70
2,455.02
-1,419.41
134.80
6,014,616.12
569,450.88
4.40
-1,233.97 2_MWD+IFR2+MS+Sag(1)
3,086.00
28.89
150.99
2,558.57
2,509.89
-1,447.20
149.31
6,014,588.48
569,465.65
3.49
-1,253.18 2_MWD+IFR2+MS+Sag(1)
3,149.26
28.06
145.14
2,614.19
2,565.51
-1,472.78
165.23
6,014,563.05
569,481.80
4.60
-1,269.79 2_MWD+IFR2+MS+Sag(1)
3,212.29
27.12
140.81
2,670.05
2,621.37
-1,496.08
182.78
6,014,539.91
569,499.57
3.51
-1,283.65 2 MWD+IFR2+MS+Sag(1)
3,275.87
26.37
134.84
2,726.84
2,678.16
-1,517.28
201.95
6,014,518.90
569,518.94
4.39
-1,294.92 2_MWD+IFR2+MS+Sag(1)
3,339.66
25.86
127.75
2,784.13
2,735.45
-1,535.79
223.00
6,014,500.59
569,540.16
4.95
-1,302.97 2_MWD+IFR2+MS+Sag(1)
3,402.70
25.49
121.18
2,840.96
2,792.28
-1,551.23
245.48
6,014,485.36
569,562.78
4.55
-1,307.64 2_MWD+IFR2+MS+Sag(1)
4/8/2019 12:44:26PM
Page
3
COMPASS 5000.15 Build 91
Halliburton
Definitive
Survey Report
Company:
Hilcorp Alaska,
LLC
Local Co-ordinate Reference: Well
MPU E41
Project:
Milne Point
TVD Reference:
MPU
E41 Actual RKB @ 48.68usft
Site:
M Pt
E Pad
MD Reference:
MPU
E-41 Actual IRKS @ 48.68usft
Well:
MPU
E-41
North Reference:
True
Wellbore:
MPU
E41 PBI
Survey Calculation Method: Minimum Curvature
Design:
MPU E41PB1
Database:
NORTH US+CANADA
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/ -S
+EI -W
Northing
Easting
DLS
Section
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft) (°Ii 00')
(ft) Survey Tool Name
3,466.50
24.90
114.67
2,898.70
2,850.02
-1,563.95
269.44
6,014,472.87
569,586.85
4.44
-1,309.21 2_MWD+IFR2+MS+Sag(1)
3,530.63
24.24
108.29
2,957.04
2,908.36
-1,573.71
294.21
6,014,463.33
569,611.71
4.26
-1,307.76 2_MWD+IFR2+MS+Sag(1)
3,594.08
23.52
101.73
3,015.06
2,966.38
-1,580.38
318.98
6,014,456.90
569,636.53
4.33
-1,303.49 2_MWD+IFR2+MS+Sag(1)
3,657.89
23.33
94.76
3,073.63
3,024.95
-1,584.01
344.04
6,014,453.49
569,661.63
4.35
-1,296.35 2_MWD+IFR2+MS+Sag(1)
3,721.90
22.45
89.43
3,132.60
3,083.92
-1,584.94
368.90
6,014,452.80
569,686.49
3.52
-1,286.83 2_MWD+IFR2+MS+Sag(1)
3,785.60
22.53
84.07
3,191.46
3,142.78
-1,583.56
393.20
6,014,454.40
569,710.78
3.22
-1,275.44 2_MWD+IFR2+MS+Sag(1)
3,849.10
24.60
79.54
3,249.67
3,200.99
-1,579.91
418.30
6,014,458.29
569,735.84
4.33
-1,261.65 2_MWD+IFR2+MS+Sag(1)
3,912.81
26.73
76.56
3,307.09
3,258.41
-1,574.17
445.28
6,014,464.28
569,762.76
3.91
-1,245.19 2_MWD+IFR2+MS+Sag(1)
3,977.03
28.88
72.24
3,363.90
3,315.22
-1,566.08
474.11
6,014,472.64
569,791.51
4.59
-1,225.82 2_MWD+IFR2+MS+Sag(1)
4,040.71
30.71
68.76
3,419.16
3,370.48
-1,555.49
503.91
6,014,483.50
569,821.21
3.95
-1,203.77 2_MWD+IFR2+MS+Sag(1)
4,103.85
33.11
65.28
3,472.76
3,424.08
-1,542.44
534.61
6,014,496.84
569,851.78
4.79
A.179.10 2_MWD+IFR2+MS+Sag(1)
4,166.87
35.40
61.22
3,524.86
3,476.18
-1,526.45
566.25
6,014,513.12
569,883.27
5.13
-1,151.38 2_MWD+IFR2+MS+Sag(1)
4,230.97
37.00
55.28
3,576.60
3,527.92
-1,506.52
598.39
6,014,533.35
569,915.22
6.01
-1,119.86 2_MWD+IFR2+MS+Sag(1)
4,294.42
39.64
50.52
3,626.38
3,577.70
-1,482.76
629.72
6,014,557.39
569,946.32
6.24
-1,085.21 2_MWD+IFR2+MS+Sag(1)
4,358.31
40.49
49.48
3,675.28
3,626.60
-1,456.33
661.22
6,014,584.11
569,977.57
1.69
-1,048.05 2_MWD+IFR2+MS+Sag(1)
4,421.50
41.97
49.05
3,722.80
3,674.12
-1,429.15
692.77
6,014,611.58
570,008.87
2.38
-1,010.19 2_MWD+IFR2+MS+Sag(1)
4,484.19
44.43
47.54
3,768.50
3,719.82
-1,400.59
724.80
6,014,640.43
570,040.63
4.26
-970.88 2_MWD+IFR2+MS+Sag(1)
4,548.16
46.38
46.03
3,813.41
3,764.73
-1,369.40
757.99
6,014,671.93
570,073.52
3.48
-928.69 2_MWD+IFR2+MS+Sag(1)
4,610.88
47.71
42.55
3,856.16
3,807.48
-1,336.54
790.02
6,014,705.08
570,105.24
4.58
-885.47 2_MWD+IFR2+MS+Sag(1)
4,675.06
49.98
41.77
3,898.39
3,849.71
-1,300.72
822.45
6,014,741.20
570,137.33
3.65
-839.39 2_MWD+IFR2+MS+Sag(1)
4,738.87
52.14
39.64
3,938.49
3,889.81
-1,263.09
854.80
6,014,779.12
570,169.33
4.27
-791.70 2_MWD+IFR2+MS+Sag(1)
4,801.16
53.56
38.80
3,976.11
3,927.43
-1,224.63
886.19
6,014,817.87
570,200.36
2.52
-743.65 2_MWD+IFR2+MS+Sag(1)
4,866.10
55.24
36.77
4,013.92
3,965.24
-1,182.89
918.53
6,014,859.90
570,232.30
3.63
-692.24 2 MWD+IFR2+MS+Sag(1)
4,929.55
58.12
36.15
4,048.77
4,000.09
-1,140.25
950.03
6,014,902.83
570,263.40
4.61
-640.35 2_MWD+IFR2+MS+Sag(1)
4,993.55
61.72
34.84
4,080.84
4,032.16
-1,095.17
982.17
6,014,948.21
570,295.12
5.90
-585.97 2_MWD+IFR2+MS+Sag(1)
5,057.07
64.09
33.55
4,109.77
4,061.09
-1,048.40
1,013.94
6,014,995.27
570,326.45
4.15
-530.21 2_MWD+IFR2+MS+Sag(1)
5,121.65
66.94
31.38
4,136.54
4,087.86
-998.81
1,045.47
6,015,045.14
570,357.52
5.37
-471.99 2_MWD+IFR2+MS+Sag(1)
5,184.60
70.11
29.08
4,159.58
4,110.90
-948.20
1,074.95
6,015,096.02
570,386.52
6.08
-413.70 2_MWD+IFR2+MS+Sag(1)
5,248.92
71.09
26.38
4,180.95
4,132.27
-894.51
1,103.17
6,015,149.97
570,414.24
4.24
-353.13 2_MWD+IFR2+MS+Sag(1)
5,312.82
72.56
24.27
4,200.88
4,152.20
-839.63
1,129.13
6,015,205.08
570,439.69
3.89
-292.43 2_MWD+IFR2+MS+Sag(1)
5,377.20
75.37
22.37
4,218.66
4,169.98
-782.82
1,153.62
6,015,262.11
570,463.64
5.21
-230.58 2_MWD+IFR2+MS+Sag(1)
5,440.05
78.95
22.08
4,232.63
4,183.95
-726.10
1,176.79
6,015,319.04
570,486.28
5.71
-169.36 2 MWD+IFR2+MS+Sag(1)
5,504.06
80.89
21.74
4,243.83
4,195.15
-667.63
1,200.31
6,015,377.71
570,509.25
3.08
-106.41 2_MWD+IFR2+MS+Sag(1)
5,567.21
81.76
21.47
4,253.36
4,204.68
-609.59
1,223.29
6,015,435.96
570,531.69
1.44
-44.08 2_MWD+IFR2+MS+Sag(1)
5,630.75
81.78
21.51
4,262.45
4,213.77
-551.08
1,246.33
6,015,494.68
570,554.18
0.07
18.72 2_MWD+IFR2+MS+Sag(1)
5,694.14
83.55
20.99
4,270.55
4,221.87
-492.48
1,269.12
6,015,553.48
570,576.42
2.91
81.47 2_MWD+IFR2+MS+Sag(1)
5,756.66
83.02
21.76
4,277.86
4,229.18
-434.66
1,291.75
6,015,611.50
570,598.51
1.49
143.46 2_MWD+IFR2+MS+Sag(1)
5,820.97
83.25
21.40
4,285.54
4,236.86
-375.29
1,315.23
6,015,671.08
570,621.44
0.66
207.22 2_MWD+IFR2+MS+Sag(1)
5,884.39
80.69
22.04
4,294.40
4,245.72
-316.96
1,338.47
6,015,729.63
570,644.13
4.16
269.93 2_MWD+IFR2+MS+Sag(1)
5,947.90
79.61
22.63
4,305.27
4,256.59
-259.08
1,362.24
6,015,787.72
570,667.37
1.93
332.45 2_MWD+IFR2+MS+Sag(1)
4182019 12:44:26PM
Page 4
COMPASS 5000.15 Build 91
Halliburton
Definitive Survey Report
Company:
Hilcorp Alaska, LLC
Local Co-ordinate Reference: Well MPU E-41
Project:
Milne
Point
TVD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Site:
M Pt E Pad
MD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Well:
MPU
E-41
North Reference:
True
Wellbore:
MPU
E-41PB1
Survey Calculation Method:
Minimum
Curvature
Design:
MPU E-41PB1
Database:
NORTH
US+CANADA
Survey
Map
Map
vertical
MD
Inc
Azi
TVD
TVDSS
+N/ -S
+E/ -W
Northing
Easting
DLS
Section
(usft)
(')
(1)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft) ("/1001)
(ft) Survey Tool Name
6,011.22
81.05
22.81
4,315.90
4,267.22
-201.50
1,386.35
6,015,845.51
570,690.94
2.29
394.84 2_MWD+IFR2+MS+Sag(1)
6,074,43
82.39
23.14
4,325.00
4,276.32
-143.91
1,410.77
6,015,903.32
570,714.81
2.18
457.36 2_MWD+IFR2+MS+Sag(1)
6,138.46
82.22
22.76
4,333.58
4,284.90
-85.48
1,435.51
6,015,961.97
570,739.01
0.65
520.79 2_MWD+IFR2+MS+Sag(1)
6,202.49
81.97
22.69
4,342.38
4,293.70
-26.99
1,460.01
6,016,020.69
570,762.96
0.41
584.17 2_MWD+IFR2+MS+Sag(1)
6,265.42
83.63
21.33
4,350.27
4,301.59
30.90
1,483.41
6,016,078.78
570,785.81
3.40
646.54 2_MWD+IFR2+MS+Sag(1)
6,328.74
84.02
19.26
4,357.08
4,308.40
89.94
1,505.24
6,016,138.01
570,807.10
3.31
709.30 2_MWD+IFR2+MS+Sag(1)
6,392.15
87.14
20.35
4,361.97
4,313.29
149.41
1.526.66
6,016,197.68
570,827.96
5.21
772.29 2_MWD+IFR2+MS+Sag(1)
6,445.25
91.49
21.03
4,362.60
4,313.92
199.07
1,545.41
6,016,247.51
570,846.25
8.29
825.25 2_MWD+IFR2+MS+Sag(1)
6,510.90
93.54
20.93
4,359.72
4,311.04
260.30
1,568.89
6,016,308.95
570,869.16
3.13
890.70 2_MWD+IFR2+MS+Sag(2)
6,575.22
93.34
21.55
4,355.86
4,307.18
320.15
1,592.15
6,016,369.00
570,891.86
1.01
954.79 2_MWD+IFR2+MS+Sag(2)
6,638.60
92.53
21.60
4,352.62
4,303.94
379.01
1,615.43
6,016,428.07
570,914.58
1.28
1,018.00 2_MWD+IFR2+MS+Sag(2)
6,702.90
91.79
21.10
4,350.20
4,301.52
438.85
1,638.82
6,016,488.12
570,937.41
1.39
1,082.14 2_MWD+IFR2+MS+Sag (2)
6,766.55
91.98
20.66
4,348.10
4,299.42
498.29
1,661.50
6,016,547.77
570,959.53
0.75
1,145.62 2_MWD+IFR2+MS+Sag(2)
6,829.16
91.98
20.81
4,345.94
4,297.26
556.81
1,683.65
6,016,606.48
570,981.14
0.24
1,208.05 2_MWD+IFR2+MS+Sag(2)
6,892.72
91.36
20.86
4,344.09
4,295.41
616.19
1,706.25
6,016,666.06
571,003.18
0.98
1,271.44 2_MWD+IFR2+MS+Sag(2)
6,956.48
90.06
20.22
4,343.30
4,294.62
675.89
1,728.61
6,016,725.96
571,024.99
2.27
1,335.03 2_MWD+IFR2+MS+Sag(2)
7,019.74
90.19
20.08
4,343.16
4,294.48
735.28
1,750.41
6,016,785.55
571,046.23
0.30
1,398.10 2_MWD+IFR2+MS+Sag(2)
7,083.36
89.32
19.65
4,343.43
4,294.75
795.11
1,772.02
6,016,845.57
571,067.28
1.53
1,461.50 2_MWD+IFR2+MS+Sag(2)
7,146.87
89.08
21.15
4,344.32
4,295.64
854.63
1,794.16
6,016,905.29
571,088.86
2.39
1,524.82 2_MWD+IFR2+MS+Sag(2)
7,210.62
89.45
22.29
4,345.14
4,296.46
913.85
1,817.75
6,016,964.72
571,111.90
1.88
1,588.48 2_MWD+IFR2+MS+Sag (2)
7,273.37
89.20
22.23
4,345.87
4,297.19
971.92
1,841.52
6,017,023.00
571,135.12
0.41
1,651.18 2_MWD+IFR2+MS+Sag (2)
7,337.00
90.19
22.27
4,346.21
4,297.53
1,030.81
1,865.61
6,017,082.11
571,158.67
1.56
1,714.75 2_MWD+IFR2+MS+Sag (2)
7,399.99
90.87
22.75
4,345.63
4,296.95
1,089.00
1,889.72
6,017,140.51
571,182.24
1.32
1,777.69 2_MWD+IFR2+MS+Sag (2)
7,463.53
91.80
22.17
4,344.15
4,295.47
1,147.70
1,913.99
6,017,199.43
571,205.95
1.72
1,841.17 2_MWD+IFR2+MS+Sag (2)
7,526.41
91.17
20.88
4,342.52
4,293.84
1,206.17
1,937.05
6,017,258.11
571,228.47
2.28
1,903.93 2_MWD+IFR2+MS+Sag (2)
7,586.61
91.98
19.71
4,340.87
4,292.19
1,262.61
1,957.93
6,017,314.74
571,248.81
2.36
1,963.94 2_MWD+IFR2+MS+Sag (2)
7,650.15
94.58
19.85
4,337.23
4,288.55
1,322.30
1,979.39
6,017,374.62
571,269.72
4.10
2,027.14 2_MWD+IFR2+MS+Sag (2)
7,713.81
94.52
19.85
4,332.18
4,283.50
1,381.99
2,000.94
6,017,434.50
571,290.71
0.09
2,090.38 2_MWD+IFR2+MS+Sag (2)
7,777.89
94.88
19.75
4,326.93
4,278.25
1,442.08
2,022.57
6,017,494.78
571,311.78
0.58
2,154.01 2_MWD+IFR2+MS+Sag(2)
7,840.90
96.51
20.64
4,320.68
4,272.00
1,500.92
2,044.22
6,017,553.82
571,332.88
2.94
2,216.52 2_MWD+IFR2+MS+Sag (2)
7,903.68
96.38
20.42
4,313.63
4,264.95
1,559.34
2,066.09
6,017,612.43
571,354.21
0.41
2,278.74 2_MWD+IFR2+MS+Sag (2)
7,973.00
96.38
20.42
4,305.93
4,257.25
1,623.90
2,090.13
6,017,677,21
571,377.64
0.00
2,347.45 PROJECTED to TD
Checked By: Chelsea Wright" Tw Approved By: Mitch Laird
-•-
Date: 04-08-2019
482019 12:44:26PM Page 5 COMPASS 5000.15 Build 91
Hilcorp Alaska, LLC
Milne Point
M Pt E Pad
MPU E-41PB2
500292362271
Sperry Drilling
Definitive Survey Report
08 April, 2019
HALLIBURTON
Sperry Drilling
Company: Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt E Pad
Well:
MPU E-41
Wellbore:
MPU E-41 PB2
Design:
MPU E-41PB2
Halliburton
Definitive Survey Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well MPU E-41
MPU E-41 Actual RKB @ 48.68usft
MPU E-41 Actual RKB @ 48.68usft
True
Minimum Curvature
NORTH US + CANADA
Project Milne Point, ACT, MILNE POINT
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Well MPU E-41
Well Position +N/ -S
+E/ -W
Position Uncertainty
Wellbore MPU E-41PB2
Magnetics Model Name
0.00 usft Northing: 6,016,034.09 usfl
0.00 usft Easting: 569,302.90 usfl
0.00 usft Wellhead Elevation: 0.00 usfl
Sample Date Declination
(9
BGGM2018 3/1/2019 16.82
Latitude: 70° 27' 14.9809 N
Longitude: 149° 26'4.0913 W
Ground Level: 21.80 usft
Dip Angle Field Strength
(") (nT)
80.97 57,437.46943635
Design
MPU E-41PB2
Audit Notes:
The plan forward is to run 4-1/2" cemented sacrificial tubing string
with 3 swell packers on a Halliburton stinger disconnect tool with
Version:
1.0 Phase:
ACTUAL
Tie On Depth: 7,463.53
Vertical Section:
Depth From (TVD)
+NIS
+EI -W Direction
(usft)
(usft)
(usft) V)
Map
26.88
0.00
0.00 24.64
Survey Program Date 4/8/2019
From To
(usft) (usft) Survey (Wellbore) Tool Name Description Survey Date
166.70 6,445.25 MPU E-41 PB1 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 03/09/2019
6,510.90 7,463.53 MPU E -41P81 MWD+IFR2+MS+Sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 03/27/2019
7,468.00 9,367.57 MPU E-41 PB2 MWD+IFR2+MS+Sag (3) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 03/27/2019
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+NIS
+EI -W
Northing
Easting
DLS
Section
(usft)
(I
(I
(usft)
(usft)
(usft)
(usft)
(ft)
(ft)
(°1100')
(ft) Survey Tool Name
26.88
0.00
0.00
26.88
.21.80
0.00
0.00
6,016,034.09
569,302.90
0.00
0.00 UNDEFINED
166.70
0.32
31.78
166.70
118.02
0.33
0.21
6,016,034.42
569,303.10
0.23
0.39 2_MWD+IFR2+MS+Sag (1)
234.53
0.70
25.93
234.53
185.85
0.87
0.49
6,016,034.96
569,303.38
0.56
0.99 2_MWD+IFR2+MS+Sag(1)
298.36
0.23
352.54
298.35
249.67
1.34
0.64
6,016,035.44
569,303.53
0.82
1.49 2 MWD+IFR2+MS+Sag(1)
360.02
1.96
234.46
360.00
311.32
0.85
-0.23
6,016,034.94
569,302.66
3.37
0.68 2_MWD+IFR2+MS+Sag(1)
422.85
3.44
229.11
422.76
374.08
-1.01
-2.53
6,016,033.06
569,300.38
2.39
.1.97 2_MWD+IFR2+MS+Sag(1)
483.92
5.23
217.83
483.66
434.98
-0.40
-5.63
6,016,029.63
569,297.32
3.23
-6.35 2 MWD+IFR2+MS+Sag(1)
545.26
6.80
210.08
544.66
495.98
-9.75
-9.16
6,016,024.25
569,293.83
2.88
-12.69 2_MWD+IFR2+MS+Sag(1)
607.29
8.36
201.84
606.14
557.46
-17.12
-12.68
6,016,016.86
569,290.38
3.06
-20.85 2_MWD+IFR2+MS+Sag (1)
670.20
10.22
192.00
668.23
619.55
-26.82
-15.54
6,016,007.12
569,287.61
3.88
-30.86 2_MWD+IFR2+MS+Sag(1)
733.85
12.70
186.32
730.61
681.93
-39.30
-17.49
6,015,994.63
569,285.78
4.28
43.02 2_MWD+IFR2+MS+Sag(1)
798.32
15.83
184.91
793.08
744.40
-55.11
-19.02
6,015,978.81
569,284.40
4.88
-58.02 2_MWD+IFR2+MS+Sag(1)
4/812019 12:45:00PM
Page 2
COMPASS 5000.15 Build 91
Survey
MD
Inc
Halliburton
TVD
TVDSS
+Nl-S
Definitive Survey Report
(')
Company:
Hilcorp Alaska, LLC
Local Co-ordinate Reference:
Well MPU E-41
Project:
Milne Point
TVD Reference:
MPU E-41 Actual RKB @ 48.68usft
Site:
M Pt E Pad
MD Reference:
MPU E41 Actual RKB @ 48.68usft
Well:
MPU E-41
North Reference:
True
Wellbore:
MPU E-41 PB2
Survey Calculation Method:
Minimum Curvature
Design:
MPU E-41 PB2
Database:
NORTH US+CANADA
Survey
MD
Inc
AN
TVD
TVDSS
+Nl-S
(usft)
(')
n
(usft)
(usft)
(usft)
862.23
18.05
183.01
854.22
805.54
-73.69
924.89
20.79
181.09
913.31
864.63
-94.50
988.39
22.56
180.83
972.31
923.63
-117.95
1,052.41 24.87
1,115.85 26.38
1,179.10 29.56
1,242.71 33.19
1,306.00 35.45
1,370.26 38.48
1,433.92 40.80
1,497.48 43.88
1,561.06 45.95
1,625.11 47.40
1,687.73 47.03
1,753.03 46.93
1,816.92 46.73
1,880.18 46.54
1,943.18 45.72
2,006.18 43.01
2,070.06 43.96
2,133.72 46.01
2,196.96 45.11
2,261.51 46.43
2,325.05 46.31
2,388.34 47.36
2,451.96 46.33
2,515.25 44.45
2,578.72 43.20
2,642.11 41.94
2,705.53 40.44
2,768.83 38.55
2,832.16 36.68
2,895.77 34.51
2,958.70 32.34
3,022.80 30.60
3,086.00 28.89
3,149.26 28.06
3,212.29 27.12
3,275.87 26.37
3,339.66 25.86
179.28
177.80
178.04
177.81
177.56
177.12
177.33
177.47
176.66
175.06
175.14
175.71
175.79
174.52
174.45
174.62
175.04
175.96
175.87
176.30
176.52
174.20
174.15
172.31
169.58
167.86
165.32
163.15
161.29
159.39
158.06
153.80
150.99
145.14
140.81
134.84
127.75
1,030.93
1,088.12
1,143.98
1,198.28
1,250.55
1,301.89
1,350.90
1,397.88
1,442.90
1,486.85
1,529.38
1,573.94
1,617.65
1,661.08
1,704.74
1,749.78
1,796.13
1,841.15
1,885.43
1,930.45
1,974.30
2,017.60
2,061.11
2,105.56
2,151.35
2,198.04
2,245.76
2,294.61
2,344.78
2,396.50
2,449.02
2,503.70
2,558.57
2,614.19
2,670.05
2,726.84
2,784.13
982.25
1,039.44
1,095.30
1,149.60
1,201.87
1,253.21
1,302.22
1,349.20
1,394.22
1,438.17
1,480.70
1,525.26
1,568.97
1,612.40
1,656.06
1,701.10
1,747.45
1,792.47
1,836.75
1,881.77
1,925.62
1,968.92
2,012.43
2,056.88
2,102.67
2,149.36
2,197.08
2,245.93
2,296.10
2,347.82
2,400.34
2,455.02
2,509.89
2,565.51
2,621.37
2,678.16
2,735.45
-143.70
-171.12
-200.76
-233.85
-269.51
-308.10
-348.66
-391.42
-436.25
-482.72
-528.51
-576.10
-622.57
-668.39
-713.60
-757.44
-801.23
-846.09
-891.12
-937.27
-983.17
-1,029.17
-1,075.34
-1,120.08
-1,163.48
-1,205.53
-1,246.15
-1,284.89
-1,321.70
-1,356.56
-1,388.87
-1,419.41
-1,447.20
-1,472.78
-1,496.08
-1,517.28
-1,535.79
Map
+Ei-W Northing
(usft) (ft)
-20.29 6,015,960.22
-21.01 6,015,939.40
-21.40 6,015,915.95
-21.41 6,015,890.21
-20.70 6,015,862.80
-19.62 6,015,833.17
-18.42 6,015,800.10
-16.98 6,015,764.46
-15.18 6,015,725.89
-13.22 6,015,685.35
-11.28 6,015,642.62
-8.97 6,015,597.81
-5.60 6,015,551.38
-1.67 6,015,505.64
2.13 6,015,458.09
5.59 6,015,411.66
9.47 6,015,365.88
13.84 6,015,320.72
18.03 6,015,276.92
21.99 6,015,233.18
25.52 6,015,188.36
28.73 6,015,143.36
31.89 6,015,097.25
34.77 6,015,051.38
38.51 6,015,005.42
43.22 6,014,959.30
48.52 6,014,914.61
55.42 6,014,871.29
63.80 6,014,829.32
73.47 6,014,788.80
84.39 6,014,750.16
96.18 6,014,713.47
108.62 6,014,678.72
121.19 6,014,646.54
134.80 6,014,616.12
149.31 6,014,588.48
165.23 6,014,563.05
182.78 6,014,539.91
201.95 6,014,518.90
223.00 6,014,500.59
Map Vertical
Easting DLS Section
(ft) (0100•) (ft) Survey Tool Name
569,283.30 3.58 -75.44 2_MWD+IFR2+MS+Sag(1)
569,282.78 4.49 -94.66 2_MWD+IFR2+MS+Sag(1)
569,282.60 2.79 -116.13 2_MWD+IFR2+MS+Sag (1)
569,282.83 3.74 -139.54 2_MWD+IFR2+MS+Sag(1)
569,283.80 2.59 -164.17 2_MWD+IFR2+MS+Sag(1)
569,285.15 5.03 -190.66 2_MWD+IFR2+MS+Sag(1)
569,286.66 5.71 -220.24 2 MWD+IFR2+MS+Sag(1)
569,288.43 3.58 -252.04 2_MWD+IFR2+MS+Sag(1)
569,290.59 4.73 -286.38 2_MWD+IFR2+MS+Sag(1)
569,292.93 3.65 -322.43 2_MWD+IFR2+MS+Sag(1)
569,295.27 4.85 -360.48 2_MWD+IFR2+MS+Sag(1)
569,297.99 3.38 -400.27 2 MWD+IFR2+MS+Sag(1)
569,301.79 2.90 -441.10 2_MWD+IFR2+MS+Sa9(1)
569,306.14 0.60 -481.08 2_MWD+IFR2+MS+Sag(1)
569,310.39 0.66 -522.75 2_MWD+IFR2+MS+Sag(1)
569,314.28 0.33 -563.55 2 MWD+IFR2+MS+Sag(1)
569,318.59 1.49 -603.58 2_MWD+IFR2+MS+Sa9(1)
569,323.37 1.30 -642.85 2_MWD+IFR2+MS+Sag(1)
569,327.97 4.31 -680.96 2_MWD+IFR2+MS+Sag(1)
569,332.34 1.55 -719.10 2_MWD+IFR2+MS+Sag(1)
569,336.28 3.38 -758.41 2_MWD+IFR2+MS+Sag(1)
569,339.92 1.43 -798.00 2_MWD+IFR2+MS+Sag(1)
569,343.50 2.10 -838.63 2_MWD+IFR2+MS+Sag(1)
569,346.81 0.31 -879.15 2_MWD+IFR2+MS+Sag(1)
569,350.98 3.15 -919.41 2_MWD+IFR2+MS+Sag(1)
569,356.12 1.62 -959.41 2_MWD+IFR2+MS+Sag (1)
569,361.83 3.62 -997.86 2_MWD+IFR2+MS+Sag(1)
569,369.14 3.57 -1,034.43 2_MWD+IFR2+MS+Sag(1)
569,377.91 2.71 -1,069.16 2_MWD+IFR2+MS+Sag(1)
569,387.95 3.54 -1,102.05 2_MWD+IFR2+MS+Sag(1)
569,399.23 3.70 -1,132.71 2_MWD+IFR2+MS+Sag(1)
569,411.36 3.45 -1,161.25 2_MWD+IFR2+MS+Sag (1)
569,424.12 3.83 -1,187.76 2_MWD+IFR2+MS+Sag (1)
569,436.99 3.64 -1,211.88 2_MWD+IFR2+MS+Sag(1)
569,450.88 4.40 -1,233.97 2_MWD+IFR2+MS+Sag(1)
569,465.65 3.49 -1,253.18 2_MWD+IFR2+MS+Sag(1)
569,481.80 4.60 -1,269.79 2_MWD+IFR2+MS+Sag(1)
569,499.57 3.51 -1,283.65 2_MWD+IFR2+MS+Sag(1)
569,518.94 4.39 -1,294.92 2_MWD+IFR2+MS+Sag(1)
569,540.16 4.95 -1,302.97 2_MWD+IFR2+MS+Sag(1)
4/82019 12:45..00PM Page 3 COMPASS 5000.15 Build 91
Survey
Halliburton
Definitive Survey Report
Map
Company:
Hilcorp Alaska, LLC
Local Co-ordinate Reference:
Well MPU E41
Project:
Milne Point
TVD Reference:
MPU E-41 Actual IRKS @ 48.68usft
Site:
M Pt E Pad
MD Reference:
MPU E-41 Actual RKB @ 48.68usft
Well:
MPU E41
North Reference:
True
Wellbore:
MPU E-41PB2
Survey Calculation Method:
Minimum Curvature
Design:
MPU E41 PB2
Database:
NORTH US+CANADA
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/ -S
+EI -W
Northing
Easting
DLS
Section
(usft)
V)
0
(usft)
(usft)
(usft)
(usft)
(ft)
(ft)
01001)
(ft) Survey Tool Name
3,402.70
25.49
121.18
2,840.96
2,792.28
-1,551.23
245.48
6,014,485.36
569,562.78
4.55
-1,307.64 2_MWD+IFR2+MS+Sag(1)
3,466.50
24.90
114.67
2,898.70
2,850.02
-1,563.95
269.44
6,014,472.87
569,586.85
4.44
-1,309.21 2_MWD+IFR2+MS+Sag(1)
3,530.63
24.24
108.29
2,957.04
2,908.36
-1,573.71
294.21
6,014,463.33
569,611.71
4.26
-1,307.76 2_MWD+IFR2+MS+Sag(1)
3,594.08
23.52
101.73
3,015.06
2,966.38
-1,580.38
318.98
6,014,456.90
569,636.53
4.33
-1,303.49 2_MWD+IFR2+MS+Sag(1)
3,657.89
23.33
94.76
3,073.63
3,024.95
-1,584.01
344.04
6,014,453.49
569,661.63
4.35
-1,296.35 2_MWD+IFR2+MS+Sag(1)
3,721.90
22.45
89.43
3,132.60
3,083.92
-1,584.94
368.90
6,014,452.80
569,686.49
3.52
-1,286.83 2_MWD+IFR2+MS+Sag(1)
3,785.60
22.53
84.07
3,191.46
3,142.78
-1,583.56
393.20
6,014,454.40
569,710.78
3.22
-1,275.44 2_MWD+IFR2+MS+Sag(1)
3,849.10
24.60
79.54
3,249.67
3,200.99
-1,579.91
418.30
6,014,458.29
569,735.84
4.33
-1,261.65 2_MWD+IFR2+MS+Sag(1)
3,912.81
26.73
76.56
3,307.09
3,258.41
-1,574.17
445.28
6,014,464.28
569,762.76
3.91
-1,245.19 2_MWD+IFR2+MS+Sag(1)
3,977.03
28.88
72.24
3,363.90
3,315.22
-1,566.08
474.11
6,014,472.64
569,791.51
4.59
-1,225.82 2_MWD+IFR2+MS+Sag(1)
4,040.71
30.71
68.76
3,419.16
3,370.48
-1,555.49
503.91
6,014,483.50
569,821.21
3.95
-1,203.77 2_MWD+IFR2+MS+Sag (1)
4,103.85
33.11
65.28
3,472.76
3,424.08
-1,542.44
534.61
6,014,496.84
569,851.78
4.79
-1,179.10 2_MWD+IFR2+MS+Sag(1)
4,166.87
35.40
61.22
3,524.86
3,476.18
-1,526.45
566.25
6,014,513.12
569,883.27
5.13
-1,151.38 2_MWD+IFR2+MS+Sag(1)
4,230.97
37.00
55.28
3,576.60
3,527.92
-1,506.52
598.39
6,014,533.35
569,915.22
6.01
-1,119.86 2_MWD+IFR2+MS+Sag(1)
4,294.42
39.64
50.52
3,626.38
3,577.70
-1,482.76
629.72
6,014,557.39
569,946.32
6.24
-1,085.21 2_MWD+IFR2+MS+Sag(1)
4,358.31
40.49
49.48
3,675.28
3,626.60
-1,456.33
661.22
6,014,584.11
569,977.57
1.69
-1,048.05 2_MWD+IFR2+MS+Sag(1)
4,421.50
41.97
49.05
3,722.80
3,674.12
-1,429.15
692.77
6,014,611.58
570,008.87
2.38
-1,010.19 2_MWD+IFR2+MS+Sag(1)
4,484.19
44.43
47.54
3,768.50
3,719.82
-1,400.59
724.80
6,014,640.43
570,040.63
4.26
-970.88 2_MWD+IFR2+MS+Sag(1)
4,548.16
46.38
46.03
3,813.41
3,764.73
-1,369.40
757.99
6,014,671.93
570,073.52
3.48
-928.69 2_MWD+IFR2+MS+Sag(1)
4,610.88
47.71
42.55
3,856.16
3,807.48
-1,336.54
790.02
6,014,705.08
570,105.24
4.58
-885.47 2_MWD+IFR2+MS+Sag(1)
4,675.06
49.98
41.77
3,898.39
3,849.71
-1,300.72
822.45
6,014,741.20
570,137.33
3.65
-839.39 2_MWD+IFR2+MS+Sag(1)
4,738.87
52.14
39.64
3,938.49
3,889.81
-1,263.09
854.80
6,014,779.12
570,169.33
4.27
-791.70 2_MWD+IFR2+MS+Sag(1)
4,801.16
53.56
38.80
3,976.11
3,927.43
-1,224.63
886.19
6,014,817.87
570,200.36
2.52
-743.65 2_MWD+IFR2+MS+Sag(1)
4,866.10
55.24
36.77
4,013.92
3,965.24
-1,182.89
918.53
6,014,859.90
570,232.30
3.63
-692.24 2_MWD+IFR2+MS+Sag(1)
4,929.55
58.12
36.15
4,048.77
4,000.09
-1,140.25
950.03
6,014,902.83
570,263.40
4.61
-640.35 2_MWD+IFR2+MS+Sag(1)
4,993.55
61.72
34.84
4,080.84
4,032.16
-1,095.17
982.17
6,014,948.21
570,295.12
5.90
-585.97 2_MWD+IFR2+MS+Sag(1)
5,057.07
64.09
33.55
4,109.77
4,061.09
-1,048.40
1,013.94
6,014,995.27
570,326.45
4.15
-530.21 2_MWD+IFR2+MS+Sag(1)
5,121.65
66.94
31.38
4,136.54
4,087.86
-998.81
1,045.47
6,015,045.14
570,357.52
5.37
-471.99 2_MWD+IFR2+MS+Sag(1)
5,184.60
70.11
29.08
4,159.58
4,110.90
-948.20
1,074.95
6,015,096.02
570,386.52
6.08
-413.70 2_MWD+IFR2+MS+Sag(1)
5,248.92
71.09
26.38
4,180.95
4,132.27
-894.51
1,103.17
6,015,149.97
570,414.24
4.24
-353.13 2_MWD+IFR2+MS+Sag(1)
5,312.82
72.56
24.27
4,200.88
4,152.20
-839.63
1,129.13
6,015,205.08
570,439.69
3.89
-292.43 2_MWD+IFR2+MS+Sag(1)
5,377.20
75.37
22.37
4,218.66
4,169.98
-782.82
1,153.62
6,015,262.11
570,463.64
5.21
-230.58 2_MWD+IFR2+MS+Sag(1)
5,440.05
78.95
22.08
4,232.63
4,183.95
-726.10
1,176.79
6,015,319.04
570,486.28
5.71
-169.36 2 MWD+IFR2+MS+Sag(1)
5,504.06
80.89
21.74
4,243.83
4,195.15
-667.63
1,200.31
6,015,377.71
570,509.25
3.08
-106.41 2_MWD+IFR2+MS+Sag(1)
5,567.21
81.76
21.47
4,253.36
4,204.68
-609.59
1,223.29
6,015,435.96
570,531.69
1.44
-44.08 2_MWD+IFR2+MS+Sag(1)
5,630.75
81.78
21.51
4,262.45
4,213.77
-551.08
1,246.33
6,015,494.68
570,554.18
0.07
18.72 2_MWD+IFR2+MS+Sag(1)
5,694.14
83.55
20.99
4,270.55
4,221.87
-492.48
1,269.12
6,015,553.48
570,576.42
2.91
81.47 2_MWD+IFR2+MS+Sag(1)
5,756.66
83.02
21.76
4,277.86
4,229.18
434.66
1,291.75
6,015,611.50
570,598.51
1.49
143.46 2_MWD+IFR2+MS+Sag(1)
5,820.97
83.25
21.40
4,285.54
4,236.86
-375.29
1,315.23
6,015,671.08
570,621.44
0.66
207.22 2_MWD+IFR2+MS+Sag(1)
5,884.39
80.69
22.04
4,294.40
4,245.72
-316.96
1,338.47
6,015,729.63
570,644.13
4.16
269.93 2_MWD+IFR2+MS+Sag(1)
4/&2019 12:45:OOPM
Page 4
COMPASS 5000.15 Build 91
Halliburton
Definitive Survey Report
Company:
Hiloorp Alaska, LLC
Local Co-ordinate Reference: Well MPU E-41
Project:
Milne Point
TVD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Site:
M Pt E Pad
MD Reference:
MPU
E41 Actual RKB @ 48.68usft
Well:
MPU
E-41
North Reference:
True
Wellbore:
MPU
E-41 PB2
Survey Calculation Method: Minimum Curvature
Design:
MPU
E -41P82
Database:
NORTH US+CANADA
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+Nl-S
+E/ -W
Northing
Easting
DLS
Section
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft) (°/100')
(ft) Survey Tool Name
5,947.90
79.61
22.63
4,305.27
4,256.59
-259.08
1,362.24
6,015,787.72
570,667.37
1.93
332.45 2_MWD+IFR2+MS+Sag (1)
6,011.22
81.05
22.81
4,315.90
4,267.22
-201.50
1,386.35
6,015,845.51
570,690.94
2.29
394.84 2_MWD+IFR2+MS+Sag (1)
6,074.43
82.39
23.14
4,325.00
4,276.32
-143.91
1,410.77
6,015,903.32
570,714.81
2.18
457.36 2_MWD+IFR2+MS+Sag(1)
6,138.46
82.22
22.76
4,333.58
4,284.90
-85.48
1,435.51
6,015,961.97
570,739.01
0.65
520.79 2 MWD+IFR2+MS+Sag(1)
6,202.49
81.97
22.69
4,342.38
4,293.70
-26.99
1,460.01
6,016,020.69
570,762.96
0.41
584.17 2_MWD+IFR2+MS+Sag(1)
6,265.42
83.63
21.33
4,350.27
4,301.59
30.90
1,483.41
6,016,078.78
570,785.81
3.40
646.54 2_MWD+IFR2+MS+Sag(1)
6,328.74
84.02
19.26
4,357.08
4,308.40
89.94
1,505.24
6,016,138.01
570,807.10
3.31
709.30 2_MWD+IFR2+MS+Sag(1)
6,392.15
87.14
20.35
4,361.97
4,313.29
149.41
1,526.66
6,016,197.68
570,827.96
5.21
772.29 2_MWD+IFR2+MS+Sag(1)
6,445.25
91.49
21.03
4,362.60
4,313.92
199.07
1,545.41
6,016,247.51
570,846.25
8.29
825.25 2_MWD+IFR2+MS+Sag(1)
6,510.90
93.54
20.93
4,359.72
4,311.04
260.30
1,568.89
6,016,308.95
570,869.16
3.13
890.70 2_MWD+IFR2+MS+Sag (2)
6,575.22
93.34
21.55
4,355.86
4,307.18
320.15
1,592.15
6,016,369.00
570,891.86
1.01
954.79 2_MWD+IFR2+MS+Sag (2)
6,638.60
92.53
21.60
4,352.62
4,303.94
379.01
1,615.43
6,016,428.07
570,914.58
1.28
1,018.00 2_MWD+IFR2+MS+Sag (2)
6,702.90
91.79
21.10
4,350.20
4,301.52
438.85
1,638.82
6,016,488.12
570,937.41
1.39
1,082.14 2_MWD+IFR2+MS+Sag (2)
6,766.55
91.98
20.66
4,348.10
4,299.42
498.29
1,661.50
6,016,547.77
570,959.53
0.75
1,145.62 2_MWD+IFR2+MS+Sag(2)
6,829.16
91.98
20.81
4,345.94
4,297.26
556.81
1,683.65
6,016,606.48
570,981.14
0.24
1,208.05 2_MWD+IFR2+MS+Sag(2)
6,892.72
91.36
20.86
4,344.09
4,295.41
616.19
1,706.25
6,016,666.06
571,003.18
0.98
1,271.44 2_MWD+IFR2+MS+Sag(2)
6,956.48
90.06
20.22
4,343.30
4,294.62
675.89
1,728.61
6,016,725.96
571,024.99
2.27
1,335.03 2_MWD+IFR2+MS+Sag(2)
7,019.74
90.19
20.08
4,343.16
4,294.48
735.28
1,750.41
6,016,785.55
571,046.23
0.30
1,398.10 2_MWD+IFR2+MS+Sag(2)
7,083.36
89.32
19.65
4,343.43
4,294.75
795.11
1,772.02
6,016,845.57
571,067.28
1.53
1,461.50 2_MWD+IFR2+MS+Sag(2)
7,146.87
89.08
21.15
4,344.32
4,295.64
854.63
1,794.16
6,016,905.29
571,088.86
2.39
1,524.82 2_MWD+IFR2+MS+Sag(2)
7,210.62
89.45
22.29
4,345.14
4,296.46
913.85
1,817.75
6,016,964.72
571,111.90
1.88
1,588.48 2_MWD+IFR2+MS+Sag(2)
7,273.37
89.20
22.23
4,345.87
4,297.19
971.92
1,841.52
6,017,023.00
571,135.12
0.41
1,651.18 2_MWD+IFR2+MS+Sag(2)
7,337.00
90.19
22.27
4,346.21
4,297.53
1,030.81
1,865.61
6,017,082.11
571,158.67
1.56
1,714.75 2_MWD+IFR2+MS+Sag(2)
7,399.99
90.87
22.75
4,345.63
4,296.95
1,089.00
1,889.72
6,017,140.51
571,182.24
1.32
1,777.69 2_MWD+IFR2+MS+Sag(2)
7,463.53
91.80
22.17
4,344.15
4,295.47
1,147.70
1,913.99
6,017,199.43
571,205.95
1.72
1,841.17 2_MWD+IFR2+MS+Sag (2)
7,468.00
91.55
21.62
4,344.02
4,295.34
1,151.84
1,915.66
6,017,203.59
571,207.58
13.51
1,845.63 2_MWD+IFR2+MS+Sag (3)
7,523.45
89.81
22.77
4,343.36
4,294.68
1,203.18
1,936.60
6,017,255.12
571,228.05
3.76
1,901.02 2_MWD+IFR2+MS+Sag(3)
7,586.59
88.77
22.70
4,344.14
4,295.46
1,261.41
1,961.00
6,017,313.56
571,251.90
1.65
1,964.12 2_MWD+IFR2+MS+Sag(3)
7,650.03
89.26
22.15
4,345.23
4,296.55
1,320.04
1,985.20
6,017,372.41
571,275.55
1.16
2,027.51 2_MWD+IFR2+MS+Sag(3)
7,713.40
90.62
23.31
4,345.30
4,296.62
1,378.49
2,009.68
6,017,431.08
571,299.49
2.82
2,090.84 2_MWD+IFR2+MS+Sag (3)
7,777.66
91.92
23.82
4,343.88
4,295.20
1,437.37
2,035.37
6,017,490.20
571,324.62
2.17
2,155.07 2 MWD+IFR2+MS+Sag (3)
7,840.81
93.28
22.00
4,341.01
4,292.33
1,495.48
2,059.92
6,017,548.52
571,348.63
3.60
2,218.12 2_MWD+IFR2+MS+Sag (3)
7,904.52
92.34
19.98
4,337.89
4,289.21
1,554.88
2,082.72
6,017,608.13
571,370.87
3.49
2,281.62 2_MWD+IFR2+MS+Sag(3)
7,968.09
92.23
18.20
4,335.35
4,286.67
1,614.91
2,103.49
6,017,668.34
571,391.08
2.80
2,344.84 2_MWD+IFR2+MS+Sag(3)
8,032.32
92.48
18.09
4,332.71
4,284.03
1,675.89
2,123.47
6,017,729.50
571,410.50
0.43
2,408.60 2_MWD+IFR2+MS+Sag (3)
8,096.14
92.91
18.37
4,329.71
4,281.03
1,736.44
2,143.42
6,017,790.23
571,429.87
0.80
2,471.96 2_MWD+IFR2+MS+Sag (3)
8,160.13
91.98
18.92
4,326.98
4,278.30
1,797.02
2,163.86
6,017,850.99
571,449.74
1.69
2,535.54 2_MWD+IFR2+MS+Sag(3)
8,223.95
90.12
19.81
4,325.81
4,277.13
1,857.21
2,185.01
6,017,911.37
571,470.34
3.23
2,599.07 2_MWD+IFR2+MS+Sag(3)
8,286.19
88.08
20.40
4,326.79
4,278.11
1,915.65
2,206.40
6,017,970.00
571,491.18
3.41
2,661.11 2_MWD+1FR2+MS+Sag (3)
8,350.27
88.34
20.41
4,328.79
4,280.11
1,975.68
2,228.74
6,018,030.23
571,512.95
0.41
2,724.98 2_MWD+IFR2+MS+Sag (3)
4/82019 12.45:OOPM
Page 5
COMPASS 5000.15 Build 91
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt E Pad
Well:
MPU E-41
Wellbore:
MPU E-41 PB2
Design:
MPU E-41 PB2
Survey
Halliburton
Definitive Survey Report
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well MPU E41
MPU E41 Actual RKB @ 48.68usft
MPU E-41 Actual RKB @ 48.68usft
True
Minimum Curvature
NORTH US + CANADA
Map Map
MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting DLS
(usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) (`/100')
8,414.01 88.46 21.73 4,330.57 4,281.89 2,035.13 2,251.64 6,018,089.89 571,535.30 2.08
8,478.39 87.16 22.54 4,333.03 4,284.35 2,094.72 2,275.88 6,018,149.69 571,558.98 2.38
8,541.67 87.66 22.72 4,335.89 4,287.21 2,153.07 2,300.20 6,018,208.26 571,582.76 0.84
8,604.52 86.91 22.45 4,338.87 4,290.19 2,211.04 2,324.31 6,018,266.44 571,606.33 1.27
8,667.96 87.22 21.96 4,342.12 4,293.44 2,269.69 2,348.26 6,018,325.31 571,629.72 0.91
8,730.33 88.90 20.94 4,344.23 4,295.55 2,327.71 2,371.05 6,018,383.53 571,651.98 3.15
8,794.42 89.14 21.35 4,345.33 4,296.65 2,387.47 2,394.17 6,018,443.50 571,674.53 0.74
8,858.29 88.27 20.78 4,346.77 4,298.09 2,447.06 2,417.12 6,018,503.29 571,696.93 1.63
8,921.33 88.89 20.77 4,348.33 4,299.65 2,505.98 2,439.47 6,018,562.42 571,718.73 0.98
8,985.82 91.31 19.43 4,348.22 4,299.54 2,566.54 2,461.63 6,018,623.17 571,740.32 4.29
9,049.11 91.86 19.66 4,346.47 4,297.79 2,626.16 2,482.80 6,018,682.98 571,760.93 0.94
9,112.21 92.29 19.54 4,344.18 4,295.50 2,685.56 2,503.95 6,018,742.57 571,781.53 0.71
9,176.51 92.29 18.28 4,341.61 4,292.93 2,746.34 2,524.77 6,018,803.54 571,801.78 1.96
9,239.77 93.53 15.55 4,338.40 4,289.72 2,806.78 2,543.15 6,018,864.14 571,819.60 4.73
9,303.94 93.40 14.63 4,334.52 4,285.84 2,868.63 2,559.83 6,018,926.13 571,836.69 1 A
9,367.57 93.46 14.10 4,330.72 4,282.04 2,930.16 2,575.59 6,018,987.80 571,850.88 0.84
9,458.00 93.46 14.10 4,325.26 4,276.58 3,017.70 2,597.58 6,019,075.53 571,872.05 0.00
vertical
Section
(ft) Survey Tool Name
2,788.57 2_MWD+IFR2+MS+Sag (3)
2,852.84 2_MWD+IFR2+MS+Sag (3)
2,916.02 2_MWD+IFR2+MS+Sag (3)
2,978.75 2_MWD+IFR2+MS+Sag(3)
3,042.05 2_MWD+IFR2+MS+Sag(3)
3,104.29 2_MWD+IFR2+MS+Sag(3)
3,168.25 2_MWD+IFR2+MS+Sag (3)
3,231.98 2_MWD+IFR2+MS+Sag (3)
3,294.65 2_MWD+IFR2+MS+Sag(3)
3,359.14 2_MWD+IFR2+MS+Sag(3)
3,422.15 2_MWD+IFR2+MS+Sag(3)
3,484.97 2_MWD+IFR2+MS+Sag(3)
3,548.89 2_MWD+IFR2+MS+Sag (3)
3,611.49 2_MWD+IFR2+MS+Sag (3)
3,674.66 2_MWD+IFR2+MS+Sag (3)
3,737.15 2_MWD+IFR2+MS+Sag (3)
3,825.89 PROJECTEDto TD
Checked By: Chelsea Wright :ww Approved By: Mitch Laird _-- Date: 04-08-2019
4/&2019 12:45.00PM Page 6 COMPASS 5000.15 Build 91
Hilcorp Alaska, LLC
Milne Point
MPtEPad
MPU E-41PB3
500292362272
Sperry Drilling
Definitive Survey Report
08 April, 2019
HALLIBURTON
Sperry Drilling
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt E Pad
Well:
MPU E-41
Wellbore:
MPU E-41 PB3
Design:
MPU E-41 P133
Halliburton
Definitive Survey Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well MPU E-41
MPU E-41 Actual RKB @ 48.68usft
MPU E-41 Actual RKB @ 48.68usft
True
Minimum Curvature
NORTH US + CANADA
Project Milne Point, ACT, MILNE POINT
Map System; US Stale Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Well MPU E-41
Well Position +N/ -S
+E/ -W
Position Uncertainty
Wellbore MPU E-41PB3
Magnetics Model Name
0.00 usft Northing: 6,016,034.09 usfl
0.00 usft Easting: 569,302.90 usfl
0.00 usfl Wellhead Elevation: 0.00 usfl
Sample Date Declination
(°)
BGGM2018 3/1/2019
Design MPU E-41PB3
Audit Notes:
Version: 1.0 Phase: ACTUAL
Vertical Section: Depth From (TVD) +N/ -S
(usft) (usfl)
26.88 0.00
16.82
Latitude: 70° 27'14.9809 N
Longitude: 149° 26'4.0913 W
Ground Level: 21.80 usft
Dip Angle Field Strength
(9 (nT)
80.97 57,437.46943635
Tie On Depth: 7,777.66
+EI -W Direction
(usft) (°)
0.00 24.64
Survey Program Date 4/8/2019
From To
(usft) (usft) Survey (Wellbore) Tool Name Description Survey Date
166.70 6,445.25 MPU E-41 P81 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 03/09/2019
6,510.90 7,463.53 MPU E-41PB1 MWD+IFR2+MS+Sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 03/27/2019
7,468.00 7,777.66 MPU E-41 PB2 MWD+IFR2+MS+Sag (3) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec 8 multi -station analysis + sa 03/27/2019
7,800.00 11,780.45 MPU E-41 P133 MWD+IFR2+MS+Sag (4) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 03/27/2019
Survey
Map
Map
Vertical
MD
(usft)
Inc
(°)
Azi
(1
TVD
(usft)
TVDSS
(usfl)
+N/ -S
(usft)
+E/ -W
(usfl)
Northing
(ft)
Easting
(ft)
DLS
(°1100')
Section
(ft) Survey Tool Name
26.88
0.00
0.00
26.88
-21.80
0.00
0.00
6,016,034.09
569,302.90
0.00
0.00 UNDEFINED
166.70
0.32
31.78
166.70
118.02
0.33
0.21
6,016,034.42
569,303.10
0.23
0.39 2_MWD+IFR2+MS+Sag(1)
234.53
0.70
25.93
234.53
185.85
0.87
0.49
6,016,034.96
569,303.38
0.56
0.99 2_MWD+IFR2+MS+Sag(1)
298.36
0.23
352.54
298.35
249.67
1.34
0.64
6,016,035.44
569,303.53
0.82
1.49 2_MWD+IFR2+MS+Sag(1)
360.02
1.96
234.46
360.00
311.32
0.85
-0.23
6,016,034.94
569,302.66
3.37
0.68 2 MWD+IFR2+MS+Sag(1)
422.85
3.44
229.11
422.76
374.08
-1.01
-2.53
6,016,033.06
569,300.38
2.39
-1.97 2_MWD+IFR2+MS+Sag(1)
483.92
5.23
217.83
483.66
434.98
4.40
-5.63
6,016,029.63
569,297.32
3.23
.6.35 2_MWD+IFR2+MS+Sag(1)
545.26
6.80
210.08
544.66
495.98
-9.75
-9.16
6,016,024.25
569,293.83
2.88
-12.69 2_MWD+IFR2+MS+Sag(1)
607.29
8.36
201.84
606.14
557.46
-17.12
.12.68
6,016,016.86
569,290.38
3.06
-20.85 2 MWD+IFR2+MS+Sag(1)
670.20
10.22
192.00
668.23
619.55
-26.82
.15.54
6,016,007.12
569,287.61
3.88
-30.86 2_MWD+IFR2+MS+Sag(1)
73385
12.70
186.32
730.61
681.93
39.30
-17.49
6,015,994.63
569,285.78
4.28
-43.02 2_MWD+IFR2+MS+Sag(1)
4/8/2019 12:46:45PM
Page
2
COMPASS 5000.15 Build 91
Company:
Project:
Site:
Well:
Wellbore:
Design:
Survey
Halliburton
Definitive Survey Report
Hilcorp Alaska, LLC
Local Coordinate Reference:
Milne Point
TVD Reference:
M Pt E Pad
MD Reference:
MPU E-41
North Reference:
MPU E-41 P133
Survey Calculation Method:
MPU E-41 PB3
Database:
Well MPU E-41
MPU E-41 Actual RKB @ 48.68usft
MPU E-41 Actual RKB @ 48.68usft
True
Minimum Curvature
NORTH US + CANADA
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/ -S
+EI -W
Northing
Easting
DLS
Section
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft)
('1100')
(ft)
Survey Tool Name
798.32
15.83
184.91
793.08
744.40
-55.11
-19.02
6,015,978.81
569,284.40
4.88
-58.02
2_MWD+IFR2+MS+Sag(1)
862.23
18.05
183.01
854.22
805.54
-73.69
-20.29
6,015,960.22
569,283.30
3.58
-75.44
2_MWD+IFR2+MS+Sag(1)
924.89
20.79
181.09
913.31
864.63
-94.50
-21.01
6,015,939.40
569,282.78
4.49
-94.66
2_MWD+IFR2+MS+Sag(1)
988.39
22.56
180.83
972.31
923.63
-117.95
-21.40
6,015,915.95
569,282.60
2.79
.116.13
2_MWD+IFR2+MS+Sag(1)
1,052.41
24.87
179.28
1,030.93
982.25
-143.70
-21.41
6,015,890.21
569,282.83
3.74
-139.54
2_MWD+IFR2+MS+Sag(1)
1,115.65
26.38
177.80
1,088.12
1,039.44
-171.12
-20.70
6,015,862.80
569,283.80
2.59
-164.17
2_MWD+IFR2+MS+Sag(1)
1,179.10
29.56
178.04
1,143.98
1,095.30
-200.76
-19.62
6,015,833.17
569,285.15
5.03
-190.66
2_MWD+IFR2+MS+Sag(1)
1,242.71
33.19
177.81
1,198.28
1,149.60
-233.85
-18.42
6,015,800.10
569,286.66
5.71
.220.24
2_MWD+IFR2+MS+Sag(1)
1,306.00
35.45
177.56
1,250.55
1,201.87
-269.51
-16.98
6,015,764.46
569,288.43
3.58
-252.04
2_MWD+IFR2+MS+Sag(1)
1,370.26
38.48
177.12
1,301.89
1,253.21
-308.10
-15.18
6,015,725.89
569,290.59
4.73
-286.38
2_MWD+IFR2+MS+Sag(1)
1,433.92
40.80
177.33
1,350.90
1,302.22
-348.66
-13.22
6,015,685.35
569,292.93
3.65
-322.43
2_MWD+IFR2+MS+Sag(1)
1,497.48
43.88
177.47
1,397.88
1,349.20
-391.42
-11.28
6,015,642.62
569,295.27
4.85
-360.48
2 MWD+IFR2+MS+Sag(1)
1,561.06
45.95
176.66
1,442.90
1,394.22
436.25
-8.97
6,015,597.81
569,297.99
3.38
.400.27
2_MWD+IFR2+MS+Sag(1)
1,625.11
47.40
175.06
1,486.85
1,438.17
.482.72
-5.60
6,015,551.38
569,301.79
2.90
-441.10
2_MWD+IFR2+MS+Sag(1)
1,687.73
47.03
175.14
1,529.38
1,480.70
-528.51
-1.67
6,015,505.64
569,306.14
0.60
-481.08
2_MWD+IFR2+MS+Sag(1)
1,753.03
46.93
175.71
1,573.94
1,525.26
-576.10
2.13
6,015,458.09
569,310.39
0.66
-522.75
2_MWD+IFR2+MS+Sag(1)
1,816.92
46.73
175.79
1,617.65
1,568.97
-622.57
5.59
6,015,411.66
569,314.28
0.33
-563.55
2_MWD+IFR2+MS+Sag(1)
1,880.18
46.54
174.52
1,661.08
1,612.40
-668.39
9.47
6,015,365.88
569,318.59
1.49
-603.58
2_MWD+IFR2+MS+Sag(1)
1,943.18
45.72
174.45
1,704.74
1,656.06
-713.60
13.84
6,015,320.72
569,323.37
1.30
-642.85
2 MWD+IFR2+MS+Sag(1)
2,006.18
43.01
174.62
1,749.78
1,701.10
-75744
18.03
6,015,276.92
569,327.97
4.31
-680.96
2_MWD+IFR2+MS+Sag(1)
2,070.06
43.96
175.04
1,796.13
1,747.45
-801.23
21.99
6,015,233.18
569,332.34
1.55
-719.10
2_MWD+IFR2+MS+Sag(1)
2,133.72
46.01
175.96
1,841.15
1,792.47
-846.09
25.52
6,015,188.36
569,336.28
3.38
-758.41
2_MWD+IFR2+MS+Sag(1)
2,196.96
45.11
175.87
1,885.43
1,836.75
-891.12
28.73
6,015,143.36
569,339.92
1.43
-798.00
2_MWD+IFR2+MS+Sag(1)
2,261.51
46.43
176.30
1,930.45
1,881.77
.937.27
31.89
6,015,097.25
569,343.50
2.10
-838.63
2_MWD+IFR2+MS+Sag(1)
2,325.05
46.31
176.52
1,974.30
1,925.62
-983.17
34.77
6,015,051.38
569,346.81
0.31
-879.15
2_MWD+IFR2+MS+Sag(1)
2,388.34
47.36
174.20
2,017.60
1,968.92
-1,029.17
38.51
6,015,005.42
569,350.98
3.15
-919.41
2_MWD+IFR2+MS+Sag(1)
2,451.96
46.33
174.15
2,061.11
2,012.43
-1,075.34
43.22
6,014,959.30
569,356.12
1.62
-959.41
2_MWD+IFR2+MS+Sag(1)
2,515.25
44.45
172.31
2,105.56
2,056.88
-1,120.08
48.52
6,014,914.61
569,361.83
3.62
-997.86
2_MWD+IFR2+MS+Sag(1)
2,578.72
43.20
169.58
2,151.35
2,102.67
-1,163.48
55.42
6,014,87129
569,369.14
3.57
-1,034.43
2_MWD+IFR2+MS+Sag(1)
2,642.11
41.94
167.86
2,198.04
2,149.36
-1,205.53
63.80
6,014,829.32
569,377.91
2.71
-1,069.16
2_MWD+IFR2+MS+Sag(1)
2,705.53
40.44
165.32
2,245.76
2,197.08
-1,246.15
73.47
6,014,788.80
569,387.95
3.54
-1,102.05
2_MWD+IFR2+MS+Sag(1)
2,768.83
38.55
163.15
2,294.61
2,245.93
-1,284.89
84.39
6,014,750.16
569,399.23
3.70
-1,132.71
2_MWD+IFR2+MS+Sag(1)
2,832.16
36.68
161.29
2,344.78
2,296.10
-1,321.70
96.18
6,014,713.47
569,411.36
3.45
-1,161.25
2_MWD+IFR2+MS+Sag (1)
2,895.77
34.51
159.39
2,396.50
2,347.82
-1,356.56
108.62
6,014,678.72
569,424.12
3.83
-1,187.76
2_MWD+IFR2+MS+Sag (1)
2,958.70
32.34
158.06
2,449.02
2,400.34
-1,388.87
121.19
6,014,646.54
569,436.99
3.64
.1,211.88
2_MWD+IFR2+MS+Sag (1)
3,022.80
30.60
153.80
2,503.70
2,455.02
-1,41941
134.80
6,014,616.12
569,450.88
4.40
-1,233.97
2 MWD+IFR2+MS+Sag(1)
3,086.00
28.89
150.99
2,558.57
2,509.89
-1,447.20
149.31
6,014,588.48
569,465.65
3.49
-1,253.18
2_MWD+IFR2+MS+Sag(1)
3,149.26
28.06
145.14
2,614.19
2,565.51
-1,472.78
165.23
6,014,563.05
569,481.80
4.60
-1,269.79
2_MWD+IFR2+MS+Sag(1)
3,212.29
27.12
140.81
2,670.05
2,621.37
-1,496.08
182.78
6,014,539.91
569,499.57
3.51
-1,283.65
2_MWD+IFR2+MS+Sag(1)
3,275.87
26.37
134.84
2,726.84
2,678.16
-1,517.28
201.95
6,014,518.90
569,518.94
4.39
-1,294.92
2_MWD+IFR2+MS+Sag(1)
482019 12:46:45PM
Page 3
COMPASS 5000.15 Build 91
Halliburton
Definitive
Survey Report
Company:
Hilcorp Alaska,
LLC
Local Co-ordinate Reference: Well
MPU E-41
Project:
Milne Point
TVD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Site:
M Pt
E Pad
MD Reference:
MPU
E-41 Actual RKB @ 48.68usft
Well:
MPU
E-41
North Reference:
True
Wellbore:
MPU
E-41PB3
Survey Calculation Method:
Minimum
Curvature
Design:
MPU
E-41PB3
Database:
NORTH
US+CANADA
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/-S
+EI-W
Northing
Easting
DLS
Section
(usft)
(°)
(`)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft) (°1700')
(ft) Survey Tool Name
3,339.66
25.86
127.75
2,784.13
2,735.45
-1,535.79
223.00
6,014,500.59
569,540.16
4.95
-1,302.97 2_MWD+IFR2+MS+Sag (1)
3,402.70
25.49
121.18
2,840.96
2,792.28
-1,551.23
245.48
6,014,485.36
569,562.78
4.55
-1,307.64 2_MWD+IFR2+MS+Sag(1)
3,466.50
24.90
114.67
2,898.70
2,850.02
-1,563.95
269.44
6,014,472.87
569,586.85
4.44
-1,309.21 2_MWD+IFR2+MS+Sag(1)
3,530.63
24.24
108.29
2,957.04
2,908.36
-1,573.71
294.21
6,014,463.33
569,611.71
4.26
-1,307.76 2_MWD+IFR2+MS+Sag(1)
3,594.08
23.52
101.73
3,015.06
2,966.38
-1,580.38
318.98
6,014,456.90
569,636.53
4.33
-1,303.49 2 MWD+IFR2+MS+Sag(1)
3,657.89
23.33
94.76
3,073.63
3,024.95
-1,584.01
344.04
6,014,453.49
569,661.63
4.35
-1,296.35 2_MWD+IFR2+MS+Sag(1)
3,721.90
22.45
89.43
3,132.60
3,083.92
-1,584.94
368.90
6,014,452.80
569,686.49
3.52
-1,286.83 2_MWD+IFR2+MS+Sag(1)
3,785.60
22.53
84.07
3,191.46
3,142.78
-1,583.56
393.20
6,014,454.40
569,710.78
3.22
-1,275.44 2_MWD+IFR2+MS+Sag(1)
3,849.10
24.60
79.54
3,249.67
3,200.99
-1,579.91
418.30
6,014,458.29
569,735.84
4.33
A,261.65 2_MWD+IFR2+MS+Sag(1)
3,912.81
26.73
76.56
3,307.09
3,258.41
-1,574.17
445.28
6,014,464.28
569,762.76
3.91
-1,245.19 2_MWD+IFR2+MS+Sag(1)
3,977.03
28.88
72.24
3,363.90
3,315.22
-1,566.08
474.11
6,014,472.64
569,791.51
4.59
-1,225.82 2_MWD+IFR2+MS+Sag(1)
4,040.71
30.71
68.76
3,419.16
3,370.48
-1,555.49
503.91
6,014,483.50
569,821.21
3.95
-1,203.77 2_MWD+IFR2+MS+Sag(1)
4,103.85
33.11
65.28
3,472.76
3,424.08
-1,542.44
534.61
6,014,496.84
569,851.78
4.79
-1,179.10 2_MWD+IFR2+MS+Sag(1)
4,166.87
35.40
61.22
3,524.86
3,476.18
-1,526.45
566.25
6,014,513.12
569,883.27
5.13
-1,151.38 2_MWD+IFR2+MS+Sag(1)
4,230.97
37.00
55.28
3,576.60
3,527.92
-1,506.52
598.39
6,014,533.35
569,915.22
6.01
-1,119.86 2_MWD+IFR2+MS+Sag(1)
4,294.42
39.64
50.52
3,626.38
3,577.70
-1,482.76
629.72
6,014,557.39
569,946.32
6.24
-1,085.21 2_MWD+IFR2+MS+Sag(1)
4,358.31
40.49
49.48
3,675.28
3,626.60
-1,456.33
661.22
6,014,584.11
569,977.57
1.69
-1,048.05 2_MWD+IFR2+MS+Sag(1)
4,421.50
41.97
49.05
3,722.80
3,674.12
-1,429.15
692.77
6,014,611.58
570,008.87
2.38
-1,010.19 2_MWD+IFR2+MS+Sag(1)
4,484.19
44.43
47.54
3,768.50
3,719.82
-1,400.59
724.80
6,014,640.43
570,040.63
4.26
-970.88 2_MWD+IFR2+MS+Sag(1)
4,548.16
46.38
46.03
3,813.41
3,764.73
-1,369.40
757.99
6,014,671.93
570,073.52
3.48
-928.69 2_MWD+IFR2+MS+Sag(1)
4,610.88
47.71
42.55
3,856.16
3,807.48
-1,336.54
790.02
6,014,705.08
570,105.24
4.58
-885.47 2_MWD+IFR2+MS+Sag(1)
4,675.06
49.98
41.77
3,898.39
3,849.71
-1,300.72
822.45
6,014,741.20
570,137.33
3.65
-839.39 2_MWD+IFR2+MS+Sag(1)
4,738.87
52.14
39.64
3,938.49
3,889.81
-1,263.09
854.80
6,014,779.12
570,169.33
4.27
-791.70 2_MWD+IFR2+MS+Sag(1)
4,801.16
53.56
38.80
3,976.11
3,927.43
-1,224.63
886.19
6,014,817.87
570,200.36
2.52
-743.65 2_MWD+IFR2+MS+Sag(1)
4,866.10
55.24
36.77
4,013.92
3,965.24
-1,182.89
918.53
6,014,859.90
570,232.30
3.63
-692.24 2_MWD+IFR2+MS+Sag(1)
4,929.55
58.12
36.15
4,048.77
4,000.09
-1,140.25
950.03
6,014,902.83
570,263.40
4.61
-640.35 2_MWD+IFR2+MS+Sag(1)
4,993.55
61.72
34.84
4,080.84
4,032.16
-1,095.17
982.17
6,014,948.21
570,295.12
5.90
-585.97 2_MWD+IFR2+MS+Sag(1)
5,057.07
64.09
33.55
4,109.77
4,061.09
-1,048.40
1,013.94
6,014,995.27
570,326.45
4.15
-530.21 2_MWD+IFR2+MS+Sag(1)
5,121.65
66.94
31.38
4,136.54
4,087.86
-998.81
1,045.47
6,015,045.14
570,357.52
5.37
-471.99 2_MWD+IFR2+MS+Sag(1)
5,184.60
70.11
29.08
4,159.58
4,110.90
-948.20
1,074.95
6,015,096.02
570,386.52
6.08
-413.70 2_MWD+IFR2+MS+Sag(1)
5,248.92
71.09
26.38
4,180.95
4,132.27
-894.51
1,103.17
6,015,149.97
570,414.24
4.24
-353.13 2_MWD+IFR2+MS+Sag(1)
5,312.82
72.56
24.27
4,200.88
4,152.20
-839.63
1,129.13
6,015,205.08
570,439.69
3.89
-292.43 2_MWD+IFR2+MS+Sag(1)
5,377.20
75.37
22.37
4,218.66
4,169.98
-782.82
1,153.62
6,015,262.11
570,463.64
5.21
-230.58 2 MWD+IFR2+MS+Sag(1)
5,440.05
78.95
22.08
4,232.63
4,183.95
-726.10
1,176.79
6,015,319.04
570,486.28
5.71
-169.36 2_MWD+IFR2+MS+Sag(1)
5,504.06
80.89
21.74
4,243.83
4,195.15
-667.63
1,200.31
6,015,377.71
570,509.25
3.08
-106.41 2_MWD+IFR2+MS+Sag(1)
5,567.21
81.76
21.47
4,253.36
4,204.68
-609.59
1,223.29
6,015,435.96
570,531.69
1.44
-04.08 2_MWD+IFR2+MS+Sag(1)
5,630.75
81.78
21.51
4,262.45
4,213.77
-551.08
1,246.33
6,015,494.68
570,554.18
0.07
18.72 2_MWD+IFR2+MS+Sag(1)
5,694.14
83.55
20.99
4,270.55
4,221.87
492.48
1,269.12
6,015,553.48
570,576.42
2.91
81.47 2_MWD+IFR2+MS+Sag(1)
5,756.66
83.02
21.76
4,277.86
4,229.18
-434.66
1,291.75
6,015,611.50
570,598.51
1.49
143.46 2_MWD+IFR2+MS+Sag(1)
5,820.97
83.25
21.40
4,285.54
4,236.86
-375.29
1,315.23
6,015,671.08
570,621.44
0.66
207.22 2_MWD+IFR2+MS+Sag(1)
4/8/2019 12:46:45PM
Page 4
COMPASS 5000.15 Build 91
Survey
Well MPU E-41
MPU E-41 Actual RKB @ 48.68usft
MPU E-41 Actual RKB @ 48.68usft
True
Minimum Curvature
NORTH US + CANADA
Halliburton
Definitive Survey Report
Company:
Hilcorp Alaska, LLC
Local Co-ordinate Reference:
Project:
Milne Point
TVD Reference:
Site:
M Pt E Pad
MD Reference:
Well:
MPU E-41
North Reference:
Wellbore:
MPU E-41 PB3
Survey Calculation Method:
Design:
MPU E-41 PB3
Database:
Survey
Well MPU E-41
MPU E-41 Actual RKB @ 48.68usft
MPU E-41 Actual RKB @ 48.68usft
True
Minimum Curvature
NORTH US + CANADA
4/82019 12:46:45PM Page 5 COMPASS 5000.15 Build 91
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+NIS
+EI -W
Northing
Easting
DLS
Section
(usft)
(°)
(`)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft)
(°1100')
(ft) Survey Taol Name
5,884.39
80.69
22.04
4,294.40
4,245.72
-316.96
1,338.47
6,015,729.63
570,644.13
4.16
269.93 2_MWD+IFR2+MS+Sag(1)
5,947.90
79.61
22.63
4,305.27
4,256.59
-259.08
1,362.24
6,015,787.72
570,667.37
1.93
332.45 2_MWD+IFR2+MS+Sag(1)
6,011.22
81.05
22.81
4,315.90
4,267.22
-201.50
1,386.35
6,015,845.51
570,690.94
2.29
394.84 2_MWD+IFR2+MS+Sag(1)
6,074.43
82.39
23.14
4,325.00
4,276.32
-143.91
1,410.77
6,015,903.32
570,714.81
2.18
457.36 2_MWD+IFR2+MS+Sag(1)
6,138.46
82.22
22.76
4,333.58
4,284.90
-85.48
1,435.51
6,015,961.97
570,739.01
0.65
520.79 2_MWD+IFR2+MS+Sag(1)
6,202.49
81.97
22.69
4,342.38
4,293.70
-26.99
1,460.01
6,016,020.69
570,762.96
0.41
584.17 2_MWD+IFR2+MS+Sag(1)
6,265.42
83.63
21.33
4,350.27
4,301.59
30.90
1,483.41
6,016,078.78
570,785.81
3.40
646.54 2_MWD+IFR2+MS+Sag(1)
6,328.74
84.02
19.26
4,357.08
4,308.40
89.94
1,505.24
6,016,138.01
570,807.10
3.31
709.30 2_MWD+IFR2+MS+Sag(1)
6,392.15
87.14
20.35
4,361.97
4,313.29
149.41
1,526.66
6,016,197.68
570,827.96
5.21
772.29 2_MWD+IFR2+MS+Sag(1)
6,445.25
91.49
21.03
4,362.60
4,313.92
199.07
1,545.41
6,016,247.51
570,846.25
8.29
825.25 2_MWD+IFR2+MS+Sag(1)
6,510.90
93.54
20.93
4,359.72
4,311.04
260.30
1,568.89
6,016,308.95
570,869.16
3.13
890.70 2_MWD+IFR2+MS+Sag(2)
6,575.22
93.34
21.55
4,355.86
4,307.18
320.15
1,592.15
6,016,369.00
570,891.86
1.01
954.79 2_MWD+IFR2+MS+Sag (2)
6,638.60
92.53
21.60
4,352.62
4,303.94
379.01
1,615.43
6,016,428.07
570,914.58
1.28
1,018.00 2_MWD+IFR2+MS+Sag (2)
6,702.90
91.79
21.10
4,350.20
4,301.52
438.85
1,638.82
6,016,488.12
570,937.41
1.39
1,082.14 2_MWD+IFR2+MS+Sag (2)
6,766.55
91.98
20.66
4,348.10
4,299.42
498.29
1,661.50
6,016,547.77
570,959.53
0.75
1,145.62 2_MWD+IFR2+MS+Sag (2)
6,829.16
91.98
20.81
4,345.94
4,297.26
556.81
1,683.65
6,016,606.48
570,981.14
0.24
1,208.05 2_MWD+IFR2+MS+Sag(2)
6,892.72
91.36
20.86
4,344.09
4,295.41
616.19
1,706.25
6,016,666.06
571,003.18
0.98
1,271.44 2_MWD+IFR2+MS+Sag(2)
6,956.48
90.06
20.22
4,343.30
4,294.62
675.89
1,728.61
6,016,725.96
571,024.99
2.27
1,335.03 2_MWD+IFR2+MS+Sag(2)
7,019.74
90.19
20.08
4,343.16
4,294.48
735.28
1,750.41
6,016,785.55
571,046.23
0.30
1,398.10 2 MWD+IFR2+MS+Sag(2)
7,083.36
89.32
19.65
4,343.43
4,294.75
795.11
1,772.02
5,016,845.57
571,067.28
1.53
1,461.50 2_MWD+IFR2+MS+Sag (2)
7,146.87
89.08
21.15
4,344.32
4,295.64
854.63
1,794.16
6,016,905.29
571,088.86
2.39
1,524.82 2_MWD+IFR2+MS+Sag (2)
7,210.62
89.45
22.29
4,345.14
4,296.46
913.85
1,817.75
6,016,964.72
571,111.90
1.88
1,588.48 2_MWD+IFR2+MS+Sag(2)
7,273.37
89.20
22.23
4,345.87
4,297.19
971.92
1,841.52
6,017,023.00
571,135.12
0.41
1,651.18 2_MWD+IFR2+MS+Sag(2)
7,337.00
90.19
22.27
4,346.21
4,297.53
1,030.81
1,865.61
6,017,082.11
571,158.67
1.56
1,714.75 2_MWD+IFR2+MS+Sag(2)
7,399.99
90.87
22.75
4,345.63
4,296.95
1,089.00
1,889.72
6,017,140.51
571,182.24
1.32
1,777.69 2_MWD+IFR2+MS+Sag (2)
7,463.53
91.80
22.17
4,344.15
4,295.47
1,147.70
1,913.99
6,017,199.43
571,205.95
1.72
1,841.17 2_MWD+IFR2+MS+Sag(2)
7,468.00
91.55
21.62
4,344.02
4,295.34
1,151.84
1,915.66
6,017,203.59
571,207.58
13.51
1,845.63 2_MWD+IFR2+MS+Sag (3)
7,523.45
89.81
22.77
4,343.36
4,294.68
1,203.18
1,936.60
6,017,255.12
571,228.05
3.76
1,901.02 2_MWD+IFR2+MS+Sag (3)
7,586.59
88.77
22.70
4,344.14
4,295.46
1,261.41
1,961.00
6,017,313.56
571,251.90
1.65
1,964.12 2 MWD+IFR2+MS+Sag(3)
7,650.03
89.26
22.15
4,345.23
4,296.55
1,320.04
1,985.20
6,017,372.41
571,275.55
1.16
2,027.51 2_MWD+IFR2+MS+Sag (3)
7,713.40
90.62
23.31
4,345.30
4,296.62
1,378.49
2,009.68
6,017,431.08
571,299.49
2.82
2,090.84 2_MWD+IFR2+MS+Sag (3)
7,777.66
91.92
23.82
4,343.88
4,295.20
1,437.37
2,035.37
6,017,490.20
571,324.62
2.17
2,155.07 2_MWD+IFR2+MS+Sag (3)
7,800.00
92.23
22.96
4,343.07
4,294.39
1,457.86
2,044.23
6,017,510.77
571,333.29
4.09
2,177.39 2_MWD+IFR2+MS+Sag (4)
7,839.95
90.80
23.81
4,342.01
4,293.33
1,494.52
2,060.08
6,017,547.56
571,348.80
4.16
2,217.31 2_MWD+IFR2+MS+Sag (4)
7,904.09
91.80
24.48
4,340.56
4,291.88
1,553.03
2,086.31
6,017,606.31
571,374.48
1.88
2,281.43 2_MWD+IFR2+MS+Sag(4)
7,968.26
91.86
24.95
4,338.51
4,289.83
1,611.29
2,113.13
6,017,664.81
571,400.75
0.74
2,345.57 2_MWD+IFR2+MS+Sag(4)
8,031.98
90.93
24.91
4,336.96
4,288.28
1,669.06
2,139.98
6,017,722.82
571,427.06
1.46
2,409.27 2_MWD+IFR2+MS+Sag (4)
8,096.01
89.38
24.90
4,336.78
4,288.10
1,727.13
2,166.94
6,017,781.14
571,453.48
2.42
2,473.30 2_MWD+IFR2+MS+Sag(4)
8,159.16
89.57
25.43
4,337.36
4,288.68
1,784.28
2,193.79
6,017,838.53
571,479.79
0.89
2,536.44 2_MWD+IFR2+MS+Sag(4)
8,223.00
88.70
24.35
4,338.32
4,289.64
1,842.19
2,220.66
6,017,896.68
571,506.12
2.17
2,600.27 2_MWD+IFR2+MS+Sag(4)
4/82019 12:46:45PM Page 5 COMPASS 5000.15 Build 91
Halliburton
Definitive Survey Report
Company:
Hilcorp Alaska, LLC
Local Co-ordinate Reference: Well MPU E41
Project:
Milne Point
TVD Reference:
MPU
E41 Actual RKB @ 48.68usft
Site:
M Pt E Pad
MD Reference:
MPU
E41 Actual RKB @ 48.68usft
Well:
MPU
E-41
North Reference:
True
Wellbore:
MPU E41 PB3
Survey Calculation
Method: Minimum Curvature
Design:
MPU
E-41 PB3
Database:
NORTH
US
+ CANADA
Survey
Map
Map
Vertical
MD
Inc
Azi
ND
TVDSS
+NI -S
+E/ -W
Northing
Easting
DLS
Section
(usft)
(1)
V)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft) (°(100')
(ft) Survey Tool Name
8,286.11
89.26
24.02
4,339.45
4,290.77
1,899.75
2,246.51
6,017,954.47
571,531.43
1.03
2,663.37 2_MWD+IFR2+MS+Sag (4)
8,350.28
89.39
23.44
4,340.20
4,291.52
1,958.49
2,272.33
6,018,013.44
571,556.70
0.93
2,727.53 2_MWD+IFR2+MS+Sag(4)
8,414.20
89.63
22.98
4,340.75
4,292.07
2,017.23
2,297.52
6,018,072.41
571,581.34
0.81
2,791.43 2_MWD+IFR2+MS+Sag (4)
8,478.27
90.69
22.35
4,340.57
4,291.89
2,076.35
2,322.21
6,018,131.76
571,605.48
1.92
2,855.46 2_MWD+IFR2+MS+Sag(4)
8,541.96
90.19
22.08
4,340.08
4,291.40
2,135.31
2,346.29
6,018,190.93
571,629.00
0.89
2,919.09 2_MWD+IFR2+MS+Sag (4)
8,605.25
89.07
21.17
4,340.49
4,291.81
2,194.15
2,369.61
6,018,249.97
571,651.78
2.28
2,982.29 2_MWD+IFR2+MS+Sag (4)
8,669.13
88.33
20.84
4,341.94
4,293.26
2,253.77
2,392.50
6,018,309.80
571,674.11
1.27
3,046.02 2_MWD+IFR2+MS+Sag (4)
8,732.55
89.39
20.57
4,343.20
4,294.52
2,313.08
2,414.92
6,018,369.31
571,695.97
1.72
3,109.28 2_MWD+IFR2+MS+Sag (4)
8,795.85
89.08
21.75
4,344.05
4,295.37
2,372.10
2,437.77
6,018,428.54
571,718.27
1.93
3,172.45 2_MWD+IFR2+MS+Sag (4)
8,859.92
88.64
23.30
4,345.32
4,296.64
2,431.27
2,462.30
6,018,487.93
571,742.25
2.51
3,236.47 2_MWD+IFR2+MS+Sag (4)
8,921.29
87.65
23.45
4,347.31
4,298.63
2,487.57
2,486.64
6,018,544.45
571,766.06
1.63
3,297.79 2_MWD+IFR2+MS+Sag (4)
8,984.92
89.21
25.25
4,349.05
4,300.37
2,545.52
2,512.86
6,018,602.63
571,791.74
3.74
3,361.39 2_MWD+IFR2+MS+Sag (4)
9,048.33
89.14
23.60
4,349.97
4,301.29
2,603.25
2,539.08
6,018,660.59
571,817.42
2.60
3,424.79 2_MWD+IFR2+MS+Sag (4)
9,113.08
89.14
23.21
4,350.94
4,302.26
2,662.66
2,564.80
6,018,720.24
571,842.58
0.60
3,489.52 2_MWD+IFR2+MS+Sag (4)
9,177.01
88.65
22.14
4,352.17
4,303.49
2,721.64
2,589.44
6,018,779.44
571,866.67
1.84
3,553.40 2_MWD+IFR2+MS+Sag (4)
9,240.71
87.03
21.32
4,354.57
4,305.89
2,780.77
2,613.00
6,018,838.78
571,889.68
2.85
3,616.97 2_MWD+IFR2+MS+Sag (4)
9,304.54
85.98
19.05
4,358.46
4,309.78
2,840.56
2,634.99
6,018,898.77
571,911.10
3.91
3,680.48 2 MWD+IFR2+MS+Sag (4)
9,368.35
86.30
17.12
4,362.76
4,314.08
2,901.08
2,654.75
6,018,959.46
571,930.30
3.06
3,743.73 2_MWD+IFR2+MS+Sag (4)
9,432.48
86.98
14.93
4,366.52
4,317.84
2,962.60
2,672.42
6,019,021.14
571,947.40
3.57
3,807.02 2_MWD+IFR2+MS+Sag (4)
9,495.88
86.54
12.32
4,370.10
4,321.42
3,024.12
2,687.33
6,019,082.78
571,961.73
4.17
3,869.15 2_MWD+IFR2+MS+Sag (4)
9,558.26
86.05
11.52
4,374.13
4,325.45
3,085.02
2,700.19
6,019,143.80
571,974.02
1.50
3,929.87 2_MWD+IFR2+MS+Sag (4)
9,622.00
85.80
9.14
4,378.66
4,329.98
3,147.57
2,711.59
6,019,206.44
571,984.84
3.75
3,991.47 2_MWD+IFR2+MS+Sag (4)
9,686.01
86.05
6.83
4,383.21
4,334.53
3,210.79
2,720.46
6,019,269.74
571,993.12
3.62
4,052.63 2_MWD+IFR2+MS+Sag(4)
9,750.48
85.99
3.35
4,387.69
4,339.01
3,274.84
2,726.16
6,019,333.84
571,998.23
5.39
4,113.23 2_MWD+IFR2+MS+Sag(4)
9,813.94
85.67
1.32
4,392.30
4,343.62
3,338.08
2,728.74
6,019,397.09
572,000.22
3.23
4,171.78 2_MWD+IFR2+MS+Sag (4)
9,877.98
85.80
1.10
4,397.07
4,348.39
3,401.93
2,730.09
6,019,460.94
572,000.97
0.40
4,230.38 2_MWD+IFR2+MS+Sag (4)
9,941.77
86.30
1.58
4,401.46
4,352.78
3,465.55
2,731.58
6,019,524.57
572,001.87
1.09
4,288.83 2_MWD+IFR2+MS+Sag(4)
10,005.58
86.85
2.34
4,405.27
4,356.59
3,529.21
2,733.76
6,019,588.24
572,003.46
1.47
4,347.60 2_MWD+IFR2+MS+Sag(4)
10,068.67
88.53
2.61
4,407.82
4,359.14
3,592.18
2,736.48
6,019,651.23
572,005.59
2.70
4,405.98 2 MWD+IFR2+MS+Sag(4)
10,132.18
88.34
3.47
4,409.55
4,360.87
3,655.58
2,739.85
6,019,714.65
572,008.37
1.39
4,465.01 2_MWD+IFR2+MS+Sag(4)
10,195.71
87.96
3.88
4,411.60
4,362.92
3,718.95
2,743.92
6,019,778.04
572,011.85
0.88
4,524.30 2 MWD+IFR2+MS+Sag(4)
10,259.26
88.21
4.63
4,413.72
4,365.04
3,782.28
2,748.63
6,019,841.42
572,015.97
1.24
4,583.83 2_MWD+IFR2+MS+Sag(4)
10,322.46
88.71
4.67
4,415.42
4,366.74
3,845.25
2,753.75
6,019,904.43
572,020.51
0.79
4,643.21 2_MWD+IFR2+MS+Sag(4)
10,385.83
91.06
4.05
4,415.55
4,366.87
3,908.44
2,758.57
6,019,967.64
572,024.73
3.84
4,702.64 2_MWD+IFR2+MS+Sa9(4)
10,449.14
91.30
4.51
4,414.25
4,365.57
3,971.55
2,763.29
6,020,030.80
572,028.87
0.82
4,761.98 2_MWD+IFR2+MS+Sag(4)
10,513.36
91.86
4.19
4,412.48
4,363.80
4,035.57
2,768.16
6,020,094.85
572,033.14
1.00
4,822.20 2_MWD+IFR2+MS+Sag(4)
10,576.90
90.74
5.48
4,411.03
4,362.35
4,098.86
2,773.51
6,020,158.18
572,037.91
2.69
4,881.96 2_MWD+IFR2+MS+Sag (4)
10,640.00
90.74
6.14
4,410.22
4,361.54
4,161.63
2,779.90
6,020,221.00
572,043.71
1.05
4,941.68 2_MWD+IFR2+MS+Sag(4)
10,702.53
91.86
7.97
4,408.80
4,360.12
4,223.67
2,787.58
6,020,283.10
572,050.81
3.43
5,001.27 2_MWD+IFR2+MS+Sag(4)
10,766.74
92.04
9.83
4,406.62
4,357.94
4,287.07
2,797.51
6,020,346.58
572,060.15
2.91
5,063.03 2_MWD+IFR2+MS+Sag(4)
4/82019 12:46:45PM
Page 6
COMPASS 5000.15 Build 91
Halliburton
Definitive Survey Report
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt E Pad
Well:
MPU E-41
Wellbore:
MPU E-41PB3
Design:
MPU E-41PB3
Survey
MD Inc Azi TVD TVDSS +N/ -S
(usft) (°) (°) (usft) (usft) (usft)
10,829.63 92.04 9,10 4,404.37 4,355.69 4,349.26
10,893.04 93,28 9.12 4,401.44 4,352.76 4,411.60
10,955.88 94,70 7,84 4,397.06 4,348.38 4,473.60
11,019.06 94.27 5.94 4,392.12 4,343.44 4,536,13
11,082.28 93.03 6.36 4,388.10 4,339.42 4,598.86
11,145.81 92.97 6.11 4,384.77 4,336.09 4,661.92
11,209.06 91.23 6.34 4,382.46 4,333.78 4,724.76
11,271.94 90.18 5.89 4,381,68 4,333.00 4,787.27
11,336.15 90.68 4.75 4,381.20 4,332.52 4,851.20
11,399.97 91.67 3.56 4,379.89 4,331.21 4,914.84
11,463.63 90.31 4.17 4,378,79 4,330.11 4,978.34
11,527.23 89.57 5.48 4,378.86 4,330.18 5,041.72
11,591.23 90.62 5.94 4,378.75 4,330.07 5,105.40
11,654.92 91.30 5.95 4,377.68 4,329.00 5,168,74
11,717.96 92.67 6.54 4,375.50 4,326.82 5,231.36
11,780.45 93.34 6.26 4,372.22 4,323.54 5,293.38
11,850,00 93.34 6.26 4,368.17 4,319.49 5,362.39
Local Co-ordinate Reference: Well MPU E-41
TVD Reference:
MPU E-41 Actual RKB @ 48.68usft
MD Reference:
MPU E-41 Actual RKB @ 48.68usft
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Database:
NORTH US + CANADA
Map Map Vertical
+E/ -W Northing Easting DLS Section
(usft) (ft) (ft) (°/100') (ft) .Survey Tool Name
2,807.87 6,020,408.86 572,069.94 1.16 5,123,88 2_MWD+IFR2+MS+Sag(4)
2,817.87 6,020,471.29 572,079.35 1.96 5,184,72 2_MWD+IFR2+MS+Sag (4)
2,827.12 6,020,533.37 572,088.02 3.04 5,244.93 2_MWD+IFR2+MS+Sag(4)
2,834.67 6,020,595.96 572,094.99 3.07 5,304.91 2_MWD+IFR2+MS+Sag(4)
2,841.43 6,020,658.74 572,101.17 2.07 5,364.74 2_MWD+IFR2+MS+Sag (4)
2,848.32 6,020,721.86 572,107.47 0.40 5,424.94 2_MWD+IFR2+MS+Sag (4)
2,855.17 6,020,784.75 572,113.74 2.77 5,484.91 2_MWD+IFR2+MS+Sag (4)
2,861.87 6,020,847.32 572,119.85 1.82 5,544.53 2_MWD+IFR2+MS+Sag (4)
2,867.82 6,020,911.30 572,125.21 1.94 5,605.12 2_MWD+IFR2+MS+Sag (4)
2,872.45 6,020,974.97 572,129.24 2.43 5,664.89 2_MWD+IFR2+MS+Sag (4)
2,876.74 6,021,038.50 572,132.94 2.34 5,724.40 2_MWD+IFR2+MS+Sag (4)
2,882.09 6,021,101.92 572,137.70 2.37 5,784.23 2 MWD+IFR2+MS+Sag (4)
2,888.46 6,021,165.65 572,143.47 1.79 5,844.77 2_MWD+IFR2+MS+Sag (4)
2,895.05 6,021,229.04 572,149.48 1.07 5,905.09 2_MWD+IFR2+MS+Sag (4)
2,901.90 6,021,291.72 572,155,75 2.37 5,964.87 2_MWD+IFR2+MS+Sag (4)
2,908.86 6,021,353,79 572,162.13 1.16 6,024.14 2_MWD+IFR2+MS+Sag (4)
2,916.43 6,021,422.87 572,169.05 0.00 6,090.03 PROJECTED to TD
a.,.,.a.
Checked By: Chelsea Wright -"'...
,.w....�"„«.,�,a ..,, Approved By: Mitch Laird Date: 04-08-2019
482019 12:46:45PM Page 7 COMPASS 5000.15 Build 91
Lease 8 Well No.
County
TO
Hilcorp Energy Company
CASING & CEMENTING REPORT
Shoe Depth:
rJn II¢ rl¢lirr¢reA
_State Alaska Supv.
CASING RECORD
Surtace �
6.474.00 PBTD:
Date Run 20.Mar-19
J. Lon /0 Amend
Nn If¢ Run 'AA Nn IN Returned
Csg Wt. On Hook: Type Float Collar: Conventional No. Him to Run: 43
Csg Wt. On Slips: 100 Type of Shoe: Conventional Casing Crew: Weatherford
Rotate Csg X Yes No Recip Csg _ Yes X No Ft. Min. 9.4 PPG
Fluid Description: Spud Mud
CEMENTING REPORT
Shoe I@ 6474 FC @ 6.392.00 Top of Liner
ush (Spacer)
Clean Spacer III Density (ppg) 10 Volume pumped (BBLs)
Extend Chem
sily (Ppg) 12
Slurry
Sacks: 600 Yield:
Volume pumped (BBLs) 252 Miring / Pumping Rate (bpm):
ily (ppg) 15.8 Volume pumped (BBLs) _
Flush (Spacer)
Density(ppg)
Sacks: 400 Yield:
82 Mixing / Pumping Rate (bpm):
Rate (bpm): Volume:
Spud Mud Density (ppg)
9.5 Rate (bpm):
4 Volume (actual / calculated):
Casing (Or Liner) Detail
(psi): 1040 Pump used for lisp:
Setting Depths
Jts.
Component
Size
Wt.
Grade
THD Make
Length
Bottom
Top
1
Shoe
95/8
Estimated TOC:
2,238
TXP BTC DHE
1.60
6,474.00
6,472.40
2
Casing
95/8
40.0
L-80
TXP BTC
78.22
6,472.40
6,394,18
1
Float Collar
95/8
TXP BTC
1.31
6,394.18
6,392.87
1
Casing
95/8
40.0
L-80
TXP BTC
38.97
6,392.87
6,353.90
1
Baffle Adapter
95/8
TXP BTC
1.47
6,353.90
6,352.43
104
Casing
95/8
40.0
L-80
TXP BTC
4,092.07
6,352.43
2,260.36
1
Pup
95/8
40.0
L-80
TXP BTC
18.47
2,260.36
2,241.89
1
ESC
95/8
40.0
L-80
TXP BTC
3.09
2,241.89
2 23
1PuP
95/8
40.0
L-80
TXP BTC
17.98
2,238.80
2,220.82
57
Casing
95/8
40.0
L-80
TXP BTC
2,193.80
2,220.82
27.02
RKB
27.02
27.02
Csg Wt. On Hook: Type Float Collar: Conventional No. Him to Run: 43
Csg Wt. On Slips: 100 Type of Shoe: Conventional Casing Crew: Weatherford
Rotate Csg X Yes No Recip Csg _ Yes X No Ft. Min. 9.4 PPG
Fluid Description: Spud Mud
CEMENTING REPORT
Shoe I@ 6474 FC @ 6.392.00 Top of Liner
ush (Spacer)
Clean Spacer III Density (ppg) 10 Volume pumped (BBLs)
Extend Chem
sily (Ppg) 12
Slurry
Sacks: 600 Yield:
Volume pumped (BBLs) 252 Miring / Pumping Rate (bpm):
ily (ppg) 15.8 Volume pumped (BBLs) _
Flush (Spacer)
Density(ppg)
Sacks: 400 Yield:
82 Mixing / Pumping Rate (bpm):
Rate (bpm): Volume:
Spud Mud Density (ppg)
9.5 Rate (bpm):
4 Volume (actual / calculated):
493/483
(psi): 1040 Pump used for lisp:
Rig
Bump Plug? X Yes _No
Bump press 1600
ig Rotated? Yes X
No Reciprocated? _Yes
X No % Returns during job
X
ant returns to surface? X Yes
—No Spacer returns?
X Yes —No Vol to Surf:
20 1/
ant In Place At: 1144
Date: 3/22/2019
Estimated TOC:
2,238
od Used To Determine TOC: Calc
Stage Collar @ 2238 Type BTC Closure OK OK
reflush(Spacer)
ype: Clean Spacer III Density (ppg) 10 Volume pumped (BBLs)
ead Slurry
ype: PO Type L Sacks: 440 Yield:
Density (ppg) 10.7 Volume pumped (BBLs) 338 Miring / Pumping Rate (bpm):
ail Slurry
ype: Swift Chem Sacks: 270 Yield:
orally (ppg) 15.8 Volume pumped (BBLs) 56 Mixing / Pumping Rate (bpm):
ost Flush (Spacer)
Rate (bpm): Volume:
Spud Mud Density (ppg)
9.4 Rate (bpm):
4 Volume (actual / calculated): 1
(psi): 600 Pump used for dup:
Rig
Bump Plug? X Yes _No Bump press
Ig Rotated?
X No
Reciprocated? _Yes
X No % Returns during job 9
_Yes
ant returns to surface? _Yes
X
No Spacer returns?
Yes X No Vol to Surf: 22
ant In Place At: 247
Data
3/23/2019
Estimated TOC: 0
od Used To Determine TOC:
Surface
Post Job Calculations:
Calculated Can Vol @ 0% excess: 385.67 Total Volume cmt Pumped:
Cmt returned to surface: 225 Calculated cement len in wellbore: 503
OH volume Calculated: 357 OR volume actual: 475 Actual % Washout:
www.wellez.net WellEz Information Management LLC ver 04818br
IA7
4
4
Schwartz, Guy L (DOA)
From: Schwartz, Guy L (DOA)
Sent: Saturday, March 30, 2019 9:56 AM
To: Joe Engel
Cc: Monty Myers; Cody Dinger; Taylor Wellman
Subject: Re: HAK MPU E-41 (PTD: 219-031) Update
Joe,
Thanks for update and plan forward. You will not need a sundry to proceed as proposed... plan APPROVED.
Abandoned lateral will require a-70'API Suffix and be labeled as E-41 PBd.
�i3 L
Regards,
Guy Schwartz
AOGCC
Sent from my iPhone
On Mar 29, 2019, at 4:50 PM, Joe Engel <iengel@hilcorp.com> wrote:
Guy -
I wanted to give you an update on MPU E-41. While drilling the 8.5" lateral in the NB, we crossed a - 23'
down throw fault at - 9,343' MD. While attempting to drill back in zone afterwards, we encountered a
wet Ugnu sand.
Due to high potential water production if left unaddressed, we will be POOH and plugging back this part
of the wellbore with a swell packer and sacrificial cemented tubing assembly from 8850'- 9150'. We will
then perform an OH sidetrack at - 7800' and continue drilling the NB lateral as planned. If there are any
changes to the proposed completion, Taylor will let you know.
Please let me know if you need anything regarding this plug back.
Thank you for your time.
-Joe
Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC
3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503
Office: 907.777.8395 1 Cell: 805.235.6265
Schwartz, Guy L (DOA)
From: Joe Engel <jengel@hilcorp.com>
Sent: Wednesday, April 10, 2019 4:34 PM
To: Schwartz, Guy L (DOA)
Subject: HAK MPU E-41 (PTD:219-031) Update
Guy —
I wanted to give you an update regarding the full list of OH sidetracks on E-41. We performed one more after the
plugged back at 7800' due to the water zone.
PBI:
Length= 505'
Depths:
7468'— 7973' MD
P82:
Length = 1658'
Depths:
7800-9458' MD
PB3:
Length = 283'
Depths:
11,567'— 11,850' MD
Regarding current operations, liner has been ran and we are preparing to run the 7-5/8" tieback and upper completion.
Please let me know if you have any questions.
Thank you for your time.
-Joe
Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC
3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503
Office: 907.777.8395 1 Cell: 805.235.6265
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Monty Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Alaska Cil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www, aogc c. o1 a s ka.gov
Re: Milne Point Field, Schrader Bluff Oil Pool, MPU E-41
Hilcorp Alaska, LLC
Permit to Drill Number: 219-031
Surface Location: 3496' FSL, 1844' FEL, SEC. 25, TI 3N, RI OE, UM, AK
Bottomhole Location: 439' FNL, 1201' FWL, SEC. 19, T13N, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced development well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs
run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment
of this well.
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,
Daniel T. Seamount, Jr.
Commissioner
DATED this Zo day of February, 2019.
STATE OF ALASKA t
ALr,o!<A OIL AND GAS CONSERVATION COMM160ION
PERMIT TO DRILL
20 AAC 25.005
RCS-a^��
ti s sa (1 Fra
FED 1; 2019
Ia. Type of Work:
11b. Proposed Well Class: Exploratory - Gas
Service - WAG ❑ Service - Disp ❑
ic. Specify if weII15 proposed for:
Drill Lateral ❑
Stmtigraphic Test ❑ Development -Oil
Service- Winj ❑ Single Zone ❑'
Coalbed Gas E3 Gas Hydrates ❑
Redrill ❑ Reentry ❑
Exploratory - Oil ❑ Development - Gas ❑
Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond: Blanket Q Single Well ❑
11. Well Name and Number:
Hilcorp Alaska, LLC
Bond No. 022035244
MPU E-41
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
MD: 13,100' TVD: 4,350'
Milne Point Field
Schrader Bluff oil Pool
4a. Location of Well (Governmental Section):
7. Property Designation:
Surface: 3496' FSL, 1844' FEL, Sec 25, T1 3N, R1 OE, UM, AK
ADL025518, ADL028231, ADL047438
Top of Productive Horizon:
8. DNR Approval Number:
13. Approximate Spud Date:
1855' FNL, 421' FEL, Sec 25, Tl 3N, R1 OE, UM, AK
LONS 94-017
3/5/2019
9. Acres in Property:
14. Distance to Nearest Property:
Total Depth:
439' FNL, 1201' FWL, Sec 19, T13N, R11 E, UM, AK
7659
9070'to nearest unit boundary
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 48.2' •
15. Distance to Nearest Well Open
Surface: x-569302 y- 6016034 Zone -4
GL / BF Elevation above MSL (ft): 21.7' ,
to Same Pool: 315' to MPE-31
16. Deviated wells: Kickoff depth: 350 feet
17. Maximum Potential Pressures in psig (see 20 AAE 25.035)
Maximum Hole Angle: 90.8 degrees
Downhole: 1904 ' Surface:
1471
18. Casing Program: Specifications
Top - Setting Depth - Bottom
Cement Quantity, c.f. or sacks
Hole
Casing Weight
Grade
I Coupling
Length
MD
TVD
MD
TVD
(including stage data)
Cond
20" -
X-52
Weld
107'
Surface
Surface
107'
107'
±270 ft3
Stg 1 L - 1082 ft3 / T - 458 ft3
12-1/4"
9-5/8" 40#
L-80
TXP
6,156'
Surface
Surface
6,156'
4,328'
Stg 2 L - 1937 ft3 / T - 314 ft3
Tieback
7-5/8" 29.7#
L-80
Hyd 521
6,006'
Surface
Surface
6,006'
4,315'
Tieback Assy.
8-1/2"
4-1/2" 13.5#
L-80
Hyd 625
7,094'
6,006'
4,315'
13,100'
4,350'
Cementless Liner w/ Screens & Pkrs
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured):
Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured):
Casing Length Size
Cement Volume MD TVD
Conductor/Structural
Surface
Intermediate
Production
Liner
Perforation Depth MD ((t):
Perforation Depth TVD (ft):
Hydraulic Fracture planned? Yes ❑ No Q
SjiqlnD
20. Attachments: Property Plat O BOP Sketch
Drilling
Program v Time v. Depth Plot v
Shallow Hazard Analysis
Diverter Sketch
B
Seabed
Report e Drilling Fluid Program e
20 AAC 25.050 requirements
21. Verbal Approval: Commission Representative:
Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Contact Name: Joe Engel
Authorized Name: Monty Myers
Contact Email:
'en el hilcor .COM
Authorized Title: Drilling Manager
Contact Phone:
777-8395
Authorized Signatu : — -
'L
Date: I J
Commission Use Only
Permit to Drill API Number:
Permit Approval
See cover letter for other
Number: O,� �d 31 50-pZ9-'�'3 2 �Op—O
Date:
j61requirements.
ne, gas hydrates, or gas contained in shales:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me haEr
Other: 3�QQ $� �O� I G�
o
Samples req'd: Yes E] No
No
Mud log req'd: Yes No
r❑l
HzS measures: Yes E] No
Directional svy req'd: Yes u No F]Spacing
�[-,�r
exception req'd: Yes LlNO LrJ Inclination -only svy req'd: Yes ❑ No (T
Post initial
injection MIT req'd: Yes ❑ No ❑
APPROVED BY
nLi/' C(
1
Approved by:
COMMISSIONER THE COMMISSION
Date: ` `
V `%� n n /1 I f A Submit Form and
Fbm`r.10-401 Re ed 017 This permit is vali f rf`I,q/ f o eAl„pt of approval per 20 AAC 25. 5 ) Attachments in Duplicate
�;' a�-� i �?9 AIt.B - 249119
Hilcorp Alaska, LLC
Milne Point Unit
(MPU) E-41
Drilling Program
Version 1
2/13/2019
Table of Contents
1.0
Well Summary.................................................................................................................................2
2.0
Management of Change Information............................................................................................3
Mandatory Regulatory Compliance / Notifications
3.0
Tubular Program: ...........................................................................................................................
4
4.0
Drill Pipe Information: ...................................................................................................................
4
5.0
Internal Reporting Requirements..................................................................................................5
Drill 12-1/4" Hole Section.............................................................................................................13
6.0
Planned Wellbore Schematic..........................................................................................................6
Run 9-5/8" Surface Casing...........................................................................................................16
7.0
Drilling / Completion Summary.....................................................................................................7
18.0
8.0
Mandatory Regulatory Compliance / Notifications
.....................................................................8
9.0
R/U and Preparatory Work..........................................................................................................10
Innovation Rig Diverter Schematic.............................................................................................42
10.0
N/U 13-5/8" 5M Diverter Configuration.....................................................................................11
Innovation Rig BOP Schematic....................................................................................................43
11.0
Drill 12-1/4" Hole Section.............................................................................................................13
Wellhead Schematic......................................................................................................................44
12.0
Run 9-5/8" Surface Casing...........................................................................................................16
13.0
Cement 9-5/8" Surface Casing.....................................................................................................21
14.0
BOP N/U and Test.........................................................................................................................26
Anticipated Drilling Hazards.......................................................................................................48
15.0
Drill 8-1/2" Hole Section...............................................................................................................27
27.0
16.0
Run 4-1/2" Production Screen Liner...........................................................................................31
Innovation Rig Choke Manifold Schematic................................................................................53
17.0
Run 7-5/8" Tieback.......................................................................................................................37
18.0
Run ESP Assembly........................................................................................................................40
19.0
RDMO............................................................................................................................................41
20.0
Innovation Rig Diverter Schematic.............................................................................................42
21.0
Innovation Rig BOP Schematic....................................................................................................43
22.0
Wellhead Schematic......................................................................................................................44
23.0
Days Vs Depth................................................................................................................................45
24.0
Formation Tops & Information...................................................................................................46
25.0
Anticipated Drilling Hazards.......................................................................................................48
26.0
Innovation Rig Layout..................................................................................................................51
27.0
FIT Procedure................................................................................................................................52
28.0
Innovation Rig Choke Manifold Schematic................................................................................53
29.0
Casing Design.................................................................................................................................54
30.0
8-1/2" Hole Section MASP............................................................................................................55
31.0
Spider Plot (NAD 27) (Governmental Sections).........................................................................56
32.0
Surface Plat (As Built) (NAD 27).................................................................................................57
33.0
Schrader Bluff NB Sand Offset MW vs TVD Chart
..................................................................58
n
HilmTE, C®ryvy
1.0 Well Summary
Milne Point Unit
E-41 SB Producer
Drilling Procedure
Well
MPU E-41
Pad
Milne Point `B" Pad
Planned Completion Type
ESP on 2-7/8" Production Tubing
Target Reservoir(s)
Schrader Bluff NB Sand
Planned Well TD, MD / TVD
13,100' MD / 4,350' TVD
PBTD, MD / TVD
13,090' MD / 4,350' TVD
Surface Location Governmental
3496' FSL, 1844' FEL, Sec 25, TON, R10E, UM, AK
Surface Location (NAD 27)
X= 569,302.89, Y= 6,016,034.09
Top of Productive Horizon
Governmental)
1855' FNL, 421' FEL, Sec 25, T13N, R10E, UM, AK
TPH Location AD 27)
X= 570,727 Y= 6,015,976
BHL Governmental
439' FNL, 1201' FWL, Sec 19, T13N, RI IE, UM, AK
BHL AD 27
X= 572,284.41, Y=6,022,687.6
AFE Number
1910939
AFE Drilling Das
19 days
AFE Completion Das
4 days
AFE Drilling Amount
$4,136,452
AFE Completion Amount
$2,129,435
AFE Facility Amount
$391,000
Maximum Anticipated Pressure
(Surface)
1471 psig
Maximum Anticipated Pressure
(Downhole/Reservoir)
1904 psig
Work String
5" 19.54 S-135 DS -50 & NC 50
KB Elevation above MSL:
26.5 ft + 21.8 ft = 48.3 ft
GL Elevation above MSL:
21.8 ft
BOP Equipment
13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams
Page 2
2.0 Management of Change Information
H
Hilcorp Alaska, LLC Hilcoorrp
Changes to Approved Permit to Drill
Date: 2/8/2019
Subject: Changes to Approved Permit to Drill for MPU E-41
File #: MPU E-41 Drilling and Completion Program
Any modifications to MPU E-41 Drilling & Completion Program will be documented and approved below.
Changes to an approved APD will be communicated to the AOGCC_
Approval:
Drilling Manager
Prepared:
Drilling Engineer
Page 3
Date
Milne Point Unit
E-41 SB Producer
Hilcorp
Drilling Procedure
2.0 Management of Change Information
H
Hilcorp Alaska, LLC Hilcoorrp
Changes to Approved Permit to Drill
Date: 2/8/2019
Subject: Changes to Approved Permit to Drill for MPU E-41
File #: MPU E-41 Drilling and Completion Program
Any modifications to MPU E-41 Drilling & Completion Program will be documented and approved below.
Changes to an approved APD will be communicated to the AOGCC_
Approval:
Drilling Manager
Prepared:
Drilling Engineer
Page 3
Date
3.0 Tubular Program:
Milne Point Unit
E-41 SB Producer
Drilling Procedure
4.0 Drill Pipe Information:
All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery).
Page 4
H
Hilcrp
En C22
5.0 Internal Reporting Requirements
Milne Point Unit
E-41 SB Producer
Drilling Procedure
5.1 Fill out daily drilling report and cost report on WellEz.
• Report covers operations from 6am to 6am
• 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.
• Ensure time entry adds up to 24 hours total.
• Try to capture any out of scope work as NPT. This helps later on when we pull end of well
reports.
• Enter the MD and TVD depths EVERY DAY whether you are making hole or not.
5.2 Afternoon Updates
• Submit a short operations update each work day to pmazzolinina hilcorp.com, mmyers .hilcorp,
ieneelnhilcpM.com and edinger@hilcorR.com
5.3 Intranet Home Page Morning Update
• 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
• Health and Safety: Notify EHS field coordinator.
• Environmental: Drilling Environmental Coordinator
• Notify Drilling Manager & Drilling Engineer on all incidents
• Submit Hilcorp Incident report to contacts above within 24 hrs
5.5 Casing Tally
• Send final "As -Run" Casing tally to mmyers e hilcorp,com ieneel@hilcoM.com and
cdinger@hilcoM.com
5.6 Casing and Cement report
• Send casing and cement report for each string of casing to mmyers@hilcorp.com
hilcorp.com
ienizel@hilcorp.com and cdingerna 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
lenael@hilcorp.com
Completion Engineer
Taylor Wellman
907.777.8449
907.907.9533
tweliman@hilcorp.com
Geologist
Kevin Eastham
907.777.8316
907.360.5087
keastham@hilcorp.com
Reservoir Engineer
Reid Edwards
907.777.8421
907.250.5081
reedwardsC@hilcorp.com
Drilling Env. Coordinator
Keegan Fleming
907.777.8477
907.350.9439
kflemina@hilcorp.com
EHS Manager
Carl Jones
907.777.8327
907.382.4336
caiones@hilcorp.com
Drilling Tech
Cody Dinger
907.777.8389
509.768.8196
cdineer@hilcorp.com
Page 5
H
Hilco2
Fm®,y
6.0 Planned Wellbore Schematic
OR. KB Ekv.:2fi5/fd Elev_ 217
Milne Point Unit
E-41 SB Producer
Drilling Procedure
Milne Point Unit
Well: MPUE-41
SCHEMATIC Last Completed: J /xx/xxxx
PTD:xxx-xxx
TREE & WELLHEAD
Tree Cameron 2-9/16' SM
WNINead I FMCGenV
9ixe
OPEN HOLE/ CEMENT DETAIL
TAIdY¢w
±2]0 ft3
12-1J4'
UJI-Lead:,1OUrr3/TAh-456¢3
BPF
2 -Leat -1937 tt3 Tab-314ft3
8-52'
Cemadess5¢eem Unerin8-I Ytmk
9ixe
Type
Wt/ Grade/ Conn
ID
Tap
Bt.
BPF
20'
Conductor
N/A/x-52/WeldN(A
GLMw/Du y.. 2-718'.1'
Surface
1065'
N/A
35/8•
Surfam
40/L-8otna,
8.ai5
Surface
6,156'
0.0756
7-5/8'
Tieback
29.]/LSO/H/d 521
6A75
Surface 1
6,006'
O.D159
4-1/Y
I U. 2509 Screens I
Gas Sepaatar. GRS FER N AR
6,006' I
12,38D
.D119
No.
Top MD
Nem
ID
1
131'
GLM:2-7/e' z r Side packet D lvl w/DPSOV
Z347-
2
S,047'
GLMw/Du y.. 2-718'.1'
2347'
3
S,15T
xNNlppLe,22OVw8o
2205'
4
±5,2W
DBmaree Head: WBS
5
±SAI'
Upper Tandem Pump: 134 SM FLEX 175
6
5,224'
toner Tandem Pump: 134 STG FM 175
7
5,246'
Gas Sepaatar. GRS FER N AR
8
5,251'
upper Tandem Seal: ONDBUr PFSA
9
5,256'
1. aver Tandem Seal: G583DBUT SB/SS PM
30
5,265'
Motor: WxP-225Np 27M 51A
31
5,280'
Sensor,Zenah
12
5,283
Centralizes Bmtom@5,285'
13
±G,006'
BOT SMP LT Packet Lim Hanger x"Ir
6.190"
14
±6,006'
7-SAr TieWck Asw.
6.151'
IS
5,015'
rH563.45'HTTC L -801N
16
±13,090"
4-11r Drillable Padcotr Sub
2390'
1]
13095'
WIV Vele LTC B.B 1'Ball on Sea
Top
Top
Btm Btm
14
(MD)
(WD)
(MD) (TVD)
TBD
4-1/2" Screens LINER DETAIL
Jts Top(MD) Top (TVD BLn (MD) Btm (ND)
TBD
TD=13,10D (W) /TD= 1,35D CM) GENERAL WELLINFO
PSM =LIM (M1) / PSTD=4,350 M)
A%:TBD
Oon Date: Future
Edned BY UD 2-12-2019
Page 6
7.0 Drilling / Completion Summary
Milne Point Unit
E-41 SB Producer
Drilling Procedure
MPU E-41 is a grassroots ESP producer planned to be drilled in the Schrader Bluff NB sand. E-41 is part of
an eight well program targeting the Schrader Bluff sand on E -Pad.
The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of
the Schrader Bluff NB sand. An 8.5" lateral section will then be drilled. A 4-1/2" 250µ screen liner will be
run in the open hole section and the well produced with an ESP assembly.
• The Innovation Rig will be used to drill and complete the wellbore.
Drilling operations are expected to commence approximately March 5, 2019, pending rig schedule.
Surface casing will be run to 6,156' MD / 4,328' 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 Innovation to well site
2. NX & Test 13-5/8" 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. N/D diverter, N/U & test 13-5/8" x 5M BOP. H 2 3F'u
5. Drill 8-1/2" lateral to well TD. Run 4-1/2" screen production liner.
6. Run 7-5/8" tieback. .
7. Run production tubing.
8. N/D BOP, N/U 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)
Page 7
H
Hilcorp
Energy Compmy
Milne Point Unit
E-41 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.
• BOPs shall be tested at (2) week intervals during the drilling and completion of MPU E-41. Ensure
to provide AOGCC 24 hrs notice prior to testing BOPS.
• The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment
will be to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial
and subsequent tests). Confirm that these test pressures match those specified on the APD.
• 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.
• All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program
and drilling fluid system".
• 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
• Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office.
AOGCC Regulation Variance Requests: Y—
None requested
Page 8
Summary of BOP Equipment and Test Requirements
Hole Section
Equipment
Test Pressure(psi)
12 1/4"
• 13-5/8" 5M CTI Annular BOP w/ 16" diverter line
Function Test Only
Milne Point Unit
• 13-5/8" x 5M Control Technology Inc Annular BOP
E-41 SB Producer
Initial Test: 250/3000
Hilcorp
E.n CmnryoY
Drilling Procedure
Summary of BOP Equipment and Test Requirements
Hole Section
Equipment
Test Pressure(psi)
12 1/4"
• 13-5/8" 5M CTI Annular BOP w/ 16" diverter line
Function Test Only
• 13-5/8" x 5M Control Technology Inc Annular BOP
• 13-5/8" x 5M Control Technology Inc Double Gate
Initial Test: 250/3000
o Blind ram in him cavity
• Mud cross w/ 3" x 5M side outlets
8-1/2"
13-5/8" x 5M Control Technology Single ram
• 3-1/8" x 5M Choke Line
Subsequent Tests:
• 3-1/8" x 5M Kill line
250/3000
• 3-I/8" x 5M Choke manifold
• Standpipe, floor valves, etc
Primary closing unit: Control Technology Inc. (CTI), 6 station, 3000 psi, 220 gallon accumulator unit.
Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric
triplex pump on a different electrical circuit 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:
• Well control event (BOPS utilized to shut in the well to control influx of formation fluids).
• 24 hours notice prior to spud.
• 24 hours notice prior to testing BOPs.
• 24 hours notice prior to casing running & cement operations.
• Any other notifications required in APD.
Regulatory Contact Information:
AOGCC
Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: iim.regg(cr�alaska.gov
Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guv.schwartz@alaska.gov
Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria. loepp alaska.gov
Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-xxx-xxxx / Email: melvin.rixsenalaska.gov
Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov
Test/Inspection notification standardization format: htW://doa.alaska.gov/opc/forms/TestWitnessNotifhtml
Notification / Emergency Phone: 907-793-1236 (During normal Business Hours)
Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours)
Page 9
9.0 R/U and Preparatory Work
9.1 E-41 will utilize a newly set 20" conductor on E Pad Expansion. 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 R/U.
9.6 Rig mat footprint of rig.
9.7 MIRU Innovation Rig. 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 (<80°F).
9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is
accidentally dropped.
9.11 Ensure 5" liners in mud pumps.
• White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 381 gpm @ 140 spm @
96.5% volumetric efficiency.
Page 10
Milne Point Unit
E-41 SB Producer
Hilcojx
F., C®p.vy
Drilling Procedure
9.0 R/U and Preparatory Work
9.1 E-41 will utilize a newly set 20" conductor on E Pad Expansion. 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 R/U.
9.6 Rig mat footprint of rig.
9.7 MIRU Innovation Rig. 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 (<80°F).
9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is
accidentally dropped.
9.11 Ensure 5" liners in mud pumps.
• White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 381 gpm @ 140 spm @
96.5% volumetric efficiency.
Page 10
H
Hilcorp
�
10.0 N/U 13-5/8" 5M Diverter Configuration
Milne Point Unit
E-41 SB Producer
Drilling Procedure
10.1 N/U 13-5/8" CTI BOP stack in diverter configuration (Diverter Schematic attached to program).
• N/U 20" x 13-5/8" DSA
• N/U 13 5/8", 5M diverter "T".
• NU Knife gate & 16" diverter line.
• Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C).
• Diverter line must be 75 ft from nearest ignition source
• Place drip berm at the end of diverter line.
• Utilized extensions if needed.
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:
• A prohibition on vehicle parking
• A prohibition on ignition sources or running equipment
• A prohibition on staged equipment or materials
• Restriction of traffic to essential foot or vehicle traffic only.
10.4 Set wear bushing in wellhead.
Page 11
10.5 Rig & Diverter Orientation:
75' Radius Clear of Ignition Sources
Page 12
I
.S
■
■ S
26
Milne Point unit
■ 30
9
E-41 SB Producer
■ 6
Hilco
M.�P
Drilling Procedure
10.5 Rig & Diverter Orientation:
75' Radius Clear of Ignition Sources
Page 12
I
.S
■
■ S
26
■
■ 30
9
■
■ 6
25
■
■ 21
11
■
■ 7
18
■
■ 18
20
■
■ 23
E-38
24
■
■ 19
E-39
t4
■
U
E-41
17
I
E-38
E-37
E-39
E-36
IE
E-41
-35
— pIVCrtCr floe
MPU E Pad Expansion �/
'Drawing Not To Scale
i
n
Hilcorp
E^.�p'CamY^Y
11.0 Drill 12-1/4" Hole Section
Milne Point Unit
E-41 SB Producer
Drilling Procedure
11.1 P/U 12-1/4" directional drilling assembly:
• Ensure BHA components have been inspected previously."
• Drift and caliper all components before M/U. Visually verify no debris inside components
11.2
11.3
IIIA
that cannot be drifted.
• Ensure TF offset is measured accurately and entered correctly into the MWD software.
• Be sure to run a UBHO sub for wireline gyro
• Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics
calculations and recommended TFA is attached below.
• Drill string will be 5" 19.54 5-135.
• Run a solid float in the surface hole section.
5" Drill string, HWDP, and Jars will come from Weatherford.
Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor.
ction to section TI
in the Schrader NB sand. Confirm this setting depth
with the Geologist and Drilling Engineer while drilling the well.
• Monitor the area around the conductor for any signs of broaching. If broaching is observed,
Stop drilling (or circulating) immediately notify Drilling Engineer.
• Efforts should be made to minimize dog legs in the surface hole. ESP equipment can be
damaged if run through high dog legs. Keep DLS < 6 deg / 100.
• Hold a safety meeting with rig crews to discuss:
• Conductor broaching ops and mitigation procedures.
• Well control procedures and rig evacuation
• Flow rates, hole cleaning, mud cooling, etc.
• Pump sweeps and maintain mud rheology to ensure effective hole cleaning.
• Keep mud as cool as possible to keep from washing out permafrost.
• Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can
handle the flow rate.
• 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
• Slow in/out of slips and while tripping to keep swab and surge pressures low
• Ensure to leave a "Pump Tangent" section that is approx. 300' long in the directional plan.
The ESP will need a straight section to sit. Target location of ESP pump tangent is 1000'
MD and 200' TVD above target reservoir.
• Ensure shakers are functioning properly. Check for holes in screens on connections.
• 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.
• Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2
minimum at TD (pending MW increase due to hydrates).
Page 13
H
Hilcorp
�Y �N%
Milne Point Unit
E-41 SB Producer
Drilling Procedure
• Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand
drilled.
• Gas hydrates have been encountered on E -Pad, typically around 2100-2400' TVD (oust
below permafrost). Be prepared for hydrates:
• Gas hydrates can be identified by the gas detector and a decrease in MW or ECD
• Monitor returns for hydrates, checking pressurized & non -pressurized scales
• Past wells on E pad have increased MW to 9.8 ppg and added 1-1.5ppb of Lecithin &
.5% lube. After drilling through hydrate sands, MW was cut back to normal
• 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.
• 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.
11.5 12-1/4" hole mud program summary
• 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. f
Depth Interval MW
Surface — Base Permafrost 8.9+
Base Permafrost - TD 9.8 (For Hydrates if need based on offset wells)
MW can be cut once —500' below hydrate zone
• PVT System: MD Totco PVT will be used throughout 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.
• 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.
• 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.
• 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.
Page 14
n
Hilco
E.,C T-
rp
Milne Point Unit
E-41 SB Producer
Drilling Procedure
• 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).
System Type: 8.8-9.8 ppg Pre -Hydrated Aquagel/freshwater spud mud
Properties:
Section
Densi
Viscosit
Plastic Viscosi
Yield Point
AN FL
pH
Tem
Surface 11
8.8-9.8 A
75-175
20-40
25-45
1 <10
8.5-9.0
570E
System Formulation: Gel + FW spud mud
Product
Concentration
Fresh Water
0.905 bbl
soda Ash
0.5 ppb
AQUAGEL
15 - 20 ppb
caustic soda
0.1 ppb (8.5 - 9.0 pH)
BARAZAN D+
as needed
BAROID 41
as required for 8.8 - 9.2 ppg
PAC -L /DEXTRID LT
if required for <10 FL
ALDACIDE G
0.1 ppb
11.6 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity.
11.7 RIH t/ bottom, proceed to BROOH t/ HWDP
• Pump at full drill rate (400-600 gpm), and maximize rotation.
• Pull slowly, 5 —10 It / minute.
• Monitor well for any signs of packing off or losses.
• Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay
balling.
• If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until
parameters are restored.
11.9 No open hole logging program planned.
Page 15
H
Hilcorp
E.n CmnyvY
12.0 Run 9-5/8" Surface Casing
12.1 R/U and pull wearbushing.
Milne Point Unit
E-41 SB Producer
Drilling Procedure
12.2 R/U Weatherford 9-5/8" casing running equipment (CRT & Tongs)
• Ensure 9-5/8" TXP x DS50 XO on rig floor and M/U to FOSV.
• Use BOL 2000 thread compound. Dope pin end only w/ paint brush.
• R/U of CRT if hole conditions require.
• R/U a fill up tool to fill casing while running if the CRT is not used.
• Ensure all casing has been drifted to 8.75" on the location prior to running.
• Be sure to count the total # of joints on the location before running.
• Keep hole covered while R/U casing tools.
• Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info.
12.3
12.4
P/U shoe joint, visually verify no debris inside joint.
Continue M/U & thread locking 120' shoe track assembly consisting of.
9-5/8"
Float Shoe
1 joint
— 9-5/8" DWC, 2 Centralizers 10' from each end w/ stop rings
1 joint
— 9-5/8" DWC, I Centralizer mid joint w/ stop ring
9-5/8"
Float Collar w/ Stage Cementer Bypass Baffle 'Top Hat'
1 joint
— 9-5/8" DWC, 1 Centralizer mid joint with stop ring
9-5/8"
HES Baffle Adaptor
• Ensure bypass baffle is correctly installed on top of float collar.
This end up.
Bypass Baffle
• Ensure proper operation of float equipment while picking up.
• Ensure to record S/N's of all float equipment and stage tool components.
Page 16
12.5 Float equipment and Stage tool equipment drawings:
Type H ES Cementer
Part No.
SO No.
Closing Sleeve
No. Shear Pins
Opening Sleeve
No. Shear Pins
ES Cementer
Depth
Baffle Adapter (if used)
ID
Depth
Bypass or Shut-off Baffle
1D
Depth
Float Collar
Depth
'Reference Casing
Sales tlanual
Section 5
Page 17
"A
Overall Length
B
Mn ID After Dnllout
C
Mar. Taol OD
D
Opener Seat ID
E
Closing Seat ID
Plug Set
Part No.
Closing Plug
Shul- ff Plug
OD
Bypass Plug
(d used)
I RBrcrp B41 RunnmB arias
ES -B Cementer
Shut On PIK
BaWAGpter
15
By-0ass MR
By Pass Beflb
Ghat Cdly
rbat Shoe
Milne Point unit
E-47 SB Producer
HilDoT
Drilling Procedure
12.5 Float equipment and Stage tool equipment drawings:
Type H ES Cementer
Part No.
SO No.
Closing Sleeve
No. Shear Pins
Opening Sleeve
No. Shear Pins
ES Cementer
Depth
Baffle Adapter (if used)
ID
Depth
Bypass or Shut-off Baffle
1D
Depth
Float Collar
Depth
'Reference Casing
Sales tlanual
Section 5
Page 17
"A
Overall Length
B
Mn ID After Dnllout
C
Mar. Taol OD
D
Opener Seat ID
E
Closing Seat ID
Plug Set
Part No.
Closing Plug
Shul- ff Plug
OD
Bypass Plug
(d used)
I RBrcrp B41 RunnmB arias
ES -B Cementer
Shut On PIK
BaWAGpter
15
By-0ass MR
By Pass Beflb
Ghat Cdly
rbat Shoe
H
Hilcorp
Mp
Milne Point Unit
E-41 SB Producer
Drilling Procedure
12.6 Continue running 9-5/8" surface casing
• Fill casing while running using fill up line on rig floor.
• Use BOL 2000 thread compound. Dope pin end only w/ paint brush.
• Centralization:
• 1 centralizer every joint t/ — 1000' MD from shoe
• 1 centralizer every 2 joints to 2,000' above shoe (Top of Ugnu)
• Verify depth of lowest Ugnu water sand for isolation with Geologist
• Utilize a collar clamp until weight is sufficient to keep slips set properly.
• Break circulation prior to reaching the base of the permafrost if casing run indicates poor
hole conditions.
• 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).
• Install centralizers over couplings on 5 joints below and 10 joints above stage tool.
• Do not place tongs on ES cementer, this can cause damaged to the tool.
• Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi.
9-5/8" 409 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
Page 18
IJ
H
Hilcorp
arcr®Cm�W^9
TXP® BTC
Outside Diameter 5.625 in
Wall Thickness 0.395m.
Grsde L90 TypeP
IAn, Wall
27.5%
Thickness
connection OO Option REGULAR
Connection OD
REGULAR
Option
Tet Band: Red
Drift
API 9tarulard
Type casing
Milne Point Unit
E-41 SB Producer
Drilling Procedure
M,— 1111) a
I-) Grade Leo
too
Type 1
connection OO Option REGULAR
COUPLING
PIPE Eddy
Eody: Red
Tet Band: Red
1%bard: S.
2nd Band:
2nd Bard. -
Brown
Sed Band : -
3rd Band: -
iWiThickne55
41h Sana -
GEOMETRY
Threads perN
5
connection OO Option REGULAR
PERFORMANCE
Normal OD
am in.
Nominal Weight
40 hoe.w
DIM
9.679..
Nominal ID
SMin.
iWiThickne55
0.395 in,
Pion End Might
39.97lb5.R
OD Tokaance API
PERFORMANCE
Body Yeld Smeriph 916 x1000 As intemalyvid 5750 psi WAYS smite,
Cc4uPse 3090 psi
GEOMETRY I
Connection OD 1062 in Comirg ieaot 10.925 in. Connection ID 9823 in.
Make-up Less 4.991 in.
Threads perN
5
connection OO Option REGULAR
PERFORMANCE
Tension E6ciencu 100.0%
Amt Yait shemgth
916.000x1000
Internal Pressure apecdy m 5750.000 psi
lbs
Canpreesion ESxiency 100%
Compression Snemgth
916 000 x1000
1.1ax. Aho gable Gentling 38 `i100 it
Its
Ecemal Pmvne Capacity 3090.000 P.
MAKE-UPTORQUES
hfaunum 19960ft-ffi Optimum 20960 ftAbe Alamnum 23060 ftdbe
OPERATION LIMB TORQUES
Opereva Toque 356008:,5 Yield Torque 43400 fi-Ibs
Notes
This connection is fully interchangeable with
TXPW BTC - 9.625 in - 36143.5147153.5158.4 Ibsift
11] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API
5C31 ISO 10400 - 2007.
Datasheet is also valid for Special Bevel option when applicable - except for Coupling Face Load, which will be reduced.
Please contact a local Tenaris technical sales representative.
Page 19
i
Milne Point Unit
E-41 SB Producer
Drilling Procedure
12.8 Continue running 9-5/8" surface casing
• Fill casing while running using fill up line on rig floor.
• Use BOL 2000 thread compound. Dope pin end only w/ paint brush.
• Centralization:
o 1 centralizer every 2 joints to base of conductor
12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if
necessary.
12.10 Slow in and out of slips.
12.11 P/U landing joint and M/U 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.
12.12 Lower casing to setting depth. Confirm measurements.
12.13 Have slips staged in cellar, along with necessary equipment for the operation.
12.14 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement
job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible
reciprocate casing string while conditioning mud.
Page 20
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.
• How to handle cement returns at surface. Ensure vac trucks are on standby and ready to
assist.
• Which pumps will be utilized for displacement, and how fluid will be fed to displacement
PUMP.
• Ensure adequate amounts of water for mix fluid is heated and available in the water tanks.
• 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
• Review test reports and ensure pump times are acceptable.
• 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 R/U 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 I" stage, confirm actual cement volumes with cementer after TD is reached.
13.8 Cement volume based on annular volume + 30% open hole excess. Job wilrcoo lead&tail, TOC brought to stage tool.
Estimated 11' Stage Total Cement Volume:
Section
Calculation
Vol (bbl)
of (ft3)
Milne Point Unit
E-41 SB Producer
Hilco
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.
• How to handle cement returns at surface. Ensure vac trucks are on standby and ready to
assist.
• Which pumps will be utilized for displacement, and how fluid will be fed to displacement
PUMP.
• Ensure adequate amounts of water for mix fluid is heated and available in the water tanks.
• 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
• Review test reports and ensure pump times are acceptable.
• 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 R/U 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 I" stage, confirm actual cement volumes with cementer after TD is reached.
13.8 Cement volume based on annular volume + 30% open hole excess. Job wilrcoo lead&tail, TOC brought to stage tool.
Estimated 11' Stage Total Cement Volume:
Page 21
asi sx
'3 q,j
Section
Calculation
Vol (bbl)
of (ft3)
12-1/4" OH x 9-5/8"
0
(5,156'- 2500') x .0558 bpf x 1.3 =
192.6
1081.7
J
Casing
Total Lead
192.6
1081.7
12-1/4" OH x 9-5/8"
(6,156'- 5,156') x.0558 bpf x 1.3 =
72.5
407
Casing
~
9-5/8" Shoe Track
120'x .0758 bpf =
9.1
51.09
Total Tail
81.6
458
Page 21
asi sx
'3 q,j
n
Hill=Eo Cm WY
Milne Point Unit
E-41 SB Producer
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.
.JY Z�
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.
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:
6,036' x .0758 bpf = 457.5 bbls
40 bbls of water to be left behind stage tool
q (i6'G5J
13.12 Monitor retums 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, t4.5 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 too -rifle 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
Page 22
Lead Slurry
Tail Slurry
System
ExtendaCEM Tm System
SwiftCEM TM System
Density
11.7 lb/gal
15.8 lb/gal
Yield
4.298 ft3/sk
1.16 ft3/sk
Mixed
Water
21.13 gal/sk
5.04 gal/sk
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.
.JY Z�
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.
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:
6,036' x .0758 bpf = 457.5 bbls
40 bbls of water to be left behind stage tool
q (i6'G5J
13.12 Monitor retums 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, t4.5 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 too -rifle 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
Page 22
Milne Point unit
E-41 SB Producer
Hilcorp Drilling Procedure
o2
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.
13.16 Increase pressure to 3300 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 2nd 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.
Page 23
Second Stage Surface Cement Job:
Milne Point Unit
E-41 SB Producer
Drilling Procedure
13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive
strength. Hold pre job safety meeting.
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 10.5 ppg tuned spacer.
13.22 Mix and pump curt per below recipe for the 2"d 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 brought to surface. However cement will continue to be
pumped until clean spacer is observed at surface.
Estimated 2"d Stage Total Cement Volume:
Cement Slurry Design (2nd stage cement job):
Section
Calculation
Vol (bbl)
Vol (ft3)
SwiftCEM'M System (Hal Cem)
20" Conductor x 9-5/8" Casing
(110') x .26 bpf x 1=
28.6
161
J
12-1/4" OH x 9-5/8" Casin
(2000'- 110') x .0558 bpf x 3 =
316.4
1776.3
Total Lead
345
1937
12-1/4" OH x 9-5 8" Casin
(2500'- 2000') x .0558 bpf x 2 =
55.8
314
~
Total Tail
55.8
314
Cement Slurry Design (2nd stage cement job):
Page 24
Lead Slurry
Tail Slurry
System
Permafrost L
SwiftCEM'M System (Hal Cem)
Density
10.7 lb/gal
15.8 lb/gal
Yield
4.3279 ft3/sk
1.16 ft3/sk
Mixed
Water
21.405 gal/sk
5.08 gal/sk
Page 24
n
Hilcorp
M�
Milne Point Unit
E-41 SB Producer
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:
2500' 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.
pose ES
13.29 Land closing plug on stage collar and pressure up to 1000 — 1500 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 annulus for returns during surface cement
job. Set slips
13.30 Make initial cut on 9-5/8" final joint. L/D 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.
Y
rr✓_
_
Gyri Ensure to report the following on wellez:
•
Pre flush type, volume (bbls) & weight (ppg)
•
Cement slurry type, lead or tail, volume & weight
•
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 jenQelna hilcorp. com and
cdingerghilcorp com This will be included with the EOW documentation that goes to the AOGCC.
Page 25
H
HilcoN
U�
14.0 BOP NX and Test
Milne Point Unit
E-41 SB Producer
Drilling Procedure
14.1 N/D the diverter T, 16" knife gate, 16" diverter line & N/U 11" x 13-5/8" 5M casing spool.
Ili►��/LIIfc3�F.31i!�.yT[�Y�ei�]" 3Y.7INME
• 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
• Double gate ram should be dressed with 2-7/8" x 5.5" VBRs in top cavity, blind ram in
bottom cavity.
• Single ram should be dressed with 2-7/8" x 5.5" VBRs or 5" Solid Body Rams
�^ • N/U bell nipple, install flowline.
Nok' p` 1 ! Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to
C' '/° mud cross).
�w9i • Install (1) manual valve & HCR valve on choke side of mud cross. (manual valve closest to
mud cross)
14.3 Run 5" BOP test plug (if not installed previously).
• Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min.
• Confirm test pressures with PTD
}� f' • Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure
is trapped underneath test plug
• Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech
14.4 R/D BOP test equipment
14.5 Dump and clean mud pits, send spud mud to G&I pad for injection.
14.6 Mix 8.9 ppg Baradrill-N fluid for production hole.
14.7 Set wearbushing in wellhead.
14.8 Rack back as much 5" DP in derrick as possible to be used while drilling the hole section.
14.9 Ensure 5" liners in mud pumps.
Page 26
11
n
Hilcorp
P . Y
15.0 Drill 8-1/2" Hole Section ( 1 &J )
15.1 M/U 8.5" Cleanout BHA (Milltooth Bit & 1.220 PDM)
Milne Point Unit
E-41 SB Producer
Drilling Procedure
15.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out
stage tool or ESIPC.
15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report.
15.4 R/U and test casing to 2500 psi / 30 min. Ensure to record volume / pressure and plot on FIT
graph. AOGCC reg is 50% of burst = 6870 / 2 = —3500 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.
K15.6 CBU and condition mud for FIT.
15.7 Conduct FIT to 12 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 & LD Cleanout BHA
15.9 P/U 8-1/2" directional BHA.
• Ensure BHA components have been inspected previously.
• Drift and caliper all components before M/U. Visually verify no debris inside components that
cannot be drifted.
• Ensure TF offset is measured accurately and entered correctly into the MWD software.
• Ensure MWD is R/U and operational.
• Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics
calculations and recommended TFA is attached below.
• Drill string will be 5" 19.5# S-135 DS50 & NC50.
• Run a ported float in the production hole section.
15.10 8-1/2" hole section mud program summary:
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.
Page 27
H
Hilcor
�Z�p
E
Milne Point Unit
E-41 SB Producer
Drilling Procedure
• 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.
• 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 > 8.5 (hole diameter) for
sufficient hole cleaning
• Run the centrifuge continuously while drilling the production hole, this will help with
solids removal.
• Dump and dilute as necessary to keep drilled solids to an absolute minimum.
• MD Totco PVT will be used throughout 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 Baradrill-N drilling fluid
Properties:
Section
Density
Plastic Viscosity
Yield Point
Total Solids
MBT
HPHT
Production
8.9-9.5
15-25
20-25
<10%
<7
<11.0
System Formulation: Baradrill-N
Product
Concentration
Water
0.955 bbl
KCL
11 ppb
KOH
0.1 ppb
N -VIS
1.0 — 1.5 ppb
DEXTRID LT
5 ppb
BARACARB 5
4 ppb
BARACARB 25
4 ppb
BARACARB 50
2 ppb
BARACOR 700
1.0 ppb
BARASCAV D
0.5 ppb
X-CIDE 207
0.015 ppb
Page 28
15.11 TIH with 8-1/2" directional assembly to bottom
15.12 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid
Milne Point Unit
E-41 SB Producer
Drilling Procedure
15.13 Begin drilling 8.5" hole section, on -bottom staging technique:
• Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8k.
• Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations
• If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to P/U
off bottom and restart on bottom staging technique. If stick slip continues, consider adding
.5% lubes
15.14 Drill 8-1/2" hole section to section TD per Geologist and Drilling Engineer.
• Flow Rate: 350-550 gpm, target min. AV's 200 ft/min, 385 gpm
• RPM: 120+
• 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.
• Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low
• Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex:
concretion deflection
• Monitor Torque and Drag with pumps on every 5 stands
• Monitor ECD, pump pressure & hookload trends for hole cleaning indication
• Surveys can be taken more frequently if deemed necessary.
• 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 stopping with the
BHA across the sand for any extended period of time.
• 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.
• Target ROP is as fast as we can clean the hole without having to backream connections
• Schrader Bluff NB Concretions: Historically 4-6% of lateral
• MPD will be used to monitor for abnormal pressure on connections
15.15 Reference: Open hole sidetracking practice:
• 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.
• Attempt to lowside in a fast drilling interval where the wellbore is headed up.
• Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string
back and forth. Trough for approx. 30 min.
• 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
• Once well has TD'd the production lateral, swap to the completion AFE
Page 29
Milne Point Unit
E-41 SB Producer
Drilling Procedure
Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent
stream, circulate more if necessary
Ensure mud has necessary lube % for running liner
If seepage losses are seen while drilling, consider reducing MW at TD to 9.Oppg minimum
15.17 Monitor the returned fluids carefully while conditioning the mud. After 4 (or more) BU,
Perform production screen test (PST). Reduce flow rate and RPM as per PST Test Procedure.
The mud has been properly conditioned when the mud will pass the production screen test (3 one
liter samples passing through the screen in the same amount of time which will indicate no
plugging of the screen). Reference PST Test Procedure
• SB NB sand screen completion require passing PST with 250µ coupons
• Circulate and condition mud as much as needed to pass the production screen test
15.18 BROOH with the drilling assembly to the 9-5/8" casing shoe
• Circulate at full drill rate (385 gpm max).
• Rotate at maximum rpm that can be sustained.
• Limit pulling speed to 5 —10 min/std (slip to slip time, not including connections).
• If backreaming operations are commenced, continue backreaming to the shoe
15.19 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while
BROOH
15.20 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps.
15.21 Monitor well for flow. Increase mud weight if necessary. If abnormal pressure has been seen,
displace to higher MW (determined on closed connections) from surface shoe to surface.
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
15.22 POOH and LD BHA. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball
drops.
15.23 Continue to POH and stand back BHA if possible. Rabbit DP on TOH, ensure rabbit diameter is
sufficient for future ball drops.
Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any
additional logging runs conducted.
Page 30
0
H
Hilcorp
Emgyf®geY
16.0 Run 4-1/2" Production Screen Liner
Mi=Procedure
E-4
Drill
16.1. 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:
• P/U & M/U 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 M/U and
available prior to running the first joint of 4-1/2" screen.
• 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.
16.2. 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:
• P/U & M/U 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). M/U 2-3/8"
and then 4-1/2" to triple connect.
• This joint shall be fully M/U with crossovers prior to running the first joint of wash pipe.
• 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.
16.3. R/U 4-1/2" screen running equipment.
• Ensure 4-1/2" x DS -50 crossover is on rig floor and M/U to FOSV.
• Ensure all casing has been drifted on the deck prior to running.
• Be sure to count the total # of joints on the deck before running.
• Keep hole covered while R/U casing tools.
• Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info.
16.4. Run 4-1/2" screen production liner — Reference screen handling and running procedure.
• Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only w/ paint
brush. Wipe off excess. Thread compound will plug the screens.
• Use Hydril 625 stabbing guide on screen joints
• Utilize a collar clamp until weight is sufficient to keep slips set properly.
• Run packoff and float shoe on bottom.
• 4-1/2" Screens should auto —fill, top off with completion brine if needed
• Swell packers will not be required on this completion unless the well is drilled out of zone
Page 31
4-%11 Lower Completion Running Order
Milne Point Unit
E-41 SB Producer
Drilling Procedure
• 4-'/2" Float Shoe, BTC box (Bakerlok all 4-'/z" shoe track connections below the last semi-
premium/premium connection)
• 4-%2" WIV (wellbore isolation valve), BTC box x pin
• 4-'/2" spacer joint, —30 - 40', IBT-M box x BTC pin
• 4-'/2" Drillable Pac Off Sub, IBT-M box x pin
• 5'4.5" 13.5# Hydril 625 Box X 4.5" 12.6# IBT Pin crossover
• 1 joint 4-'/2" 13.5#/ft L-80 Hydril 625 Liner (optional)
• 4-'/2" 13.5#/ft L-80 Hydril 625 Screens to 13,541' MD
• Joints of 4-1/2" 13.5#/ft Hydril 625 L-80 Liner (liner lap) as needed
•
4'4.5" 13.5# Hydril 625 Box X Pin pup joint (safety joint)
• 7" 26# HYD 563 Box x4.5" 13.5# Hydril 625 Pin crossover
• Baker SLZXP Liner Hanger/Liner Top Packer w/ 7" 26# Hydril 563 pin
4-1/211 11.5 if I. -SO Hydril 62.5 Torque
OD
Minimum
Maximum
Operating Torque
4.5"
8,000 ft -lbs
11,300 ft -lbs
11,300 ft -lbs
Page 32
Wedge 625® �.-10!31/1017
Otdside Diameter
4.600 in.
Milne Point Unit
87.5%
,
E-41 SB Producer
HilcoT
tl� �
Drilling Procedure
Wedge 625® �.-10!31/1017
Otdside Diameter
4.600 in.
Min. Wall
87.5%
,
GEOMETRY
Thickness
(') Grade L80
Nominal OD
4500 in.
Nominal Weight
13.50InIft
Type 1
3.795in,
Wall Thickness
0.290 in.
Connection OD
REGULAR
COUPLING
PIPE BODY
ODTokrance
AW
Option
PERFORMANCE
Body: Red
1st Bang Red
Grade
L80 Type V
Drift
API Standard
1st Band: Broom
2nd Band'
Cdlapse
8510w
2m1 Band: -
Brown
CONNECTION DATA
3rd Band: -
3rd Band: -
GEOMETRY
Type
Casing
4th Band: -
PIPE BODY DATA
,
GEOMETRY
Nominal OD
4500 in.
Nominal Weight
13.50InIft
Drift
3.795in,
Nominal 10
3.920 h.
Wall Th1amn
0390 in.
Wain End Wepht
13.05Ibsft
ODTokrance
AW
PERFORMANCE
Body Yell Birength
307 x1000 nm
imemal YNE
9020 psi
sws
90000 psi
Cdlapse
8510w
CONNECTION DATA
GEOMETRY
Ccnnede 00
4.714 in.
Connection 10
3.819 in.
Make-up Loss
1930 in.
Threads per in
3.59
Conn on OD Option
REGULAR
' PERFORMANCE
Tensan Effi ren
910%
Joint Yekl Svength
279.370 x1000
Inwnal Pressure Capacny
9020.000 psi
lbs
Compression Efioenry
915%
Compnsson SvengN
290.115x1000
Max MM&Ie Benclim
73.7.1100ft
8r5
E�al Pressure Capawy
8540.000 psi
MAKE-UP TORQUES
Minimum
8000 R -lbs
Op4mum
9600f"n
Mamnum
12900 P.ibs
OPERATION LIMIT TORQUES
Opernng Torque
12800 Rdbs
YlWd Tovque
15000ft4bs
l
Page 33
H
Hilcorp
E�x
Milne Point Unit
E-41 SB Producer
Drilling Procedure
Note: Blank Pipe and Swell Packers may be ran if any out of zone excursion occur during lateral drilling
16.6. Pick up enough liner to provide for approximately 150' overlap inside 9-5/8" casing.
• 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. RAJ false rotary and run 2-3/8" 6.4 # Inner String
• Drift 2-3/8" inner string with minimum 1.5" drift (WIV closing ball 1.25")
Note: Once inner string in run and set inside packoff, displace 9-5/8" casing back to PST passed
drilling mud with lubricants added.
16.8. 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.
16.9. M/U liner hanger/liner top packer to inner string and 4-1/2" liner. Fill liner tieback sleeve with
"Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packof. .
Wait 30 min for mixture to set up.
16.10. Note PUW, SOW, ROT and torque. Run liner in the hole one stand and pump through liner
hanger to ensure a clear flow path exists.
16.11. Displace 9-5/8" casing back to lubricated mud.
16.12. RIH w/ liner on DP no faster than 30 ft/min — this is to prevent buckling the liner and drill string.
Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down
running speed if necessary.
16.13. The screens and inner string will prevent the DP from auto filling. Fill DP with PST passed mud
every 5 stands, more frequently if SOW trend indicates.
16.14. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe
depth + S/O depth every stand. Record torque value if it becomes necessary to rotate the string
to bottom.
16.15. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10,
& 20 rpm
16.16. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure
shoe enters correct hole.
16.17. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in
tension.
,I/"-
Page
I//
Page 34
H
Hilcorp
e� 42
16.18. Rig up to pump down the work string with the rig pumps.
Milne Point Unit
E-41 SB Producer
Drilling Procedure
NOTE: The wellbore will be swapped over to brine after the liner has reached TD to keep
from plugging the screens with solids. The success of this well depends upon the screens not
becoming plugged with solids.
16.19. Break circulation and begin displacing wellbore to 2% KCl/NaCl brine, ensure weight matches
MW or previous brine weights. Begin circulating at —I BPM and monitor pump pressures.
Slowly bring rate up while swapping the lateral to brine. Pump train as follows: 20 bbl high vis
sweep / 2 x OH volume brine / 40 bbl SAPP pill #1 / 50 bbl brine / 40 bbl SAPP pill 42 / 50 bbl
brine / 40 bbl SAPP pill #3.
16.20. Ensure circulation pressures do not exceed set pressure for liner hanger pusher tool.
16.21. Monitor pump pressures closely and adjust pump rate if the well appears to be packing off at the
swell packers (if run). Note all losses. Confirm all circulating pressures with Baker. Capture mud
for reconditioning and reuse if possible
16.22. Monitor the returned fluids carefully during displacement. Perform production screen test (PST).
The wellbore has been properly conditioned when the return fluid will pass the production screen
test (3 one liter samples passing through the screen coupon in the same amount of time which
will indicate no plugging of the screens).
16.23. Circulate out SAPP pills 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.
16.24. Shut down pumps. Drop setting ball down the workstring and pump slowly (1-2 bpm). Slow
pump before the ball seats. Do not allow ball to slam into ball seat. Pressure up to 1,500 psi to
shift the wellbore isolation valve closed.
16.25. Continue pressuring up to 2700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes.
Slack off 20K lbs on the SLZXP to ensure the HRDE setting tool is in compression for release
from the SLZXP liner hanger/packer. Continue pressuring up to 4500 psi to activate the
hydraulic pusher tool to set the SLZXP packer. This will also release the HRDE running tool.
16.26. Bleed DP pressure to zero, 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 50k4 again,
16.27. PU to neutral weight, close BOP and test annulus to 1500 psi for 10 min and chart record same.
16.28. 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.
16.29. P/U above liner top packer and displace well to completion fluid.
Page 35
16.30. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned,
LDDP on the TOR L/D 2-3/8" inner string.
Page 36
Milne Point Unit
E-41 S8 Producer
Hilcorp
E� ®E�y
Drilling Procedure
16.30. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned,
LDDP on the TOR L/D 2-3/8" inner string.
Page 36
17.0 Run 7-5/8" Tieback
Milne Point Unit
E-41 SB Producer
Drilling Procedure
17.1 RIH with mule shoe on 5" DP to Liner Top and circulation Liner Top and SBE clean. POOH.
17.2 R/U and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder
to be used for tie -back space out calculation. Install and test 7-5/811(250/3000 psi) solid body
casing rams.
17.2 R/U 7-5/8" casing handling equipment.
• Ensure XO to DP made up to FOSV and ready on rig floor.
Rig up computer torque monitoring service.
String should stay full while running, r/u fill up line and check as appropriate.
17.3 P/U tieback seal assembly and set in rotary table. Ensure 7-5/8" seal assembly has x4 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.
17.4 M/U first joint of 7-5/8" to seal assy.
l/
17.5 Run 7-5/8" 29.7# H521 tieback to position seal assembly two joints above tieback sleeve.
Record up & down weights.
• Following running procedure outlined above.
Page 37
Wedge 5218
Milne Point unit
E-41 SB Producer
Hilcorp
XC,
Drilling Procedure
Wedge 5218
--........1116312016
Outside BiamNer
7ffis n.
Min. Wall
BT.S`
Thlekness
G,.& LBO
ow
T
Typo 1
Type
Wall Thickness
0375 n.
Comevti"OD
REGULAR
Option
GOWUNG
MEBOOY
Bahr Red
151 amid Rad
Grad.
LBOTypav
Orin
A 15Wndard
19 Bard: Brown
2rd Dan
2rd Bard -
Bram
TYP.
Gasing
3rd Ban¢ •
331d Gard.
4th
PIPE BODY DATA
GEOMETRY
�,
NaminalOG
]R3 m.
bpmnal •R.mpM
2S.Mt m
Pnll
6.T9in.
Npminal6)
6.975:n.
'will ViKknos
0.379:a
R.M E. w.krlt
29Mlt,t
GO T.W..
A£I
J
EOOj Ypd Strorglh
603 r1UCO 1az
1m.m.L Yn1:1
6890 KI
611Y9
IOOGO On
c.lapm
4:"v..
CATH
t GEOMETRY
Gpnnpam GO
?.947,n
Gunn.clzry 10
000n r
3333. .q: Vs:
3 700:n.
Thwldspaln
310
Cpnn.clm GGC zc,
R£GUTAR
PERFORMANCE
l
T.nWE16[a ,
]1TM
Jam YOld st,.Vb:
4062 .1[OJ
NWmal Preazurp Capa[lR
68"A00 pu
Ip:
Gompruslon EaxG v
BTA A
Gpmppssgn 5nvnbCi
697Ai5.1[G0
Wa A90wa0b 0sAM)
34S'1100 tI
Iaz
£at.Tal P .s^na. capra:lty 4790!-00 P.
' MAKE-UP TORQUES
wimum 54N t -x Opamum 1010014L's Stadmum 14]"NMs
OPERATION LIMIT TORQUES
Opo.wgT ii.. 390"1..-I.z Y.0 Top.. 93000? --lis
Notes
This connection is I^ interchangeable with -
Wedge 521 a - 7.625 in. - 26.4133.7139 IbRM
Connections with DopelesstD Technology are fully campathle with tl, a same connection in its Standard ver n
Page 38
17.6 M/U 7-5/8" to DP crossover.
Milne Point Unit
E-41 SB Producer
Drilling Procedure
17.7 M/U stand of DP to string, and M/U top drive.
17.8 Break circulation at 1 bpm and begin lowering string.
17.9 Note seal assembly entering tieback sleeve with a pressure increase, Stop pumping and bleed off
pressure, leave standpipe bleed off valve open.
17.10 Continue lowering string and land out on no-go. Set down 5 — l Ok lbs. Mark the pipe at this
depth as "NO-GO DEPTH".
17.11 P/U string & remove unnecessary 7-5/8" joints.
17.12 P/U hanger assembly and space out. M/U (or L/D) necessary joints and pup joints to position
seal assembly 1 ft above "NO-GO DEPTH" when tie -back hanger lands out in wellhead.
17.13 Ensure circulation is possible through 7-5/8" string.
17.14 RU and circulation corrosion inhibited brine in the 9-5/8" x 7-5/8" annulus.
7.15 With seals stabbed into SBE, Spot diesel freeze protection from 2500' to surface in 7-5/8" x 9-
5/8" annulus by reverse circulating through the holes in the seal assembly. Ensure annular
pressure are limited to prevent casing collapse of 7-5/8", verify collapse pressure of 7-5/8" tie
back.
17.16 Slack off and land hanger.
17.17 Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on
morning rpt.
17.18 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint.
Set tubing hanger pack off. RILDS. Test void to 3000 psi / 10 min.
17.19 R/D casing running tools.
17.20 Test 7-5/8" x 9-5/8" production annulus to 1000 psi / 30 min.
17.3 Set test plug and change top rams from 7-5/8" to 2-7/8" x 5-1/2" VBR. Test annular and lower
Ily rams to 2-7/8" test joint, 250 low / 3000 psi high.
Page 39
n
Hilcorp
18.0 Run ESP Assembly
Milne Point Unit
E-41 SB Producer
Drilling Procedure
18.1 RU spooler with ESP power cable and heat trace. RU two 3/8" capillary string spoolers. The
capillary strings should be filled with hydraulic fluid.
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 2-7/8" 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.
i. Ensure appropriate well control crossovers on rig floor and ready.
ii. Monitor displacement from wellbore while RIH.
• Centrilift ESP Assembly with bottom of assembly @ predetermined depth
• 10' 2-7/8" 6.5#, L-80 Pup Joint
• 1 joint 2-7/8" 6.5#, L-80 EUE 8rd tubing
• 2-7/8" "XN" nipple (2.313" packing bore / 2.205" No -Go ID)
• 3 joints 2-7/8" 6.5#, L-80 EUE 8rd tubing
• 10' 2-7/8" 6.5#, L-80 Pup Joint
• GLM 2-7/8" x 1" GLM w/ dummy installed
• 10' 2-7/8" 6.5#, L-80 Pup Joint
• 2-7/8" 6.5#, L-80 EUE 8rd tubing
• 10' 2-7/8" 6.5#, L-80 Pup Joint
• GLM 2-7/8" x 1" w/ SO @ --140' MD
• 10' 2-7/8" 6.5#, L-80 Pup Joint
• 3 joints 2-7/8" 6.5#, L-80 EUE 8rd tubing
• Tubing Hanger
o Check the conductivity of electric cable every 2,000' and every new splice
while running in hole.
o Function test the capillary tube every 2,000' when checking the
conductivity of the electric cable.
Page 40
H
Hilcorp
X�
Milne Point Unit
E-41 SB Producer
Drilling Procedure
o Use Cannon clamps on every joint to secure the capillary tube.
o The make up torque values for 2-7/8" L-80 6.59 EUE 8rd tubing are:
Minimum: 1,730 ft -lb, Optimum: 2,300 ft -lb, and maximum: 2,800 ft -lb.
o The 2-7/8" L-80 6.5# EUE 8rd tubing performance properties are:
Body Yield: 145,000#, Burst: 10,570 psi, Collapse: 11,160 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 2-7/8" x 7-5/8" annulus (Volume should 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.
19.0 RDMO
19.1 REMO Innovation Rig
Page 41
20.0 Innovation Rig Diverter Schematic
3.118' Kill
13.518
Technology
13
Page 42
ontrol Technology
3-5'8.5M Conbol
echrabgy Double Ram
-1r8' Choke Line
—16' Diverter Line
Milne Point unit
E-41 SB Producer
Hilcrp
E. z
Drilling Procedure
20.0 Innovation Rig Diverter Schematic
3.118' Kill
13.518
Technology
13
Page 42
ontrol Technology
3-5'8.5M Conbol
echrabgy Double Ram
-1r8' Choke Line
—16' Diverter Line
21.0 Innovation Rig BOP Schematic
3-1/8" Kill
13-5/8" NOM
9-5/8" BTC Btm x
10.5" -4 SA Pin Top
W/ Primary Seal
Page 43
X13-5/8" 5M Control Technology
Annular BOP
—13-5/8' 5M Control
J Technology Double Ram
13.5/8" x 5M
—11" x 5M
\-2-1/16"x 5M
—13-5/8"x 5M
\-2-1/16"x x 5M
.asing
Casing
—3-1/8' Choke line
13-5/8" 5M Control
Technology Single Ram
Milne Point unit
E-41 SB Producer
Hilc
� ��,
Drilling Procedure
21.0 Innovation Rig BOP Schematic
3-1/8" Kill
13-5/8" NOM
9-5/8" BTC Btm x
10.5" -4 SA Pin Top
W/ Primary Seal
Page 43
X13-5/8" 5M Control Technology
Annular BOP
—13-5/8' 5M Control
J Technology Double Ram
13.5/8" x 5M
—11" x 5M
\-2-1/16"x 5M
—13-5/8"x 5M
\-2-1/16"x x 5M
.asing
Casing
—3-1/8' Choke line
13-5/8" 5M Control
Technology Single Ram
22.0 Wellhead Schematic
I : F
Page 44
Milne Point Unit
AIO-25-17
",RGUEL
E-41 SB Producer
Hilc
MT,
Drilling Procedure
22.0 Wellhead Schematic
I : F
Page 44
-V 4.1 I'll 0,
'"D 2495
0,"0"
0 'Seer s..1 -7O I-
W"
6 50 91Y PGC
146 L0
p
5EH 5 SLIM HOLE
SURFACE NELLNEAD LAYDUT
16 H 9 `,8 1 7 a 4 1117
CASPIC. PROGRAM,
1-51, 1 4 PIG bf.
0MIE -sail
.R, W. CIO 5330
AIO-25-17
",RGUEL
MOICL IS
25 IT
IIA
IFL AI
A
J- rlhg'A
C,
-V 4.1 I'll 0,
'"D 2495
0,"0"
0 'Seer s..1 -7O I-
W"
6 50 91Y PGC
146 L0
p
5EH 5 SLIM HOLE
SURFACE NELLNEAD LAYDUT
16 H 9 `,8 1 7 a 4 1117
CASPIC. PROGRAM,
1-51, 1 4 PIG bf.
0MIE -sail
.R, W. CIO 5330
AIO-25-17
",RGUEL
MOICL IS
25 IT
IIA
A
J- rlhg'A
C,
I
H
Hilcorp
6vcp'CmopmY
23.0
Days Vs Depth
Page 45
0
2000
n 6000
v
0
v
� 5000
v
12000
14000
Milne Point Unit
E-41 SB Producer
Drilling Procedure
MPU E-41 Days vs Depth
0 5 10 15 20 25
Days
H
HilmE,
24.0 Formation Tops & Information
Milne Point Unit
E-41 SB Producer
Drilling Procedure
MPU E-41 Formations
(wp03)
MD
(ft)
TVDss
(ft)
ND
(ft)
Formation Pressure
(psi)
EMW
(ppg)
Base Permafrost
2067
1854
1806
795
8.46
LA3
4941
3880
3832
1686
8.46
Schrader Bluff NA
5966
4349
4301
1892
8.46
Schrader Bluff OA
6156
4280
4328
1904
8.46
Page 46
Milne Point Unit
E-41 SB Producer
Drilling Procedure
GENERALIZED GEOLOGICAL
FORECAST
SS
GEOLOGICAL
TVD
FM
LITH
DESCRIPTION
mi Dsoi.
•
ion'II �
Gubl
i
Unconsolidated coarse to medium sand and small gravel with
«. am%
bpd
,
,
,;
minor siltstone.
Heavy gravel conglomerate to 1400'. Wood fragments
1 000,
Io
p
-
throughout permafrost zone. Abundant pyrite at 15D0 It.
Basepertnafrost -4400 RUNNING GRAVELS
1700,
2.000H
Be prepared for HYDRATE gas cut
HYDRATESII
C
road 2000 to 2500' as (E -land E -S)
Saga
nlrktok
-226-2311. (E-14,40, '. HYDRATES.
I
L
.33&-21). E4
•33 d -211. E 32 GAS CUT MUD
A
Predomknanty clay to H- 7000' with Interbeds of sand, clays
and Illusional with occasional shows of mal.
1
Y
3,000
and WIN occbetween
Contin:"war Cld3 of sandtstan
30onal
at coal. and InWrlsedSiones,
shows of coal. Clay, slttsrone and sand Interbeds between 3000 and
6000'. Lignite 3400-3500 fl_ SV intervals more ratty ("muddier"Ithm
C
those In the Prudhoe Bay area.
los
UG4JK15
SWABBINGISTICKY
L,. r
A
300 mostlymemedd d fl Eyed,
Ugnu: Thick package-200hydrocarbon.
schThe
e
y
oIn
Ugmas,
dstoneh
some 30hlea are faltd with Irytlrocarbon. The Ugnu aecbm (Interbedded fluvial saridstare
Ae
and state) represents the Initial pnogradaDon of the Ugnu deltaic system over the underlying CLAYIGUMBO: E -20a. -28,
D
w
=and
shallow narine Schrader Sluff section. Fluvial nahae ran make N didlcuh to delennime lop
D
Y
base of individual units. Saturn bounding surface of the entire Ugnu package is picked -329-12.
a"
A
at the regional unconlomilty MISS (see the Msands below). GAS CUT MUD E-24 AT 3996
y
M•Sarl Fluvlal- delta c channel sandstones prograeed over the underlying shallow TVD; E-136 @ 3618 tvd.
4,000
marine sandstones at the Schrader Bluff- The M -Sands we subdivided Into three TIGHTIPACKING OFF, E -25A-,
1fO
lithostr3tigraptkc units (Me. Mb. Mc from lop to bottan) mat can be difticub to correlate due
A
v
to their fluvlN4eltwc nature. The M70S marks the lower most boundary. M -sand intervals Surface cash seat
e
B
-
are typically coarsening upward packages of varying thicknesses, rargina from sQ,80 th ok for Schrader BIuN
C
C-
g
Al zones are highly unconsolidated sandstones wit h porosities range in the 30-38% and
completion.
permaablldles readung Upwards of 2000-50DD mo. Each M -sand Interval acts as a
L4ns
hydraulically separate reservoir based on current undemlandirg_ TIGHTILEDGES (COAL)
N -Saeid S: The Nsads are composed of smoked. marine shaeface, sandstones that
b
RUNNING SURFACE
A
e
mudstones Into Nin, low r very fine W medium CASING. E-24, 33 8 dS.
camsen upwstor homheN
>
A
O
quality ne
grained sandstones The NB. NC b tab -sands are the best quaay reservoir rack of dean,
.N
Y
high nelgross fine to medium grained sandstorhe. N -sand porosity ranges from 12365t and
z
penreaDllums range from 100-3000 Ind. The HC d ND -ands we the primary target, with
C
3
E
secondary targets In the NBswM. The more unconsolidated sands (typically the NS, NC 8
J
m
NO) lend to washout, and the finer grained sirry mudstones can cause slow ROP.
Each N -sand ads as a hydraulically Isolated separate reservoir.
axtr-
alis
i
O -sands: They of ace marines ands that clean
A
�
mudssconsist
ererIingstacked,ades) o thin
upwards from spry mudstones (Inlervening shales] to thin bedded, very fine to IUhe grained
i
sandstones. These OA and OB sandstones are 25-Wthck, and the OA -sand is the primary
a
trilarger
for horizontal wells at Eyad. Oland porosities range from 112-315%. and permeabillUes
W
in the 06 -sand reach upwards of IIDD rid, whereas permeadMies In the OA -sand reach only
350 ma There are radedyirg OB sands (OBD -0811 that correlate over One "on.
®
C
May contain fight nodules and lenses that cause directional deflection (especially when
horizontal) and slow ROP. Each 0 -sand Interval acts as a hydraulically Isolated reservoir.
The numerous subseismic 530 it faults and the lateral discontinuity of the NS -sands make it
4800'
0
essential for clear pick Identification down though the Ugnu and N -sands, as well as careful
.1-100
geosteering In horizontal weirs.
Page 47
H
Hilc�
25.0 Anticipated Drilling Hazards
Milne Point Unit
E-41 SB Producer
Drilling Procedure
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 hydrates have been seen on E Pad. 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:
There are a number of wells in close proximity. Take directional surveys every stand, take additional
surveys if necessary. Continuously monitor proximity to offset wellbores and record any close
approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in
adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well.
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.
Page 48
H
Hilcorp
Milne Point Unit
E-41 SB Producer
Drilling Procedure
1. The AOGCC will be notified within 24 hours if 1-12S is encountered in excess of 20 ppm during
drilling operations.
2. The rig will have fully functioning automatic 1-12S detection equipment meeting the requirements
of 20 AAC 25.066.
In the event H2S is detected, wellwork will be suspended and personnel evacuated until a
detailed mitigation procedure can be developed.
Page 49
n
Hilcorp
Milne Point Unit
E-41 SB Producer
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 1-12S events have been documented
on drill wells on this pad.
1. The AOGCC will be notified within 24 hours if 1-12S 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 1-12S is detected, wellwork will be suspended and personnel evacuated until a
detailed mitigation procedure can be developed.
Abnormal Pressures and Temperatures:
• Abnormal pressure has been seen on E -Pad. Utilize MPD to mitigate any abnormal pressure seen.
Anti -Collision
There are no wells with a clearance factor <1.0 on this lateral. Take directional surveys every stand, take
additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic
interference with another well.
Page 50
H
HHCO2Eon®�
26.0 Innovation Rig Layout
Milne Point Unit
E-41 SB Producer
Drilling Procedure
Page 51
27.0 FIT Procedure
Formation Integrity Test (FIT) and
Leak -Off Test (LOT) Procedures
Procedure for FIT:
Milne Point Unit
E-41 SB Producer
Drilling Procedure
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.
Page 52
28.0 Innovation Rig Choke Manifold Schematic
Page 53
i
Milne Point unit
E-41 SB Producer
Hilco
E=2
Drilling Procedure
28.0 Innovation Rig Choke Manifold Schematic
Page 53
i
Milne Point Unit
E-41 SB Producer
Drilling Procedure
29.0 Casing Design
MR=
Calculation & Casing Design Factors
Hole Size 12-1/4"
Hole Size 8-1/2"
Hole Size
DATE: 2/8/2019
WELL: MPU E-41
DESIGN BY: Joe Engel
Criteria:
Mud Density: 9.2 ppg
Mud Density: 9.2 ppg
Mud Density:
Drilling Mode
MASP: 1471 psi (see attached MASP determination & calculation)
MASP:
Production Mode
MASP: 1914 psi (see attached MASP determination & calculation)
Collapse Calculation:
Section Calculation
1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress
Page 54
Casing Section
Calculation/Specification
1
2 3 4
Casing OD
9-5/8"
4-1/2"
Top (MD)
0
6,006
Top (TVD)
0
4,315
Bottom (MD)
6,156
13,100
Bottom (TVD)
4,328
4,350
Length
6,156
7,094
Weight (ppf)
40
13.5
Grade
L-80
L-80
Connection
T)(P
M25
Weight w/o Bouyancy Factor (Ibs)
246,240
95,769
Tension at Top of Section (lbs)
246,240
95,769
Min strength Tension (1000 lbs)
916
279
Worst Case Safety Factor (rension)
3.72
2.91
Collapse Pressure at bottom (Psi)
2,138
2,149
Collapse Resistance w/o tension (Psi)
3,090
8,540
Worst Case Safety Factor (Collapse)
1.45 V
3.97
MASP (psi)
1,471
1,904
Minimum Yield (psi)
5,750
9,020
Worst case safety factor (Burst)
3.91 V
4.74
Page 54
30.0 8-1/2" Hole Section MASP
Maximum Anticipated Surface Pressure Calculation
14
HilCorp 8-1/2" Hole Section
'^'
MPU E-41
Milne Point Unit
MD TVD
Planned Top: 6156 4328
Planned TD: 13100 4350
Anticipated Formations and Pressures:
8.8-9.1
Surface
Milne Point unit
Formation
E-41 SB Producer
Hilco
U -LT
Drilling Procedure
30.0 8-1/2" Hole Section MASP
Maximum Anticipated Surface Pressure Calculation
14
HilCorp 8-1/2" Hole Section
'^'
MPU E-41
Milne Point Unit
MD TVD
Planned Top: 6156 4328
Planned TD: 13100 4350
Anticipated Formations and Pressures:
8.8-9.1
Surface
4125
Formation
TVD
Est Pressure Oil/Gas/Wet
PPG Grad
Schrader Bluff OA Sand
2015
4,328
1900
1 Oil
8.44 /1
0.440
Offset Well Mud Densities
Well MW range Top (TVD) Bottom (TVD) Date
L-50
8.8-9.1
Surface
4125
2015
L-49
9.0-9.2
Surface
4196
2015
L-48
8.9-9.2
Surface
4147
2015
L-47
8.8-9.0
Surface
4158
2015
L-46
9.0-9.3
Surface
4177
2015
Assumptions:
1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW.
2. Maximum planned mud density forthe 8-1/2" hole section is 9.5 ppg.
3. Calculations assume full evacuation of wellbore togas
Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface:
4,328 (ft) x 0.78(psi/ft)= 3376
3376(psi)-[0.1(psi/ft)*4328(ft))= 2943 psi
MASP from pore pressure (complete evacuation of wellbore togas from Schrader Bluff OA sand)
4328 (ft) x 0.44(psi/ft)= 1904 psi e
1904(psi) - 0.1(psi/ft)*4328(ft) 1471 psi i
Summary:
1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation G
of entire wellbore to gas at 0.1 psi/ft.
Page 55
H
Hilcorp
Em spy
31.0
Milne Point Unit
E-41 SB Producer
Drilling Procedure
Spider Plot (NAD 27) (Governmental Sections)
1L________.
1 I
_
,� ! -
-
-
r'
V�
-- ADL047437
'' ••
! ' ° i 'ADL047438
\
SeC.19
�
Sec.. 23
i
/ i( -i ''(839)\`
�.
MILNE POINT UNIT-U013N010E,'�
r rl j
$i e_., U013NO11E
, r
,
\�
r
I
_________
�n
—- ��-:-J�'m
•suave'r
CC_ea
A
-
--_ E.°t
-----------
_
- -. _
-
-_-- MPE-41_SHL
°
-�--
''
` Legend
ADLO25518 Seo.25
b4
ADL025. 0 MPE41_SHL
X MPE41_TPH
1
r
r
t
+ MPE41_BHL
�
\
`�Z, Other Surface Holes (SHL)
Other Bottom Holes (BHL)
- - - Other Well Paths
1V,
Oil antl Gas Unit Bountlary
\ \\
(_� Pad Footprint
Page 56
Milne Point Unit
MPE41 Well 0 1,000 2,000
wD03 mmmmmmmmmmmK======== Feet
32.0 Surface Plat (As Built) (NAD 27)
Milne Point Unit
S■
E-41 SB Producer
Hilco�{(y
Eovgy Cmnpmy
Drilling Procedure
32.0 Surface Plat (As Built) (NAD 27)
NOTFS,
1.
LrOFNA
NA9M STATE FLAKE COORDINATES ARC ZONE 4, NAD27.
S■
■6
2.
DAIS OE IGMTKNF 6 MONMIMNTS M-3 AND E-1,
■ EfOSTNG LOM1UC10A
I NEOE9Y 00i NAT I AM
PROPERLY RE4:151G4E0 MTD LJOENSFD
3.
"SID, OF QEYA1pM MILNE PGNT SATIN La
POSMON(DLAS)
PRAUCE LAND SLR) Q DN
■ 2
y
WE OF'
MN
5.
S
GRAPHIC SCALE
27 ■
■ 32
"%CY OATE+ MAY 31.20111* 1LY 11 NIS . D
100 200
10 ■
■
F479 NCE 11EID DIEN: NC14-02 PDS. 24-29
24 ■
4 ■ 4
ML1E-OZ PGS. E 73
C IN FEES)
Z2 ■
■ t
a
I
251 ■
X= 569 4D7.52'
c.ATT:n POTs1:N OPTIMACTFD
SFC. 25. T. 13 N.. R. TD E..
I! ■
■ S
1,738' FEL
24 •
• 30
70"27'16.412'
70.4545569'
9 ■
• 6
-N-
X= 569 388.37'
25•
821
149.4337617'
it
■ 7
Y=6,016.08T.C6'
N-1,890.22'
D ■
■ 14
MPU "ADN
Xe 569.265-12'
E=1,291.58'
149'26'05.189-
24 ■
• 1s
1881'F-eL
14•
- 1,85975'
7027'15.210"
70.4542250'
15 ■
3314
f7
E-39
X- 569.284.13'
E -38E-37
14926'04.636'
149.4346211'
E-39
E-36
Y-6,018,034.09'
o
N-'.,629.93'
E-41
E-35
NOTFS,
1.
LrOFNA
NA9M STATE FLAKE COORDINATES ARC ZONE 4, NAD27.
+ AS -SALT CGNDUCTQA
SURVEYOR'S CERTFICAM
2.
DAIS OE IGMTKNF 6 MONMIMNTS M-3 AND E-1,
■ EfOSTNG LOM1UC10A
I NEOE9Y 00i NAT I AM
PROPERLY RE4:151G4E0 MTD LJOENSFD
3.
"SID, OF QEYA1pM MILNE PGNT SATIN La
POSMON(DLAS)
PRAUCE LAND SLR) Q DN
A
GEODETIC P09NNS ARE NAM.
WE OF'
MN
5.
PAD YEAH SCMF PAC1L11 IT 0.90054
GRAPHIC SCALE
IIS ASUL)TRETE
�RESel175 a 93RREY
C
"%CY OATE+ MAY 31.20111* 1LY 11 NIS . D
100 200
ADD MAZYZ ST A& CR I1NOrR MY DIRECT
7.
F479 NCE 11EID DIEN: NC14-02 PDS. 24-29
%'VERK90M AND THAT ALL
O�VDNS AND AIE
ML1E-OZ PGS. E 73
C IN FEES)
CORRECT AS W MAYE310EMS.
7D.4544939'
21 T
1 Me, -203 h
E-36
X= 569 4D7.52'
c.ATT:n POTs1:N OPTIMACTFD
SFC. 25. T. 13 N.. R. TD E..
UMIAT MERIDIAN. ALASKA
WELL
A.5 -P.
PLANT
GEODETIC
GEODETIC
CELLAR
SECTION
NO.
I COORi NATES
COOROINATES
POSMON(DLAS)
PosrnON(D.DD)
13OX ELM
OFFSETS
Y=6,D16,133,24'
N-1.829.99'
70'27'15945"
7D.4544292'
21.7
A594'FSL
E-35
X- 569 a26.3Y
E= 1 450.02'
14926'CO.a36"
144.4334550'
1,720' F0.
Y-6,016,156.74'
N=1,860.12'
70'27'16.178'
7D.4544939'
21 T
3,617' FSL
E-36
X= 569 4D7.52'
E= 1 450.03'
14926'C0.984"
149.4338067'
1,738' FEL
Y. 6.016,180.37'
N=1,890.58'
70"27'16.412'
70.4545569'
21'7
3841' FEL
E-37
X= 569 388.37'
E- 1.4-49.84'
14926'01.542"
149.4337617'
I757FEL
E-38
Y=6,016.08T.C6'
N-1,890.22'
702715.446"
70.45429C5'3.543'FSL
21,8'
Xe 569.265-12'
E=1,291.58'
149'26'05.189-
149.4347747'
1881'F-eL
Y=6,016,057,25'IN
- 1,85975'
7027'15.210"
70.4542250'
21.7'
3519' FSL
E-39
X- 569.284.13'
E=1,291.52'
14926'04.636'
149.4346211'
1 863' FEL
Y-6,018,034.09'
o
N-'.,629.93'
7027'14.981"
70.4541514'
21'8'
3496'FSL
E -N
X= 302. 0'
= 1.291
749'26'04.091"
149.4344697
1,844' fEL
wPce HilcorpAlaska
6 1 0
MILNE PpNL ALASKA "R
Ir.rsom u< �� MP E -PAD, HELLS 36. 36. 37, 38, 39 h 41
sea m14sIaAPea.ut .Pw. MMR +. " 2IX7 CONDUCTOR AS -BUILT 1 "
w. e.Tl 1 ecsoe F P+ OW vrm j
Page 57
H
HiImTGv® Cmp^Y
Milne Point Unit
E-41 SB Producer
Drilling Procedure
33.0 Schrader Bluff NB Sand Offset MW vs TVD Chart
Page 58
8.5
0
111
u I1/
6000
p 8000
1 19
.101
SB NB Offset MW vs MD
EMW, ppg
9.5 10.5 11.5 12.5
—J-27 (2015) -J-28 (2015) —L-53 (2017)
—L-52 (2017)—L-51(2017)
Hilcorp Alaska, LLC
Milne Point
M Pt E Pad
Plan: MPU E-41
MPE-41
Plan: MPU E-41 WP03
Standard Proposal Report
04 February, 2019
HALLIBUATON
Sperry Drilling Services
HALLIBURTON
Sperry Drilling
Project., Milne Point
Site: M Pt E Pad
Well: Plan: MPU E-41
Wellbore: MPE-41
Design: MPU E-41 WP03
c
� 1
Co-ordinate (WE) Reference: Well Plan: MPU E41, True North
Vertical (TVD) Reference: WELL Q 48.20usft (Original Well Elev)
Measured Depth Reference: WELL @ 48.20usft (Original Well Elev)
Calculation Method : Minimum Curvature
Start Dir 3'/100': 350' MD, 3507VD
Stan Dir 4011M': 550' MD, 549.63TVD
- - - End Dir : 1583.73' MD, 1461.49' WD
Spp - Start Dir 4°/100': 2511.99' MD, 210627TVD
O
.2 2500 3000
�
ev W A'
H 3000 3500 4- pan
IV
IV
3500 &
O r O
ayd5 4b
r
h
4000-
-
000
0
4500 95/8"x121/4" 0 0 0
fvWE-Wcftpn NB Heel
T T�T
-1500 -1000 -500 0 500 1000 1500 2000
WELL DETAILS: Plan: MPU E41
Ground Level: 21.70
.WS +FJ -W Northing Easting Latittude Longitud
0.00 0.00 6016034.09 569302.90 70' 27'14.981 N 149'26-4.0-
SURVEY
49°26'4.00
SURVEY PROGRAM CASING DETAILS
ata: 20111-10-19Tlto Moo wanted: Yes version: WD MOSS MD Size Noma
328.20 4280.00 6156.00 9-5/8 9 5/8" x 12114-
Depth From Depth To 6mvey/Plan TODI 350.38 4302.18 13100.00 6-5/8 65/8"x81/2"
26.50 6156.00 MPU E41 WPM (MPE- JvMtDNFR2♦MS+Sag
6156.00 13090.83 MPU E41 WPM (MPE-R9MWD+IFR2+M5e5ag
Hilcotp Alaska, LLC
FORMATION TOP DETAILS Calculation Method: Minimum Curvature
No formation data is avallaMe Error System: ISCWSA
Scan Method: Closest Approach 30
Error Surece: Pedal Curve
Warning Method: Error Ratio
p'� Dpyr7� p "1
46 4
�\
a
,r Orr, er R c
61, y m' 4
c p, ra ,MPU E41 WPM
p, �o j
0 0 0 0 6 5/8" x 8 1/2"
MPE-Wolman N8 CP1 MPE-Wellman NB CP2 MPE-Wellmen NS tae
-(TTr -1TTrT
2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000
Vertical Section at 24.67° (1000 usfUin)
SECTION DETAILS
Sec
MD
Inc
Azi
TVD
+N/ -S
+E/ -W
Dag
TFace
VSect
Target
Annotation
1
26.50
0.00
0.00
26.50
0.00
0.00
0.00
0.00
0.00
2
350.00
0.00
0.00
350.00
0.00
0.00
0.00
0.00
0.00
StartDir 3°/100' : 350' MD, 3507VD
3
550.00
6.00
210.00
549.63
-9.06
-5.23
3.00
210.00
-10.42
StartDir 4°/100' : 550' MD, 549.63'TVD
4
1583.73
46.18
175.36
1461.49
-046.69
-1.90
4.00
-38.38
-406.71
End Dir : 1583.73' MD, 1461.49' TVD
5
2511.99
46.18
175.36
2104.27
-1114.20
52.32
0.00
0.00
.990.66
Start Dir 4°/100' :2511.99' MD, 2104.27'TVD
6
5656.00
85.00
21.58
4284.62
-534.52
1240.43
4.00
-147.15
32.02
End Dir :5656' MD, 4284.62' TVD
7
6156.00
85.00
21.58
4328.20
-71.34
1423.63
0.00
0.00
529.40
MPE-Wellman NO Heel
Start Dir 4°/100':6156' MD, 4328.2 -TVD
8
6300.94
90.80
21.58
4333.51
63.29
1476.89
4.00
0.04
673.97
End Dir : 6300.94' MD, 4333.51' TVD
9
8837.58
90.80
21.58
4298.20
2421.83
2409.96
0.00
0.00
3206.69
MPE-Wellman NB CP1
Start Dir 2°/100': 8837.58' MD, 4298.27VD
10
9189.48
88.50
14.93
4300.36
2755.80
2520.13
2.00
-109.05
3556.16
End on : 9189.48' MD, 4300.36' TVD
11
9440.60
88.50
14.93
4306.94
2998.35
2584.81
0.00
0.00
3803.57
Start Dir 2°/100' : 9440.6' MD, 4306.94'TVD
12
9762.08
88.44
8.50
4315.53
3312.85
2650.03
2.00
-90.61
4116.59
End Dir : 9762.08' MD, 4315.53' TVD
13
10962.08
88.44
8.50
4348.20
4499.23
2827.34
0.00
0.00
5268.69
MPE-Wellman NB CP2
Start Dir 2°/100': 10962.08' MD, 4348.2'TVD
14
11122.32
90.00
5.70
4350.38
4658.22
2847.14
2.00
-60.90
5421.42
End Dir : 11122.32' MD, 4350.38' TVD
15
13100.00
90.00
5.70
4350.38
6626.12
3043.56
0.00
0.00
7291.68
Total Depth : 13100' MD, 4350.38' TVD
Co-ordinate (WE) Reference: Well Plan: MPU E41, True North
Vertical (TVD) Reference: WELL Q 48.20usft (Original Well Elev)
Measured Depth Reference: WELL @ 48.20usft (Original Well Elev)
Calculation Method : Minimum Curvature
Start Dir 3'/100': 350' MD, 3507VD
Stan Dir 4011M': 550' MD, 549.63TVD
- - - End Dir : 1583.73' MD, 1461.49' WD
Spp - Start Dir 4°/100': 2511.99' MD, 210627TVD
O
.2 2500 3000
�
ev W A'
H 3000 3500 4- pan
IV
IV
3500 &
O r O
ayd5 4b
r
h
4000-
-
000
0
4500 95/8"x121/4" 0 0 0
fvWE-Wcftpn NB Heel
T T�T
-1500 -1000 -500 0 500 1000 1500 2000
WELL DETAILS: Plan: MPU E41
Ground Level: 21.70
.WS +FJ -W Northing Easting Latittude Longitud
0.00 0.00 6016034.09 569302.90 70' 27'14.981 N 149'26-4.0-
SURVEY
49°26'4.00
SURVEY PROGRAM CASING DETAILS
ata: 20111-10-19Tlto Moo wanted: Yes version: WD MOSS MD Size Noma
328.20 4280.00 6156.00 9-5/8 9 5/8" x 12114-
Depth From Depth To 6mvey/Plan TODI 350.38 4302.18 13100.00 6-5/8 65/8"x81/2"
26.50 6156.00 MPU E41 WPM (MPE- JvMtDNFR2♦MS+Sag
6156.00 13090.83 MPU E41 WPM (MPE-R9MWD+IFR2+M5e5ag
Hilcotp Alaska, LLC
FORMATION TOP DETAILS Calculation Method: Minimum Curvature
No formation data is avallaMe Error System: ISCWSA
Scan Method: Closest Approach 30
Error Surece: Pedal Curve
Warning Method: Error Ratio
p'� Dpyr7� p "1
46 4
�\
a
,r Orr, er R c
61, y m' 4
c p, ra ,MPU E41 WPM
p, �o j
0 0 0 0 6 5/8" x 8 1/2"
MPE-Wolman N8 CP1 MPE-Wellman NB CP2 MPE-Wellmen NS tae
-(TTr -1TTrT
2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000
Vertical Section at 24.67° (1000 usfUin)
r
7333 CASING DETAILS
WD TVDSS MD Size Name
4328.20 4260.00 1.00 9-5I8 5B" x 12
4350.38 4302.18 13310000.00 6-5/6 6 5/6' x 8112" r2"
6
6�.
61PELtklLrm
6667—
REFERENCE INFORMATION=Elav)
0
OeuNinate (NISI Refinance: Well Plan: MPU E-41, Tme NOdh
- - End Dir : 9189.48-M0,430036' llrD
2667
Vedical (rVD) Referece: WELL 4a30usR(Original Wal
+
s
Meeemed Depth Reference: WELL@ 48.POush(Odginal Wel
0
y
G
Stan Dir 2-110,10' : 8e]].58' MD, 4298.2 -TVD
Calculation Method Minimum Cunelune
6000
WELL DETA : Plan: MPD E41
667-
— Gmund Level: 21.70
9 5,8"x 12 14"
+N/ -S +E/ -W NaMing Farting LnNuude Longitude
-- - - - -- End Dir :63M.94- Mo 4333.51'TVI]
Q
Start Dir3°/100':350'MD, 35tlTVD-_ _ 50
0.00 0 N 601603409 569302 90 70° 27-14.981 N 149026-4.
W
5333
---_,
Sun Dir ell DO' : 550'MD, 549.63"
1250
Start Dv 4'/IW: 6156' MD, 4328 2'TVD
500
Project: Milne Point
-
Site: M Pt E Pad
-
Well: Plan: MPU E-41
EM Dir :5656' ME), 4284.62'lVD
2000
Wellbore: MPE-41
4667
Plan: MPU E-41 WP03
4.27
Stan Dir4°/100': 2511.99' FID, 210TVD T42
MPE-Welhren NR CP2
4000
HALLIBURTON
MPDE41 WPU3 Efperry Orllling
65/8"x%12"
4350
End Dir : 11122.32' MD, 4350.38' WD
- - - Start Dir 2'/100':10962.08- MD, 4348.2'TVD
3133
_ - End Dir :9762.08' MO TVD
C
6�.
S. Dir 2°/100': 94406' MD, 430694'TVD
0
- - End Dir : 9189.48-M0,430036' llrD
2667
+
s
MPE-Wclltrw NB CR _
0
y
G
Stan Dir 2-110,10' : 8e]].58' MD, 4298.2 -TVD
9 2000-
000133366795/x"
1333-
667-
9 5,8"x 12 14"
MPE-Wellman NB Heel
`—_
-- - - - -- End Dir :63M.94- Mo 4333.51'TVI]
Q
Start Dir3°/100':350'MD, 35tlTVD-_ _ 50
1000
---_,
Sun Dir ell DO' : 550'MD, 549.63"
1250
Start Dv 4'/IW: 6156' MD, 4328 2'TVD
500
End D'u : 1583.73' MD, 146149' TVD
-667
-
750 >1sp
EM Dir :5656' ME), 4284.62'lVD
2000
2250A.c
-1333
4.27
Stan Dir4°/100': 2511.99' FID, 210TVD T42
-2000
-2000 -1333 -667 0 667 1333 2000 2667 3333 4000 4667
West( -)/East(+) (1000 usft/In)
HALLIBURTON
Database:
NORTH US+CANADA
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt E Pad
Well:
Plan: MPU E-41
Wellbore:
MPE-41
Design:
MPU E-41 WP03
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Halliburton
Standard Proposal Report
Well Plan: MPU E-41
WELL @ 48.20usft (Original Well Elev)
WELL @ 48.20usft (Original Well Elev)
True
Minimum Curvature
.Mject Milne Point, ACT, MILNE POINT
Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Nap Zone: Alaska Zone 04 Using geodetic scale factor
Site M Pt E Pad, TR -13-10
MPE-41
Site Position:
Northing:
From: Map
Easting:
Position Uncertainty: 0.00 usft
Slot Radius:
Well Plan: MPU E-41
Well Position +NIS 0.00 usft
Northing:
+E/ -W 0.00 usfl
Easting:
Position Uncertainty 0.00 usft
Wellhead Elevation:
6,013,798.68usft Latitude:
569,440.72usft Longitude:
0" Grid Convergence:
6,016,034.09 usfl Latitude:
569,302.90 usfl Longitude:
0.00 usfl Ground Level:
70° 26'52.982 N
149° 26'0.655 W
0.53 °
70° 27' 14.981 N
149° 26'4.091 W
21.70 usfl
Wellbore
MPE-41
Magnetics
Model Name
Sample
Date
Declination
Dip Angle
Field Strength
BGGM2018
311/2019
16.82
80.97
57,437.46943635
Design
MPU E-41 WP03
Audit Notes:
Version:
Phase:
PLAN
Tie On
Depth:
26.50
Vertical Section:
Depth From
(TVD)
+NI -S
+E/ -W
Direction
(usfl)
(usft)
(usfl)
(I
26.50
0.00
0.00
24.67
Plan Sections
Measured
Vertical
TVD
Dogleg
Build
Turn
Depth Inclination
Azimuth
Depth
System
+N/ -S
+E/ -W
Rate
Rate
Rate Tool Face
(usfl) (°)
(1
(usft)
usft
(usfl)
(usfl) (°1100usft)
(°/100usft)
(°1100usft)
(')
26.50
0.00
0.00
26.50
-2170
0.00
0.00
0.00
0.00
0.00
0.00
350.00
0.00
0.00
350.00
301.80
0.00
0.00
0.00
0.00
0.00
0.00
550.00
6.00
210.00
549.63
501.43
-9.06
-5.23
3.00
3.00
0.00
210.00
1,583.73
46.18
175.36
1,461.49
1,413.29
446.69
-1.90
4.00
3.89
-3.35
-38.38
2,511.99
46.18
175.36
2,104.27
2,056.07
-1,114.20
52.32
0.00
0.00
0.00
0.00
5,656.00
85.00
21.58
4,284.62
4,236.42
-534.52
1,240.43
4.00
1.23
-4.89
-147.15
6,156.00
85.00
21.58
4,328.20
4,280.00
-71.34
1,423.63
0.00
0.00
0.00
0.00
6,300.94
90.80
21.58
4,333.51
4,285.31
63.29
1,476.89
4.00
4.00
0.00
0.04
8,837.58
90.80
21.58
4,298.20
4,250.00
2,421.83
2,409.96
0.00
0.00
0.00
0.00
9,189.48
88.50
14.93
4,300.36
4,252.16
2,755.80
2,520.13
2.00
-0.65
-1.89
-109.05
9,440.60
88.50
14.93
4,306.94
4,258.74
2,998.35
2,584.81
0.00
0.00
0.00
0.00
9,762.08
88.44
8.50
4,315.53
4,267.33
3,312.85
2,650.03
2.00
-0.02
-2.00
-90.61
10,962.08
88.44
8.50
4,348.20
4,300.00
4,499.23
2,827.34
0.00
0.00
0.00
0.00
11,122.32
90.00
5.70
4,350.38
4,302.18
4,658.22
2,847.14
2.00
0.97
-1.75
-60.90
13,100.00
90.00
5.70
4,350.38
4,302.18
6,626.12
3,043.56
0.00
0.00
0.00
0.00
2/42019 1.:57:40PM
Page 2
COMPASS 5000.15 Build 91
HALLIBURTON
Database:
NORTH US+CANADA
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt E Pad
Well:
Plan: MPU E-41
Wellbore:
MPE-41
Design:
MPU E-41 WP03
Planned Survey
Measured Vertical
Depth Inclination Azimuth Depth TVDss
(usft) V) (^) (usft) usft
26.50 0.00 0.00 26.50 -21.70
100.00 0.00 0.00 100.00 51.80
200.00 0.00 0.00 200.00 151.80
300.00 0.00 0.00 300.00 251.80
350.00 0.00 0.00 350.00 301.80
Start Dir3°/100': 350' MD, 350'TVD
400.00 1.50 210.00 399.99 351.79
500.00 4.50 210.00 499.85 451.65
550.00 6.00 210.00 549.63 501.43
Start Dir 4°1100' : 550' MD, 549.63'TVD
600.00 7.67 200.66 599.28 551.08
700.00 11.33 190.71 697.90 649.70
800.00 15.16 185.66 795.22 747.02
900.00 19.06 182.62 890.78 842.58
1,000.00 23.00 180.59 984.10 935.90
1,100.00 26.95 179.13 1,074.73 1,026.53
1,200.00 30.91 178.01 1,162.24 1,114.04
1,300.00 34.88 177.13 1,246.18 1,197.98
1,400.00 38.86 176.41 1,326.16 1,277.96
1,500.00 42.84 175.80 1,401.79 1,353.59
1,583.73 46.18 175.36 1,461.49 1,413.29
End Dir : 1583.73' MD, 1461.49' TVD
1,600.00 46.18 175.36 1,472.76 1,424.56
1,700.00 46.18 175.36 1,542.01 1,493.81
1,800.00 46.18 175.36 1,611.25 1,563.05
1,900.00 46.18 175.36 1,680.50 1,632.30
2,000.00 46.18 175.36 1,749.74 1,701.54
2,100.00 46.18 175.36 1,818.98 1,770.78
2,200.00 46.18 175.36 1,888.23 1,840.03
2,300.00 46.18 175.36 1,957.47 1,909.27
2,400.00 46.18 175.36 2,026.72 1,978.52
2,500.00 46.18 175.36 2,095.96 2,047.76
2,511.99 46.18 175.36 2,104.27 2,056.07
Start Dir 4°/100' : 2511.99' MD, 2104.27'TVD
2,600.00 43.25 172.57 2,166.81 2,118.61
2,700.00 40.02 169.02 2,241.55 2,193.35
2,800.00 36.91 164.96 2,319.85 2,271.65
2,900.00 33.97 160.30 2,401.33 2,353.13
3,000.00 31.22 154.89 2,485.59 2,437.39
3,100.00 28.74 148.60 2,572.22 2,524.02
3,200.00 26.60 141.31 2,660.80 2,612.60
3,300.00 24.89 132.98 2,750.90 2,702.70
3,400.00 23.69 123.69 2,842.08 2,793.88
3,500.00 23.10 113.72 2,933.90 2,885.70
3,600.00 23.15 103.52 3,025.90 2,977.70
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Halliburton
Standard Proposal Report
Well Plan: MPU E-41
WELL @ 48.20usft (Original Well Elev)
WELL @ 48.20usft (Original Well Elev)
True
Minimum Curvature
-1,175.76
58.80
Map
6,014,859.04
Map
569,372.62
4.00
-1,043.90
+N/ -S
+E/ -W
Northing
Easting
DLS Vert
Section
(usft)
-1,099.07
(usft)
(usft)
83.28
(usft)
6,014,733.13
-21.70
569,398.28
0.00
-1,148.32
0.00
6,016,034.09
100.49
569,302.90
6,014,677.97
0.00
0.00
0.00
-1,191.41
0.00
6,016,034.09
120.92
569,302.90
6,014,628.38
0.00
0.00
0.00
-1,228.12
0.00
6,016,034.09
144.46
569,302.90
6,014,584.60
0.00
0.00
0.00
-1,258.29
0.00
6,016,034.09
170.99
569,302.90
6,014,546.84
0.00
0.00
0.00
-1,281.76
0.00
6,016,034.09
200.39
569,302.90
6,014,515.28
0.00
0.00
-0.57
-1,298.42
-0.33
6,016,033.52
232.51
569,302.58
6,014,490.08
3.00
-0.65
-5.10
-1,308.18
-2.94
6,016,028.96
267.20
569,300.00
6,014,471.36
3.00
-5.86
-9.06
-1,311.01
-5.23
6,016,024.98
304.28
569,297.75
6,014,459.22
3.00
-10.42
-14.45
-1,306.88
-7.71
6,016,019.57
569,295.32
4.00
-16.35
-30.35
-11.90
6,016,003.64
569,291.29
4.00
-32.54
-53.03
-15.01
6,015,980.93
569,288.38
4.00
-54.45
-82.37
-17.05
6,015,951.58
569,286.62
4.00
-81.97
-118.23
-18.00
6,015,915.71
569,286.00
4.00
-114.95
-160.44
-17.86
6,015,873.51
569,286.54
4.00
-153.25
-208.78
-16.62
6,015,825.18
569,288.22
4.00
-196.66
-263.04
-14.30
6,015,770.96
569,291.05
4.00
-245.00
-322.93
-10.90
6,015,711.10
569,295.01
4.00
-298.00
-388.18
-6.44
6,015,645.91
569,300.07
4.00
-355.43
446.69
-1.90
6,015,587.45
569,305.15
4.00
-406.71
458.39
-0.95
6,015,575.76
569,306.21
0.00
-416.94
-530.30
4.89
6,015,503.91
569,312.72
0.00
-479.85
-602.21
10.73
6,015,432.07
569,319.23
0.00
-542.76
-674.12
16.57
6,015,360.22
569,325.74
0.00
-605.67
-746.03
22.41
6,015,288.37
569,332.25
0.00
-668.58
-817.94
28.26
6,015,216.53
569,338.76
0.00
-731.48
-889.85
34.10
6,015,144.68
569,345.27
0.00
-794.39
-961.76
39.94
6,015,072.84
569,351.78
0.00
-857.30
-1,033.67
45.78
6,015,000.99
569,358.29
0.00
-920.21
-1,105.58
51.62
6,014,929.15
569,364.80
0.00
-983.11
-1,114.20
52.32
6,014,920.53
569,365.58
0.00
-990.66
-1,175.76
58.80
6,014,859.04
569,372.62
4.00
-1,043.90
-1,241.32
69.36
6,014,793.58
569,383.79
4.00
-1,099.07
-1,301.91
83.28
6,014,733.13
569,398.28
4.00
-1,148.32
-1,357.24
100.49
6,014,677.97
569,416.00
4.00
-1,191.41
-1,407,02
120.92
6,014,628.38
569,436.89
4.00
-1,228.12
-1,451.03
144.46
6,014,584.60
569,460.83
4.00
-1,258.29
-1,489.05
170.99
6,014,546.84
569,487.72
4.00
-1,281.76
-1,520.88
200.39
6,014,515.28
569,517.41
4.00
-1,298.42
-1,546.38
232.51
6,014,490.08
569,549.76
4.00
-1,308.18
-1,565.43
267.20
6,014,471.36
569,584.62
4.00
-1,311.01
-1,577.92
304.28
6,014,459.22
569,621.82
4.00
-1,306.88
2/42019 1:57:40PM Page 3 COMPASS 5000.15 Build 91
HALLIBURTON
Halliburton
Standard Proposal Report
Database:
NORTH US + CANADA
Local Co-ordinate Reference: Well Plan: MPU E-41
Company:
Hilcorp Alaska, LLC
TVD Reference:
WELL
@ 48.20usft (Original Well Elev)
Project:
Milne Point
MD Reference:
WELL @ 48.20usft (Original Well Elev)
Site:
M Pt E Pad
North Reference:
True
Well:
Plan: MPU E-41
Survey
Calculation
Method: Minimum Curvature
Wellbore:
MPE-41
Design:
MPU E-41 WP03
Planned Survey
Measured
Vertical
Map
Map
Depth
Inclination Azimuth
Depth
TVDss
+N1 -S
+E/ -W
Northing
Easting
DLS
Vert Section
(usft)
(I
V)
(usft)
usft
(usft)
(usft)
(usft)
(usft)
3,069.44
3,700.00
23.85
93.63
3,117.64
3,069.44
-1,583.80
343.59
6,014,453.70
569,661.17
4.00
-1,295.82
3,800.00
25.13
84.49
3,208.68
3,160.48
-1,583.04
384.92
6,014,454.85
569,702.49
4.00
-1,277.88
3,900.00
26.92
76.32
3,298.56
3,250.36
-1,575.64
428.07
6,014,462.64
569,745.57
4.00
-1,253.15
4,000.00
29.13
69.21
3,386.86
3,338.66
-1,561.65
472.84
6,014,477.06
569,790.20
4.00
-1,221.74
4,100.00
31.65
63.07
3,473.13
3,424.93
-1,541.12
519.00
6,014,498.01
569,836.16
4.00
-1,183.82
4,200.00
34.43
57.79
3,556.97
3,508.77
-1,514.15
566.33
6,014,525.41
569,883.24
4.00
-1,139.56
4,300.00
37.41
53.23
3,637.96
3,589.76
-1,480.89
614.61
6,014,559.12
569,931.20
4.00
-1,089.18
4,400.00
40.54
49.27
3,715.70
3,667.50
-1,441.49
663.59
6,014,598.97
569,979.80
4.00
-1,032.93
4,500.00
43.79
45.79
3,789.83
3,741.63
-1,396.14
713.03
6,014,644.78
570,028.82
4.00
-971.08
4,600.00
47.13
42.70
3,859.97
3,811.77
-1,345.06
762.70
6,014,696.31
570,078.01
4.00
-903.93
4,700.00
50.54
39.94
3,925.79
3,877.59
-1,268.51
812.36
6,014,753.31
570,127.13
4.00
-831.82
4,800.00
54.02
37.43
3,986.96
3,938.76
-1,226.75
861.76
6,014,815.52
570,175.95
4.00
-755.08
4,900.00
57.54
35.14
4,043.19
3,994.99
-1,160.10
910.65
6,014,882.62
570,224.22
4.00
-674.10
5,000.00
61.11
33.02
4,094.21
4,046.01
-1,088.87
958.81
6,014,954.29
570,271.71
4.00
-589.27
5,100.00
64.70
31.05
4,139.75
4,091.55
-1,013.40
1,006.00
6,015,030.18
570,318.19
4.00
-500.99
5,200.00
68.31
29.18
4,179.62
4,131.42
-934.08
1,051.99
6,015,109.92
570,363.43
4.00
-409.72
5,300.00
71.95
27.41
4,213.60
4,165.40
-851.28
1,096.55
6,015,193.12
570,407.22
4.00
-315.88
5,400.00
75.60
25.71
4,241.53
4,193.33
-765.41
1,139.47
6,015,279.38
570,449.33
4.00
-219.93
5,500.00
79.27
24.07
4,263.28
4,215.08
-676.89
1,180.54
6,015,368.27
570,489.57
4.00
-122.35
5,600.00
82.94
22.47
4,278.74
4,230.54
-586.14
1,219.55
6,015,459.37
570,527.74
4.00
-23.60
5,656.00
85.00
21.58
4,284.62
4,236.42
-534.52
1,240.43
6,015,511.18
570,548.13
4.00
32.03
End Dir
: 5656' MD, 4284.62' TVD
5,700.00
85.00
21.58
4,288.46
4,240.26
-493.76
1,256.56
6,015,552.09
570,563.87
0.00
75.80
5,800.00
85.00
21.58
4,297.17
4,248.97
-401.12
1,293.20
6,015,645.05
570,599.65
0.00
175.27
5,900.00
85.00
21.58
4,305.89
4,257.69
-308.49
1,329.84
6,015,738.01
570,635.42
0.00
274.75
6,000.00
85.00
21.58
4,314.60
4,266.40
-215.85
1,366.48
6,015,830.98
570,671.19
0.00
374.22
6,100.00
85.00
21.58
4,323.32
4,275.12
-123.21
1,403.12
6,015,923.94
570,706.97
0.00
473.70
6,156.00
85.00
21.58
4,328.20
4,280.00
-71.34
1,423.63
6,015,976.00
570,727.00
0.00
529.40
Start Dir 4°1100' : 6156' MD, 4328.2'TVD - 9 5/8" x 12 1/4"
6,200.00
86.76
21.58
4,331.36
4,283.16
-30.53
1,439.78
6,016,016.96
570,742.76
4.00
573.22
6,300.94
90.80
21.58
4,333.51
4,285.31
63.29
1,476.89
6,016,111.11
570,779.00
4.00
673.97
End Dir
: 6300.94' MD, 4333.51' TVD
6,400.00
90.80
21.58
4,332.13
4,283.93
155.40
1,513.33
6,016,203.54
570,814.57
0.00
772.88
6,500.00
90.80
21.58
4,330.74
4,282.54
248.38
1,550.11
6,016,296.85
570,850.49
0.00
872.72
6,600.00
90.80
21.58
4,329.35
4,281.15
341.36
1,586.89
6,016,390.16
570,886.40
0.00
972.57
6,700.00
90.80
21.58
4,327.96
4,279.76
434.33
1,623.68
6,016,483.47
570,922.31
0.00
1,072.41
6,800.00
90.80
21.58
4,326.56
4,278.36
527.31
1,660.46
6,016,576.77
570,958.23
0.00
1,172.26
6,900.00
90.80
21.58
4,325.17
4,276.97
620.29
1,697.25
6,016,670.08
570,994.14
0.00
1,272.11
7,000.00
90.80
21.58
4,323.78
4,275.58
713.27
1,734.03
6,016,763.39
571,030.06
0.00
1,371.95
7,100.00
90.80
21.58
4,322.39
4,274.19
806.25
1,770.81
6,016,856.70
571,065.97
0.00
1,471.80
7,200.00
90.80
21.58
4,321.00
4,272.80
899.23
1,807.60
6,016,950.01
571,101.88
0.00
1,571.64
7,300.00
90.80
21.58
4,319.60
4,271.40
992.21
1,844.38
6,017,043.31
571,137.80
0.00
1,671.49
7,400.00
90.80
21.58
4,318.21
4,270.01
1,085.18
1,881.16
6,017,136.62
571,173.71
0.00
1,771.33
7,500.00
90.80
21.58
4,316.82
4,268.62
1,178.16
1,917.95
6,017,229.93
571,209.62
0.00
1,871.18
7,600.00
90.80
21.58
4,315.43
4,267.23
1,271.14
1,954.73
6,017,323.24
571,245.54
0.00
1,971.02
2142019 1:57.40PM
Page 4
COMPASS 5000.15 Build 91
HALLIBURTON
Database:
NORTH US+CANADA
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt E Pad
Well:
Plan: MPU E-41
Wellbore:
MPE-41
Design:
MPU E-41 WP03
Planned Survey
Measured
WELL @ 48.20usft (Original Well Elev)
MD Reference:
WELL @ 48.20usft (Original Well Elev)
Vertical
True
Survey Calculation Method:
Depth
Inclination
Azimuth
Depth
TVDss
(usft)
(1)
(1)
(usft)
usft
Vert Section
7,700.00
90.80
(usft)
21.58
4,314.04
4,265.84
(usft)
7,800.00
90.80
21.58
4,312.64
4,264.44
1,991.51
7,900.00
90.80
21.58
4,311.25
4,263.05
2,070.87
8,000.00
90.80
21.58
4,309.86
4,261.66
8,100.00
90.80
0.00
21.58
4,308.47
4,260.27
8,200.00
90.80
6,017,603.16
21.58
4,307.08
4,258.88
0.00
8,300.00
90.80
1,643.06
21.58
4,305.68
4,257.48
6,017,696.47
8,400.00
90.80
21.58
4,304.29
4,256.09
1,736.04
8,500.00
90.80
21.58
4,302.90
4,254.70
8,600.00
90.80
21.58
4,301.51
4,253.31
8,700.00
90.80
571,461.02
21.58
4,300.12
4,251.92
8,800.00
90.80
2,212.22
21.58
4,298.72
4,250.52
571,496.93
8,837.58
90.80
2,669.94
21.58
4,298.20
4,250.00
2,249.00
Start Dir 2°1100'
: 8837.58'
MD,
4298.27VD
0.00
8,900.00
90.39
2,107.95
20.40
4,297.55
4,249.35
6,018,163.01
9,000.00
89.74
18.51
4,297.44
4,249.24
2,200.93
9,100.00
89.08
16.62
4,298.47
4,250.27
9,189.48
88.50
14.93
4,300.36
4,252.16
End Dir
: 9189.48'
MD,
4300.36' TVD
0.00
3,069.32
9,200.00
88.50
14.93
4,300.64
4,252.44
9,300.00
88.50
0.00
14.93
4,303.26
4,255.06
9,400.00
88.50
6,018,478.00
14.93
4,305.87
4,257.67
0.00
9,440.60
88.50
2,480.10
14.93
4,306.94
4,258.74
6,018,536.47
Start Dir 2"1100'
: 9440.6'
MD, 4306.947VO
2.00
3,268.97
9,500.00
88.49
13.74
4,308.50
4,260.30
9,600.00
88.47
2.00
11.74
4,311.16
4,262.96
9,700.00
88.45
6,018,726.64
9.74
4,313.85
4,265.65
2.00
9,762.08
88.44
2,755.79
8.50
4,315.53
4,267.33
6,018,812.94
End Dir
: 9762.08'
MD,
4315.53' TVD
3,556.16
9,800.00
88.44
2,522.84
8.50
4,316.56
4,268.36
571,799.67
9,900.00
88.44
3,566.52
8.50
4,319.29
4,271.09
2,548.60
10,000.00
88.44
8.50
4,322.01
4,273.81
3,665.05
10,100.00
88.44
8.50
4,324.73
4,276.53
10,200.00
88.44
0.00
8.50
4,327.45
4,279.25
10,300.00
88.44
6,019,056.07
8.50
4,330.18
4,281.98
0.00
10,400.00
88.44
3,055.88
8.50
4,332.90
4,284.70
6,019,113.73
10,500.00
88.44
8.50
4,335.62
4,287.42
3,153.38
10,600.00
88.44
8.50
4,338.34
4,290.14
10,700.00
88.44
8.50
4,341.07
4,292.87
10,800.00
88.44
571,912.49
8.50
4,343.79
4,295.59
10,900.00
88.44
2,650.03
8.50
4,346.51
4,298.31
571,921.75
10,962.08
88.44
4,116.60
8.50
4,348.20
4,300.00
2,655.63
Start Dir 201100'
: 10962.08' MD, 4348.2'TVD
11,000.00
88.81
0.00
7.84
4,349.11
4,300.91
11,100.00
89.78
6,019,507.66
6.09
4,350.34
4,302.14
0.00
Halliburton
Standard Proposal Report
Local Co-ordinate Reference: Well Plan: MPU E-41
TVD Reference:
WELL @ 48.20usft (Original Well Elev)
MD Reference:
WELL @ 48.20usft (Original Well Elev)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
4,536.76 2,832.72 6,020,596.57 572,093.04 2.00 5,305.04
4,636.01 2,844.84 6,020,695.92 572,104.23 2.00 5,400.29
2/4/2019 1:57:40PM Page 5 COMPASS 5000.15 Build 91
Map
Map
+N/ -S
+E/ -W
Northing
Easting
DLS
Vert Section
(usft)
(usft)
(usft)
(usft)
4,265.84
1,364.12
1,991.51
6,017,416.55
571,281.45
0.00
2,070.87
1,457.10
2,028.30
6,017,509.85
571,317.37
0.00
2,170.71
1,550.08
2,065.08
6,017,603.16
571,353.28
0.00
2,270.56
1,643.06
2,101.86
6,017,696.47
571,389.19
0.00
2,370.40
1,736.04
2,138.65
6,017,789.78
571,425.11
0.00
2,470.25
1,829.01
2,175.43
6,017,883.09
571,461.02
0.00
2,570.09
1,921.99
2,212.22
6,017,976.39
571,496.93
0.00
2,669.94
2,014.97
2,249.00
6,018,069.70
571,532.85
0.00
2,769.78
2,107.95
2,285.78
6,018,163.01
571,568.76
0.00
2,869.63
2,200.93
2,322.57
6,018,256.32
571,604.68
0.00
2,969.48
2,293.91
2,359.35
6,018,349.63
571,640.59
0.00
3,069.32
2,386.89
2,396.13
6,018,442.93
571,676.50
0.00
3,169.17
2,421.83
2,409.96
6,018,478.00
571,690.00
0.00
3,206.69
2,480.10
2,432.32
6,018,536.47
571,711.82
2.00
3,268.97
2,574.38
2,465.63
6,018,631.05
571,744.25
2.00
3,368.56
2,669.71
2,495.81
6,018,726.64
571,773.54
2.00
3,467.78
2,755.79
2,520.14
6,018,812.94
571,797.06
2.00
3,556.16
2,765.96
2,522.84
6,018,823.13
571,799.67
0.00
3,566.52
2,862.55
2,548.60
6,018,919.95
571,824.52
0.00
3,665.05
2,959.14
2,574.36
6,019,016.76
571,849.38
0.00
3,763.57
2,998.35
2,584.81
6,019,056.07
571,859.47
0.00
3,803.57
3,055.88
2,599.52
6,019,113.73
571,873.64
2.00
3,861.99
3,153.38
2,621.56
6,019,211.42
571,894.77
2.00
3,959.79
3,251.59
2,640.19
6,019,309.79
571,912.49
2.00
4,056.81
3,312.86
2,650.03
6,019,371.14
571,921.75
2.00
4,116.60
3,350.35
2,655.63
6,019,408.68
571,927.01
0.00
4,153.00
3,449.21
2,670.41
6,019,507.66
571,940.86
0.00
4,249.01
3,548.08
2,685.18
6,019,606.65
571,954.71
0.00
4,345.02
3,646.94
2,699.96
6,019,705.64
571,968.57
0.00
4,441.03
3,745.81
2,714.74
6,019,804.63
571,982.42
0.00
4,537.03
3,844.67
2,729.51
6,019,903.62
571,996.28
0.00
4,633.04
3,943.54
2,744.29
6,020,002.61
572,010.13
0.00
4,729.05
4,042.40
2,759.06
6,020,101.60
572,023.98
0.00
4,825.06
4,141.27
2,773.84
6,020,200.59
572,037.84
0.00
4,921.07
4,240.13
2,788.61
6,020,299.57
572,051.69
0.00
5,017.07
4,339.00
2,803.39
6,020,398.56
572,065.55
0.00
5,113.08
4,437.86
2,818.16
6,020,497.55
572,079.40
0.00
5,209.09
4,499.24
2,827.34
6,020,559.00
572,088.00
0.00
5,268.69
4,536.76 2,832.72 6,020,596.57 572,093.04 2.00 5,305.04
4,636.01 2,844.84 6,020,695.92 572,104.23 2.00 5,400.29
2/4/2019 1:57:40PM Page 5 COMPASS 5000.15 Build 91
HALLIBURTON
Database:
NORTH US+CANADA
Company:
Hiloorp Alaska, LLC
Project:
Milne Point
Site:
M Pt E Pad
Well:
Plan: MPU E-41
Wellbore:
MPE-41
Design:
MPU E-41 WP03
Planned Survey
Measured
0.00 0.00 4,348.20
6,623.18
TVD Reference:
Vertical
MO Reference:
Depth
WELL
Inclination
North Reference:
Azimuth
Depth
TVDss
(usft)
Survey Calculation
(1)
Curvature
(')
(usft)
usft
11,122.32
Map
90.00
0.00 0.00 4,298.20
5.70
4,350.38
4,302.18
End
Dir
: 11122.32'
Vert Section
MD, 4350.38'
TVD
(usft)
11,200.00
4,302.18
90.00
4,658.21
5.70
4,350.38
4,302.18
11,300.00
5,421.42
90.00
2,854.85
5.70
4,350.38
4,302.18
11,400.00
4,835.02
90.00
6,020,895.08
5.70
4,350.38
4,302.18
11,500.00
2,874.72
90.00
572,131.33
5.70
4,350.38
4,302.18
11,600.00
6,021,094.25
90.00
0.00
5.70
4,350.38
4,302.18
11,700.00
572,149.34
90.00
5,873.16
5.70
4,350.38
4,302.18
11,800.00
0.00
90.00
5,332.54
5.70
4,350.38
4,302.18
11,900.00
6,062.29
90.00
2,924.38
5.70
4,350.38
4,302.18
12,000.00
5,531.55
90.00
6,021,592.17
5.70
4,350.38
4,302.18
12,100.00
2,944.24
90.00
572,194.36
5.70
4,350.38
4,302.18
12,200.00
6,021,791.34
90.00
0.00
5.70
4,350.38
4,302.18
12,300.00
572,212.37
90.00
6,535.14
5.70
4,350.38
4,302.18
12,400.00
0.00
90.00
6,029.08
5.70
4,350.38
4,302.18
12,500.00
6,724.27
90.00
2,993.90
5.70
4,350.38
4,302.18
12,600.00
6,228.09
90.00
6,022,289.26
5.70
4,350.38
4,302.18
12,700.00
3,013.76
90.00
572,257.40
5.70
4,350.38
4,302.18
12,800.00
6,022,488.43
90.00
0.00
5.70
4,350.38
4,302.18
12,900.00
572,275.41
90.00
7,197.12
5.70
4,350.38
4,302.18
13,000.00
0.00
90.00
5.70
4,350.38
4,302.18
13,100.00
90.00
5.70
4,350.38
4,302.18
Total Depth : 13100'
MD, 4350.38'
TVD - 6
5/8" x 8 1/2"
Targets
Target Name
- hit/miss target
- Shape
MPE-Wellman NB CP2
- plan hits target center
- Point
Halliburton
Standard Proposal Report
Local Co-ordinate Reference: Well Plan: MPU E-41
0.00 0.00 4,348.20
6,623.18
TVD Reference:
WELL @ 48.20usft (Original Well Elev)
MO Reference:
- Point
WELL
@ 48.20usft (Original Well Elev)
North Reference:
True
0.00 0.00 4,328.20
-71.34
1,423.63
Survey Calculation
Method: Minimum
Curvature
- Point
Map
Map
0.00 0.00 4,298.20
2,421.83
+N/ -S
+E1 -W
Northing
Easting
DLS
Vert Section
(usft)
(usft)
(usft)
(usft)
4,302.18
4,658.21
2,847.14
6,020,718.14
572,106.32
2.00
5,421.42
4,735.51
2,854.85
6,020,795.50
572,113.32
0.00
5,494.88
4,835.02
2,864.78
6,020,895.08
572,122.32
0.00
5,589.45
4,934.52
2,874.72
6,020,994.67
572,131.33
0.00
5,684.02
5,034.03
2,884.65
6,021,094.25
572,140.33
0.00
5,778.59
5,133.53
2,894.58
6,021,193.84
572,149.34
0.00
5,873.16
5,233.04
2,904.51
6,021,293.42
572,158.34
0.00
5,967.73
5,332.54
2,914.44
6,021,393.00
572,167.35
0.00
6,062.29
5,432.05
2,924.38
6,021,492.59
572,176.35
0.00
6,156.86
5,531.55
2,934.31
6,021,592.17
572,185.36
0.00
6,251.43
5,631.06
2,944.24
6,021,691.76
572,194.36
0.00
6,346.00
5,730.57
2,954.17
6,021,791.34
572,203.37
0.00
6,440.57
5,830.07
2,964.10
6,021,890.93
572,212.37
0.00
6,535.14
5,929.58
2,974.04
6,021,990.51
572,221.38
0.00
6,629.70
6,029.08
2,983.97
6,022,090.09
572,230.38
0.00
6,724.27
6,128.59
2,993.90
6,022,189.68
572,239.39
0.00
6,818.84
6,228.09
3,003.83
6,022,289.26
572,248.39
0.00
6,913.41
6,327.60
3,013.76
6,022,388.85
572,257.40
0.00
7,007.98
6,427.10
3,023.70
6,022,488.43
572,266.40
0.00
7,102.55
6,526.61
3,033.63
6,022,588.02
572,275.41
0.00
7,197.12
6,626.12
3,043.56
6,022,687.60
572,284.41
0.00
7,291.68
Dip Angle Dip Dir. TVD
(1) (1) (usft)
0.00 0.00 4,348.20
+N/ -S +E/ -W
(usft) (usft)
4,499.23 2,827.34
MPE-Wellman NB toe
0.00 0.00 4,348.20
6,623.18
3,080.13
- plan misses target center by 36.75usft
at 13100.00usft MD (4350.38 ND, 6626.12 N, 3043.56 E)
- Point
MPE-Wellman NB Heel
0.00 0.00 4,328.20
-71.34
1,423.63
- plan hits target center
- Point
MPE-Wellman NB CPI
0.00 0.00 4,298.20
2,421.83
2,409.96
- plan hits target center
- Point
Northing Easting
(usft) (usft)
6,020,559.00 572,088.00
6,022,685.00 572,321.00
6,015,976.00 570,727.00
6,018,478.00 571,690.00
2142019 1:57 40PM Page 6 COMPASS 5000.15 Build 91
Halliburton
HALLIBURTON Standard Proposal Report
Database:
NORTH US + CANADA
Local Coordinate Reference:
Well Plan: MPU E-41
Company:
Hilcorp Alaska, LLC
TVD Reference:
WELL @ 48.20usft (Original Well Elev)
Project:
Milne Point
MD Reference:
WELL @ 48.20usft (Original Well Elev)
Site:
M Pt E Pad
North Reference:
True
Well:
Plan: MPU E-41
Survey Calculation Method:
Minimum Curvature
Wellbore:
MPE-41
(usft)
(usft)
Design:
MPU E-41 WP03
350.00
350.00
Casing Points
Measured Vertical
Depth Depth
(usft) (usft)
6,156.00 4,328.20 95/8"x121/4"
13,100.00 4,350.38 65/8"x81/2"
Casing
Diameter
Name ()
9-5/8
6-5/8
Hole
Diameter
(11)
12-1/4
8-1/2
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+N/ -S
+El -W
(usft)
(usft)
(usft)
(usft)
Comment
350.00
350.00
0.00
0.00
Start Dir 3'1100': 350' MD, 350'TVD
550.00
549.63
-9.06
-5.23
Start Dir 4-1100': 550' MD, 549.63'TVD
1,583.73
1,461.49
-446.69
-1.90
End Dir : 1583.73' MD, 1461.49' TVD
2,511.99
2,104.27
-1,114.20
52.32
Start Dir 4°/100': 2511.99'MD, 2104.27'TVD
5,656.00
4,284.62
-534.52
1,240.43
End Dir : 5656' MD, 4284.62' TVD
6,156.00
4,328.20
-71.34
1,423.63
Start Dir 4°/100': 6156'MD, 4328.2'TVD
6,300.94
4,333.51
63.29
1,476.89
End Dir : 6300.94' MD, 4333.51' TVD
8,837.58
4,298.20
2,421.83
2,409.96
Start Dir 2°/100' : 8837.58' MD, 4298.2'TVD
9,189.48
4,300.36
2,755.79
2,520.14
End Dir : 9189.48' MD, 4300.36' TVD
9,440.60
4,306.94
2,998.35
2,584.81
Start Dir2°/100': 9440.6' MD, 4306.94'TVD
9,762.08
4,315.53
3,312.86
2,650.03
End Dir : 9762.08' MD, 4315.53' TVD
10,962.08
4,348.20
4,499.24
2,827.34
Start Dir 2°/100' : 10962.08' MD, 4348.2'TVD
11,122.32
4,350.38
4,658.21
2,847.14
End Dir : 11122.32' MD, 4350.38' TVD
13,100.00
4,350.38
6,626.12
3,043.56
Total Depth : 13100' MD, 4350.38' TVD
2142019 1:57:40PM Page 7 COMPASS 5000.15 Build 91
HALLIBLJRTON
Project: Milne Point REFERENCE INFORMATION WELL DEfAILS:PIan: MPU E4I NAD 19271NADCON CONUS) Alaaka Zane 04
Cgurdirem ) Reference: Well Plan: MPU E41. Two Noah Genaid Le sl: 21,70
Site: MPtEPad
9pemy OMIIInB
yemca1 (TVD)NO)Rerers
ree:WELL @ 48.20u(O
sk (Original Wall Elea
Well: Plan: MPU E-41 Measurec Deem(Original Well Elev) +N/ -S +&-W Nonhin6 EasBng Lafined27.14.c Inngilade
Methee: WELL
on
calculation Memos: Minimum Curvelure 0.00 O.W 6016034 09 569302.90 70° 2T 14981 N 149° 26' 4.091 W
ConnouR 91
Wellbore: MPE-41
Plan: MPU E-41 WP03 SURVEY PROGRAM NO GLOBAL FILTER: Using user defined selection 8 filtering criteria
Dale:201B-10.197000000 Validated: Yes Version: 26.50 To 13100.00
Ladder / S.F. Plots Depth DepthFrom ol CASMG DETA LS
26.50 616.00 MPUeE41 WP03(MPE41) 2�MWD+IFR2+MS+Sag
TVD TVDSS MD Sixe Name
SH(1 of 2) 6156.00 13099.83 MPU E41 WP03(MPE41) 2_MWD+IFR2+MS+Sag
4328 20 4280.00 6156.00 9-5/8 9 5/8" x 12 1/4"
4350.38 4302.18 13100.00 6-5/8 6519".91J2"
180.00
-U,—
c
42150.00—
OPE-24A
MPE-14A
-
o
MPE-24
M14
m120.00
-
-
--
p
MPE-1
---MP
E-39 wp0
90.00
-
�
_.
.._.....
�
J)
d
U E Plac
holder
-
U60.00
_ -'
i
--MPH
E
Placehatd
--
-
—
—
--
o
0)
MPE-40 m
p02
PE40
WPM
C 30.00
0
MPU E-39
wp03
0.00
0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175
Measured Depth (650 usft/in)
4.50-
.50
o
0
0 3.00
_.
....__._....._
.._....
UL
C
0
m
CI-
Collision Risk Procedures Rec
I.
(D 1.50
-
Collision Avoidance Req.
No -Go Zone - Stop Drilling
0.00
0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300
Measured Depth
Hilcorp Alaska, LLC
Milne Point
M Pt E Pad
Plan: MPU E-41
M P E-41
MPU E-41 WP03
Sperry Drilling Services
Clearance Summary
Anticollision Report
04 February, 2019
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt E Pad - Plan: MPU E-41 - MPE-41 - MPU E41 WP03
Well Coordinates: 6,016,034.09 N, 569,302.90 E (70° 27' 14.98" N. 149° 26'04.09" W)
Datum Height: WELL @ 48.20usft (Original Well Elev)
Scan Range: 26.50 to 6,156.00 usft. Measured Depth.
Scan Radius Is Unlimited. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation Is 1,500.00 usft
Geodetic Scale Factor Applied
Version: 5000.15 Build: 91
Scan Type: NO GLOBAL
Scan Type: 25.00
HALLIBURTON
Sperry Drilling Services
HALLIBURTON
Hilcorp Alaska, LLC
Milne Point
Anticollision Report for Plan: MPU E-41 - MPU E-41 WP03
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt E Pad - Plan: MPU E-41 - MPE-41 - MPU E-41 WP03
Scan Range: 26.50 to 6,156.00 usft. Measured Depth.
Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited.
Max Ellipse
Separation is 1,500.00 usft
Measured
Minimum
@Measured
Ellipse
@Measured
Clearance
Summary Based on
Site Name
Depth
Distance
Depth
Separation
Depth
Factor
Minimum
Separation Warning
Comparison Well Name -Wellbore Name - Design
(usft)
(usft)
(usft)
(usft)
usft
M Pt E Pad
` MPE-05 - MPE-05 - MPE-05
26.50
412.38
26.50
411.47
37.01
450.280
Centre Distance
Pass -
MPE-05 - MPE-05 - MPE-05
401.50
413.55
401.50
409.35
415.07
98.533
Ellipse Separation
Pass -
MPE-05 - MPE-05 - MPE-05
5,476.50
735.07
5,476.50
673.84
4,587.53
12.005
Clearance Factor
Pass -
MPE-06 - MPE-06 - MPE-06
354.70
339.19
354.70
334.51
365.14
72.372
Centre Distance
Pass -
MPE-06 - MPE-06 - MPE-06
376.50
339.29
376.50
334.34
386.91
68.521
Ellipse Separation
Pass -
MPE-06 - MPE-06 - MPE-06
6,156.00
558.99
6,156.00
492.43
4,660.06
8.398
Clearance Factor
Pass -
MPE-07 - MPE-07 - MPE-07
354.96
287.52
354.96
282.83
365.38
61.335
Centre Distance
Pass -
MPE-07 - MPE-07 - MPE-07
376.50
287.61
376.50
282.66
387.01
58.100
Ellipse Separation
Pass -
MPE-07 - MPE-07 - MPE-07
5,551.50
489.64
5,551.50
424.24
4,931.52
7.488
Clearance Factor
Pass -
MPE-08 - MPE-08 - MPE-08
26.50
646.04
26.50
644.97
34.50
604.847
Centre Distance
Pass -
MPE-08 - MPE-08 - MPE-08
376.50
647.45
376.50
643.48
387.63
163.068
Ellipse Separation
Pass -
MPE-08 - MPE-08 - MPE-08
6,156.00
1,444.85
6,156.00
1,396.87
4,399.72
30.112
Clearance Factor
Pass -
MPE-11 - MPE-11 - MPE-11
359.58
239.23
359,58
235,42
365.66
62.780
Centre Distance
Pass -
MPE-11 - MPE-11 - MPE-11
401.50
239.45
401.50
235.28
407.04
57.416
Ellipse Separation
Pass -
MPE-11 - MPE-11 - MPE-11
4,476.50
911.65
4,476.50
866.13
4,191.68
20.026
Clearance Factor
Pass -
MPE-12 - MPE-12 - MPE-12
26.50
199.10
26.50
198.02
35.64
185.125
Centre Distance
Pass -
MPE-12 - MPE-12 - MPE-12
276.50
199.83
276.50
196.09
283.31
53.374
Ellipse Separation
Pass -
MPE-12 - MPE-12 - MPE-12
551.50
221.43
551.50
215.93
542.28
40.259
Clearance Factor
Pass -
MPE-14 - MPE-14 - MPE-14
270.50
119.87
270.50
117.52
280.00
51.163
Centre Distance
Pass -
MPE-14 - MPE-14 - MPE-14
376.50
119.96
376.50
116.87
385.99
38.824
Ellipse Separation
Pass -
MPE-14 - MPE-14 - MPE-14
4,251.50
648.43
4,251.50
571.32
4,282.41
8.409
Clearance Factor
Pass -
MPE-14 - MPE-14A- MPE-14A
270.50
119.87
270.50
117.52
280.00
51.163
Centre Distance
Pass -
MPE-14 - MPE-14A - MPE-14A
376.50
119.96
376.50
116.87
385.99
38.824
Ellipse Separation
Pass -
MPE-14 - MPE-14A- MPE-14A
4,251.50
648.43
4,251.50
572.30
4,282.41
8.518
Clearance Factor
Pass -
MPE-14-MPE-I4APB1-MPE-I4APB1
270.50
119.87
270.50
117.52
280.00
51.163
Centre Distance
Pass -
MPE-14 - MPE-14APB1 - MPE-14APB1
376.50
119.96
376.50
116.87
385.99
38.824
Ellipse Separation
Pass -
MPE-14-MPE-I4APB1-MPE-I4APB1
4,251.50
648.43
4,251.50
572.29
4,282.41
8.516
Clearance Factor
Pass -
MPE-15 - MPE-15 - MPE-15
380.05
89.23
380.05
83.64
386.25
15.949
Centre Distance
Pass -
04 February, 2019 - 13:58 Page 2 of 8 COMPASS
HALLIBURTON
Anticollision Report for Plan: MPU E-41- MPU E-41 WP03
Closest Approach 30 Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt E Pad - Plan: MPU E-41 - MPE-41 - MPU E-41 WP03
Scan Range: 26.50 to 6,156.00 usft. Measured Depth.
Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft
Hilcorp Alaska, LLC
Milne Point
04 February, 2019 - 13:58 Page 3 of 8 COMPASS
Measured
Minimum
@Measured
Ellipse
@Measured
Clearance
Summary Based on
Site Name
Depth
Distance
Depth
Separation
Depth
Factor
Minimum
Separation Warning
Comparison Well Name - Wellbore Name -Design
(usft)
(usft)
(usft)
(usft)
usft
MPE-15 - MPE-15 - MPE-15
451.50
89.68
451.50
83.05
457.67
13.513
Ellipse Separation
Pass -
MPE-15 - MPE-15 - MPE-15
726.50
107.91
726.50
97.21
731.89
10.086
Clearance Factor
Pass -
MPE-17 - MPE-17 - MPE-17
26.50
182.61
26.50
181.70
31.85
198.925
Centre Distance
Pass -
MPE-17 - MPE-17 - MPE-17
276.50
183.72
276.50
180.66
280.21
59.903
Ellipse Separation
Pass -
MPE-17 - MPE-17 - MPE-17
776.50
245.16
776.50
237.75
768.15
33.076
Clearance Factor
Pass -
MPE-18 - MPE-18 - MPE-18
26.50
210.32
26.50
208.97
36.52
155.850
Centre Distance
Pass -
MPE-18 - MPE-18 - MPE-18
101.50
210.46
101.50
208.70
110.80
120.159
Ellipse Separation
Pass -
MPE-18 - MPE-18 - MPE-18
951.50
305.67
951.50
298.06
932.20
40.169
Clearance Factor
Pass -
MPE-19 - MPE-19 - MPE-19
26.50
218.37
26.50
217.46
36.85
238.173
Centre Distance
Pass -
MPE-19 - MPE-19 - MPE-19
276.50
218.73
276.50
216.34
285.21
91.694
Ellipse Separation
Pass -
MPE-19 - MPE-19 - MPE-19
876.50
300.84
876.50
294.07
872.58
44.440
Clearance Factor
Pass -
MPE-20 - MPE-20 - MPE-20
397.77
178.13
397.77
174.42
405.04
48.038
Centre Distance
Pass -
MPE-20 - MPE-20 - MPE-20
426.50
178.25
426.50
174.34
433.33
45.642
Ellipse Separation
Pass -
MPE-20 - MPE-20 - MPE-20
826.50
217.72
826.50
210.96
827.85
32.180
Clearance Factor
Pass -
MPE-20 - MPE-20A - MPE-20A
397.77
178.13
397.77
174.42
409.79
48.038
Centre Distance
Pass -
MPE-20 - MPE-20A- MPE-20A
426.50
178.25
426.50
174.34
438.08
45.642
Ellipse Separation
Pass -
MPE-20 - MPE-20A- MPE-20A
826.50
217.72
826.50
210.96
832.60
32.181
Clearance Factor
Pass -
MPE-20 - MPE-20AL1 - MPE-20AL1
397.77
178.13
397.77
174.42
409.79
48.038
Centre Distance
Pass -
MPE-20 - MPE-20AL1 - MPE-20AL1
426.50
178.25
426.50
174.34
438.08
45.642
Ellipse Separation
Pass -
MPE-20 - MPE-20ALl - MPE-20AL1
826.50
217.72
826.50
210.96
832.60
32.181
Clearance Factor
Pass -
MPE-20 - MPE-20ALl PB1 -MPE-20AL1 PB1
397.77
178.13
397.77
174.42
409.79
48.038
Centre Distance
Pass -
MPE-20-MPE-20AL1 PB1 -MPE-20AL1 PB1
426.50
178.25
426.50
174.34
438.08
45.642
Ellipse Separation
Pass -
MPE-20-MPE-20AL1 PBI -MPE-20AL1 PB1
826.50
217.72
826.50
210.96
832.60
32.181
Clearance Factor
Pass -
MPE-21 - MPE-21 - MPE-21
354.21
312.59
354.21
310.09
363.56
124.720
Centre Distance
Pass -
MPE-21 - MPE-21 - MPE-21
376.50
312.69
376.50
310.04
385.89
117.783
Ellipse Separation
Pass -
MPE-21 - MPE-21 - MPE-21
6,026.50
602.53
6,026.50
539.92
4,556.90
9.624
Clearance Factor
Pass -
MPE-23 - MPE-23 - MPE-23
356.23
238.80
356.23
235.15
362.84
65.365
Centre Distance
Pass -
MPE-23 - MPE-23 - MPE-23
376.50
238.89
376.50
235.06
383.16
62.386
Ellipse Separation
Pass -
MPE-23 - MPE-23 - MPE-23
6,156.00
629.70
6,156.00
590.18
4,519.88
15.932
Clearance Factor
Pass -
MPE-24 - MPE-24 - MPE-24
310.89
149.26
310.89
146.61
319.80
56.312
Centre Distance
Pass -
04 February, 2019 - 13:58 Page 3 of 8 COMPASS
HALLIBURTON
Anticollision Report for Plan: MPU E-41- MPU E-41 WP03
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt E Pad - Plan: MPU E-41 - MPE-41 - MPU E-41 WP03
Scan Range: 26.50 to 6,156.00 usft. Measured Depth.
Scan Radius Is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft
Hileorp Alaska, LLC
Milne Point
04 February, 2019 - 13:58 Page 4 of 8 COMPASS
Measured
Minimum
@Measured
Ellipse
@Measured
Clearance
Summary Based on
Site Name
Depth
Distance
Depth
Separation
Depth
Factor
Minimum
Separation Warning
Comparison Well Name - Wellbore Name - Design
(usft)
(usft)
(usft)
(usft)
usft
MPE-24 - MPE-24 - MPE-24
401.50
149.59
401.50
146.30
410.77
45.447
Ellipse Separation
Pass -
MPE-24 - MPE-24 - MPE-24
3,226.50
481.40
3,226.50
404.81
3,430.31
6.285
Clearance Factor
Pass -
MPE-24 - MPE-24A - MPE-24A
310.89
149.26
310.89
146.72
316.40
58.736
Centre Distance
Pass -
MPE-24 - MPE-24A- MPE-24A
401.50
149.59
401.50
146.41
407.37
47.009
Ellipse Separation
Pass -
MPE-24 - MPE-24A- MPE-24A
3,226.50
481.40
3,226.50
405.19
3,426.91
6.317
Clearance Factor
Pass -
MPE-24 - MPE-24AL1 - MPE-24AL1
310.89
149.26
310.89
146.72
316.40
58.736
Centre Distance
Pass -
MPE-24 - MPE-24AL1 - MPE-24AL1
401.50
149.59
401.50
146.41
407.37
47.009
Ellipse Separation
Pass -
MPE-24 - MPE-24AL1 - MPE-24AL1
3,226.50
481.40
3,226.50
405.11
3,426.91
6.310
Clearance Factor
Pass -
MPE-30 - MPE-30 - MPE-30
390.04
362.44
390.04
359.54
404.53
124.807
Centre Distance
Pass -
MPE-30 - MPE-30 - MPE-30
401.50
362.48
401.50
359.50
414.92
121.673
Ellipse Separation
Pass -
MPE-30 - MPE-30 - MPE-30
1,026.50
506.69
1,026.50
499.47
986.66
70.133
Clearance Factor
Pass -
MPE-30 - MPE-30A- MPE-30A
390.04
362.44
390.04
359.54
404.53
124.807
Centre Distance
Pass -
MPE-30 - MPE-30A- MPE-30A
401.50
362.48
401.50
359.50
414.92
121.673
Ellipse Separation
Pass -
MPE-30 - MPE-30A - MPE-30A
1,026.50
506.69
1,026.50
499.47
986.66
70.131
Clearance Factor
Pass -
MPE-30-MPE-30AL1-MPE-30AL1
390.04
362.44
390.04
359.54
404.53
124.807
Centre Distance
Pass -
MPE-30 - MPE-30AL1 - MPE-30ALl
401.50
362.48
401.50
359.50
414.92
121.673
Ellipse Separation
Pass -
MPE-30 - MPE-30AL1 - MPE-30AL1
1,026.50
506.69
1,026.50
499.47
986.66
70.132
Clearance Factor
Pass -
MPE-30-MPE-30AL1PB1-MPE-30AL1PB1
390.04
362.44
390.04
359.54
404.53
124.807
Centre Distance
Pass -
MPE-30 - MPE-30ALlPBI-MPE-30AL1PB1
401.50
362.48
401.50
359.50
414.92
121.673
Ellipse Separation
Pass -
MPE-30-MPE-30ALIPB1-MPE-30AL1 PB1
1,026.50
506.69
1,026.50
499.47
986.66
70.131
Clearance Factor
Pass -
MPE-30 - MPE-30APB1 - MPE-30APB1
390.04
362.44
390.04
359.54
404.53
124.807
Centre Distance
Pass -
MPE-30 - MPE-30APB1 - MPE-30AP61
401.50
362.48
401.50
359.50
414.92
121.673
Ellipse Separation
Pass -
MPE-30-MPE-30APB1-MPE-30APB1
1,026.50
506.69
1,026.50
499.47
986.66
70.131
Clearance Factor
Pass -
MPE-31 - MPE-31 - MPE-31
92.97
494.67
92.97
492.70
101.07
251.087
Centre Distance
Pass -
MPE-31 - MPE-31 - MPE-31
301.50
496.07
301.50
491.97
303.88
120.780
Ellipse Separation
Pass -
MPE-31 - MPE-31 - MPE-31
801.50
564.55
801.50
554.74
760.22
57.582
Clearance Factor
Pass -
MPE31-MPE-31 PB1 -MPE-31 PB1
92.97
494.67
92.97
492.70
101.07
251.087
Centre Distance
Pass -
MPE-31 - MPE-31PB1 - MPE-31PB1
301.50
496.07
301.50
491.97
303.88
120.780
Ellipse Separation
Pass -
MPE-31 - MPE-31PS1 - MPE-31PS1
801.50
564.55
801.50
554.74
760.22
57.582
Clearance Factor
Pass -
MPE-32 - MPE-32 - MPE-32
26.50
523.28
26.50
521.93
33.54
389.301
Centre Distance
Pass -
04 February, 2019 - 13:58 Page 4 of 8 COMPASS
HALLIBURTON
Anticollision Report for Plan: MPU E-41- MPU E-41 WP03
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt E Pad - Plan: MPU E-41 - MPE-41 -MPU E-41 WP03
Scan Range: 26.50 to 6,156.00 usft. Measured Depth.
Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft
Mleorp Alaska, LLC
Milne Point
04 February, 2019 - 13:58 Page 5 of COMPASS
Measured
Minimum
@Measured
Ellipse
@Measured
Clearance
Summary Based on
Site Name
Depth
Distance
Depth
Separation
Depth
Factor
Minimum
Separation Warning
Comparison Well Name - Wellbore Name - Design
(usft)
(usft)
(usft)
(usft)
usft
MPE-32 - MPE-32 - MPE-32
351.50
524.59
351.50
519.92
353.96
112.355
Ellipse Separation
Pass -
MPE-32 - MPE-32 - MPE-32
6,156.00
841.61
6,156.00
755.20
4,930.05
9.740
Clearance Factor
Pass - -
MPE-32 - MPE-32L1 - MPE-321-1
26.50
523.28
26.50
521.93
33.54
389.301
Centre Distance
Pass -
MPE-32 - MPE-321-1 - MPE-321-1
351.50
524.59
351.50
519.92
353.96
112.355
Ellipse Separation
Pass -
MPE-32-MPE-321-1-MPE-321-1
6,156.00
841.61
6,156.00
754.98
4,930.05
9.716
Clearance Factor
Pass-
MPE-32 - MPE-32PB1 - MPE-32PB1
26.50
523.28
26.50
521.93
33.54
389.301
Centre Distance
Pass -
MPE-32 - MPE-32PB1 - MPE-32PB1
351.50
524.59
351.50
519.92
353.96
112.355
Ellipse Separation
Pass -
MPE-32 - MPE-32PB1 - MPE-32PB1
6,156.00
841.61
6,156.00
755.20
4,930.05
9.740
Clearance Factor
Pass -
MPU E-35 - MPU E-35 - MPU E-35
197.22
158.35
197.22
156.26
197.74
75.920
Centre Distance
Pass -
MPU E-35 - MPU E-35 - MPU E-35
276.50
158.54
276.50
155.97
276.23
61.606
Ellipse Separation
Pass -
MPU E-35 - MPU E-35 - MPU E-35
701.50
226.72
701.50
221.69
672.17
45.058
Clearance Factor
Pass -
MPU E-35 - MPU E-35 P81 - MPU E-35 PB1
197.22
158.35
197.22
156.26
197.74
75.920
Centre Distance
Pass -
MPU E-35 - MPU E-35 PB1 - MPU E-35 PB1
276.50
158.54
276.50
155.97
276.23
61.606
Ellipse Separation
Pass -
MPU E-35 - MPU E-35 PB1 - MPU E-35 PB1
701.50
226.72
701.50
221.69
672.17
45.058
Clearance Factor
Pass -
MPU E-37 - MPU E-37 - MPU E-37
26.50
169.41
26.50
168.49
26.78
185.781
Centre Distance
Pass -
MPU E-37 - MPU E-37 - MPU E-37
176.50
169.74
176.50
167.83
175.54
88.620
Ellipse Separation
Pass -
MPU E-37 - MPU E-37 - MPU E-37
626.50
226.83
626.50
222.29
592.32
50.003
Clearance Factor
Pass -
MPU E-37 - MPU E-37 PBI - MPU E-37 PB1
26.50
169.41
26.50
168.49
26.78
185.781
Centre Distance
Pass -
MPU E-37 - MPU E-37 PB1 - MPU E-37 PB1
176.50
169.74
176.50
167.83
175.54
88.620
Ellipse Separation
Pass -
MPU E-37 - MPU E-37 PB1 - MPU E-37 PBI
626.50
226.83
626.50
222.29
592.32
50.003
Clearance Factor
Pass -
Plan: MPU E-38 - MPE-38 - MPE-38 WP07
280.10
60.28
280.10
56.25
280.20
14.942
Centre Distance
Pass -
Plan: MPU E-38 - MPE-38 - MPE-38 WP07
401.50
60.71
401.50
55.20
401.37
11.002
Ellipse Separation
Pass -
Plan: MPU E-38 - MPE-38 - MPE-38 WP07
501.50
64.86
501.50
58.14
500.00
9.649
Clearance Factor
Pass -
Plan: MPU E-40 - MPE-40i - MPE-40 wp02
276.50
29.92
276.50
27.22
276.50
11.066
Centre Distance
Pass -
Plan: MPU E-40 - MPE40i - MPE-40 wp02
326.50
30.13
326.50
27.08
326.23
9.871
Ellipse Separation
Pass -
Plan: MPU E-40 - MPE-401- MPE-40 wp02
676.50
40.24
676.50
34.79
670.26
7.382
Clearance Factor
Pass -
Prelim Duall-at Plan: MPU E-42 - MPE-42 - MPE-42 wl
352.00
263.20
352.00
259.75
353.61
76.330
Centre Distance
Pass -
Prelim Duall-at Plan: MPU E-42 - MPE-42 - MPE-42 wl
451.50
263.62
451.50
259.40
456.04
62.535
Ellipse Separation
Pass -
Prelim Duall-at Plan: MPU E-42 - MPE-42 - MPE42 wl
2,526.50
630.00
2,526.50
595.49
2,575.95
18.257
Clearance Factor
Pass -
Prelim DualLatPlan: MPU E-39 - MPU E-391 - MPU E-:
664.50
25.06
664.50
19.79
667.62
4.760
Centre Distance
Pass -
04 February, 2019 - 13:58 Page 5 of COMPASS
HALLIBURTON
Anticollision Report for Plan: MPU E-41- MPU E-41 WP03
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt E Pad - Plan: MPU E-41 - MPE-41 - MPU E-41 WP03
Scan Range: 26.50 to 6,156.00 usft. Measured Depth.
Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft
Hilcorp Alaska, LLC
Milne Point
From To Survey/Plan Survey Tool
(usft) (usft)
26.50 6,156.00 MPU E-41 WP03 2_MWD+IFR2+MS+Sag
6,156.00 13,099.83 MPU E-41 WP03 2_MWD+IFR2+MS+Sag
Ellipse error terms are correlated across survey tool tie -on points.
Calculated ellipses incorporate surface errors.
Separation is the actual distance between ellipsoids.
Distance Between centres is the straight line distance between wellbore centres.
Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).
All station coordinates were calculated using the Minimum Curvature method.
04 February, 2019 - 13.58 Page 6 of 8 COMPASS
Measured
Minimum
@Measured
Ellipse
@Measured
Clearance
Summary Based on
Site Name
Depth
Distance
Depth
Separation
Depth
Factor
Minimum
Separation Warning
Comparison Well Name - Wellbore Name - Design
(usft)
(usft)
(usft)
(usft)
usft
Prelim DualLatPlan: MPU E-39 - MPU E -39i - MPU E-:
701.50
25.23
701.50
19.70
704.98
4.565
Ellipse Separation
Pass -
Prelim DualLatPlan: MPU E-39 - MPU E -39i - MPU E-;
801.50
27.40
801.50
21.14
806.03
4.381
Clearance Factor
Pass -
Prelim: MPU E -Pad Expansion Placeholder - Wellbore
744.47
51.28
744.47
45.25
777.27
8.505
Centre Distance
Pass -
Prelim: MPU E -Pad Expansion Placeholder - Wellbore
751.50
51.30
751.50
45.22
784.11
8.436
Ellipse Separation
Pass -
Prelim: MPU E -Pad Expansion Placeholder - Wellbore
801.50
52.81
801.50
46.37
832.57
8.197
Clearance Factor
Pass -
Rig: MPU E-36 - MPU E-36 - MPU E-36 wp12A
276.50
161.22
276.50
158.11
276.50
51.730
Centre Distance
Pass -
Rig: MPU E-36 - MPU E-36 - MPU E-36 wp12A
301.50
161.34
301.50
158.01
300.00
48.456
Ellipse Separation
Pass -
Rig: MPU E-36 - MPU E-36 - MPU E-36 wp12A
601.50
201.96
601.50
196.10
570.57
34.500
Clearance Factor
Pass -
Rig: MPU E-36 - MPU E-36 - MPU E-36
80.13
161.22
80.13
159.84
80.13
116.436
Centre Distance
Pass -
Rig: MPU E-36 - MPU E-36 - MPU E-36
101.50
161.23
101.50
159.66
100.00
102.920
Ellipse Separation
Pass -
Rig: MPU E-36 - MPU E-36 - MPU E-36
226.50
204.93
226.50
201.03
100.00
52.589
Clearance Factor
Pass -
From To Survey/Plan Survey Tool
(usft) (usft)
26.50 6,156.00 MPU E-41 WP03 2_MWD+IFR2+MS+Sag
6,156.00 13,099.83 MPU E-41 WP03 2_MWD+IFR2+MS+Sag
Ellipse error terms are correlated across survey tool tie -on points.
Calculated ellipses incorporate surface errors.
Separation is the actual distance between ellipsoids.
Distance Between centres is the straight line distance between wellbore centres.
Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).
All station coordinates were calculated using the Minimum Curvature method.
04 February, 2019 - 13.58 Page 6 of 8 COMPASS
Hilcorp Alaska, LLC
Milne Point
M Pt E Pad
Plan: MPU E-41
MPE-41
MPU E-41 WP03
Sperry Drilling Services
Clearance Summary
Anticollision Report
04 February, 2019
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt E Pad - Plan: MPU E-41 - MPE-41 - MPU E-41 WP03
Well Coordinates: 6,016,034.09 N, 569,302.90 E (70° 27' 14.98" N, 149° 26' 04.09" W)
Datum Height: WELL @ 48.20usft (Original Well Elev)
Scan Range: 6,156.00 to 13,100.00 usft. Measured Depth.
Scan Radius Is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft
Geodetic Scale Factor Applied
Version: 5000.15 Build: 91
Scan Type:
Scan Type: 25.D0
HALLIBURTON
Sperry Drilling Services
Hilcorp Alaska, LLC
HALLIBURTON
Milne Point
Anticollision Report for Plan: MPU
E-41 - MPU E-41 WP03
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt E Pad - Plan: MPU E-41 - MPE-41 - MPU E-41 WP03
Scan Range: 6,156.00 to 13,100.00 usft. Measured Depth.
Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse
Separation is 1,500.00 usft
Measured
Minimum
@Measured
Ellipse
@Measured
Clearance
Summary Based on
Site Name
Depth
Distance
Depth
Separation
Depth
Factor
Minimum
Separation Warning
Comparison Well Name - Wellbore Name - Design
(usft)
(usft)
(usft)
(usft)
usft
M Pt B Pad
MPB-01 - MPB-01 - MPB-01
13,051.76
516.71
13,051.76
388.55
3,897.00
4.032
Centre Distance
Pass -
MPB-01 - MPB-01 - MPB-01
13,100.00
518.96
13,100.00
377.00
3,897.00
3.656
Clearance Factor
Pass -
MPB-01 - MPB-01 PB1 - MPB-01 P81 'F
-
MP&02-MPB-02-MPB-02
13,100.00
495.18
13,100.00
351.33
4,357.90
3.442
Clearance Factor
Pass -
MP&03 - MP&03 - MPB-03
13,100.00
729.39
13,100,00
596.54
4,200.00
5.490
Clearance Factor
Pass -
MPB-04 - MPB-04 - MPB-04
13,100.00
951.41
13,100.00
895.86
3,966.48
17.127
Clearance Factor
Pass -
MPB-04 - MPB-04A- MPB-04A
13,031.00
898.31
13,031.00
800.09
3,941.43
9.146
Clearance Factor
Pass -
MP&04 - MPB-04A- MPB-04A
13,100.00
889.59
13,100.00
792.70
3,928.62
9.181
Ellipse Separation
Pass -
MPB-I2-MPB-I2-MPB-12
13,100.00
1,492.62
13,100.00
1,409.18
3,877.26
17.889
Clearance Factor
Pass -
MPS-13-MPB-I3-MPB-13
12,156.00
1,348.05
12,156.00
1,188.73
4,556.13
8.461
Clearance Factor
Pass -
MPB-13 - MPB-13 - MPB-13
12,806.00
1,218.11
12,806.00
1,092.53
4,140.17
9.699
Ellipse Separation
Pass -
MPB-13 - MPB-13 - MPB-13
12,871.62
1,216.72
12,871.62
1,094.15
4,106.81
9.927
Centre Distance
Pass -
MPB-14-MPB-I4-MPB-14
13,100.00
1,089.87
13,100.00
1,010.31
4,425.10
13.698
Clearance Factor
Pass -
MPB-I5-MPB-I5-MPB-15
11,481.00
568.68
11,481.00
346.68
5,260.81
2.562
Clearance Factor
Pass -
MPB-15 - MPB-15 - MPB-15
11,506.00
567.83
11,506.00
346.23
5,238.60
2.562
Ellipse Separation
Pass -
MPB-I5-MPB-15-MPB-15
11,546.00
567.28
11,546.00
346.79
5,204.61
2.573
Centre Distance
Pass -
MPB-16 - MPB-16 - MPB-16
12,881.00
198.06
12,881.00
32.20
4,620.97
1.194
Clearance Factor
Pass -
MPB-16 - MPB-16 - MPB-i6
12,930.15
194.40
12,930.15
35.70
4,590.00
1.225
Centre Distance
Pass -
MPB-17-MPB-17-MPB-17
12,206.00
1,457.29
12,206.00
1,311.73
4,118.58
10.012
Clearance Factor
Pass -
MPB-17 - MPB-17 - MPB-17
12,606.00
1,396.75
12,606.00
1,271.03
3,900.00
11.109
Ellipse Separation
Pass -
MPB-17-MPB-17-MPB-17
12,671.85
1,395.43
12,671.85
1,272.74
3,872.63
11.374
Centre Distance
Pass -
MPB-20 - MPB-20 - MPB-20
13,100.00
723.77
13,100.00
555.44
4,900.00
4.300
Clearance Factor
Pass -
MPS -21 - MPB-21 - MPB-21
11,356.00
717.00
11,356.00
404.94
5,625.33
2.298
Clearance Factor
Pass -
MPB-2I-MPB-21-MPB-21
11,481.00
701.03
11,481.00
399.33
5,534.80
2.324
Ellipse Separation
Pass -
MPB-21 - MPB-21 - MPB-21
11,640.69
693.77
11,640.69
409.75
5,415.43
2.443
Centre Distance
Pass -
MPB-2I-MPB-21PB1-MPB-21 PB1
11,356.00
717.00
11,356.00
404.96
5,625.33
2.298
Clearance Factor
Pass -
MPB-2I-MPB-21PB1-MPB-21 PB1
11,481.00
701.03
11,481.00
399.35
5,534.80
2.324
Ellipse Separation
Pass -
MPB-2I-MPB-21 P81-MPB-21 PB1
11,640.69
693.77
11,640.69
409.76
5,415.43
2.443
Centre Distance
Pass -
04 February, 2019 - 13:59 Page 2 of 7 COMPASS
HALLIBURT®N
Anticollision Report for Plan: MPU E-41- MPU E-41 WP03
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt E Pad - Plan: MPU E-41 - MPE41 - MPU E41 WP03
Scan Range: 6,156.00 to 13,100.00 usft. Measured Depth.
Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft
Hileorp Alaska, LLC
Milne Point
MPB-29 - MPB-29 - MPB-29
Measured
Minimum
@Measured
Ellipse
@Measured
Clearance
Summary Based on
Pass -
Site Name
Depth
Distance
Depth
Separation
Depth
Factor
Minimum
Separation Warning
Comparison Well Name - Wellbore Name - Design
(usft)
(usft)
(usft)
(usft)
usft
9.306
Ellipse Separation
Pass -
MPB-22 - MPB-22 - MPB-22
10,181.00
1,495.05
10,181.00
1,151.67
5,950.18
4.354
Clearance Factor
Pass-
MPB-22 - MPB-22 - MPB-22
10,656.00
1,417.26
10,656.00
1,116.59
5,579.79
4.714
Ellipse Separation
Pass - -
MPB-22-MPB-22-MPB-22
11,687.18
1,331.80
11,687.18
1,147.72
4,571.35
7.235
Centre Distance
Pass -
MPB-22 - MPB-22A - MPB-22A
10,181.00
1,495.05
10,181.00
1,151.67
5,950.18
4.354
Clearance Factor
Pass-
MPB-22 - MPB-22A - MPB-22A
10,656.00
1,417.26
10,656.00
1,116.59
5,579.79
4.714
Ellipse Separation
Pass-
MPB-22 - MPB-22A - MPB-22A
11,687.18
1,331.80
11,687.18
1,147.72
4,571.35
7.235
Centre Distance
Pass-
MPB-22-MPB-22APB1-MPB-22APB1
10,181.00
1,495.05
10,181.00
1,151.67
5,950.18
4.354
Clearance Factor
Pass-
MPB-22-MPB-22APB1-MPB-22AP61
10,656.00
1,417.26
10,656.00
1,116.59
5,579.79
4.714
Ellipse Separation
Pass -
MPB-22 - MPB-22APB1 - MPB-22APB1
11,687.18
1,331.80
11,687.18
1,147.72
4,571.35
7.235
Centre Distance
Pass -
MPB-28 - MPB-28 - MPB-28
12,356.00
1,159.90
12,356.00
1,063.34
4,019.52
12.012
Clearance Factor
Pass-
MPB-28 - MPB-28 - MPB-28
12,531.00
1,145.74
12,531.00
1,050.89
3,992.75
12.079
Ellipse Separation
Pass-
MPB-28 - MPB-28 - MPB-28
12,541.15
1,145.70
12,541.15
1,050.93
3,992.75
12.089
Centre Distance
Pass -
MPB-29 - MPB-29 - MPB-29
13,100.00
975.64
13,100.00
875.49
3,925.81
9.742
Clearance Factor
Pass -
MPU B-30 - MPU B-30 - MPV B-30
12,381.00
1,033.08
12,381.00
921.65
4,431.97
9.270
Clearance Factor
Pass -
MPU B-30 - MPU B-30 - MPU B-30
12,456.00
1,029.81
12,456.00
919.15
4,407.63
9.306
Ellipse Separation
Pass -
MPU 8-30 - MPU B-30 - MPU B-30
12,469.25
1,029.73
12,469.25
919.25
4,403.39
9.321
Centre Distance
Pass -
MPU B-30 - MPU B-30 PB1 - MPU B-30 PB1
12,381.00
1,033.08
12,381.00
921.65
4,431.97
9.270
Clearance Factor
Pass -
MPU B-30 - MPU B-30 PB1 - MPU B-30 PB1
12,456.00
1,029.81
12,456.00
919.15
4,407.63
9.306
Ellipse Separation
Pass -
MPU B-30 - MPU B-30 PB1 - MPU B-30 PB1
12,469.25
1,029.73
12,469.25
919.25
4,403.39
9.321
Centre Distance
Pass -
MPU B-33 - MPU B-33 - MPU B-33
13,100.00
1,275.06
13,100.00
1,187.77
3,845.62
14.607
Clearance Factor
Pass -
M Pt E Pad
MPE-05 - MPE-05 - MPE-05
6,156.00
974.32
6,156.00
914.18
4,526.78
16.201
Clearance Factor
Pass -
MPE-05 - MPE-05 - MPE-05
6,156.00
974.32
6,156.00
914.18
4,526.78
16.201
Ellipse Separation
Pass -
MPE-06 - MPE-06 - MPE-06
6,666.25
242.28
6,666.25
166.19
4,730.14
3.184
Clearance Factor
Pass -
MPE-07 - MPE-07 - MPE-07
6,156.00
829.31
6,156.00
760.31
4,812.40
12.020
Clearance Factor
Pass -
MPE-08 - MPE-08 - MPE-08
7,629.57
542.08
7,629.57
471.82
5,039.69
7.716
Centre Distance
Pass -
MPE-08 - MPE-08 - MPE-08
7,656.00
542.62
7,656.00
471.60
5,049.85
7.639
Ellipse Separation
Pass -
MPE-08 - MPE-08 - MPE-08
7,731.00
550.14
7,731.00
477.18
5,076.28
7.540
Clearance Factor
Pass -
MPE-11 - MPE-11 - MPE-11
6,156.00
1,430.55
6,156.00
1,389.23
4,236.95
34.621
Clearance Factor
Pass -
MPE-12 - MPE-12 - MPE-12
8,995.79
211.36
8,995.79
126.00
5,832.01
2.476
Centre Distance
Pass -
04 February, 2019 - 13:59 Page 3 of 7 COMPASS
HALLIBURTON
Anticollision Report for Plan: MPU E-41- MPU E-41 WP03
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt E Pad - Plan: MPU E-41 - MPE-41 - MPU E-41 WP03
Scan Range: 6,156.00 to 13,100.00 usft. Measured Depth.
Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft
Hileorp Alaska, LLC
Milne Point
04 February, 2019 - 13:59 Page 4 of 7 COMPASS
Measured
Minimum
@Measured
Ellipse
@Measured
Clearance
Summary Based on
Site Name
Depth
Distance
Depth
Separation
Depth
Factor
Minimum
Separation Warning
Comparison Well Name - Wellbore Name - Design
(usft)
(usft)
(usft)
(usft)
usft
MPE-12 - MPE-12 - MPE-12
9,031.00
214.42
9,031.00
121.09
5,833.79
2.297
Ellipse Separation
Pass -
MPE-12 - MPE-12 - MPE-12
9,056.00
220.20
9,056.00
122.13
5,834.86
2.245
Clearance Factor
Pass -
MPE-21 - MPE-21 - MPE-21
6,422.69
476.85
6,422.69
431.85
4,623.70
10.596
Centre Distance
Pass -
MPE-21 - MPE-21 - MPE-21
6,481.00
480.31
6,481.00
429.18
4,632.84
9.394
Ellipse Separation
Pass -
MPE-21 - MPE-21 - MPE-21
6,756.00
579.07
6,756.00
498.71
4,679.49
7.205
Clearance Factor
Pass -
MPE-23 - MPE-23 - MPE-23
6,156.00
629.70
6,156.00
590.18
4,519.88
15.932
Clearance Factor
Pass -
MPE-30 - MPE30 - MPE-30
9,731.00
198.80
9,731.00
29.94
6,626.04
1.177
Clearance Factor
Pass -
MPE-30 - MPE-30 - MPE-30
9,756.00
192.76
9,756.00
29.18
6,642.76
1.178
Ellipse Separation
Pass -
MPE-30 - MPE-30 - MPE-30
9,832.64
184.37
9,832.64
46.62
6,694.53
1.338
Centre Distance
Pass -
MPE-30 - MPE-30A- MPE-30A
9,731.00
198.80
9,731.00
28.70
6,626.04
1.169
Clearance Factor
Pass -
MPE-30 - MPE-30A- MPE-30A
9,756.00
192.76
9,756.00
28.01
6,642.76
1.170
Ellipse Separation
Pass -
MPE-30 - MPE-30A- MPE-30A
9,948.60
160.54
9,948.60
109.03
6,923.58
3.117
Centre Distance
Pass -
MPE-30 - MPE-30ALl - MPE-30ALl
9,756.00
191.56
9,756.00
27.18
6,649.67
1.165
Clearance Factor
Pass -
MPE-30 - MPE-30ALl - MPE-30ALl
10,486.87
143.54
10,486.87
75.16
7,385.00
2.100
Centre Distance
Pass -
MPE-30 - MPE-30ALl - MPE-30ALl
10,706.00
174.77
10,706.00
25.45
7,561.65
1.170
Ellipse Separation
Pass -
MPE-30 - MPE-30AL1PB1 - MPE-30AL1PB1
9,731.00
198.70
9,731.00
28.90
6,626.83
1.170
Clearance Factor
Pass -
MPE-30-MPE-30ALIPB1-MPE-30AL1PB1
9,756.00
192.58
9,756.00
28.22
6,643.77
1.172
Ellipse Separation
Pass -
MPE-30-MPE-30AL1PB1-MPE-30AL1PB1
10,484.86
146.49
10,484.86
79.38
7,385.00
2.183
Centre Distance
Pass -
MPE-30 - MPE-30APB1 - MPE-30APB1
9,731.00
198.80
9,731.00
28.70
6,626.04
1.169
Clearance Factor
Pass -
MPE-30-MPE-30APB1-MPE-30APB1
9,756.00
192.76
9,756.00
28.01
6,642.76
1.170
Ellipse Separation
Pass -
MPE-30 - MPE-30APB1 - MPE-30APBI
9,948.60
160.54
9,948.60
108.92
6,923.58
3.110
Centre Distance
Pass -
MPE-31 - MPE-31 - MPE-31
9,228.73
286.42
9,228.73
151.63
5,878.62
2.125
Centre Distance
Pass -
MPE-31 - MPE-31 - MPE-31
12,331.00
323.13
12,331.00
55.40
9,042.00
1.207
Ellipse Separation
Pass -
MPE-31 - MPE-31 - MPE-31
12,356.00
327.66
12,356.00
55.68
9,042.00
1.205
Clearance Factor
Pass -
MPE-31 - MPE-31 PB1 -MPE-31 PB1
9,228.73
286.42
9,228.73
151.63
5,878.62
2.125
Centre Distance
Pass -
MPE-31 - MPE-31 PB1 -MPE-31 PB1
12,106.00
332.23
12,106.00
64.94
8,810.60
1.243
Clearance Factor
Pass -
MPE-32 - MPE-32 - MPE-32
6,956.00
101.10
6,956.00
28.18
5,114.57
1.386
Clearance Factor
Pass -
MPE-32 - MPE-32 - MPE-32
7,014.12
83.67
7,014.12
45.76
5,127.74
2.207
Centre Distance
Pass -
MPE-32 - MPE-32LI - MPE-321-1
6,956.00
101.10
6,956.00
28.01
5,114.57
1.383
Clearance Factor
Pass -
MPE-32-MPE-321-1-MPE-321-1
7,014.12
83.67
7,014.12
45.72
5,127.74
2.205
Centre Distance
Pass -
04 February, 2019 - 13:59 Page 4 of 7 COMPASS
HALLIBURTON
Anticollision Report for Plan: MPU E-41- MPU E-41 WP03
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt E Pad - Plan: MPU E-41 - MPE-41 - MPU E-41 WP03
Scan Range: 6,156.00 to 13,100.00 usft. Measured Depth.
Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft
Hilcorp Alaska, LLC
Milne Point
From
Measured
Minimum
@Measured
Ellipse
@Measured
Clearance
Summary Based on
Site Name
Depth
Distance
Depth
Separation
Depth
Factor
Minimum
Separation Warning
Comparison Well Name -Wellbore Name - Design
(usft)
(usft)
(usft)
(usft)
usft
MPE-32 - MPE-32PB1 - MPE-32PBI
6,956.00
101.10
6,956.00
28.18
5,114.57
1.386
Clearance Factor
Pass -
MPE-32 - MPE-32PB1 - MPE-32PB1
7,014.12
83.67
7,014.12
45.76
5,127.74
2.207
Centre Distance
Pass -
MPU E-35 - MPU E-35 - MPU E-35
7,250.15
1,297.69
7,250.15
1,246.58
4,024.17
25.392
Centre Distance
Pass -
MPU E-35 - MPU E-35 - MPU E-35
7,256.00
1,297.70
7,256.00
1,246.54
4,025.56
25.367
Ellipse Separation
Pass -
MPU E-35 - MPU E-35 - MPU E-35
7,406.00
1,306.24
7,406.00
1,253.68
4,070.51
24.852
Clearance Factor
Pass -
MPU E-35 - MPU E-35 PBI - MPU E-35 PBI
7,250.15
1,297.69
7,250.15
1,246.58
4,024.17
25.392
Centre Distance
Pass -
MPU E-35 - MPU E-35 PBI - MPU E-35 PB1
7,256.00
1,297.70
7,256.00
1,246.54
4,025.56
25.367
Ellipse Separation
Pass -
MPU E-35 - MPU E-35 PB1 - MPU E-35 PBI
7,406.00
1,306.24
7,406.00
1,253.68
4,070.51
24.852
Clearance Factor
Pass -
Plan: MPU E-38 - MPE-38 - MPE-38 WP07
6,531.45
1,487.72
6,531.45
1,443.00
3,800.00
33.267
Ellipse Separation
Pass -
Plan: MPU E-38 - MPE-38 - MPE-38 WP07
6,631.00
1,491.04
6,631.00
1,446.10
3,800.00
33.178
Clearance Factor
Pass -
From
To
(usft)
(usft)
26,50
6,156.00 MPU E-41 WP03
6,156.00
13,099.83 MPU E-41 WP03
Survey/Plan
Ellipse error terms are correlated across survey tool tie -on points.
Calculated ellipses incorporate surface errors.
Separation is the actual distance between ellipsoids.
Distance Between centres is the straight line distance between wellbore centres.
Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).
All station coordinates were calculated using the Minimum Curvature method.
Survey Tool
2_MWD+IFR2+MS+Sag
2_MWD+IFR2+MS+Sag
04 February, 2019 - 13'59 Page 5 of COMPASS
11
0
REFERENCE INFORMATION WELL DUAIISPIan: MPU FAI NAD 1927 NADCON CONUS) AlaskaZ ri, 04
HALLIBURTON
Project: Milne Point
co-omloa�ew/E) Relelrl War Pian: MPU E41. Truo North
Site: MPtE Pad VeNLalCM) Rerermee:WELL@ 41(Oli9irel Well Bev) Ground Level: 21.70
Sperry Drilling
Well: Plan: MPU E-41 Measursel Depth Reference: WELL@ 4020uafi orgral Well Eley) +W -S +V -W Northinz Eastin6 LailLpngiNde
camplaton Ml Minimum Cuna l 0.00 0.00601603609 569302.90 70° 27 14.981 N 149° 264.091 W
Wellbore: MPE-41
Plan: MPU E-41 WPO3 SURVEY PROGRAM NO GLOBAL FILTER: Using user defined seledim, B filtering mil
EM
Date:2018-10-19T00:00:00 Validated: Yes Verson: 26.50 To 13100.00
Depth From Depth To Survey/Plan Tool CASING DETAILS
Plots
Ladder/ S.F. 28.50 615600 MPU E-41 WP03(MPE-011 2 MWD+IFR2+MS+Sag TVD TVDSS MD Size Name
PH(2 of 2) 6156.00 13099.83 MPU E -0l WEDS(MPE-011 2—MWD+IFR2+MS+Seg 4328.20 4280.00 6156.00 9-5/8 95/8"x121/4"
4350.38 4302.18 13100.00 6-5/8 65/8"z81/2"
180.00
.,..,- —
_ MPE-3�IA
1
MPE-30A
B
I
X150.00
---
'- --
D
0
o
o7z0.00
-
�
-
0
90.00
---
--
M'
E-32-------------
i
�P
d
MPE-32L1
3gAL1PB
PB -01
B
- -
U60.00----
MP
-30AL7
D
d
C 30.00
—
____ _
_
—.._._.__
__-_ __
0)
U
0.00
6375 6750 7125 7500 7875 8250 8625 9000 9375 9750 10125 10500 10875 11250 11625 12000 123754.
Measured Depth (750 usfUin)
4.00
— —
`o
MILL
� 3.00
O
6
a
z.00
Collision Risk Procedures Req.
Collision Avoidance Req,
1.00
_
No -Go
Zone -
Stop Drillig_01
0.00
6375 6750 7125 7500 7875 8250 8625 9000 9375 9750 10125 10500 10875 11250 11625 12000 12375 12750 13125
Measured Depth (750 usfUin)
11
0
Transform Points
Source coordinate system Target coordinate system
State Plane 1927 - Alaska Zone 4 Albers Equal Area (-154)
Datum: MPtLr=—+I Datum:
NAD 1927 - North America Datum of 1927 (Mean NAD 1927 - Nohh America Datum of 192/ (Mean)
FM
J;
Twe values into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to
,copy and Ctd+V to paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system.
X
< Back Fnish Cancel Help _.
TRANSMITTAL LETTER CHECKLIST
WELL NAME: M P (� E-�I
PTD: 'a Q -03 1
✓ Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: ti i lh P, PO ; n+ POOL: JCC ra J �eL B (.CP4—' 0I
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing well Permit
LATERAL
No. , API No. 50 -
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50-
-� from records, data and logs acquired for well
name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
/
well logs to be nm. In addition to the well logging program proposed by
V/
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140
Well Name: MILNE PT UNIT E-41 Program QEV Well bore seg ❑
PTD#:2190310 Company HILCORP ALASKA LLC Initial Class/Type
BEV PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal ❑
Administration
1
Permit fee attached--- - - - - - - - - - - - - . - - . - . - - - - - . - - - . - - .... - - - - - - -
NA
.. _ _ . _ _ _ _ _ ........ - . - - - - -
2
Lease number appropriate- - - - --- - - - - - - - ---------- - - - - - - _ .. - - -
Yes
-
3
Unique well name and number - - - - - - - - - - - - - - - - - - - - - .... - - _ _
Yes
. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
4
Well located in a_ defined pool .... ....... ............................
Yes
_..
5
-Well located proper distance from drilling unit boundary . ........ . . . . . . . ....... .
Yes
6
Well located proper distance from other wells_ ___ _ _ _ _ _ _ _ _ _ _ _ _ __ _ __ _ _ _ _ _ _ _
Yes
7
Sufficient acreage available in drilling unit . . . . . . . ...... . . . . . . . . . ..... .
Yes
_
8
If deviated, is wellbore plat included - - --- - - - - - - - - - - - - - --- - - - - - - - - - - -
Yes
9
Operator only affected party - - - --- - - - - - - - - - --- - - - - - - - - - - - - - -----
Yes
10
Operator has appropriate bond in force - - - - - - - - - -------- - - - _ ...... -
Yes
11
Permit can be issued without conservation order _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ __
Yes
_
Appr Date
12
Permit can be issued without administrative approval - __ _ _ _ _ _ ___ _ _ __ _ _
Yes
13
Can permit be approved before 15 -day wait_ _ _ _ _ _ _ _ _ _ _ ______ _ _ _ _ _ _ _ _ _
Yes
- - - - -
DLB 2/19/2019
14
Well located within area and strata authorized by. Injection Order# (put 10# in.comments)_(For-
NA
....... _ _ _
15
All wells within 1/4 -mile area of review identified (For service well only) . . ..... .... . .
NA
_ _ _ _ _ .....-
16
Pre -produced injector: duration of pre production less than 3 months. (For service well only) - .
NA
_ _ _ _ _ _ _ _ _ _ _______
17
18
Nonconven, gas conforms to AS31,05.030([ .A),Q,2.A-D) - - - - - - - --- - - - - - - - -
Conductor stringprovided- _ .. _ _ _ .... - _ _ _ _ _ - - - - _ ..
-----------
NA............
Yes
_ _ _ _ _ _ _ 20" conductor set
Engineering
19
Surface_casing.protects all known USOWs _ _ . - - -
NA
_ _ _ _ No aquifers.. Permafrost
20
CMT vol adequate. to circulate on conductor& surf. esg ___ _ _ _ _ _ _ _ _ _____ _ _ _ _ _ _ _ _Yes
....... 9 5/0" casing will be fully cemented... ES cementer used
21
CMT. vol -adequate to fie -in JQngstring to surf csg_ . . . . . . .........
Yes
_ _ _ _ _ _ 7 5/8". tieback liner will be run. to provide MIT.annulus,
22
CMT will cover all known productive horizons;.... _ _ _ - - - - - - - - - - .
No_
_ Horz lateral will have.OH screens and packers.
23
Casing designs adequate for C, T, B & permafrost__ _ _ _ _ _ _ _ _ _ ____ _ _ _ _ _ _ _
Yes
.. _ _ . BTO supplied
24
Adequate tankage or reserve pit -- - - - - - - - - - --- - - - - - - ........ - - -
Yes
_ _ _ . Rig has steel tanks, _ .... _ ....
25
if a_re-drill, has,a 10-403 for abandonment been approved _ _ _ ___ _ _ _ _ _ _ _ _ _ _ ___
NA_
_ . _ _ Grassroots well,
26
Adequate wellbore separation proposed _ _ _ _ _ ______ _ _ _ _ _ _ _ _ _ _____ _ _ _ _ _ _ _ _
Yes
....... One close crossing with B01 P61 .. This well is abandonded.
27
If diverter required, does it meet regulations . . . . . . . . . ....... . . . .... . ...... .
Yes
_ 16" diverter on rig ... schematic of layout is. provided..
Appr Data
28
Drilling fluid program schematic_& equip list adequate_ _ _ _ _ . _ - -- - - - - - - - - - - - -
Yes
_ _ _ Max form pressure.- 1904 psi (8.5 ppg_ EMW) will drill with 8.8- 9.8 ppg mud] _
GLS 2/26/2019
29
BOPEs, do they meet regulation ______ _ _ _ _ _ _ _ _
Yes
. - . - - - _ Innovation has 13 5/8"ROPE_.. 5000 psi wp
30
BOPE press rating appropriate; test to (put psig in comments)... _ _ _ _ _ ... _ _ _ _
Yes
_ _ .... MASP = 1471- psi _Will test BORE to 3000 psi
31
Choke. manifold complies w/API-RP-53 (May 84)- - - - - - - - - - -- - - - - - - - - ---- -
Yes
32
Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _______ _ _ _ _
Yes
..
33
)s presence. of H2S gas probable ... . . . . . . . .......... . . . . . . . ... . . . .
No
..... H2$ not expected but rig has working sensors.and alarms,
34
.Mechanical condition of wells within AOR verified (For service well only) _ _ _ . _
NA_
_ . .... . . . . . . . . . . .............. . . . . . . . . . . . .
35
Permit can be issued w/o hydrogen_ sulfide measures _ _ _ _ _ _ _ ______ _ _ _ _ _ _
Yes
_ . _ _ . _ _ H2S not anticipated from drilling of offset wells; however, rig will have H2S sensors and alarms.
Geology
36
Date. presented on potential overpressure zones ------Yes
...........
..........�-� -
Appr Date
37
Seismic analysis of shallow gas zones... - - . . . . . . . . . ... . . . . . ..........
NA_
_ _ _ .... - - - - - - - - ...................
DLB 2/19/2019
38
Seabed -condition survey (if off -shore) ----------------....__.
� - - - - - - - -
NA._
- - - . ....... .-.---------- ..........------.
39
Contact name/pbone for weeklyprogressreports [exploratory only] ...... . . . . . . . . ..
NA
- - - - - - - - - - - .... - - . - - - - - - .
Geologic Engineering Public
Commissioner: Date:9:7
r: Z. -Z Dae Commissioner Date
