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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout219-119DATA SUBMITTAL COMPLIANCE REPORT
1/14/2020
Permit to Drill 2191190 Well Name/No. KUPARUK RIV UNIT 1C-061-1-02 Operator ConocoPhillips Alaska, Inc.
MD 13262 TVD 6621 Completion Date 10/1/2019 Completion Status 1WINJ Current Status 1WINJ
REQUIRED INFORMATION /
Mud Log No ✓
Samples No I/
API No. 50-029-20564.62.00
UIC Yes
Directional Survey Yes
DATA INFORMATION
List of Logs Obtained:
GR/Res
(from Master Well Data/Logs)
Well Log Information:
Log/
Electr
Data
Digital
Dataset
Log Log Run Interval CHI
Type
Med/Fant
Number Name
Scale Media No Start Stop CH Received
Comments
ED
C
31334 Digital Data
10/21/2019
Electronic File: 1C-0611-02 EOW - NAD83.pdf
ED
C
31334 Digital Data
10/21/2019
Electronic File: 1C-061-1-02 EOW NAD27.pdf
ED
C
31334 Digital Data
10/21/2019
Electronic File: 1C-061-1-02 EOW NAD27.txt
ED
C
31334 Digital Data
10/21/2019
Electronic File: 1C-061-1-02 MD NAD83.txt
Log
31334 Log Header Scans
0 0
2191190 KUPARUK RIV UNIT 1C-061-1-02 LOG
HEADERS
ED
C
31370 Digital Data
9178 13262 10/23/2019
Electronic Data Set, Filename: 1C-061-1-02
GAMMA RES.las
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 2MD Final Log.cgm
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 5MD Final Log.cgm
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 5TVDSS Final
Log.cgm
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 2MD Final Log.pdf
ED
C
31370 Digital Data
10/23/2019
Electronic File: lC-06L1-02 5MD Final Log.pdf
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 5TVDSS Final
Log.pdf
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-0611-02 EOW NAD27.pdf
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 EOW NAD27.txt
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 Final Surveys TD
13262.csv
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 Final Surveys TD
13262.xlsx
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 Survey Listing.txt
AOGCC Page I of Tuesday, January 14, 2020
DATA SUBMITTAL COMPLIANCE REPORT
1/1412020
Permit to Drill
2191190 Well Name/No. KUPARUK RIV UNIT 1C -06L1-02 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20564.62-00
MD
13262
TVD 6621 Completion Date 10/1/2019
Completion Status 1WINJ Current Status 1WINJ UIC Yes
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 Surveys.iM
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-
02_25_tapescan_BHI CTK.txt
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-
02_5_tapescan_BHI_CTI(JA
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061.1-02_output.tap
ED
C
31370 Digital Data
10/23/2019
Electronic File: iC-061-1-02 21VID Final Log.tif
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 SMD Final Log.tif
ED
C
31370 Digital Data
10/23/2019
Electronic File: 1C-061-1-02 5TVDSS Final Log.tif
Log
31370 Log Header Scans
0 0
2191190 KUPARUK RIV UNIT 1C-061-1-02 LOG
HEADERS
Well Cores/Samples Information:
Sample
Interval
Set
Name
Start Stop
Sent Received Number
Comments
INFORMATION RECEIVED
Completion Report Y
Production Test Information Y / NA
Geologic Markers/Tops Y
COMPLIANCE HISTORY
Completion Date: 10/1/2019
Release Date: 9/10/2019
Description
Directional / Inclination Data Y Mud Logs, Image Files, Digital Data Y / NA Core Chips Y / NA
Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Y Core Photographs Y / NA
Daily Operations Summary Y Cuttings Samples Y / NA Laboratory Analyses Y / NA
Date Comments
Comments: ------ - --- — -- - - -- ----- - --
AOGCC Page 2 of 3 Tuesday, January 14, 2020
DATA SUBMITTAL COMPLIANCE REPORT
1/14/2020
Permit to Drill 2191190 Well Name/No. KUPARUK RIV UNIT 1C-061-1-02 Operator ConocoPhillips Alaska, Inc. API No. 50.029-20564-62-00
MD 13262 TVD 6621 Completion Date 10/1/2019 Completion Status 1WINJ Current Status 1WINJ UIC Yes
Compliance Reviewed By:
Date:
AOC.CC Page 3 of 3 'Puesday, January 14, 2020
Winston, Hugh E (CED)
From: Winston, Hugh E (CED)
Sent: Friday, January 17, 2020 10:49 AM
To: Winston, Hugh E (CED)
Subject: RE: KRU 1C-06 Sundry Issues
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Wednesday, January 15, 2020 9:50 AM
To: Winston, Hugh E (CED) <hugh.winston@alaska.gov>
Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>
Subject: KRU IC -06 Sundry Issues
Hugh,
Could you please hand make these changes on the forms, put a copy of this list in each of the well files and
correct in RBDMS?
Let me know if you have any questions.
Thanx,
Victoria
From: Germann, Shane <Shane.Germann@conocophillips.com>
Sent: Wednesday, January 15, 2020 8:57 AM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; Winston, Hugh E (CED) <hugh.winston@alaska.gov>
Subject: RE: [EXTERNAL]KRU 1C-06 Sundry Issues
Victoria,
Below are the forms that have WINJ checked instead of WAG along with the corresponding well names and PTD
#'s. Let me know if you need anything else. I apologize for the inconvenience this has caused.
Well Name
PTD #
Form
KRU 1C-06
181-025
10-403 (Sundry # 319-380)
KRU 1C-06
181-025
10-404 (Sundry # 319-380)
KRU 1C-061-1
219-117
10-401
KRU 1C-061-1-01
219-118
10-401
KRU 1C -06L1-02
219-119
10-401
KRU 1C -06L1
219-117
10-407
KRU 1C-061-1-01
219-118
10-407
KRU 1C-061-1-02
219-119
10-407
Shane Germann
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4597
Cell: 406-670-1939
700 G St, ATO 664, Anchorage, AK 99501
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov>
Sent: Wednesday, January 15, 2020 8:37 AM
To: Germann, Shane <Shane.Germann@conocophillips.com>
Cc: Brooks, Phoebe L (CED) <phoebe. brooks @alaska.gov>; Winston, Hugh E (CED) <hugh.winston@alaska.gov>
Subject: (EXTERNAL]KRU 1C-06 Sundry Issues
Shane,
Please list the wells, PTD #s, Sundry #s and the forms where WI instead of WAG is checked.
We will take a look at 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. Loepa(Malaska.gov
CONFIDENTIALRY 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 low. 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: Tuesday, January 14, 2020 3:12 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; Ohlinger, James J
<James.J.Ohlinger@conocophillips.com>
Subject: KRU 1C-06 Sundry Issues
Victoria,
It has been brought to my attention that the KRU 1C-06 Sundry (319-380) and CTD sidetrack PTD's (219-217,
219-118, 219-119) have a mistake on them. The 1C-06 is a WAG injector and has been on WAG since 2007. The
1C-06 CTD laterals were always planned to be on WAG injection, but I inadvertently checked the "WINJ" box
instead of "WAG" on the 10-401's, 10-403, 10-404, and 10-407's. The well status for the 1C-06 motherbore as
well as the three CTD laterals (L3, Ll -01, and 1.1-02) should be WAG.
Please advise if any formal documentation is required. I've attached the email chain that brought this up and
the 10-404 for KRU 1C-06. Feel free to call or reply with any questions.
Shane Germann
Coiled Tubing Drilling Engineer
STATE OF ALASKA
AI ACkA nu ANTI rAR CONRFRVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑
t0i 20AAC 25.105 20AAC 25.110
GINJ ❑ WINJ L WAG// WDSPL ❑ No. of Completions:
1b. Well Class:
Development ❑ Exploratory El
Service ❑ ' Stratigraphic Test ❑
2. Operator Name:
6. Date Comp., Susp., or
14. Permit to Drill Number / Sundry:
ConocoPhillips Alaska, Inc.
Abend.: 1011/2019
219-119
3. Address:
7. Date Spudded:
15. API Number:
P.O. Box 100360 Anchorage, AK 99510-0360
912612019
50-029.20564-62-00 '
4a. Location of Well (Governmental Section):
8. Date TD Reached:
16. Well Name and Number:
Surface: 137V FNL, 858' FWL, Sec 12, T11 N, R1 OE, UM
9/2912019
KRU 1C-061-1.02
9. Ref Elevations: K6:94
GL: 55 - BF:
17. Field / Pool(s):
Kuparuk River FieldlKuparuk River Oil Pool
Top of Productive Interval:
38V FSL, 1586' FEL, Sec 36, T12N, R10E, UM
10. Plug Back Depth MDIIVD:
18. Property Designation:
Total Depth:
3279' FNL, 708' FEL, Sec 36, T12N, R10E, UM
• 13165/6627
ADL 25649, ADL 25638 "
4b. Location of Well (State Base Plane Coordinates, NAD 27):
11. Total Depth MDTFVD:
19. DNR Approval Number:
Surface: x- 561864 - y- 5968860 Zone- 4 '
TPI: x- 5Ug7 5(.'%3_' y- 5975928 Zone- 4
• 1326216621 •
LONS 79-016
12. SSSV Depth MD/TVD:
20. Thickness of Permafrost MD/TVD:
Total Depth: x- 565501 y- 5977547 Zone- 4
2238/2021
1 1931/1785
5. Directional or Inclination Survey: Yes ❑� (attached) No ❑
13. Water Depth, if Offshore:
21. Re-drill/Lateral Top Window MD/TVD:
I
Submit electronic and printed information per 20 AAC 25.050
N/A (ft MSL)
. 11339/6562 -
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
DECEIVED
GRI/Res OCT 3 0 1019
23CASING, LINER AND CEMENTING RECORD AOGGG
WT. PER SETTING DEPTH MD SETTING DEPTH TVD I AMOUNT
CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED
16 1 65 H-40 32 65 32 65 36 426sx Permafrost
10 314 45.5 K-55 31 3287 31 2685 13 314 3400 sx AS II
7 26 K-65 30 10226 30 7090 8314 535 sx Class G
2318 4.6 L-60 9274 13165 6418 6627 3 Slotted Liner
24. Open to production or injection? Yes E No ❑
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
25. TUBING RECORD
SIZE DEPTH SET (MD) IPACKER SET (MD/TVD)
31/2 9367 1 9151/6326
Size and Number; Date Perfd):
SLOTTED LINER @:
1 9281/6423
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
9274-13165 MD and 6418-6627 TVD... 9130/2019 COMPLETION
D T
lop ZD(J
Was hydraulic fracturing used during completion? Yes ❑ No E]
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
VERIFIED
DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED
27 PRODUCTION TEST
Date First Production:
Method of Operation (Flowing, gas lift, etc.):
N/A
INJECTION ONLY -- NOT PRE -PRODUCED
Date of Test:
Hours Tested:
Production for
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Choke Size:
Gas -Oil Ratio:
Test Period
Flow Tubing
Casino Press:
I
Calculated
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Oil Gravitv - API (corr):
Press.
24 -Hour Rate
Form 10-407 Revised 5/2017 Vr1-//�5/�/�/,/G/NCONTINUED ON PAGE2 RBDMSLf' OCT 3010195 ittO�G�IALo
28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑�
If Yes, list formations and intervals cored (MDfTVD, Fromlro), 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 ❑�
If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Surface
Permafrost - Base
1931
1785
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
11336
6562
information, including reports, per 20 AAC 25.071.
Formation @ TPI -Kuparuk C
TD
13262
6621
Formation at total de the
Ku aruk C
31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
cialeontoloaical report production or well test results per 20 AAC 25,070.
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: James Ohlin er Contact Name: Shane Germann
Authorized Title: Staff CTD Engineer Contact Email: shane. ermann co .com
Authorized Contact Phone: 263-4597
Signature: Date:
INSTRUCTIONS
General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 26: 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 10407 Revised 5/2017 Submit ORIGINAL Only
IC -06 Final CTD Schematic uomi.a: +aivm+a s,o
3-12" TRM61015E 666V ® 2238' MD
3-12° 9.aaLA0 EUE BM Tubing to surface
i6" 859 H10 sboe
®85'MD
10-3I4'o K-55
shoe ®328r MD
Baker 3IZ PBR ® 9192' MD (0.0' ID)
Baker FHL packer® 8115' MO (3A" ID)
X -Nipple (2 9159' MD (2.813" IO)
Baker EL -1 SBR ® 9222' MO (4.3]5" ID)
Baker FHL Packer® 924T MO (3.0• ID)
3-12" Cemco O lending nipple ® 928W MD (Milled W 2,80" ID)
3-1W tubing tag ® 9288' MO
13,282' MO
: W2 MD BOX=
Gantl parts
9410' • 9485' MD
T' 269 K55 shoe
10,226'MD
MD
BOL=13,822' MD
Roar MD BOL=11,568'MD
sWhed Neer W What
conocOPIIllips
Aleska, ri
WELLNAME 1C-06
WELLBORE
IC -06
mas,,azvzgM+zm'favM
Last Tag
ymyy acly,eyc Rosi
Amnfayw, pq,m llx(B) EM Datr WNIWre .Moe By
Last Tap: RKB 9,658.0 852019 1C mTO
Last Rev Reason
--- ------
----
Annolallon Ihe Us. Werpore Last Moe By
HANGER: as
Rev Reason'. Add Liner CTO liner top ',rhe 19 1C-Ofi tergusp
Casing Strings
Casing Descrlpnon GO(nl IGDnI Top lXNel ael Oxplk nMB1 Set DepIM1 INDI... WULen(I 1(tratla TOPTxreW
CONDUCTOR 16 1506 32.0 fi5.0 65.0 62.58 H40 WELDED
Casing Conscription GD tint m[n) iop (XXBI sN DepIx 1XHB) ae+Dap,M1 (N01... WIILen 11._ Grade TOP TXrIII
SURFACE 1l 10314 9.95 31.3 3,280 2,fi85.1 4550 K-55 BUTT
Caainp Caeog,bn oolso mpnl 11161-01 Sal nepslXKB) se, DePln (IVpL.. wULen O... Gratle TOPTnroad
PRODUCTION ) 6.28 29.6 10,2258 ],0901 2600 K-55 BTC
Tubing Strings
Tuning Description string M.... Ip Un) rNlRl set oepu ln_sel Cegn TVD11W, 01LR1 Grade Top COnnecron
TUBING 2007 WO 3112 2.99 12-6P.9' 92329 638].5 9.J0 L-80 Brtl
Completion Details
...n, WNDUCTO6: uDas.D
WETyvw:2237.e
TOPIrvm TOP mal xominal
TOP SHOT nRe1 fl Item Des Com IG Im)
26.9 269 OBO HANGER FMC Tubing HANGER 3.500
2,237. 2,021.0 43,75 SAFETY VLV 35" TRMAXX5E Safety Valve (Serial # HYS-]0) 2 812
9,1355 13,3134 3906 PBR Baker PBR seal assembly Pinned 40M#) W2.39'spaseout 30M
9,1515 6,325.8 39.54 PA KER Baker FHL Packer(pinne, 60M#Shear) 300
9,1932 6,35].6 40.]9 NIPPLE 2. HIS XNipple 2.813
suRRue, a4pGzeT.o-
9,231.9 6,386] 41.80 OVERSHOT Baker Tubing tub Overshot+ l' sp87OW 3.610
iibler DescripXon aVl,q Ma_. mpn) iop XNBI Be[DepIg IX.. aN Deplg (ND)1-. WtpNlll Grade Tap to nnedlon
TUBING' WO 5314 4.3] 9,2322 9,281.5 6.4234
Completion Details
Gas upT: e,orea
XXm
Top -.1
Tap(NDI Tavmor
InKal 1°I I,am Des Com
ID tial
DTI
9,255.2
6404.0 42.38 SBR BAKER EL-158R(no full joint, TBG slang sM1Owing SBR DDIID)
4.375
Tubingl4aonPtpn Sting Ma... ID lin) iopt IB) Set DaPIb IX.. aN Dapb Bri (...W1drNhp Grade ToPConterrin
TUBING Original 3112 299 9,281.5 9,38)2 6,498] 920 K-55 BTC
Completion Details
efp,.jaii
PACBF0.9,,de
Top "to Tap no Nomwl
Top IXXB) IXRB) (°) IM1m Oen Co. ID IMI
9,281.5 6,4234 43.04 PACKER BAKER FHL PACKER 3.800
Mwte:.,ra.z
9,349.3 8,4]2.1 44.98 NIPPLE DNIPPLE NILLED N Nipple 2.800
behind pipe: 1C-06 Ll -0 CTD liner.
9,380.9 6,494.3 4593 505 2932
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Tap (ND)
Top IXKBI InKel
Top lncl
1'1
Dos Cam
0.un DaR 10 (n)
WEflSXGi; e,919
ena0 6,41]9
42.85
Liner Tap Liner up into ma0er, here: C 019 -061A Liner
95012019 1.992
op.
saw. e,zzz
10,0260 6.9464
44.00
FisM1 Vann Gun Leh mm original ped 101'long
62511981
Perforations & Slots
Shot
PgCRER; B.atb
Dens
TP'MR)
BIm (XSB)
Top MD)
IM e)
BW IND)
I l
oaken Zone
Dele
(ahoKM
I
Tvw
Com
9,410.0
9,485.0
Q514.4
0,00a 5
120
1
3UN
6
NRRIF; g,91.p
Mandrel Inserts
r
P
iop MDl
MXB)
Make
Model
ODIm)
SeN
viva
Type
IamX
TYPn
Ramsim
An)IWpCam9.2
TI10 RunBi
6,26 Y
Camco
MMG
1 t2
GAS LIFT
DMY
BK
I 000 1
00
tt/11200]
Notes: General & Safety
Eneoan Annotation
1211993 NOTE'. WORKOVER
PM B,metrg,I%.0�
42]2004 NOTE WAIVEREDWELL'. T%IA OMMUNICATON
2/282010 NOTE: VIEW SCHEMATIC -v- chemaeo9.
pap Ig,oAg
PROOurchoc :1eti-ILoop,
Ine"o.
1C-0 14Q.10232019120231M
KUP Ste
WELLNAME 1C-06 WELLBORE
1C—O6L1-02
ConocoPh1III
Well Attribute,
Ma.1 Angle l
l•)
TD
NCI Bon 111NB)
OO tln)
23/8
I011n)
199
Fleld Neme
=1,APYUWI We11W--Sngus II{d IMOIIM
TRJ 99ifl 44
132626
Aaska IOC
1C-0 14Q.10232019120231M
Casing Strings
ys.(altllanepcl 9J)
Casing 0accripdon
LINER
OO tln)
23/8
I011n)
199
Top 111RB) g.OagnlnNB) SeL OevlNlrvO)...WULen 11...Gace
9,274.1 13,1650 fi.62>0 4.60 L-80
lop TM1read
STL
Lt -02
Liner Details
xommal m
tovtnNel rav(rvDI NLND)
ldpmd
Nemec
cont
Iln)
&274.1 8,41'! 9 4288 5 ment
NOM Deployment Sieeve
1920
jg
Sleeve
...g.369
11,3150
8,561.8
90.12
—P,oyment
Sleeve
Nmty Depbyment Sleeve
1.920
Mi WNDUCTOR;MY O
sAFETryw:2r3Te
SURFACE: 313 WgB
WS JFT: 9.W92
Pa. 9,135.5
PACI(ER: 9.I5L5
0•
NIPPLE: 9.193.2
..OT apt e
SBR: 9.Y3.2
PRODUCTION; 4 &10=55
L102 LINER: 8,3]01-13.1SSOJ
Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Slad Depth
Start Time I End Time Dw(hr) Phase Op Code Acbvity Code Time P -T -X Operation (fIKB) End Depth(rlKe)
9/11/2019 9/11/2019 2.75 MIRU MOVE MOB P move from 1G-113to 1G-103 0.0 0.0
00:00 02:45
9/1112019
9111/2019
2.00
MIRU
MVE
O
MOB
P
On location, remove jeeps, hook up
0.0
0.0
02:45
04:45
truck to drilling sub module, spot over
well
9/11/2019
9/11/2019
2.00
MIRU
MOVE
MOB
P
Spot in rig mats, spot pit module next
0.0
0.0
0445
06:45
to drilling sub, pusher headed to
retrieve shop from 1 G -pad.
9/11/2019
9/11/2019
3.25
MIRU
MOVE
MOB
P
Work on Rig Move check list, secure
0.0
0.0
06:45
10:00
all landings, walking surfaces, and
cellar floor, hook up PUTZ (inter-
connech.Rig up steam lines / heaters,
tool house on location, rig up tiger
tank line placing tiger tank off drillers
side along well row.
9/11/2019
9/11/2019
2.00
MIRU
WHDBOP
NUND
P
Nipple up BOP stack, tighten tree
0.0
0.0
1000
12:00
bolts, valve crew service tree. Service
rig valves in preparation4 for BOPe
test,
"' Note: Rig Accept 10:00
9/11/2019
9/11/2019
1.00
MIRU
WHDBOP
NUND
P
Complete prepping for BOPe test.
0.0
0.0
12:00
13:00
Line up and fluid pack rig. Obtaint
shell test
9/11/2019
9/11/2019
7.00
MIRU
WHDBOP
DOPE
P
Start BOP testing, 250 psi Low/3,500
0.0
0.0
13:00
20:00
psi High/2,500 psi annular witness
was waived by Adam Earl (AOGCC).
Fail / Replace on C-4, Test complete
9111/2019
911112019
1.80
MIRU
Rl G M -NT
PRTS
P
Test PDL's and TT line
0.0
0.0
20:00
21:48
9/11/2019
9/11/2019
1.60
MIRU
RIGMNT
CTOP
P
Skid injetor to rig loor. Prep CT and
0.0
0.0
21:48
23:24
install coil tubing connecor, Pull test to
35K
9/11/2019
9/12/2019
0.60
MIRU
RIGMNT
CTOP
P
Test wire - good, Head up E -line
0.0
0.0
23:24
00:00
1
9/12/2019
9/12/2019
0.75
MIRU
RIGMNT
CTOP
P
Continue heading up E line and
0.0
0.0
00:00
00:45
testing.
9/12/2019
9/12/2019
2.00
MIRU
RIGMNT
CTOP
P
Fill CT with seawater, PT inner reel
0.0
0.0
00:45
02:45
iron, CTC, and upper quick connect to
4000 PSI
9/12/2019
9/12/2019
1.00
MIRU
P
Check pack offs. Install floats in UQC
0.0
0.0
02:45
03:45
911212019
9112/2019
1.00
SLOT
PULD
P
P/U BHA#i. FCO with straight motor
0.0
0.0
0345
04:45
and 2.80" D-331 mill. Load into PDL.
rRGMNCTOP
Hang motor in well
9/12/2019
9/12/2019
1.75
SLOT
PULD
P
PJSM. PD BHA#1, surtace test tools
0.0
0.0
04:45
06:30
(good), stab INJH, tag up reset
counters.
9/12/2019
9/12/2019
3.00
SLOT
TRIP
P
RIH to 2,000', adjust gooseneck,
0.0
2,837.0
0630
09:30
inspect gooseneck rollers (good),
continue IH, park @ 2,837', re -adjust
gooseneck, make back-up cable for
PCL cabinet (ethernet), repair
fberoptic calble in putz
9/12/2019
9/12/2019
1.50
SLOT
WELLPR
TRIP
P
Continue IH, RIW 15k
2,837.0
9,180.0
09:30
11:00
9/12/2019
9/12/2019
0.30
SLOT
WELLPR
DLOG
P
Log K1 marker (+9.5'), PUW 46 k,
9,180.0
9,213.7
11:00
11:18
close EDC,
9/12/2019
9/12/2019
0.30
SLOT
WELLPR
TRIP
P
PUH
9,213.7
9,280.0
11:18
11:36
9/12/2019
9/12/2019
0.70
SLOT
WELLPR
DLOG
P
Log CCL 9,280'to 9,450' @ 20 fpm,
9,280.0
9,450.0
11:36
12:18
pumping 1.9 bpm/3,688 psi
Page 1122 Report Printed: 10/3/2019
Operations Summary (with Timelog Depths)
r
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Depth
Shen Time
End Time
our(hr)
Phase
Do Code
Activity Code
Time P -T -X
P
Operation
POOH, chasing milling fluid to surface,
(MB)
9,450.0
End Depth(flK8)
500.0
9112/2019
9/12/2019
1.40
SLOT
WELLPR
TRIP
1218
13:42
@ 746' notice scale and sand on
shaker
9/12/2019
9112/2019
-c).30
SLOT
WELLPR
TRIP
P
Perform jog back in hole, to 1000,
500.0
51.3
13:42
14:00
PBOH
9/12/2019
9/12/2019
-1 60
SLOT
WELLPR
PULD
P
PUD CO BHA #1
51.3
0.0
14:00
9/12/2019
15:36
9/12/2019
-0 50
PROD1
RPEQPT
PULD
P
PIU NS HEW BHA
0.0
0.0
15:36
-g/1 2/20-19
16:06
9/12/2019
-0 30
PROD1
RPEQPT
PULD
P
PD, BHA#2 NS/HEW
0.0
73.5
16:06
9/1212019
16:24
9/12/2019
1.00
PROD1
RPEQPT
PULD
T
Tool tagging shallow in PDL. Lay
73.5
0.0
16:24
17:24
down tool inspect. HEW hanging up
on no go pll ate. Modify HEW
9/12/2019
9/12/2019
-1 30
PROD1
RPEQPT
PULD
P
PD BHA#2 Northern SoultionsHEW
0.0
73.5
17:24
18:42
whipstock. Make up to coil and
surface test tool.
9/12/2019
9/12/2019
2.00
PR0D1
RPEQPT
TRIP
P
RIH, BHA #2 Whipstock, EDC open
73.5
9,210.0
18:42
9/12/2019
20:42
9/12/2019
0.20
PRODt
RPEQPT
DLOG
P
Log K1 for+ 1.5' correction.
9,210.0
9,242.0
20:42
20:54
PUW=39K
-9/_1 21201-9
9/12/2019
0.30
PROD1
RPEQPT
TRIP
P
Continue into set depth @ 9438.78'.
9,242.0
9,438.0
Oriented to high side. Close EDC.
20:54
21:12
Pressure up setting tool. See tool shift
@ 3900 PSI. Set down 4K. Good
9/12/2019
9/12/2019
1.80
PROD?
RPEQPT
TRIP
P
Trip out after seting whipstock, EDC
9,438.0
60.0
21:12
9/12/2019
23:00
9/12/2019
0.60
PROD1
RPEQPT
PULD
-P7
open
Tag up and space out. PJSM PUD
80.0
0.0
23:00
23:36
BHA#2
9/12/2019
9/13/2019
-040
PROD1
RPEQPT
PULD
P
P/U NS setting tool. M/U mill motor,
0.0
0.0
pup, 2.80 NS window mill and 2.79
23:36
00:00
String reamer
9/13/2019
9/13/2019
1.30
PRODi
WHPST
PULD
P
Pressure deploy BHA#3 with WFT 1
0.0
76.6
fixed bend motor, NS 2.80 window
00:00
01:18
mill, NS 2.79 string reamer and 10'
pup. Make up to coil and surface test.
9/13/2019
9/13/2019
-1 .60
PRODI
WHPST
TRIP
P
RIH BHA#3
76.6
9,210.0
0118
9/13/2019
02:54
9113/2019
-0 10
PRODi
W H P S T
DLOG
p7-
Log K1 for+.5'
9,210.0
9,238.0
0254
03:00
9/13/2019
9/13/2019
0.40
PROD1
WHPST
TRIP
P
Continue in well. Dry tag whipstock @
9,238.0
9,433.0
03:00
03:24
9433'. PUH, PUW=40K
9113/2019
9113/2019
5.25
PROD1
WHPST
WPST
P
Bring pumps on 1.79 BPM @ 3631
9,433.0
9,435.3
PSI FS, BHP=3927. Call milling pinch
03:24
08:39
point @ 9432.4
9/13/2019
9/13/2019
3.20
PROD1
WHPST
WPST
P
Mill exited the casing, continue time
9,435.3
9,459.0
08:39
11:51
milling with string reamer at exit.
9/13/2019
9/13/2019
0.85
PROD1
WHPST
REAM
P
Ream casing exit @ 60 fph/1.0' fpm,
9,459.0
9,459.0
11:51
12:42
w/sweep, perform dry drift (clean)
9113/2019
9/13/2019
-1 50
PROD?
WHPST
TRIP
15
POOH, chasing sweep to
9,459.0
73.5
1242
14:12
surface.PJSM
9/13/2019
9/13/2019
-1 20
PR0D1
WHPST
PULD
P
Tag up at surface, PUD milling BHA
73.5
0.0
1412
15:24
"" Note: Mills within gauge 2.80"od no
go
9/13/2019
9/13/2019
0.30
PROD1
DRILL
CTOP
P
Slide cart forward and install nozzle,
0.0
0.0
stab INJH, get stack and surface lines,
15:24
15:42
unstab INJH, brake nozzle off,
9113/2019
9/13/2019
1.30
PROD1
DRILL
PULD
P
PD pre -loaded build BHA #4 w/2.4°
0.0
72.2
15:42
17:00
ako motor
Page 2122 ReportPrinted: 10/3/2019
Operations Summary (with Timelog Depths)
IC -06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Tune
Our (hr)
Phase
Op Code I
Activity Cade
Time P -T -%Operation
(NCB)
End Depth (NCB)
9/13/2019
9/13/2019
1.80
PROD1
DRILL
TRIP
P
Tag up, reset counters, RIH wtih BHA
72.2
9,200.0
17:00
18:48
#4 Build assembly with 2.4° ako
motor, and new HHC bit
9/1312019
9113/2019
0.10
PROD1
DRILL
DLOG
P
Log K1 for +3.5'correction, lose EDC,
9,200.0
9,228.0
18:48
18:54
PUW=40K, RIW=16.9
9/13/2019
9/13/2019
0.20
PROD1
DRILL
TRIP
P
Continue in hole. good pass through
9,228.0
91460.0
18:54
19:06
window. Bobble at BOW
9/13/2019
9/1312019
0.60
PROD1
DRILL
DRLG
P
9460', Drill, 1.8 BPM @ 3742 PSI FS,
9,460.0
9,495.0
19:06
19:42
1
BHP=3841
9/13/2019
9/1312019
0.40
PROD?
DRILL
WPRT
P
Stall, PUW=40K. PUH through
9,495.0
9,200.0
19:42
20:06
1
window. tie into Kt
9/13/2019
9/13/2019
0.30
PROD1
DRILL
DLOG
P
Log K1 for+1'. RBIH through window.
9,200.0
9,470.0
20:06
20:24
Log RA @ 9437.5. TOWS=9430.5,
TOW=9432.5, BOW=9435.5
9/13/2019
9113/2019
0.10
PROD1
DRILL
TRIP
P
Trip in to Drill
9,470.0
9,495.0
20:24
20:30
9/13/2019
9/14/2019
3.50
PROD1
DRILL
DRLG
P
9495', Drill, 1.8 BPM @3676 PSI FS,
9,495.0
9,709.0
20:30
00:00
BHP=3888. Hard time getting past
9495. Low differential with High
DHWOB. Drilling break @ 9500 ROP+
60-80 FPH
9114/2019
9/14/2019
0.40
PRODt
DRILL
DRLG
P
Continue drilling build section, 1.8
9,709.0
9,745.0
00:00
00:24
BPM @ 3676 PSI FS, BHP=3906
9/14/2019
9/14/2019
2.20
PROD1
DRILL
TRIP
P
Call end of build, Pump sweeps,
9,745.0
72.0
00:24
02:36
PUW=42k. recip twice through 7"
casing. AVG DLS=47.25°
9/14/2019
9/14/2019
0.70
PRODi
DRILL
PULD
P
At surface, Tag up and space out.
72.0
72.0
02:36
03:18
1
PUD BHA#4.
9114/2019
9114/2019
1.70
PROD1
DRILL
PULD
T
Pull BHA into lubricator assembley
72.0
72.0
03:18
05:00
hung @ 10 out of -18 turns of slickline
winch. Try closing master to move
BHA around. No good. Try both swabs
them Aannular bag in turn. Try
pumping across the top. try pumping
into tangos. No good. Pressure up
surface safety valve, No good. Dump
SSSV, unable to bleed off well. Try
pressuring up WH. No good. Consult
town. Shift fluid around to line up
12PPG fluid down well for kill.
9/14/2019
9114/2019
1.00
PROD1
DRILL
PULD
T
Line up and bullhead 110 BBIs 12.0
72.0
72.0
05:00
06:00
PPG down tubing @ 3 BPM,
WHP=1175
9/14/2019
9/14/2019
1.10
PROD1
DRILL
PULD
T
Monitor WHP 749 psi, pressure
72.0
72.0
06:00
07:06
dropping,continue to monitor WHP, 81
psi WHP, open choke bleed pressure
to 70 psi, shut choke back in, and
continue to monitor WHPWHP 10 psi,
open whiney on PDL, well is dead,
PJSM
9/14/2019
9/14/2019
0.50
PROD1
DRILL
PULD
P
LD, build assembly over a dead well
72.0
0.0
07:06
07:36
9/14/2019
9/14/2019
0.75
PROD1
DRILL
PULD
P
PU lateral assembly over a dead well,
0.0
80.3
07:36
08:21
inspect pac-off
9/14/2019
9/14/2019
1.00
PROD1
DRILL
DISP
T
Displace coil to 12.0 ppg KWF wtih
80.3
488.0
08:21
09:21
open EDC
-@48V,
9/14/2019
9114/2019
1.50
PROD1
DRILL
TRIP
P
RIH, surface test agitator
488.0
9,280.0
09:21
10:51
attempt to obtain screen shot
9/14/2019
9/14/2019
0.25
PROD1
DRILL
DLOG
P
Log formation for depth control (0.0')
9,280.0
9,393.0
10:51
11:06
9/14/2019
9/14/2019
0.60
PROD1
DRILL
TRIP
P
Continue IH
9,393.0
9,730.0
11:06
11:42
Page 3/22 Report Printed: 1 01312 01 9
Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Tlme Log
Start Dapih
Start Time EM Time Dur(hr) Phase Op Cade Aavq Code Time P -T -X Dperaaan (Win End Depth(ftKa)
9/14/2019 9/14/20191.75 PROD1 DRILL DISP T Displace well to new drilling Fluid, 9,730.0 9,730.0
11:42 13:27 System #1,PUH slowly.
9/14/2019
9/14/2019
1.30
PRODt
DRILL
DRLG
P
OBD, 1.9 bpm at 4,555 psi, FS=1,442
9,730.0
9,953.0
13:27
14:45
psi, WHP=256, BHP=3,953, IA=2,
OA=64
" Note: Re -head drillers side Slickline
Unit.
9/14/2019
9/14/2019
1.25
PROD1
DRILL
DRLG
P
OBD, 1.6 bpm at 3,914 psi,
9,953.0
10,150.0
14:45
16:00
Diff --1,240, WHP=219, BHP=3,912,
IA=7, OA=70, increase pump back up
to full drilling rate 1.9 bpm at 4,555
psi, Diff --1,264 psi.
9/14/2019
9/14/2019
0.30
PROW
DRILL
WPRT
P
Short wiper up hole to the EOB 9,745',
10,150.0
9,745.0
16:00
16:18
PUW=45 k
9/14/2019
9/14/2019
0.25
PROM
DRILL
WPRT
P
Wiper back in hole, RIW 14 k
9,745.0
10,150.0
16:18
16:33
9/14/2019
9/14/2019
0.60
PROD1
DRILL
DRLG
P
BOBD, 1.9 bpm at 4,550 psi,
10,150.0
10,270.0
16:33
17:09
Diff=1,280 psi, WHP=239,
BHP=3,939, IA=8. OA=71
9/14/2019
9/14/2019
0.10
PR0D1
DRILL
WPRT
P
Pull BHA wipe, grab survey,
10,270.0
10,270.0
17:09
17:15
1
PUW=45K
9/14/2019
9/14/2019
1.85
PROD1
DRILL
DRLG
P
10„270', Drill, 1.8 BPM @ 4425 PSI
10,270.0
10,428.0
17:15
19:06
1
1
FS, BHP=3943
9/14/2019
9/14/2019
0.10
PRODt
DRILL
WPRT
P
10428, BHA Wiper, PUW=57K
10,428.0
10,428.0
19:06
19:12
9/14/2019
9/14/2019
2.20
PROM
DRILL
DRLG
P
10,428', Drill, 1.8 BPM @ 4219 PSI
10,428.0
10,554.0
19:12
2124
FS, BHP=3920, 10,513' faulted out of
zone. Gamma 160+, ROP 30FPH
9/14/2019
9/14/2019
1.00
PROD1
DRILL
WPRT
P
10554 wiper to window with sweeps,
10,554.0
9,300.0
21:24
22:24
PUW=50K, Jet 7" up to 9300' with
sweeps, High gamma area good on
this wiper
9/14/2019
9/14/2019
0.10
PRO01
DRILL
WPRT
P
Wiper back through window
9,300.0
9,445.0
22:24
22:30
9/14/2019
9/14/2019
0.10
PRODt
DRILL
DLOG
P
Log RA marker for +4' correction
9,445.0
9,480.0
22:30
2236
9/14/2019
9/14/2019
0.50
PROM
DRILL
WPRT
P
RBIH to drill, No poor hole conditions
9,480.0
10,556.0
22:36
23:06
9/14/2019
9/15/2019
0.90
PROD1
DRILL
DRLG
P
10556', Drill, 1.8 BPM @ 4361 PSI
10,556.0
10,566.0
23:06
00.00
FS, BHP=3925
9/15/2019
9/15/2019
0.80
PROM
DRILL
DRLG
P
1586', Drill 1.8 BPM @ 4361 PSI FS,
10,586.0
10,638.0
00:00
00:48
BHP=3951
9/15/2019
9/15/2019
0.10
PROM
DRILL
WPRT
P
BHA wiper, PUW=50K
10,638.0
10,638.0
00:48
00:54
9/15/2019
9/15/2019
2.40
PROD1
DRILL
DRLG
P
10638', Drill, 1.81 BPM @ 4360 PSI
10,638.0
10,810.0
00:54
03:18
FS, BHP=3945
9/15/2019
9/15/2019
0.20
PROD1
DRILL
WPRT
P
Pull mini wiper. Get surveys off bottom
10,810.0
10,810.0
03:18
03:30
due to high vibration levels, PUW=47K
9/15/2019
9/15/2019
2.30
FR
DRILL
DRLG
P
1081', Drill 1.80 @ 4360 PSI FS,
10,810.0
10,954.0
03:30
05:48
BHP=3955
9/15/2019
9/15/2019
0.30
PROD1
DRILL
WPRT
P
Wipe up hole, PUW 45 k
10,954.0
9,980.0
05:48
06:06
9/15/2019
9/15/2019
0.30
PROD1
DRILL
WPRT
P
Wiper back in hole, RIW 12 k
9,980.0
10,954.0
06:06
06:24
9/15/2019
9/15/2019
1.00
PR0D1
DRILL
DRLG
P
BOBD, 1.88 bpm at 4,882 psi,
10,954.0
11,095.0
06:24
07:24
Diff --1,252 psi, WHP=218,
BHP=3,995, IA=22, OA=87
9/15/2019
9/15/2019
0.50
PR0D1
DRILL
WPRT
P
Lost returns (0.4 bpm), PUH PUW 45
11,095.0
11,095.0
07:24
07:54
k, 10690', RBIH, slowly healing up.
Page 4122 ReportPrinted: 1013120191
Operations Summary (with Timelog Depths)
r
1 C-06
Job: DRILLING SIDETRACK
Rig: NABORS CDR3-AC
Time Log
Start Depth
start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(flKB)
11,095.0
End DepM(M1KB)
11,264.0
9/15/2019
9/15/2019
1.90
PROD1
DRILL
DRLG
P
BOBD, 1.88 bpm at 4,885 psi,
Diff=1,250, WHP=234, BHP=3,995,
07:54
09:48
IA=22, OA=87
9/15/2019
9/15/2019
0.85
PRODI
DRILL
WPRT
P
Lost all returns, pull wiper to the
11,264.0
9,180.0
09:48
10:39
window, PUW 52 k
9/15/2019
9/15/2019
-0 20
PROD1
DRILL
DLOG
P
Log K1 marker (+3.0)
9,180.0
9,233.6
10:39
9/15/2019
10:51
9/15/2019
0.60
FROM
DRILL
WPRT
P
Wiper back in hole, RIW 17 k, no
9,233.6
11,264.0
returns, close choke, continue RIH
10:51
11:27
630 psi WHP, 11.7ppg ECD
9/15/2019
9/15/2019
0.85
PROD1
DRILL
DRLG
P
BOBD, 1.86 bpm at 4,435 psi,
11,264.0
11,350.0
Diff=1 250, WHP=234, BHP=3,995,
1127
12:18
IA=22, OA=87
9115/2019
9/15/2019
-1 00
PROD1
DRILL
DRLG
P
BOBD, snubbing -5 k CTSW,
11,350.0
11,376.0
DHWOB=0.4-1.3 k 1.63 bpm at 4,060
12:18
13:18
psi, Diff=970, WHP=251, BHP=4,050,
IA=8, OA=84
9/15/2019
9/15/2019
3.25
PROD1
DRILL
DRLG
P
BOBD, 1.58 bpm at 4,430 psi,
11,376.0
11,664.0
Diff -970, WHP=251, BHP=4,050,
13:18
16:33
IA=8, OA=84
9/15/2019
9/15/2019
0.50
PROD1
DRILL
WPRT
P
Wiper up hole, PUW 52 k
--TI-664.0
10,664.0
16:33
-§-/ 15/20-19
17:03
-ET/1 5120-19
0.30
PROM
DRILL
WPRT
P
Wiper back in hole, RIW 6 k
10,664.0
11,664.0
1703
9/15/2019
17:21
9115/2019
1.40
PROD1
DRILL
DRLG
P
BOBD, 1.81 BPM @ 4865 PSI FS,
11,664.0
11,808.0
1721
18:45
BHP=4093, Choke shut
9/15/2019
9/15/2019
0.10
PROM
DRILL
WPRT
P
BHA wiper, PUW=491<
11,808.0
11,806.0
18:45
9/15/2019
18:51
9/15/2019
3.15
PROD1
DRILL
UK
P
11,808', Drill, 1.8 BPM @ 5005 PSI
11,808.0
11,962.0
18:51
22:00
FS, BHP=4112, Choke shut
9/15/2019
9/16/2019
2.00
PROD1 7
11962, Call TD @ X -Y coordinate.
11,962.0
9,420.0
Pump 10 X 10 Sweeps. Open choke
22:00
00:00
at 7 inch. Pumping 1.8 Returns @ 1.2
BPM
9/16/2019
9116/2019
1.90
PROD1
DRILL
WPRT
P
On wiper trip to swab. Unloaded
9,420.0
70.0
cuttings @ - 500'. Jog back in hole to
00:00
01:54
1000'. Continue out of well.
9/16/2019
9/16/2019
1.70
PROD,
DRILL
DRLG
P
At surface, Tag up, reset counters,
70.0
9,200.0
01:54
03:36
Trip back in well
9/16/2019
9116/2019
0.10
TROD
DRILL
DLOG
P
Log Ki for -1' correction
9,200.0
9,280.0
0336
9/16/2019
03:42
9/16/2019
0.40
PRODi
DRILL
TRIP
P
RIH to 9401. Get static pressure.
9,280.0
9,401.0
sensor depth TVD 6473.6, Start test a
03:42
04:06
3843 annular, Bled down to 3731 PSI
in 10 minutes. Down to 11.1 PPG MW
9/16/2019
9/16/2019
1.00
PROD1
DRILL
TRIP
P
Continue in hole to confirm TD
9,401.0
11,964.0
@11,964, RIW=14.3, PUW=45K, Trip
04:06
05:06
out pumping 8.5 Beaded liner pill
9/16/2019
9/16/2019
0.90
PROD1
DRILL
TRIP
P
POOH, pumping 8.5 ppg beaded liner
11,964.0
9,539.0
05:06
911612019
06:00
9/1612019
200
TROD
DRILL
TRIP
P
pill
Continue POOH pumping 11.4 ppg
9,539.0
80.3
06:00
08:00
completion fluid
9/16/2019
9/16/2019
0.50
PRODi
DRILL
(5W-FFAt
WFF
P
surface, check well for flow, PJSM
80.3
80.3
0800
08:30
"Note: Static loss rate 9 bbl/hr
9/16/2019
9/16/2019
1.00
PROD1
DRILL
PULD
P
LD drilling assembly #5
80.3
0.0
08:30
9116/2019
09:30
9/16/2019
0.35
COMPZI
CASING
PUTB
P
Prep RF for liner operations
0.0
0.0
09:30
9/16/2019
09:51
9/16/2019
3.20
COMPZ1
CASING
PUTB
P
Start ::I' -L1 slotted liner completion
0.0
2,101.3
09:51
13:03
1
w/53 joints and Liner top billet
Page 5122 Report Printed: 10/3/2019
Uperations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log stag Depth
Siad Tlme End Time Dur(hh Phase Op Code Activity Code Time P -T-% Operation (MB) End Dept (ftKB)
2,101.3 2,145.5
9/16/2019 9/16/2019 0.90 COMPZI CASING PULD P PJSM, PU CmiTrak tools.
1303 13:57
9/16/2019
9/16/2019
1.75
COMPZI
CASING
RUNL
P
Tag up, reset counters, RI with BHA
2,145.5
10,374.0
13:57
15:42
#6
" Note: Hanging weight 20 k surface
weight
9/16/2019
9/16/2019
0.20
COMPZI
CASING
RUNL
P
Initial set down 10,374', PUW 38 k
10,374.0
10,376.0
15:42
15:54
with a little drag, work pipe for a short
period, continue in hole
9/16/2019
9/16/2019
1.30
COMPZt
CASING
RUNL
P
Continue IH, set down @ 11,568',
10,376.0
11,568.0
15:54
17:12
TOL=9 466.7', CTC=9422.7', work
pipe unable to move up or down per
the weak point (billet 24k), GS rated
49k
9/16/2019
9/16/2019
0.30
COMPZI
CASING
RUNL
T
Dicuss with town team, bring pump
11,568.0
11,568.0
1712
17:30
online, release liner, PUW 35 k, build
50 bbl beaded 11.4 ppg liner running
pill, RBIH latch up to liner, PUW 44 k,
seems we are re -latched into liner,
standby for liner pill
9/16/2019
9/16/2019
0.70
COMPZI
CASING
RUNL
T
Standby for beaded liner running pill
11,568.0
11,568.0
1730
18:12
9/16/2019
9/16/2019
3.00
COMPZI
CASING
RUNL
T
Pump 50 BBI beaded liner running pill
11,568.0
18:12
21.12
down backside. CT in compression.
Pump 70 BBIs -20 BBIs pill past
window. Work pipe +65K to -9K. No
go. Pump 5 more bbls. CT in tension.
Work pipe no good. Go to neutral
weight pump 5 bbls down CT. Work
pipe No good. Pump down back side
1.5 BPM while working pipe. No
movement. Consult town. Trip for
agitator
9/16/2019
9/16/2019
1.70
COMPZI
CASING
TRIP
T
Lineup down CT, Pump 1.5 BPM.
11,568.0
70.0
21:12
22:54
Release off fish. PUW=40K,
TOF=9469, Remove liner length left in
hole from counters
9/16/2019
9/16/2019
1.00
COMPZI
CASING
PULD
T
At surface, PJSM lay down BHA on
70.0
50.3
2254
23:54
dead well. No Flow test good. Unstab
injector. Inspect CT for Flat spots. Back
off GS. M/U agitator and GS spear.
M/U to coil and surface test. Check
pack offs
9/16/2019
9/17/2019
0.10
COMPZI
CASING
TRIP
T
Trip in hole BHA #7
50.3
480.0
23:54
00:00
9/17/2019
9/17/2019
1.60
COMPZI
CASING
TRIP
T
Stop at 480', Shallow test agitator.
480.0
9,185.0
00:00
01:36
Continue in well
9/17/2019
9/17/2019
0.30
COMPZ1
CASING
DLOG
T
Log K1 for+1.5'
9,185.0
9,221.0
01:36
01:54
9/17/2019
9/17/2019
0.10
COMPZI
CASING
TRIP
T
Continue in well. Clean pass through
9,221.0
9,467.0
01:54
02:00
window. Tag up @ 9467. Work pipe
two cycles PUW=58, DHWOB=IOK
9/17/2019
9/17/2019
0.70
COMPZI
CASING
CIRC
T
Put CT in light tension PUW=45K.
9,467.0
9,467.0
02:00
02:42
Bring pump on. Agitating. Roll CT to
8.5 PPG recovering 11.4
9/17/2019
9/17/2019
0.10
COMPZI
CASING
CIRC
T
Coil swapped to 8.5 PPG Duo vis
9,467.0
9,467.0
0242
02:48
Iight.Been agotating in light tension.
Shut down pump. Work pipe. Pull out
of billet @ 62K DHWOB=-16.8. Try to
relatch. No good.
9/17/2019
9/17/2019
0.50
COMPZI
CASING
CIRC
T
Set down on fish. 19K. Continue to
9,467.0
9,467.0
02:46
03:18
agitate down. 1.7 BPM, Recovering
KWF from well DHWOB-3.5K,
Page 6122 ReportPrinted: 10/3/2019
operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Dept,
StartTime EnETime Dur(hr) Phase Op Code I A Iy Cme TMe P -T-% Operation M13) I End Depth (WB)
9/17/2019 9/17/2019 0.50 COMPZ1 CASING CIRC T Bring DHWOB up to 4.7K, Continue 9,467.0 9,467.0
03:18 03:48 agitating down
9/17/2019
9/17/2019
0.40
COMPZ1
CASING
CIRC
T
Work pipe down, 8.5 PPG all around.
9,467.0
9,467.0
03:48
04:12
Bring annular down from 3850 to
365OPSI. Work pipe down
9/17/2019
9/17/2019
0.80
COMPZ1
CASING
CIRC
T
Line up down backside, 50 BBI
9,467.0
9,467.0
04:12
05:00
beaded liner running pill in 11.4,
displace bill around BHA
9/17/2019
9/1712019
2.25
COMPZI
CASING
CIRC
T
Continue agitating with 8-9k CTSW
9,467.0
9,467.0
05:00
07:15
stacked out 8 k
9/17/2019
9117/2019
1.25
COMPZ1
CASING
CIRC
T
Continue agitating with 8-9k CTSW
9,467.0
9,467.0
07:15
08:30
slacked out 8 k, build 50 bbl 8.5 ppg
beaded lubed pill
9/17/2019
9/17/2019
1.75
COMPZ1
CASING
CIRC
T
Diplace 50 bbl pill down the back side
9,467.0
9,467.0
08:30
10:15
9/17/2019
9/17/2019
1.30
COMPZI
CASING
CIRC
T
Pill displaced, work pipe, PUW 35 k,
9,467.0
9,467.0
10:15
11:33
RIW 14 k, no movemen, line back
down coil, stack out 13.9k, no
movement, stackout again 2.5k agitate
some more.
9/17/2019
9/1712019
1.40
COMPZI
CASING
TRIP
T
Unable to move liner assembly, POOH
9,467.0
45.3
11:33
12:57
9117/2019
911712019
1.20
COMPZ1
CASING
PULD
T
At surface, space out, PUD BHA #7
45.3
0.0
12:57
14:09
BOT GS Spear, and NOV Agitator
9/17/2019
9/17/2019
1.00
PROD2
STK
PULD
P
PU/MU/PD DrillinglBuild L1-01 lateral
0.0
62.6
14:09
15:09
9/17/2019
9/1712019
1.50
PROD2
STK
TRIP
P
Tag up, reset counters, RIFF -62.6
9,205.0
15:09
16:39
9/17/2019
9/17/2019
0.25
PROD2
STK
DLOG
P
Log K1 for depth control
9,205.0
9,228.0
16:39
16:54
9/17/2019
9/17/2019
0.30
PROD2
STK
TRIP
P
Continued IH tagged TOB at 9,467',
9,228.0
9,467.0
16:51
17:12
stacked out 1.6 k
9/17/2019
9/1712019
0.20
PROM
STK
KOST
P
PUH, PUW 38 k, obtain
9,467.0
9,467.0
17:12
17:24
parameters1.80 bpm 4,132 psi,
Diff=428 psi, WHP=354, BHP=3,861,
IA=17, OA=81
9/17/2019
2.10
PROD2
STK
KOST
P
Kickoff billet as per RP, time mill 1', 2',
9,467.0
9,470.0
19:30
and 3'
9/17/2019
0.30
PROD2
STK
KOST
P
Push on it to 9,472', seem to be
9,470.0
9,472.0
19:48
stacking weight, PU to PUW 35 k,
continue kicking off with controled
r24
WOB
9/17/2019
1.10
PROD2
DRILL
DRLG
P
Drill ahead, 1.78 bpm at 4,234 psi,
9,472.0
9,557.0
20:54
Diff --709, WHP=354, BHP=3,863,
IA=17, OA=81
9/1712019
9/17/2019
0.30
PROD2
DRILL
WPRT
P
Stall motor, PUW 41 k, continue up
9,557.0
9,250.0
20:54
21:12
hole to dry drift kickoff point, slight
bobble pulling across billet
9/17/2019
9117/2019
0.20
PROM
DRILL
WPRT
P
Dry drift kickoff point (clean), continue
9,250.0
9,557.0
21:12
21:24
1
IH
9/17/2019
911712019
1.60
PROD2
DRILL
DRLG
P
BOBD, 1.79 bpm at 4,400 psi,
9,557.0
9,720.0
21:24
23:00
Diff --532, WHP=351, BHP=3,895,
IA=22, OA=88
9/17/2019
9/17/2019
0.30
PROD2
DRILL
WPRT
P
TD, build section, wiper to the window,
9,720.0
9,400.0
23:00
23:18
PUW 37 k, Jog 7inch, open EDC
9/17/2019
9/18/2019
0.70
PROD2
DRILL
TRIP
P
POOH, At 5841' at midnight
9,400.0
5,841.0
23:18
00:00
9/18/2019
9/18/2019
1.10
PROD2
DRILL
TRIP
P
Continue out of well
5,841.0
62.0
00:00
01:06
9118/2019
9/18/2019
1.10
PROD2
DRILL
PULD
P
Al surtace, Tag up and space out,
62.0
0.0
01:06
02:12
PJSM PUD BHA #8.
Page 7122 Report Printed: 101312019,
operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log Stan Depth
Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operaton (IKB) End Depth (ftKB)
0.0
9/18/2019 9/18/2019 0.50 PROD2 DRILL BOPE P Pick up BOPE test joint perform Bi- 0.0
0212 02:42 weekly BOPE function test
9/18/2019
9/18/2019
0.80
PR0D2
DRILL
PULD
P
TD -BHA #9 from pre loaded PDL..7°
0.0
78.3
0242
03:30
AKO motor, Hyc A3 bi center. Make up
to coil and surface test. Check pack
offs. Tag up and reset counters.
9/18/2019
9/18/2019
1.90
PROD2
DRILL
TRIP
P
R I H BHA #9, Shallow test agitator @
78.3
9,205.0
03:30
05:24
500'
9/18/2019
9/18/2019
0.10
PROD2
DRILL
DLOG
P
Log K1 for -.5'
9,205.0
9,231.0
05:24
05:30
9/18/2019
9/18/2019
0.40
PROD2
DRILL
TRIP
P
Continue in well, Set down in bottom
9,231.0
9,720.0
05:30
05:54
of window 9437'. PUH roll pump then
go through window clean. Clean past
billet
9/18/2019
9/18/2019
2.80
PROD2
DRILL
DRLG
P
9720', Drill 1.81 BPM @ 5458 PSI FS,
9,720.0
10,020.0
0554
08:42
BHP=3977
9/18/2019
9118/2019
0.60
PR0D2
DRILL
WPRT
P
10020', Wiper trip to window, perform
10,020.0
9,451.0
0842
09:18
MAD pass 9725 to 9451
9/18/2019
9/18/2019
0.10
PROD2
DRILL
[LOG
P
9451 Log RA marker for +2' correction
9451.0
9,476.0
09:18
09:24
9/18/2019
9/18/2019
0.20
PROD2
DRILLWPRT
P
9476 RBIH to drill
9,476.0
10,020.0
0924
09:36
9/18/2019
9/18/2019
2.20
PROD2
DRILL
DRLG
P
10020', Drill. 1.8 BPM @ 5595 PSI
10,020.0
10,420.0
0936
11:48
FS, BHP=4006
9/18/2019
9/18/2019
0.70
PROD2
DRILL
WPRT
P
10420', Wiper trip, 1000%PUW=35K
10,420.0
10,420.0
1148
12:30
9/18/2019
9/18/2019
2.10
PROD2
DRILL
DRLG
P
10420', Drill, 1.8 BPM @ 5773 PSI
10,420.0
10,559.0
1230
14:36
FS, BHP=4104
9/18/2019
9/18/2019
0.10
PROD2
DRILL
WPRT
P
BHA wiper, PUW=34K
10,559.0
10,559.0
1436
14:42
9/18/2019
9118/2019
1.40
PROD2
DRILL
-[7R-LG
P
10559', Drill, 1.8 BPM _@5844 PSI
70 559.0
10,759.0
14:42
16:06
FS, BHP=4032. _SRV up to 57K.
Consult mud eng. Get _SRV back to
plan
9/18/2019
9118/2019
0.10
PR0D2
DRILL
WPR7
P
10759', Pick up to get new pressures,
10,759.0
10,759.0
16:06
16:12
PUW=37K
9/18/2019
9/18/2019
0.50
PROD2
DRILL
DRLG
P
10759', Drill, 1.8 BPM @5690 PSI FS,
10,759.0
10,820.0
16:12
16:42
1
DHWOB=3.1K
118
9/2019
9/18/2019
0.9D
PROD2
DRILL
WPRT
P
10,820'. Wiper to window, Jet 7"
10,820.0
9,196.0
16:42
17:36
casing. Tie in for depth control
9/18/2019
9/18/2019
0.10
PROD2
DRILL
DLOG
P
Log K1 for+3' correction
9,196.0
9,232.0
17:36
17:42
9/18/2019
9/18/2019
0.80
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW = 13K, set -down
9,232.0
10,820.D
1742
18:30
6.51< WOB at BOW, got through on
second attempt
9118/2019
9/18/2019
4.10
PROD2
DRILL
DRLG
P
Drilling, FS = 1300 psi @ 1.8 bpm,
10,820.0
11,218.0
18:30
22:36
CWT = 12.8 @ 1 K WOB, annular -
3982 psi, WHP = 122 psi, 11.4 ppg @
widnow, pump = 5870 psi, dip= 1442
psi drilling, IA= 39 psi, OA= 104 psi,
97% returns, PUW =38K @ 11,144'
Lower ROP 11,178'- 11,190'(-50 fph)
9/18/2019
9/18/2019
0.40
PROD2
DRILL
WPRT
P
Wiperup-hole, PUW=40K
11,218.0
10,270.0
22:36
23:00
9/18/2019
9118/2019
0.40
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW = 11.9K
10,270.0
11,218.0
23:00
23:24
9/18/2019
9/19/2019
0.60
PROD2
DRILL
DRLG
P
Drilling, FS = 1300 psi @ 1.8 bpm,
11,218.0
11,268.0
23:24
00:00
CWT = 7.4K @ 2K WOB, annular =
4039 psi, WHP = 101 psi, pump =
6118 psi
Page 8144 ReportPrinted: 1 01312 01 9
Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Stan Time
End Time
Dur(m)
Phase
Op Code
Activity Code
DRLG
Time PJA
P
Operation
Drilling, FS = 1300 psi @ 1.8 bpm,
(ftKB)
11,268.0
End Depth(WEI)
11,544.0
9/19/2019
9/19/2019
2.50
PROD2
DRILL
00:00
02:30
CWT = 6.71K @ 1.9K WOB, pump =
6024 psi, annular = 4048 psi, WHP =
70 psi, swap to system #3, new mud
hits bit at 11,479'
9/19/2019
9/19/2019
0.90
PROD2
DRILL
DRLG
P
Drilling, new mud all the way around,
11,544.0
11,620.0
0230
03:24
FS = 1284 psi @ 1.8 bpm, CWT = 4K
@ 1.7K WOB, annular = 3995 psi,
WHP = 368 psi, pump = 5757 psi
9/19/2019
9/19/2019
0.30
PROD2
DRILL
WPRT
P
Wiper up -hole, PUW = 44K
11,620.0
10,620.0
0324
03:42
9/19/2019
9/19/2019
0.40
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW = 8K, WOB bobble
10,620.0
11,620.0
0342
04:06
at -11,554'(1.1 K)
9/19/2019
9/19/2019
2.80
PROD2
DRILL
DRLG
P
Drilling, FS = 1290 psi @ 1.8 bpm,
11,620.0
11,753.0
0406
06:54
CWT = 8.7K @ 1.2K WOB, annular =
4000 psi, WHP = 343 psi, pump -
5710 psi, harder drilling beginning at
-11,625' (PUW's - 47K)
9/19/2019
9/19/2019
1.40
PROD2
DRILL
WPRT
P
Running low on surface weight. Hard
11,753.0
9,205.0
06:54
08:18
to maintain steady state drilling. Pull
wiper to tubing tail. PUW=53K. recip
7" X2.
9/19/2019
9119/2019
0.20
PROM
DRILL
DLOG
P
Log K1 for +5.5
9,205.0
9,225.0
08:18
08:30
9/19/2019
9/19/2019
0.80
PROD2
DRILL
WPRT
P
Continue wiper back in hole to drill
9,225.0
11,754.0
0830
09:18
9/1912019
9119/2019
2.20
PROM
DRILL
DRLG
P
11754', Drill, 1.81 BPM @ 5586 PSI
11,754.0
11,880.0
09:18
11:30
FS, BHP=4035, RIW=6.8K,
DHWOB=I.3K. ROP=41 FPH
9/19/2019
9/19/2019
0.20
TR
DRILL
WPRT
P
11880', Pull 100' BHAwiper,
11,880.0
1,188.0
11:30
11:42
PUW=43K
9
9/19/2019
3.10
PROD2
DRILL
DRLG
P
11,880', Drill, 1.81 BPM @ 5580 PSI
1,188.0
12,034.0
14:48
FS, BHP=4003, RIW=-5K.
BDHWOB=3K
9
9/19/2019
0.40
PROD2
DRILL
WPRT
P
Pu11250'wiper, PUW=38K
12,034.0
12,034.0
F14:48
15:12
9
9/19/2019
2.00
PROD2
DRILL
DRLGP
12,034', Drill, 1.80 BPM @ 5780 PSI
12,034.0
12,138.0
17:12
FS, BHP=4102, RIW=2K,
DHWOB=2.2K
19
9/19/2019
0.30
PROD2
DRILL
DRLG
P
Drilling, 1.8 bpm, annular = 4150 psi,
12,138.0
12,150.0
1712
17:30
WHP = 215 psi, pump = 6040 psi,
pumping beads to aid in weight
transfer (20 bbl in straight drilling Fluid)
9/19/2019
0.30
PROM
DRILL
WPRT
P
Wiper up -hole, PUW
12,150.0
11,153.0
17:48
9/19/2019
050
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW=8.8K
11,153.0
12,150.0
18:18
F30
9/19/2019
280
PROD2
DRILL
DRLG
P
Drilling, FS =1338 psi@ 1.8 bpm,
12150.0
12,270.0
21:06
CWT = 8.3K @ 1.3K WOB, annular=
4089 psi, WHP = 181 psi, pump =
6164 psi, difficult drilling when back on
bottom, struggling w/ weight transfer,
snubbing to -5K & 0.8K WOB,
pumping 25 bbl beaded pills to good
effect, avg ROP = 43 fph
9/19/2019
9/20/2019
2.90
PROD2
DRILL
DRLG
P
Drilling, annular = 4167 psi, WHP =
12,270.0
12,379.0
21:06
00:00
136 psi, pump = 5979 psi, struggling
w/ weight transfer unless beads are
coming around (continue pumping 25
bbl beaded pills built from active),
PUW = 43K from 12,373', struggle to
get to bottom after BHA wiper w/o
beads on back -side
Page 9122 ReportPrinted: 10/3/2019
Operations Summary (with Timelog Depths)
1c-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time I
our (hr)
Phase
Op Code
Activity Code
DRLG
Time PJA
P
Operation
Drilling, annular =4129 psi, WHP=
(fiKB)
12,379.0
End Depth (Wit)
12,471.0
9/20/2019
9/2019
/20
3.00
PROD2
DRILL
00:00
03:00
146 psi, pump = 6160', drilling through
low ROP interval, WOB = 2.6K @ 17
fph, break out
Pump 50 bbl lubed pill (2% 776 / 1%
LoTorq), hits bit at 12,417'), limited
benneft
9/20/2019
9/20/2019
2.30
PROD2
DRILL
DRLG
P
Drilling, CWT=-6K, WOB=0.6K,
12,471.0
12,550.0
0300
05:18
annular =4137 psi, WHIP = 128 psi,
pump = 6103 psi, continue pumping
beaded pills
9/20/2019
9/20/2019
1.60
PROD2
DLL
RI
WPRT
P
Wiper to window and jet 7 inch casing
12,550.0
9,205.0
0518
06:54
X2, PUW=39K
9/20/2019
9/20/2019
0.10
PROD2
DRILL
DLOG
P
Log tie in for+6'
9,205.0
9,224.0
06:54
07:00
9/20/2019
9/20/2019
1.90
PROD2
DRILL
WPRT
P
Wiper trip back in hale
9,224.0
12,550.0
07:00
0854
9/20/2019
9/20/2019
3.50
PROD2
DRILL
DRLG
P
12,550' Drill
12,550.0
12,672.0
08:54
12:24
9/20/2019
9/2012019
0.80
PROD2
DRILL
DRLG
P
Pull off bottom. Free spin has been
12,672.0
12,685.0
12:24
13:12
gradually climbing at 5946 @ 1.8
BPM. Lower flow rate to 1.7. Free spin
now 5685. Mud @ 40K _SRV
9/20/2019
9/20/2019
3.10
PROD2
DRILL
TRIP
T
Pressures still high. ROP low for being
12,685.0
73.5
13:12
16:18
in zone. No indications we are not in
zone. Trip to inspect BHA
9/20/2019
9/20/2019
1.10
PROD2
DRILL
PULD
T
At surface, PJSM. PUD BHA 119, bit
73.5
0.0
16:18
17:24
came out graded a 1-1
9/20/2019
9/20/2019
1.00
PROD2
DRILL
PULD
T
PD BHA#10 Lateral Assembly (NOV
0.0
73.0
17:24
18:24
agitator, new 0.7° AKO motor, RB
Baker P104 bit), slide in cart, change
out pack-offs, MU to coil, tag up, set
counters
9/20/2019
9/20/2019
1.80
PROD2
DRILL
WPRT
T
RIH, close EDC
73.0
9,200.0
18:24
20:12
Shallow test agitator: MD = 546', 1.8
bpm, FS = 1157 psi, pump = 5928 psi
9/20/2019
9/20/2019
0.20
PROD2
DRILL
DLOG
T
Log K1 for +45 correction, PUW =
9,200.0
9,234.0
20:12
2024
35K
1.10
PROD2
DRILL
WPRT
T
Continue RIH
9,234.0
12,685.0
21:30
9/20/2019
080
PROD2
DRILL
DRLG
P
Drilling, FS = 1043 psi @ 1.8 bpm,12685.0
12,732.0
22:18
CWT=7K@ 1.8K WOB, annular4157
psi, WHP = 50 psi, pump = 5150
r9/20/200199/20/2019
psi, -96e/ returns
Swap to PowerPro system (system
#4), new mud at bit, 12,686'
9/21/2019
1.70
PROD2
DRILL
DRLG
P
New mud all the way around, PU for
12,732.0
12,800.0
new parameters, FS = 1177 @ 1.8
22:18
00:00
bpm, CWT = 5.3K @ 1 K WOB,
annular = 4107 psi, WHP = 247 psi,
pump = 5128 psi, quickly begin
snubbing at -8K,
PUW = 42K from 12,766', bore
pressure climbs -5600 pis, perform
BHA wiper, bore pressure returns to
normal (-5300 psi)
Blow-down micro motion
9/21/2019
9/21/2019
2.00
PROD2
DRILL
DRLG
P
Drilling, CWT=-5K @ 0.3K WOB,
12,800.0
12,860.0
00:00
02:00
annular = 4113 psi, pump = 5122 psi
Page 10122 ReportPrinted: 101312019
Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan DePm
start Time
End Time
Dur (hr)
Phase
Op Code
Acd,nty Coda
Time P -T -X
Operation
(fixe)
End Depth (nKB)
9/21/2019
9/21/2019
2.00
PROD2
DRILL
DRLG
P
Drilling, FS = 1072 psi @ 1.8 bpm,
12,860.0
12,908.0
02:00
04:00
CWT = -6.9K @ 1.4K WOB, annular =
4131 psi, WHIP = 273 psi, pump =
5127 psi, pumped 20 bbl beaded pill
Begin seeing slight increase in rate
out at 12,866'(-1.9 bpm out), pinched
in choke a to 11.5 ppg at window,
drilled ahead, then begin losing fluid
holding 11.35 ppg, losses quickly
began to heal
9/21/2019
9121/2019
7.10
PROD2
DRILL
DRLG
P
Drilling, CWT = -4.8K @ 1.4K WOB,
12,908.0
13,043.0
04:00
11:06
annular = 4135 psi, WHIP = 262 psi,
pump = 5238 psi, returns -97%, pump
10 x 10 w/ beads
912112019
9/21/2019
0.10
PROD2
DRILL
WPRT
P
Pull BHA wiper, PUW=43
13,043.0
13,043.0
11:06
11:12
9/21/2019
9/21/2019
2.50
PROD2
DRILL
DRLG
P
13043', Drill, 1.8 BPM @ 5138 PSI
13,043.0
13,142.0
11:12
13:42
FS, BHP=4149. Unable to maintain
steady state drilling without beads.
Pump multiple 20 BBls beaded pills.
ROP with beads above 40 FPH
9/21/2019
9/21/2019
0.10
PROD2
DRILL
WPRT
P
13142', Pull BHA wiper
13,142.0
13,142.0
13:42
13:48
9/21/2019
9/21/2019
2.40
PROD2
DRILL
DRLG
P
13142', Drill, Low ROP. Pump multiple
13,142.0
13,165.0
13:48
16:12
beaded 25 BBI pills. Get to 13165'.
Unable to make any ROP. Unable to
stall motor. Not getting any Diff
pressure or reactive torque. Oscillate,
Pump more beads. Try to stall motor
with beads. Able to get 1.9K
DHWOB.No change in parameters.
Consult towm
9121/2019
9121/2019
3.30
PROD2
DRILL
TRIP
T
Trip out to inspect / swap out BHA,
13,165.0
78.0
16:12
19:30
PJSM
9/21/2019
912112019
2.00
PROD2
DRILL
PULD
T
PUD BHA#10, checks not holding,
78.0
0.0
19:30
21:30
change to PUD w/ failed checks (EDC
closed), pop off, see residual coil
pressue, stab on & bleed pump, good,
PT CTC to verify no leak path (4500
psi), good, complete PUD, bit came
out a 1-1
'Difficulty turning motor at surface
(motor appears to have failed)
9/2112019
9122/2019
2.50
PROM
DRILL
PULD
T
PU & PD BHA#11 Lateral Assembly
0.0
78.0
21:30
00:00
#3 (New MWD tools, NOV agitator,
Iron Horse 0.5° AKO motor, RB HYC
A3 bit), slide in cart, check pack -offs,
change out checks in UQC, MU to
coil, tag up, set counters
9/2212019
9/22/2019
0.40
PROD2
DRILL
PULD
T
Complete PD BHA#11 Lateral
78.0
78.0
00:00
00:24
Assembly #3 (New MWD tools, NOV
agitator, Iron Horse 0.5° AKO motor,
RB HYC A3 bit)
9122/2019
9/22/2019
1.70
PROD2
DRILL
TRIP
T
RIH w/BHA #11
78.0
9,200.0
00:24
02:06
Shallow test agitator: MD = 50301, 1.8
bpm, pump = 5350 psi, rip = 1421 psi
9/2212019
9/22/2019
0.10
PROD2
DRILL
OLOG
T
Log K1 for +3.5' correction, PUW =
9,200.0
9,232.5-
02:06
02:12
1
I
33K
Page 11122 Report Printed: 1013/2019
Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Oepm
Stan Time
End Time
our (hr)
Phew
Op Code
Activity Code
Time PJA
Operetion
(flKB)
End Depth (flKB)
9/22/2019
9/22/2019
1.80
PROD2
DRILL
TRIP
T
Continue RIH w/ BHA#11, clean
9,232.0
13,165.0
02:12
04:00
through window & past billet, observe
drop in MW out, take reduced density
returns to tiger -tank, CWT falls off
quickly begommomg at —12.875',
reduced speed to get to bottom
9/22/2019
9/22/2019
2.00
PROD2
DRILL
DRLG
P
Drilling, FS = 1510 @ 1.8 bpm, CWT =
13,165.0
13,213.0
04:00
06:00
-6.7K @ 1 K WOB, annular = 4189 psi,
WHP = 142 psi, pump = 5205 psi,
vibrations up to 6
9/22/2019
9/22/2019
0.60
PROM
DRILL
WPRT
P
13,213, High vibrations, Pick up to get
13,213.0
13,213.0
06:00
06:36
surveys. PUW=45K, Hard time turning
around. Work to get to bottom with
beads
9/22/2019
9/22/2019
1.00
PROD2
DRILL
DRLG
P
13213', Drill 1.78 BPM @ 5111 PSI
13,213.0
13,230.0
06:36
07:36
FS, BHP=4226, RIW=1.3K,
DHWOB=20. Pumping beaded pills
9/22/2019
9/22/2019
0.20
PROD2
DRILL
WPRT
P
13230, Pick up to get surveys,
13,230.0
13,230.0
07:36
07:48
PUW=50K, Tough to get turned
around
9/22/2019
9/22/2019
3.80
PROD2
DRILL
DRLG
P
13230', Drill, 1.78 BPM @ 5111 PSI
13,230.0
13,359.0
07:48
11:36
FS, BHP=4226, RIW=1 K with
DHWOB=.5K, ROP=40 FPH. Pump
many beaded pills 50 RBIs
9/22/2019
9/22/2019
0.20
PROD2
DRILL
WPRT
P
Pull 100'wiper, PUW=42K
13,359.0
13,359.0
11:36
11:48
9/22/2019
9/22/2019
4.20
PROD2
DRILL
DRLG
P
13359', Drill, 1.78 BPM @ 5202 PSI
13,359.0
13,449.0
11:48
16:00
FS, BHP=4249. Pumping beaded pills
almost continuiously 50 BBL then
spacer while batching up another one
9/22/2019
9/22/2019
0.10
PROM
DRILL
WPRT
P
13449, BHA Wper, PUW=39K
13,449.0
13,449.0
16:00
16:06
9/22/2019
9/22/2019
2.00
PROD2
DRILL
DRLG
P
13449, Drill, 1.8BPM @ 5189PSI FS,
13,449.0
13,494.0
16:06
18:06
BHP=4254. Still pumping beaded pills
to maintain drilling
9/22/2019
9/22/2019
2.10
PROD2
DRILL
DRLG
P
Drilling, CWT = -2K @ 0.2K WOB,
13,494.0
13,523.0
18:06
20:12
annular = 4267 psi, WHIP = 45 psi,
pump = 5509 psi, pumping 40 bbl
beaded pills to stay drilling, low ROP
& struggling to get weight to bit, avg
ROP = 11.5 fph, pump 10 bbl LoVis
followed by 40 bbl beaded mud
9/2212019
9/22/2019
0.30
PROD2
DRILL
WPRT
P
Wiper up -hole, PUW = 39K, lay in
13,523.0
12,523.0
20:12
20:30
beads on wiper
9/22/2019
9/22/2019
1.30
PROD2
DRILL
WPRT
P
Wiper in-hole, snubbing to bottom (up
12,523.0
13,523.0
20:30
21:48
to -8K), reduced RIH speed down to 6
fpm at times, reduce rate to 1 bpm @
13,488'to grab missed survey
9/22/2019
9/23/2019
2.20
PROD2
DRILL
DRLG
P
Drilling, FS = 1302 psi @ 1.8 bpm,
13,523.0
21:48
00:00
annular = 4267 psi, WHP = 77 psi,
pump = 5138 psi, pump 15 bbl LoVis
followed by 15 bbl beaded pill, notice
rate out drops as LoVis exits bit,
immediatly comes back as beaded pill
exits bit, possibly losing to formation
due to low LSRV in LoVis, pump 10
bbl LoVis followed by 40 bbl HiVis
beaded pill
Difficulty working to bottom after BHA
wipers (requires reducing rate &
speed)
Page 12122 ReportPrinted: 10/312019
Uperations Summary (with Timelog Depths)
IC -06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Steri Depen
Star) Time
End Time
Dur (hr)
Phase
op Cade
A ty Cade
Time P -T -X
Operation
(RKS)
End Dexh (WIR)
9123/2019
9/23/2019
2.00
PROD2
DRILL
DRLG
P
Drilling, snubbing to -81K, struggling w/
13,567.0
13,606.0
00:00
02:00
weight transfer, annular = 4277 psi,
pump = 5636 psi, continue pumping
10 x 40 bbl (Lots x Beaded HIVIs),
avg ROP = -20 fph
9/23/2019
9/23/2019
2.50
PROD2
DRILL
DRLG
P
Drilling, annular = 4211 psi, WHIP =
13,606.0
13,658.0
02:00
04:30
238 psi, pump = 5583 psi, WOB 0.1 K -
0.3K, continue pumping 40 bbl beaded
pills, avg ROP = -21 fph
PU, drop rate to grab missed surverys
due to vibration, immediatly bring rate
back to 1.8 bpm
9/23/2019
9/23/2019
1.70
PROD2
DRILL
DRLG
P
Drilling, annular =4248 psi, WHIP =
13,658.0
13,698.0
04:30
06:12
278 psi, pump = 4338 psi, continue
pumping 40 bbl beaded pills
9/23/2019
9/23/2019
0.10
PROD2
DRILL
WPRT
P
BHA wiper, Gel surveys, PUW=38K
13,698.0
13,696.0
06:12
06:18
9/23/2019
9/23/2019
2.90
PROD2
DRILL
DRLG
P
13698', Drill, 1.81 BPM @ 5184 PSI
13,698.0
13,726.0
06:18
09:12
FS, BHP=4239, RIW=-1.8K,
DHWOB=.3K. Bump 40 BBI beaded
pilss
9/2312019
9/23/2019
0.10
PROD2
DRILL
WPRT
P
13726, BHA wiper, PUW=47K
13,726.0
13,726.0
09:12
09:18
9/23/2019
9/23/2019
3.90
PROD2
DRILL
DRLG
P
13726', Drill, 1.72 BPM @ 5043 PSI
13,726.0
13,780.0
09:18
13:12
FS, BHP=4255. Hard time staying on
bottom drilling, Pump beaded pills,
frequent pick ups.
9/23/2019
912312019
0.10
PROD2
DRILL
WPRT
P
BHA wiper, PUW=42K
13,780.0
13,780.0
13:12
13:18
9/23/2019
9/23/2019
1.90
PROD2
DRILL
DRLG
P
13780', D611, 1.72 BPM @ 5075PSI
13,780.0
13,804.0
13:18
15:12
FS, BHP=4246
9/23/2019
9/23/2019
0.10
PROD2
DRILL
WPRT
P
BHA pick up, PUW=44K
13,804.0
13,604.0
15:12
15:18
9/2312019
9/23/2019
1.00
PROD2
DRILL
DRLG
P
13804', Drill, 1.82 BPM @ 5265 PSI
13,804.0
13,817.0
15:18
16:18
FS, BHP=4276
912312019
9/23/2019
1.70
PROD2
DRILL
WPRT
T
Town call TD, Go to pull off bottom.
13,817.0
13,817.0
16:18
18:00
Made initial pull to 65K and turned
around. Unable to move pipe. No
change on DHWOB. Able to orient
freely. Pull to 80K. Gel LVT ready to
pump. 40 BBI beaded pill going down
coil, relax to 3550 psi and pull to 80K
w/ beads around, no good
9/23/2019
9/23/2019
1.50
PROD2
DRILL
CIRC
T
Crew change, complete loading 20 bbl
13,817.0
13,817.0
18:00
19:30
LVT in pill pit, relaxed to 3549 psi
annular, attempt to pull free, no good,
pump 20 bbl LVT with pipe in tensioin
at 55K CWT, WHIP is down to 9 psi
when pumping at 1.8 bpm (possible
partial pack -oft), begin taking returns
to tiger -tank (density out dropping),
W/ 5 bbl LVT out bit, let soak & relax
to 3815 psi annular, pull to 80K twice,
no luck, can still orient freely, pump
additonal 10 bbl out bit (15 bbl LVT in
annulus), annular= 4364 psi @ 1.8
bpm in & 1 bpm out (appear to be
partially packed off), popped free after
soaking in tension at 55K for 5 min
Page 13122 Report Printed: 101312019
Uperations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Depth
Start-rime
End Tlme
our(hr)
Phase
Op Code
Activity Corte
Time P -T -X
T
Operation
Pipe free, 1.8 bpm in & 1 bpm out, pull13,817.0
(WB)
End Depth(W[3)
13,500.0
9/23/2019
1.20
PROM
DRILL
CIRC
20:42
off bottom at 12 fpm, annular = 4328
psi, continue circulating allowing pack
off to erode, rate climbs to 1.8 bpm
over 9 minutes (achieve 1 -for -1
returns), circulate bottoms up, pump
40 bbl beaded pill to aid in RBIH after
swab wiper
9/23/2019
9/24/2019
3.30
PROM
DRILL
WPRT
P
Pertorm swab wiper, lay in 40 bbl
13,500.0
78.0
2042
00:00
beaded pill, jog 7" casing
9/24/2019
9/24/2019
1.8o
PROD2
DRILL
TRIP
P
RBIH to confirm TD
78.0
9,200.0
00:00
01:48
9/24/2019
9/24/2019
0.20
PROM
DRILL
DLOG
P
Log K1 for+3' correction, RIH to
9,200.0
9,231.0
01:48
02:00
window
9/24/2019
9/24/2019
0.50
PROD2
DRILL
DLOG
P
RIH to window. Confirm 11 4 ppg kills
9,231.0
9,415.0
02:00
02:30
well, drop pumps, shut in choke
MD = 9415.5', TVD sensor = 6483',
annular = 3774 psi, EMW = 11.21 ppg
Note: annular was rock solid at 3774
psi
9/24/2019
9/24/2019
1.80
PROD2
DRILL
TRIP
P
PUW @ window = 34K, continue RIH,
9,475.0
13,822.0
02:30
04:18
clean through window & past billet,
clean to bottom, confirm TD at 13822',
PUW = 35K
9/24/2019
9/24/2019
4.10
PROD2
DRILL
TRIP
P
Lay in LRP & KWF to surface, paint
13,822.0
78.0
0418
08:24
flags, 12760 & 8280
9/24/2019
9/24/2019
0.50
PROD2
DRILL
PULD
P
At surface, Flow check well od. -Go
78.0
78.0
08:24
08:54
PJSM lay down BHA on dead well.
9/24/2019
9/24/2019
0.70
PROM
DRILL
PULD
P
Unstab injector, Inspect CT for wall
78.0
0.0
0854
09:36
thickness. Lay down BHA #11,
Ironhorse motor bearing end seems to
have excessive gap.
9/24/2019
9/24/2019
0.80
COMPZ2
CASING
RURD
P
Prep floor to run liner
0.0
0.0
0936
10:24
9/24/2019
9/24/2019
2.00
COMPZ2
CASING
PUTB
P
M/U BHA#12, L1-01 lower liner
0.0
1,093.3
1024
12:24
segment with non ported bullnose, 36
jts slotted 2 3/8" liner, and shorty
deployment sleeve
9/24/2079
9/24/2019
0.70
COMPZ2
CASING
PULD
P
M/U coil track to liner. WE to injector
1,093.3
1,137.6
1224
13:06
and surface test. Tag up and set
counters
9/24/2019
9124/2019
2.30
COMPZ2
CASING
TRIP
P
RIH BHA#12, EDC closed pumping .2
1,137.6
9,337.0
13:06
15:24BPM
9/24/2019
9/24/2019
0.10
COMPZ2
CASING
DLOG
P
Tie into flag for -6.88'
9,337.0
9,337.0
15:24
15:30
9/24/2019
9/24/2019
0.30
COMPZ2
CASING
TRIP
P
9337 Continue in. Clean trip through
9,337.0
10,280.0
15:30
15:48
window and past billet
9/24/2019
9/24/2019
0.10
COMPZ2
CASING
DLOG
P
10280', Lag K1 for +T, Stop and reset
10,280.0
10,296.0
15:48
15:54
counters
9/24/2019
9/24/2019
1.20
COMPZ2
CASING
TRIP
P
Continue in hole, 50 FPM. Slick trip to
10,296.0
12,429.0
15:54
17:06
bottom @ 13,822', PUW=50K. Set
back down. Bring pumps online,
Release from liner. PUW=35K. PUH
13,803. Remove liner length left in
hole from counters
9/24/2019
9/24/2019
2.80
COMPZ2
CASING
TRIP
P
Tip out of hole. Paint flag @ 7944.2
12,429.0
57.0
17:06
19:54
9/24/2019
9/24/2019
0.50
50MPZ2
CASING --TUTLD
P
Tag up, Pertorm flow check. PJSM.
57.0
0.0
19:54
20:24
Lay down liner running tools on dead
well
9/24/2019
9/24/2019
0.60
COMPZ2
CASING
FTU RD
P
Rig up floor for liner ops
0.0
0.0
2024
21:00
Page 14/22 Report Printed: 1013/2019
Summary (with Timelog Uepths)
AimOperations
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
stars oepm
Start Time
End Time
our (hr)
Phase
Op Cade
Activity Code
Time P-T-X
operation
(RKB)
End neplh (ftKB)
9/24/2019
9125/2019
3.00
COMPZ2
CASING
PUTB
P
Pick up L1-01 upper liner segment
0.0
1,375.0
21:00
00:00
with non-ported bullnose, 45 Jts
slotted 2 3/8" liner, 6' pup joint, and
aluminum liner top billet, begin PU
BHA#13 Liner Tools
9/25/2019
9/25/2019
0.30
COMPZ2
CASING
PULD
P
Complete PU BHA#13 Liner Tools,
1,375.0
1,433.0
00:00
00:18
slide in cart, check pack-offs, MU to
coil, tag up, set counters
9125/2019
9/25/2019
2.90
COMPZ2
CASING
RUNL
P
RIH w/ BHA#13, -6.12' correction to
1,433.0
12,728.0
00:18
03:12
window flag, PUW = 36K, drive by RA
for +7,5' correction, arrive at set depth,
PUW = 47K, set-down, come up to 1.5
bpm, PUW = 39K, release off liner
TOL -11,339'
9_/25/2019
9/25/2019
2.30
COMPZ2
CASING
TRIP
P
Reset counters, POOH
12,728.0
50.0
03:12
05:30
9/25/2019
9/25/2019
0.70
COMPZ2
CASING
PULD
P
Flow check, LD BHA#13, crew
50.0
0.0
05:30
06:12
change, carry on LD tools
9/25/2019
9125/2019
1.20
PROD3
WHDBOP
CTOP
P
MU nozzle, jet stack, break off nozzle,
0.0
0.0
06:12
07:24
1
clear rig floor, displace coil to fresh
water
9125/2019
9/25/2019
0.40
PROD3
WHDBOP
PRTS
P
PT Test IRV (250 low / 3500 high)
0.0
0.0
07:24
07:48
9/25/2019
9/25/2019
1.20
PROD3
WHDBOP
CTOP
P
Grease swabs, master, & tangos,
0.0
0.0
07:48
09:00
bravo's & romeo's, DSO on site to
bleed down GI line in cellar, break off
nozzle, prep rig floor, install night cap
9/25/2019
9/25/2019
0.30
PROD3
WHDBOP
(TT-Op
P
Fluid pack lines, lineup valves for test,
0.0
0.0
09:00
0918
put up barriers
9/25/2019
9/25/2019
5.20
PROD3
WHDBOP
BOPE
P
Test BOP'S (witness waived by Austin
0.0
0.0
09:18
1430
McLeod of the AOGCC), PU test jnt,
continue wl test, filling the hole wl MP
line
'250 low / 3500 high
9/25/2019
9125/2019
0.30
PROD3
WHDBOP
ROPE
P
Pertorm draw down test
0.0
0.0
1430
14:48
9/25/2019
9/25/2019
0.50
PRODS
WHDBOP
PRTS
P
LD test jnt, clear rig Floor
0.0
0.0
1448
15:18
9/25/2019
9/25/2019
1.20
PRODS
STK
CTOP
P
Change out UQC, MU nozzle, stab on,
0.0
0.0
15:18
16:30
open swab 2, flow check, pop off,
break off nozzle
9/25/2019
9/25/2019
1.20
PRODS
STK
PULD
P
PU BHA#14 KO Build/Turn Assembly
0.0
78.0
1630
17:42
(1.0° AKO motor, RR Baker bit), slide
in cart, check pack-off, MU to coil, tag
up, set counters
9/25/2019
9/25/2019
1.70
PRODS
STK
TRIP
P
RIH
78.0
9,204.0
17:42
19:24
9/25/2019
9125/2019
0.20
PRODS
STK
DLOG
P
Tie into the K1 for +3' correction
9,204.0
9,220.0
19:24
19:36
9/25/2019
9/25/2019
0.10
PROD3
STK
TRIP
P
RIH to just above the window
9,220.0
9,411.0
19:36
19:42
9/25/2019
9/25/2019
1.20
PROD3
STK
DISP
P
Turn well over to drilling fluid ramping
9,411.0
9,401.0
1942
20:54
up rate targeting 11.4 ppg, 20:47, mud
weight out dropping to drilling fluid
density, PU Wt 33 kibs, Close EDC
Charging gas injection line in cellar @
1125 psi
SSSV 4300 psi
9/25/2019
9/25/2019
0.60
PROD3
STK
TRIP
P
RIH,
9,401.0
11,316.0
20:54
21:30
"Dry tag TOB @ 11,338'
PU Wt 38 k bs.
Page 15122 ReportPrinted: 10/3/2019
Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Sten Tm
Entl Tune
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(NCB)
End Depth (RKB)
9/25/2019
9/25/2019
0.10
PROD3
STK
TRIP
P
Set rate, CT 4211 psi @ 1.80 bpm in
11,316.0
1,336.2
21:30
21:36
and 1.65 bpm out, BHP 4092 psi, 11.5
ppg @ the window, 11.9 ppg @ the
toe. WH 18 psi, IA 11 psi, OA 69 psi,
free spin diff 894 psi.
MW out dropped to 8.0 ppg as open
hole bottoms up arrived at surface,
export returns to Tiger tank.
9125/2019
9/25/2019
0.90
PROD3
STK
KOST
P
Time drill off billet @ 60 ° ROHS @ -
1,336.2
11,337.2
21:36
22:30
Brought returns back inside - 10 bbls,
1 fl/hr for 1' - seeing some aluminum
back at he shaker from initial milling
bottoms up.
9/25/2019
9/26/2019
1.50
PROD3
STK
KOST
P
2ft/hr for 1'- WOB 0.65 k lbs, Ct Wt 8
11,337.2
11,338.0
22:30
00:00
k lbs.
11337.84 - Stall - PU Wt 36 klbs,
RBIH,
RIH Wt 12 k lbs, CT 4120 psi, 1.81
bpm in and 1.81 bpm out, BHP 4045
psi, Free spin diff 503 psi, Saw motor
work @ 11,335.8'
Stall #2 @ 11,337.6' PU 38 k lbs,
RBIH
9/26/2019
9/26/2019
0.10
PRODS
STK
KOST
P
Continue to time drill ahead@ 2 ft/hr
11,338.0
11,338.2
00:00
0006
9/26/2019
9/26/2019
0.20
PROD3
STK
KOST
P
Increase rate to 3 ff/hr
11,338.2
11,339.2
00:06
0018
9/26/2019
9/26/2019
4.70
PROD3
DRILL
DRLG
P
Drilling ahead, work WOB up to 1.5 k
11,339.2
11,630.0
00:18
05:00
lbs, ROP 160 ft/hr.
Stacking out @ 11377'. WOB up to 3
k and string weight as low as 6 k lbs
with no motor work.
Multiple PU's, Pull above billet, tug -1
k WOB @ 11325', other than that,
billet clean.
RBIH, drilling ahead.
11,476 - PU Wt 43 k lbs
CT 4222 psi @ 1.82 bpm in and 1.70
bpm out, BHP 4074 psi, 11.45 ppg
EMW @ the window, Free spin diff
564 psi, 12.2 k CT RIH wt, OBD, Ct wt
9 k lbs, WOB 1-0.6 k lbs.
9/26/2019
9/26/2019
2.70
PROD3
DRILL
TRIP
P
POOH, PJSM
11,630.0
72.0
05:00
07:42
9/26/2019
9/26/2019
1.30
PROD3
DRILL
PULD
P
PUD BHA#14, blow down tools, clear
72.0
0.0
07:42
09:00
rig Floor, inspect injector, bit came out
2-2 w/ 1 plugged n=le (aluminum in
n=le)
9/26/2019
9/26/2019
1.00
PRODS
DRILL
PULD
P
PD BHA#15 (NOV agitator, 0.6"AKO
0.0
78.0
09:00
10:00
motor, New Dynamus bit), slide in cart,
check pack -offs, MU to coil, tag up,
set counters
9/26/2019
9/26/2019
1.70
PROD3
DRILL
TRIP
P
RIH w/ BHA#15, shallow test, dp =
78.0
9,200.0
10:00
11:42
940 psi @ 1.8 bpm
9/26/2019
9/26/2019
0.10
PROD3
DRILL
DLOG
P
Log K1 for +4'correction, PUW = 36K
9,200.0
9,232.0
11:42
11:48
9/26/2019
9/26/2019
0.90
PRODS
DRILL
TRIP
P
Continue RIH, weight bobble @
9,232.0
11,630.0
11:48
12:42
11,383' (2K)
9126/2019
9/26/2019
2.20
PRODS
DRILL
DRLG
P
Drilling, FS = 1060 psi, @ 1.9 bpm,
11,630.0
11,795.0
12:42
1454
CWT = 12K @ 1.8 WOB, annular=
4085 psi, WHIP = 25 psi, pump = 5108
psi, avg ROP = 75 fph
Page 16/22 Report Printed: 10/3/2019
♦ Uperations Summary (with Timelog Depths)
B t7l
1 IC-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
P7-
Time P-T-X
OperaYon
Tillinngrtann5030410597°/reHP=42
(ftKa)
11,795.0
End 1 (flKa)
11,898.0
9/26/2019 9/26/2019
1.70
PROD3
DRILL
DRLG
14:54 16:36
avg
ROP = -61 fph
2.50
PROD3
DRILL
DRLG
P
Drilling, annular = 4106, WHIP= 34
11,898.0
12,030.0
9/26/2019
9/26/2019
psi, 11.4 ppg at window, lower ROP in
16:36
19:06
hard spots (possibly Siderite as seen
on the L1 & L1-01)
Start new mud down the coil - Duo vis
lite
system doctered up w power vis
New mud at the bit 18:42 and 12,000'.
Average ROP over interval 53- ft/hr
9/26/2019
9/26/2019
0.30
PROD3
DRILL
WPRT
P
#1 wt 40 k Is, Pull up hole on wiper
12,030.0
11,360.0
19:06
19:24
Saw -1.3 k WOB tug @ 11,380 onn
way up hole.
9/26/2019
9/26/2019
0.20
PROD3
DRILL
WPRT
P
RBIH
11,360.0
.
12,0300
19:24
19:36
0.22 bbls of cutting returned on the trip
9126/2019
9/27/2019
4.40
PROD3
DRILL
DRLG
P
Ct 4740 psi @ 1.90 by in and 1.90
bpm out, Free spin diff 1111 psi, BHP
12,030.0
12,348.0
19:36
00:00
4077, 11.4 ppg EMW at the window.
11.84 ppg @ the bit, WH 347 psi, IA
29 psi, OA 91 psi. OBD, CT Wt 4.4 k
lbs, 1.92 k WOB -Average ROP 72
fUhr
12,171' PU Wt 44 k lbs
12,239' PU Wt 45 k lbs
12,301' PU Wt 44 k lbs
12,326' PU W141 k lbs
9/27/2019
9/27/2019
1.70
PROD3
DRILL
DRLG
P
ead
to ll39hk
12,348.0
12,480.0
12 404' PU WtContinue
lbs
00:00
01:42
12,482' PU Wt 46 k lbs
CT 5033 psi, 1.89 bpm in and 1.85
bpm out, Free spin 1,248 psi, BHP,
RIH Wt 6.5 k lbs, OBD, CT Wt 1.5 k Is,
WOB 1.45 k lbs -Average ROP 77.6
ft/hr
9/27/2019
9/27/2019
1.70
PROD3
DRILL
-ITR-LG
P
CT ROPslowed 5 k bsigW00 fly k lbs, ROP -
12,480.0
12,513.0
01:42
03:24
20 fUhr
12,496' losses increased to 0.1 bpm
Gamma started to wrap @12,475'
178 API gamma @ 12,482'
9/27/2019
9/27/2019
1.20
PROD3
DRILL
WPRT
P
PU Wt 40 k lbs, pull into casing
12,513.0
9,420.0
03:24
04:36
DRILL
WPRT
P
Jet 7" and chase bottoms up.
9,420.0
9,200.0
9/27/2019
9/27/2019
0.50
PROD3
04:36
05:06
DRILL
DLOG
P
Tie into the Kt for 5' correction.
9,200.0
9,230.0
9/27/2019
9/27/2019
0.20
PROD3
05:06
05:18
0.20
PROD3
DRILL
WPRT
P
Measure BHP, stabilizes at 11.2 ppg
9,230.0
9,410.0
9/27/2019
9/2712019
05:18
05:30
1.10
PROD3
DRILL
WPRT
P
RBIH to drill & begin
9,410.0
12,513.0
9/27/2019
9/2712019
&reaquire
motor-work
seeing weight & motor-r-work beginning
05:30
06:36
at 12,479' (1.3K WOB), a bit ratty to
bottom
1.80
PROD3
DRILL
DRLG
P
Drilling, FS = 1106 psi @ 1.9 bpm,
12,513.0
12,549.0
9/2712019
9127/2019
CWT = 1.6K @ 2.2K annular =
06:36
08:24
psi,
4120 psi, WHP = 242 psi, pump =
5159 psi, 20 fph to 30 fph, pump 5 X 5
sweeps
"'Monitor hole stability through high
gamma interval
Page 17/22 Report Printed: 101312019
IL'. .. Uperations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
$tart Time
End Time
our (hr)
Phase
Op CodeActivity
Code
Time P -T -X
P
Operation
Drilling break at — 12,549', CWT = -2K
(RKB)
12,549.0
End Depth(fiKB)
12,653.0
9/27/2019
9/27/2019
2.60
FROM
DRILL
DRLG
@ 0.6K WOB, annular= 4133 psi,
08:24
11:00
WHP = 215 psi, pump = 5192 psi, rate
out dropped at —12,645' (—.25 bpm),
,avg ROP = 40 fph, PUW = 46 at
12,653'
" Wrapping gamma interval: 12,478'
to 12,532'
9/27/2019
9/27/2019
1.50
PROD3
DRILL
DRLG
P
Drilling, CWT 2K @ 1.5K WOB,
12,653.0
12,693.0
annular = 4179 psi, WHP = 290 psi,
11:00
12:30
pump = 5445 psi, PUW = 43K from
12,693', —90% returns, reduce rate &
speed to get back to bottom, avg ROP
= 27 fph
5/27/2019
9/27/2019
2.10
PRODS
DRILL
DRLG
P
12,693.0
12,753.0
pumpg5 X 15Tbeaded�( o/h) to
12:30
14:36
moderate effect, PUW = 46K @
12,720', mud foaming up (pump
efficiency Fluctuating), add defoamer
to mud, rate out down to 1.3 bpm,
climbs back to 1.76 bpm out, avg ROP
= 29 fph
Pump 50 bbl beaded pill
019
9/27/2019
1.30
PRODS
DRILL
DRLG
Beads iIg bit at 12,7557—UW=
ha
12,753.0
12,813.0
6K, much mproved weight sfer,
14:36
14:36
15:54
increase in ROP, up to 90 fph, avg
ROP = 46 fph
69K PUW from 12,786
9/27/2019
9/27/2019
0.20
PROD3
DRILL
WPRT
P
3ma to
12.813.0
12,000.0
cleanthroughhigh gamma i am
15:54
9/27/2019
16:06
9/27/2019
0.40
FROM
DRILL
WPRT
P
Wiper in-hole, preemtively reduce rate
12,000.0
12,813.0
to 1.25 bpm running through high
16:06
16:30
gamma interval, stack a bit of weight
at 12,495' & 12,516', reduce to 0.5
bpm, reduce speed to 30 fpm, get
through w/o much trouble, RIW = 0.5K
9/27/2019
9/27/2019
1.80
PROD3
DRILL
DRLG
P
psi 1.9 bpm,
FS=bit
12'813.0
12,863.0
beads exiting CWT@1K
16:30
18:18
WOB, annular it 4177 psi, WHP = 129
psi, pump = 5536 psi
9/27/2019
9/27/2019
5.40
PROD3
DRILL
DRLG
P
Crew change, PU to grab parameters
12,863.0
13,035.0
CT 5166 psi @ 1.80 bpm in and 1.64
1818
23:42
bpm out, Free spinn 1077 psi, BHP
4208 psi,
CT Wt to -6 k lbs, WOB 1.2 k -0.3k
lbs. Struggling with weight transfer,
100' BHA wipers seemd giving limited
help. 2 ppb beaded sweeps limited
help, Reduced pump rate to 1.5 bpm
CT inlet pressure reduced to 4466 psi,
some weight ransfer benift but still
picking up more than drilling.
Average ROP over section 31 ft/hr
9/27/2019
9/28/2019
0.30
FROM
DRILL
WPRT
P
PU Wt 37 k lbs, pull wiper to casing
13,035.0
12,048.0
2342
9/28/2019
00:00
9/28/2019
1.20
PROD3
DRILL
WPRT
P
Continue to PUH, dragging low side,
12,048.0
9,404.0
0000
01:12
chasing sweeps
-1.6 k WOB tug @ 11373' - old trouble
spot
-1.7 k WOB tug @ 11325'- billet
-1.7 k WOB tug while coming through
the window
Page 18122 ReportPrinted: 10/3/2019
Uperations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
star Depth
Stan Time
End Time
Dur (hr)
Phase
Op Code
A Ity Code
Time P -T -X
Operation
(IIKS)
End Depth (NI(a)
9/28/2019
9/28/2019
0.40
PRODS
DRILL
WPRT
P
Jet 7" and chase bottoms up.
9,404.0
9,199.0
01:12
01:36
9/28/2019
9/28/2019
0.20
PRODS
DRILL
DLOG
P
Ye into the K1 marker for +72'
9,199.0
9,242.7
01:36
01:48
correction.
9/28/2019
9/28/2019
1.50
PRODS
DRILL
WPRT
P
RBIH
9,242.7
13,035.0
01:48
03:18
WOB spikes to - 1.5 k lbs ® 10,264'
and 11,136'
WOB spike to 2.9 k IDS 11,338'- billet,
stacked out some coil weight too then
popped through.
Started exporting returns to the tiger
tank line and new mud down the coil.
'• 0.91 bbls of cuttigs returned on the
round trip.
•' New mud at the bit
9/28/2019
9/28/2019
2.90
PROD3
DRILL
DRLG
P
CT 4599 psi @ 1.79 bpm in and 1.79
13,035.0
13,103.0
03:18
06:12
bpm out, free spin 1052 psi, BHP
4212 psi, WH 81, IA 46, OA 107 psi.
OBD, CT Wt 5.2 k lbs, WOB 2.8 k lbs,
13,056' - PU Wt 44 k IDS, Free spin diff
1065 psi w new mud all the way
around.
9/28/2019
9128/2019
3.70
PRODS
DRILL
DRLG
P
Drilling, CWT = 3.2 @ 0.2 WOB,
13,103.0
13,181.0
06:12
09:54
annular = 4206 psi, WHP = 211 psi,
pump = 4323, pump 10 x 101ow/high
beaded sweeps, mud aired up, add
defoamer to system, -96% returns,
pump 10 low x 40 high beaded
9/28/2019
9128/2019
0.60
PROD3
DRILL
DRLG
P
Drilling, pumping 50 bbl beaded pills,
13,181.0
13,251.0
09:54
10:30
annular = 4355 psi, WHIP = 176 psi,
pump = 5109 (w/ high vis down coil),
BHA wiper from 13,182'
Rate out dropped to .38 bpm at
13,211' (80% lasses), ECD drops 10.3
ppg, drill ahead in attempt to heal
losses, drill to 13,251', returns to -.5
-.8 bpm (fluctuating), pump high vis
sweep, wiper to window
9/28/2019
9/28/2019
1.30
PRODS
DRILL
WPRT
P
Wiper to window on losses, PUW=
13,251.0
9,400.0
10:30
11:48
49K, 1.86 bpm in, 0.6 bpm out, rate
out climbs to 0.9 = 1.0 bpm at window
w/ reduced frictional pressure loss
(holding 11.4 ppg at window), reduce
to 11.1 ppg for 1.4 bpm returns
9128/2019
9/28/2019
1.00
PRODS
DRILL
CIRC
P
Jog 7" casing, pump sweeps, circulate
9,400.0
5,000.0
11:48
12:48
bottoms up, wiper up -hole to 5000'
9/28/2019
9/28/2019
1.90
PRODS
DRILL
CIRC
P
RBIH to window, circulating awaiting
5,000.0
9,400.0
12:48
14:42
fluid to rig, trucks arrive at dg, begin
unloading
"Log K1 for+12' correction
9/28/2019
9/28/2019
1.40
PRODS
DRILL
TRIP
P
Pump 1.9 bpm, holding 11.4 ppg,
9,400.0
12,762.0
14:42
16:06
returns are 1 for 1, losses at window
are much reduced, RBIH, mud trucks
stuck behind Parker 272 dg move
Al 12,763', 1.86 bpm in, 0.97 bpm out,
confer W town, decison made to
POOH & circulate pending rig move
9/28/2019
9/28/2019
1.10
PRODS
DRILL
TRIP
T
POOH to window to circulate pending
12,762.0
9,328.0
16:06
17:12
rig move
9/28/2019
9/2812019
4.30
PROD3
DRILL
WAIT
T
Circulate waiting on trucks
12,762.0
9,328.0
17:12
21:30
Page 19/22 Report Printed: 101312019
Uperations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Stan Time
End Time
Ni-ft)
Phase
Op Code
Activity Corte
Time P-T-x
Operation
mKB)
End DepM (nKB)
9/28/2019
9/28/2019
0.40
PRODS
DRILL
DISP
T
Shut choke, line up down the coil,
9,328.0
9,335.0
21:30
21:54
stage pump rate up to drilling rate.
CT 4800 psi @ 1.80 bpm, 11.81 ECD
at the window and slowly climbing,
WH 766 psi, IA 21 psi, OA 90 psi. S/D
9/28/2019
9/28/2019
0.60
PRODS
DRILL
DISP
T
Line up down the back side, Pump 50
9,335.0
9,300.0
21:54
22:30
1
bbl lube pill down the back side.
9/28/2019
9/29/2019
1.50
PRODS
DRILL
TRIP
T
RIH, window clean, stacked WOB on
9,300.0
12,914.0
2230
00:00
lower billet, again - 11,336'
stacked out coil, no WOB 12,579'
9/29/2019
9/29/2019
1.50
PRODS
DRILL
DRLG
T
Struggling to get to bottom, CT Wt -7 k
12,914.0
13,249.0
00:00
01:30
his, any pumping sticks the coil
diferentially.
9/29/2019
9/29/2019
3.10
PRODS
DRILL
DRLG
P
CT 4748 psi @ 1.80 bpm, BHP 4300
13,249.0
13,261.0
01:30
04:36
psi, 12.47 ppg EMW, WH 1099 psi, IA
23 psi, OA 97 psi.
13,261' PU 65 k lbs
13,262' PU 65 k Iles
9/29/2019
9/29/2019
1.00
PRODS
DRILL
DRLG
T
Attempt to pick up, stuck.
73,261.0
13,261.0
04:36
05:36
Worked pipe to 75 k, WOB to -11 k
lbs. No success. Able to orient freely.
Drop pump rate and relax, work pipe
with no sucess.
9/29/2019
9/29/2019
0.80
PRODS
DRILL
CIRC
T
Pump 7 bbls LVT, with 4 bbl out,
13,261.0
13,261.0
05:36
06:24
9/29/2019
9/29/2019
1.00
PRODS
DRILL
CTOP
T
Let soak (choke closed), pumps off,
13,261.0
13,261.0
06:24
07:24
annular = 3852 psi, WHIP = 786 psi,
begin working pipe to 80K, no good,
let soak in 70K tension
11.2 ppg calculated at window (8.79
ppg out, TVD window = 65282, WHIP
= 815 psi)
Work pipe, no good, pump .45 bpm
LVF while working pipe, briefly crack
choke while pumping 1.9 bpm, work
pipe, no good, all LVT away, shut
down pumps, crack bleeder vavle to
see if hole is full, with -800 WHP no
flow through WT valve
9/29/2019
9/29/2019
1.30
PRODS
DRILL
CTOP
T
Load LVT 16 bbl into pill pit, build 60
73,261.0
13,261.0
0724
08:42
bbl 1%11% 776/LoTorq & 1.5 ppb
beaded pill
9/29/2019
9/29/2019
1.10
PRODS
DRILL
CTOP
T
Bullhead 16 bbl LVF followed by
13,261.0
13,261.0
0842
09:48
lubed/beaded pill to theif zone, 1.25
bpm, WHIP = 1950 psi, 69 bbl away
(down to thief zone), shut down
pumps & let soak, pop free holding
77K in tension (5 min soak time)
9/29/2019
9/29/2019
1.40
PRODS
DRILL
TRIP
P
Pipe free, pull to window
13,261.0
9,390.0
09:48
11:12
9/29/2019
9/29/2019
0.10
PRODS
DRILL
CIRC
P
Pump @ 1.8 bpm, open choke to
9,390.0
9,390.0
11:12
11:18
establish returns holding 3880 psi
annular (-11.4 ppg EMW at window),
returns -97%, confirm 11.4 ppg kills
well (drop to 11.0 ppg)
9/29/2019
9/29/2019
0.30
PRODS
DRILL
DLOG
P
PUH, Log K1 for+17' correction
9,390.0
9,180.0
11:18
11:36
9/29/2019
9/29/2019
1.30
PRODS
DRILL
WPRT
P
RBIH to 13,150', RIW = BK-10K at
9,180.0
13,150.0
11:36
12:54
13,160'
Page 20122 ReportPrinted: 1013/2019
Uperations Summary (with Timetog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
sten Depth
Stan Time
End Time
our (hr)
Phase
Op Code
Activit' Code
Time P44
Operation
(Wa)
EM Depth (fiKB)
9/29/2019
9/29/2019
2.00
PRODS
DRILL
WPRT
P
PUH to 7890', PUW = 46K, clean
13,150.0
7,890.0
12:54
14:54
Log K1 for +6.5' correction, clean
counter wheel
9/29/2019
9/29/2019
1.20
PROD3
DRILL
DISP
P
Bull -head 50 bbl LRP to 13,160'(11.4
7,890.0
7,890.0
1454
16:06
ppg)• 1.25 bpmm, WHP = 1207 psi
9/29/2019
9/29/2019
2.30
PROD3
DRILL
DISP
P
Layin 11.4 ppg KWF to surface (1 -for-
7,890.0
78.0
16:06
18:24
1), 0.7 bpm @ 80 fpm per trip
schedule
9/29/2019
9/29/2019
0.90
PROD3
DRILL
PULD
P
Flow check, LD BHA#15, inspect
78.0
0.0
18:24
19:18
pipe, 0.202, 0.202, 0.196, 0.203"
found thinnest spot of 0.14" atypical
wear, multiple flat spots radialy around
the pipe.
•. Bit graded out 1-2, observed slight
burnishing on leading edge cutters
and reamers.
9/29/2019
9/29/2019
0.90
COMPZ3
CASING
CTOP
P
Found basket ball sized ball of Brillo
0.0
0.0
19:18
20:12
pad in the stack just above swab #2.
Attempted unsuccessfully to remove
with dg vac and water hose.
9/29/2019
9/29/2019
1.40
COMPZ3
CASING
CIRC
P
Make up jet nozzle and stab injector.
0.0
0.0
20:12
21:36
Jet stack @ 1.88 bpm , un stab, vac
stack down, debris clean.
9/29/2019
9/29/2019
0.30
COMPZ3
CASING
PUTB
P
Prep floor for running liner
0.0
0.0
21:36
21:54
9/29/2019
9/30/2019
2.10
COMPZ3
CASING
PUTS
P
Lt -02 completion -61 joints of 4.6#, L
0.0
300.0
21:54
00:00
-80, ST -L Slotted R2 Liner under a
shorty deployment sleeve over a non
ported bull nose. ( LOA 1849.97')
•• Note, unable to pass 1.94" drift in
first two joints, swapped to 1.63" drift
Joint #4 box end found exploded -
appears to have been made up, over
torqued, and broke out. - removed
from completion.
9/30/2019
9/30/2019
2.70
COMPZ3
CASING
PUTB
P
Continued to PU lower Ll -02
300.0
1,850.0
00:00
02:42
completion - 61 joints of 4.6#, L-80, ST
-L Slotted R2 Liner under a shorty
deployment sleeve over a non ported
bull nose. ( LOA 1849.97')
9/30/2019
9/30/2019
0.10
COMPZ3
CASING
PUTB
P
Clear / clean floor from running liner.
1,850.0
1,850.0
02:42
02:48
9/30/2019
9/30/2019
0.90
COMPZ3
CASING
PULD
P
PU lower Lt -02 completion running
1,850.0
1,894.2
02:48
03:42
BHA, inspect pack offs - good, fill the
hole - 67 bbls KW lost while at
surface.
9130/2019
9/30/2019
5.50
COMPZ3
CASING
RUNL
P
RIH with lower L1-02 completion, ddve
1,850.0
13,165.0
03:42
09:12
by K1 for+1' (did not stop to correct
counters)
Stack weight at 11,538', PUW = 50K,
work pipe, continue RIH, stacked at
12,108', PU, got by, work to pass
12,933', continue to work pipe to
13,165', bring up rate to 1.5 bpm, dp =
995 psi, PUW = 38K, liner is off
TOL - 11,315'
9/30/2019
9/30/2019
2.60
COMPZ3
CASING
TRIP
P
POOH, logged K1 for +10'correction,
13,165.0
44.0
09:12
11:48
j
pait flags at 9269.22'& 7244.22'
9/30/2019
9/30/2019
0.80
COMPZ3
CASING
PULD
P
PJSM, LD BHA#16, check coil for flat
44.0
0.0
11:48
12:36
1
1
spots, pump managed pressure, KWF
arrives at dg
Page 21122 Report Printed: 11013120119
Operations Summary (with Timelog Depths)
1 C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Stan Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
TP
Time P -T -X
operation
(flKB)
0.0
End DaM(i1KB)
0.0
9/30/2019
9/30/2019
0.90
COMPZ3
CASING
P
PJSM, clear floor, off-load KWF, prep
1236
13:30
to run liner
9/30/2019
9/30/2019
2.90
COMPZ3
CASING
PUTB
P
PU Upper Completion (ported BN, 67
0.0
2,039.0
jnts slotted liner, & shorty deployment
13:30
16:24
sleeve), 30 bph losses PU liner
9/30/2019
9/30/2019
0.60
COMPZ3
CASING
PULD
P
PJSM, PU liner running tools, BHA
2,039.0
2,085.0
16:24
17:00
#17
9/30/2019
9/30/2019
2.60
COMPZ3
CASING
RUNL
P
RIH W upper Lt -02 completion - 672,085.0
11,320.0
joints of 4.6#, L-80, ST -L Slotted R2
1700
19:36
Liner under a shorty deployment
sleeve over a ported bull nose.
( 2040.93' LOA)
Tie into flag for+ 1.8' correction. PU
Wt 36 k lbs, WOB -8 k lbs
tag TOL @ 11320', WOB spiked from
5.4 to 7.9 k lbs
Stage pump to 1.5 bpm, Diff 908 psi,
PU 36 k lbs, WOB 0 k - liner released
- TOL 9274'
9/30/2019
9/30/2019
1.90
C0MPZ3
CASING
DISP
P
PUH after releasing liner, reset
11,320.0
43.0
counters, line up down the coil with
19:36
21:30
seawater. Attempt to lift KW fluid.
Losses to great to circ out an reuse
KW fluid. Bulkhead seawater down
the coil turning it over to seawater, line
up down the backside and bullhead
seawater down the tubing while
POOH.
" unable to measure BHP.
9/30/2019
9/30/2019
0.50
C0MPZ3
CASING
[TSP
P
LRS lined up to the coil, Load with 30
43.0
43.0
MIS diesel, S/D, RD LRS, Pump
21:30
22:00
additional 5 bbls seawater to the coil.
9/30/2019
9/30/2019
1.00
COMPZ3
CASING
PULD
P
PUD BHA# 17, liner running
43.0
0.0
2200
23:00
assembly.
9/30/2019
9/30/2019
0.70
DEMOB
WHDBOP
DISP
P
Stab injector, bullhead 30 bbls of
0.0
0.0
2300
23:42
diesel to the well - FP.
Prior to pumping w column of
seawater- 8.55 ppg, WH was 707 psi.
Unload coil trak from PDL.
final tubing pressure 1120 psi.
9/30/2019
10/1/2019
0.30
DEMOB
WHDBOP
CIRC
P
Jet stack W seawater
0.0
0.0
23:42
10/1/2019
00:00
10/1/2019
0.30
DEMOB
WHDBOP
CIRC
P
Continue to Jet stack
0.0
0.0
00:00
10/1/2019
00:18
10/1/2019
0.20
DEMOB
WHDBOP
CIRC
P
Flush, blow down, bleetl off, unstab
0.0
0.0
00:18
00:30
injector
1011/2019
10/1/2019
3.00
DEMOB
WHDBOP
CTOP
P
Remove upper quick connect, cut coil,
0.0
0.0
00:30
03:30
cut back 12' of pipe. Rehead, pull test
to 35 k lbs- good, rehead test wire -
greater than 2000 mega ohms and
64.8 ohms - good
Vac down stack, dump meth, Bore -O -
scope stack.
10/1/2019
10/112019
2.50
DEMOB
WHDBOP
NUND
P
Work RD checklist, ND BOP's
0.0
0.0
03:30
06:00
"Rig released at 0600 him on 10/1119
Page 22/22 ReportPrinted: 1013120191
ConocoPhillips
ConocoPhillips Alaska Inc_Kuparuk
Kuparuk River Unit
Kuparuk 1C Pad
1C -06L-1-02
50-029-20564-62
Baker Hughes INTEQ
Definitive Survey Report
17 October, 2919
Baker Hughes S
v
iAF10C0Phllllp5
Conocophillips
Definitive Survey Report
Company: ConocaPhithps Alaska lacKupamk
Local C..nainate Reference:
Prolecc Kupamk groan Unit
WO Reference:
Site. Kupamk lC Pad
MD Reference'.
Well: 11-06
North Reference
Wellbore: 1C -66L1-62
Survey Calculation Method:
Design'. IC-05L102Database'.
iC-08
Proud
Kupamk River Unit, North Shope Alaska, United Sales
Map System:
US State Plane 1927 (End mium n)
System Datum:
Geo Datum:
NAD 1927 (NADCON CONUS)
Map Zone:
Alaska Zone 04
Well
iC-08
Well Posited
.MS 0.00 usa
Northls,
.0m 0.00 usa
Sugar,
Position Uncertainty
0.00 usa
Wellhead Elevation:
Wellbore
IC -0611 -02 -- —.----+_---
Magnetics
Maki Dame Sample Dab
BGGM2018 1WI12019
Design
IC -06L1-02 __— ---_-
--_-
Audit Notes:
We111L-06
10.06 @ 94.00usa (IC -0S)
lC-06 ® 94.O0usa (1C-06)
True
Minimum Cus aIYrt
EDT 14 Alaska Production
Mean Sea Level
Using Well Reference Point
Using geode is scale factor
5.966.660.00us5
561.864.01
son
Declination
11
16.44
Version '. 10 Phase: ACTUAL Tie On Depal: 11.315.59
Vertical Soch0n'. Depth From ITVD) .KIS
(NSRI IuaRl
33.50 0.00
tatilude:
Longitude:
Ground Level:
Dip MOW
PI
WAS
.EI'W
Direction
lusrtl 1°I
0.00 0.00
Baker Hughes S
70° 19' 31.647 N
149' 29' 54.042 W
0.00 usg
Field Strength
ren
57,404
10/172019 V57:24PM Papel C011IPASSSU70.I4134indd55N
ConocoPhillips
Baker H13ghes
ConocoPhillips
DMnitive Survey Report
Company:
ConocoPhillips Alaska Inc Kuparuk
Local Coardlnaaa Reference:
mil lc -06
Pro)eq:
Kupamk River Unit
ND Reference:
1C-06@94.00usfl(10-06)
SOe:
Kupamk I Pad
MO Reference:
1C @ 94.00usfi(1C-06)
Well:
IC -06
North Reference:
True
Wellbore:
1C-0611-02
Survey Calculation Method:
Minimum Curvature
Des9n:
1C-0611-02
Database'.
EDT 14 Alaska Production
Survey Program
Dab
From
TO
Sarney
Survey
lush)
(halo
Survuy(y om)
Tool Name
Description
SbnI
EM Dale
1 DO50
4,40000
1C46(1C418)
GYD-CT-CMS
Gyrodala cont.casing this
811512000
9,430.00
9.46062
1C-0611 Miliall(1"61-1)
MWD-INC_ONLY
MN INC_ONLYFILLER
91IY2919
91148019
9,467.00
9,49606
1C -06L1-01 MWD-INO(1O561-1-01)
MW INC ONLY
MWAINC_ONLYFILLER
91178919
91178019
9.527.18
11,31559
1C-0611-01 MWD(1DO6L141)
MWD 00056
OWGG MM -Standard
91188019
91238019
11,335.00
13,22485
1C -0611 -02(1C -06L1-02)
MWD OWSG
OVVSG MM -Standard
91298019
9898019
Survey_____._
Nap
Map
Vertical
MD
Inc
ASI TWO
1V055
WS
Edi
No
EaI"I DLS
Section Survay Tool Name
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(usfll
I°)
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IN)
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H,318.59
90.00
355.. 6,561.7
6,45].]67,M.16
263200
5,9]5,91060
564 l 602
7,028.16 MWDO Mi (4)
TIP
11,mmad
69.63
357..51 den 82
6,46].62
T,045.SC
283094
5.975.91
564.635.49 11.77
7,045.54 MND OWBG (S)
KOP �
11.3648]
9e.83
9.13 6,550.70
6,486.m
7,074.06
2832.59
5,9]5,956.51
584,637.91 44.35
7,074.08 ~OMSG (5)
11,394.19
95.707
8.89 6656.00
6,460.00
7.103.11
2,837.20
5,875985.58
58464227 2.93
7.103.11 MWD OW6G (5)
71,423.91
8857
10.55 6556.60
6,462.Be
7.132.39
2642.21
5,976,01490
564,647.00 21.1
7.132.39 Mate OW6G(5)
11,457.41
8969
Is. 6,555.86
6 4
7,164.99
264923
5,9M047.55
SEA,664.30 1456
7,164.99 MND OWSG (6)
11.40.47
90.74
23.36 6558.73
6462.74
7.196.15
28E020
5,975,076.60
564.665.01 2417
7,196.15 MNDd G(y)
11.516.96
6665
Am 6,555.34
6462.34
7,22167
2,111
5.976,107.42
5646]7.48 2164
7,221.67 MNDOW6G(5)
11.54921
8687
32.14 8.566.94
6.462.94
7,24761
2,111
5,976130e9
5647092.75 15.79
7.247.61 MNDGW6G(5)
11,573.71
85.14
35.03 6,55664
6,184.64
7,267.97
2,9@.39
5,976,15096
564,706.00 138
7.267.97 MWDO MSG (5)
11,602.15
81.90
37.59 6561.85
6.451
7,290.74
2.919.11
5,976173.86
564,TC.63 14.46
7,28024 MMID MSG (5)
11.83261
79.75
41.55 Lei
6,413.71
7,31391
293816
5,008.197.19
564,741.59 1467
7,31391 MWDO ISO (5)
11.706318
03.11
45,04 6.5808
6,47506
7,335.81
7.08.90
5.976.21925
564.76255 1127
7,33581 MWD OWBG (5)
11,694.79
799
47.64 6,5"700
6,48363
7,357,211
2,981.41
5.976,240.92
564.7114,37 527
7,35719 MWD OWBG (5)
11.723.51
a1'36
4599 653239
6,488.39
7,37(1
3,00206
5.976,260.47
564.60165 8.42
7,376.68 MWD OWBG (5)
1125248
83.24
4261 6.586.25
6.49225
7,397.08
3.02197
5,976.281.04
55482460 13.35
7,39708 MND OW8G (5)
11262.63
81
39.73 6599.63
6,49563
7419.76
3041.82
5,9M,30369
564,84426 973
7,419.78 ~0VdSG(5)
'.
11.612.90
9434
37.62 6591.]2
Saturn
7,44329
3,060.64
5.91
564562.88 TM
7.,143.29 MND OMG (5)
11.843,04
85.97
35.92 6,1516
6,501.26
7,461
3,07659
5,976,351.77
SW,111 9.04
7.467370 MND O'N6G (5)
COMPASS 500014 Shear OW
10H7MI9 1:57: }IPM
Pape
3
ConocoPhlllips
Conoccl illips
Definitive
Survey Report
Baker Hughes
Company.
Cor0coPhIII1p5
Alaska
lnc Kuparuk
Local Ooardlnate Reference:
Noll IC -06
Proi
Kupamk River Unit
TWO Reference:
10-0611194.00usft OC
-06)
Sae:
Kupafuk 1C
Pad
MD Reference
iC-06@ 94.00u9B(IC46)
Well:
1C-06
North Reference:
hue
WNlbore:
1C-0611-02
Survey Calculation fila :
Minimum
Curvature
Design:
1C -06L1-02
Catabase.
EDT 14 Alaska Production
i
Survey
Map
Map
Vertical
MD
too
Ad
TWO
MASS
aN13
egai
No
Emitting
DLS
Season Survey Tool Wim
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1°1
logi
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lune!
(-ft)
(ft)
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IM
84 1
(•110Ur)
1111
T 8799
67 0a
33.91
61
6,503.05
7,496.80
3,09920
5876,301.48
564900.99
5.97
7.455.90 MWDOW6G (5)
11,910.14
07.82
34,34
6598,03
6,501.03
7,522.54
3.116.59
5,930.407.26
566,918.17
267
7,522.54 MWD OWSG (5)
11,940.36
88.62
no
6599.77
6,599.77
7547.53
3133.53
596.432.39
554,93491
299
7,547.53 MWDO SG (5)
i
11970.31
88.39
34.04
6.699.58
6.506.56
7,572.37
3,150.27
5.9136
50495188
102
7,57237 MWOO SG (6)
�
12.000."
87.91
34.70
6,601.55
5.50755
7.51
3,167.27
5.976482.35
564.999.7.1
261
7.597.22 VIVID MSG (6)
�
4,031.83
87.27
Malt
6.501.07
6,508.07
7,623,01
Vai
5,976.508.28
SaLaSSR6
204
7,62301 MNOMSG (5)
12,06037
a7.57
33.84
6.604.15
6,510.15
7,646.58
3.201.17
5,976.531.98
all 71
309
7,64658 NAND MSG (5)
4,990.09
8]30
34,51
6.605.52
6.511,62
7,671.80
3.218.29
5,975,557,34
565,016.63
Z.
7,61 NOM MSG (5)
'
8132.90
87.85
33.92
6.69930
6,54.30
7,706.51
3241.89
5.97fi.59224
Sig.CIt94
IR2
7,705,51 MA'D MSG (5)
8150.71
67.82
Not
6,607.97
6513.97
7.721.23
3,25189
5,976.60704
555.051,02
3.99
7721.23 MrW MSG (5)
1$180,"
0738
34.02
6.6011
6,51531
7,745.02
326563
5,9711
99,068.35
2.08
7,74502 MN CANto 5)
12,210."
08.19
37.23
6.610,37
6516.37
7.77015
328607
5,976656.23
565.085.59
11.03
7.720.15 MWDOiani
12,240.48
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39.45
6,611.28
6,51728
7,79370
3,30459
5.97687993
595,111402
7.40
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12270.31
a0.40
43.17
6.612.13
6,51813
781609
3,32487
5,976,702.0
565,43.51
12.47
7.616.99 MWD OWSG (5)
12,299]7
8825
4675
6,64.99
6,51699
7, 836.93
334516
597693].49
565,14414
12,16
7.83493 NVA)M as
4,330.22
50.82
50.07
5.613.02
6,519.82
7,057.13
3.35734
5,0367".07
565,166.73
10.97
7857,13 MWDOWSGIS)
8369.23
89.26
49.87
5,814,30
6,52030
7,076.43
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5,976,763.4
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223
7,876.43 MWOOWSG (5)
12.39002
89.32
99,62
6fi11
5,52016
7,811
3.414,43
5.91
585,21250
246
74895.99 MND MSG (5)
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54.65
6.614.96
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7,914.12
3.438.18
5,975801."
anna,a9
1361
7,91412 gain MSG (5)
12450,27
9092
55.32
561476
6520,76
7.931.08
3,462.39
5.876li
5652011.56
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7,931ae MNOOWSG(5)
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12479.52
85.59
51.69
6.814,89
6,521188
7,94040
3455,90
5976,83618
555.283.92
1475
7940A8 "JUDO SG (5)
12,50961
6738
48.02
6.61594
6521.94
7,967.70
3,508.02
5976.855.60
565,306.88
1033
7,967.70 MJUD OWSG (5)
4,539.59
04.89
47.99
66896
6,52395
7,98774
353122
5,9tilkam01
551
10,21
7,997.74 MWD OW6G (5)
12,569.65
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6,52851
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356556
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14.61
8,o2A.07 MWDOWSGIS)
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85.17
was,
6,625.50
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12,649.8]
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361
6627.25
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0.070,54
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5,976.959.2(1
565,40010
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12,69006
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6620.2E
6,53425
8,099.19
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5,976,983.98
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8,095.19 MWD OWSG (5)
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12709.75
8791
31.62
6,629.35
5,535.35
8,120.08
3,621
5971.00901
505.43337
8.95
8.120.00 MWD OWSG (5)
I
12739]8
81.33
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6,536.59
8,146.20
3,651.53
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2.17119
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:,63299
6,5311
8.175.31
3.65590
5,91
665,462.02
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0,176.31 MJa00 SG (5)
12,80505
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20.17
6.53426
6,5"26
5,205.80
3.87700
5,977095"1
565473.08
1134
8,205.80 insist MSG (5)
COMPASS, SOod, 14 Budd Si
10117Q019 1:5724PM
Popo
4
Survey
MD
(MafU
4,830.11
12,859.90
ConocoPhillips
Aal
PI
15.83
14.89
111D
(teem
6,635.]0
6.535.51
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(wiry
6.541.]8
6542.51
Baker Hughes 21
ConocoPhillips
Definitive Survey Report
Map
Ending
IR)
565483.02
565,40815
Company: ConocoPhillips Alaska Inc Kuparuk
Local Coartllnake Reference:
lAbh lc -06
Pmja.c Kuparuk River Urn
WO Reference:
1C-06@ 94.00usd(1 C-06)
Slte: Kuparuk 1C Rod
MD ReMrence:
1C46 @ 94.00uaM1 (IC -05)
Well: 1C-06
North Reference:
True
Wellbore: 1[-0611-02
Survey Calculation Method:
Minimum Curvature
Nolan: 1C-0611-02
Game....
EDT 14 Alaska Pmduclion
Survey
MD
(MafU
4,830.11
12,859.90
Me
r)
87.60
80.93
Aal
PI
15.83
14.89
111D
(teem
6,635.]0
6.535.51
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(wiry
6.541.]8
6542.51
a1414
(USM
5.235.29
0,359.30
♦Efm
Juan)
3,60738
3,693.70
Map
Northing
(ft)
5,97712462
5.87.14700
Map
Ending
IR)
565483.02
565,40815
DLS
I.11dP1
1421
692
Vertical
Section Survey Tool Nvma Anotation
(M
8235.29 MWDMSG(5)
0,255.30 MNO MSG (5)
12,869.95
12,819.73
12,949.63
12,979.82
13.038.54
92.2a
905]
9025
80.86
9].43
12.52
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6.S
3.22
359.90
6.636.20
6.635.42
6635.15
6,634.55
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6,542,M
6,54142
6,541,15
6,540.56
6.540.52
8,287.41
8.316.51
0,346.21
83]6.29
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3,700,80
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3,]13.2]
3,]190]
5,9]],1]8.04
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5,917235.71
5,9]!.26501
5.97.295.52
565,497.00
555.501.54
58550549
565.50)73
565,508.30
1350
10.20
12AS
10.27
11.26
0,257.41 MNOMSG (5)
8,31661 MUWGWSGIS)
8,316.21 MWDOW6G I5)
8,37&2B MND MSG (5)
8,405.99 MND PMSG (5)
13,038.2]
13.05].2]
13,07..51
13,109.82
13,139.55
91.01
91.90
9387
94.40
93.32
39.H
356.31
354]9
355.83
35500
SAWS
663366
663254
6,[30.35
6,628.35
6,640.19
6.539.60
6,538.54
6,536.35
6,534.35
6,432.71
8,45360
8,47552
0,50565
8.535.57
3,71350
3 71Z6
3.710.82
3,70.34
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5,9"]32223
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5,97.36531
5,9",395.42
5.9,425.01
565.607,58
565505.37
585501.48
565 501,74
565.499.35
].4]
See
11.18
3.04
367
8,43271 MWD DWSG (5)
"SO 1M1DMSG(5)
0,475.82 MND MSG (5)
0,505.95 MND MSG (5)
8,535.9 MNDOW6G(5)
13,16516
13,195.]]
13.224.85
13,26200 `
9285
93.10
94.15
94.15
357.11
0.43
5.41
5.41
5,626.9
6625.30
6623.51
6030.85 •
6632.9]
6.531.38
6,529.54
6,528.05
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8.59162
O,62O.Oo
5.657.48
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3,]264
3,705.51
3,70..01
5,97450.49
5,91.4O1.D4
5,9],51003
5,975`6.94
555,497,64
SSSA%.73
665,49,97
565.501.16
46.
1086
9.47
0.00
5.661.06 MWD OWSG (6)
5.591.62 MWD MSG (5)
8,620.60 MWD MSG (6)
0,657.40 PROJECTED W TD
1M71O19 1:57,21 peas COMPASS 5000
BA ER PRINT DISTRIBUTION LIST
F�UGHES
a GE company
COMPANY ConocoPhillips Alaska, Inc.
WELL NAME 1C -06L1-02
FIELD Greater Kuparuk Area
COUNTY North Slope Borough
BHI DISTRICT Alaska
AUTHORIZED BY Patrick Rider
EMAIL Patrick.Rider@bakerhughes.com
STATUS Final Replacement
COMPANY
ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX)
PERSON ATTENTION
V
1 BP North Slope.
EOA, PBOC, PRB-20 (Office 109)
D&GW O Wells Admin Brenda Glassmaker & Peggy O'Neill
'i900 E. Benson Blvd.
Anchorage, Alaska 99508
2 ConocoPhillips Alaska Inc.
Attn: Ricky Elgarico
ATO 708
700 G Street
Anchorage, AK 99510
3 Exxon Mobil, Alaska
Attn: Lynda M. Yaskell and/or Leonardo Elias
3201 C Street, Suite 505
Anchorage, AK 99503
2191,19
31370
ce sign and return one copy of this transmittal form to:
ocoPhillips Alaska, Inc.
i Osterkamp (WNS Petroleum Technician)
G Street.
horage. Alaska 99510
of this data.
LOG TYPE GR - RES
LOG DATE September 29, 2019
TODAYS DATE October 22, 2019
Revision
No Details:
Rev. Requested by: --
FIELDI
FINAL
CD/DVD
FINAL
PRELIMLOGS
(las, dlis, PDF, META,
SURVEY
I
REPORT
LOGS
CGM, Final Surveys)
(Compass)
# OF PRINTS
# OF COPIES
# OF COPIES
# OF COPIES
4 4 4
pzo%�_
4, State of Alaska - AOGCC 1 1
IAttn: Natural Resources Technician 11
333 W. 7th .Ave, Suite 100
.Anchorage, Alaska 99501
DNR - Division of Oil & Gas ***
Attn: Resource Evaluation
550 West 7th Avenue, Suite 1100
Anchorage, Alaska 99501
... Stamp "confidential" on all material deliver to
S BP Exploration (Alaska) Inc.
Petrotechnical Data Center, LR2-1
1900 E. Benson Blvd.
Anchorage, Alaska 99508
TOTALS FOR THIS PAGE: 0 1 2 0 0
Date:
Baker Hughes
j October 18, 2019
To: Fr
Abby Bell
AOGCC
333 West 7t' Ave, Suite 100
Anchorage, Alaska 99501
I --
21 91 19
3 133 4
Letter of Transmittal
Harvey Finch
Baker Hughes
795 East 94" Avenue
Anchorage, Alaska 99515
Please find enclosed the directional survey data for the following well(s):
1C -06L1
1C -06L1-01
1C -06L1-02
RECEIVED
OCT 2 1 2019
AOGCC
(3) Total print
i
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Harvey Finch, Baker Hughes, Wellplanner
Harvey.Finch@bakerhughes.com
i
I
V-
ConocoPhillips
ConocoPhillips Alaska Inc_Kuparuk
Kuparuk River Unit
Kuparuk 1C Pad
1C -06L1-02
50-029-20564-62
Baker Hughes INTEQ
Definitive Survey Report
W October, 2019
21 91 19
31334
Baker Hughes S
gn.
Project Kuparuk River Unit, North Slope Alaska, United States
Map System:
ConocoPhillips
r'
ConocoPhillips
Definitive Survey Report
Company: ConocoPhillips Alaska Inc_Kupami,
Local Co-ordinate Reference:
Project: Kuparuk River Unit
TVD Reference:
Site: Kuparuk 1 C Pad
MD Reference:
Well: 1 C-06
North Reference:
Wellbore: 1C-0611-02
Survey Calculation Method:
Desi1C-0611-02
Database:
gn.
Project Kuparuk River Unit, North Slope Alaska, United States
Map System:
US State Plane 1927 (Exact solution)
System Datum:
Geo Datum:
NAD 1927 (NADCON CONUS)
Map Zone:
Alaska Zone 04
Well
1C-06
Well Position
-NI-S 0.00 usft
Northing:
.El -W 0.00 usft
Easting:
Position Uncertainty
0.00 usft
Wellhead Elevation:
Wellbore
1C-0611-02
Magnetics
Model Name
Sample Date
BGGM2018
10/112019
Design 1C-0611-02
Audit Notes:
Version: 1.0 Phase: ACTUAL
Vertical Section: Depth From (TVD)
(usft)
33 50
Well 1 C-06
1C-06 @ 94.00usft (1C-06)
1C-06 @ 94 o0usft (1C-06)
True
Minimum Curvature
EDT 14 Alaska Production
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
5.968,860 00 usft
561,864.00usft
usft
Declination
(I
1644
Tie On Depth: 11,318.59
-NI-S
(usft)
000
+El -W
(usft)
000
Latitude:
Longitude:
Ground Level:
Dip Angle
(')
80.86
Direction
(1)
0.00
Baker Hughes U
70' 19' 31.647 N
149` 29' 54.042 W
0.00 usft
Field Strength
(nT)
57,404
10/17/2019 1.5724PM Page 2 COMPASS 5000. 14 Build 85H
Survey
ConocoPhillips
ConocoPhillips
Definitive Survey Report
Company:
ConocoPhillips Alaska Inc_Kupamk
Local Co-ordinate Reference:
Well 1C-06
MD
Project
Kuparuk River Unit
TVD
TVD Reference:
1C-06 Q 94.00usft (1C-06)
tFJ-W
Site:
Kuparuk 1C Pad
DLS
MD Reference:
1C-06 @ 94.00usft (1C-06)
Well:
1C-06
North Reference:
True
Wellbore:
1C-061-7-02
Easting
Survey Calculation Method:
Minimum Curvature
Survey Tool Name
Design:
1C -06L7-02
1%
Database:
EDT 14 Alaska Production
(usft)
Survey Program
(usft)
Date
(ft)
(-iiai
(ft)
From
To
11.318.59
90.00
35550
Survey
(usft)
(usft)
Survey (Waltham)
Tool Name
Description
Start Date
100.00
9,400.00
1C-06(1 C-06)
GYD-CT-CMS
Gyrodata cont.casing m/s
8/25/2000
9,430.00
9,460.62
1C-0611 MWD -INC (1 C-0611)
MWD -INC -ONLY
MWD -INC -ONLY -FILLER
9/13/2019
1 9,467.00
9,496.86
1C-0611-01 MWD-INC(1C-061-1-01)MWD-INC
ONLY
MWD -INC -ONLY -FILLER
9/17/2019
9,527.18
11,318.59
1C-0611-01 MWD(1C-061-1-01)
MWD OWSG
OWSG MWD - Standard
9/18/2019
11,336.00
13,224.85
1C-0611-02(1 C-0611-02)
MWD OWSG
OWSG MWD - Standard
9/29/2019
Survey
Baker Hughes `�
Survey
End Date
9/14/2019
9/17/2019
9/23/2019
9/29/2019
Annotation
TIP
KOP
1011712019 1: 57:24PM Page 3 COMPASS 5000.14 Build 85H
Vertical
MD
inc
Azi
TVD
TVDSS
-Ni
tFJ-W
DLS
Northing
Easting
Section
Survey Tool Name
(usft)
1%
P)
Wish)
(usft)
(usft)
(usft)
(ft)
(ft)
(-iiai
(ft)
11.318.59
90.00
35550
6.56176
6.467.76
7.028.16
2,832.00
5.975,910 60
564.63770
8.02
7,028.16
MWD OWSG (4)
11,336.00
89.W
357.51
6,551.82
6,467.82
7,045.54
2,830.99
5.975,927.96
564,636.49
1177
7,045.54
MWD OWSG (5)
11,364.67
94.83
9.13
6,560.70
6.466.70
7,074.08
2,832.59
5,975,95651
564,637.91
44.35
7,074.08
MWD OWSG (5)
11,394.19
9566
8.89
6,558.00
6,464.00
7,103.11
2,837.20
5,975,985.58
564,642.27
293
7,103.11
MWD OWSG (5)
r-
11.423.94
89.57
10.55
6556.64
6462.64
7.132.39
2,842.21
5,976,01490
564.647.05
21.22
7.132.39
MWD OWSG (5)
11,457.41
8969
1543
6.556.86
6,462.86
7,164.99
2.84973
5,976,04756
564.654.30
1458
7.164.99
MWD OWSG (5)
11490.47
9074
23.35
6,656.73
6.46274
7,196.15
2,860.70
5,976,078.80
584,665.01
2417
7,196.15
MWD OWSG (5)
11,518.98
90.86
2952
6,556.34
6,462.34
7,22167
2,87338
5,976.104.42
564,677.48
21.64
7,22167
MWD OWSG (5)
11,549.21
85.87
32.14
6,556.94
6.462.94
7,24761
2,888.87
5,976,13049
664,692]5
15.79
7,24761
MWD OWSG (5)
11.573.71
85.14
35.03
6,558.64
6.464.64
7,267.97
2,902.39
5.976,15696
564706.09
13.72
7,267.97
MWD OWSG (5)
11,602.15
8190
37.59
6,561.85
6,467.85
7290.74
2.919.11
5.976,17386
564,722.63
1448
7,290.74
MWD OWSG (5)
11,632.61
7975
41.56
6,566.71
6,47271
7,313.91
2,938.26
5,976,197.19
564,74159
14.67
7,313.91
MWD OWSG (5)
11,663.18
80.11
45.04
6,572.06
6,478.06
7335.81
2,95890
5,976,21925
564,762.05
11.27
7,335.81
MWD OWSG (5)
11,694.79
79.57
47.64
6,577.63
6,483.63
7,35].29
2,98141
5,976,240.92
564]64.37
827
7,357.29
MWD OWSG (5)
11723.51
81.36
45.99
6,582.39
6,486.39
7,37668
3,00205
5.976,260.47
564.804.66
8.42
7,376.68
MWD OWSG (5)
11,752.29
83.24
42.61
6.586.25
6.492.25
7,397.08
3,021.97
5,976,281.04
564,824.60
13.35
7,397.08
MWD OWSG (5)
1
i
11,782.63
81%
3973
8,58963
6,495.63
7,419.78
3,041.82
5,976,303.89
564844.26
973
7,419.78
MWD OW$G(5)
11,812.90
84.34
3762
6.59272
6.498.72
7443.29
3.060.64
5.976,32755
564,862.88
7.05
744329
MWD OWSG (5)
11 843.04
8597
3582
6.595.26
6.50126
1467.35
3,07859
5.976351.77
564,880 63
8.04
7.467 36
MWD OWSG (5)
Baker Hughes `�
Survey
End Date
9/14/2019
9/17/2019
9/23/2019
9/29/2019
Annotation
TIP
KOP
1011712019 1: 57:24PM Page 3 COMPASS 5000.14 Build 85H
`,
ConocoPhillips
ConocoPhillips
Definitive Survey Report
Baker Hughes
Company: ConocoPhillips Alaska Inc_Kuparuk
Local Co-ordinate Reference:
Well 1C-06
Project: Kuparuk River Unit
TVD Reference:
1C-06 @ 94.00usft (1C-06)
Site: Kuparuk 1C Pad
MD Reference:
1C-06 @ 94.00usft (1C-06)
Well: 1C-06
North Reference:
True
Wellbore: 1C-061-1-02
Survey Calculation Method:
Minimum Curvature
Design: 1C-06Lt-02
Database:
EDT 14 Alaska Production
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVO6S
-NI-S
.EhW
Northing
Easting
DLS
Section
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°A00')
Survey Tool Name Annotation
(ft)
(ft)
(ft)
11,879.13
87.08
33.97
6,59745
6,503.45
7,496.90
3.099.20
5,976,38148
564,900.99
5.97
7,496.90
MWD OWSG(5)
11,910.14
87.82
34.34
6598.83
6.504.83
7,522.54
3,116.59
5,976,407.26
564,918.17
267
],522.54
MWD OWSG(5)
11,940.35
88.62
33.92
6,59977
6,505]7
754753
3,13353
5.976,432 39
564.934.91
2.99
7,547.53
MWD OWSG(5)
1197031
88.30
34.04
6,600.56
6,506.56
7,572.37
3,150.27
5,976.457.36
564,95144
1.02
7,572.37
MWD OWSG(5)
12,000.44
8791
34.70
6,601.55
6,507.55
7,597.22
3,467.27
5,976,482.35
564.968.23
2.61
7,597.22
MWD OWSG(5) j
12,031.83
87.27
34.67
6,602.87
6,508.87
7,62301
3,185.12
5.976,50828
564.985.86
2.04
7,623,01
MWD OWSG(5)
12,060.37
87.57
33.84
6,604.15
6,510.15
7,646.58
3,201.17
5.976,531 98
565.001.71
3.09
7,646.58
MWD OWSG(5) I
12,090.89
87.30
34.51
6,605.52
6,511.52
7,671.80
3,21829
5,976,55734
565,018.63
2.36
7,671.80
MWD OWSG(5)
12,132.90
87.85
33.92
6,60730
6,513.30
7,706.51
3,24189
5.976,592 24
565,041.94
1.92
7,706.51
MWD OWSG(5)
12,150.71
87.82
3 Air
6,607.97
6,51397
7,72123
3,251.89
5.976,607.04
565.051.82
3.09
7,721.23
MWD OWSG(5)
12,180.48
87.39
34.02
6,60921
6,515.21
7,745.82
326863
5.976631 76
565,068.35
2.09
7,745.82
MWD OWSG(5) i
12,210.44
88.19
37.23
6,61037
6,516.37
7.770.15
3,286.07
5,976,656.23
%5,085.59
1103
7,770.15
MWD OWSG(5)
12,240.48
88.34
39.45
6,611.28
6,517.28
7,793.70
3,304.69
5,976,679.93
565,104.02
7.40
],793.70
MWD OWSG(5)
12,270.31
8840
43.17
6,612.13
6,518.13
7,816.09
3,324.37
5,976,702.48
565,12351
1247
7.816.09
MWD OWSG(5)
12,299.77
88.25
46.75
6,61299
6,518.99
],836.93
3,345.18
5.976 723,49
565.144.14
12.16
7,836.93
MWD OWSG(5)
12,33022
8862
50.07
6,613.82
6.51982
7,857.13
3,367.94
5,976,74387
565.166.]3
10.97
7,857.13
MWD OWSG(5) j
12,36023
8926
49.87
6,614.38
6.520.38
7,876.43
3,390.92
5,9]6,763.36
565,18954
2.23
7.876.43
MWD OWSG(5)
12,390.82
89.32
5062
6.614.76
6,520.76
7,895.99
3,414.43
5,976,783.11
565,212.90
2.46
7.895.99
MWD OWSG(5)
12,420.71
89.88
54.65
6.614.%
6,520.96
7,914.12
3438.16
5,976,801,44
565,236.49
1361
7,914.12
MWD OWSG(5)
12,450.27
90.92
55.32
6.61476
6,520.76
7,931.08
3,462.39
5,976,81860
565,250.56
4.19
7.931.08
MWD OWSG(5) j
72,479.52
86.59
5169
6,614.88
6,52088
],948.46
3,485.90
5,976,836.18
565,283.92
14.75
7,948.48
MWD OWSG (5)
12,509.61
8739
48.82
6,61594
6,521.94
7,96770
3,509.02
5,976,855.60
565,306.88
1033
7,96770
MWD OWSG(5)
12,539.59
84.89
4705
6.617.96
6.52396
7.987.74
3,531,22
5,976,875.81
56532892
10.21
7,987.74
MWD OWSG(5)
12,589.85
84.05
39.72
6,622.81
6,528.81
8,024.07
3,565.55
5,9]6,91242
565,362.95
14.61
8,02407
MWD OW/SG(5)
12,61955
85.17
39.93
6,625.50
6,53160
8,046.78
3.564.50
5,976,935.28
565,381.70
384
8,04678
MWD OWSG(5)
12,649.83
8844
36.40
6,627.28
6,533.28
8,070.54
3,603.17
5,976,959.20
565,400.18
1588
8,07054
MWD OW/SG(5)
12680.06
87.88
34.28
6.628.26
6.534.26
8.095.19
3.620.65
5.976,98398
565,41745
7.25
8,095.19
MWD OWISG (5)
12,709.75
8791
31.62
6.629.35
6.535.35
8120.08
3.636.79
5.977,009.01
565,433.37
8.95
6,12008
MWO OW/SG(5)
12,]39.78
87.33
2725
6.630.59
6,536.59
8,146.20
3.65153
5.977,03525
565.44790
14.63
8,146.20
MWD OWSG(5)
12,773.19
6650
23.78
6,632.39
6,538.39
8,176.31
3,665.90
5,977,06547
565,46202
10.69
8,176.31
MWD OWSG(5)
12,805.06
86.78
2017.
6,634.26
6,54026
820580
3677.80
5977095%
565.4]368
1134
8,205.80
MWD OWSG(5) .
10/172019 1: 57.24PM
Page 4
COMPASS 5000.14 Build 85H
111"-
ConocoPhillips
ConocoPhillips
Definitive
Survey Report
Company:
ConocoPhillips Alaska
Inc-Kuparuk
Local Co-ordinate Reference:
Well 1C-06
Project:
Kuparuk River Unit
TVD Reference:
1C-06 @ 94.00usft (1C-06)
Site:
Kuparuk 1C
Pad
MD Reference:
1C-06 @ 94.00usft (1C
-O6)
Well:
1C-06
North Reference:
True
Wellbore:
1C-061-1-02
Survey Calculation Method:
Minimum
Curvature
Design:
1C-061-1-02
Database:
EDT 14
Alaska Production
Survey
MD
Inc
Azi
TVD
TVDSS
*N43
+E/.W
Map
Map
Vertical
(usft)
V)
(')
(usft)
(usft)
(usft)
(usft)
Northing
Easting
S
Section
Survey Tool Name
(ft)
(ft)
("D )
(ft)
12,836.11
8760
1583
6,635.78
6,541.78
8,235.29
3,687.38
5,977,124.62
565483.02
14.21
8,235.29
MWD OWSG (6)
12,859.98
88.93
14.89
6.636.51
6,542.51
8158.30
3.693.70
5.977,147.68
565,489.15
6.82
8,258.30
MWD OVVSG(5)
12,889.95
92.24
12.52
6,636.20
6,54220
8,287.41
3.700.80
5.977,17684
565,496.00
13.58
8,287.41
MWD OWSG(5)
12,919.73
9017
9.86
6,635.42
6,54142
8,31661
3,706.58
5,977,205 09
565,501.54
1020
8,316.61
MWD OWSG(5)
12,94963
90.25
6.26
6,635.15
6,541.15
6,346.21
3,710.77
5977,235.71
M5,505 49
12.16
8,346.21
MWD OWSG(5)
12,979.82
90.86
3.22
6,634.86
6,54086
8,376.29
3,713.27
5,977,26581
565.507.73
10.27
8,37629
MWD OVJSG(5)
13,09.54
9043
359.90
6,634.52
6,540.52
8,405.99
3,71407
5,97],295.52
565.50.30
11.26
8,405.99
MWD OWSG(5)
13,03627
91.01
35799
6,634.19
6,540.19
8.432.71
3,71358
5,977,322.23
565,507.58
7.47
8,432.71
MWD OWSG(5)
13,0727
91.90
356.31
6,633.66
6,539.66
8,453.68
3,712.54
5,977,343.19
565,5136 37
9.05
8,45368
MWD OWSG(5)
13,079.51
93.87
354.79
6,632.54
6,538.54
8,475.82
3,710.82
5,977,365.31
565,504.46
11.18
8,475.82
MWD OWSG(5)
13.10.82
94.40
35583
6,630.35
6.536.35
8.505.95
3.70634
5.977,39542
565,50174
3.84
850.95
MWD OWSG(5)
13,139.58
93.32
356.0
6,628.35
6.534.35
8,535.57
3.70.23
5,977.425.01
565,499.38
367
8,53557
MWD OWSG(5)
13,165.16
92.86
35711
6,626.97
6,532.97
8,561.0
3,704.69
5,977,450.49
565.497,64
469
8,561.0
MWD OWSG(5)
13,195.77
93.10
043
6,625.38
6,531.38
8,59162
3,704.04
5,977,481.04
565,496.73
10.86
8,591.62
MWD OWSG(5)
13,224.85
94.15
5.41
6,623.54
6.529.54
8,620.60
3,70.51
5,977,510.03
565.497.97
1747
8.620.60
MWD OWSG(5)
13262.00
94.15
5.41
6.62085
6,52685
8,65748
3,709.01
5,977,54694
565501.16
0.00
665748
PROJECTED to TD
Baker Hughes S
Annotation
10117/2019 1:57 24PM Page 5 COMPASS 5000.14 Build 85H
THE STATE
°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
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C -06L1-02
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-119
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
w .aogcc.alaska.gov
Surface Location: 1375' FNL, 858' FWL, SEC, 12, TI IN, R10E, UM
Bottomhole Location: 2623' FNL, 679' FEL, SEC. 36, T12N, R10E, UM
Dear Mr. Ohlinger:
Enclosed is the approved application for the permit to redrill the above referenced service well.
The permit is for a new wellbore segment of existing well Permit No. 181-025, API No. 50-029-
20564-00-00. Production should continue to be reported as a function of the original API number
stated above.
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,
. 'Y C. -
eJ ssiielowski
Commissioner
DATED this 10 day of September, 2019.
Winston, Hugh E (CED)
From: Winston, Hugh E (CED)
Sent: Friday, January 17, 2020 10:49 AM
To: Winston, Hugh E (CED)
Subject: RE: KRU 1C-06 Sundry Issues
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Wednesday, January 15, 2020 9:50 AM
To: Winston, Hugh E (CED) <hugh.winston@alaska.gov>
Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>
Subject: KRU 1C-06 Sundry Issues
Hugh,
Could you please hand make these changes on the forms, put a copy of this list in each of the well files and
correct in RBDMS?
Let me know if you have any questions.
Thanx,
Victoria
From: Germann, Shane <Shane.Germann@conocophillips. com>
Sent: Wednesday, January 15, 2020 8:57 AM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.�>
Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.xov>; Winston, Hugh E (CED) <hueh.winston@alaska.aov>
Subject: RE: [EXTERNAL]KRU 1C-06 Sundry Issues
Victoria,
Below are the forms that have WIN1 checked instead of WAG along with the corresponding well names and PTD
#'s. Let me know if you need anything else. I apologize for the inconvenience this has caused.
Well Name
PTD #
Form
KRU 1C-06
181-025
10-403 (Sundry # 319-380)
KRU 1C-06
181-025
10-404 (Sundry # 319-380)
KRU 1C-061-1
219-117
10-401
KRU 1C-061-1-01
219-118
10-401
KRU 1C-061-1-02
219-119
10-401
KRU 1C-061-1
219-117
10-407
KRU 1C-061.1-01
219-118
10-407
KRU 1C -06L1-02
219-119
10-407
Shane Germann
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
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, January 15, 2020 8:37 AM
To: Germann, Shane <Shane.Germann@conocophillips.com>
Cc: Brooks, Phoebe L (CED) <phoebe.brooks alaska.gov>; Winston, Hugh E (CED) <hugh.winston@alaska.gov>
Subject: [EXTERNAL)KRU 1C-06 Sundry Issues
Shane,
Please list the wells, PTD #s, Sundry #s and the forms where WI instead of WAG is checked.
We will take a look at 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
V ictoria. Loeop(d-Waska.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 Loeoa@alaska.aov
From: Germann, Shane <Shane.Germann@conocophillips.com>
Sent: Tuesday, January 14, 2020 3:12 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; Ohlinger, James J
<James.J.Ohlinger@conocophillips.com>
Subject: KRU 1C-06 Sundry Issues
Victoria,
It has been brought to my attention that the KRU 1C-06 Sundry (319-380) and CTD sidetrack PTD's (219-217,
219-118, 219-119) have a mistake on them. The 1C-06 is a WAG injector and has been on WAG since 2007. The
1C-06 CTD laterals were always planned to be on WAG injection, but I inadvertently checked the "WIND" box
instead of "WAG" on the 10-401's, 10-403, 10-404, and 10-407's. The well status for the 1C-06 motherbore as
well as the three CTD laterals (1-1, L1-01, and L1-02) should be WAG.
Please advise if any formal documentation is required. I've attached the email chain that brought this up and
the 10-404 for KRU 1C-06. Feel free to call or reply with any questions.
Shane Germann
Coiled Tubing Drilling Engineer
STATE OF ALASKA
A, KA OIL AND GAS CONSERVATION COMM. SION
PERMIT TO DRILL
Cii-v f! 'Bf1
1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑
Drill ❑ Lateral 2 Stratigraphic Test ❑ Development - Oil ❑
Redrill [I Reentry El Exploratory -Oil El Development -Gas ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
Service - WAG Service - Disp ❑
Service - Winj I Single Zone 0
Service - Su L-1 Multiple Zone El
Supply P
5. Bond: Blanket ❑✓ Single Well ❑
Bond No. 5952180
6. Proposed Depth:
MD: 13,900' ND: 6622'
7. Property Designation:
ADL 25649.7flpLODd?�
ic. Specify if well is proposed for:
Coalbed'Gas ❑ Gas Hydrates ❑
Geothermal [I Shale Gas ❑
11. Well Name and Number: -
KRU 1C -06L1-02
12. Field/Pool(s): .
Kuparuk River Pool /
Kuparuk River Oil Pool
4a. Location of Well (Governmen
Surface: 1375' FNL, 858' FWL, Sec. 12, T11N, R10E, UM
Top of Productive Horizon:
292' FSL, 1465' FEL, Sec. 36, Tl 2N, RI OE, UM
Total Depth:
2623' FNL, 679' FEL, Sec. 36, T12N, R10E, UM
4b. Location of Well (Stale Base Plane Coordinates - NAD 27):
Surface: x- 561864 y- 5968860 Zone- 4
16. Deviated wells: Kickoff depth: 9,430 feet
Maximum Hale Angle: 98 degrees
18. Casing Program: Specifications
Hole Casing Weight Grade Coupling Length
3" 2-3/8" 4.7# L-80 ST -L 4570
8. DNR Approval Number: d' 1q
LONS 79-016
13. Approximate Spud Date:
9/10/2019 .-
9. Acres in Property: 14. Distance to Nearest Prooertv:
2560 2806'
10. KB Elevation above MSL (ft): 94 15. Distance to Nearest Well Open
GL / BF Elevation above MSL MY 55 - to Same Pool: 1204' (1C-191-1)
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Downhole: 3888 Surface: 3235
Top -Setting Depth -Bottom Cement Quantity, sacks
MD TVD MD ND (including stagea data )
9320' 6451' 13,900' 6622' Uncemented Slotted Liner
19, PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total DepthND (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depp19ND (ft): Junk (measured):
10,243' 7102' N/A 10,127'
Length Size Cement Volume MD ND
Casing 65'
Conductor 33' i6" 425 sx PF 65'
Surface 3255' 10-314" 340 sx AS 11 3287' 2685'
7•• 535 sx Class G 10,226' 7090'
Production 10.196'
Perforation Depth MD (ft): 9410 - 9485 Perforation Depth ND (ft): 6514-6566
Hydraulic Fracture planned? Yes❑ No ❑1
hPlo' Shallow Hazard Analys
20. Attachments: Property Plat ❑ BP Sketch DivertOer Sketch B SelabedDrilinro'part B DriBi g Fluid Pram Time v. rogrram e 20 AAC 25.050 require menls8
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. errnann COP.COm
Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4597
Date: 1/-3/z %r
Authorized Signature:
Commission Use Only
Permit to Drill API Number: Permit Approval See cover letter for other
Number: 1 —1� 50-Q2r1— x06'6' — Fi a dC� Date: requirements.
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:PF
�y
Other: /� a. ,» Samples req'd: Yes [] No� Mud log req'd: Yes El No IJ
By / <-Sf � ��U�Y /� �Q,YJ �r HzS measures: Yes LrJ No❑ Directional svy req'd: YesN No❑�,/
✓3 r)!// a! ✓ P r< t�<✓+- f �r To Z `J y 5 ,--,/ Inclination -only svy req'd: Yes ❑ NoL7
// $pacing exception req'd: Yes ❑ No L� ❑
f]/¢6 2 , b) rj , ' ) �` Post initial injection MIT req'd: Yes �No
15 9ra)'J7r_d1 to Q//ow i7 -e k7'Cko P l�f
oGY1y ?1ofni a��n9 fht �a✓f'7f 7a < `t l
✓ l�
/ APPROVED BY q / I U '
(( lam- COMMISSIONER THE COMMISSION Date: /
Approved by: Submit Form and
/� V-7 L JJIr /I `1
Form l0 01 Revised 5/2017 T perdlit is valid for }'� o f� Ih�dtlteQf pproval per 20 AAC 25.005 Attachmentsi�uplkate
U'1A I NAL 'moi
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 29, 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 permits to drill three laterals out of the KRU 1 C-06
(PTD# 181-025) using the coiled tubing drilling rig, Nabors CDR3-AC.
CTD operations are scheduled to begin in mid September 2019. The objective will be to drill three laterals, KRU
1C -06L1, 1C-061-1-01, and 1C-061-1-02, targeting the Kuparuk C -sand interval.
To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20
AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of
being limited to 500' from the original point.
Attached to permit to drill applications are the following documents:
- Permit to Drill Application Forms (10-401) for 1C-061-1, 1C-061-1-01, and 1C-061_1-02
- Detailed Summary of Operations
- Directional Plans for 1C-061-1, 1C-061-1-01, and 1C-061-1-02
- Current Wellbore Schematic
- Proposed CTD Schematic
If you have any questions or require additional information, please contact me at 907-2634597.
Sincerely,
Shane Germann
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Kuparuk CTD Laterals
1C-061-1, 1C-061.1-01, & 1C-061-1-02
Application for Permit to Drill Document
1.
Well Name and Classification........................................................................................................
(Requirements of 20 AAC 25.005(Q and 20 AAC 25.005(b)) ........ ........................................................._..........................................._...2
2
2
""
2.
Location Summa
(Requirements of 20 AAC 25.005(c)(2)) ........................................................................................................................
.
3.
Blowout Prevention Equipment Information.................................................................................
(Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................
2
2
4.
Drilling Hazards Information and Reservoir Pressure..................................................................
(Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................
2
2
5.
Procedure for Conducting Formation Integrity tests...................................................................
(Requirements of 20 AAC 25.005(c)(5))...............................................................................................................................................
2
2
3
6.
Casing and Cementing Program....................................................................................................
(Requirements of 20 AAC 25.005(c)(6))................................................................................................................................................
3
3
7.
Diverter System Information..........................................................................................................
(Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................
3
3
8.
Drilling Fluids Program..................................................................................................................
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................
3
9.
Abnormally Pressured Formation Information.............................................................................4
(Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................
4
10.
Seismic Analysis.............................................................................................................................
(Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................
4
4
11.
Seabed Condition Analysis............................................................................................................
(Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................
4
4
12.
Evidence of Bonding
(Requirements o/ 20 AAC 25.005(c)(12))..........................................................................................................................
4
. ""
13.
Proposed Drilling Program.............................................................................................................4
(Requirements of 20 AAC 25.005(c)(13))............................................................................................................................................
4
Summaryof Operations...................................................................................................................................................4
Liner Running
""' .......................5
14.
Disposal of Drilling Mud and Cuttings..........................................................................................
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................
6
6
15.
Directional Plans for Intentionally Deviated Wells.......................................................................
(Requirements of 20 AAC 25.050(b))......................................................................................................................................................
6
s
16. Quarter Mile Injection Review........................................................................................................ 6
(Requirements of 20 AAC 25.402).......................................................................................................................................................... 6
17. Attachments....................................................................................................................................7
Attachment 1: Directional Plans for 1C-061-1, 1C-061-1-01, & 1C-061-1-02 laterals.........................................................7
Attachment 2: Current Well Schematic for 1 C-06............................................................................................................7
Attachment 3: Proposed Well Schematic for 1C -06L1, 1C-061-1-01, & 1C-061-1-02 laterals ...........................................7
Page 1 of 7
January 30, 2019
PTD Application: 1C-061-1, 1C-061-1-01, & 1C-061-1-02
Well Name and Classification
(Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))
The proposed laterals described in this document are 1C-061-1, 1C-061-1-01, & 1C -06L1-02. All laterals will be
classified as "Development' wells.
Location Summary
(Requirements of 20 AAC 25.005(c)(2))
These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface
and subsurface coordinates of the 1C-061-1, 1C-061-1-01, & 1C-061-1-02.
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. Using the
maximum formation pressure in the area of 3888 psi in 1C-11 (i.e. 11.9 ppg EMW), the maximum
potential surface pressure in 1C-06, assuming a gas gradient of 0.1 psi/ft, would be 3235 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.
4. Drilling Hazards Information and Reservoir Pressure
(Requirements of 20 AAC 25.005 (c)(4))
Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a))
The formation pressure in KRU 1 C-06 was measured at the datum to be 3585 psi (11 0 ppg EMW) on
7/23/2017. The maximum downhole pressure in the 1 C-06 vicinity is to the south in the 1 C-11 producer.
Pressure was measured to be 3888 psi, at the datum, (11.9 ppg EMW) in May of 2019.
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
The offset injection wells to IC -06 have injected gas, so there is a possibility of encountering free gas while
drilling the 1C-06 laterals. 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 1C-06 laterals will be shale instability across faults. Managed
pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings.
Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 1C-06 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity
test is not required.
Page 2 of 7 January 30, 2019
PTD Application: 1C-061-1, 1C-061-1-01, & 1C-061_1-02
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
Existing Casing/Liner Information
Weight
Lateral Name
Liner Top
Liner Btm
Liner Top
TVDSS
Liner Btm
TVDSS
Liner Details
OD
MD
MD
Connection
Top MD
Btm MD
TVD
TVD
psi
psi
Conductor
2-3/8", 4.7#, L-80, ST -L slotted liner;
1C-06LI
9900'
13,000'
6452'
6404'
aluminum billet on to
65'
1640
670
Surface
10-3/4"
2-3/8", 4.7#, L-80, ST -L slotted liner;
1C -06L1-01
11,250'
14,300'
6439'
6405'
aluminum billet on to
3580
2090
Production
7"
26.0
2-3/8", 4.7#, L-80, ST -L slotted liner;
1C-061-1-02
9320'
13,900'
6357'
6528'
deployment sleeve on to
Existing Casing/Liner Information
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: Water -Based PowerVis milling fluid (8.6 ppg)
— Drilling operations: Water-based PowerVis mud (8.6 ppg). This mud weight will not hydrostatically
overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with 11.4 ppg NaCl / NaBr completion fluid in order to
provide formation over -balance and well bore stability while running completions.
Inaged Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation and promote wellbore stability 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 econdary well control as detailed in section 3
"Blowout Prevention Equipment Information".
In the 1C-06 laterals we will target a constant BHP of 11.4 ppg EMW at the window. 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 7 August 29, 2019
Weight
Top
Btm
Burst
Collapse
Category
OD
Grade
Connection
Top MD
Btm MD
TVD
TVD
psi
psi
Conductor
16"
62.5
H-40
Welded
Surface
65'
Surface
65'
1640
670
Surface
10-3/4"
45.5
K-55
BTC
Surface
3287'
Surface
2685'
3580
2090
Production
7"
26.0
K-55
BTC
Surface
10,226'
Surface
7090'
4980
4320
Tubing
3-1/2"
9.3
1--80
EUE-8rd
Surface
9381'
Surface
6494'
10,160
10,540
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: Water -Based PowerVis milling fluid (8.6 ppg)
— Drilling operations: Water-based PowerVis mud (8.6 ppg). This mud weight will not hydrostatically
overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with 11.4 ppg NaCl / NaBr completion fluid in order to
provide formation over -balance and well bore stability while running completions.
Inaged Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation and promote wellbore stability 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 econdary well control as detailed in section 3
"Blowout Prevention Equipment Information".
In the 1C-06 laterals we will target a constant BHP of 11.4 ppg EMW at the window. 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 7 August 29, 2019
PTD Application: 1C -06L1, 1C -06L1-01, & 1C -06L1-02
o.... -....-....a atie 11' na winrinw 1Qd3n' mn 652R' TVDI Usina MPD 1,
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
KRU well 1C-06 is a Kuparuk C -Sand injector equipped with 3-1/2" tubing and 7" production casing. The CTD
sidetrack will utilize three laterals to target the C -sands to the north and west of 1 C-06. The laterals will increase
C -sand resource recovery and throughput.
Prior to CTD rig up, E -Line will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the
planned kick off point of 9430' MD. The 1 C-061_1 lateral will exit through the 7" casing at 9430' MD and drill to a
planned TD at 13,000' MD, targeting the C sand to the west. The lateral will be completed with 2-3/8" slotted liner
from TD up to 9900' MD with an aluminum billet for kicking off.
The 1C-061_1-01 lateral will kick off at 9900' MD and drill to a planned TD of 14,300' MD targeting the C sand to
the north. It will be completed with 2-3/8" slotted liner from TD up to 11,250' MD with an aluminum billet for
kicking off.
The 1C-061-1-02 lateral will kick off at 11,250' MD and drill to a planned TD of 13,900' MD targeting the C sand to
the north-east. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 9330' MD with a
deployment sleeve and seal bore assembly.
Pre -CTD Work
1. RU Slickline: Dummy whipstock drift, C/O GLV's
2. RU E -line: Caliper
3. RU CTU: Mill out D -Nipple to 2.80" ID, cleanout if fill is encountered.
Page 4 of 7 August 29, 2019
Pumps On 1.9 bpm)
Pumps Off
C -sand Formation Pressure 11.0
3734 psi
3734 psi
Mud Hydrostatic 8.6
2919 psi
2919 psi
Annular friction i.e. ECD, 0.080psi/ft)
754 psi
0 psi
Mud + ECD Combined
no chokepressure)
3673 psi
underbalanced -61psi)
2919 psi
underbalanced -815Psi)
Target BHP at Window 11.4
3870 psi
3870 psi
Choke Pressure Required to Maintain
Target BHP
197 psi
951 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
KRU well 1C-06 is a Kuparuk C -Sand injector equipped with 3-1/2" tubing and 7" production casing. The CTD
sidetrack will utilize three laterals to target the C -sands to the north and west of 1 C-06. The laterals will increase
C -sand resource recovery and throughput.
Prior to CTD rig up, E -Line will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the
planned kick off point of 9430' MD. The 1 C-061_1 lateral will exit through the 7" casing at 9430' MD and drill to a
planned TD at 13,000' MD, targeting the C sand to the west. The lateral will be completed with 2-3/8" slotted liner
from TD up to 9900' MD with an aluminum billet for kicking off.
The 1C-061_1-01 lateral will kick off at 9900' MD and drill to a planned TD of 14,300' MD targeting the C sand to
the north. It will be completed with 2-3/8" slotted liner from TD up to 11,250' MD with an aluminum billet for
kicking off.
The 1C-061-1-02 lateral will kick off at 11,250' MD and drill to a planned TD of 13,900' MD targeting the C sand to
the north-east. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 9330' MD with a
deployment sleeve and seal bore assembly.
Pre -CTD Work
1. RU Slickline: Dummy whipstock drift, C/O GLV's
2. RU E -line: Caliper
3. RU CTU: Mill out D -Nipple to 2.80" ID, cleanout if fill is encountered.
Page 4 of 7 August 29, 2019
PTD Application: 1C -06L1, 1C-O6L1-01, & 1C -06L1-02
4. RU E -Line: Set top of high expansion wedge at 9430' MD
5. Prep site for Nabors CDR3-AC.
Ria Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. 1C -06L1 Lateral (C sand - West)
a. Mill 2.80" window at 9430' MD.
b. Drill 3" bi-center lateral to TD of 13,000' MD.
c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 9900' MD.
3. 1C-061_1-01 Lateral (C sand - North)
a. Kickoff the aluminum billet at 9900' MD.
b. Drill 3" bi-center lateral to TD of 14,300' MD.
c. Run 2%" slotted liner with an aluminum billet from TD up to 11,250' MD.
4. 1C-061-1-02 Lateral (C sand -North-East)
a. Kickoff of the aluminum billet at 11,250' MD.
b. Drill 3" bi-center lateral to TD of 13,900' MD.
c. Run 2%" slotted liner with deployment sleeve and seal bore from TD up to 9330' MD.
5. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC.
Post -Rig Work
1. Return to production
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on
the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double
swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the
BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two
barriers to reservoir pressure, both internal and external to the BHA, during the deployment process.
During BHA deployment, the following steps are observed.
— Initially the double swab valves on the tree are 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 valves. The swab valves are opened and
the BHA is lowered in place via slick -line.
— When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate
reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate
reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from
moving when differential pressure is applied. The lubricator is removed once pressure is bled off above
the deployment rams.
— The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the
closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the
double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized,
and the deployment rams are 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 1C-06 laterals will be displaced to an overbalancing fluid (11.4 ppg NaCl / NaBr) prior to running
liner. See "Drilling Fluids" section for more details.
Page 6 of 7 August 29, 2019
PTD Application: 1C -06L1, 1C-061,1-01, & 1C -06L1-02
- While running 2-3/8" slotted liner, a joint of 2-3/8" 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 2-3/8" rams will
provide secondary well control while running 2-3/8" liner.
14. Disposal of Drilling Mud and Cuttings
(Requirements of 20 AAC 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 (1R-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))
- 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, resistivity, 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
1 C -06L1
6830'
1 C -06L1-01
2694'
1C -06L1-02
2806'
- Distance to Nearest Well within Pool
Lateral Name
Distance
Well
1C -06L1
1079'
1C-19
1C-06LI-01
1139'
1C-111-2-02
1C-061,1-02
1204'
1C-191-1
J 16.Quarter Mile Injection Review
(Requirements of 20 AAC 25.402) ,
The only wells that lie within '/. -mile of the proposed 1C-06 laterals are the 1C-06 mother bore, 1C -07A• 1C-19,
1C-191-1, and 1C-111-2-02.�The casing and cementing of 1C-06 is described below. See the attached schematic
for further details.
1C-06 Mother bore
Well 1C-06 was drilled and completed in 1981. The 7", 26 ppf, K-55 BTC production casing was set at 10,225'
MD in the Miluveach. 1C-06 is a service well with a "Normal Well" Ann -Comm status. Itis capable of injecting to
the Kuparuk C sands but is not open to the A sands. The mother bore will continue to be open to the current C -
sand perforations.
IC -07A
Well 1C -07A (PTD #209-029) was drilled and completed in 2009. It is a sidetrack from the 1C-07 mother bore
(PTD #181-031) which was drilled and completed in 1981. The 1C-07 mother bore had the C sand perforations
cement squeezed prior to the CTD project in 2009. The 1 C -07A is a C sand lateral completed with 2-3/8" 4.7 ppf
L-80 slotted liner. The 1C-07 is a production well with a "Problem Well" Ann -Comm status open to produce from
only the C sand. There was suspected IAxOA communication in 2014. The 7", 26 ppf K-55 BTC production
casing was set at 9766' MD in the Miluveach. The 1C -06L1 to 1C -07A center to center distance is roughly 1223'.
Page 6 of 7 August 29, 2019
PTD Application: 1C -06L1, 1C-06LI-01, & 1C -06L1-02
1C-19 & 1C-191_1
Well 1C-19 (PTD #203-054) was drilled and completed in 2003. The 7", 26 ppf BTC production casing was set
at 10,429' MD in the B sand. The 1C-19 is a production well with a "Normal Well" Ann -Comm status open to
produce from only the C sand. The 1C-19 is the mother bore for CTD sidetrack lateral 1 C -19L1 (PTD #219-086)
drilled in 2019 and completed with 2-3/8" 4.7 ppf L-80 slotted liner. 1C-191_1 is located in the C sand to the north
of 1C-19. The 1C-061_1 to 1C-19 center to center distance is roughly 1079'. The 1C -06L1-02 to 1C-191_1 center
to center distance is roughly 1204'.
1 C-11 L2-02
Well 1C-11 L2-02 (PTD #219-043) was drilled and completed in 2019. It is a sidetrack from the 1C-11 mother
bore (PTD #196-172). The 1C-11 mother bore had the C sand perforations cement squeezed prior to the CTD
project in 2019. The 1C-11 L2-02 is a C sand lateral completed with 2-3/8" 4.7 ppf L-80 slotted liner. The 1C-11
is a production well with a "Normal Well" Ann -Comm status open to produce from only the C sand. The 7", 26
ppf L-80 BTC production casing was set at 10,427' MD in the Kalubik. The 5", 18 ppf L-80 LTC liner was set at
11,300' MD in the Miluveach. The 1 C -06L1-01 to 1 C-11 L2-02 center to center distance is roughly 1139'.
17.Attachments
Attachment 1: Directional Plans for 1C -06L1, 1C-061_1-01, & 1C -06L1-02 laterals
Attachment 2: Current Well Schematic for 1 C-06
Attachment 3: Proposed Well Schematic for 1C-061_1, 1C-061_1-01, & 1C -06L1-02 laterals
Page 7 of 7 August 29, 2019
Well fcaU XX -XX Nabors CDR3-AC: 4 -Ram BOP Configuration 2" Date April 2a, 2019
Coiled Tubing and 2-318" BHA
Quick Test Sub to Ot
Top of 7" Otis
Distances from top o
Excluding quick -test
Top of Annular
Ci Annular
Bottom Annular Flan.
C, Blind/Shears
CL 2" Combi's
Ci 2-318" Combi's
CL 2" Combi's
CL of Top
Top of Sw:
CL Swab 1
Flow Tee
CL SSV
CL Master
LDS
Grounc
Tree Size 3 118
ne
ConocoPhillips
ConocoPhillips Alaska lnc_Kuparuk
Kuparuk River Unit
Kuparuk 1C Pad
IC -06
IC -06L1 -O2
Plan: 1 C-061-1-02_wp02
Standard Planning Report
15 August, 2019
BA UGHES
a GE company
ConocoPhillips BA ER
I UGHES
ConocoPhillips Planning Report aGE<ompany
Database:
EDT 14 Alaska Production
Company:
ConocoPhillips Alaska Inc Kuparuk
Project:
Kuparuk River Unit
Site:
Kuparuk 1C Pad
Well:
1 C-06
Wellbore:
1 C-061.1-02
Design:
1 C-06L7-02_wp02
Local Coordinate Reference:
TVD Reference:
MO Reference:
North Reference:
Survey Calculation Method:
Well 1C-06
Mean Sea Level
10-06 @ 94.00usft (1 C-06)
True
Minimum Curvature
Project Kuparuk River Unit, North Slope Alaska, United States
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
site Kupamk 1C Pad
Northing:
5,968,522.46usft Latitude:
70,19-28 285 N
Site Position:
Map
Easting:
562,372.05usft Longitude:
49° 29' 39.293 W
149'29'39
From:
0.48 `
Position Uncertainty:
0.00 usft Slot Radius:
0.000 in Grid Convergence:
Well
1C-06
Well Position
+N/ -S
0.00 usft Northing:
5,968,860.00 usft Latitude:
70° 19' 31.647 N
+E/ -W
0.00 usft Basting:
561,864.00 usft Longitude:
149` 29'54.042 W
Position Uncertainty
0.00 usft Wellhead Elevation:
usft Ground Level:
0.00 usft
Wellbore
1C -06L7-02
Magnetics
Model Name Sample Date
Declination Dip Angle
Field Strength
K)
BGGM2018 10/1/2019
16.44 80.86
57,404
Design
1C-06L1-02_wp02re
...-..:s..a..,.x.
Audit Notes:
Version:
Phase: PLAN
Tie On Depth:
11,250.00
Vertical Section:
Depth From (TVD)
-N/-S
+E/ -W Direction
(usft)
(usft)
l0.00
(°)
-66.50
0,00
- -
a.ao 1s.00
__ -- -
Plan Sections
Measured
TVD Below
Dogleg Build Tum
Depth Inclination
Azimuth System -NIS
+E/.W
Rate Rate Rate
TFO
(usft) (°)
(°) (usft) (usft)
(usft)
(1I100usft) (°/100usft) (°/100usft)
(°)
Target
11,250.00
90.56
34889 6439.71 6,948.02
2952.05
0.00 0.00 0.00
0.00
11,320.00
86.31
351.35 6,441.62 7,016.94
2,940.04
7.00 -6.06 3.50
150.00
11,700.00
81.79
17.71 6,481.68 7,390.26
2,969.25
7.00 -1.19 6.94
101.00
12,000.00
89.32
37.39 6,505.14 7,653.81
3,107.05
7.00 2.51 6.56
70.00
12,225.00
88.80
53.14 6,508.86 7,811.65
3,266.35
7.00 -0.23 7.00
92.00
12,625.00
89.88
25.15 6,513.58 8,118.78
3,516.34
7.00 0.27 -7.00
-88.00
12,825.00
89.88
39.15 6,514.00 8,287.68
3,622.51
7.00 0.00 7.00
90.00
13,225.00
89.90
11.15 6,514.79 8,646.16
3,790.85
7.00 0.00 -7.00
-90.00
13,625.00
88.50
343.19 6,520.51 9,041.66
3,771.31
7.00 -0.35 -6.99
-93.00
13,900.00
88.58
2.44 6,527.57 9,313.13
3,737.09
7.00 0.03 7.00
90.00
8/152019 9:41.:20AM Page 2 COMPASS 500014 Build 85H
ConocoPhillips BA ER
ConocoPhillips Planning Report F IGHES
BAT
GE company
Database:
EDT 14 Alaska Production
Company:
ConocoPhillips Alaska Inc-Kuparuk
Project:
Kuparuk River Unit
Site:
Kuparuk 1C Pad
Well:
1C-06
Wellbore:
1C-0611-02
Design:
1C-06L1-02_wp02
Planned Survey
Measured
6,997.21
6,441.62
Depth
Inclination
Azimuth
(usft)
(I
(�)
11,250.00
90.56
348.89
TIP/KOP
7,482.85
11,300.00
87.53
350.64
11,320.00
86.31
351.35
Start
DLS 7.00 TFO
101.00
11,400.00
85.26
356.86
11,500.00
84.02
3.78
11,600.00
82.85
10.73
11,700.00
81.79
17.71
Start
DLS 7.00 TFO
70.00
11,800.00
84.24
24.32
11,900.00
86.76
30.87
12,000.00
89.32
37.39
Start
OLS 7.00 TFO
92.00
12,100.00
89.08
44.39
12,200.00
88.85
51.39
12,225.00
88.80
53.14
Start
DLS 7.00 TFO
-88.00
12,300.00
88.99
47.89
12,400.00
89.25
40.89
12,500.00
89.53
33.90
12,600.00
89.81
26.90
12,625.00
89.88
25.15
Start
DLS 7.00 TFO
90.00
12,700.00
89.88
30.40
12,800.00
89.88
37.40
12,825.00
89.88
39.15
Start
OLS 7.00 TFO
-90.00
12,900.00
89.88
33.90
13,000.00
89.88
26.90
13,100.00
89.89
19.90
13,200.00
89.89
12.90
13,225.00
89.90
11.15
Start
DLS 7.00 TFO
-93.00
13,300.00
89.62
5.91
13,400.00
89.26
358.92
13,500.00
88.91
351.93
13,600.00
88.58
344.93
13,625.00
88.50
343.19
Start
DLS 7.00 TFO
90.00
13,700.00
88.51
348.44
13,800.00
88.53
355.44
13,900.00
88.58
2.44
Planned TD at 13900.00
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
TVD Below
System ♦N/-5 +E/ -W
(usft) (usft) (usft)
6,439 71 6,948.02 2,952.05
6,440.55
6,997.21
6,441.62
7,016.94
6,447.50
7,096.27
6,456.85
7,195.76
6,468.30.
7,294.25
6,481.68
7,390.26
6,493.85
7,482.85
6,501.71
7,571.14
6,505.14
7,653.81
6,506.54
6,508.35
6,508.86
6,510.31
6,511.85
6,512.92
6,513.51
6,513.58
6,513.74
6,513.95
6,514.00
6,514.15
6,514.36
6,514.55
6,514.75
6,514.79
6,515.11
6,516.08
6,517.68
6,519.87
6,520.51
6,522.47
6,525.05
6,527.57
7,729.35
7,796.35
7,811.65
7,859.32
7,930.73
8,010.12
8,096.32
8,118.78
8,185.11
8,268.06
8,287.68
8,347.93
8,434.12
8,525.84
8,621.71
8,646.16
8,720.30
8,820.14
8,919.75
9,017.63
9,041.66
9,114.33
9,213.24
9,313.13
2,943.17
2,940.04
Vertical Dogleg
Well 1C-06
Mean Sea Level
1C-06 @ 94.00usft (1C -O6)
True
Minimum Curvature
Section
Rate
(usft)
(°/100usft)
7,475.32
0.00
7,520.54
7.00
7,538.76
7.00
2,931.85
7,613.29
7.00
2,932.40
7,709.54
7.00
2,944.93
7,807.91
7.00
2,969.25
7,906.94
7.00
3,004.84
8,005.58
7.00
3,051.00
8,102.81
7.00
3,107.05
8,197.17
7.00
3,172.46
3,246.59
3,266.35
3,324.20
3,394.11
3,454.79
3,505.37
3,516.34
3,551.28
3,607.02
3,622.51
3,667.14
3,717.72
3,757.41
3,785.64
3,790.85
3,801.97
3,606.18
3,798.21
3,778.18
3,771.31
3,752.94
3,738.93
3,737.09
8,287.07
8,370.98
8,390.87
8,451.89
8,538.95
8,631.35
8,727.70
8,752.23
8,825.35
8,919.90
8.942.86
9,012.60
9,108.95
9,207.82
9,307.72
9,332.69
9,407.18
9,504.72
9,598.87
9,688.23
9,709.66
9,775.10
9,867.02
9,963.02
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
Toolface
Map
Azimuth
Northing
(°)
(usft)
0.00
5,975,831.46
150.00
5,975,880.57
149.97
5,975,900.26
101.00
5,975,979.52
100.59
5,976,079.00
99.95
5,976,177.58
99.15
5,976,273.78
70.00
5,976,366.65
69.20
5,976,455.30
68.68
5,976,538.43
Map
Easting
(usft)
564,758.39
564,749.10
564,745.82
564,736.97
564,736.70
564,748.42
564,771.94
564,806.76
564,852.19
564,907.55
92.00
5,976,614.50
564,972.33
91.90
5,976,682.11
565,045.90
91.78
5,976,697.57
565,065.53
-88.00
5,976,745.71
565,122.98
-87.90
5,976,817.68
565,192.29
-87.79
5,976,897.56
565,252.31
-87.72
5,976,984.16
565,302.17
-87.68
5,977,006.71
565,312.95
90.00
5,977,073.33
565,347.34
89.99
5,977,156.72
565,402.40
89.97
5,977,176.47
565,417.72
-90.00
5,977,237.08
565,461.84
-89.99
5,977,323.68
565,511.71
-89.97
5,977,415.71
565,550.64
-89.96
5,977,511.80
565,578.07
-89.95
5,977,536.29
565,583.08
-93.00
5,977,610.51
565,593.59
-92.98
5,977,710.38
565,596.98
-92.91
5,977,809.90
565,588.19
-92.80
5,977,907.61
565,567.35
-92.64
5,977,931.58
565,560.29
90.00
5,978,004.08
565,541.32
89.86
5,978,102.87
565,526.50
89.68
5,978,202.73
565,523.83
Casing Points
Measured vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name (in) (in)
13,900.00 6,527.57 2-3/8" 2.375 3.000
8/152019 9:41: 20AM Page 3 COMPASS 500014 Build 85H
_ ConocoPhillips BA ER
Planning Report F�UGHES
ConocoPhillips aGEcompany
Database:
EDT 14 Alaska Production
Company:
ConowPhillips Alaska Inc_Kuparuk
Project:
Kuparuk River Unit
Site:
Kuparuk 1C Pad
Well:
1C-06
Wellbore:
1C-061-1-02
Design:
1C-061.1-02_WP02
Plan Annotations
Measured
Vertical
Depth
Depth
lush)
(usft)
11,250.00
6,439.71
11,320.00
6,441.62
11,700.00
6,481.68
12,000.00
6,505.14
12,225.00
6,508.86
12,625.00
6,513.58
12,825.00
6,514.00
13,225.00
6,514.79
13,625.00
6,520.51
13,900.00
6,527.57
Local Corordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Local Coordinates
-NI-S
+EI -W
(usft)
(usft)
6,948.02
2,952.05
7,015.94
2,940.04
7,390.26
2,969.25
7,653.81
3,107.05
7,811.65
3,266.35
8,118.78
3,516.34
8,287.68
3,622.51
8,646.16
3,790.85
9,041.66
3,771.31
9,313.13
3,737.09
Well 1C-06
Mean Sea Level
1 C-06 @ 94.00usft (1 C-06)
True
Minimum Curvature
Comment
TIPIKOP
Start DLS 7.00 TFO 101.00
Start DLS 7.00 TFO 70.00
Start DLS 7.00 TFO 92.00
Start DLS 7.00 TFO -88.00
Start DLS 7.00 TFO 90.00
Start DLS 7.00 TFO -90.00
Start DLS 7.00 TFO -93.00
Start DLS 7.00 TFO 90.00
Planned TD at 13900.00
8/152019 9:41:20AM Page 4 COMPASS 5000.14 Build 85H
ConocoPhillips
Company:
ConocoPhillips Alaska Inc_Kuparuk
Project:
Kuparuk River Unit 1
Reference Site:
Kuparuk IC Pad
Site Error:
0.00 usft
Reference Well:
1C-06
Well Error:
0.00 usft
Reference Wellbore
1C-0611-02
Reference Design:
1C-06L1-02_wp02
Reference 1C-061-142_wp02
ConocoPhillips
Anticollision Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method: MD Interval 25.00usft Error Model:
Depth Range: 11,250.00 to 13,900.00usft Scan Method:
Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface:
Warning Levels Evaluated at: 2.79 Sigma Casing Method:
Survey Tool Program Date 8/14/2019
From To
(usft) (usft) Survey (Wellbore)
well 1C-06
1 C-06 @ 94.00usft (10.06)
1C-06 @ 94.00usft (1C-06)
True
Minimum Curvature
2.00 sigma
EDT 14 Alaska Production
Offset Datum
ISCWSA
Tmv. Cylinder North
Combined Pedal Curve
Added to Error Values
Tool Name Description
100.00
9,400.00 IC -06 (1C-06)
GYD-CT-CMS
Gyrodata contcasing m/s
9,400.00
9,900.00 iC-061-1_wp02(1C-0617)
MWD OWSG
OWSG MWD - Standard
9,900.00
11,250.00 1C-06L1-01_wp02(1C-0611-01)
MWD OWSG
OWSG MWD - Standard
11,250.00
13,900.00 1C-06L1-02_wp02(1C-0611-02)
MWD OWSG
OWSG MWD - Standard
Summary
Site Name
Offset Well - Wellbore - Design
Kuparuk 1 C Pad
I C-06 - 1 C -06L1-01 - 1 C-0611-01_wp02
10.06 -1C -0611 -01 -1C -06L1-01 w1302
1 C-07 - 1 C-07ALl - i G-07ALI
1 C-07 - 1 C-07ALl - 1 C-07ALl
1 C-07 - 1 C-07ALl PB1 -1C-07ALl PBI
1 C-07 - iC-07ALl PB1 - 1 C-07ALl PB1
1 C-150 - 1 C-150 - 1 C-150
1C-150 - 1 C-150 - 1 C-150
iC-151-1C-151-16151
1C-152 - 10.152 - 16152
1C-152 - IC -152- 1C-152
1C-153 - 1C-153 - 1C-153
1C-153 - 1C-153 - 1C-153
1C-154 - 1C-154 - 1C-154
1C-154 - 1C-154 - 1C-154
IC -154 - 1C-154 - 1C-154
IC -155 - 1C-155 - 10.155
1C-155 - 1C-155- 1C-155
1C-16- 1 C-16 - IC -16
1016 -1C -16-1C-16
1C-170 - IC -170 - 1C-170
1C-170 - 1C-170 - 1C-170
1C-174 - 1C-174 - 1C-174
IC -174 - 1C-174 - 1C-174
IC -19 - 1G-191-1 - 1C-191-1
1C -19-1C-1 91-1-161 91-1
1619 -1C -191 -1 -IC -191-1
1619 - 1C-191-1 - IC -191-1
1619 - 1C-191-1 - 1C-191-1
1C-19 - 1C-191-1 - 1C-1911
Plan: IC -156 - Plan: IC -156 - 1 C-156wp07
Plan: 1C-158 - PlanA C-158 - 1 C-158wp02
Reference Offset
Measured Measured
Depth Depth
(usft) (usft)
11,571.32 11,575.00
11,767.45 11,800.00
Distance
Between Between Separation
Centres Ellipses Factor
(usft) (usft)
45.41 43.45
115.93 104.06
13,350.00
13,475.00
1,206.78
810.31
13,350.00
13,475.00
1,206.78
810.31
13,400.00
13,600.00
1,198.39
807.80
13,400.00
13,600.00
1,198.39
807.80
13,500.00
13,850.00
1,192.68
817.91
13,500.00
13,850.00
1,192.68
817.91
Warning
23.124 CC, ES
9.766 SF
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
3.044 SF
3.044 SF
3.068 ES
3.068 ES
3.182 CC
3.182 CC
Out of range
Out of range
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
81142019 10:39:54AM Page 2 COMPASS 5000.14 Build 85H
c
ConocoPhillips
Company:
ConocoPhillips Alaska lnc Kuparuk
Project:
Kupal River Unit _1
Reference Site:
Kuparuk 1C Pad
Site Error:
0.00 usft
Reference Well:
10.06
Well Error:
0.00 usft
Reference Wellbore
160611-02
Reference Design:
1C-061-1-02_wp02
ConocoPhillips
Anticollision Report
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
well 1 C-06
1C-06 a 94.00usft (1606)
1C-06 Q 94.00usft (1606)
True
Minimum Curvature
2.00 sigma
EDT 14 Alaska Production
Offset Datum
Summary
Kuparuk
IC Pad-
1C-06-1C-06L1-01-1C-06L1-01_wp02
Reference
Offset
Distance
o)eetseserrac Doo usft
survey Pro92m:
Measured
Measured
Between Between
Separation Warning
Site Name
Depth
Depth
Centres Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
(usft)
(usft) fust[)
Kuparuk 1C Pad
Aate
Prelim. 1C -157 -Plan 1 C-157 - 1 C-157wp06
Measured
Out of range
Prelim. IC -157 -Plan 16157 - 1 C-157wp06
Vantcal
Reional
Onset
Out of range
Offset Design
Kuparuk
IC Pad-
1C-06-1C-06L1-01-1C-06L1-01_wp02
o)eetseserrac Doo usft
survey Pro92m:
100-3VUCT-CMS,
9400 -MWD
Ciel 9900.11050 ONSG
Seen Wet) Error: 0.00 usft
Rererente
Offset
84mi Major
Aate
Distance
Measured
Vernon
Measured
Vantcal
Reional
Onset
Anmmh
Oster Wellbore
Cantu
Between
Be...
Minimum
Separation Wamin9
Depth
Depth
Dearth
Depth
from North
.1,115
+EHV
Carl
Ellipses
5eparaeon
Factor
fusel
(usft)
lural
(user
lueft)
(usft)
(°)
(-it)
(use)
loaf)
(uanl
he l
1121699
6,53380
11275.00
6533.36
0.%
051
11.28
6,972.62
2941,59
048
-0.09
0.56
0.843 STOP Drilling
11,299.93
6,534.55
11,300.00
6,532.78
112
1.02
12.17
6.997.33
2,W3.86
1.90
0.99
0.91
2.092 Caution Monitor Closely
11324]8
6.535.93
11,325.00
6531.98
135
1.53
13.17
7,022.13
2.940.84
4.26
3,05
1,20
3.542
11340.64
6.53263
11,350.00
6530.96
1.41
284
14,02
7,047.01
2,938.56
7.15
5.89
1.46
4,094
11374.47
6.539.47
11,375,00
6,529.72
1.60
2.53
14,55
7,071.93
2.937.01
10.37
8.69
1.60
8166
11.399.27
6.541.44
11,400.00
6,528.25
1.02
3.03
15.06
7.096.07
2.926.19
13.93
1105
1,00
7.409
11.424.02
6.543.55
11,425,00
6,526.57
2.06
3.52
15+65
7,121.01
2.936.09
17.83
15.77
2.06
8,663
11.448.72
8.545]9
11,450.00
6,524.68
2.31
4.00
16.31
7.146.73
2.936]4
22.05
19.84
2,22
9,925
11,473.37
6,548.15
11,475.00
6,522.57
2.57
4.40
17.05
7,171.60
2,938.11
26.63
2426
2,37
11.215
11,497.95
6,550.64
11,500.00
6,520,24
2.84
4.95
17,07
7,196.40
2.940.21
31.53
29.01
252
12.511
11.522.51
6,553.25
11,525,00
6,517.91
332
5.43
17+72
7,221.21
2.942.31
36.40
Saw
2.53
14.370
11,547.01
6555.90
11.550,00
6,515.78
3.40
5.91
15.96
7,246.00
2.943.67
40.96
38.65
231
17]08
11.571.32
6,558.81
11,575.00
6,513.85
3.69
6.42
13.04
7.270.99
Zell
45.41
43.45
1.96
23.124 CC. ES
11,595.31
8,561,72
11.600.05
6.512.12
3.98
6.93
9.25
7,295,93
2,544.20
49.99
48.23
1+76
28.357
11,616.88
6,564.60
11,625.05
6.510.80
4.26
7.48
4.86
7,320.87
2,943.35
54.97
52]6
2.18
25.181
11,641.90
6,567.68
11,650.00
6,509.28
4.54
8.02
0.14
7,34538
2,94178
60,60
57.40
3.20
18.913
11,664.30
6,570.69
11.675.00
6,508.17
4.81
8.59
-4.66
7,370.65
2,939.47
67.11
62.58
4.53
14,800
11,605.97
6,573.69
11,700.00
8,507.26
5.05
9,17
.9.33
7.395.45
2,938.43
74.68
60.69
5.99
12.468
11,707.16
6.576.68
11,725.00
6,505.57
5.33
9,76
-13.70
7,420,15
2932.87
83.40
75.91
7.49
11.129
11,728.13
6,579.53
11,750.00
6.506.00
5.56
lUli
-17.76
7.444,74
2,928,17
93.17
04.18
9.02
10.334
11,748.25
6,582.08
11,.45.00
6.505.81
5.03
10.98
-21.46
7,469.19
2,922.96
104.01
93.52
10.48
9.920
11,767.45
6,58435
11.800.00
6,505]4
8.06
11.60
-24.78
7,493,47
2,917.03
115.93
104.06
11.87
9+766 SF
11,786.11
6586,41
11.025.00
6505.85
6.29
1223
-27.52
7,517.76
2,911.10
128,53
115.40
13.13
a7e)
11,804.64
6.588.31
11,850.00
85013.11
6.52
12.86
.29.61
7,54221
2.905.91
141,31
127.07
14.24
9,922
11,823.04
6.590.05
11875.00
6,506.52
6.74
13.49
-31.20
7.566.81
2.901,46
154.15
138.90
15.25
10.110
11,841,32
6.591.63
11,900.00
6,507.06
cats
14.11
-32.43
7,591.52
2897.74
16fi.98
150.82
16,16
10.331
11,859.47
6.593.05
11925.00
6,507.76
7.10
14.72
-33.36
7.616.33
gal
179.75
162,75
17.01
10.570
11.827.50
6,594.32
11.950.00
6.500.59
739
15.34
-30.08
7,%1.22
2,892.54
192.42
174,63
17.79
10.819
11.895.41
6.595.44
11975,00
6,509.57
7.61
15.94
-34,81
7.656.16
2.891.06
205.95
186.44
18.51
11.073
11.913.20
6.505.42
12,000.00
6,510.70
7.82
16.53
-35.00
7,691.12
2.890.34
217.32
198.14
19,10
11.330
11930.88
6,597.24
12,025.00
6,511.96
8.03
17.11
-35.28
7,718.09
2.890.36
229.53
20932
19,81
11.589
11.950.00
6.597.98
12,05080
6,513.36
8.25
17.69
-3536
7,741.03
2,891.13
241.56
221,05
2051
11]80
11.965.88
6,598.47
12.075.0
6.514.90
8,44
10.24
-35,56
7,765.94
2.892.65
253.37
232,44
20.93
12.105
11,983.21
6,590.80
12.10000
8516.58
8.64
18.80
-35.61
7,790]0
2.894,92
265.00
243.56
21.43
12.363
12.000.00
6,599.14
12,125.0
6,518.26
8.83
19.35
-35.63
7,815.62
2,897.19
277.05
255.16
21.90
12,648
12,015.54
6,599.33
12,150.00
6,51981
9.01
19.91
-35.62
7,040.52
2,898.71
290.23
Still
22.31
13.009
12030.23
6,599.52
12.17580
6.521.22
9.17
20.51
-35.59
7,865,47
2,899.40
304.48
20178
22.70
13.413
12,050.00
5,599.79
12,200.00
6.522.49
9.39
21.10
-35.14
7,890.44
2.099.50
319.03
296.33
23.50
13.611
12.057.40
6.599.89
12.225.00
8,523.63
9.48
2173
-35,47
7,915.40
2,090.77
335.99
312.55
23.43
14.340
12,059,05
6.600.08
12,250.00
6,524.63
9.61
22.36
-35.30
7,940,33
2.897.29
353.13
329.35
23.78
14.053
12,081.55
6,600.25
12,275.00
6.525.49
934
2102
-35.28
7,965.22
2,895.06
371.12
30.01
24.11
15.393
CC - Min centre to center distance or covergent point, SF- min separation factor, ES - min ellipse separation
81142019 10..39:54AM Page 3 COMPASS 5000.14 Build 85H
3
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ConocoPhillips
Project: Nuparuk River Unit t
xmMn.wrry. wnn
Mgro4o Nen^ f%^a'
WELLBORE DETAILS: IC-O6L1
WEREMCE INFORMaiIDM
coartreu(WX) R...—: Wel 1Cu6 T—f+mn
Parent Wellbore: 1 C-06
Site: Kupamk IC Pad
MeaMk E„M
Verlka(ND)Refere 1ca6@N.00osalfca6l
Well: 1C-06
onrym 5'..R
Te on MD: 9400.00
S%emiv$i Relwemce SbL(DWN.a.WEI
Wellbore: 1C -06L1
tle aqr°' �'�
Mmsur� OSpN Relnenre: 1CL6 ®41.Wuatl (1fA6)
Plan: aC4 Lt_wp02 (t C418ItC-0BL4)
nxew ei or�.r�m�
Calwaem Memos: Mhmum awre
5500
5000 nm
4000350
}L PW h
ivenk'-ite:.'eac _
Rsnn anon d500 5000 SWM 6600 b500 7000 7500 8000 8500 900f h( IuOuo lr)Olj11000 ll�uu
West( -)/East(+) (500 usft/in)
iC-O6 � 94.00usO (iC-06)
i UGHES
GEmmpa,
KUP INJ WtLLNAMt TO-Ub WIFLLULIKt is-06
Cbreol:43 1hilfip$ MW ' Well Attributes Max Angle & MD TO
pieta Name WeI1Wre PPIlUN1 WNIMre Statue ncl E) MD Itt ACI BM IM1KBI
A1a97 E, IDC. KUPARUK RIVER UNIT 500292056400 INJ 8.00 4,200.00 102430
GeneratedH351ppml Date M, tine EM Dale KBGrtl lfll flg Pelease Dab
SSSV: TR DP Las WO'. 1112/007 39.01 W31I1981
1.1,14e01a11o9aea4 Last Tag
Veliwle[FemMe(aamen Amh.on DepNgnam End USE i We11Lre Lead Mod By
- -- --. --.-. _.-
HANGER; 2i,9�,
wx9xcrDRsoaSp
ary'r vtv. lana
6DRFAC E: 31 }3,9)0-
GPSDFT: 9.0]9.2
PBR; 9.1]5.5
PA it rest]
NIPPLE: Shod
OVERSHOT: SabiPerforations
SBR: 925
PACKER: 9lala
Se
NIPPLE.93,9.3
Ped.9 a10.69,485.0�
FIah 10.016.0
PROWLTION',.610..-
1
_
Last Tag: PIKE ander.9,I ]/82019 I 1006 ldri
Last Rev Reason
Attention I End Dab I W¢uba,e LastMm ev
Rev Reason Tag I ➢812019 1C-O6 1 fergusp
casing htgs
er oo lint IDlinl
CONDUCTOR
CONOues-e I6 15.06
Top (nnal Sul Dep(F lnNe) Set Depm ITVDL..
65.0 65
62,58 l_. Grade
H-40
WELDED
WELDED
SURF Deecriplion 1.0 tal0314 IDlinl
SURFACE 103/4 9.95
ded
Top IM1KBI Set Depth (XNa) Sat Depth liw,
Top
Well
45.50 .. Grade
K-55
Tap Threat
BUTT
Casing ate-quits (on OD lint IDlinl
PRODUCTION I 628
Top Set Deo Set Del
Top IXKBI Set Depth (M1KB) Se Depth liw.
296 10225.8 ]090.1
vatco
26.00 K-55
26.00 (I... K-55
Top Th,ead
BTC
Tubing Strings
TUEing Oezcrim; Suring do 11D(nI TaA She, imt Do,, F 1R..5al Depth ITVDI "(1flm Grade Top Gonnectlon
TUBING 2007 W0 3112 2.99 269 92329 6,38].5 9.30 L-80 Ord
Color on Details
Tap mi Top mN Nominel
ropinke IXKBI pl item Des Lom IE I:n)
269 26.9 0.00 HANGER FMC Tubing HANGER 3.500
2,237.6 2,021.0 43.75 SAFETY VIED 3.S Inkil -SE Safely Valve (Serial M HYS703) 2.812
9,135.5 6313.4 3. PENN Baker Pi seal assembly (pinned 40M#) W12.39' sDaceaut 3.000
9,1515 6.3258 39.54 PACKER Baker FHL Packer (pinned MW shear) 3.000
9.193.2 635].6 4079 NIPPLE 2.81 Y X Nipple 2SU3
9,231.9 6.381 41.80 OVERSHOT Baker Tubing Stub Overshot +)'Space Out 3.610
Tuning Descriplbn Slnng Ma,. ID(nl IT east SN DeghIR. Sel Depb ITVO I.. Wt111LAt Grace Top Lonrreclion
TUBING 1993 WO 53/4 d.3] 92322 9,281.5 6,423.4
Completion Details
Lphile"
rop USED
dreg,
Top) l
E9
uam Dee Lom
Nominal
In n)
9.2552
6.4040
42.38
SBR SANER EL-1 SBR (prone O joiM,TBG Siring shwnn8 BR DIID)
4.375
Tubing Deecnptan $Nng Ma... IDlin Tap IXKBI 6e10¢pth lX.. Sel DeptM1 ITVDI I... Wt(Eard Grade Top Canmearm
TUBING Original 31/2 2.99 9.281.5 9,38] 2 6498 ] 9.20 K-55 BTC
Completion Details
Top(1VD) TWIIWI Nominal
Top IBKBI brale E) XBm Db Lam IO fin)
.d 43.04 PACKER BAKER FHL PACKER 3000
.5 66-15
9.49. 6,41.7 44.98 NIPPLE CAMC DNIPPLE NO GO 2750
9 Jorm V 6.494.3 45.3 SOS 2992
Other In Hole (Wireline retrievable plugs, Valves, PUmps,.. _ Sw .)
iapfTVDI
lop IM1KB) IRKS
T^P Incl
E) Oez Com
Run Dale
ID (in)
10,026.0 6,9464
44.00 Fisn Vann Gun Leh irpm original ped. 101'long
6125/1981
& Slots
Tap IflKB1
Btm (M1KB)
Top IND)
fhKBl
Btm lrw)
IRKS)
tinktl2ane
Oetr
$Fd
Dens
(ehaam
1
Tyce
Com
Asle0
I 9.485.0
6514.4
I 6565.8
UNIT D, CI,C-
3, 1606
311111981 I
124
Mandrel Inserts
w
N
Top INKBI
ToppV9)
(hKB
Make
MWN
ODlin)
Sery
Wlw
Type
Try,
type
Port Su¢
(n)
TRO Run
(Wi)
Run W1ek.-
90]9.2
6269.2
Came
MMG
112
GASLIFT
DMV
BK
0000
0.0
11111/ OB]
Notes: General & Safety
Em Dme Mnolmon
112311993 NOTE_ WORKOVER
alP20o4 NOTE WAIVEREDWELL; T. A COMMUNICATION
12/282010 INOUE; VIEW SCHEMATIC W/Alaska Schem duSh0
Proposed CTD Schematic
16"65# H-40 shoe
@65'MD
10-3/4"46# K-55
shoe @ 3287' MD
9430'
C -sand per(s
9410'- 9485' MD
7" 26# K-55 shoe @
10,226' MD
3-1/2" TRMAXX-5E SSSV @ 2238' MD
3-1/2" 9.3#L-80 ELIE 8rd Tubing to surface,
3-1/2" Cameo MMG gas lift mandrel @ 9079'
Baker 3-1/2" PBR @ 9136' MD (3.0" ID)
Baker FHL packer @ 9152' MD (3.0" ID)
X -Nipple @ 9193' MD (2.813" ID)
Baker EL -1 SBR @ 9255' MD (4.375" ID)
Baker FHL Packer @ 9282' MD (3.0" ID)
3-1/2" Camco D landing nipple @ 9349" MD (2.75" min ID, No -
Go)
3-1/2" tubing tail @ 9381' MD
1C-06Li-02 wp02
TD -top
-MD
Linertop- 9320'MD
1C -06L1-01 wp02
TD -14,300' MD
Billet/Liner top - 11,250' MD
MD
p - 9900' MD
le", t-. th—, nm.
Well No.
Status
f ng
She
TWOfCSand
09 pool (MD)
TWd4SaMtNI
Pool (MSS)
TWof Cement
(RAD)
TWdCemmt
)NOSI
Topor Lament
Determined By
Beserwir Rmus
Zonal limitation
Cement0pera6ons
Summary
Mechanical Intuavity
IC -06
Inlectm open to only C -Sand
MMA passed @3000 PSI 7/26/19
)Motherbom)
Shut-in
T'
9611'
6021'
5225'
3680'
LOS
through,erfortbns.
Packer at 9292' and TOC at 5225'
535sa ClassGcement
MITOA passed@IWO ps17/26/19
Producer open only to C -Sand
IGI94.1
through mmherbom perforations
)IC -19
and RD sidetrack completed
MMA passed @270 psi 9/7/17
Mothwbum)
Producin
7"
lo,ia0'
6059'
9281'
MO.
L.1
with slotted finer.
PftWat10,035'aMTOCat9281'
200uCionGcement
MITOA BIIeE S/28/07
t I
Loepp, Victoria T (CED)
From: Loepp, Victoria T (CED)
Sent: Monday, September 9, 2019 5:19 PM
To: Germann, Shane
Subject: Re: PTO's for KRU 1 C-06 Laterals
They're in process. Not much lead time on these permits.
Sent from my iPhone
On Sep 9, 2019, at 2:59 PM, Germann, Shane <Shane.Germann@conocophillips.com> wrote:
Victoria,
I'm checking in to see what the status is for the PTD's for the KRU 1C-06 laterals (1C-061-1, 1-1-01, & L1-
02). We should be moving to the 1C-06 tomorrow night (9/10). Feel free to give me a call or email if
there is any information you need from me.
Thanks,
Shane Germann
Coiled Tubing Drilling Engineer
Office: 907-263-4597
Cell: 406-670-1939
700 G St, ATO 664, Anchorage, AK 99501
1
Loepp, Victoria T (CED)
From: Loepp, Victoria T (CED)
Sent: Tuesday, September 10, 2019 7:50 AM
To: Germann, Shane
Subject: KRU 1C-061-1, -1-1-01,-L1-02(PTD 219-117, 219-118, 219-119) 1/4 mile AOR
Shane,
Please send a well plat showing the % mile review area for each lateral and a table outlining information as shown in the
example attached plat and table.
Thanx,
Victoria
Section 2 — Plat 20 AAC 25.283 (a)(2)
Plat 1: Wells within .5 miles
ASRCNPR7
ASRCNPR3
AA092347
AA081817
ConoCoPhillips
ALisk3
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• Frac Poets
QHair We Frac Pon Bev
O Hail Lob Well Track Bun
— Weds wCxn Truk Bu!lee
AW Track
Open lm IVIII
.-NIP 4 – Alpine PA
Unit Boundary
\8 CPAI Lease
ASRCNPR4
CDS-98 1% AA081B17 i
Lease Plat 1 0 02 04 08 0.8 1
m Miles
2
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TRANSMITTAL LETTER CHECKLIST
WELL NAME: k Kik
PTD: a 19,119
Development "Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: K N p u li C4 1 ✓PV— POOL: I-<UPQ l ex // �\ 1 lip �/ O/ L
1
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing well Permit
LATERAL
No. I S 1 —0 ZS—, API No. 50- 001- aO�'cr- ca- 00.
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50- -
_) from records, data and logs acquired for well
name on pit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are fust caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
It
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100
Well Name: KUPARUK RIV UNIT -06L1-02 Program SER _ Well bore seg
PTD#:2191190 Company Cono_coPhilli s -Alaska Inc Initial Class/rype
SERI PEND GeoArea 890 _ Unit 11160 On/Off Shore On Annular Disposal [i
Administration
1
Permitfee 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 & 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 be issued without administrative approval - - - - - - - - -- - - - --- - - - -
YeS
13
Can permit be approved before 15 -day wait _ _ _ _ _ _ - - - - _ ...
Yes
DLB 9/6/2019
14
WeII located within area and strata authorized by Injection Order # (put 10# in.comments).(For.
Yes
_ Area Injection Order No. 2C -. Kuparuk River Unit.
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 than_3 months _(For service well only) . -
NA ....
- - Well will not be pre=produced per ConocoPhillips.
17
Nonqonven, gas conforms to AS31,05.030([.1.A).0,2.A-D) - - - --- - - - - - - - - - - - -- - --
NA-
.. _ . - - - - - - - - - - - - - - - - - -
18
Conductor stringprovided - - - _ _ _
NA- - -
- - - - Conductor set .farKRU tQ-06
Engineering
19
Surface casingprotects.all known USDWs . . . . . . .. . . . . . ....
NA_ _ _
.... - Surface casing set for KRU 1C-06. .
20
CMT. vol adequate to circulate on conductor & surf.csg _ _ _ _ _ _ _
NA
_ _ _ Surface casing set and fully cemented
21
CMT. voladequate_ to tie-in long string to surf csg- - - - - - - - - - - - - - - - - - -
NA
22
CMT. will cover all known productive horizons _ _ . . . ..... . . . . . .. . . .
Yes _
- _ _ _ _ Productive_ interval will be completed with uncemented slotted. liner
23
Casing designs adequate for C, T, 13 & permafrost. _ _ _ . . ... . . . . ......
Yes
24
Adequate tankageor reserve pit _ _ _ - - - - - - - --- - - - - - --- - -
Yes ...
_ _ _ Rig has steel tanks; all waste to approved disposal wells
25
If a. re -drill, has 10-403 for abandonment been approved ..... . . . ... . . . . .....
NA
26
Adequate wellbore separation proposed _ _ _ ... _ _ _ _ . . . . ...... . .. . . .
Yes _ _
..... Anti -collision analysis complete; no major risk failures
27
If diverter required, does it meet regulations - _ .. - - - - - - - - -
NA
28
Drilling Fluid program schematic & equip list adequate.... . . . .. . . . . ..... .
Yes -
- _ . Max formation- pressure is 3866 psig(11.9 ppg EMW ); will drill. w/ 8,6.ppg EMW and maintain overbal w/ MPD
Appr Date
VTL 9/10/2019
29
BOPEs, do they meet regulation _ - - - - ----- - - - - -- - - - -Yes
- - - - - - - - - - - - - - - - - - - - - - - - - -
30
ROPE press rating appropriate; test to (put psig in comments)... _ _ _ _ _ _ _ ....
Yes
_ _ _ Max formation pressure is 3235 prig; will test BOPS to 3500 psig _
31
Choke manifold complies w/API. RP -53 (May 64).. _ _ _ _ _ .... - -
- -
Yes
32
Work will occur without operation shutdown- - - _ _ _ ....
Yes
33
Is presence of 1-12S gas. probable . . . . . . . . . . . .... . . . . . .. . . . . . ...... . . . .
Yes _ _
_ H2S measures required. _ ...
34
Mechanical condition of wells within AOR verified (For service well only) _ _ _ _ .. - - - - . _
Yes _ _
_ _ KRU 1 C -07A, 1C-19, 1Q -19L1 and 1C-111-2-02 mech integrity verified_
35
Permit can be issued w/o hydrogensulfidemeasures _ _ _ _ _ _ __ _ _ _ _ _ _ ____ _ _ _ _
No.. _
_ Wells on 1C7Pad are H2S-bearing. H2S measures required,
Geology
36
Dista presented on potential overpressure zones
Yes
Appr Date
37
Seismic analysis of shallow gas -zones
NA - ---
- - - - - - - - - - - - - - - - - - - - - - - - - - - -
DLB 9/6/2019
38
Seabed condition survey _(if off -shore) _ _ _ _ _ _ _ _ _ _ ___ _ _ .... _ _ ....
NA_
39
Contact name/phone for weekly progress reports [exploratory only] _ _ _
NA
Geologic Engineering Public
Commissioner: Date: Commissioner: Date Commissioner Date
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