Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout219-098MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, June 1, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Austin McLeod
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1R-104
KUPARUK RIV UNIT 1R-104
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 06/01/2023
1R-104
50-029-21407-01-00
219-098-0
W
SPT
3230
2190980 1500
547 552 540 538
102 113 112 112
4YRTST P
Austin McLeod
5/5/2023
MITIA
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV UNIT 1R-104
Inspection Date:
Tubing
OA
Packer Depth
480 1800 1710 1690IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSAM230506184125
BBL Pumped:0.6 BBL Returned:0.5
Thursday, June 1, 2023 Page 1 of 1
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James B. Regg Digitally signed by James B. Regg
Date: 2023.06.02 11:13:08 -08'00'
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Reqq, James B (CED)
From: NSK West Sak Prod Engr <n1638@conocophillips.com>
Sent: Monday, October 14, 2019 10:26 AM
To: Regg, James B (CED)
Cc: Fox, Pete B; CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael
(Alaska); Mowrey, Andrew F
Subject: LPP/SSV Reinstated on CPAI well 1 R-104 on 10/13/2019
Jim,
This is to report that the LPP/SSV per below has been placed back in service with the original 500# LPP still in service
successfully. Feel free to contact me if there are questions.
Pete Fox
C: 832-561-6050
From: NSK West Salk Prod Engr <n1638@conocophihips.com>
Sent: Sunday, October 13, 2019 8:37 AM
To: jim.regg@alaska.gov
Cc: Fox, Pete B<Pete.B.Fox@conocophillips.com>; CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv
<n2067@conocophillips.com>; CPF1&2 Ops Supt <n2073@conocophillips.com>; Braun, Michael (Alaska)
<Michael.Braun@conocophillips.com>; Mowrey, Andrew F <Andrew.F.Mowrey@conocophi Ilips.com>; NSK West Salk
Prod Engr <n1638@conocophillips.com>
Subject: LPP/SSV Defeated on CPAI well 111-104 on 10/13/2019
Jim,
The low pressure pilot (LPP) on well 1R-104 (PTD# 219-098) was defeated and added to the "Facility Defeated Safety
Device Log" 10/13/2019 at the completion of this new injector's 30 day pre -production period and placed into injection
service. The LPP will be reinstated shortly once a lower pressure LPP (500 psi trip currently being replaced with a 200 psi
trip) is installed to allow for safe operation during the initial 'fill up' period as surface injection pressure rises above 500
psi.
This notification is in accordance with "Administrative Approval No. CO 4068.001."
Please let me know if you have any questions.
Pete Fox
WSak Production Engineer
0:907-659-7234
STATE OF ALASKA
AA0VA nu Arvin nec rnnICFRVGTInN COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1 a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑
MAAc25105 20AAC25.110
1 b. Well Class:
Development ❑ Exploratory ❑
GINJ ❑ WINJ 0 • WAG[] WDSPL ❑ No. of Completions:
Service 0 • Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Abend.: 8/20/2019
14. Permit to Drill Number / Sundry:
• 219-0981319-102
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded:
8/12/2019
15, API Number:
50-029-21407-01-00
4a. Location of Well (Governmental Section):
8. Date TO Reached:
16. Well Name and Number:
Surface: 334' FNL, 137' FWL, Sec 20, T12N, R10E, UM
Top of Productive Interval:
922' FNL, 290' FWL, Sec 20, T12N, R10E, UM
8/18/2019
KRU 1R-104
9. Ref Elevations: KB:84
GL: 45 - BF:
17. Field / Pool(s):
Kuparuk River FiekINVest Sak Oil Pool
10. Plug Back Depth MD/TVD:
N/A
18, Property Designation:
ADL 25635, ADL 25640
Total Depth:
2923' FNL, 4731' FWL, Sec 30, T12N, R10E, UM
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MDITVD: 19. DNR Approval Number:
Surface: x- 539830 y- 5990870 • Zone- 4 . 1088613391 ' LONS 83.134
TPI: x- 539988 y- 5990283 Zone- 4 12. SSSV Depth MDfTVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- 539641 y- 5983002 Zone- 4 NIA 1575/1575
5. Directional or Inclination Survey: Yes I] (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 N/A (ft MSL) 3508/3350
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
GR
23 CASING, LINER AND CEMENTING RECORD
WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT
HOLE SIZE CEMENTING RECORD PULLED
CASING FT GRADE TOP BOTTOM TOP I BOTTOM
16 1 62.5 H-40 38 115 38 1115 124 250sx CS II
95/8 36 J-55 37 4297 37 13927 1121/4 1190sz PF E, 425 sx PF C
7 26 J-55 35 8427 35 16853 18112 300sx Class G, 250sx PF C
31/2 9.2 L-80 3473 3825 33233454 4 114 Solid Liner
27/8 6.5 L-80 3825 10885 3454 3391 4 1/4 Slotted Liner
24. Open to production or injection? Yes ❑� No ❑
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
25. TUBING RECORD
SIZE DEPTH SET(MD) PACKER SET (MD/TVD)
4 112 3364 N/A
Slotted Liner@:
3826-10885 MD and 3454 - 339126.
MMPLETION
D TE
0(h
PERFS SQUEEZED OFF @: VERIFI D
3398-3558 MD and 3264-3386 TVD.... 5126/2019 _
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes E] No ❑�
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
3398-3558 34bbls 15.8ppg Class G
27 PRODUCTION TEST
Date First Production:
Method of Operation (Flowing, gas lift, etc.):
N/A
Date of Test: Hours Tested: Production for
INJECTOR WELL - PRE PRODUCED UNDER 30 DAYS
Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio:
Test Period
Flow Tubing
Casing Press:
Calculated
Oil -Bbl: Gas -MCF:
Water -Bbl: Oil Gravity-API(corr):
Press.
24-Hour Rate
Form 10-407 Revised 5/2017 ' j0/�'AINUED ON PAGE 2Submit ORIGINAL or /�
RBDMSI SEP 2 3 2019 w.i�
28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No ❑�
If Yes, list formations and intervals cored (MD/TVD, From/ro), 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 FZI
Permafrost - Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results.
1575 1575 Attach separate pages to this form, if needed, and submit detailed test
Permafrost - Base
Top of Productive Interval 3506 3349 information, including reports, per 20 AAC 25.071.
Formation @ TPI - N Sand
West Sak D 3539 3373
West Sak C 3615 3420
West Sak B 3930 3376
TO 10885 3391
Formation at total de the West Sak B
31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontologicalr well test re
1 hereby that the foregoing is true and"correct to the best of my knowledge.
32. certify
Authorized Name: James Ohlin er Contact Name: Shane Germann
Authorized Title: Staff CTD Engineer Contact Email: co.com
263-4Shane.Germann
Authorized 114A" � ,LAtLaJ�t'1��vr Contact Phone: 263-4597
1<d,ali
Signature: ;Sr 73-ovA h aC Date: 1
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 ta: 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 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water-Altemating-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
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LOCATOR; Sale
Other In Hole (Wireline retrievable plugs,
valves, Pumps, fish, etc.)
Tnp InRR)
Top Trim)
al
I Top III
I 1')
oez
Core
Run Dale
to lm)
aBu nssr:3xla
3,473.0
3,3232
39.0]
N
Baker i uard Packer wl NorNem dollies 8/2312019
2.310
RETRIEVABLE
PTSA. OAL10'Max OD2.70"
LINER TOP
PACKER
3,508.0
3.350.2
40.01
WHIPST K
Set Nonhem Solutions Inner W ge on top of X -Lock 8itit
w019
1. 0
,U3523r 2Plpwgsinsmlled7'belowbpofwhipsW&.
Top of whipstock at 3508', 0- (high side) Orientation, DAL
1571-
571'Perforations
Perforations& Slots
snol
Dena
TOP Im(D) Dem mice)
Top Rvp)
InlcR)
elm (rvgl
mK(B)
LinRea zine
pale
pnmsm
)
*rro
e°'n
7390.0 7,5560
3,2644
3.3858
512512019
120
GMTSOZ
51/ "12SUmgRDX H
.
1
TCP pelf guns
Cement Squeezes
Sees LINER: 3anitam1.0
PRODUCTION; sagal 5
�p
J'
sop (NO) B1m ITo
SURPPCE; 31.0+ 39)5
NON RETRIEVPBLE LINER "�
I'd..) B1m IRR.)
(tire) Inial Des
518n Oile
LOm
70P PncrER; 34n0
cemey Spmam: sero. xmSOUEE2E
CMTe02;33N0a,353.0
3,398.0 Jamul,
3,2644 3385.8 CEMENT
512612019
34bblsof15.8Ppg Pumped
Mandrel Inserts
Ni
o TpP lTyg)
x TOp mK.j IRrHI
Valor I.akn Ponslee TRO Run
Mexe MWII ODlln) SMY Typ Typf (b) IWg Run OaA COT
IN
24887 2,418.
Camra KBMG 5.981 GAS LIFT GLV BK 0.188 i, 4.0 9ItOQD19
1 3,306.6 3,192.6
Camco KBMG 5.984 GA6LIFT OV BK 0.188 0E 9/10/2019
-
wnlPsrocr3YA.o,
Near r-, 33.M 0.
v>�
Notes: General & Safety
Ery.
Annlmtbn
911&2019 N
TE View BCMm89C wl Alaska S[Nemauc10.0
1
I
I
I
CTO. aneR 3473 mareg o...�J
I
I
1 R-104
Plug Perforations, Perforate New Pool
Re -Enter Susp Well, Pull Tubing
Set Whipstock
DTTMSTPJOBTYP SUMMARYOPS
5/21/19 RECOMPLETION MIRU. Rig accepted at 1300 hours. Take on 9.0 ppg Sea water in pits. Pull BPV.
Displace diesel out of well to 9.0 ppg Sea Water. Nipple down production tree.
Nipple BOP.
5/22/19 RECOMPLETION Perform in between well BOP maintenance. Pressure test BOP. Pull tubing hanger.
CBU.
5/23/19 RECOMPLETION POOH LD 3 1/2" tubing. MIRU eline set CIBP, ND BOP, back off nuts on Tubing
head to allow growth.
5/23/19 DRILLING MIRU Eline. Attempt to drift w/ 5.93" Gauge ring and hang up in tree. Run in with
SUPPORT- 5.74" SL Centralizer and tag top of tubing stub at 4506'. Log GR/CCL to confirm
CAPITAL correlation for plug passes. Set first CIBP at 3710' to avoid collar. CCL to Mid
5/24/19 RECOMPLETION 4 bolt tubing head and allow casing to grow. Wait on PESI Hydratight personnel.
NU BOP and build 40 stands of 3-1/2" drill pipe. ND BOP. RU Hydratight and allow
7" casing to grow. Stretch 7" casing with 7" spear. Land casing NU new tubing
head, BOP.
5/24/19 DRILLING (7ES RIG JOB) DRIFT 7" CSG TO IRON PLUG @ 3587' RKB wl 5.735" CENT &
SUPPORT- 5.97" DRILL BIT. COMPLETE
CAPITAL
5/25/19 RECOMPLETION Slick line gauge ring run. Perforate well on DP. RIH w/ wash tool.
5/26/19 RECOMPLETION Cement. WOC.
5/27/19 RECOMPLETION WOC, drill out.
5/28/19 RECOMPLETION Drill out Cement PT.
5/29/19 RECOMPLETION Continue to displace well to clean brine. POOH. Lay down BHA. Perform USIT log
Run 4-1/2" liner. Cement the same. POOH laying down pipe in singles.
5/29/19
DRILLING
"RIG JOB ON NABORS 7ES"' LOG USIT AND CBL. JOB COMPLETE.
SUPPORT -
CAPITAL
5/30/19
RECOMPLETION
Continue laying down drill pipe. Run 4-1/2" completion string.
5/31/19
RECOMPLETION
Finish Running 4-1/2" 12.6# L-80 503 completion String. Land tubing hanger. NU
tree and freeze protect.
6/30/19
DRILLING
(PRE -CTD) : TREE VALVE DDT PASSED ON SV, SSV & MV, TREE VALVE PPT
SUPPORT-
PASSED ON SV, SSV & MV.
CAPITAL
7/20/19
DRILLING
DRIFT w/ 3" BAILER TO TOP OF CEMENT @ 3579'RKB. DRIFT w/ 17'x3 5/8"
SUPPORT-
DUMMY WHIPSTOCK TO 3575'RKB. SET 3.81" X -LOCK & FLOW THROUGH
CAPITAL
SUB @ 3549'RKB. VERIFY LOCK FULLY SET w/ X CHECK SET. IN PROGRESS.
7/21/19 DRILLING SET CATCHER ON X -LOCK @ 3549'RKB. PULL DMY & SET GLV @ 2491'RKB.
SUPPORT- PULL SOV @ 3309'RKB. MULTIPLE ATTEMPTS TO SET OV @ SAME. UNABLE
CAPITAL TO FULLY NO-GO VALVE IN POCKET. IN PROGRESS.
7/22/19 DRILLING PULL OV, BRUSH POCKET & RE -SET OV @ 3308'RKB. IDENTIFY LEAK IN GLM
SUPPORT- @ 2491'SLM. PULL & RE -SET GLV @ SAME. MIT -T TO 2500PSI *PASS*. PULL
CAPITAL CATCHER @ 3549'RKB. READY FOR E -LINE TO SET WHIPSTOCK, IN
PROGRESS.
7/24/19 DRILLING SET NORTHERN SOLUTIONS 4.5" INNER WEDGE ON TOP OF X -LOCK.
SUPPORT- WHIPSTOCK ORIENTED 4 DEG ROHS ON X -LOCK AT 3549'. TOP OF
CAPITAL WHIPSTOCK AT 3533.3'. PIP TAGS INSTALLED AT 3540.3'. LOGGED GAMMA
RAY / CCL PASS FROM TAG DEPTH TO 2400'. JOB COMPLETE.
Operations Summary (with Timelog Depths)
1 R-104
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Start Time I
End Time
Dur (hr)
Phase
Ov Cotle
Activity Code
Time P -T-%
Operation
(ftKB)
Entl Depth (ftKB)
8/512019
8/5/2019
1.00
MIRU
MOVE
RURD
P
Commeu RD checklist, secure stairs &
0.0
0.0
12:00
13:00
landing, safe -out all areas, Peak
trucks arrive at i pm
8/5/2019
8/5/2019
2.00
MIRU
MOVE
RURD
P
PJSM, rig up to sows & pull pits & sub
0.0
0.0
1300
15:00
off well
8/5/2019
8/5/2019
0.10
MIRU
MOVE
MOB
P
Move rig to adjacent well (1R-04)
0.0
0.0
1500
15:06
8/5/2019
8/5/2019
0.90
MIRU
MOVE
MOB
P
Spot sub & pits over well
0.0
0,0-
1506
16:00
8/5/2019
8/5/2019
4.00
MIRU
MOVE
RURD
P
Work RU checklist, MU tiger tank hard
0.0
0.0
1600
20:00
-line, MU scaffold in cellar, energize
reel & injector, MU PUTZ,
8/5/2019
8/5/2019
1.00
MIRU
WHDBOP
NUND
P
Rig Prep on location install and
0.0
0.0
2000
21:00
inspect scaffolding, Nipple Up stack,
check tree bolts.
8/5/2019
8/5/2019
1.00
MIRU
WHDBOP
RURD
P
Grease well control choke, stack, and
0.0
0.0
21:00
22:00
Valve crew on location to service well
head.
8/5/2019
8/6/2019
2.00
MIRU
WHDBOP
BOPE
P
Start BOPE test, option to witness test
0.0
0.0
22:00
00:00
1
waived by Jeff Jones (AOGCC), 250
psi/3,500 psi/2,500 psi annular.
8/6/2019
8/6/2019
2.00
MIRU
WHDBOP
BOPE
P
Continue ROPE test, option to witness
0.0
0.0
00:00
02:00
test waived by Jeff Jones (AOGCC),
250 psi/3,500 psi/2,500 psi annular.
8/6/2019
8/6/2019
3.00
MIRU
WHDBOP
BOPE
P
Complete BOP test (difficulty testing
0.0
0.0
02:00
05:00
swab 2, swap out Bleeder 1 A, good
est)
8/6/2019
8/6/2019
1.50
MIRU
WHDBOP
PRTS
P
Perform draw -down test, test IRV &
0.0
0.0
05:00
06:30
stripper, test gas alarms
-0
8/6/2019
8/6/2019
1.00
MIRU
WHDBOP
PRTS
P
PT tiger tank lines & PDLs
0
0.0
06:30
07:30
8/6/2019
8/6/2019
2.00
PROD1
WHPST
CTOP
F7-
Bleed off well (12 psi at surface), rack
0.0
0.0
0730
09:30
back PDL, blow down lines, open up &
watch well, MU elevators, AnTech
changes out flow tube, test NRJ
8/6/2019
8/6/2019
0.50
PROD1
WHPST
CTOP
P
Position reel, lock -out & inspect,
0.0
0.0
0930
10:00
discovered 4 cracks (2 DS & 2 ODS),
call GBR Welding in Prudhoe
8/6/2019
8/6/2019
3.00
PROD1
WHPST
RGRP
T
Prep reel area for hot work, grind &
0.0
0.0
1000
13:00
prep cracks for welders
8/6/2019
8/6/2019
3.70
PRODt
WHPST
RGRP
T
GBR Welders arrive, RU welders,
0.0
0.0
13:00
16:42
repair cracked spokes
8/612019
8/6/2019
1.50
PROD1
WHPST
PULD
P
PJSM, PU BHA #1 Window Assembly
0.0
57.2
16:42
18:12
(NS 3.80" string reamer & window
mill), attempt to test tools (no-good),
PJSM
8/6/2019
8/6/2019
1.30
PROD1
WHPST
CTOP
T
Unstab NRJ & trouble shoot
57.2
57.2
18:12
19:30
8/6/2019
8/6/20191.00
PROD1
WHPST
CTOP
T
PJSM, LD milling assembly
57.2
0.0
1930
20:30
8/6/2019
8/6/2019
3.00
PROD1
WHPST
CTOP
T
Take NRJ apart and continue
0.0
0.0
2030
23:30
troubleshooting
8/6/2019
8/7/2019
0.50
PROD?
WHPST
CTOP
T
Phone out Rig Electrican to
0.0
0.0
2330
00:00
troubleshoot Bulkhead (no -test),
lockout reel and INJH.
8/7/2019
8/7/2019
3.00
PROD1
WHPST
CTOP
T
Continue re -heading inner reel
0.0
0.0
0000
03:00
bulkhead, test a -line (All wires tested
good) unlock reel and INJH
8/7/2019
8/7/2019
2.00
PROD1
WHPST
CTOP
T
PJSM, slide cart forward, re -head NRJ
0.0
0.0
03:00
05:00
Page 1/14 Report Printed: 915/2019
Uperations Summary (with Timelog Depths)
1 R-104
.e
.6
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Start Time I
Entl Time
Dur (hp
Phase
Op Code
ACOVlty GDde
Time P-T-X
Operabon
(flKB) I
End Depth (fiKB)
8!7/2019
8/7/2019
2.00
PROD1
WHPST
PULD
P
PJSM, PU BHA#1 Window Assembly
0.0
0.0
05:00
07:00
(NS 3.80" string reamer & window
mill), attempt to test tools (good),
PJSM
8/7/2019
8/7/2019
1.00
PR001
WHPST
TRIP
P
RIH w/ CV open
0.0
3,370.0
07:00
08:00
8/7/2019
8/7/2019
0.20
PROD1
WHPST
DLOG
P
Log initial correlation pass, +3 -ft
3,370.0
3,470.0
08:00
08:12
1
1
correction, 35K up wt.
8/7/2019
817/2019
1.20
PROD1
WHPST
CIRC
P
RIH wl 17.3K, dry tag TOW at 3536',
3,470.0
3,500.0
08:12
09:24
34K PU and circulate well with
seawater to TT, swap to 8.6 ppg
Duovis, w/ 6% KCL, 1.5% Clayslop,
1 % L776, New mud all the way
around, divert flow to shakers, close
DHCV.
8/7/2019
817/2019
2.20
PROD1
WHPST
MILL
P
Bring PR up to 2.7 bpm, 1944 psi CP,
3,535.7
3,537.5
09:24
11:36
60 psi WHP, 1825 psi AP, 400 psi DP,
RIH at 15 FPM, 14.7K, tag at 3535.7',
Begin milling in Autodrill at 1 FPH
8/7/2019
8/7/2019
4.90
PROD1
WHPST
MILL
P
Continue milling window a12.7 bpm,
3,537.5
3,542.0
11:36
16:30
2143 psi CP, 62 psi WHP, 1823 psi AP,
657 psi DP, 4.2K WOB, Mill window to
3542'....
8/7/2019
8/8/2019
7.50
PROD1
WHPST
MILL
P
Crew change, continue milliing
3,542.0
3,541.9
16:30
00:00
forward 2.7 bpm at 2,458 psi,
Dif--488, WHP=67, BHP=1,847,
IA=510, OA=170,
"" Note: Thru the 4-1/2" 3,541.4'@
21:30, ROP slowing down possible
mid point of window exit
8/8/2019
818/2019
3.00
PROW
WHPST
MILL
P
Continue milling ahead from 3,541.9',
3,541.9
3,542.3
00:00
03:00
2.7 bpm at 2,495 psi, Diff-640,
WHP=67, BHP=1,866
8/8/2019
8/8/2019
2.00
PROD1
WHPST
MILL
P
Continue milling ahead, 2.7 bpm at
3,542.3
3,543.4
03:00
05:00
2,514 psi, Diff-620, WHP=66,
BHP=1,668
8/8/2019
8/8/2019
1.30
PROD1
WHPST
REAM
P
PUH, and perform reaming pass @ 60
3,542.7
3,485.0
05:00
06:18
fph/as milled TF, dry drift was clean,
saw slight overpull at X-nipple
818/2019
8/812019
0.70
PROD1
WHPST
TRIP
P
Pump 5x5 sweep, recip pipe until
3,485.0
57.2
06:18
07:00
sweep is out, chase sweep OOH.
8/8/2019
8/8/2019
0.50
PROD1
WHPST
OWFF
P
At surface, observe well for 30 min, no
57.2
0.0
07:00
07:30
flow observed
8/8/2019
818/2019
1.00
PROD1
WHPST
PULD
P
Pull BHA#2, gauged mill and string
0.0
0.0
07:30
08:30
reamer, both under gauged at 3.76"
NO-GO. MU torque on new mill and
reamer was 2800 ft-lbs. Surface test
AnTech tools,
8/8/2019
8/8/2019
2.00
PROD1
WHPST
PULD
P
MU BHA#3 w/ new 3.80" mill and
0.0
0.0
08:30
10:30
string reamer, problem with lower
NRJ, fiberglass sleeve pulled out of
housing.
8/812019
818/2019
1.75
PROD1
WHPST
PULD
T
Pull upper BHA and laydown, change
0.0
0.0
10:30
12:15
lower NRJ. PU1MU BHA#4, re-scribe
motor orienter. Attempt to surface test
upper NRJ, too much EL wire slack,
not able to push slack in the coil. Pull
BHA, Gose swab, monitor WHP
8/8/2019
8/8/2019
1.75
PROD1
WHPST
PULD
T
Cut 6 ft of 7116" ELine, Rehead upper
0.0
0.0
12:15
14:00
NRJ
8/8/2019
818/2019
0.80
PROD1
WHPST
PULD
P
Open swab, PU1MU BHA #4. surface
0.0
57.2
14:00
14:48
test UPR & LWR NRJ, slide injector
over, space out, set depths
Page 2114 Report Printed: 91512019
Uperations Summary (with Timelog Depths)
a
1 R-104
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Lo®
Start Depth
start Time
End Time
Dur (hr)
Phase
Op Code
Activsy Code
Time P -T -X
Operatlon
(N(B)
End DepN (OKE)
8/8/2019
818/2019
0.70
FROM
WHPST
TRIP
P
Trip in hole,
57.2
3,370.0
14:48
15:30
8/8/2019
8/8/2019
0.30
FROM
WHPST
DLOG
P
Log correlation, plus 6 fl correction,
3,370.0
3,433.5
15:30
15:48
35K up, close CV, highside TF
8/8/2019
8/8/2019
3.54
PROD1
WHPST
MILL
P
RIH to mill window, 35K up / 15.7K
3,433.5
3,546.2
15:48
19:20
down, 2.81 bpm, 2210 psi CP, 382 psi
dP, 1850 psi AP. Seeing light motor
work starting 3538'
8/8/2019
818/2019
1.00
FROM
WHPST
MILL
T
Lost comms with Down hole tool,
3,546.2
7546.2
19:20
20:20
perform troubleshooting checklist,
determine failure is down hole, pump
5x5 sweep
8/8/2019
8/8/2019
1.00
FROM
WHPST
TRIP
T
POOH
3,546.2
57.2
20:20
21:20
8/8/2019
8/8/2019
0.50
PROD1
WHPST
PULD
T
At surface, perform flow check (flow)
57.2
57.2
21:20
21:50
PJSM
8/8/2019
818/2019
1.10
FROM
WHPST
PULD
T
PUD milling assembly BHA#4
57.2
0.0
21:50
22:56
troubleshoot issues, test coil a -line
(good), test upper NRJ (not good)
8/8/2019
8/9/2019
1.06
FROM
WHPST
PULD
T
Continue prepping replacment tools,
0.0
0.0
22:56
00:00
while LD milling assembly,
8/9/2019
8/9/2019
1.75
PROD1
WHPST
PULD
T
Continue prepping replacement tool
0.0
0.0
00:00
01:45
8/9/2019
819/2019
1.50
PRODt
WHPST
PULD
T
PU/MU milling assembly BHA #5
0.0
57.2
01:45
03:15
819/2019
8/9/2019
1.00
FROM
WHPST
WAIT
T
Problem with previous milling
57.2
57.2
03:15
04:15
run,AnTech discovered MWD internal
offset was incorrect, window milled
90° LOHS (0° Planned orientation).
Phoned town team, discuss plan
forward. Plan to set second back up
HEW.
8/9/2019
8/9/2019
2.25
PROD1
WHPST
WAIT
T
LD milling BHA#5, Finalize plan
57.2
0.0
04:15
06:30
forward with town team, make call for
Slikline unit.
819/2019
8/9/2019
2.50
PROD1
WHPST
SLKL
T
Wait on HES Slickline
0.0
0.0
06:30
09:00
8/9/2019
8/9/2019
3.00
PROD1
WHPST
SLKL
T
MIRU SLU 764, bring tools to dg floor,
0.0
0.0
09:00
12:00
orientation and PJSM.
8/9/2019
8/912019
2.50
PROD1
WHPST
SLKL
T
Ran 3.77" gauge ring, FB brush, SD in
0.0
0.0
12:00
14:30
GLM at 2487' SLM (2991' RKB), saw
X -Nipple at 3518' SLM (3523' RKB), to
3524' SLM (did not tag). POOH, Ran
3.81" OD x 1.6'X -Lock, set lock at
3523' RKB, POOH, Ran check set w/
3116" brass. Check set came back
sheared (good set)
8/9/2019
81912019
1.00
PROM
WHPST
SLKL
T
PJSM, RD SLU 764, ---(Call BOT to
0.0
0.0
14:30
15:30
hotshot a a XO from 1-1/2" MT pin to
2-3/8" PAC box)***
8/9/2019
8/9/2019
1.00
PRODi
WHPST
WAIT
T
Wait on BOT to bring XO
0.0
0.0
15:30
16:30
8/9/2019
8/9/2019
1.50
FROM
RPEQPT
PULD
T
PU NS Wedge, setting tool, MU BHA
0.0
3,300.0
16:30
18:00
#6
8/9/2019
8/9/2019
1.30
PRODt
RPEQPT
DLOG
_-F_
Log formation for depth control (+3.0'),
3,300.0
3,460.0
18:00
19:18
PUW 31 k
6/9/2019
8/9/2019
0.20
PROM
RPEQPT
TRIP
T
Continue IH
3,460.0
3,526.4
19:18
19:30
8/9/2019
8/9/2019
0.30
PROD1
RPEQPT
TRIP
T
Tag up with 0.8 k OHWOB, oriented
3,526.4
3,526.4
19:30
19:48
HIS, bring pump online establish
returns, shut down dg pump, function
closed CV bring pump up to shear @
3,427 psi 9.4 k DHWOB
Page 3114 Report Printed: 915/2019
operations Summary (with Timelog [Depths)
1 R-104
Rg:
NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Nne I End Time Dur(hr) Phase Op Code Ace yCode TIM P -T -X Operation (WS) End Depth(ftn)
8/9/2019 8/9/2019 0.75 PROD1 RPEQPT TRIP T POOH 3,526.4 60.1
19:48 20:33
8/9/2019
8/9/2019
0.50
PROD1
RPEQPT
PULD
T
At surface, check well for flow
60.1
60.1
20:33
21:03
8/9/2019
8/9/2019
0.80
PROD1
RPEQPT
PULD
T
LD Setting tools
60.1
0.0
21:03
21:51
8/9/2019
8/9/2019
0.75
PROD1
WHPST
CTOP
T
Swap out lower NRJ
0.0
0.0
21:51
22:36
8/9/2019
8/10/2019
1.40
PRODi
WHPST
PULD
T
-F5-U-/MU Milling Assembly BHA #7
0.0
0.0
22:36
00:00
8/10/2019
8/10/2019
0.40
PRODi
WHPST
PULD
T
Continue stabbbing NRJ
0.0
57.6
00:00
00:24
8/10/2019
8/10/2019
1.00
PROW
WHPST
TRIP
T
Tag up reset counters RIH with Milling
57.6
3,300.0
00:24
01:24
Assembly BHA#7
8/10/2019
8/10/2019
0.30
PROD1
WHPST
DLOG
T
Log formation for depth control plus
3,300.0
3,431.5
01:24
01:42
4.0'
8/10/2019
8/10/2019
2.00
PROD1
WHPST
MILL
T
Bring pump online, 2.7 bpm at 2,137
3,511.5
3,512.8
01:42
03:42
psi, Diff -305, WHP=59, BHP=1,858,
IA=O, OA=123
8/1012019
8/10/2019
0.50
PROD1
WHPST
TRIP
T
Continue IH, dry tag pinch point @
3,431.5
3,511.5
03:42
04:12
3511.5', PUW 31 k
8/10/2019
8/10/2019
1.80
PRODi
WHPST
MILL
T
Milling Ahead 2.7 bpm at 2,359 psi,
3,512.8
3,513.3
04:12
06:00
Di"- 84, WHP=60, BHP=1,852, IA=O,
OA=142, CTSW=11.5 k, DHWOB=4.6
k
8/1012019
8110/2019
11.00
PR0D1
WHPST
MILL
T
Crew change, continue auto milling
3,513.3
3,518.5
06:00
17:00
ahead, 2.7 bpm, 2336 psi, 603 psi diff,
60 psi WHIP, staying under 5K WOB.
At 3518.5, let WOB & DP mill off.
8110/2019
8/10/2019
0.50
PROD1
WHPST
REAM
T
Ream window area clean, dry drift to
3,518.5
3,518.5
17:00
17:30
1
ITID 3,518.5'
8/10/2019
811012019
0.50
PRODt
WHPST
TRIP
T
POOH
3,516.5
59.2
17:30
18:00
8/10/2019
8/10/2019
0.50
PRODi
WHPST
OWFF
T
Check well for flow (no -flow), PJSM
59.2
59.2
18:00
18:30
8110/2019
8/10/2019
1.00
PROD1
WHPST
PULD
T
LD milling assembly BHA #7
59.2
0.0
18:30
19:30
8/10/2019
8/1012019
0.80
PROD1
WHPST
CTOP
T
Replace lower NRJ, bend previous
0.0
0.0
19:30
20:18
motor from 0.6°ako to 1.0° ako, torque
up BHI FVS and milling pup
8/10/2019
8/10/2019
0.80
PROD?
WHPST
PULD
T
PU/MU milling assembly BHA#8
0.0
57.2
20:18
21:06
w/1.0° ako motor, inspect pac-off and
change out.
8/10/2019
8/1012019
0.30
PRODt
WHPST
PULD
T
Stab coil, surface test BHA (good),
57.2
57.2
21:06
21:24
stab INJH, tag up, reset counter
depths
8/10/2019
8/10/2019
0.80
PROD1
WHPST
TRIP
T
RIH
57.2
3,300.0
21:24
22:12
8/10/2019
8/10/2019
0.30
PRODt
WHPST
DLOG
T
Log fortnalion for depth control (+2.0")
3,300.0
3,423.5
22:12
22:30
8/10/2019
8/10/2019
0.30
PROD1
WHPST
TRIP
T
Continue IH
3,517.5
22:30
22:48
811012019
8110/2019
0.20
PROD1
WHPST
TRIP
T
Dry tag @ 3,517.5', PUH 35 k, obtain
3,517.5
22:48
23:00
parameters
8/1012019
8/11/2019
1.00
PROD1
WHPST
MILL
T
Milling ahead 2.74 bpm at 2,138 psi,
r3,517.5
3,517.8
23:00
00:00
Diff -364, WHP=60. BHP=1,808, ]A=O,
OA=154
8111/2019
8/11/2019
2.00
PROD1
WHPST
MILL
T
Milling Ahead, 2.72 bpm at 2,353 psi,
3,518.4
00:00
02:00
Diff=596, WHP=63, BHP=1,800,
IA=144, OA=177
Page 4114 ReportPrinted: 91512019
operations Summary (with Timelog Depths)
W
1R-104
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
our nn
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth rtKB)
6/11/2019
8/11/2019
WHPST
MILL
T
Milling Ahead, 2.72 bpm at 2,328 psi.
3,518.4
3,518.6
02:00
04:00
Diff-577, WHP=63, BHP=1,814,
IA= 169, OA= 179
8/11/2019
8/11/2019
WHPST
MILL
T
Milling Ahead, 2.71 bpm at 2,306 psi,
3,518.6
3,518.8
04:00
06:00
#40
Diff=531, WHP=62, BHP=1,807,
IA=241, OA=185
8/11/2019
8/11/2019
WHPST
MILL
P
Milling Ahead, 2.70 bpm at 2,430 psi,
3,518.8
3,519.0
0600
11:24
Diff=581, WHP=63, BHP=1,819 psi,
ROP has dropped to zero for the past
2 hours, Decision to pull BHA to look
at mill.
8/11/2019
8/11/2019
0.60
PROD1
WHPST
TRIP
T
POOH, PUW=35K
3,519.0
82.3
11:24
12:00
8/11/2019
8/11/2019
0.50
PROD1
WHPST
OWFF
T
30 min Flow check
82.3
82.3
1200
12:30
8/11/2019
8/11/2019
1.25
PROD1
WHPST
PULD
T
Stripped up, inspect gouge mark on
64.2
0.0
1230
13.45
coil 20' up from BHA, mark is not
fresh, Pull BHA#8, inspect mills, Mill=
3.80, Reamer- 3.80" NO-GO. Center
of mill was starting to core out. Inspect
PO's (good), cleaned brass.
8/11/2019
8/11/2019
1.30
PRODi
WHPST
PULD
T
PU/MU milling assembly BHA#9, re-
0.0
57.3
1345
15:03
run 1.0° ako motor, with new mill,
3.80" Baker large carat, re-run NS
string reamer, test UPR NRJ (good),
test LWR NRJ (good)
8/11/2019
8/11/2019
0.95
PROD1
WHPST
TRIP
T
Stab coil, surface test BHA (bad),
57.3
57.3
15:03
16:00
troubleshoot resistance readings,
found no problem stab INJH, tag up,
reset counter depths, RI
8/11/2019
8/11/2019
0.30
PROD1
WHPST
DLOG
T
Log formation for depth control plus
3,330.0
3,450.0
16:00
16:18
1
6.0'
8/11/2019
8/11/2019
2.00
PROD1
WHPST
MILL
P
Milling Ahead, 2.80 bpm at 2,450 psi,
3,519.0
3,521.6
1618
18:18
Diff=340 psi, WHP=62, BHP=1,830,
IA=O, OA=164,
8/11/2019
8/11/2019
0.40
PROD1
WHPST
MILL
P
Milling ahead 2.8 bpm at 2,238 psi.
3,521.6
3,522.2
1818
18:42
Diff--523, WHP=63, BHP=1,832,
IA= 170, OA=193
8/11/2019
8/11/2019
1.50
PROD1
WHPST
MILL
P
Drill ahead rat hole, 20 fph, 2.8 bpm at
3,522 2
3,540.0
1842
20:12
2,261, Dlff=305, WHP=63,
BHP=1,832, IA=171, OA=193
8/11/2019
8/11/2019
2.20
PROD1
WHPST
REAM
P
TO Rat hole, PUH 30 k, Ream window
3,540.0
3,540.0
2012
22:24
area as milled TF, 30° LOHS, 30'
ROHS, and 180° from milled TF,
launch 5x5 sweep
8/11/2019
8/11/2019
0.75
PROD1
WHPST
TRIP
P
POOH
3,540.0
57.2
2224
23:09
8/11/2019
8/12/2019
0.85
PROD?
WHPST
PULD
P
At surface, spaceout, PUD milling
57.2
57.2
23:09
00:00
1
assembly
8/12/2019
8/12/2019
1.50
PROD1
WHPST
PULD
P
Continue LD Milling assembly, Flush
57.2
0.0
00:00
01:30
1
BHI Mud Motor
8/12/2019
8/12/2019
1.00
PROD1
WHPST
PULD
P
Slide cart forward, MU Nozzle, stab
0.0
0.0
01:30
02:30
INJH, jet BOPE and surface lines
clean, Unstab INJH, brake off Nozzle,
inspect Upper NRJ (no-good)
8/12/2019
8/12/2019
2.50
PROW
WHPST
PULD
T
Remove flow-sub, a-line moved
0.0
0.0
0230
05:00
forward and hands were unable to
push back in, cut a-line and rehead
upper quick, test a-line and upper
quick (good-test)
Page 5114 Report Printed: 9/5/2019
Uperations Summary (with Timelog Depths)
1 R-104
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
start Tme
EM Time
our(hn
Phase
Op Code
Activity Code
Time P -T -X
Operation
(flKB)
End Depth(WS)
8/12/2019
8/12/2019
3.50
PROD1
DRILL
PULD
T
PU/PD Build Section BHA#10, slide
0.0
53.7
05:00
08:30
inject forward, test LWR NRJ (good),
test UPR NRJ (bad), Remove flow
sub, AnTech troubleshooting UPR
NRJ, #5 wire is reading low resistivity,
Call rig electrician, to double check
AnTech, swap wires #5 w/ ground and
use #2 wire. Test UPR NRJ (good),
MU flow thru sub.
8/12/2019
8/12/2019
0.50
PROD1
DRILL
PULD
T
Stab coil, surface check (good), strip
53.7
53.7
08:30
09:00
down, line up MP, finish PD checklist,
power up tool, lost comms with
everything below release device.
8/12/2019
8/12/2019
1.50
PROD1
DRILL
PULD
T
PUD BHA #10, laydown Antech tools
0.0
0.0
09:00
10:30
8/12/2019
8/12/2019
1.00
PROM
DRILL
PULD
T
Bring another Antech BHA into pipe
0.0
0.0
10:30
11:30
shed, CoMan witnessed CV function
test, high side and roll test.
8/12/2019
8/12/2019
1.00
PROM
DRILL
PULD
T
PU/PD Build Section BHA # 11 (Orion
0.0
53.6
11:30
12:31
1
1
1 run #10)
8/12/2019
8/12/2019
0.50
PROD1
DRILL
PULD
T
Slide injector forward, stab coil and
53.6
53.6
12:30
13:00
surface test (good), tag up reset
counters
8/12/2019
8/12/2019
0.70
PROD1
DRILL
TRIP
P
RIH, pumped managed pressure.
53.6
3,350.0
13:00
13:42
8/12/2019
8/12/2019
0.40
PROD1
DRILL
DLOG
P
Log formation for depth control, repeat
3,350.0
3,432.0
13:42
14:06
correlation pass, DO was moving TF
during tie-in pass, zero feel correction,
close CV.
8/12/2019
8/12/2019
0.20
PROD1
DRILL
TRIP
P
RIH to drill build section, 14.6K, 2.8
3,432.0
3,543.0
14:06
14:18
bpm at 2500 psi, Dif(=485 psi,
WHP=60 psi, BHP=1900 psi, IA= 0,
OA= 131
8/12/2019
8/12/2019
1.20
PROD1
DRILL
DRLG
P
OBD at 3543', see WOB and torque,
3,543.0
3,720.0
14:18
15:30
motor stall, PUW= 35K, OBD again,
2.8 bpm at 2700 psi, Diff -700 psi,
WHP=60 psi, BHP=1890 psi,
8/12/2019
8/12/2019
0.60
PROD1
DRILL
WPRT
P
Geo wiper to check survey, pumped
3,720.0
3,720.0
15:30
16:06
5x5, PUW= 35K, wiper uphole 3570'
8/12/2019
8/12/2019
0.50
PROD1
DRILL
DRLG
P
OBD, land build at 3760', TVD 5'
3,720.0
3,760.0
16:06
16:36
higher than plan, 87° dev
8/12/2019
8/12/2019
0.40
PROD1
DRILL
TRIP
P
Wiper uphole, chase 5x5,
3,760.0
3,338.0
16:36
17:00
8/12/2019
8/12/2019
1.00
PROD1
DRILL
DLOG
P
Log formation -1.5' correction, log
3,338.0
3,600.0
17:00
18:00
across RAtag at 3512.6'.
8/12/2019
8/12/2019
0.70
PROD1
DRILL
TRIP
P
POOH, bump up, line up to pump MP,
3,600.0
54.5
18:00
18:42
WHP= 180 psi
8/12/2019
8/12/2019
2.00
PROD1
DRILL
PULD
P
PJSM, PUD BHA #11. LD lower BHA.
54.5
0.0
18:42
20:42
8/12/2019
8/12/2019
0.30
PROD1
DRILL
CTOP
P
Performed bi-weekly function test
0.0
0.0
20:42
21:00
8/12/2019
8/12/2019
1.00
PROD1
DRILL
PULD
P
MU Lateral Assembly and stage into
0.0
0.0
21:00
22:00
PDL
8/12/2019
8/12/2019
1.50
PROD1
DRILL
PULD
T
Inspect NRJ/Flow-sub (no-good),
0.0
0.0
22:00
23:30
brake apart and replace Upper NRJ
8/12/2019
8/13/2019
0.50
PROD1
DRILL
PULD
P
Continue PD Lateral Assembly BHA
0.0
57.9
23:30
00:00
#12
8/13/2019
8/13/2019
0.75
PROM
DRILL
PULD
P
Continue PD Lateral Assembly BHA
57.9
57.9
00:00
00:45
#12, perform surface test (good)
8/13/2019
8/13/2019
0.20
PROD1
DRILL
TRIP
P
Tag up, reset counters, function closed
57.9
57.9
00:45
00:57
CV, surface test agitiator.
Page 6114 Report Printed: 915/2019
Operations Summary (with Timelog Depths)
1 R-104
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Steri Time
End Time
Our (hr)
Phase
Op Code
Activhy Code
Time P -T -X
Operation
(MB)
End Deptli(WEI)
8/13/2019
8/13/2019
0.80
PRODt
DRILL
TRIP
P
RIH w/BHA #12 0.6° ako motor
57.9
3,515.0
00:57
01:45
8/13/2019
8/13/2019
0.30
PRODi
DRILL
DLOG
P
Log the RA marker (-1.0') PUW 30 k
3,515.0
3,556.0
01:45
02:03
8/13/2019
8/13/2019
0.20
PRODi
DRILL
TRIP
P
Continue IH
3,556.0
3,760.0
02:03
02:15
8/13/2019
8/13/2019
0.15
PRODi
DRILL
DRUG
P
OBD, 2.8 bpm at 2,941 psi, Diff -1,100,
3,760.0
3,769.2
0215
02:24
WHP=106, BHP=2,023, IA=O,
OA=139
8/13/2019
8/13/2019
0.15
PROD1
DRILL
WPRT
P
PUH and obtain pump paramaters,
3,769.2
3,769.2
02:24
02:33
PUW 28 k
8/13/2019
8/13/2019
0.30
PRODi
DRILL
DRLG
P
BOBD, 2.8 bpm at 3,008 psi,
3,769.2
3,856.0
02:33
02:51
Diff=1,181 psi, WHP=107,
BHP=2,003, IA=O, OA=139
*'.• Note: New mud to bit @ 3,769'
8/13/2019
8/13/2019
0.15
PRODt
DRILL
WPRT
P
PUH, PUW 36 k, resent
3,856.0
3,856.0
0251
03:00
8/13/2019
8/13/2019
0.60
PRODt
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,815 psi,
3,856.0
4,062.0
03:00
03:36
Diff --1,074, WHP=91, BHP=1,953,
IA=O, OA=143, drilled 52'@ 400' fph,
unable to build, PUH 36 k
8/13/2019
8/13/2019
0.75
PROD1
DRILL
WPRT
T
PUH, conferred with Town Team and
4,062.0
4,062.0
03:36
04:21
Loral GEO, decision was made to pull
for correction BHA
8/13/2019
8/13/2019
0.30
PROD1
DRILL
WPRT
T
Launch 5x5 sweep, PUH above
4,062.0
3,485.0
04:21
04:39
window, perform jog, function opened
Cv.
8/13/2019
8/13/2019
0.75
PROD1
DRILL
TRIP
T
POOH
3,485.0
57.9
04:39
05:24
8/13/2019
8/13/2019
1.50
PRODt
DRILL
PULD
T
At surface, PUD lateral assembly BHA
57.9
0.0
05:24
06:54
1#12
8/13/2019
8/13/2019
1.50
PRODt
DRILL
PULD
T
LD and scribe motor to 1.0`
0.0
0.0
06:54
08.24
8/13/2019
8/13/2019
1.50
PROD1
DRILL
PULD
T
PD, Lateral Assembly BHA#13, MU to
0.0
57.9
08:24
09:54
coil perform surface test (good -test)
8/13/2019
8/13/2019
0.20
PRODi
DRILL
TRIP
T
Stab INJH, tag up, reset counters, RIH
57.9
500.0
09:54
10.06
8/13/2019
8/13/2019
0.15
PROD1
DRILL
TRIP
T
Surface lest agitator, 2.8 bpm at 1,126
500.0
500.0
10:06
10:15
psi, Diff=680
8/13/2019
8/13/2019
0.50
PROD1
DRILL
TRIP
T
Continue IH, BHA#13 w/1.0" ako
500.0
3,525.0
10:15
10:45
motor
8/13/2019
8/13/2019
0.20
PROD1
DRILL
DLOG
T
Log the RA marker (-1.0')
3,525.0
3,548.0
10:45
10:57
8/13/2019
8113/2019
0.20
PRODt
DRILL
TRIP
T
Continue IH
3,548.0
4,062.0
10:57
11:09
8/13/2019
8113/2019
1.00
PRODi
DRILL
DRUG
P
OBD. 2.8 bpm at 2,533 psi, Diff=930,
4,062.0
4,271.0
11:09
12:09
WHP=61, BHP=1,862, IA=O, OA=132,
8/13/2019
8/13/2019
0.50
PRODi
DRILL
DLOG
P
Perform MADD pass up hole,
4,271.0
4,050.0
12:09
12:39
8/13/2019
8/13/2019
0.80
PROD1
DRILL
WPRT
P
PUH, perform wiper up hole, confer
4,050.0
4,050.0
12:39
13:27
with town team, PUW 36 k
8/13/2019
8113/2019
0.80
PROD1
DRILL
TRIP
P
POOH
4,050.0
57.9
13:27
14:15
8/13/2019
8113/2019
1.40
PROD1
DRILL
PULD
P
PUD Lateral Drilling Assembly
57.9
0.0
14:15
15:39
8/13/2019
8/13/21119
0.50
PRODi
DRILL
PULD
P
Adjust and scribe Mud Motor
0.0
0.0
15:39
16:09
8/13/2019
8/13/2019
1.50
PROD?
DRILL
PULD
P
PD Lateral Drilling Assembly BHA #14.
0.0
57.9
16:09
17:39
With .8° AKO motor
8/13/2019
8/13/2019
1.00
PROD1
DRILL
TRIP
P
Trip in well,
57.9
3,540.0
17:39
18:39
Page 7114 ReportPrinted: 91512019
Operations Summary (with Timelog Depths)
1R-104
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Depth
Start Time
End Time
Our (hr)
Phase
Op Code
AcEviy Code
Time P -T-%
Operation
(ftKB)
End Depth (W)
8/13/2019
8/13/2019
0.10
PROD1
DRILL
DLOG
P
3450'. Log RA for foot correction
3,540.0
3,600.0
18:39
18:45
8/13/2019
8/13/2019
0.20
PROD1
TRIP
P
Continue in hole
3,600.0
4,271.0
18:45
18:57
8/13/2019
8/13/2019
0.50
PROD1
DRLG
P
4271', Drill. 2.8 BPM @ 2725 PSI,
4,271.0
4,418.0
18:57
19:27
Diff --1436, BHP=1864
8/13/2019
8/13/2019
0.10
PROD1
EDR
WPRT
P
Pull BHA wiper, PUW=30K
4,418.0
4,418.0
19:27
19:33
8/13/2019
8/13/2019
1.50
PROD1
DRLG
P
4418', Drill, 2.8 BPM @ 3250,
4,418.0
4,671.0
19:33
21:03
Diff --1295, BHP=1955
6/13/2019
8/13/2019
0.50
PROD1
WPRT
P
4671', Wiper trip #1800'
4,671.0
4,671.0
21:03
21:33
8113/2019
8/13/2019
0.50
PRODi
DRILL
DRLG
P
4671', Drill, 2.8 BPM @ 3250 PSI,
4,671.0
4,711.0
21:33
22:03
Dirr=1295, BHP=1950
8/13/2019
8/13/2019
1.45
PROD1
DRILL
TRIP
T
Lost comms with tools.Pump 5 X 5
4,711.0
61.0
22:03
23:30
sweeps Trip out. PUW=32K
8/1312019
8/1412019
0.50
PROW
DRILL
PULD
T
At surface, PJSM. PUD BHA#14.
61.0
0.0
23:30
00:00
Plug into tool at surface. Tool values
out of spec. Does not appear to be E -
Line problem
8/14/2019
8/14/2019
1.00
PROD1
DRILL
PULD
T
At surface, Trouble shoot / Change out
0.0
0.0
00:00
01:00
BHA
8/14/2019
8114/2019
1.50
PROD1
DRILL
PULD
T
Service Upper NRJ
0.0
0.0
01:00
02:30
6/14/2019
8/14/2019
2.00
PROD7
DRILL
PULD
T
PJSM, PD BHA #15 with -.Vmotor motor
0.0
57.9
02:30
04:30
and RR Hycalog bi center, Make up to
coil and surface test
8/14/2019
8/14/2019
0.75
PROD1
DRILL
TRIP
T
Trip in hole, BHA #15. Stop @ 500'.
57.9
3,525.0
04:30
05:15
Close circ valve. Shallow test agitator
2.8 BPM @ 2630 PSI Pump pressure,
Continue in well.
6/14/2019
8/14/2019
0.20
PROD1
DRILL
DLOG
T
Log the RA Marker (-1.5')
3,525.0
3,600.0
05:15
05:27
8/14/2019
6/14/2019
0.20
PROD1
DRILL
TRIP
T
Continue IH
3,600.0
4,711.0
05:27
05:39
8/14/2019
8/14/2019
3.00
PRODt
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,850 psi,
4,711.0
5,115.0
05:39
08:39
Diff=840, WHP=63, BHP=1,899, IA=O,
OA=159
- Note: Trouble getting survey's
GeoMagnetism Storms inference,
Work to obtain suveys.
8/14/2019
8/14/2019
0.30
PRODt
DRILL
WPRT
P
Wiper up hole, PUW 33 k
5,115.0
4,115.0
08:39
08:57
8/14/2019
8/14/2019
0.30
PROD1
DRILL
WPRT
P
Wiper back in hole, RIW 13.7 k
4,115.0
5,115.0
08:57
09:15
8114/2019
8/14/2019
2.50
PROD1
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,770 psi, Diff -951,
5,115.0
5,515.0
09:15
11:45
WHP=54, BHP=1,941, IA=O,OA=162
8/14/2019
8/14/2019
0.30
PRODt
DRILL
WPRT
P
Wiper up hole, PUW 36 k
5,515.0
4,715.0
11:45
12:03
8/14/2019
8/14/2019
0.30
PROD1
DRILL
P
Wiper back in hole, RIW
4,715.0
5,515.0
12:03
12:21
8/14/2019
8/14/2019
2.00
PROD1
DRILL
P
BOBD, 2.8 bpm at 2,770 psi, Diff --951,
5,515.0
5,935.0
1221
14:21
WHP=54, BHP=1,941, IA=O,OA=162
8/14/2019
8/14/2019
1.00
PROW
DRILL
P
Wiper up hole to the window, PUW 35
5,935.0
3,525.0
14:21
15:21
FWPRI
k
8/14/2019
8/1412019
0.30
PROD1
DRILL
P
Log the RA (+2.51)
3,525.0
3,563.0
15:21
15:39
6/14/2019
8/14/2019
1.00
PRODt
DRILL
P
Wiper back in hole, RIW 14.7 k
3,563.0
5,935.0
15:39
16:39
Page 8114 Report Printed: 91512019
Operations Summary (with Timelog Depths)
1 R-104
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(Win
End Depth (W)
8!14/2019
8/14/2019
2.20
PROD1
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,770 psi, Diff=951,
5,935.0
6,180.0
16:39
18:51
WHP=54, BHP=1,941, IA=O,OA=162.
Tool not steering corectly. Toolface
inadvertantly shifted into gravity mode.
Problem idenified and corrected.
Inclination down to 81.83° 10' below
plan. Able to tum up and build angle
right away
8/14/2019
8/14/2019
0.40
PROD1
DRILL
WPRT
P
6180', wiper trip to 6050', PUW=31K
6,180.0
6,180.0
18:51
19:15
8/14/2019
8/14/2019
0.65
PROW
DRILL
DRLG
P
6180', l, 2.8 BPM @ 3358,
Dril
6,180.0
6,340.0
19:15
19:54
Diff=1415, BHP=1943
8/14/2019
8/14/2019
0.70
PROD1
DRILL
WPRT
P
6340', Pull 800'wiper trip,PUW=35K
6,340.0
6,340.0
19:54
20:36
8/14/2019
8/14/2019
1.70
PROD1
DRILL
DRLG
P
6340', Drill, 2.8 BPM @ 3174 PSI,
6,340.0
6,749.0
20:36
22:18
Diff --1237, BHP=1937
8/14/2019
8/14/2019
0.60
PRODt
DRILL
WPRT
P
6749', 800' wiper, PUW=36K
6,749.0
6,749.0
22:18
22:54
8/14/2019
8/15/2019
1.10
PROW
DRILL
DRLG
P
6749', Drill 2.8 BPM @ 3232PSI,
6,749.0
6,991.0
22:54
00:00
Diff -1258, BHP=1928. Midnight depth
6991
8/15/2019
8/15/2019
1.30
PROD1
DRILL
DRLG
P
6991', Drill 2.8 BPM @ 3232PSI,
6,991.0
7,034.0
00:00
01:18
1
Diff --1258, BHP=1928
8/15/2019
8/15/2019
1.60
PROD1
DRILL
WPRT
P
Wiper trip to window with tie in,
7,034.0
7,000.0
01:18
02:54
PUW=35K, Tie in for+2'. RBIH. Well
started unloading clay ball just aftr
starting in. Out density to 10.3 PPG.
Micro motion plugging o0. Bypass and
clear.
8/15/2019
8/15/2019
0.60
PROD1
DRILL
DRLG
P
7032', Bring on pumps get set up to
7,000.0
7,030.0
02:54
03:30
drill. Unable to orient. Trouble shoot
surface equipment
8/15/2019
8/15/2019
1.75
PROD1
DRILL
TRIP
T
Unable to get tool to orient. Trip out of
7,030.0
57.9
03:30
05:15
hole, PUW=33K, Saw negative
DHWOB of -2.5K @ 3660. Not a big
overpull. Paint EDP flag @ 3357'
8/1512019
8/15/2019
1.30
PRODi
DRILL
PULD
T
At surface, tag up, spaoi PUD
57.9
0.0
05:15
06:33
drilling assembly BHA #16
8/15/2019
8/15/2019
2.40
PROD1
DRILL
PULD
T
ick
LD tool and prep new tool to be ped
0.0
0.0
06:33
08:57
up.
8/15/2019
8/15/2019
1.50
PRODt
DRILL
PULD
T
PD drilling assembly BHA #16
0.0
57.2
08:57
10:27
8/15/2019
8/15/2019
0.45
PROD1
DRILL
PULD
T
Preform surface test (not -good), swap
57.2
57.2
10:27
10:54
out lower NRJ
6/15/2019
8/15/2019
1.30
PROD?
DRILL
PULD
T
Finish PD Lateral Drilling BHA916,
57.2
57.2
10:54
12:12
perform surface test (no-good)
8/15/2019
8/15/2019
1.20
PROD1
DRILL
PULD
T
Break off and inspect NRJ, Test Lower
57.2
57.2
12:12
13:24
NRJ and tools (good -test), test upper
NRJ (not -good), break apart upper
NRJ, clean all 8 boots and re -test (not -
good)
8/15/2019
8/15/2019
1.50
PROD1
DRILL
PULD
T
PUD, failed BHA#16
57.2
0.0
13:24
14:54
8/15/2019
8/15/2019
1.30
PROD1
DRILL
CTOP
T
Send tools out to the AnTech shop,
0.0
0.0
14:54
16:12
1 continue testing replacement tools
8/15/2019
8/15/2019
1.40
PROD1
DRILL
PULD
T
PJSM, PD Lateral Drilling Assembly
0.0
57.2
16:12
17:36
BHA#16
8/15/2019
8/15/2019
1.00
PR0D1
DRILLTRIP
T
Tag up, re -set counters, RIH w/BHA
57.2
3,450.0
17:36
18:36
#16, 0.8° ako motor and RR bi-center
bit
019
8/15/2019
0.10
PRUU1
DRILL
DLOG
T
Log RA marker for -1.5'
3,450.0
3,550.0
18:36
18:36
18:42
Page 9114 Report Printed: 91512019
Operations Summary (with Timelog Depths)
a
1 R-104
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code AMity Code Time P -T -X Operation MM) End Deph(rtKB)
8/15/2019 1811512019
1.30
PRODI
DRILL
TRIP
T
Continue in hole
3,550.0
7,034.0
18:42
20:00
8/15/2019
8/15/2019
2.20
PRODI
DRILL
DRLG
P
7034', Drill, 2.8 BPM @ 3174 PSI,
7,034.0
7,434.0
20:00
22:12
Diff=1207, BHP=1967
8/15/2019
8/15/2019
0.70
PROD1
DRILL
WPRT
P
7434', Pull 800 -wiper. PUW=39K
7,434.0
7,434.0
22:12
22:54
8/15/2019
8/16/2019
1.10
PROD?
DRILL
DRLG
P
7434', Drill, 2.8 BPM @ 3129 PSI,
7,434.0
7,710.0
22:54
00:00
Diff=1136, BHP=1993
8116/2019
8116/2019
0.60
PROD1
DRILL
DRLG
P
7770', Drill, 2.8 BPM 3129 PSI,
7,710.0
7,834.0
00:00
00:36
Diff=1136, BHP=1993
8/16/2019
8/16/2019
0.60
PROD1
DRILL
WPRT
P
7836', Pull 800'wiper, PUW=41K
7,834.0
7,834.0
00:36
01:12
8/16/2019
8/16/2019
0.40
PROD1
DRILL
DRLG
P
7834', Dri112.8 BPM @ 3300 PSI,
7,834.0
7,897.0
01:12
01:36
Diff --1298, BHP=2002
8/16/2019
8/16/2019
1.60
PRODI
DRILL
WPRT
T
Unable to get clean surveys, Check
7,897.0
7,500.0
01:36
03:12
forecasted solar activity - moderate.
PUH haveing problems gelling clean
check shots. Reduce pump rate.
Antech consulting their engineers.
PUH slowly
8/16/2019
8/1612019
0.40
PRODI
DRILL
WPRT
T
Pull to cased hole while plugginh into
7,500.0
5,550.0
03:12
03:36
back up tool to evakuate possible
problems with solar activity. Antech
own showing heighten solor activity
8116/2019
1811612019
0.50
PRODI
DRILL
WPRT
T
Solor activity subsiding, surveys
5,550.0
7,897.0
03:36
04:06
cleaning up. Tool on surface reacting
like tool in well. RBIH to survey I Drill
8/16/2019
8/16/2019
0.60
PROD1DRILL
DRLG
P
7897'. Drill, 2.75 BPM @ 3090 PSI,
7,897.0
8,034.0
04:06
04:42
Diff -1430, BHP=1986
8/16/2019
8/16/2019
0.10
PRODI
DRILL
WPRT
P
BHA wiper, get surveys, PUW=43k
8,034.0
8,034.0
04:42
04:48
8/16/2019
8/16/2019
0.90
PRODI
DRILL
DRLG
P
8034', Drill, 2.75 BPM @ 2986 PSIm
8,034.0
8,234.0
04:48
05:42
Diff -1451, BHP=2009, perform jog
3800-4450'
8/16/2019
8/1612019
1.60
PROD1
DRILL
WPRT
P
Wiper to the window, PUW
8,234.0
3,525.0
05:42
07:18
8116/2019
8116/2019
0.30
PROD1
DRILL
DLOG
P
Log the RA marker (+4.0'), lots of clay
3,525.0
3,563.0
07:18
07:36
across the shaker.
8/16/2019
8/16/2019
0.45
PROD1
DRILL
WPRT
P
Wiper back in hole to 3,800', RIW 12.2
3,563.0
3,800.0
07:36
08:03
It
8/16/2019
8/76/2019
0.85
PROD1
DRILL
DLOG
P
Perform MADD pass 3,800'-3,524'
3,800.0
3,524.0
08:03
08:54
8116/2019
8116/2019
1.50
PROD1
DRILL
WPRT
P
Wiper back in hole, RIW 12.2 k
3,524.0
8,234.0
08:54
10:24
8!1612019
8/16/2019
2.00
PRODI
DRILL
DRLG
P
BOBD, 2.8 bpm a0,247 psi, Diff --900,
8,234.0
8,634.0
10:24
12:24
WHP=39, BHP=1,988, IA=O, OA=164
8/1612019
8/16/2019
0.50
PROD1
DRILL
WPRT
P
Wiper up hole 800', PUW 37 k
8,634.0
7,834.0
12:24
12:54
8/16/2019
8/16/2019
0.30
PROD1
DRILL
WPRT
P
Wiper back in hole, RM 12.0 k
7,834.0
8,634.0
12:54
13:12
8/16/2019
8/16/2019
1.15
PROM
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,727 psi, Dlff=-997,
8,634.0
8,890.0
13:12
14:21
WHP=95, BHP=1,984, IA=O, OA=162,
surveys dirty, continue drilling ahead
75'
"' Note: New mud at the bit 8,634'
8/16/2019
8/1612019
0.20
PROW
DRILL
WPRT
P
Lost depth reading, PUH slowly
8,890.0
8,830.0
14:21
14:33
trouble shoot, reboot computers, good
to go
8/16/2019
8/16/2019
0.30
PROD1
DRILL
WPRT
P
Continue up hole to perform check
8,830.0
8,890.0
14:33
14:51
1
shots, 8,830' and 8,860'
Page 10114 Report Printed: 91512019
Operations Summary (with Timelog Depths)
Jim,
1R-104
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Achviry Code
Tlma P-T-X
Operation
(Po(B)
EM Depth (ftKB)
8/1612019
0.75
PROM
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,727 psi, DIff=997,
8,690.0
9,050.0
14:51
15:36
WHP=95, BHP=1,984, IA=O, OA=162,
1811612019
175'
surveys dirty, continue drilling ahead
8/16/2019
8/16/2019
0.50
PROD1
DRILL
WPRT
P
Wiper up hole, PUW 37 k
9,050.0
8,050.0
15:36
16:06
8/16/2019
8/16/2019
0.50
PROD1
DRILL
WPRT
P
Wiper back in hole RIW
8,050.0
9,050.0
16:06
16:36
8/16/2019
8/16/2019
1.40
PROD1
DRILL
DRLG
P
9050, Drill, 2.8 BPM @ 3300 PSI,
9,050.0
9,450.0
16:36
18:00
1
Diff-1350, BHP=1950
8/1612019
8/1612019
4.60
PROD1
DRILL
WPRT
P
Wiper to window with tie in,
9,450.0
9,450.0
18:00
22:36
PUW=37K. RA ie in for+5'. No
overpulls in 3700 - 3600' area. No
major increase in cuttings. Out density
not over 9.1
8/16/2019
8/17/2019
1.40
PROD1
DRILL
DRLG
P
9450', Drill, 2.8 BPM @ 3068 PSI,
9,450.0
9,732.0
22:36
00:00
1
Diff--1085, BHP=1983
8/1712019
8117/2019
0.80
PROD1
DRILL
DRLG
P
9732', Drill, 2.8 BPM @ 3068 PSI,
9,732.0
9,850.0
00:00
00:48
Diff--1085, BHP=1983
8/17/2019
8117/2019
0.90
PROD1
DRILL
WPRT
P
9850', Pull 1000'wiper trip
9,850.0
9,850.0
00:48
01:42
8/17/2019
8/17/2019
1.00
PRODt
DRILL
DRLG
P
9850', Drill. 2.8 BPM @ 3023 PSI,
9,850.0
10,001.0
01:42
02:42
Diff=1023, BHP=2000
8/17/2019
8117/2019
0.10
PROD1
DRILL
WPRT
P
10001', Pull BHA wiper, RIW -12
10,001.0
10,001.0
02:42
02:48
8117/2019
8/17/2019
0.80
PROD1
DRILL
DRLG
P
10,001', Drill, 2.8 BPM @ 3079,
10,001.0
10,030.0
02:48
03:36
Diff--1427, BHP=2026. RIW=-12K,
DHWOB=.16K, ROP=65FPH.
8/17/2019
8/1712019
0.40
PROM
DRILL
WPRT
P
Pull BHA Wiper, RIW=-15K. Low ROP,
10,030.0
10,030.0
03:36
04:00
PUW=42K
8/17/2019
8/1712019
0.90
PROD1
DRILL
DRLG
P
10030', Drill, 2.8 BPM @ 3450 PSI,
10,030.0
10,065.0
04:00
04:54
Diff--1439, BHP=2011
8/1712019
8117/2019
0.50
PROD1
DRILL
WPRT
P
Pull 1 000'wiper trip with sweeps,
10,065.0
9,065.0
04:54
05:24
PUW=40K
8/17/2019
8/17/2019
0.30
PROD1
DRILL
WPRT
P
Wiper back in hole, RlW
9,065.0
10,065.0
05:24
05:42
8117/2019
8/17-2019
3.00
PRODt
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,984 psi, DIff-940,
10,065.0
10,193.0
05:42
08:42
WHP=45, BHP=2,050, IA=O, OA=152,
8/17/2019
8117/2019
0.20
PROD1
DRILL
WPRT
P
Wiper up hole 240', PUW 39 k
10,193.0
9,950.0
08:42
08:54
8/17/2019
8/17/2019
0.20
PRODt
DRILL
WPRT
P
Wiper back in hole RIW -11 k
9,950.0
10,193.0
08:54
09:06
8/17/2019
8117/2019
0.30
PROD1
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,984 psi, DIff=900,
10,193.0
10,215.0
09:06
09:24
WHP=43, BHP=2,029, IA=O, OA=154
•" Note: Start sending 10 bbl beaded
pills
8/17/2019
8117/2019
0.20
PROD1
DRILL
WPRT
P
Wiper up hole,PUW 37 k
10,215.0
9,720.0
09:24
09:36
8/1712019
8117/2019
0.20
PRODi
DRILL
WPRT
P
Wiper back in hole, RIW
9,720.0
10,215.0
09:36
09:48
8/1712019
8/17/2019
0.80
PRODt
DRILL
DRLG
P
BOBD, 2.8 bpm a12,984 psi, DItf=940,
10,215.0
10,222.0
09:48
10:36
WHP=45, BHP=2,050, IA=O, OA=152,
811712019
8/17/2019
0.20
PROD1
DRILL
WPRT
P
BHA Wiper up hole, PUW 37 k
10,222.0
10,222.0
10:36
10:48
8/17/2019
8/17/2019
1.80
PROD1
DRILL
DRLG
5
BOBD, 2.8 bpm at 2,984 psi, DIff=940,
10,222.0
10,335.0
10:48
12:36
WHP=45, BHP=2,050, IA=O, OA=152,
8117/2019
8/17/2019
0.20
PRODt
DRILL
WPRT
P
PUH, PUW 40 k to 9,963'
10,335.0
9,963.0
12:36
12:48
8/17/2019
8/1712019
0.20
PROD1
DRILL
WPRT
P
RBIH, TIW -10 k @ 49 fpm
9,963.0
10,335.0
12:48
13:00
Page 11111114 Report Printed: 91512019
Operations Summary (with Timelog Depths)
1 R-104
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Sart Depth
Slap Time
End Time
Dur(hr)
-PROD1
Phase
Op CodeActivity
Code
Time P -T -X
P
Dperehon
BOBD, 2.8 bpm at 2,984 psi, DIff=940,
(11KB)
10,335.0
End DepUt(flKSh
10,455.0
8/17/2019
8/17/2019
2.20
DRILL
DRLG
WHP=45, BHP=2,050, IA=O, OA=152,
13:00
15:12
Average ROP 40 fph
Note: New Mud at the bit 10,449'
8/17/2019
8/17/2019
2.00
PROD?
DRILL
WPRT
P
Wiper up hole, PUW 40 k
10,455.0
3,525.0
15:12
8/17/2019
17:12
8/17/2019
0.20
PROD1
DRILL
DLOG
P
Log the RA Marker, +6.5'
3,525.0
3,569.0
17:12
8/17/2019
17:24
8/17/2019
2.60
TR -0D1
DRILL
WPRT
P
Wiper back in hole, RIW 12.2 k
3,569.0
10,455.0
17:24
8/17/ 2 019
20:00
8/17/2019
1.10
PR0D1
DRILL
DRLG
P
10455', Drill, 2.8 BPM @ 3367 PSI,
10,455.0
10,598.0
20:00
21:06
Diff=1368, BHP=1999
8/17/2019
8/17/2019
0.40
PROD,
DRILL
WPRT
P
BHA Wiper, PUW=40K
10,598.0
10,598.0
21:06
8117/2019
21:30
8/17/2019
1.10
PROD1
DRILL
DRLG
P
10598', Drill, 2.8 BPM @ 2859,
10,598.0
10,660.0
21:30
22:36
Diff=671, BHP=1988
8/17/2019
8/17/2019
0.10
TR-ODIDRILL
WPRT
P
Short wiper, PUW=37K
10,660.0
10,660.0
2236
8/17/2019
22:42
8/17/2019
0.80
'FR ODI
DRILL
DRLG
P
10660', Drill, 2.8 BPM @ 2848 PSI,
10,660.0
10,712.0
Diff=872, RIW=-12.1K
2242
8/17/2019
23:30
8/17/2019
0.20
PROD1
DRILL
WPRT
P
10712', 100'wiper, PUW=40K
10,712.0
10,712.0
2330
8/17/2019
23:42
8/18/2019
0.30
PROD
DRILL
DRLG
P
10,712', Drill, 2.8 BPM @ 3438,
10,712.0
10,716.0
Diff=1449, BHP=1988, RIW=-14K
2342
8/1812019
00:00
8/18/2019
1.80
PROD1
DRILL
DRLG
P
10,716', Drill, 2.8 BPM @ 3438,
10,716.0
10,796.0
Diff=1449, BHP=1988, RIW=-14K
00:00
1812019
01:48
8/18/2019
0.20
PROD1
DRILL
WPRT
P
10796, BHA wiper, PUW=42K
10,796.0
10,796.0
:48
18/2019
02:00
8/18/2019
1.60
PROD1
DRILL
-[TR-LG
P
10796', Drill, 2.8 BPM @ 3131,
10,796.0
10,885.0
Diff=1139, BHP=1992, RIW=-19K18/2019
:00
[02
03:36
8/18/2019260PROD1
DRILL
WPRT
P
10885', Call TD. Pump 10 X 10
10,885.0
3,525.0
sweeps and chase to window, Avg
:36
06:12
DLS in lateral section 5.4', PUW=41 K
18/2019
8/18/2019
0.20
PRODi
DRILL
DLOG
P
Log the RA marker (+4.5')
3,525.0
3,558.0
06:12
06:24
2.30
PROD1
DRILL
WPRT
P
Continue wiper back in hole, RIW 12.2
3,558.0
10,885.0
8/18/2019
8/18/2019
k, confirm TD 10,885'
06:24
8/18/2019
08:42
8/18/2019
3.25
PROD1
DRILL
PRT
P
POOH, performing swab wiper while
10,885.0
57.2
displacing well to clean new mud
08:42
8/18/2019
11:57
8/18/2019
0.70
PROD1
DRILL
TRIP
P
Tag up, reset coutners, RBIH
57.2
3,500.0
11:57
8/18/2019
12:39
8/1812019
0.60
IFR
DRILL
TRIP
P
Obtain SBHP @ 3,500' CTMD, Sensor
3,500.0
3,500.0
depth 3,318.1' TVD, AP=1,650,
12:39
13:15
EMW=9.53 ppg, PUW 30 k
8/18/2019
8/18/2019
0.20
PROD1
DRILL
LOG
P
Continue IH, log the RA marker -(l -.0')
3,500.0
3,558.0
1315
8/18/2019
13:27
8/18/2019
2.70
PR0D1
DRILL
TRIP
P
Continue IH
3,558.0
10,885.0
1327
8/18/2019
16:09
8/18/2019
1.75
PROD1
DRILL
DISP
P
Tag bottom, send beaded LRP down
10,885.0
10,885.0
16:09
8/18/2019
17:54
8/18/2019
2.90
PRODt
DRILL
TRIP
P
coil
POOH, laying in 9.8 ppg beaded LRP
10,885.0
55.0
1754
8/18/2019
20:48
8/18/2019
0.70
PROD?
DRILL
PULD
P
At surface, Flow check well. PJSM lay
55.0
0.0
down BHA on dead well
2048
8/18/2019
21:30
8/18/2019
1.30
COMPZi
CASING
KURD
P
Rig up floor to pick up lower finer
0.0
0.0
segment. Inspect injector and reel.
21:30
22:48
Found new cracks in storage reel.
Page 12114 Report Printed: 91512019
Armprl ' Operations Summary (with Timelog Depths)
1R-104
W
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
stars Depth
Stan Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
P
Operation
Make up lower liner segment with NS
(flKB)
0.0
End Depth (ftKB)
2,220.9
8/18/2019
8/19/2019
1.20
COMPZI
CASING
PUTB
guide nose, 34 Jts slotted 2 7/8", 3 Jts
2248
00:00
2 718" blank liner, 34 more joints 2 7/8"
liner,3 Jts 2 7/8" Blank, and OH QCLL
8/19/2019
8/19/2019
2.10
COMPZI
CASING
PUTB
P
Continue making up lower liner
2,220.9
2,220.9
00:00
02:06
segment
8/19/2019
8/19/2019
0.60
COMPZI
CASING
RURD
P
R/D floor from liner ops. Skid injector
2,220.9
2,220.9
to floor. Change out packoffs
02:06
8/19/2019
02:42
8/19/2019
0.80
COMPZI
CASING
CTOP
P
Antech inspecting / servicing upper
2,220.0
2,256.4
NRJ. Make up coil and surface test -
02:42
03:30
Good. Strip on well
8/19/2019
8119/2019
0.40
COMPZI
CASING
TRIP
P
RI HBHA#17
2,256.4
3,360.9
03:30
8/19/2019
03:54
8/19/2019
0.10
TCO MPZ1
CASING
DL -OG
P
Correct -4.465 at flag, PUW-28K
3,360.9
3,356.0
0354
8/19/2019
04:00
8/19/2019
0.70
COMPZI
CASING
TRIP
P
Continue in hole. Clean pass through
3,356.0
5,720.0
0400
8/19/2019
04:42
8/19/2019
0.10
COMPZI
CASING
DLOG
P
window
Log RA marker -for -2' correction
5,720.0
5,750.0
0442
8/19/2019
04:48
8/19/2019
4.00
COMPZI
CASING
TRIP
P
Continue in with liner
5,750.0
10,885.0
0448
8/1912019
08:48
8/19/2019
0.30
C0MPZ1
CASING
TRIP
P
On bottom, PUW 32 k, set back down,
10,885.0
8,673.0
bring pump online 1.5 bpm, 1.2 bpm
08:48
09:06
returns, PUW 25 k, remove liner
length from counters, line up across
the top
8/19/2019
8/19/2019
1.00
COMPZI
CASING
TRIP
P
POOH, pumping across the top
8,673.0
35.3
09:06
8/19/2019
10:06
8/19/2019
0.50
COMPZl
CASING
OWFF
P
At surface, check well for flow, PJSM
35.3
0.0
10:06
8/19/2019
10:36
8/19/2019
0.75
COMPZI
CASING
PULD
P
Flush, blow downLD AnTech BHA #17
0.0
0.0
10:36
8119/2019
11:21
8/19/2019
0.30
COMPZI
CASING
PUTB
P
Prep Rig Floor for liner ops
0.0
0.0
11:21
8/19/2019
11:39
8/19/2019
5.20
COMPZI
CASING
PUTB
P
PU liner segment#2, joint#108
0.0
3,268.0
11:39
8/19/2019
16:51
8/19/2019
4.15
COMPZ1
CASING
PUTB
P
Continue PU liner
3,268.0
5,190.8
16:51
8/19/2019
21:00
8/19/2019
1.30
COMPZI
CASING
PULD
P
All liner in well, PJSM Skid injector to
5,190.8
5,217.2
floor. P/U Colt BHA M/U to liner
21:00
8/19/2019
22:18
8/19/2019
1.20
COMPZ1
CASING
TRIP
P
Trip in well, Upper liner segment
5,217.2
8,664.0
22:18
8/19/2019
23:30
8/19/2019
0.10
COMPZ1
CASING
TRIP
P
8664, set down on lower liner
8,664.0
8,664.0
segment, Recip 3 times to get latched
23:30
23:36
up to lower segmet. Pumpson 2 BPM.
PUW=30K
8/19/2019
8/20/2019
0.40
DEMOB
WELLPR
PRTS
P
Obtain static BHP test, Sensor
8,664.0
3,449.0
MD=3405', Sensor TVD=3269.91,
23:36
00:00
BHP=1720 Remove liner length from
counters
8/20/2019
8/20/2019
0.50
DEMOB
WELLPR
CIRC
P
Continue displacing well to seawater
3,449.0
3 449.0
recovering 9.8 PPG completion fluid
0000
8/20/2019
00:30
8/20/2019
1.80
DEMOB
WELLPR
TRIP
P
Trip out of well, Freeze protect with 45
3,449.0
29.0
BBS Diesel, Lay in from 2500'
0030
8/20/2019
02:18
8/20/2019
1.00
DEMOB
WELLPR
PULD
P
At surface, PJSM to lay down tools
29.0
0.0
02:18
8/20/2019
03:18
8/20/2019
2.70
DEMOB
WELLPR
CIRC
P
Make up nozzle. Stab injector back on
0.0
0.0
well. Jet stack and flush rig, Vacate
03:18
06:00
fluid from BOPE, MU and run bore -o -
scope (all -good)
Page 13/14 ReportPrinted: 91512019
r
Rig:
Operations Summary (with Timelog Depths)
1R-104
NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Start Time
Ertl Time
our(hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(ftKB)
0.0
End Dept (ftKB)
0.0
8/20/2019
8/20/2019
4.00
DEMOB
WELLPR
CTOP
P
Remove all safety guards and inspect
INJH, goose neck, levelwind, reel, and
06:00
10:00
counters.
8/20/2019
8/20/2019
2.50
DEMOB
WELLPR
CTOP
P
Open 3.13" ram door, replace with
0.0
0.0
10:00
12:30
3.0" rams.
8/20/2019
8/20/2019
—0 50
DEMOB
WELLPR
CTOP
P
Nipple Down Stack, freeze protect and
0.0
0.0
1230
13:00
secure wellhead.
Note: RIG RELEASE @ 13:00
Page 14114
ReportPrinted: 915/2019
ConocoPhillips
ConocoPhillips Alaska
Inc_Kuparuk
Kuparuk River Unit
Kuparuk 1 R Pad
1 R-104
50-029-21407-01
BA
JUGHES
E campy^v
Baker Hughes INTEQ
Definitive Survey Report
13 September, 2019
Wellbore 1R-104
Magnetics Model Name Still Dap Dedication
PI
8GGM2018
Design 1R-104
Audit Notes:
Version: 1.0
Vertical Section:
0112019 16AB
Phase: ACTUAL Tie On Depth: 3.500.00
Depth From TWO) aWS aEl4N
(.an) (..ft) (tram)
e2 oa o.90 ON
Dlp Angle
(9
80.89
Dhecdon
IDI
1NGO
Field Sttangm
I -T)
57,409
Survey Program
Dale
ConocoPhillips
llka`!
COnocoPhillips
Definitive Survey Report
Survey
Compny.
DonomPhillips Alaska lnc Kupatuk
Local Coordinate Reference:
Well 1R-04
1leacdptien
Schlumberger GCT mullishot
OWED MWD - Standard
Set Data
vanow
Stil 19
Pmfec%
Kupamk River Unit
WD Reference:
1R-04@82.00usfl(1R-04)
COMPASS 5000.14 Sued SW
9 "19 101037,4111
MD Reference:
1R414 @82,ONs%(1 R-04)
SHe,
WeII:
Repoli lR Pad
1R-00
Ruth Reference
True
Survey Calculation Method:
Minimum Curvature
Wellbore:
1R-104
Database:
EDT 14 Alaska Production
Design:
1R-104
.
Pmjeot
Kupamk River Unit, North Slope Alaska, United Stakes
Map System:
US State Plane 1927 (Exact solution)
System Datum: Mean Sea Levet
Geo Osi
NAD 1927(NADCON CONICS)
Using Well Reference
Print
Using geodetic scale recur
Map Zone:
Alaska Zone 04
—1
.
Well
1R-04
5.990,870.26us%
Ltl%ude:
70° 23' 9.802 N
Well Position♦NIS
0.00 us%
Nortbin9:
Longitude:
149°40'33.83897
SEI -W 0.00 us%
EUNn9: 539,829.77usfl
0.00 wall__
yNllhead Elevation:
Ground Level:
---'----
-...0.0ous11
.-- _"— "'-- '�-'"-
Position Uncertainty
Wellbore 1R-104
Magnetics Model Name Still Dap Dedication
PI
8GGM2018
Design 1R-104
Audit Notes:
Version: 1.0
Vertical Section:
0112019 16AB
Phase: ACTUAL Tie On Depth: 3.500.00
Depth From TWO) aWS aEl4N
(.an) (..ft) (tram)
e2 oa o.90 ON
Dlp Angle
(9
80.89
Dhecdon
IDI
1NGO
Field Sttangm
I -T)
57,409
Survey Program
Dale
Survey
Survey
Fire. To
lus%1 lusnl
10000 3.500.00
3506 00 10,834.97
SOay(MelFare)
m
1R-04 (1 R,04)
1R -1M MM (1 R-104)
Tool f.
GOT -MS
MWDOVSG
1leacdptien
Schlumberger GCT mullishot
OWED MWD - Standard
Set Data
vanow
Stil 19
End Data
will
—
COMPASS 5000.14 Sued SW
9 "19 101037,4111
Pas, 2
oc es
ConoeoPhillips �`-,m,,,,. ®
conocoPhillip5 Definitive Survey Report
company:
ConamPhillips Alaska lnc_Kupamk
Project
Kupamk River Unit
Site:
Kupamk 1 R Pad
well
1R.04
Walloons:
1R-104
Design:
1R-104
LecelCo-orUlnMe ReTenoce:
We01R-04
M ReAMIMat
1R-04®82.00usR(1 R-04)
MD RMannce:
iR-04 i@ 0200us8 (1R-04)
North Referenee:
True
survey Copper.. earned:
Minimum Curvature
Database:
EDT 14 Alaska Production
Survey
MD
(own
3.909.00
3,50&03
3,545W
3,5R.E
31600M
3,03.13
3,857.7
3,89345
3114.2)
3.754.17
3.708.7.
3,819.91
3.849.09
3,Banks
3914M
3,26120
3,99189
4.021.53
405752
4,09131
4,H9]o
4,14&78
4.183.40
4,213.14
424022
426748
4,30357
4,32.79
i 437637
4,41083
Inc
P)
39.53
39.64
46.80
50.76
5531
8220
OX
78.0
8511
90.53
90W
Mal
87.88
87%
87,3
Me"
8420
8340
8375
By.
saw
87.33
88,61
9205
936k
9408
9137
90.75
9026
9137
Atl
19
163.45
16351
16390
164.10
164.40
164]0
165.90
165.39
1.'84
162.47
161.19
16052
16tm
16212
161.37
159.11
190.65
162.37
161.71
162.23
163.16
171.69
17185
Mae
171.70
72.62
1888
17365
7890
178.70
TVD
(-am
3.3"05
3,348.67
3,3]1.0]
3,395.03
3411.86
3.42895
3438.80
3,40.70
3.452.82
3453.80
3.453.40
3,453.55
343.45
3.45573
3456M
3.458]8
3.462.03
3,485.21
3,469.22
34899
3,475.84
3,477.81
3,479.04
3.47&W
3,47)51
3.475.53
347391
3,473.18
3.47288
348.39
lVDBS
(-ft)(usul
3,51.05
3,265.67
3.295.08
3,313.03
3,32986
3.346.95
3,356.80
3.366.70
3370.82
3,371.00
3.371.40
3,371.56
3.3]1.4.5
3,373.73
3,37491
3,375.78
3,380.03
3.383.21
3,387.22
3,39089
3,39386
3,395.81
3,39704
3,396.86
3,395.51
3.393.53
339191
339118
3.39088
3,39039
rW4T
SM 30
58795
-613.58
33.27
-654.76
'501.85
-70300
-736.70
-766.71
-794.B3
-aV.M
-057.12
-8367
410.13
-9451.
-90122
-1.01965
-1.047.83
-1,091&5
-1,113.78
-1.140]5
-1.1..04
-1,20320
-12M 7.
-14259.58
-0,28&50
-1,31338
-1,361.22
4.394.68
-1.429.10
aFJ4V
(usD)
15390
154.99
182.50
16816
174.22
181,70
187.43
196,33
2W.25
21)71
223.3
233.71
24327
2336
26375
276.19
289.14
29775
308.78
319.7
3279
333.80
338.83
WaS
346.0
350.15
3345
359.,4
35183
3..17
MBP
Nonni,
(n)
5,990286.85
5990,983.19
5,990,257.62
5,990 237.96
5,990.21850
5990.189.45
5,90,168.34
5.990.13.69
5990 105M
5,93J.076.65
5.9.0.043.82
5950.014.40
5.989.986.98
5,989,953.59
5,983925.7
5.909 890.62
5,989.85237
5,989.82414
5989 ,70.18
5,989,758.31
5,989.731.39
5,889.703.13
5,990,90892
5989,639.46
5,989.61.87
5969583]!
5990,550,02
5,909511"
5989,477.67
5,990.443.25
Map
Easting
(R)
539,D.77
539 907A7
539.995.52
540001.2.
540907,46
540.01508
540020.82
540,033.00
30,03887
540.04&09
540,057.66
54005502
540077.]3
30.088.99
54009&3
54041116
540,124.31
540,133.07
30144.2.
540.13.3
540,163.38
540,1..3
540.17497
540178.95
54010281
30.18574
540191.22
30.196.02
30,188.99
540,01451
(.�LS
166
194
1837
14M
15.93
21.25
29.85
2637
]1.13
1]62
3.78
7,38
342
2,62
?86
6.60
1263
497
199
1.78
6.33
3038
3.73
1z%
0.68
341
799
2,52
950
631_
VarRral
eaceon survey Tool Name
(R)
504130 MNDMSG(2)
59].96 peou MWW
61350 MWD 9WSG(2)
833?7 MNDOWSG(2)
654.78 MvW0W63(2)
60185 MNDOWSG(2)
70:1.00 MJUDOWSGG)
7%.70 MWD OWSG(2)
766.21 MNDOWSG(2)
794.&1 MW➢0WeG(2)
027,72 MD OWSG(2)
357.12 MND M93 (2)
8367 MWD OWSG(2)
81813 soAD OWSG(2)
990.00 MiN00WSG(21
98122 MWD OWSG(2)
101965 MND OWSG(2)
?047.&3 MWD OWSG(2)
108185 MNDOWSG(2)
181370 MW30WSG(2)
114075 MWD OWSG(2)
1.16984 MNDOWSGP)
1,,013.28 MWll OWSG(2)
123276 MND OWSG(2)
1,159.58 MND 0905612)
1200.50 MWD OWSG (2)
?32220 MAID OWSG(2)
1261.22 Mno MSG (2)
1396fi8 MWD OWSG (2)
?42410 MWD OWSG P)
9p9Q019 10.10.37M
Page J
Annotation
TIP
KOP
COMPASS 5000 M Build SW
ConocoPhIIII eA s
ConocoPhillips Defnitive Survey Report
Company:
ConowPhd4ps Alaska Inc_ Kupamk
Pr0lece
Kupamk River Unit
Sire:
Kupamk 1R Pad
Well:
1R-04
Wellbore:
1R-104
Design:
IR -104
Survey
Local Coordinate Reference:
Mil 1R-04
7VD Reference:
1R-04 ® 82.00usn (1R-04)
MO Reference:
1R-04 ® 82.00usn (1R-04)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Database:
EDT 14 Alaska Pmducam,
MO
(.an)
Inc
(°)
A8
(')
TVD
(NIM
TVDBS
(-all)
4W4e
here)
.evNorthing
law"
Map
(re)
Map
Emig,
Inl
DLS
1°noo9
Vertical
Se"Isse Survey Tool Name Appellation
Inl
444233
9135
18190
3471.65
3,389.85
-1,460.49
363.01
5,9894118]
5402D].52
10.19
1489.49 MAD MSG (2)
4,490.25
9289
182.8]
3.459.87
3,38]8]
-1509.44
WIN
5,989.363.92
540,19880
3.71
1`.48.44 MAD MSG (2)
4,52379
9215
179.08
3,456.40
3,385.40
-154193
350.49
5,989.330.42
54019843
1130
1,54193 MWOOWSG(2)
4,583.21
91.55
18021
3457.12
3305.12
-1581.33
360,74
5989,29103
540.19989
3.24
1,581.33 MND MSG (2)
4.502.33
91.17
18269
3,46620
3384.20
-1,620.42
35975
5,989,25193
54 AWII
fi41
1520.42 MND MSG (2)
4,541.62
90.39
189.18
3,465.66
93.47.65
-1,659.69
358.76
5 g
540,197,33
6.70
1,559.69 MAD MSG 12)
4.57772
90.40
183.7
3.465.42
3.383.42
-1,60.79
358.46
5,989,176.57
SW 187.22
1.64
1895.79 MAD MSG (2)
4,699.84
90.61
179.21
3,465.18
3,383.18
4,71801
358.47
5.989,15435
540197.35
TW
1,718.01 M690WSG(2)
4,85.50
89.16
176.74
3465.19
3,38].18
-1,743.57
35893
5,989.128.80
SW.19794
671
1]4357 MWD MSG (2)
4.75185
89.08
101.35
3,46589
3.30.1.69
-1,77594
3S&W
59890911.43
SWANOW
389
1,775.94 MWD MSG (2)
4.79168
89.42
181.84
3,463.13
3,384.13
-1,BGI
]57.96
5,MeOW65
540,19]33
1M
1889.8 MADOW6G121
4833.17
86.54
183.21
3.467.59
3,385.59
-195114
356.13
5,95,021.22
540185.8
7,69
1.85144 MAD MSG (2)
4,85168
67.32
78196
346868
3,385.50
-1,85.59
355.30
5.969.892.70
540.194.5
7,96
1,859.59 UkkDMSG(2)
4,878.02
8828
18101
3489.52
3.307.52
-186392
354.5
5,988,97844
540,194.40
4.64
1893.92 MWD MSG (2)
4,90831
88.5
181.75
3.47032
3.363.8
-1,8ffi.18
353.70
51988989.18
SW.19368
2.16
1,MIS MAID MSG (2)
4039.04
88.
111
3.471.10
3,389.10
-1,95587
352.30
5,98891548
540.19245
597
1.03687 MAD MSG (2)
4973.72
8804
I"'M
3,48.23
3,39023
-1,99147
38936
5,988,88080
540,190.62
0.78
199147 MAll MSG (2)
5.015.8
6759
184.09
347383
3321B3
-2033.35
347.60
5,888,838.90
540,180.16
231
2,033.89 MNDOWSG(2)
5.04346
88.92
184.57
3,47463
3,39269
-2,061.34
34548
598581089
SWASS19
S."
2891.34 MAD MSG (2)
6 Sears
8799
185.40
3,475.5
3,393.5
-2087.22
340.23
5,988.755.11
643,184.07
4.89
?087.22 MND MSG (2)
5,09999
Be 16
18454
3.475.41
3,39446
$11729
340.61
5, We 75502
54.181.62
2.90
2,117.29 MND 08954(2)
5,13540
BS4S
184.30
3.47745
3.39545
-2, In Se
Was
5,96$719]2
541
1.05
3,152.58 MAOOW5G12)
5.15933
8797
184.11
3,47820
3,396.20
-2.176.44
3%.13
5,05.695.88
589,17!.45
216
2,176.44 MaD MSG R)
519153
685
162.94
3,479.25
338725
1.25.5
334.15
.673
5.955
540.175.64
3.77
2.20855 MAD MSG (2)
5.727.89
90.34
18221
3,479.5
3,39768
-2,244.88
33252
595627.41
640,174.21
5.96
2244.88 MWD MSG (2)
5.25522
9141
18412
3.47925
3,57.25
-227318
330.95
5,988599.12
54.1879
7.73
2273.16 MNOOVOI
5,284.05
91.77
1814
3.476.47
3.39647
-2,301
329.11
595,571.35
540,171.5
281
2,300.92 MND MSG(2)
5.3135
8903
183.50
3,47827
3,396.27
-2,33001
327.31
595,541.95
54075.M
9.30
2.33031 MAD MSG (2)
5355.24
8801
18425
3,47935
3397.35
1,37194
324.49
5.990,50032
SW,1%.5
303
2.37194 MND MSG (2)
5,39127
SOB
183.8
3,45.75
3,30,75
-2.412.85
32164
5,988.459.40
540164.23
130
?41285 MWD MSG (2)
5428.15
580
1545
3,481.34
3,393.34
-2444.66
319eS
5,95427.5
5416240
5.46
?44486 MWD OWSG(2)__ _
9/132019 10'10: 37AM
Pape 4
COMPASS 500014 Budd MH
ConocoPhillips I4WN 4
ConocoPhillips Definitive Survey Repoli
Company:
COnowPhlI,a Alaska lnc_Kupamk
Local Co-ondmale Reference:
Wen 1P-04
Protect
Kupamk River Unit
TVD Reference:
1R-04®82OOusS(1 R-04)
Site:
Kupamk I Pad
SAID Reference:
1R44®82.00usfl(1 R-04)
wall
1R44
North Reference:
True
Wellbore.
1RA04
Survey Calculation Method:
Minimum Curvature
Design:
IRAN
Database:
EDT 14 Alaska Ptolucbon
Survey
MO
1-11)
5,45358
Ix
fl
09,11
AN
M
18428
TVD
(-am
3.01.67
M55
IMNq
3,39967
eWLS
(-am
-2480.00
♦ESW
tutu
31726
Mop
Nallhing
Int
5,980,392.23
Nap
Fabling
(n)
540.16.20
CALS
Meet)
3.05
WeM.l
Stoaan Son, Tool Name
IM
2,480.00 MWDOW&G(2)
,
Annotation
5,6152
90.92
10409
3.481.66
3399,66
2517.89
31449
5.908.354.33
SW,15763
499
2,517,89 MWDO SG (2)
5,530.74
9054
182.6
3,48129
339939
-2,547.01
312.77
5,980.32521
540156.07
5.01
2,54701 MND MSG (2)
5.57536
9005
184.39
3,481.86
3,390.06
3,591.54
31002
5980.2006
540,16.55
3.99
2,591.54 MNDOWSGI2)
5,613.69
9040
185.95
3,46.91
3,390.91
-2,62.21
36.6
5,900.24248
54(1,15030
4.17
2629.71 tAMOMSGoo
5649.09
Saw
10459
3,46.92
3.390.92
-2,W+96
303.31
5986207.21
540.14724
4.49
2,649S A)MSG I2)
5.6901
90.20
18543
3.48101
3390.01
$714.69
299.95
5.988,157.47
56,1'GAS
200
2714.69 MWD OWSG (2)
5,M.29
90.98
186.30
3,480.70
3398.70
-2,744.81
235.6
5,900,127.34
540.14031
3.888
2744.81 MWD OWSG (2)
5.761.70
8000
10723
3480.42
3,390.42
-2 Man
282.04
5.980,095.14
540.135.57
4.15
2,776.99 MWD MSG p)
i
5,6268
906
140]2
3,46.19
3,390.19
-2.017.67
287.07
5,989,054.44
540,131.01
202
2,817.61 .MSG (2)
5831.70
916
1852(1
3.479.6
3.397.6
-206.52
284.00
5,980.025.57
SW.12895
631
2016.52 MWD OW5G (2)
5,87025
6.&i
164.08
3.478.72
3396.72
-2084.94
26.94
5,07.987.14
56.126.04
36
2884.94 MWDOWSG(2)
5.96.97
89.98
185.24
3,478.45
3,396.45
3918.54
27030
5,98795353
56123.0
445
291654 MWD MSG (2)
5,954.44
90.6
181.06
34MO
3,30.20
3,96.91
275.00
5,907.90315
266,120.6
6.75
2,968.91 MNDOWSG(2)
5,995.29
0849
185.23
3,470.03
3,39683
-3,010.67
27249
5,907,861.38
540,118.26
676
3,010.67 MJN OWSG (2)
603065
64.28
183.6
3,481.12
3.399.12
4.08464
26.63
598787.21
540.11578
1197
3,044.84 MAN OWSG (2)
6,07163
01.83
18676
3.465.00
3,404oll
3085.37
26.40
5.987)86.05
540.1126
782
3,065.37 MWDOWSG(2)
6,11541
WAS
10,17
3,40 55
3,40855
3126.n
262.34
5,9877626
56106.74
1059
3,120.72 MWD O MSG (2)
6.14502
89.47
18741
3.491.64
3,40964
3.16ffi
258.01
5,907.7136
540,105.57
1241
3,158.92 MWD OWSG (2)
6P7A4
92.53
16.%
3,491.09
3,499.06
-3,169.99
25512
590761.99
540.101.05
893
3,109.6 MND OWSG I2)
6.213.07
9221
1MS3
3.46.61
3.40701
4225.70
25146
5987.640.26
540.0'630
5.71
3225.70 MNO OW6G (2)
634540
91.40
16.83
3.46.59
3.406.6
-3.257.84
24810
5.987,81411
540.065.27
667
3,25784 MNDO SG(2)
i
6,279.78
9120
18700
3,487.01
340581
-,291.6
244.6
5,907576.97
5400932
0.93
3,29196 MWDOWSOG)
S.M.
90.05
16.91
348745
3405.45
-,311.6
241.60
5,907500.26
540.080.90
1.96
3,3116 MVA MSG R)
6.332.6
91.14
185.211
3466.6340400340400-3
,384.49
23612
5,907,52742
540,085.67
5.25
3,344.49 MAT)MSG (2)
fi374.R
91.6
1652
3,405.08
3,<0 W
-3,366,00
23]6
5957485.6
540.08163
335
3,385.00 MND OWSG (2)
6404.01
9292
18728
3.484.60
3,402.68
3416.17
230.21
5,987,455.70
540,078.4
501
3.41617 NOD OWSG (2)
! 6439.61
9D.M
10780
3,483.6
3,401.69
-4666
225.64
5,90742119
54007370
76
3.450.66 MWD MSG R)
8.484.99
9294
105.45
34MM
3,40D.39
-4495.71
MA1
5,907,376.12
54006.77
7.72
349571 MWD MSG (2)
6.522.49
9190
16.02
3.481
3396.
.3,532.89
21667
5,907,339.82
SW065.22
340
3,62.6 MWD OWSG (2)
,
6,5392
91.70
184.05
3.479.6
3.3976
-3,664.25
2136
5,67,307.84 _
.,_ 540_056.
3n
3,584.26 MWD OWSG (2)
9/181401910:1037 M
Pages
COMPASS 5000.14 Shod Sell
Survey
ConocoPhillips
ConocoPhilhp5
Definitive Survey Report
Company. Lan..Pliillipa Alaska lnc Kupamk
Local Coordlmte Rahn.:
Well 1R-04
Pnjecn Kupamk Rimer Une
MRsl4na.oe:
1R-04®82.00us8(I R44)
She: Kupamk 1 Pad
MO Rssetenca:
1R-04 @82.00use(1 R-04)
Well. 1R-04
NOM Rennnca:
True
Wellbore: 1R-104
survey Cakulatlon Methad:
Minimum Curvatura
Deals.: IR -104
Datatlsse:
EDT 14 Alaska ProEuction
Survey
MD
Inc
Arl
ND
TVDss
+WS
elEfm
Naelllns
Esetlns
DW
6eutlan survey Toal Nemo
(..ft)
("(
(')
(YaR)
(wll)
last.
(Ulm
(m
m)
(•HOC)
(III
m
6,58520
9%le
185.13
3.47..06
3,397.06
3595.41
21097
5,90],2]6.38
54605986
217
3,59541 M CAAGG(2)
6.618.27
91]3
186.37
3,470.23
3,396.23
3,62830
207.68
5,681
540,056.]3
4.13
3.628.30 MND0WSG(2)
6,653.40
9162
10530
3,4]].20
3.395.20
-,66331
204.66
5,967,20845
546053.31
283
3,663.31 MND OWS3(2)
6.607,09
90.81
105.51
3.4]6.40
3,394.48
-,898.]0
2D3.07
5.40],1]4.98
566,06630
244
3.6.6.76 MND MSG (2)
671833
8993
166.86
3,478.20
3,84.20
-)27.]9
197.50
5,9B7 1QW
S ,.7.10
518
3.7]19 MND MSG (2)
6,74911
91.23
184.97
3,475..7
3,393.97
-3,754.43
194.33
5,987 11329
510.01.09
7,45
3,75843 MWDOWSG(2)
6]8].02
93.66
183.Q
3.4]052
3,392.52
-3,]9].01
191.50
5.907 074.A)
510.041.47
6.19
3.]9].01 1AVYDOWSG(2)
6.826.78
93.71
181.10
3,4Mn
3,390M
-,035.82
100.95
5901.03589
516039.12
2.41
3,835.82 MWO MSG (2)
6,056.54
92.51
11,3100
3.410.61
3,380.61
-,865.47
10111
5,987 Oce22
546037,44
5507
3.865.47 MWD MSG (2)
6900.49
9D.28
183.62
3. &,.
3,387.54
-,909.34
184.57
5986,962.35
540,035.14
5.27
3.90934 IMAD MSG (2)
6,935.59
1111
104.98
3,469.36
3,38].36
3.4434
101.94
590892].1
540,03270
1"
3,914.34 MWD OW Go (2)
6,9]3.56
.963
18351
3469.38
3,387.38
39028
1]9.13
5186.889.46
546030.09
4.27
3,982211 MWD MSG (2)
],01]65
9241
18511
3,468.59
3.366.59
4,026.16
17582
5,906.1,45.49
540.027D1
7.27
4,026.16 MWD ON5G 12)
7.049.80
9133
18843
3467.54
3.38554
4405812
17259
5.966,813.51
540.023.95
5.30
4,00.12 MND M93 (2)
( 7.0820
00.41
185.92
3A6898
3.384.96
4.09637
1680.5
5.955 776,24
516020.m
273
4.08537 Ni
7,111.09
66.07
18]]5
3.46850
3,304.90
4,11902
16574
SSB6,752.59
SW.017A2
8.35
4,11902 MND MSIG(2)
7,1451
M61
186]0
3.467.00
3,38509
y15304
16142
5,986718.55
540.013.29
3.24
4,15304 MND MSG (2)
7.10285
9007
184.Z!
3,496.96
3,38496
4, Inn
157,06
5,985.68124
5]0.669.92
7.55
4,190.33 MVYDGWSG(2)
7,216.16
91.0
15507
3.16.22
3, 3"n
4,2nN
154.90
5,985,547.78
5W,W715
SA5
4,223.1,0 MWDOWSGQ)
7,250.15
90.62
10x'.69
3.405.54
3,38154
4.257.25
151.22
5.116.6145
540.003Ge
3.95
425728 MAID MSG (2)
7,201.1
9112
103.49
3,465.07
3.383.07
-0,20854
148.43
5,988582.8
540.001.02
1032
4266.54 MWD MSG (2)
],32195
9044
18899
3,41.52
3.382.52
4.328.]]
1M.74
5,986.12]5
539.997.55
802
4,320.77 MWD MSG (2)
7,35140
90.40
11.59
3,464.30
3,302.30
4,350.15
141.7
5,9..51336
5399947
8.13
4 M 15 MND MSG (2)
7,37.37
89.39
166.61
3,489.M
3,382.34
4.37993
12963
5,956.491.55
539,992]1
10.32
4.379.93 MWD MISS (2)
7,420.18
90.15
181]1
341.53
3,302.53
4.42655
135.42
5,983,441.93
Me 966.]5
6.66
4126.55 MND OW6G (2)
7.451.81
9122
18630
3.454.15
3,382.15
-.458.05
132.66
5.M.413.Q
58,906.16
666
4,450.05 MND MSG (2)
7,40473
91.02
inn
3,463.42
3.381.42
4,495.33
129.56
5.966,376.12
539,983.25
8.25
4,4533 MND MISS (2)
7,51519
92.69
183.211
3.66255
3380.58
4521.24
128.10
5,.66,35022
58,98191
6.43
452124 MND MSG (2)
],569.]3
880
103.28
3,461,92
3,379.92
4,5]56]
45.@
5,986,293]1
58,9]9.15
7.34
4,57S67 Ni
7.59362
9044
18381
3.162.10
3,38010
459952
12355
5.9W 271n
58.9]].80
7.SS
4,599.52 MWD MSG (2)
7,621]4
1,80]
18269
3462.51
338051
1530.59
121 7g
5908240.05
539.0620
842
4,630.58 MWD MSG (2)
(
M1S?O19101037AM Page 6
Annotation
CDMPAss 500014 Sued 85H
ConocoPhillips
�f &°`GRA •
v
Co000 hillips
r1
Definitive Survey Report
company'.
Con..Phdh,
Alaska
lnc Kupamk
Local Coominam Rebmnu:
Well1&04
Pm(en:
Kupamk River
Unil
TVD Relerence:
1R-04@
82.03u8X(I
R54)
Site:
Kupamk I Pad
MD Re6emnce:
1R-04@
02.00.8X(1
Roil)
Well:
iR44
Nenh Renitence:
Tme
Wellbom:
1R-1N
Survey Calculation McNad:
Minimum
Oumalum
Design:
1R-104
Dambase:
EDT 14 Alaska Production
Survey
Map
Map
Vertical
MD
Inc
Atl
TID
TA99
+NIS
+61281
NOXtdng
Eaflo
DLS
Section 9urvay Tool Noma
Annotation
PI
1°I
IuW
IwRI
luslN
IusXl
(11)(
I
hl
1°1100•1
1X)
7,659.19
W.n
18636
3404.87
3,382.06
AMMBS
11807
5,928287.
53997367
1129
4.,188 MWDO .(2)
760203
2873
128.74
3,40.35
3.303.35
4,687.56
116.m
5.9i',183.B5
539971.30
2R
4,68]56 MND OWSG (2)
7$3.70
BB.BT
182.65
3.466.95
33..95
4,729.07
113.55
5,983,142.32
539.968.49
0.63
4)29.0] MWD OWSG (2)
],M0
9D.51
104.87
3487.15
3,385.15
4,]8533
111.07
5.986.106.05
5%1..20
7,37
4,785.33 MND OWBG (2)
j
7,796.28
91A7
103..
3.466.52
3,3..53
4,601.46
10635
5,906,069.92
539983..
4.53
4,W1.. MND OWSG (2)
7,638.69
8123
186.20
3.46553
3,383.53
4,04309
104.71
5,98502767
539987.]!
605
4,8,1359 M OWSG (2)
7.873.63
9In
186.81
3,487.61
3,38261
4.879.40
100.76
5.985,892.95
539955.48
2.33
4.878.40 MND OWSG (2)
7,912.5
92.13
WAS
3,46320
3301.29
4,917.11
NO
5,965,954382
528.952.87
603
4,917.11 MWDMSG(2)
7,9,17.38
92.60
18743
3461.85
3379.65
4.951]0
W,N
5,80591953
539.950.17
205
4,01]1, MW➢OWSG(2)
7,977,79
9086
165.10
34W.N
3.378.96
4,,982.06
91.38
5,9%,8&9.25
539.94785
6.30
4.982W MWD OWSO(2)
8,W5..
90.35
IM78
348774
3.376.74
5,009.00
8900
5,905.86169
539,944.44
13.31
5,00960 MYN OWSG (2)
B040A0
91.5
181.87
340.18
3,378.16
IOna9
83.96
5,985.827.38
5399405
1235
5,.389 MWD OMG (2)
6W8.32
91.95
191,54
3.4W.3D
3,3]/.30
SOR.90
81.11
5,985798.29
539,937.80
65
5,87290 MWD OWSG (2)
0,187.9]
93.18
18567
3A765
3375.5
5, loe.
1723
5.985,761.90
539.931.20
4.19
5,109.. MND OWSG (2)
0,147.0
9278
1M.17
3.4Ya.49
3,373.49
-5.151.10
73.87
5.985,720.13
539930.65
3.59
5.16110 BIND OWSG (2)
8,101.50
91.10
185.37
3,0.51.33
3,3h.33
.5,1M.57
TOM
5.965,686 65
539.02623
5.90
5.181.57 MJJD OMG (2)
8.20596
Bt31
189.73
3,453.W
337.00
5,208.80
68.29
5,805662.33
533.925]9
5.56
5,58.69 MND OWSG (2)
8.240.80
90.41
1..92
3.453.28
3,37120
5.243.54
64.75
5,965.82268
539,922.44
5.80
5.N3.54 MMD MSG (2)
8,281,93
92M
18632
3,452P
3,370.27
5.2".37
60.01
5,887,55.87
539,917.92
9.56
52..37 IMOMSG(2)
8,312.87
91.02
107.52
345111
3.369.11
5,314.20
SS.w
5,985,556.95
539.913.92
2.92
5,31420 MWDO SG (2)
"MA
0.97
187..
3<W.37
3.360.37
5,34264
5213
5.885528.87
539,91034
387
5,34284 MWD MSG (2)
8360.85
09"
187.0
3,4W.23
3.368,22
29,37044
460
5,91,5.500.5
539,98741
687
5,37044 MWD OWSG (2)
6390.63
8676
1.As
3,487.63
3,36963
5,383.86
434
5.985,471.N
53903.87
470
5,39906 BMTIOWSG(2)
6426.0
9027
109.5
3.48707
3,%8.87
5,4 M
3918
5,985443.26
53989105
7.30
5,427.02 MD OMG (2)
8.406.91
90..
189.52
3,4$61
3,35.61
-5,18725
32%
5,98640380
53989tH
0.53
5,46725 B OW5G (2)
8,503.97
90.04
192.87
1A.,15
3,36646
-5,500.65
25.94
5,98,37036
539,08500
9.92
5,50.0 MNO OWSG (21
85361.01
89.0
191.77
3.4%46
33MAS
5,534.89
18.47
5,98533509
539,077]1
315
5.534.N MND MSG (2)
6,577.63
91,40
1%.91
3449.97
3367.97
5.57569
1028
5,928,295.25
539.869,75
4.05
5,575.69 MNDOWSG(2)
8,604.58
91.81
191.20
3449.21
3,36721
£.60213
5.12
5,985,26879
539.284.72
1.86
5.60213 MMDO so (2)
0647N
92.40
188.12
344728
3,365.63
5.844.50
-2.11
5,928228.%
539,05772
727
5,644.58 MMA ONSG (2)
867194
$1.69
187.31
3.445.55
3.384.55
5,68680
S.E
5,985.202.27
539650.87
3M
5,668.6D MWD ONEG (2)
Papel
9113R019 10,10.37M
ConocoPhiilips
Compan,
ConocaPhilhps Alaska Inc Kupamk
Project
Kupamk River Unit
site:
Kupamk IR Pad
well:
1R-04
Wellbore:
iR-104
Design:
1R-104
Survey
ConocoPhillips IES
Definitive Survey Report
Local C..Mntla Rafnumaki
Vial IR -04
TVD Reference:
1R-04 @ 82.ODusft (1R-04)
MD Reference:
1R-04 @ 82.ODusft (IR -04)
North Reference:
True
Survey Calculation Method:
Minimum Ourvaluro
Dalabase:
EDT 14 Alaska Production
Annotation
9/13201910: 1037AM Page 8 COMPASS 500014 Build 854
Map
Map
Vertical
MD
IM
Asl
TVD
TVDSS
-NIS
+EPN
Northing
Eaating
DLS
Section survey Tool Name
(-am
1°1
(')
(.an)
luau)
Juan)
loan)
(ft)
Ift)
Viloo')
(ft)
8.]15,16
IS
18]95
3,445.76
3,363]0
5,701.51
977
5,985,16933
5398503fi
83a
5,70151 MWD MSG (2)
8,1392.
09.35
18020
3,44598
336298
0,73528
-14.56
5,98513555
Me 845.]5
1.99
5.73520 MW1)MSG (2)
8.76921
9024
inn
3,kki
3,36408
S764.eB
-1845
5,965,10582
539,842.02
5.76
5,76499 MWD MSG (2)
8,79686
09.8
10568
3.445.10
3,&.10
5,]9238
-2142
5,9059]052
539,039.20
430
5,7@38 MWD MSG (2)
Still
69.12
181
3,44656
3,361
5,835.00
-0,37
5,9&5,0349]
539,83448
3,93
5.835.80 MWD MSG (2)
0tleam
910
1050]
3448]8
3,364,28
0,87994
-31.16
5,9"mon
53902393
7,56
5.879,94 MWD MSG (2)
Sari
9241
181
344538
33tarm
0,908.55
-33.63
59".883.19
539, all
4.85
Sol MWD MSG (2)
BaW33
9134
1M.7
3,444.16
3,36216
5,943.04
-3730
5,9",927"
539824.12
5.37
Sot MWD MSG (2)
8980.01
90.41
l"m
3443.71
3,361.70
0,97461
39."
5,934,8%.10
'oa'A 73
2T6
5,97461 MWD MSG (2)
grom ee
8981
lion
3,443.63
3,61.63
..011.06
-02M
5,90485985
53981935
ant
6,011.06 MND MSG (2)
901
8980
181
3.3631]
3.361]]
4,051.94
45.31
5P",810.76
53981868
215
6,051,94 MWD MSG (21
9.100-01
89"
182,91
3,36421
3.36221
0,095.13
-0009
5,364j]5S
539.36414
399
6,085.13 MWD MSG (2)
6,14303
9063
183.56
3.44432
3,3(233
8.13738
5047
5,981
53981198
4.07
6,13]38 MND MSG R)
9,17096
91.62
185.60
3.44318
3,361]8
0,105.11
0270
5,981 Se
539,809.90
012
6,16541 MND MSG (2)
930388
9117
185.31
3,44281
3,360.81
..19].8]
0583
5.911
539.80895
On
6,19]8] MND MSG (2)
9.24042
90.6
18340
3,442.04
3,360.04
4,23429
-6061
5.93663635
539.804,37
6."
633429 MND MSG R)
9 M
90]6
13647
3.441]1
3359.71
4,26054
0 ki
5,9".61010
533.80270
439
6,26054 MND MSG (2)
828334
92.72
18398
3.44090
3358.90
6,2870
.216
5,93650355
Mulli99
9.03
6.207.00 MND GWSG (2)
9,32930
9314
In"
3.439.63
3,35763
0322.95
43.36
5,914547,68
53971651
1.77
6,32295 MNDGWSGG)
9,36317
92,4
18274
3,437."
3355.45
Usei
85.52
S SR51389
539)9311
240
6,356]4 MNDG ISi
934550
92.54
181
3,436.07
3,354.07
438893
07.40
Sam 48164
53076632
4.62
6,88.96 MNDGWSGGh
91
In
1"06
3,436.83
3MSG
641
0085
5,mula4a83
539,794.12
2.33
6,421.78 MNDOW6GI2)
9,45587
91.72
Inn
3,433.88
3,351.98
0,449.11
-842
591 149
530]91]0
9.58
6,"811 MNooneak 2)
9.41
91.85
1"34
3433.09
3,351.09
04n%
-0527
59M,3Pis.
539]8100
683
6,477.56 MMDOVr5G12)
9.51942
9163
18389
3.431.99
3349,89
b,5t1"
-77.81
5,9",35959
53SMIS
3.04
6,511.36 "JVD MSG (2)
555943
9171
185,09
343085
334086
fi,548.87
.0"
59M,321.70
539,71 1
3.79
6.`48.87 hi MSG (2)
Stunt]
0.91
18691
3,430.15
3,30,15
0,579.65
4367
5936,29163
539781,14
4.44
857955 MWD MSG (2)
8,611.10
0.83
18729
3"oen
3,34].]9
0,63361
40,52
5,936,263.93
538]7043
4,51
801 MWD MSG (2)
9.64273
89.59
ta750
3.429.67
3,34767
.,6"97
'90.61
".:,a5, M
539]]4.50
4.03
6.634.97 MWD MSG (2)
9terse
9107
1"37
342938
tell
4,6".16
96.50
5,936.1361
539768]8
3.09
6,364tfi MWD MSG (2)
972265
9287
18827
342831
33,531
6.714.26
-mi
5936.1`4,22
539.76511
9,08
511426 MWD MSG (2)
Annotation
9/13201910: 1037AM Page 8 COMPASS 500014 Build 854
ConocoPhillips
ealuEc"al9s
ConocoPhillips
Definitive
Survey Report
Company:
ConocoPhillips
Alaska
Inc_Kupamk
Local Oo-Ortlinate Rehtental
Well 1R44
Project:
Kupamk River
Unit
TVO Reference:
1R44@ 82.00ukn(111414)
Site:
Kupamk I Pad
MD Reference
1R.04@82.00usl(IR44)
Wel;
iR44
Nock Reference:
Tme
Wellbpm
1R-1.
Survey calculation Mefho2
Minimum
Guradee
Oeslpn:
1R-104
Database:
EDT 14 Alaska Production
Survey
Map
Map
Vertical
MD
Inc
AM
TVD
11,1115,12,
w.$
4EWl
NorMlnl
Eavoinl
DLS
Section Survey Total Name
Annotation
(use)
(°I
("1
(--M
IInR)
lustq
lulu
IS)
Ie)
1.091)9
Df)
9]503]
9232
IBB.%
S.T.
3,345.04
46,741,64
104.56
6984,128.82
539,]6110
3.50
674164 MWO OASG(2)
9.76923
92.75
169.69
3425.32
3,343.32
-6.]]9.95
-110.
6.884,0%.49
59,755.01
211
6]]9.% MWD CMG (2)
9,641.10
9289
18925
3,422.76
3,340.76
39.031.05
-11940
5,964,039.%
539.]48.]8
069
6,931.% MYA OWSG(2)
9,37141
94.05
1111
3p20.93
3330.83
1,%0.69
-1243]
5,964,069.40
539.]41.95
005
13,%0.49 MO OWaO(2)
9,%153
9346
tsoM
3418.95
3.336.95
39.890%
-IM15
5.%3.9]9.]0
539,737.33
3.82
6,890.56 MWDOWBG(21
9,948.27
9233
104.40
3416.60
3,334.68
6.93495
-134.23
5,%3.935.38
538,73249
983
6.934.0 MWDOW6GR)
9,979.00
9349
187,82
3A15.D2
3.333.02
6.967.44
-137.70
5.814.90287
539729.10
1102
6.657.44 MNDOWSG(2)
10,01920
93.%
367,22
3,412.54
3.330.55
-7,007.31)
-142.97
5,%3.662%
539,72A.14
150
7.MT.30 MWD OWSG(2)
t0.Qb`.61
...
187.95
MI I)
3,328]0
-7.044.46
-147.91
5,983,825.01
539,719.39
4.40
7.W.45 MND OMS3(2)
10,105.91
%.16
184.81
340973
3,32]]3
-7.09323
-153.37
5.953.7]].01
539,714.19
T.4]
7.093.23 MND MSG (2)
10,134.%
09.4.5
18524
3409.62
3,R7.@
-7,12219
-055.91
5,983.74304
539,711.80
291
7,12219 MND 0W6G(2)
10,16046
WAS
164.3f13.410.14
3,326.14
-],14].50
-156.05
5,983,MM
5.709.81)
365
],14]58 MND 03756(2)
10215.%
89.50
165.42
3,410.78
3.328.79
-0,ID251
-162.75
5,983.%7.69
539,]%.40
Z.
7,20251 hVd)MSG (2)
1024261
0.02
18].04
3.410%
3,328.%
-],229.34
-065.86
4963610.45
539,]0242
9.16
7,@9.34 MND MSG (2)
1D.2]4]4
%.65
18610
3.41065
3,328.65
-7 MIN
-169.78
5.963600.94
Sn(GSS]
5.78
7.261.23 MND MSG (2)
10,30443
9134
188.71
3.410.09
3328.09
-7.2%.T2
-17313
5,983579.43
539.637.40
2.68
],290]2 MND OWSG(2)
t0, 33543
91.%
187,15
3.409.19
GU7.19
-7,321.48
-17669
5,983548.66
539691.89
243
7,321.40 MJJD OWSG(2)
10,%3.52
91.54
1%.82
3,408.32
3,326.32
-7,349.35
-100.30
5,983,520.76
539.68463
189
7, 349.35 MND OW6G(2)
10.39462
9172
10212
3,407..
3,32544
1,3%.21
-084ID
5,961AMM
539.68502
tt2
7,360.21 MWD CMG (2)
10,42419
9237
109.11
3,4W.35
3,324.35
-7,409.46
-IM24
6983A60.63
539.88100
7.22
7,409.46 MWII GWSG(2)
10,45066
9162
l8i
3405.35
332335
-],435.6]
-1917
5,983A34.40
539,6]].62
11.21
7,435.87 AY)OVASOC)
10.4N.W
92M
1%33
3403.91
3,321.91
-],05.5]
-1%.tfi
5,993.39449
539673..
121)
7,475.57 MWDOV5GC)
10,515.8
93.54
104.55
3,402.64
3,320.64
-7,500.32
-1%.52
5,963369.]3
539.671.2
673
7.500.32 MNDOW03C)
10.516.36
92.55
184.21
3A01.D2
3.31903
-7,53063
-237.95
5963.33921
539.669.04
342
7,530.63 61WDOW0G(2)
1057541
92.62
183.72
3,399.71
3,31].]1
4,559.78
-MM
5,983,31025
5396157.19
1]0
],59]8 MKD GWS3(2)
10.603.91
92]4
18524
3.39037
3,316.37
-7.58016
-237,08
5,983281.%
5396%.12
5.34
7,58816 MWD MSG (2)
10,61862
92.%
164.57
3396.7
3.314]]
-],622]0
-39805
5,983.247.30
539662.34
200
],622]0 MWD CIVIC (2)
10.67358
92.10
t%]S
3,3%.35
3.313.35
-7,65749
31119
5,983,21250
539659.38
30
7,657..49 MND MSG R)
tD.70558
9154
t84M
3.394.33
3,312.33
-7,809.30
-214.12
5,963,1%.64
539,6%62
3.58
7,689.34 MND OWSG (2)
1073713
9037
1%.57
3,3%.67
3311.67
-7 M3`3
-21724
5,903,14924
539653.67
6.13
7,72013 MJN OWSG(2)
10766.34
90.55
iW.13
3.3%.31
3,311.31
-],]49.01
-219%
5,9831MAS
53965110
8.42
--
7749.81 MWD CRAIG (2)
--
---
cal
COMPISSS 014BIASI
9/13801910,10: 37AM
ConocoPhillips B0�'
ConocoPhillips Definitive Survey Report
Company:
ConocoPhillips Alaska Inc_ Kupamk
Project:
Kupamk River Unit
See:
Kupamk 111 Pad
Well:
1R-04
WeHoori
1R-104
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EDT 14 Alaska Production
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BA ER
I UGHES
a GE company
Date:
September 13, 2019
Abby Bell
AOGCC
333 West 711 Ave, Suite 100
Anchorage, Alaska 99501
1B-104
21 9099
31212
Letter of Transmittal
Harvey Finch
Baker Hughes, a GE Company
795 East 94`" Avenue
Anchorage, Alaska 99515
find enclosed the directional survey data for the following well(s):
RECEIt
VrU
SEP 16 2019
AOGCC
(1) Total print
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Harvey Finch, Baker Hughes GE, Wellplanner
Harvey.Finch@BakerHughes.com
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21 9098
3,1 182
ConocoPhillips
Sent Via: CD
Justification: Compliance
Quantity*:
1
1
Attachments:
-�I
Transmittal #1255 Detail
Date: 9/10/2019
To (External Party):
Email*:
abby.bell@alaska.gov
First
Abby
Name*:
Last Name*:
Last Name*:
Bell
Phone
(907)793-1225
Number:
Company:
Company:
AOGCC
Address:
333 W 7th Ave.
City:
Anchorage
State:
AK
Zip Code:
99501
Sent Via: CD
Justification: Compliance
Quantity*:
1
1
Attachments:
-�I
Transmittal #1255 Detail
Date: 9/10/2019
Data Detail
Description*: Type*:
1 R-104 LWD data CD
1 R-126 LWD data CD
Date:v
01�
Date:
ED
From (CPAI Contact):
Email*:
dchard.e.elgarico@conocophillips.com
First Name*:
Ricky
Last Name*:
Elgarico
Phone Number:
(907) 265-6580
Company:
ConocoPhillips
Address:
700
City:
Anchorage
State:
Alaska
RECEP
Zip Code:
99501
10 i
Transmittal Info
Tracking #:
/nSEPP
AOG r
Data Detail
Description*: Type*:
1 R-104 LWD data CD
1 R-126 LWD data CD
Date:v
01�
Date:
ED
pro a 1'7 -09S'
Loepp, Victoria T (CED)
From: Hobbs, Greg S <Greg.S.Hobbs@conocophiIli ps.com>
Sent: Friday, September 6, 2019 7:22 AM
To: Loepp, Victoria T (CED)
Cc: Thomson, Stephanie; Rixse, Melvin G (CED)
Subject: RE: [EXTERNAL]Re: 1 R-104 (219-098) Pre -production request
Follow Up Flag: Follow up
Flag Status: Flagged
Thank -you!
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Thursday, September 5, 2019 5:38 PM
To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Cc: Thomson, Stephanie <Stephanie.Thomson@conocophillips.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>
Subject: [EXTERNAL]Re: 1R-104 (219-098) Pre -production request
This email is sufficient for production less than 30 days. I will let you know tomorrow if anything else is needed.
Victoria
Sent from my iPhone
On Sep 5, 2019, at 5:14 PM, Hobbs, Greg S <Gree S Hobbs@conocophillips com> wrote
Victoria,
111-104, a new West Sak injector is not taking water at predicted rates.
The KRU group would like to turn the well around to production for 30 days or less to remove near
wellbore damage.
They would like to pursue this on Saturday.
The reason Mel is on the mail is because he had his cell phone on his message, so I called him.
That led to this mail and the question from me to you both that if the long term service of the well is not
changed, nor is the completion, what paperwork is required beyond this notification.
Also, here is the rig schedule that came out today -
Thank -you!
G reg
Greg Hobbs, P.E.
Compliance and Regulatory Engineer Drilling and Wells W:(907)263-4749 C:(907)231-0515
Pro
Loepp Victoria T (CED)
From: Loepp, Victoria T (CED)
Sent: Friday, August 9, 2019 1:55 PM
To: Germann, Shane
Subject: RE: KRU 1R-104 (PTD# 219-098) Approval to Proceed/Upper whipstock
Shane,
Assuming it's the same well, that is, same BHL, directional survey etc then approval is granted to proceed. Please
include this approval with the approved PTD.
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria Loeppaalaska.00v
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Victoria Loepp at (907)793-1247 or victoria Loeoo@alaska aov
From: Germann, Shane <Shane.Germann@conocophillips.com>
Sent: Friday, August 9, 2019 1:15 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Cc: Starck, Kai<Kai.Starck@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com>;
McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com>; Hayes, James C <James.C.Hayes@conocophillips.com>
Subject: KRU IR -104 (PTD# 219-098)
Victoria,
Nabors CDR3-AC is currently working KRU 111-104 (219-098), a well that was recently worked over to install a tandem
wedge assembly for CDR3 to kick off from. A window was milled in the lower tandem wedge at 3535' MD to drill the 111-
104 lateral in the West Sak B sand, but unfortunately the window milling did not go as planned and we drilled to 3546'
MD before determining that the window was not in good enough condition to continue drilling the lateral. Only 11' was
drilled from the top of whipstock so no surveys were taken.
Our plan forward is to set a whipstock in our upper tandem wedge with top of whipstock at 3508' MD and drill the 111-
126 lateral targeting the West Sak B sand. Completion plan will stay the same with 2-7/8" slotted liner and 3-1/2" solid
liner in the build. I attached an updated proposed CTD schematic.
Is any formal notification or approval required forthis change?
Thanks,
Shane Germann
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4597
Cell: 406-670-1939
700 G St, ATO 664, Anchorage, AK 99501
MEMORANDUM
State of Alaska
Permit Number: 219-098-0
Alaska Oil and Gas Conservation Commission
Insp Num: mitSAM190908151103
DATE: Friday, September 13, 2019
TO: Jim Regg
P.I. Superyisor I I I�I i�
SUBJECT: Mechanical Integrity Tests
l
ConocoPhillips Alaska, Inc.
IR -104
FROM: Austin McLeod
KUPARUK RIV UNIT KRU IR -104
Petroleum Inspector
Initial 15 Min 30 Min 45 Min 60 Min
Well IR 104
Ste: Inspector
3230 Tubing vo
Reviewed By:
PTD 219
P.I. Supry h�—
NON-CONFIDENTIAL
Comm
Well Name KUPARUK RIV UNIT KRU IR- API Well Number 50-029-21407-01-00 Inspector Name: Austin McLeod
104
Permit Number: 219-098-0
Inspection Date: 9/8/2019 '
Insp Num: mitSAM190908151103
Rel Insp Num:
Packer
Depth Pretest
Initial 15 Min 30 Min 45 Min 60 Min
Well IR 104
Type InJ- TV—D—
--�—
3230 Tubing vo
say aba va
PTD 219
'Type Test sPT Test psi
Isoo loo
Iavo es
Pumped:
BBL Returned:
0.7 OA iu
�
- —
124 za uBBL
Interval
IMTAL jP/F
P
.,
Notes:
Friday, September 13, 2019 Page I of I
THE STAT L.
°fALASKA
GOVERNOR MIKE DUNLEAVY
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
v✓v✓w. oog c c.alaska.gov
Re: Kuparuk River Field, West Sak Oil Pool, KRU 1R104
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-098
Surface Location: 334' FNL, 137' FWL, SEC. 20, T12N, R10E, UM
Bottomhole Location: 3472' FNL, 3' FWL, SEC. 29, TI 2N, RI OE, UM
Dear Mr. Ohlinger:
Enclosed is the approved application for the permit to redrill the above referenced 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,
2ssieL.Iielowski
Commissioner
DATED thisc?i day of July, 2019.
STATE OF ALASKA
A KA OIL AND GAS CONSERVATION COMM ;ION JUL 09
PERMIT TO DRILL 2019
_rr8-A(J(Q 20 AAC 25.005
1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑
to. Specify II f r:
Drill El Stratigraphic Test El Development - Oil El Service - Winj ❑Q Single Zone 0Coalbed
Gas Gas Hydrates ElRedri110'
Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond: Blanket ❑� Single Well ❑
11. Well Name and Number:
ConocoPhillips Alaska, Inc.
Bond No. 5952180 •
KRU 1 R-104 `
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 11,500' TVD: 3381'
Kuparuk River Field /
West Salk Oil Pool
4a. Location of Well (Govemmental Section):
7. Property Designation:
Surface: 334' FNL, 137' FWL, Sec 20, T12N, R10E, UM
ADL 25635 • APc 2,56yQ
Top of Productive Horizon:
8. DNR Approval Number: Z fi /c1,,
13. Approximate Spud Date:
943' FNL, 296' FWL, Sec 20, T12N, R1 OE, UM
LONS 83-134
7/23/2019 '
9. Acres in Property:
14. Distance to Nearest Property:
Total Depth:
3472' FNL, T FWL, Sec 29, T12N, R1 OE, UM
2560
17,058'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): lW
15. Distance to Nearest Well Open
Surface: x- 539830 y- 5990870 Zone- 4
GL / BF Elevation above MSL (ft): 45'
to Same Pool: 744', 1 R-05
16. Deviated wells: Kickoff depth: 3534' feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 92 degrees
Downhole: 1517 Surface: 1180
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)
4-1/4" 3-1/2" 9.2# L-80 HYD 511 256'
3524' 3363' 3780' 3470' Solid Liner
4-114" 2-7/8" 6.5# L-80 HYD 533 7111'
3780' 3470' 11,500' 3381' Slotted Liner
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):
8440' 6864' 3709' 3711' 3503' 3708'
Casing Length Size Cement Volume MD TVD
Conductor/Structural 77' 16" 250 sx Cold Set II 115' 115'
Surface 4260' 9-5/8" 1190 sx PF E, 425 sx Class PF C 4298' 3927'
Production 8392' 7" 300 sx Class 'G' 8427' 6853'
Liner 328' 4-1/2" 35 bbls Class'G' 3358'-3686' 3233-3484'
Perforation Depth MD (ft): 3398'-3558', 7892'-8188' (all plugged) Perforation Depth TVD (ft): 3264'-3388', 6442'-6667' (all plugged)
Hydraulic Fracture planned? Yes❑ No Q
20, Attachments: Property Plat ❑ BOP Sketch ,�
Drilling Program
Time v. Depth Plot
Shallow Hazard Analysis
Diverter Sketch
Seabed Report
e Drilling Fluid Program
8 20 AAC 25.050 requirementse
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: Shane Germann
Authorized Name: James Ohlinger Contact Email: Shane.Germann CO .Com
Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4597
-7 /
Date: S/f
I(
Authorized Signature:
Commission Use Only
Permit to Drill
API Number:
Permit Approve
See cover letter for other
Number: -.
50-02q- *-0 -7- •-OO
Date:
requirements.
Conditions of approval : If box is checked, well may not be used to expic hit6n ,gas hydrates, or gas contained in shales:
Other: Samples req'd: Yes E]No[e" Mud log req'd: Yes ❑ NoW
/a 19 r .f 7o 35-0 0 /o :;�` 5 _
!/ p
.�_V 2 1, r�V2 measures: Yes ❑ No[y Directional svy req'd: Yes &r No❑
�
Spacing exception req'd: Yes ❑ NOL.1 Inclination -only svy req'd: Yes Nov
�❑/
Varl4neC /1o 117- 0) aO.A ACZS. 412 (C) Post initial injection MIT req'd: Yes LVJ No El
,26A4C'.7s,
9rArn 10 CLI/4CbC-Cl �'oncltfiors {o fjWrvva
APPROVED BY
Approved by: — COMMISSIONER THE COMMISSION Date: `
.717 -Vs
^
^
•
Submit Form and
Farm 1 - 01 Revised 5/2017 pe mit is valid
r
t
r
i
r„fie
f a royal per 20 AAC 25.005 Attachments in Duplicate
La pp (g)
gl`_R z/.../
KRU 1R-304(PTD 219-098)
Conditions for Approval
A variance to 20 AAC 25.412(b) & (c) is granted for KRU 111-104 subject to the condition outlined below:
This variance is granted based on the reservoir properties of the West Sak and the Ugnu, namely the
high viscosity and low reservoir pressure (MPSP< 1200 psig).
The condition applies to wells where the West Sak or the Ugnu is not zonally isolated with cement under
regulation 20 AAC 25.030(d)(5) and/or where the OA(below a cement packer) is in hydraulic
communication with the reservoir or injection fluids as a result of West Sak CTD. This includes any wells
in the AOR of a West Sak injector or a newly drilled West Sak CTD well(injector or producer) from a
plugged Kuparuk wellbore.
The condition is the wells must be identified in a single list and the OA pressure tracked and reported to
the AOGCC upon request or when an anomalous OA pressure is detected. The list must include
information on the mechanical integrity of the well specifically the IA and OA pressures and the MIT
history. A complete list in a proposed format is due to the AOGCC by 9/30/19 for review and approval.
This condition is in addition to existing sustained casing pressure (SCP) rules.
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
July 3, 2019
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby submits applications for sundry and permit to drill one lateral out of the KRU
1 R-04 (PTD# 185-178) using the coiled tubing drilling rig, Nabors CDR3-AC.
CTD operations are scheduled to begin on July 22nd, 2019. The objective will be to drill one lateral 1R-104
targeting the West Sak B -sand.
Attached to the permit to drill application are the following documents:
- Permit to Drill Application Form (10-401) for 1 R-104
- Detailed Summary of Operations
- Directional Plan for 1 R-104
- Current wellbore schematic
- Proposed CTD schematic
Attached to the sundry application are the following documents:
- Sundry Application Form (10-403) for 1R-04
- Summary of Operations
- Current wellbore schematic
- Proposed CTD schematic
If you have any questions or require additional information, please contact me at 907-263-4597.
Sincerely,
Shane Germann
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Kuparuk CTD Lateral
1 R-104
Application for Permit to Drill Document
1.
Well Name and Classification ................ ..... ...... .......
...... ..... ........ 2
(Requirements of 20AAC 25.005(1) and 20AAC 25,005(b))— .... .... ...
-- ---.....2
.. 2
""
2.
Location Summa •••••• •""'
"" """
(Requirements of 20 AAC 25.005(c)(2)). .......... ... ..
............. .. ....... .... ...........2
3.
Blowout Prevention Equipment Information.................................................................................
2
(Requirements of 20 AAC 25.005(c)(3))... ----
4.
Drilling Hazards Information and Reservoir Pressure..................................................................
2
..... _..
(Requirements of 20 AA C 25.005 (c) (4)).. ........
.......... _.. . _.,...... _....
5.
Procedure for Conducting Formation Integrity tests...................................................................
2
(Requirements of 20 AAC 25.005(c)(5))... _..... ............... ..._....._._... _......_
6.
Casing and Cementing Program....................................................................................................
3
(Requirements of 20 AAC 25.005(c)(6))...
....._ .......... ..._..............................3
7.
Diverter System Information ..........................................................................................................3
.......... .
(Requirements of 20 AAC 25.005(c)(7))... .... ..... .... ......... _. .................... _...._.......
.................................. .
8.
Drilling Fluids Program..................................................................................................................
3
(Requirements of 20 AAC 25.005(c)(8)).. ..... _....---.......3
9.
Abnormally Pressured Formation Information.............................................................................4
4
(Requirements of 20 AAC 25.005(c)(9)).. ...... _..
.............. ... _........... .. _................
10.
Seismic Analysis.............................................................................................................................
4
(Requirements of 20 AAC 25.005(c)(10))...._ .............
-------
11.
Seabed Condition Analysis............................................................................................................4
(Requirements of 20 AAC 25.005(c)(11)) .................. .. .................
.... _...._... __....._... ..._..........
12.
Evidence of Bonding "
....... 4
""' """ ""
(Requirements of 20 AAC 25.005(c)(12)) ......... .. .... _... ..
......... .................4
13.
Proposed Drilling Program.... ••••.• ••••• •••••
••••..""' """' 4
. ............4
(Requirements of 20 AAC 25.005(c)(13)) ..__.......
4
Summary of Operations...................................................................................................................................................
5
LinerRunning... ................................................................................................................................................................
14.
Disposal of Drilling Mud and Cuttings..........................................................................................
5
_................ 5
(Requirements of 20 AAC 25.005(c)(14))....... .. _.
..... _....... ...................
15.
Directional Plans for Intentionally Deviated Wells.......................................................................
5
(Requirements of 20 AA C 25.050(b))........ ....... ..... .._
................ .... _. _..............._5
16.
Attachments....................................................................................................................................6
Attachment 1: Directional Plans for 1 R-104....................................................................................................................6
Attachment 2: Current Well Schematic for IR -104 ..........................................................................................................6
Attachment 3: Proposed Well Schematic for IR -104 .............................................................................................
Page 1 of 6 July 3, 2019
PTD Application: 1R-104
1. Well Name and Classification
(Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))
The proposed lateral described in this document is 1R-104. The lateral will be classified as "Service - Winj"
wells.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
This lateral will target the B sand package in the West Sak reservoir. See attached 10-401 form for surface and
subsurface coordinates of 1 R-104.
3. Blowout Prevention Equipment Information
(Requirements of 20 AAC 25.005 (c)(3))
Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC.
BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations.
- Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. The
nearest MDT in the West Sak formation was recorded to be 0.45 psi/ft in 2006. The maximum
potential surface pressure in 1 R-104, assuming a gas gradient of 0.1 psi/ft, would be 1180 psi. See
the "Drilling Hazards Information and Reservoir Pressure" section for more details. &
- The annular preventer will be tested to 250 psi and 2,500 psi. 1
4. Drilling Hazards Information and Reservoir Pressure `6 ,05 G5
(Requirements of 20 AAC 25.005 (c)(4)) 3 � '
Reservoir Pressure and Maximum Downhole Pressure (Requirements 20 AAC 25.005 (c)(4)(e)) ✓
The nearest formation pressure gradient measurement in the West Sak was 0.45 psi/ft with an MDT in 2006.
Based on this pressure gradient, the downhole pressure at the window is estimated to be 1517 psi. Reservoir
pressure is not anticipated to have changed since no production or injection has occurred in the West Sak
formation in the vicinity of this project ✓
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
Free gas is not anticipated while drilling the 1R-104 lateral. If gas is detected in the returns the contaminated
mud can be diverted to a storage tank away from the rig.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c))
The major expected risk of hole problems in the 1 R-104 lateral will be lost circulation and differential sticking.
Reduced mud rheology will be used to minimize ECDs and attempt to prevent lost circulation and differential
sticking.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 1 R-104 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity
test is not required.
Page 2 of 6 July 3, 2019
PTD Application: 1R-104
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a
diverter system is not required.
8. Drilling Fluids Program
(Requirements of 20 AAC 25.005(c)(8))
Diagram of Drilling System
A diagram of the Nabors CDR3-AC mud system is on file with the Commission.
Description of Drilling Fluid System
— Window milling operations: Chloride -based PowerVis mud (8.4 ppg)
— Drilling operations: Chloride -based PowerVis mud (8.4 ppg). This mud weight may not hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with NaCl completion fluid in order to provide
formation over -balance while running completions. If pressures higher than anticipated are
encountered NaBr completion fluids may also be used.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases,
the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke.
BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment
Information'.
In the 1R-104 lateral we will target a constant BHP to match formation pressure. The constant BHP target will be
adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased
reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed
for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change
in depth of circulation will be offset with back pressure adjustments.
Page 3 of 6 July 3, 2019
Top
Liner Top
Liner Btm
Liner Top
Liner Btm
Liner Details
Lateral Name
MD
MD
TVDSS
TVDSS
TVD
TVD
psi
psi
Conductor
16"
2-7/8", 6.5#, L-80, HYD 533 slotted;
1 R-104
3524'
11,500'
3281'
3299'
3-1/2", 9.2#, L-80, solid liner in the
1640
670
Surface
9-5/8"
36.0
build
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a
diverter system is not required.
8. Drilling Fluids Program
(Requirements of 20 AAC 25.005(c)(8))
Diagram of Drilling System
A diagram of the Nabors CDR3-AC mud system is on file with the Commission.
Description of Drilling Fluid System
— Window milling operations: Chloride -based PowerVis mud (8.4 ppg)
— Drilling operations: Chloride -based PowerVis mud (8.4 ppg). This mud weight may not hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with NaCl completion fluid in order to provide
formation over -balance while running completions. If pressures higher than anticipated are
encountered NaBr completion fluids may also be used.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases,
the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke.
BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment
Information'.
In the 1R-104 lateral we will target a constant BHP to match formation pressure. The constant BHP target will be
adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased
reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed
for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change
in depth of circulation will be offset with back pressure adjustments.
Page 3 of 6 July 3, 2019
Top
Btm
Burst
Collapse
Category
OD
Weight
Grade
Connection
Top MD
Btm MD
TVD
TVD
psi
psi
Conductor
16"
65.0
H-40
Welded
Surface
115'
Surface
115'
1640
670
Surface
9-5/8"
36.0
J-55
BTC
Surface
4298'
Surface
3927'
3520
2020
Production
7"
--i-55
26.0
BTC
Surface
8427'
Surface
6853'
4980
4320
Liner
4-1/2"
11.6
L-80
BTC
3358'
3686'
3233'
3484'
7780
6350
Tubing
4-1/2"
12.6
L-80
HYD 503
Surface
3367'
Surface
3240'
8430
7500
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a
diverter system is not required.
8. Drilling Fluids Program
(Requirements of 20 AAC 25.005(c)(8))
Diagram of Drilling System
A diagram of the Nabors CDR3-AC mud system is on file with the Commission.
Description of Drilling Fluid System
— Window milling operations: Chloride -based PowerVis mud (8.4 ppg)
— Drilling operations: Chloride -based PowerVis mud (8.4 ppg). This mud weight may not hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with NaCl completion fluid in order to provide
formation over -balance while running completions. If pressures higher than anticipated are
encountered NaBr completion fluids may also be used.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases,
the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke.
BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment
Information'.
In the 1R-104 lateral we will target a constant BHP to match formation pressure. The constant BHP target will be
adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased
reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed
for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change
in depth of circulation will be offset with back pressure adjustments.
Page 3 of 6 July 3, 2019
PTD Application: 1R-104
Pressure at the 1R-104 Window 13534' MD. 3370' TVD) Usina MPD
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AAC 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AAC 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AAC 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
Background
KRU well 1 R-04 was recently worked over and is now equipped with 4-1/2" tubing and 7"
production casing. The CTD sidetrack will utilize one lateral to target the West Sak B -sand to the
south of 1 R-04.
An inner wedge will be set pre -CTD inside the tandem wedge in the 4-1/2" tubing at a planned
kickoff point of 3534' MD
CDR3-AC will use the inner wedge to mill a window in the 4-1/2", 7", and 9-5/8" casing strings.
The 1R-104 lateral will exit through the casing at 3534' MD and TD at 11,500' MD. It will be
completed with 2-7/8" slotted liner from TD up the end of the build and 3-1/2" solid liner from the
end of the build to inside the parent wellbore.
Pre -CTD Work
1. RU E -Line: Drift, set inner wedge at 3534' MD
2. Prep site for Nabors CDR3-AC rig.
Page 4 of 6 July 3, 2019
Pumps On 3 bpm)
Pumps Off
B -sand Formation Pressure 8.65
1517 psi
1517 psi
Mud Hydrostatic 8.4
1472 psi
1472 osi
Annular friction i.e. ECD, 0.035 psi/ft
124 psi
0 psi
Mud + ECD Combined
no chokepressure)
1596 psi
Overbalanced -79psi)
1472 psi
Underbalanced -45psi)
Target BHP at Window 8.65
1517 psi
1517 si
Choke Pressure Required to Maintain
Target BHP
0 psi
45 psi
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AAC 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AAC 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AAC 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
Background
KRU well 1 R-04 was recently worked over and is now equipped with 4-1/2" tubing and 7"
production casing. The CTD sidetrack will utilize one lateral to target the West Sak B -sand to the
south of 1 R-04.
An inner wedge will be set pre -CTD inside the tandem wedge in the 4-1/2" tubing at a planned
kickoff point of 3534' MD
CDR3-AC will use the inner wedge to mill a window in the 4-1/2", 7", and 9-5/8" casing strings.
The 1R-104 lateral will exit through the casing at 3534' MD and TD at 11,500' MD. It will be
completed with 2-7/8" slotted liner from TD up the end of the build and 3-1/2" solid liner from the
end of the build to inside the parent wellbore.
Pre -CTD Work
1. RU E -Line: Drift, set inner wedge at 3534' MD
2. Prep site for Nabors CDR3-AC rig.
Page 4 of 6 July 3, 2019
PTD Application: 1R-104
Rig Work
1. MIRU Nabors CDR3-AC rig using 2-5/8" coil tubing. NU 7-1/16" BOPE, test.
2. 1R-104 Lateral (West Sak B -sand -South)
a. Mill 3.80" window at 3534' MD
b. Drill 4-1/4" bi-center lateral to TD of 11,500' MD
c. Run 2-7/8" slotted liner and 3-1/2" solid liner with deployment sleeve from TD to 3524' MD
3. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Rig Work
4. Return well to production.
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the
Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the
Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator.
This pressure control equipment listed ensures reservoir pressure is contained during the deployment process.
During BHA deployment, the following steps are observed.
- Initially the swab valve on the tree is closed to isolate reservoir pressure. The lubricator is installed on the
BOP riser with the BHA inside the lubricator.
- Pressure is applied to the lubricator to equalize across the swab valve. The swab valve is opened and the
BHA is lowered in place via slick -line.
- When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir
pressure via the annulus. A closed ball valve and check valve isolate reservoir pressure internal to the
BHA. Slips on the deployment ram prevent the BHA from moving when differential pressure is applied.
The lubricator is removed once pressure is bled off above the deployment ram.
- The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to
the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is
made up to the riser, annular pressure is equalized, and the deployment ram is opened. The BHA and
coiled tubing are now ready to run in the hole.
During BHA undeployment, the steps listed above are observed, only in reverse.
Liner Running
- The 1 R-104 lateral will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids"
section for more details.
- While running liner, a joint of 2-5/8" non -slotted tubing will be standing by for emergency deployment. A
floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with
this emergency joint on every slotted liner run. The 2-5/8" rams will provide secondary well control
while running 2-3/8" liner.
14. Disposal of Drilling Mud and Cuttings
(Requirements of 20 AA 25.005(c)(14))
• No annular injection on this well.
• All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal.
• Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18
or 1B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable.
• All wastes and waste fluids hauled from the pad must be properly documented and manifested.
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200).
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
Page 5 of 6 July 3, 2019
PTD ADDlication: 1R-104
- The Applicant is the only affected owner.
- Please see Attachment 1: Directional Plans
- Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
- MWD directional and gamma ray will be run over the entire open hole section.
- Distance to Nearest Property Line (measured to KPA boundary at closest point)
Lateral Name Distance
I 1 R-104 17,058'
- Distance to Nearest Well within Pool
Lateral Name
Distance
Well
IR -104
744'
1 1 R-05
16. Attachments
Attachment 1: Quarter Mile Injection review for IR -104
Attachment 2: Directional Plan for the 1R-104 lateral
Attachment 3: Current Well Schematic for 1R-104
Attachment 4: Proposed CTD Well Schematic for the 1R-104 lateral
Page 6 of 6 July 3, 2019
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Well KRU XX•XX Nabors COR3-AC: 4 -Ram BOP Configuration Date June 26, 2016
2-5/8" Coiled Tubing and 3-1/8" BHA
Quick Test Sub to Ot
Top of 7" Otis
Distances from top o
Excluding quick -test
Top of Annular
Cc Annular
Bottom Annular Flan
Ct Blind/Shears
Ci 2-518" Combi s
Ci 3-118" Combi's
CL VBR's
CL of Top
Top of Swc
CL Swab 1
Flow Tee
CL SSV
CL Master
LDS
Groun<
Tree Size 4 1/16
ine
ConocoPhillips
_ConocoPhillips Export Company
Kuparuk River Unit
Kuparuk 1R Pad
1 R-04
1 R-104
Plan: 1 R-104 wp03
Standard Planning Report
25 March, 2019
BA UGHES
a GE company
ConocoPhillips BA ER
ConocoPhillips Planning Report IUGHES
a GE company
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kupamk River Unit
Site:
Kupamk 1R Pad
Well:
1R-04
Wellbore:
1R-104
Design:
1 R-104 wp03
Local C"rdinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 R-04
Mean Sea Level
1 R-04 Q 82.00usft (1 R-04)
True
Minimum Curvature
Project
Kupawk River Unit, North Slope Alaska, United States
Map System:
Geo Datum:
Map Zone:
US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
NAD 1927 (NADCON CONUS) Using Well Reference Point
Alaska Zone 04 Using geodetic scale factor
site
Kupamk 1R Pad
Site Position:
From:
Position Uncertainly:
Map
0.00 usft
Northing:
Easdng:
Slot Radius:
5,991,050.01 usft Latitude:
539,829.93 usft Longitude:
0.000in Grid Convergence:
70" 23' 11.370 N
149° 40' 33.803 W
0.31 °
Well
1 R-04
Well Position
Position Uncertainty
+N/ -S 0.00 usft
+EI -W 0.00 usft
0.00 usft
Northing:
Easting:
Wellhead Elevation:
5,990,870.26 usft Latitude:
539,829.77 pall Longitude:
usft Ground Level:
70° 23'9.602 N
149'40'33+836 W
0.00 usft
Wellbore
1 R-104
Magnetics
Model Name
Sample Date
Declination Dip Angie Field Strength
(°I (°)Tj
BGGM2018
1/1/2019
16.82 80.91
57434._
Design
1R-104wp03
Audit Notes:
Version:
Phase: PLAN
Te On Depth: 3,500.00
Vertical Section: Depth From (TVD) -NIS +El -W Direction
(usft) (usft) (usft) (°)
0.00 0.00 0.00 180.00
3/252019 2:56:42PM Page 2 COMPASS 5000.14 Build 85D
ConocoPhillips BA, KER
ConocoPhillips Planning Report �j IGHES
BAT
.GE..ny
Database:
EDT 14 Alaska Production
Local Coordinate Reference:
Well 1R-04
Company:
_ConocoPhillips Export Company
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1R-04 @ 82.00usft (1R-04)
Site:
Kuparuk 1R Pad
North Reference:
True
Well:
1 R-04
Survey Calculation Method:
Minimum Curvature
Wellbore:
1R-104
Azimuth
System
Design:
1 R-104 wp03
Rate
Rate
Plan Sections
Measured
TVD Below
Dogleg
Build
Tum
Depth
Inclination
Azimuth
System
+N/ -S
+E/ -W
Rate
Rate
Rate
TFO
lush)
V)
V)
(usft)
(usft)
(usft)
(-1100usft)
(°/100usft)
l'/100usft)
V) Target
3,500.00
39.53
163.45
3,262.05
-584.30
153.90
0.00
0.00
0.00
0.00
3,540.00
40.28
163.82
3,292.73
-608.92
161.13
1.97
1.88
0.93
17.70
3,575.00
49.03
163.82
3,317.61
-632.52
167.98
25.00
25.00
0.00
0.00
3,779.85
90.00
163.82
3,387.78
-812.91
220.32
20.00
20.00
0.00
0.00
3,900.00
90.00
155.41
3,387.78
-925.44
262.14
7.00
0.00
-7.00
-90.00
4,300.00
90.00
183.41
3,387.78
-1,314.72
334.92
7.00
0.00
7.00
90.00
4,600.00
90.00
162.41
3,387.78
-1,610.77
371.75
7.00
0.00
-7.00
-90.00
5,000.00
90.00
190.41
3,387.78
-2,006.02
396.55
7.00
0.00
7.00
90.00
5,200.00
90.24
176.41
3,387.35
-2,205.17
384.68
7.00
0.12
-7.00
-89.00
5,600.00
90.68
204.41
3,384.06
-2,594.67
313.12
7.00
0.11
7.00
89.00
6,000.00
90.60
176.41
3,379.48
-2,984.16
241.58
7.00
-0.02
-7.00
-90.00
6,300.00
90.20
197.40
3,377.34
-3,280.31
205.71
7.00
-0.13
7.00
91.00
6,700.00
89.71
169.41
3,377.64
-3,675.64
182.18
7.00
-0.12
-7.00
-91.00
7,100.00
90.21
197.40
3,377.90
-4,070.97
158.65
7.00
0.13
7.00
89.00
7,500.00
90.19
169.40
3,376.46
-4,466.30
135.14
7.00
-0.01
-7.00
-90.00
7,900.00
90.17
197.40
3,375.19
-4,861.63
111.62
7.00
-0.01
7.00
90.00
8,300.00
90.15
169.40
3,374.07
-5,256.97
88.11
7.00
0.00
-7.00
-90.00
8,700.00
89.66
197.40
3,374.75
-5,652.30
64.61
7.00
-0.12
7.00
91.00
9,100.00
92.05
169.50
3,368.68
-6,047.57
40.76
7.00
0.60
-6.98
-85.00
9,500.00
91.81
197.51
3,354.96
-6,442.62
16.57
7.00
-0.06
7.00
90.00
9,900.00
91.59
169.50
3,342.85
-6,837.72
-7.63
7.00
-0.05
-7.00
-90.00
10,300.00
91.41
197.51
3,332.16
-7,232.87
-31.83
7.00
-0.05
7.00
90.00
10,700.00
91.71
169.50
3,321.05
-7,628.01
-56.04
7.00
0.08
-7.00
-89.00
11,100.00
91.51
197.51
3,309.57
-8,023.13
-80.25
7.00
-0.05
7.00
90.00
11,500.00
91.33
169.50
3,299.43
-8,418.29
-104.46
7.00
-0.04
-7.00
-90.00
3/25/2019 2: 56 42P Page 3 COMPASS 5000.14 Build 85D
Planned Survey
ConocoPhillips
ConocoPhillips
Planning Report
UGHES
aGEwmpany
Database: EDT 14 Alaska Production
Local Coordinate Reference:
Well 1R-04
Company: _ConocoPhillips Export Company
TVD Reference:
Mean Sea Level
Project Kuparuk River Unit
MD Reference:
iR-04 @! 82.00usft (1R-04)
Site: Kuparuk 1R Pad
North Reference:
True
Well: 1R-04
Survey Calculation Method:
Minimum Curvature
Wellbore: 1R-104
System
+N/ -S
Design: 1 R-104 wp03
Section
Rate
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination
Azimuth
System
+N/ -S
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(_)
(_)
(usft)
(usft)
(usft)
(usft)
('/100usft)
V)
(usft)
(usft)
3,500.00
39.53
163.45
3,262.05
-584.30
153.90
584.30
0.00
0.00
5,990,286.85
539,986.77
TIP
3,540.00
40.28
163.82
3,292.73
-608.92
161.13
608.92
1.97
17.70
5,990,262.27
539,994.13
KOP
3,575.00
49.03
163.82
3,317.61
-632.52
167.98
632.52
25.00
0.00
5,990,238.71
540,001.10
End 25
dls, Start 20
ells
3,600.00
54.03
163.82
3,333.15
-651.31
173.43
651.31
20.00
0.00
5,990,219.94
540,006.65
3,700.00
74.03
163.82
3,376.72
-737.22
198.36
737.22
20.00
0.00
5,990,134.18
540,032.03
3,779.85
Woo
163.82
3,387.78
-812.91
220.32
812.91
20.00
0.00
5,990,058.61
540,054.39
End 20
dis, Start 7 ells
3,800.00
90.00
162.41
3,387.78
-832.20
226.17
832.20
7.00
-90.00
5,990,039.36
540,060.35
3,900.00
90.00
155.41
3,387.78
-925.44
262.14
925.44
7.00
-90.00
5,989,946.32
540,096.80
5
4,000.00
90.00
162.41
3,387.78
-1,018.68
298.10
1,018.68
7.00
90.00
5,989,853.28
540,133.26
4,100.00
90.00
169.41
3,387.78
-1,115.61
322.43
1,115.61
7.00
90.00
5,989,756.49
540,158.10
4,200.00
90.00
176.41
3,387.78
-1,214.79
334.76
1,214.79
7.00
90.00
5,989,657.39
540,170.96
4,300.00
90.00
183.41
3,387.78
-1,314.72
334.92
1,314.72
7,00
90.00
5,989,557.47
540,171.65
6
4,400.00
90.00
176.41
3,387.78
-1,414.66
335.08
1,414.66
7.00
-90.00
5,989,457.54
540,172.34
4,500.00
90.00
169.41
3,387.78
-1,513.84
347.42
1,513.84
7.00
-90.00
5,989,358.44
540,185.21
4,600.00
90.00
162.41
3,387.78
-1,610.77
371.75
1,610.77
7.00
-90.00
5,989,261.65
540,210.05
7
4,700.00
90.00
169.41
3,387.78
-1,707.70
396.08
1,707.70
7.00
90.00
5,989,164.86
540,234.89
4,800.00
90.00
176.41
3,387.78
-1,806.87
408.41
1,806.87
7.00
90.00
5,989,065.77
540,247.76
4,900.00
90.00
183.41
3,387.78
-1,906.81
408.57
1,906.81
7.00
90.00
5,988,965.84
540,248.45
5,000.00
90.00
190.41
3,387.78
-2,006.02
396.55
2,006.02
7.00
90.00
5,988,866.58
540,236.95
8
5,100.00
90.12
183.41
3,387.67
-2,105.23
384.52
2,105.23
7.00
-89.00
5,988,767.31
540,225.46
5,200.00
90.24
176.41
3,387.35
-2,205.17
384.68
2,205.17
7.00
-89.01
5,988,667.39
540,226.15
9
5,300.00
90.36
183.41
3,386.83
-2,305.11
384.83
2,305.11
7.00
89.00
5,988,567.46
540,226.84
5,400.00
90.48
190.41
3,386.09
-2,404.32
372.81
2,404.32
7.00
89.04
5,988,468.20
540,215.34
5,500.00
90.58
197.41
3,385.17
-2,501.32
348.79
2,501.32
7.00
89.09
5,988,371.08
540,191.84
5,600.00
90.68
204.41
3,384.06
-2,594.67
313.12
2,594.67
7.00
89.15
5,988,277.55
540,156.67
10
5,700.00
90.68
197.41
3,382.87
-2,688.02
277.46
2,688.02
7.00
-90.00
5,988,164.02
540,121.51
5,800.00
90.66
190.41
3,381.70
-2,785.02
253.44
2,785.02
7.00
-90.08
5,988,086.90
540,098.01
5,900.00
90.64
183.41
3,380.56
-2,884.23
241.42
2,884.23
7.00
-90.17
5,987,987.64
540,086.52
6,000.00
90.60
176.41
3,379.48
-2,984.16
241.58
2,984.16
7.00
-90.24
5,987,887.72
540,087.21
11
6,100.00
90.48
183.41
3,378.54
-3,084.09
241.74
3,084.09
7.00
91.00
5,987,787.80
540,087.91
6,200.00
90.34
190.41
3,377.82
-3,183.30
229.73
3,183.30
7.00
91.07
5,987,688.54
540,076.42
6,300.00
90.20
197.40
3,377.34
-3,280.31
205.71
3,280.31
7.00
91.12
5,987,591.41
540,052.93
12
6,400.00
90.08
190.41
3,377.09
-3,377.32
181.70
3,377.32
7.00
-91.00
5,987,494.29
540,029.43
6,500.00
89.96
183.41
3,377.06
-3,476.53
169.68
3,476.53
7.00
-91.02
5,987,395.02
540,017.94
6,600.00
89.83
176.41
3,377.24
-3,576.47
169.84
3,576.47
7.00
-91.02
5,987,295.10
540,018.64
6,700.00
89.71
169.41
3,377.64
-3,675.64
182.18
3,675.64
7.00
-91.01
5,987,196.00
540,031.50
13
6,800.00
89.84
176.41
3,378.04
-3,774.81
194.52
3,774.81
7.00
89.00
5,987,096.91
540,044.37
6,900.00
89.96
183.41
3,378.21
-3,874.75
194.68
3,874.75
7.00
88.97
5,986,996.98
540,045.06
7,000.00
90.09
190.41
3,378.17
-3,973.96
182.67
3,973.96
7.00
88.96
5,986,897.72
540,033.58
3252019 2:56.42PM Page 4 COMPASS 5000.14 Build 85D
ConocoPhillips
ConocoPhillips
Planning Report
'T�UGHES
.GEcmnpany
Database:
Company:
Project
Site:
Well:
Wellbore:
Design:
EDT 14 Alaska Production
_ConocoPhillips Export Company
Kuparuk River Unit
Kupamk 1 R Pad
1R-04
111-104
1R-104 WP03
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1R-04
Mean Sea Level
1R-04 @ 82.00usft (1R-04)
True
Minimum Curvature
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Azimuth
Map
Northing
Map
Easting
Depth
Inclination
Azimuth
System
-NIS
+EI -W
Section
(usft)
Rate
(°Moousft)
(°)
(usft)
(usft)
(usft)
(°)
(°)
(usft)
(usft)
(usft)
197,40
3,377.90
4,070.97
158.65
4,070.97
7.00
88.96
5,986,800.59
540,010.08
7,100.00
90.21
14
90.21
190.40
3,377.53
4,167.98
134.64
4,167.98
7.00
-90.00
5,986,703.46
539,986.59
7,200.00
183.40
3,377.16
-4,267.19
122,62
4,267.19
7.00
-90.03
5,986,604.20
539,975.10
7,300.00
90.21
176.40
3,376.81
-4,367.13
122.79
4,367.13
7.00
-90.05
5,986,504.27
539,975.80
7,400.00
9020
3,376.46
4,466.30
135,14
4,466.30
7.00
-90.08
5,986,405.18
539,988.67
7,500.00
90.19
169.40
1b
90.19
776.40
3,376.13
4,565.48
147.48
4,565.48
7.00
90.00
5,986,306.08
540,001.55
7,600.00
90.18
183.40
3,375.81
4,665.41
147.65
4,665.41
7.00
90.02
5,986,206.16
540,002.25
7,700.00
90.18
190.40
3,375.49
4,764.63
135.64
4,764.63
7.00
90.05
5,986,106.89
539,990.76
7,800.00
197.40
3,375.19
4,861.63
111.62
4,861.63
7.00
90.07
5,986,009.77
539,967.27
7,900.00
90.17
16
190A0
3,374.90
4,958.64
87.61
4,958.64
7.00
-90.00
5,985,912.64
539,943.77
8,000.00
90.17
3,374.62
-5,057.86
75.59
5,057.86
7.00
-90.02
5,985,813.37
539,93228
8,100.00
90.16
183.40
176.40
3,374.34
-5,157.79
75.76
5,157.79
7.00
-90.04
5,985,713.45
539,932.99
8,200.00
90.16
3,374.07
-5,256.97
88.11
5,256.97
7.00
-90.06
5,985,614.35
539,945.86
8,300.00
90.15
169.40
17
90.02
176.40
3,373.92
-5,356.14
100.45
5,356.14
7.00
91.00
5,985,51526
539,958.74
8,400.00
89.80
183.40
3,373.99
-5,456.08
100.62
5,456.08
7.00
91.01
5,985,415.33
539,959.44
8,500.00
3,374.27
-5,555.29
88.62
5,555.29
7.00
91.01
5,985,316.07
539,947.96
8,600.00
89.76
190.40
197.40
3,374.75
-5,652.30
64.61
5,652.30
7.00
90.99
5,985,218.94
539,924.47
8,700.00
89.66
18
90.27
190.43
3,374.81
-5,749.30
40.58
5,749.30
7.00
-85.00
5,985,121.82
539,900.96
8,800.00
3,373.81
-5,848.51
28.50
5,846.51
7.00
-85.00
5,985,022.56
539,889.42
8,900.00
90.88
183.45
-5,948.42
28.57
5,948.42
7.00
-85.07
5,984,922.66
539,890.01
9,000.00
91.47
176.48
3,371.75
40.76
6,047.57
7.00
-85.21
5,984,823.59
539,902.73
9,100.00
92.05
169.50
3,368.68
-6,047.57
19
9,200.00
92.03
176.50
3,365.12
-6,146.69
52.94
6,146.69
7.00
90.00
5,984,724.54
539,915.43
539,915.96
9,300.00
91.98
183.50
3,361.61
-6,246.57
52.93
6,246.57
7.00
90.25
5,984,624.67
5,984,525.49
539,904.30
9,400.00
91.91
190.51
3,358.21
-6,345.71
40.75
6,345.71
7.00
90.50
90.73
5,984,428.45
539,880.64
9,500.00
91.81
197.51
3,354.96
-6,442.62
16.57
6,442.62
7.00
20
91.79
190.51
3,351.82
-6,539.54
-7.62
6,539.54
7.00
-90.00
5,984,331.42
539,856.98
9,600.00
91.75
183.50
3,348.72
-6,638.68
-19.80
6,638.68
7.00
-90.22
5,984,232.22
539,845.32
9,700.00
91.69
176.50
3,345.72
-6,738.57
-19.81
6,738.57
7.00
-90.44
5,984,132.34
539,645.85
9,800.00
3,342.85
-6,837.72
-7.63
6,837.72
7.00
-90.65
5,984,033.26
539,858.55
9,900.00
91.59
169.50
21
91.58
176.50
3,340.08
-6,936.88
4.54
6,936.88
7.00
90.00
5,983,934.18
539,87125
10,000.00
91.55
183.50
3,337.34
-7,036.78
4.53
7,036.78
7.00
90.19
5,983,834.30
539,871.78
10,100.00
190.51
3,334.69
-7,135.94
-7.65
7,135.94
7.00
90.39
5,983,735.08
539,860.12
10,200.00
91.49
3,332.16
-7,232.87
-31.83
7,232.87
7.00
90.57
5,983,638.03
539,836.46
10,300.00
91.41
197.51
22
91.52
190.51
3,329.60
-7,329.81
-56.02
7,329.81
7.00
-89.00
5,983,540.98
539,812.79
10,400.00
183.51
3,326.87
-7,428.96
-68.20
7,428.96
7.00
-89.18
5,983,441.77
539,801.13
10,500.00
91.61
176.50
3,324.01
-7,528.86
-68.21
7,528.86
7.00
-89.37
5,983,341.89
539,801.66
10,600.00
91.67
169.50
3,321.05
-7,628.01
-56.04
7,628.01
7.00
-89.57
5,983,242.81
539,814.36
10,700.00
91.71
23
91.70
176.50
3,318.07
-7,727.16
-43.87
7,727.16
7.00
90.00
5,983,143.74
539,827.06
10,800.00
91.66
183.51
3,315.13
-7,827.05
43.88
7,827.05
7.00
9021
5,983,043.86
539,827.58
10,900.00
190.51
3,312.28
-7,926.20
-56.06
7,926.20
7.00
90.41
5,982,944.65
539,815.92
11,000.00
91.60
3,309.57
-8,023.13
-80.25
8,023.13
7.00
90.61
5,982,847.60
539,792.26
11,100.00
91.51
197.51
24
Page 5
COMPASS
5000.14 Build 850
3252019 2:56:42PM
Measured
Vertical
ConocoPhillips
BAT
BA
ER
ConocoPhillin s
SEI -W
Planning Report
(usft)
(usft)
GEmmpany
(usft)
r
3,500.00
3,262.05
-584.30
153.90
TIP
Database: EDT 14 Alaska Production
3,292.73
Local Coordinate Reference:
Well 1R-04
KOP
3,575.00
Company: _ConocoPhillips Export Company
-632.52
TVD Reference:
Mean Sea Level
3,779.85
3,387.78
Project: Kuparuk River Unit
220.32
MD Reference:
1R-04 @ 82.00usft (1R-04)
3,387.78
Site: Kuparuk 1 R Pad
262.14
North Reference:
True
3,387.78
-1,314.72
Well: 1R-04
6
Survey Calculation Method:
Minimum Curvature
-1,610.77
371.75
Wellbore: 1R-104
5,000.00
3,387.78
-2,006.02
396.55
8
Design: 1 R-104 wp03
3,387.35
-2,205.17
384.68
9
5,600.00
Planned Survey
-2,594.67
313.12
10
6,000.00
3,379.48
Measured TVD Below
241.58
Vertical
Dogleg Toolface
Map
Map
Depth Inclination Azimuth System
♦N/S
+E/ -W Section
Rate Azimuth
Northing
Easting
(usft) Vl (_) (usft)
(waft)
(usft) (usft)
("1100usft) V)
(usft)
(usft)
11,200.00 91.50 190.51 3.306.93
-8,120.06
.104.43 8,120.06
7.00 -90.00
5,982,750.55
539,768.591
11,300.00 91.47 183.51 3,304.34
-8,219.22
-116.62 8,219.22
7.00 -90.18
5,982,651.34
539,756.93
11,400.00 91.41 176.50 3,301.83
-8,319.13
-116.63 8,319.13
7.00 -90.37
5,982,551.45
539,757.46
11,500.00 91.33 169.50 3,299.43
-8,418.29
-104.46 8,418.29
7.00 -90.54
5,982,452.36
539,770.16
Planned TD at 11500.00
9,500.00
3,354.96
-6,442.62
16.57
20
9,900.00
3,342.85
-6,837.72
-7.63
21
10,300.00
nim' tsis
Casing Points
-7,232.87
-31.83
22
10,700.00
3,321.05
Measured Vertical
-56.04
23
Casing
Hole
-8,023.13
Depth Depth
24
11,500.00
Diameter
Diameter
-104.46
(usft) (waft)
Name
(in)
(in)
11,500.00 3,299.43 23/8"
2.375
3.000
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
-NI-S
SEI -W
(usft)
(usft)
(usft)
(usft)
Comment
3,500.00
3,262.05
-584.30
153.90
TIP
3,540.00
3,292.73
-608.92
161.13
KOP
3,575.00
3,317.61
-632.52
167.98
End 25 dis, Start 20 dls
3,779.85
3,387.78
-812.91
220.32
End 20 dis, Start 7 dis
3,900.00
3,387.78
-925.44
262.14
5
4,300.00
3,387.78
-1,314.72
334.92
6
4,600.00
3,387.78
-1,610.77
371.75
7
5,000.00
3,387.78
-2,006.02
396.55
8
5,200.00
3,387.35
-2,205.17
384.68
9
5,600.00
3,384.06
-2,594.67
313.12
10
6,000.00
3,379.48
-2,984.16
241.58
11
6,300.00
3,377.34
-3,280.31
205.71
12
6,700.00
3,377.64
-3,675.64
182.18
13
7,100.00
3,377.90
-4,070.97
158.65
14
7,500.00
3,376.46
-4,466.30
135.14
15
7,900.00
3,375.19
4,861.63
111.62
16
8,300.00
3,374.07
-5,256.97
88.11
17
8,700.00
3,374.75
-5,652.30
64.61
18
9,100.00
3,368.68
-6,047.57
40.76
19
9,500.00
3,354.96
-6,442.62
16.57
20
9,900.00
3,342.85
-6,837.72
-7.63
21
10,300.00
3,332.16
-7,232.87
-31.83
22
10,700.00
3,321.05
-7,628.01
-56.04
23
11,100.00
3,309.57
-8,023.13
-80.25
24
11,500.00
3,299.43
-8,418.29
-104.46
Planned TD at 11500.00
3/25/2019 2:56:42PM Page 6 COMPASS 5000.14 Build 85D
ConocoPhillips
ConocoPhillips Anticollision Report �I ER
aGEcompany
Company:
ConowPhillips Alaska lnc Kupawk
Project:
Kuparuk River Unit -2
Reference Site:
Kupawk 1R Pad
Site Error.
0.00 usft
Reference Well:
iR-04
Well Error:
0.00 usft
Reference Wellbore
1R-104
Reference Design:
1R-104wp03
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1 R-04
1R-04 @ 82.00usft (IR-04)
1 R-04 Q 82.00usft (1 R-04)
True
Minimum Curvature
2.00 sigma
EDT 14 Alaska Production
Offset Datum
Reference 1 R-104 wp03
Filter type:
NO GLOBAL FILTER: Using user defined selection 8 filtering
criteria
Interpolation Method:
MD Interval 25.00usft
Error Model:
ISCWSA
Depth Range:
3,500.0010 11,500.00usft
Sun Method:
Tray. Cylinder North
Results Limited by:
Maximum center -center distance of 1,341.80 usft
Error Surface:
Combined Pedal Curve
Warning Levels Evaluated at 2.79 Sigma
Casing Method:
Added to Error Values
Survey Tool Program Date 3/2512019
From TO
(usft) (usft) Survey (Wellbore) Toot Name Description
100.00 3,500.00 IR-04(lR-04)11,500.00 GCT -MS Schlumberger GCT multishot
3,500.00 1R-104 wp03(1 R-104) MWD MWD - Standard
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
lusitl
(usftl
(usft)
(usft)
Kuparuk 1R Pad
1 R-01 -1 R-01 - i R-01
3,510.40
3,900.00
992.16
931.91
16.469 CC, ES, SF
1R -01 -1R -01A -1R -01A
3,510.40
3,900.00
992.16
931.91
16.469 CC, ES, SF
1R -01 -1R -01B -1R -01B
3,510.40
3,900.00
992.16
931.91
16.469 CC, ES, SF
1 R-01 - 1 R-011311 - 1 R-01BL1
3,510.40
3,900.00
992.16
931.91
16.469 CC, ES, SF
1R-01-1R-01BL1-01-1R-01BL1-01
3,510.40
3,900.00
992.16
931.91
16.469 CC, ES, SF
IR-01-1R-01BL1-01PB1-1R-01 311-01 PB1
3,510.40
3,900.00
992.16
931.91
16.469 CC, ES, SF
1R-01-iR-01BL1 PB1-1R-01 BI -1 PB1
3,510.40
3,900.00
992.16
931.91
16.469 CC, ES, SF
IR -01 - 1R-011-1 - 1R-01 L1_wp00 (4 dls)
10,800.00
11,675.00
819.28
509.31
2.643 Normal Operations, CC
1R -01 -1R -011-7-1R-01 L1_wp00(4 dls)
10,817.50
11,700.00
819.65
508.66
2.636 Normal Operations, ES
IR -01-1R-01 Ll -1R-01 L1_wp00(4 dls)
10,842.39
11,750.00
822.91
510.12
2.631 Normal Operations, SF
1R -01 -Plan: IR-01C-iR-01Cwp02
3,508.53
3,900.00
990.64
930.43
16.451 CC, ES, SF
1R -02 -1R -02-1R-02
3,950.00
3,575.00
1,325.84
1,277.65
27.512 CC, ES
1R -02 -1R -02-1R-02
3,975.00
3,675.00
1,340.63
1,290.92
26.971 SF
1R-03-1R-03-iR43
3,511.29
3,900.00
856.23
805.74
16.960 CC, ES, SF
1R -03 -1R -03A -1R -03A
3,511.29
3,900.00
856.23
805.74
16.960 CC, ES, SF
1R-03-1R-03APBI-1R-03APBi
3,511.29
3,900.00
856.23
805.74
16.960 CC, ES, SF
1 R-04 - 1 R-04 - 1 R-04
3,810.15
3,900.00
170.55
165.08
31.193 CC, ES, SF
1R -05 -1R -05-1R-05
3,516.60
3,575.00
744.16
683.52
12.272 CC, ES, SF
1 R-26 - i R-26 - 1 R-26
Out of range
1 R-26 - i R-26 - 1 R-26
Out of range
1 R-26 - 1 R-26 - 1 R-26
Out of range
1R-26 - 1R-26LI - 1R-26L1_wp00 (4 dial
Out of range
1R-26 - iR-26L7 - 1R-26L7_wp00 (4 dls)
Out of range
1 R-26 -1 R-2611 - 1 R-26L1_wp00 (4 dls)
Out of range
1 R-27 - 1 R-27 - 1 R-27
Out of range
1 R-27 - 1 R-27 - 1 R-27
Out of range
1 R-27 - 1 R-27 - i R-27
Out of range
1 R-29 - 1 R-29 - 1 R-29
Out of range
1 R-29 - 1 R-29 - 1 R-29
Out of range
1 R-29 -1 R-29 - 1 R-29
Out of range
1 R-29 - 1 R -29L1 - 1 R-291-1
Out of range
1 R-29 - 1 R-2911 - 1 R-2911
Out of range
1 R-29 - i R -29L1 - 1 R-2911
Out of range
1 R-29 - 1 R -29L7-01 - 1 R-291-1-01
Out of range
1 R-29 - 1 R -29L7-01 - 1 R-2917-01
Out of range
1 R-29 - 1 R-2911-01 - 1 R -29L1-01
Out of range
CC - Min centre to center distance or wvergent point, SF - min separation factor, ES - min ellipse separation
3/2WO19 11:15:40AM Page 2 COMPASS 5000.14 Build 85D
�. ConocoPhillips
ConocoPhillips Anticollision Report RI UGHES
a GEmmpany
Company:
ConocoPhillips Alaska lnc_Kuparuk
Project:
Kuparuk River Unit -2
Reference Site:
Kuparuk 1R Pad
Site Error:
0.00 usft
Reference Well:
1R-04
Well Error:
0.00 usft
Reference Wellbore
1R-104
Reference Design:
1 R-104 wp03
Summary
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1 R-04
1 R-04 @ 82.00usft (1 R-04)
1 R-04 @ 82.00usft (1 R-04)
True
Minimum Curvature
2.00 sigma
EDT 14 Alaska Production
Offset Datum
Offset Design
Reference
Offset
Distance
Measured
Measured
Between Between
Separation Warning
Site Name
Depth
Depth
Centres Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
(usft)
(usft) (usft)
Kuparuk 1R Pad
Offset Well Erron 0.00 usft
Reference
1 R-29 - 1 R -29L1-02 - 1 R -29L1-02
semi Maior
Axis
Out of range
1 R-29 - 1 R-29Li-02 - 1 R-29Li-02
Distance
Out of range
1 R-29 - 1 R-291-1-02 - 1 R-2911-02
Measured
Vertical
Measured
Out of range
1 R-29 - i R-2911-03 - 1 R -29L1-03
Offset
A mmM1
Offset Wellbore
Out of range
I R-29 - 1 R -29L1-03 - 1 R-2911-03
Between
Minimum
Separation
Out of range
I R-29 - 1 R-291-7-03 - i R -29L7-03
Depth
Depth
Dumb
Out of range
1 R-29 - 1 R-29L7-03PB1 - 1 R-2911-03PB1
from Norp
-NIS
-It4w
Out of range
1 R-29 -1 R-2911-03PB1 - 1 R-29L1-03PB1
Separation
Factor
Out of range
1R-29- 1R-291-1-03PBi - 1 R-291-1 -03PB1
lural
(usft)
(psft)
Out of range
Kuparuk UGNU
(ush)
(usft)
(usft?
(mft)
Plan East Ugnu # 1 - Ugnu #1 - Plan #2
3,510A0
Out of range
Offset Design
Kuparuk 1R Pad-
1R-01 -1R-01 - 1R
-Cl
Offset site Error: 600 usft
Survey program: 100.GCT-M6
Offset Well Erron 0.00 usft
Reference
Offset
semi Maior
Axis
Distance
Measured
Vertical
Measured
Vertical
Reference
Offset
A mmM1
Offset Wellbore
Centre
aeMeen
Between
Minimum
Separation
warning
Depth
Depth
Depth
Dumb
from Norp
-NIS
-It4w
Carries
Ellipses
Separation
Factor
(usft)
luso(
lural
(usft)
(psft)
(.an)
(1)
(ush)
(usft)
(usft?
(mft)
tusk)
3,510A0
3.352.06
3,900.00
353267
30.18
34.48
57.00
-11283
1006.3a
992.16
931.91
60.24
16469 CC,
ES, SF
3.52500
3,383.27
3,92500
3,550.03
3026
34.75
57.13
-119.01
1,022,93
1,006.22
945.79
60.43
18.650
3,$41.61
3,375.95
3.950.00
3,567.38
30.31
35.02
57.25
-IM.78
1039.53
1.020.37
959.73
60.64
16827
3,5$0.00
3,30222
3,975.00
3.584.73
30.33
3530
57.29
-133.73
1,056.13
1.034.71
974.03
60.68
12052
3.560.42
3.389.70
4,000.00
3,60200
30.34
35.57
57.30
-140.80
1,072.73
1,049.28
988.55
60.73
17.277
3,575.00
3.399.61
4,025.00
3,819.43
30.35
35.84
57.20
.147.61
1.089.34
1,064.12
1.003.27
60.85
17.487
3,57500
3.399.61
4,050.00
3,836]9
30.35
30.12
57.20
-154.54
1105.94
1,079.11
1.018.39
6073
17."0
3.587.46
3,407.57
4,07500
3,654,16
30.36
36.40
57.09
-161.47
1,122.54
1.094.32
1,033.53
60.80
18.000
3.600.00
3,415.15
4.100.00
3,671.53
30.38
36.67
56.96
-168.38
1,139.13
1.10974
1,040.87
60.87
18.230
3,600.00
3,415.15
4,125.00
3.680.91
30.30
thugs
56.80
-175.31
1,16571
1125.34
1,064.61
60.74
19.526
3,614.55
3.423.40
4,150.00
3.706.31
30.41
37.23
56.61
-162.25
1.172.26
1,141.05
1.060.21
00.84
18.756
3,625.00
3.428.94
4.175.00
3723.73
30.42
37.51
56.40
.109.22
1.18879
1,156.95
1,096.08
6687
19.006
3,625.00
3,428.94
4,200.00
3741.16
30.42
3779
56.18
-196.21
1,205.29
1,173.03
1.112.32
60.71
ism
3,639.62
3,438.14
4.225.00
3,758.61
30.46
30.07
5593
-203.22
1221.76
1,189.19
1,128,39
60.81
19558
3,650.00
3,440.85
4.250.00
3,776.10
30.49
38.35
55.66
-210.24
1238.19
1.205.55
1,144.72
60.83
19.818
3,850.00
3,440.85
4,275.00
3793.61
30.49
38.64
55.38
-217.29
1.254.50
1.22.06
1,161.40
8085
20.148
3.662.55
3,448.10
4,300.00
3.811.16
30.53
30.92
55.08
-224.36
1,270.93
1,238.67
1,177.95
60.71
20.402
3,675.00
3.450.00
4,325.00
3,828.70
30.57
3820
5476
-231.45
1,287.27
1255.49
1,194.72
00.77
20.660
3,675.00
3,450.00
4,350.00
3.846.20
30.57
39.49
54.46
-230.57
1.303.63
1,272.43
1.211.05
60.58
21.003
3.683.34
3,453.69
4.375.00
3,863.67
30.60
39.77
54.13
-24573
1,320.03
1.289.57
1,229.01
60.56
21,295
3,888.82
3,45575
4,400.00
3.881.09
30.63
40.06
53.01
-252.92
1,336.45
1.306.88
1.246.38
8049
21.603
.470800
3,458.72
4,425.00
3.890.44
30.87
40.35
$3.48
-260.06
1,352.97
1.324.45
1.263.96
60.50
21.893
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
3/25/2019 11: 15 40A Page 3 COMPASS 5000.14 Build 85D
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40.96 NIPPLE AVA PORTED NIPPLE
2.75"
N'uppee Q4Xa
W6 6,W4
40.71 LOCATOR BAKER LOCATOR SOB
2,408
e09: e.De.e
S, 24.4 fi,5618
40.)0 PACKER BAKER F&l PACKER
2, )
80392 6.553.0
40.59 NIPPLE CANICO'D'NIPPLE
2,250
8,046.8 6.5508
40.53 SOS CAMSHEAROUT BOB
2441
iPERp: e.ne441a..o-
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, ate.)
Top1ND)
FceH e,na.o
TOp /nKB) (nKB/
1•) pas Com Run
PAR
oneIO MI
33.0 0
009 APV BeG preaeunR veMe iRsfalkdm 1@050GIKem, 57)12"19
apERF'. a.rae.Da.+mP-
3)080 3,500.5
423][15H ODBeddPTCIBParm7.pmmmConw ."CIBP0.t 5/232019
37M
pRopucTlDx: Bxoe.u4s
Corwco`Phillips KUP [NJ WELLNAME 1R-04 WELLBORE 1R-04
Ala9ka. etc.
,a.w, a2ersme us5:ww4
Other In Hole (Wireline retrievable plugs, valves, pumps, fish. etc.)
V^ryul Nl✓neYPnbM)
TOP IWIR Top Intl
Tup(RRBl (RKB) 1'1 Dee Com Run Da ID Rnl
HAM
BPVw;vO
3709.2 3,501.4 42.20 PERMANENT WB CIBP 5234019
BRIDGE PLUG
4,500.0 4.070.5 4628 JET CUT Jet Cul T69ILGL 4486.6') 4242019 2.992
t
7,610.0 6,2319 42.73 CEMENT 13.6' Cement Relair .2.)5"x1,46'" 4/212019 0.000
RETAINER
GJNgLT kP., 150
L
7,8254 C.391.R 41.39 TUBING 101122�EUM-UPCT-MPO 5y3 Laa,wd) Tubing Pun h- 3282019 2.992
PERFORATION SPD
Iw: z.wu
7,840.0 6.4030 41.40 PATCH HESRCPpBmb,ICh1rh2745'. iWinN5bu *GLM &726D0 1.310
7,985.1 1 6.512.1 4096 SLEEVE -C BPI ISO sleeve Set 4012000 4/12000 2.310
1w, 33m2
8136.0 6,6269 39.87 FISH PUValve Len Pieces in Hol, &22/1995
MPPIE; "ase
Perforahons 6 Slots
.TOR', A35fi.]
y,N
SEALASSY:530].
T.IRK-)
BIm IRKBI
T. .I
InKB)
Mm Pup)
1RN8)
LInKOE Zone
(aMWA
pale 1
typo
Cam
3.398.0
3,558.0
1 32M 4
3,388.4
5252019 12.0
CMT SOZ
51/8'12spfx RDXBH
TCP pert Buns
7,892.0
>,932D
6,4420
6.472.1
MI. R4
102&1985 12.0
(PERF
EBMru!&bl, HJ 11:120
d" ph
4mam aPmaael339panNB
CMT SOZ: 3.3G.O1559.0
8,118.0
8.134.0
6.6116
6.625.4
Ay1RL0
102&198.5 12.01PERF
4' W II Cap Gun: 90dn,ph
B,t46.0
8,188.0
6,831.6
666]0
AJ.1R4
10/2&1985 4.01PERF
4'W II CW Gun; SO ft ph
mb Omt 33710 ftB
Cement
Squeezes
Tu' ;WD) ..(WD)
Top Bun(RKB) IRKS) ("B) pea $LR patt Com
7,142.0 ],642.0 1.1 6,255.5 CEMEWPLUG 4212019
7,100.0 8,127,0 5,860.5 U.bmolCEMENT PLUG 4212019
3.398.0 3.558.0 3,2&4 3,388.4 CEMENT 5282019 34 bels of l5. ppg tamped
SQUEEZE
SCPB LINER: 9. 3890.0
Mandrel Insertsmm
PEflNANEM BRIWE%V,;
MI
3,M1
°n
N T,(1KB)
Top Pup)
InNB)
Mahe M04e1
Nlve LahR P°rt SM TRO Run
ODlln) Sery Type Type 1N) IT1 Run Dm Cum
2 2491.3
214812
Lames NBMG
5.984 IW DMY 1.000 Saaeo19
Su...3
1 3,3092
3.1N6
Camw IKBMG
5.984 INJ SGV 1.000 b3&2019
Notes: General S Safety
EM flab nnOO,Non
Lp�
112000 NOTE: Found PP35RPO leaks@7858'WLM&]842' WW (PATCHED 572000)
1'82 NOTE: "'WARNING"'Max lest peswre on lA l9WM true WSrab Lieler PKR�]380'
22 15 NOTE: Scab liner- max ditnhRlal pmswre 1900 pet
*N6Q5Q0I9
NOTE: V. SObem., w/AhRA. of 10.0
c.l,mx FaM: 7.lw.onKa
eue uxER: a,m7.p7,wo.o
CP,EM
Cemml Mq:
"Mr R7.,000PNB R:>0RO
Ny
peg UFT; ].al.]
LOCATOR: 7 01 2
-
BEwLASRY:T00.].5
PBR:
PACKER, 7,7W.0
MPPLE T.)IRB
SEALABSY; T.]N.]
PoR TW1.5
PAGER: ].8133
TI,eING FERFCRATI
7.8]50
PATCH: 7.800
LWE4TgN: ]BS3.a
IP.1; 7..,0-7..3 O
BI
NIPPUE 7M I
HIPMF, ]905.1
.TOR; B=.
PACIRR'. 00741
NPPIE;B.pt97
909'. e01a.a
IPERF,O,/,..",
MIR:31m.0
IPRRP,01w0e,,m0�
PRODUCTION;3509@0.5
K
zZ
�e�0 NHm
O N N
Loepp, Victoria T (CED)
From: Eller, J Gary <J.Gary.Eller@conocophillips.com>
Sent: Thursday, July 18, 2019 5:05 PM
To: Loepp, Victoria T (CED)
Cc: Hampton, Kyle; Germann, Shane; NSK West Sak Prod Engr
Subject: RE: [EXTERNAL]KRU 1 R-104(PTD 219-098) Injection Pressure & KRU 1 R-04(PTD 185-178)
Perf Interval Cement Evaluation
Follow Up Flag: Follow up
Flag Status: Flagged
Victoria — The NSK West Sak Production Engineer (cc'd) tells me that they apply a do -not -exceed injection gradient of
0.62 psi/ft at the sand face.
-Gary
From: Germann, Shane <Shane.Germann@conocophillips.com>
Sent: Thursday, July 18, 2019 3:57 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Cc: Eller, J Gary <J.Gary.Eller@conocophillips.com>; Hampton, Kyle <Kyle.Hampton @conocophitlips.com>
Subject: RE: [EXTERNAL]KRU 1R-104(PTD 219-098) Injection Pressure & KRU 1R-04(PTD 185-178) Perf Interval Cement
Evaluation
Hi Victoria,
The expected injection pressure at the sand face is 2100 psi.
Thanks,
Shane Germann
Coiled Tubing Drilling Engineer
�C3P ( i' iliUi n,bl
Office: 907-263-4597
Cell: 406-670-1939
700 G St, ATO 664, Anchorage, AK 99501
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Wednesday, July 17, 2019 10:29 AM
To: Germann, Shane <Shane.Germann@conocophillips.com>
Cc: Eller, J Gary <J.Gary.Eller@conocophillips.com>; Hampton, Kyle <Kyle.Hampton @conocophillips.com>
Subject: [EXTERNAL]KRU 1R-104(PTD 219-098) Injection Pressure & KRU 1R-04(PTD 185-178) Perf Interval Cement
Evaluation
What is the expected injection pressure at the sand face?
Thanx,
Victoria
From: Loepp, Victoria T (CED)
Sent: Tuesday, July 16, 2019 11:03 AM
To: Hampton, Kyle <Kyle Hampton Lwconocophillips.com>
Cc: Eller, J Gary (1 Gary Eller@conocophillips.com)<1.Garv.Eller@conocophillips.com>
Subject: KRU 1R-04(PTD 185-178) Perf Interval Cement Evaluation
Kyle,
Could you please resend the Archer log and CBL referred to in the email you sent below(5/29/19 3:11 PM). I can't seem
to locate it.
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loepp(dalaska.gov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepip@olaska.gov
From: Hampton, Kyle <Kyle Hampton conocophillips.com>
Sent: Wednesday, May 29,201911:08 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Cc: Eller, J Gary <1 Gary Eller@conocophillips.com>; Regg, James B (CED) <iim.resa@alaskaaov>; Regg, James B (CED)
<iim.regg@alaskaaov>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>
Subject: RE: [EXTERNAL]RE: 111-04 Perf Interval Cement Evaluation
Victoria,
Our perforations were from 3,398' RKB to 3,548' RKB. The interval was shifted away from the 7" casing collars, -20'
relative to the sundry depths provided. Based on the CBL, we interpret good coverage from 3,398' RKB to 3,556' RKB.
We have good cement coverage above and across the perforated interval. I attached an email Gary sent about this
depth correction.
While pressure testing the 7" casing across the perfs, we were leaking at 3 psi/min, leaking from inside the 7" casing
(most likely at the base of the pert interval) to the 7" x 9-5/8" annulus. While testing, we did not observe any pressure at
surface on the OA; we passed an MIT -OA prior to rigging up, but we have not performed a new test since.
We do not plan to change our cement job because we believe we have sufficient cement coverage from the perf cement
job.
Both 111-26 and 1R-04 and being converted into CTD injector wells; they should be under the same considerations. CTD is
planning an uncemented liner. I attached an email Gary sent about this well previously.
Thanks,
Kyle Hampton
Senior Wells Engineer ) Office. 907-263-4627 1 Cell. 832-421-1506 ) Kyle. Hampton@cop.com
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Wednesday, May 29, 2019 4:19 PM
To: Hampton, Kyle <KVIe.Hampton@conocophillips.com>
Cc: Eller, J Gary <J.Gary.Eller@conocophillips.com>; Regg, James B (CED) <jim.regg@alaska.gov>; Regg, James B (CED)
<iim.regg@alaska.gov>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>
Subject: (EXTERNAL)RE: 113-04 Perf Interval Cement Evaluation
Kyle, Gary,
There appears to be no cement above the top perforation — about 14' of perfs above the cement. The pressure loss of 3
psi/min is much lower than 111-26. What leak rate does this correspond to? I am concerned that the open perfs are
above the top of cement. Is there any indication of OA pressure? Any changes in your planned liner cement job? 111-26
is a producer and this well is an injector so the situation is different. How will this well be completed?
Victoria
From: Hampton, Kyle <Kvle.Ham pton@conocophillips.com>
Sent: Wednesday, May 29, 2019 3:11 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Regg, James B (CED) <[im.regg@alaska.gov>
Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Eller, J Gary <J. Gary. Eller@conocophillips.com>; Hayes,
James C <James.C.Hayes@conocophillips.com>; NSK RWO CoMan <NSKRWOCoMan@conocophillips.com>
Subject: 1R-04 Perf Interval Cement Evaluation
Victoria,
We are preparing to run and cement the 4-1/2" liner on IR -20 (PTD 185-178). We have drilled out the cement, passing a
14.2 ppg EMW test 50' above the perforated interval but leaking at 3 psi/min on a 14.2ppg EMW test after drilling out
the perforated interval. We believe we have a properly cemented annulus based on the CBL and wash/cement job
conditions. The results are very similar to 1R-26, so we are planning to proceed forward with running the liner and
cementing it in place. Do you need any other information from us before proceeding?
I have attached the Archer log and CBL. Please let me know if you have any questions.
Thanks,
Kyle Hampton
Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle.Hampton@cop.com
Loepp, Victoria T (CED)
From: Hampton, Kyle <Kyle.Hampton@conocophillips.com>
Sent: Thursday, July 18, 2019 12:39 PM
To: Loepp, Victoria T (CED)
Cc: Eller, J Gary
Subject: RE: [EXTERNAL]KRU 1 R-04(PTD 185-178) Perf Interval Cement Evaluation
Attachments: Job Log - 1 R-04.pdf, 1 R-04 CBL-VDL 29-May-2019.pdf
Victoria,
I have attached the CBL and Archer job log for your reference.
Thanks,
Kyle Hampton
Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 ( Kyle. Hampton Pcop.com
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Tuesday, July 16, 2019 11:03 AM
To: Hampton, Kyle <Kyle.Hampton @conocaphillips.com>
Cc: Eller, J Gary <J.Gary.Eller@conocophill ips.com>
Subject: [EXTERNAL]KRU 1R-04(PTD 185-178) Perf Interval Cement Evaluation
Kyle,
Could you please resend the Archer log and CBL referred to in the email you sent below(5/29/19 3:11 PM). I can't seem
to locate it.
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil 8 Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
V ictoria.Loeooroialaska.aov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeoo@alaska.aov
From: Hampton, Kyle <Kyle. Ham pton@conocophillips.com>
Sent: Wednesday, May 29, 2019 11:08 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.zov>
,
Acquisition System
Version
Maxwell 2018 SP2
8.2.104493.3100
Run Name Pass Objective
Direction
Top
Bottom
Start
Stop
DSC Mode
Depth Shift
Include
Parallel Data
Run 4 Log[5j:Up
Up
3258.89 ft
3703.43 ft
29 -May -2019 29
-May -2019
ON
16.50 ft
No
11:16:30 AM
1131:38 AM
All depths are referenced to toolstring zero
Company:ConocoPhillips (Alaska), Inc. WellAR-04
••
Rijn 4- Locil'5171-ImS0110
Description: CBL VDL Format: Log ( Sonic CBL with VDL) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date:
29 -May -2019 11:4740
F BIEP -Bond Index Event Pips DSLT-H
TIME -1900 - Time Marked every 60.00 (s)
Stuck Tool CBL Amplitude (CBL) DSLT-H
Indicator,
0 mV 50
Total(STIT)
0 It 50 CBL Amplitude (CBL) DSLT-H
0 mV 10
Gamma Ray (ECGR_EDTC) EDTC-B Cable
Good Bond (GOBO) Min Amplitude Max
0 gAPI 150 Tension
(TENS) 0 mV 10
Transit Time for CBL (TT) DSLT-H - - 10000 0 Variable Density Log (VDL) DSLT-H
.. .
400 us 200 Ibf ; ',GocdBond from CBL to GOBO- ; ; ; ; 200 us 1200
3220
3230
� 1
3240
`i
—
3250
3260
3270
'
� 1
3280
3290
4
3300
ti
ts
,
3310 '
Gamma Ray (ECGR_EDTC) EDTC-B
gAPI
Transit Time for CBL (TT) DSLT-H
us
Time Marked every 60.00 (s)
3540
3550 ,
3560
3570
3580
TIT
3590
CB
3600
3610
3620
3630
3640
3650 ;
3660
3670
3680
3690
3700
Stuck Tool
Indicator,
Total (STIT)
CBL Amplitude (CBL) DSLT-H
0 mV 5(
0 ft 50
CBL Amplitude (CBL) DSLT-H
0 mV 1(
Cable
Tension
(TENS)
10000 0...
IV
Good Bond (GOBO)
0 mV 1(
....
:: ,',GoodBond from CBL to GOBO•,•::: ,
Amplitude Maxl
Variable Density Log (VDL) DSLT-H
us 1200
BIEP - Bond Index Event Pips DSLT-H
CBL_VDL Format: Log( Sonic CBL with VDL ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date:
911:47:40
Run 4- Parameters
Parameter
Description
Tool
Value
Unit
AMSG
Auxiliary Minimum Sliding Gate
DSLT-H
126
us
BARI(ISSBAR)
Barite Mud Presence Flag
Borehole
No
BHS
Borehole Status(ODen or Cased Mole)
Borehole
Cased
BS
Bit Size
WLSESSION
12.25
in
CBLG
CBL Gate Width
DSLT-H
69
us
CBLO
Casing Bottom (Logger)
WLSESSION
8427
fl
CBRA
CBL LOC Reference Amplitude in Free Pipe
DSLT-H
62
mV
COEN
Cement Density
EDTC-B
2
gfcm3
CMTY(U-USIT_CEMT)
Cement Type
USI -17-E
Regular Cement
DETE
Della -T Detection
DSLT-H
E1
DFD
Drilling Fluid Density
Borehole
9
Ibm/gal
GCSE DOWN_PASS
Generalized Caliper Selection for WL Log Dom Passes
Borehole
BS(RT)
GCSE—UP—PASS
Generalized Caliper Selection for WL Log Up Passes
Borehole
BS(RT)
GOBO CURR
Good Bond in Arbitrary Cement
DSLT-H
2.87
mV
WAR
Image Rotation
USIT-E
Off
MAHITR
Manual High Threshold Reference for first amval detection
DSLT-H
120
MATT_CURR
Maximum Attenuation in Arbitrary Cement
DSLT-H
11.82
dB/8
MCI
Minimum Cemented Interval for isolation
DSLT-H
14.81
8
MNHTR
Minimum High Threshold Reference for first anival detection
DSLT-H
100
MSA
Minimum Sonic Amplitude
DSLT-H
1.33
mV
MSA CURR
Minimum Sonic Amplitude in Arbitrary Cement
DSLT-H
1.33
mV
NMSG
Near Minimum Sliding Gate
DSLT-H
257
us
SGAD
Sliding Gate Status
DSLT-H
Off
SGDT
Sliding Gate Delta -T
DSLT-H
47
us/ft
U-USIT_DFSZ
Drilling Fluid Specific Acoustic Impedance
USTr-E
0
Mreyl
USI FVEL_SEL
USI Fluid Velocity Selection
USIT-E
Automatic
USI ZMUD_SEL
USI Mud Impedance Selection
USIT-E
Theoretical
Run 4: Parameters
Parameter
Description
Tool
Value
Unit
MODE
DSLT Acquisition Mode
DSLT-H
CBL
RATE
DSLT Fidng Rate
DSLT-H
15 Hz
DTFS
DSLT Telemetry Frame Size
DSLT41
536
MAX LOG SPEED
Toolstring Maximum Logging Speed
WLSESSION
5000
ff/h
SGAI
Selectable Acquisition Gain
DSLT-H
x1
ULOG
Logging Objective
USIT-E
MEASUREMENT
UPAT
USIT Emission Pattern
USIT-E
Pattern 375 kHz
lMN(M
USIT Working Mode
USIT-E
Uncompressed 10 deg at 6.0
in
DATE
TIME
- EVENT DESCRIPTION
17.05.2019
0800
Brandon Leccese and Krzysztof Roicki check in Anchorage airport for a
flight to Ku aruk.
11:30
Reached KOC Camp in Kuparuk. Meet with Sean Helton
(Superintendent) and receive safety orientation.
Visit rig Nabors 7ES. Talk to company man. Rig currently on well 1R-20
16:00
and RIH WBCU. Next operation: RIH completion.
NC38 swivel still did not arrive to wireline shop.
18.05.2019
16:00
Visit location. Current ops: RIH slickline junk basket and gauge ring.
Had issues RIH completion last night and had to POOH.
19.05.2019
10:00
Got a call from wireline shop supervisor that Swivel has arrived.
11:00
Check and inspect swivel — all good.
13:00
Visit location. Current ops: space out completion string.
20.05.2019
13:00
Come to location. Current ops: completed well 1R-20. N/D BOP.
21.05.2019
15:00
Come to location. Rig has moved over well 1R-04. Current ops: killing
the well before setting BPV and N/D X-mas tree.
22.05.2019
12:00
Visit location. Current ops: testing BOP. Discussed the job with
company man.
23.05.2019
11:40
Visit location. Talk to co -man — issues with 5.875" gauge ring passing
through the wellhead. May need to N/D BOP and assess the condition.
Visit location. Talk to company man — set 2xCIBP on a -line while
24.05.2019
10:30
waiting for personnel to come fix the wellhead. CIBP @ 3710ft &
3587ft. Current ops: M/Up stands for TCP while waiting to
person nel/e ui pment to come fix wellhead.
18:00
Got a call from company man to move tool to the rig overnight due to
limited trucking availability.
Move Barricade Tool assembly and NC38 swivel to location and place in
25.05.2019
6:30
pipe barn. Talked to company man — wellhead fixed, gauge run with
5.99" performed without any issues. Current ops: P/U TCP guns. Asked
company man to call us out when rig will be laying down TCP guns.
Start POOH with guns. Tagged top CIBP 15ft higher than expected @
17:40
3572ft.
Current perforations depth DP — 3543 — 3383ft.
20:40
OOH with TCP guns. All shots fired and confirmed.
P/U Barricade assembly to rig Floor, inspect swab cups and tool —
21:20
everything good. RIH assembly below rotary, set in slips and install
dog collar.
21:45
M/up x -over onto the NC38 swivel and M/U on the bottom of first
stand. Make up on the Barricade assembly and RIH slowly through the
DATE
TIME
EVENT DESCRIPTION
wellhead. Hold pre -job meeting with rig crew on RIH with Barricade
assembly.
25.05.2019
22:30
10stds IN.
23:45
30 stands in.
23:55
M/Up single joint DP on top of STD #33 (space out).
Screw in to stand #36 before getting into perforations. Set depth at
26.05.2019
0:20
tool joint to 3367.93ft. PU 80 klbs SO 80klbs. Stretch 0.5ft
0:25
RIH to 3380ft bit depth).
0:30
Perform integrity test 1000 si/5min.
Intergrity test good, pressure holding and no returns on Flowline. WIR
0:35
90klbs (1000psi)
Bleed off pressure to 500psi and RIH to locate top perf. Top perf
0:40
located at 3391.77ft DP
RIH to 3397ft (5ft into perforations) and take parameters:
35 SPM (2BPM) — 90PSI
0:43
69 SPM (4BPM) — 270PSI
104 SPM (6BPM) — 560PSI
139 SPM (8BPM) — 94OPSI
174 SPM IOBPM — 140OPSI
Free rotation weight (40RPM) — 82klbs.
0:52
60RPM — 2000 ftlbs
8ORPM — 3000 ftlbs
10ORPM — 3600 ftlbs
P/U to top perforation and start washing down.
1:00
Note: Wash data in a table below.
While washing down @3455ft (bit depth) start taking weight. Weight
2:48
dropped from 72klbs to 62klbs while RIH and washing. P/U while
circulating to PU 86klbs and WIR broke over at 81klbs.
2:54
Wash down to 3456ft without problem. SO 76klbs
3:00
Finish washing down la stand. M/Up TIW valve onto the string.
Taking weight at 3528ft. SO 65klbs, PU to 80klbs (WIR break over) and
4:35
RIH without a problem.
5:00
Finished washing down. Bottom perforation @3543ft bit depth).
Perform integrity test @3555ft. No returns over shakers, pressure
5:10
holding.
Bleed off pressure to 500psi and P/U into perforation to confirm depth
5:13
on u wei ht — 3552ft.
Start circulating well clean @3551.5ft (bit depth) — circulating port
5:25
@° 3543ft.
10BPM @1450psi and 80RPM @1100ftlbs. Circulate until day crew
comes on tower.
5:45
Pumped 3500strokes — returns coming back clean.
6:00
Stop rotation. Keep circulating 3xBU.
PJSM for Pump&Pull. Will displace cement with rig pumps as brine
6:35
truck did not arrive.
DATE
- TINE
EVENT DESERIMON
6:50
Stop circuatlin —15 175strokes total.
Practice run for Pump&Pull to adjust Pulling speed and pumping rig
7:40
and prepare the crew for the operation. Will pull 35ft/min and pump
2.5BPM 44 SPM
Finish practice run. Position tool @3547.82ft (bit depth). Circulating
7:50
ort @3539.43ft (4ft above bottom perforation).
8:10
Pressure test lines from cement unit to manifold.
8:15
Start mixing 35bbls of 15.8 G-class cement.
8:30
Start pumping cement 4BPM and 220psi.
Line up valves for Pump&Pull. RIH to 3551ft (circulating port at bottom
8:40
perforation) and start pulling 35 min and pumping 2.5BPM 44s m .
Connection. Close TIW and close annular. Pumped 119strokes —
8:43
6.9bbls calculated 114strokes — 6.6bbis
Resume P&P. Reach top perf with 223 strokes total pumped - 12.8bbis
8:48
tanned 11.4bbls .
Pull Barricade Assembly 5ft into casing and pressure up to shear solid
8:50
seat.
8:53
Sheared solid seat @bbls
8:58
Pum &Pull in casing 60ft/min and 30spm 1.7BPM .
Stop pumps at 312strokes — 18bbis (planned 16.5bbls) at 3307ft
9:00
lanned TOC 3223ft and pull through cement.
9:10
Pull 5stands + 1 single 50ft min then circulate.
9:32
POH 5 stands to 2668ft.
Start circulating 10BPM. Receive cement/contaminated cement on
9:46
shakers from 1270 to—1500strokes-13bbls
10:10
Pumped 2500strokes. Stop circulation.
Tool OOH. Inspect — a lot of metal debris on the tool (jammed in the
12:00
cups), upper lower cup deformed with a big chunk of metal jammed in
it. Cement residue showing signs of cement dehydration already.
12:30
L/D tool and prepare for backload.
16:00
Got a ticket and LFP signed by company man.
Brandon and Krzysztof leaving Kuparuk to Anchorage and will stay in
27.05.2019
8:00
town standby for next well SG-03.
Table 1 Washing down.vards data
Time
Flow Rate
(bpm/spm)
Pressure
(psi)
TrippingPerforation
Speed
(ft/min)
(ft)
Bit Depth (ft)
Notes
1:25
AM
10/172
1490
1
0
3392
1:28
AM
10/172
1418
1
2
3394
1:30
AM
10/172
1422
1
4
3396
1:34
AM
10/172
1415
1
6
3398
1:37
AM
10/172
1411
1
8
3400
1:41
AM
1.5/26
1412
1
10
3402
Pump 1.5BPM
1.5/26
1
12
3404
10.5-13ft
1:45
AM
10/172
1385
1
14
3406
1:47
AM
10/172
1396
1
16
3408
1:49
AM
10/172
1400
1
18
3410
1:51
AM
10/172
1395
1
20
3412
1:54
AM
10/172
1396
1
22
3414
1:56
AM
10/172
1395
1
24
3416
1:59
AM
10/172
1396
1
26
3418
2:01
AM
10/172
1395
1
28
3420
2:03
AM
10/172
1397
1
30
3422
1.5/26
1
32
3424
Pump 1.5BPM
2:09
AM
1.5/26
1390
1
34
3426
32-34ft
2:11
AM
10/172
1391
1
36
3428
2:14
AM
10/172
1398
1
38
3430
2:17
AM
10/172
1394
1
40
3432
2:19
AM
10/172
1397
1
42
3434
2:21
AM
10/172
1402
1
44
3436
2:24
AM
10/172
1402
1
46
3438
2:27
AM
10/172
1401
1
48
3440
2:29
AM
10/172
1447
1
50
3442
2:32
AM
10/172
1389
1
52
3444
1.5/26
1
54
3446
Pump 1.5BPM
2:36
AM
1.5/26
1390
1
56
3448
53-56ft
2:38
AM
10/172
1393
1
58
3450
2:40
AM
10/172
1397
1
60
3452
2:42
AM
10/172
1397
1
62
3454
2:50
AM
10/172
1399
1
64
3456
2:52
AM
10/172
1398
1
66
3458
3:24
AM
10/172
1442
1
68
3460
3:26
AM
10/172
1440
1
70
3462
3:28
AM
10/172
1447
1
72
3464
3:30
AM
1.5/26
1447
1
74
3466
Pump 1.5BPM
1.5/26
1
76
3468
74-77ft
332 AM
10/172
1446
1
78
3470
3:34 AM
10/172
1460
1
80
3472
3:37 AM
10/172
1460
1
82
3474
3:40 AM
10/172
1468
1
84
3476
3:43 AM
10/172
1467
1
86
3475
3:46 AM
10/172
1477
1
88
3480
3:48 AM
10/172
1485
1
90
3482
3:50 AM
10/172
1450
1
92
3484
3:53 AM
10/172
1458
1
94
3486
1.5/26
1
96
3488
Pump 1.5BPM
3:57 AM
1.5/26
1410
1
98
3490
95,5-98,5ft
4:00 AM
10/172
1425
1
100
3492
4:02 AM
10/172
1426
1
102
3494
4:04 AM
10/172
1425
1
104
3496
4:06 AM
10/172
1424
1
106
3498
4:08 AM
10/172
1424
1
108
3500
4:10 AM
10/172
1425
1
110
3502
4:12 AM
10/172
1422
1
112
3504
4:14 AM
10/172
1421
1
114
3506
4:16 AM
10/172
1422
1
116
3508
4:18 AM
1.5/26
38
1
118
3510
Pump 1.5BPM
4:20 AM
1.5/26
1416
1
120
3512
117-119ft
4:22 AM
10/172
1420
1
122
3514
4:24 AM
10/172
1419
1
124
3516
10/172
1418
1
126
3518
10/172
1418
1
128
3520
E4:34
10/1721420
1
130
3522
10/172
1419
1
132
3524
10/172
1410
1
134
3526
4:38 AM
10/172
1418
1
136
3528
1.5/26
50
1
138
3530
Pump 1.5BPM
1.5/26
1
140
3532
138-141ft
4:46 AM
10/172
1431
1
142
3534
4:48 AM
10/172
1433
1
144
3536
4:50 AM
10/172
1428
1
146
3538
4:52 AM
10/172
1430
1
148
3540
4:54 AM
10/172
1427
1
150
3542
4:56 AM
10/172
1425
1
152
3544
4:58 AM
10/172
1425
1
154
3546
4:59 AM
10/172
1428
1
156
3548
5:01 AM
10/172
1425
1
158
3550
5:02 AM
4/69
300
1
160
3552
From: Germann, Shane
To: Boyer David L (CED)
Subject: RE: [EXTERNAL]Digital Survey File for KRU 1R-104 Proposed Well
Date: Wednesday, July 10, 2019 2:04:22 PM
We do plan on pre -producing it before water injection. It will be less than 3 months. Right now
we're thinking it will be around 30 days.
Thanks,
Shane
From: Boyer, David L (CED) <david.boyer2@alaska.gov>
Sent: Wednesday, July 10, 2019 1:54 PM
To: Germann, Shane <Shane.Germann@conocophillips.com>
Subject: RE: [EXTERNAL] Digital Survey File for KRU 1R-104 Proposed Well
Thank you Shane. Since West Sak wells are new to 1R Pad, there is no H2S history in that formation
on 1R that we are aware of.
I forgot to ask, will 113-104 be pre -produced before water injection? If so, for haw long? Less than 3
months?
Thanks,
Dave B.
From: Germann, Shane <tihane Germann(@conocophillios com>
Sent: Wednesday, July 10, 2019 1:44 PM
To: Boyer, David L (CED) <david bovei 2C7a alaska.gov>
Subject: RE: [EXTERNAL] Digital Survey File for KRU 1R-104 Proposed Well
Hi David,
I attached the planned surveys for our well plan in Excel form. Let me know if you need anything
else.
Thanks,
Shane Germann
Coiled Tubing Drilling Engineer
Conomilhilllps Alaska
Office: 907-263-4597
Cell: 406-670-1939
700 G St, ATO 664, Anchorage, AK 99501
From: Boyer, David L (CED) <d avid. bcyei2 L ala5ka gov>
Sent: Wednesday, July 10, 2019 12:28 PM
To: Germann, Shane <Shane Cerm,�nnnconoco I� sn conn
Subject: [EXTERNAL] Digital Survey File for KRU 1R-104 Proposed Well
Hi Shane,
I just began the geological review of the PTD application for the KRU 1R-104 West Sak well. Would it
be possible to e-mail over a digital file of the proposed surveys in either Excel or ASCII format. We
load the surveys into the AOGCC GeoGraphix database.
Thank you,
Dave Boyer
Senior Geologist
AOGCC
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150
PTD#:2190980 Company ConocoPhilliMAlaska Inc— Initial Class/Type _
Well Name: &)FAVI UK RIV UNIT KRU 1R-104 Program SER Well bore seg
SER/PEND GeoArea 890 Unit 11160 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
Directional. plan view and wellbore profile included.
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 he issued without administrativeapproval..... - - - - - -
Yes
- -- - - - - - - - - - - - - - - - - -
13
Can permit be approved before 15 -day. wait - - - - - - ...
Yes
- -
DLB 7/10/2019
14
Well located within area andstrataauthorized byInjectionOrder # (put. 10# in.comments).(For
Yes
- - - - - - Area Injection Order No. 26
15
All wells within 1/4. mile area of review identified (For service well only) ..............
Yes
- - - - - ..... - - - - - -
16
Pre -produced injector: duration of pre -production less then 3 months(Forservice well only)
Yes
- - - - - - - - - - - - - - - - - - - - -
17
Nonqonven, gas.conforms to AS31,05.0300.1.A),0,2.A-D) ------- - - - - - - - - - - - -
NA.
- - - - - - - - -
18
Conductor stdng.provlded .. -- - - - - - - - - - --------- - - - - - - - - - - -
NA-
Conductor set for KRU 1R-04 -
Engineering
19
Surface casing. protects all known USDWs . . . ........... - - - - - - - -
NA.
Surface casing set for KRU-1R-04-
20
GMT vol adequate to circulate on conductor & surf-csg - - - - - - - --- - - --- - - - - - - -
NA.
Surface casing set and fully cemented - - - - -
21
CMT -vol adequatetotie-in long string tosurfcsg- - - . ............
.NA.
22
CMT will coverall known productive horizons- - - - - - - - - - - - - -
No
- - Productive. interval will be completed with -uncemented solid and slotted Jiner
23
Casing designs adequate for C, T, B &-permafrost. - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - -
24
Adequate tankage of reserve pit - - - - - - - - -
Yes
- Rig has steel tanks; all waste to approved disposal sites...
25
Jf a. r"rill, has.a 107403 for abandonment been approved - - - - - - - -
Yes
PTD 1657178,. Sundry 319-092-
26
Adequate wellbore separation proposed.. - - .. ......
Yes
- - - - - Anti -collision analysis complete; no major risk failures - - - - - - - - - - -
27
If diverter required, does it meet regulations. - - - - - - -
NA
Appr Date
28
Drilling fluid program schematic & equip list adequate. -
Yes
- Max formation pressure is 1517 psig(B.65 ppg.FMW ); will drill w/ B,4-ppg and maintain overbal w/ MPD
VTL 7/18/2019
29
BOPEs, do they meet regulation - - - - - - - - - - - -
Yes
- - - - - - - - - - - - - -
30
ROPE.press rating appropriate; test to(putpsig in comments)- - - - - - - - - - - -
Yes
- MPSP is 1160 psig; will test BOPS -to 3500 psig - ....................... . .
31
Choke. manifold complies w/API RP -53 (May 84).... -- - - - - - - - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - -
32
Work will occur without operation shutdown- - - - .......... . . .. . ...
Yes
33
Is presenceofH2S gas. probable - ... - - - - - - - - - - - ......
No.
...... . .. . . . .
34
.Mechanical condition of wells within AOR verified (For service well only) ..............
Yes -
- - - - - - KRU 1R-07: SC set above WSak; increased OA monitoring. - - - -
35
Permit can be issued w/o hydrogen. sulfide measures - - - - - - - - - - - - ------
Yes .
- - - - - West Sak development is new to 1R Pad, ... - .. _
Geology
36
Data. presented on potential overpressure zones.. - - - - - ......
Yes ------
- - - - - - - - - - - - - - - - - - - - - - ---
Appr Date
37
Seismic analysis of shallow gas zones - - - - - - - - - - - -
NA--
- -- - - - - - - - - - - - - - - - - - - - - - - - - -
DLB 7/10/2019
38
Seabed condition survey -(if off -shore) - - - - - - - - - - ......
M ......
- - - - - - - - - - - -
39
Contact name/phone for weeklyprogressreports. [exploratory only] - --- - - - - - - - - - - - - -
NA
Geologic
Commissioner: Date:
_7 IZ:4 H)
Engineering Public
Commissioner: Date Commissioner Date
