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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout219-117DATA SUBMITTAL COMPLIANCE REPORT
1/14/2020
Permit to Drill 2191170 Well Name/No. KUPARUK RIV UNIT 1C-061-1 Operator ConocoPhillips Alaska, Inc.
MD 11964 TVD 6529 Completion Date 10/1/2019 Completion Status 1WINJ Current Status 1WINJ
REQUIRED INFORMATION /
Mud Log No J
DATA INFORMATION
List of Logs Obtained: GR/Res
Well Log Information:
Log/
OH /
Electr
Data
Digital
Dataset
Type
Med/Frmt Number Name
ED
C
31332 Digital Data
ED
C
31332 Digital Data
ED
C
31332 Digital Data
ED
C
31332 Digital Data
Log
31332 Log Header Scans
ED
C
31368 Digital Data
ED
C
31368 Digital Data
ED
C
31368 Digital Data
ED
C
31368 Digital Data
ED
C
31368 Digital Data
ED
C
31368 Digital Data
ED
C
31368 Digital Data
ED
C
31368 Digital Data
ED
C
31368 Digital Data
ED
C
31368 Digital Data
ED C 31368 Digital Data
ED C 31368 Digital Data
ED C 31368 Digital Data
AOGCC'
Samples No ✓
API No. 50-029-20564-60-00
UIC Yes
Directional Survey Yes 1/
(from Master Well Data/Logs)
Log Log Run Interval
OH /
Scale Media No Start Stop
CH Received
Comments
10/21/2019
Electronic File: 1C-061-1 EOW - NA083.pdf
10/21/2019
Electronic File: 1C-061-1 EOW NAD27.pdf
10/21/2019
Electronic File: 1C-061-1 EOW NAD27.bd
10/21/2019
Electronic File: 1C-061-1 MD NAD83.bd
0 0
2191170 KUPARUK RIV UNIT 1C-061-1 LOG
HEADERS
9178 11964
10/23/2019
Electronic Data Set, Filename: 1C-061-1 GAMMA
RES.Ias
10/23/2019
Electronic File: 1C -06L1 21VID Final Log.cgm
10/23/2019
Electronic File: 1C-061-1 51VID Final Log.cgm
10/23/2019
Electronic File: 1C-061-1 5TVDSS Final Log.cgm
10/23/2019
Electronic File: 1C-061-1 51VID Final Log.pdf
10/23/2019
Electronic File: 1C-061-1 5TVDSS Final Log.pdf
10/23/2019
Electronic File: 1C-061-1 2MD Final Log.pdf
10/23/2019
Electronic File: 1C-061-1 EOW NAD27.pdf
10/23/2019
Electronic File: 1C-061-1 EOW NAD27.bd
10/23/2019
Electronic File: 1C-061-1 Final Surveys TO
11964.csv
10/23/2019
Electronic File: 1C-06Li Final Surveys TO
11964.x18x
10/23/2019
Electronic File: 1C-061-1 Survey Listing.bd
10/23/2019
Electronic File: 1C-061-1 Surveys.txt
Page I o£3
Tuesday, January 14,2020
DATA SUBMITTAL COMPLIANCE REPORT
1/14/2020
Permit to Drill 2191 170 Well Name/No. KUPARUK RIV UNIT 1C -06L1 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20564-60-00
MD
11964
TVD 6529 Completion Date 10/1/2019
Completion Status 1WINJ Current Status 1WINJ UIC Yes
ED
C
31368 Digital Data
10/23/2019
Electronic File: 1C -
06L1 _25_tapescan_BH I_CTK.txt
ED
C
31368 Digital Data
10/23/2019
Electronic File: 1C -
06L1 _5_tapescan_BHI_CTK.txt
ED
C
31368 Digital Data
10/23/2019
Electronic File: 1C-06t1_outputtap
ED
C
31368 Digital Data
10/23/2019
Electronic File: 1C-061-1 2MD Final
Log.cgm.meta.tif
ED
C
31368 Digital Data
10/23/2019
Electronic File: 1C-061-1 5MD Final
Log.cgm.meta.tif
ED
C
31368 Digital Data
10/23/2019
Electronic File: 1C-061-1 5TVDSS Final
Log.cgm.meta.tif
Log
31368 Log Header Scans
0 0
2191170 KUPARUK RIV UNIT 1C-061-1 LOG
HEADERS
Well Cores/Samples Information:
Sample
Interval
Set
Name
Start Stop
Sent Received Number
Comments
INFORMATION RECEIVED
Completion Report
Production Test Information Y 19
Geologic Markers/Tops , ' 1
COMPLIANCE HISTORY
Completion Date: 10/1/2019
Release Date: 9/10/2019
Description
Comments:
Directional / Inclination Data YO Mud Logs, Image Files, Digital Data /Y�/ Core Chips Y
Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files 6 Core Photographs YA
Daily Operations Summary Cuttings Samples Y / IP Laboratory Analyses Y NA
Date Comments
AOOCC Page 2 of 3 1 ucsday, January 14, 2020
DATA SUBMITTAL COMPLIANCE REPORT
1/14/2020
Permit to Drill 2191170 Well Name/No. KUPARUK RIV UNIT 1C -06L1 Operator ConocoPhillips Alaska, Inc.
MD 11964 TVD 6529 Completion Date 10/1/2019 Completion Status 1WINJ Current Status 1WINJ
Compliance Reviewed By:
API No. 50-029-20564-60-00
UIC Yes
Date: 1 / ("I / a62-0
AOOC'C' Page 3 of 3 Tuesday, 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 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.Pov>
Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.eov>; Winston, Hugh E (CED) <huxh.winston@alaska.aov>
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 SC -06
181-025
10-404 (Sundry # 319-380)
KRU 1C -06L1
219-117
10-401
KRU 1C-061-1-01
219-118
10-401
KRU 1C -06L1-02
219-119
10-401
KRU 1C-061-1
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.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
Vicfofia Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loepp@alaska.0oy
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain
confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or
federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the
AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or victoria Loeoo@alaska.aov
From: Germann, Shane <Shane.Germann@conocophillips.com>
Sent: 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, lames 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, 1-1-01, 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
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1a. Well Status: Oil ❑ Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑
/ 20AAC 25.105 20AAC 25.110
F1WINJ ' ' WAS✓ � WDSPL❑ No. of Completions:
ib. Well Class:
Development E] Exploratory L]GINJ
Service ❑� ' Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Abend.: 10/1/2019
14. Permit to Drill Number / Sundry:
211� 01 - if I I "
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded:
9/13/2019
15. API Number:
50-029-20564-60.00
4a. Location of Well (Governmental Section):
Surface: 1375' FNL, 858' FWL, Sec 12, T11N, R10E, UM
Top of Productive Interval:
1323' FNL, 1268' FEL, Sec 1, T11N, R10E, UM
Total Depth:
426' FNL, 2060' FWL, Sec 1, T11N, R10E, UM
8. Date TD Reached:
9/16/2019
16. Well Name and Number:
KRU 1C -06L7 '
9. Ref Elevations: KB:94 .
GL:55 - BF:
17. Field / Pool(s):
Kuparuk River Field/Kuparuk River Oil
10. Plug Back Depth MD/TVD:
' 11568/6537
18. Property Designation:
ADL 25649 '
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 561864 y- 5968860 - Zone- 4
TPI: x- 564970 y- 5974218 Zone- 4
Total Depth: x- 563011 y- 5975098 Zone- 4
11. Total Depth MD/TVD:
. 11964/6529 '
19. DNR Approval Number:
LONS 79-016
12. SSSV Depth MD/FVD:
2238/2021
20. Thickness of Permafrost MD1TVD:
1931/1785
5. Directional or Inclination Survey: Yes Q (attached) No ❑
Submit electronic and printed information per 20 AAC 25.050
13. Water Depth, if Offshore:
NIA (ft MSL)
21. Re-drill/Lateral Top Window MD/TVD:
9430/6528
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
DECEIVE®
GR/Res
OCT 3 0 2019
23. CASING, LINER AND CEMENTING RECORD AOGce
WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT
CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED
16 65 H40 32 65 32 65 36 425sx Permafrost
103/4 45.5 K-55 31 3287 31 2685 133/4 3400 sx AS II
7 26 K-55 30 10226 30 7090 8314 535 sx Class G
23/8 4.6 L-80 9467 11568 6551 6537 3 Slotted Liner
24. Open to production or injection? Yes ❑Q No ❑ -
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
SLOTTED LINER @:
9467-11568 MD and 6551-6537 TVD... 9/16/2019
COMPLETION
TE
(p (
VERIFIED
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MDffVD)
31/2 9387 915116326
9281/6423
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes ❑ No R]D
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED
27. PRODUCTION TEST
Date First Production:
NIA
Method of Operation (Flowing, gas lift, etc.):
INJECTION ONLY -- NOT PRE -PRODUCED
Date of Test:
Hours Tested:
Production for
Test Period
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Choke Size:
Gas -Oil Ratio:
Flow TubingCasing
Press.
Press:
Calculated
24 -Hour Rate
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Oil Gravity -API (corr):
Form 10-407 Revised 5/2017 VTI- / //r// 9 (/ TINUED ON PAGE 2 ,�BDMS f1'--- OCT 3 O r,O19 Submit ORIGINAL onl
�� �is77
28. CORE DATA Conventional Core(s): Yes ❑ No 2 ' Sidewall Cores: Yes ❑ No 2]
If Yes, list formations and intervals cored (MD/TVD, 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
ND Well tested? Yes ❑ No ❑✓
Surface If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Permafrost - Base
1931
1785 Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
9430
6528 information, including reports, per 20 AAC 25.071.
Formation @ TPI - Kuparuk C
TD
11964
6529
Formation at total depth:
Kuparuk C
31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontolooicalr
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: James Oh linger Contact Name: Shane Germann
Authorized Title: Staff CTD Engineer Contact Email: chane. ermannO co .com
Authorized Contact Phone: 263-4597
Signature: Date: O 9 f
INSTRUCTIONS
General: Th s 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 8 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 ND for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Form 10-407 Revised 5/2017 Submit ORIGINAL Only
1C-06 Final CTD Schematic uewua. ra-rvmiasn
3-112" TRM4XX5E BSBV 0 2238' MD
3-112" 9.01.410 EUE BN Tubing to surface
16" 65k l 40 sMe
* BS' MD
3-112' Camco MMG gas lilt mandrel ® 9045'
10-3/4" 48f K-55
shoe � 328T MD
Baker 3-1IY PBR ® 9102' MD (3.0' 10)
Baker FHL packers 9115' MD (3.0" ID)
X -Nipple @ 9159' MD (2.013" 10)
Baker EL -1 SBR ® 9222' MO (4.375" ID)
Baker FHL Pact er@ 9247 MD (3.0' ID)
3.12" Camco D bexin, nipple ® 9288" MD (Milled to 2.80" ID)
112" tubing tell ® 928V MD
C-san8 P.ff
94111'-9405' MO
MD
nt alaeua
10326 MD shoe
®� R� 1D41I1,
TD= 11,984' MO
TOL=8467 MD BOL-11,588'MD
13,822' MO
KUP INJ WELLNAME 1C-06 WELLBORE 1C_06
Wall Altribut Max Angle 1 TD
ConomPhillips "' g
FIeN Name We11Wre APVUWI WeIIWre Slaluz Icl l'1 MOII. Ac,etm (MNB
Alaska, FK:. K PAR KRVLR NT 5nnJPJnSfidnn N 8nn 4200 f1U 182439
TRDP I I ILSa WO:
1cm.,aum,e,zpz'.w PM
Last Tag
VeOUIwMmLeAi
Annolalien
DomphKel EMOffi Asn", batmoday
........ _.. ..........
GER;
,WIx4a
�� coapvcTOR. az.Iws.D
SAFETY VLV, 2.2376
SURFACE: s,
GFSOFT:90FI2
1. %rasa
pACYER', 8,1515
NIVPLE a,tm.x
ovERsnoT: 9.2419
sea: e.x55.x
PACKER: 9.al s is
RPPUS ITS4c.s
Pert.a<,ao9.aes.o-
FIN:,0.03S.D
PRODUCTION: 8 a,0.225.9�
orwr Top, g,V40
_._.....__...__..
I
�I
Last Tag:RKB
96580 l 19 1 -06 oan.,
Last Rev Reason
Amwlalon Era Dale wallbpre I.atMm er
Rev Reason: Atltl Liner CTD liner lop 101612019 1C -O6 term,
Casing Strings
easing 0euxpuon 100(k) John) TopaMa) semeptn plKe) Se,Depm IN01_. D, L.. Graoe Top Tinrevel
CONDUCTOR 16 15.06 320 65.0 65.0 62.58 H40 WELDED
Feet, wsedmt Op and to lml Top,mal, ser Depot mKm SN Depth(No) -.wVLeo P_Omae Top Tr-vd
SURFACE 10314 995 31.3 3,287.0 2.685.1 45.50 K-55 BUTT
Found gacripWnOp IMI m1.) iupa ) MDepM (SNB) Ser Oepar llVD1-leve en IL. Grade 1.1Th,eaa
PRODUCTION ) 6,28 29.6 10,225.8 ),090.1 2600 K-55 BTC
Tubing Strings
Tube Dawiplion SOMA Ma... mpo) Top lrtnal set Depth lrt.. sot Depin (rvDI (._ 93(OIW o,aae Top connectwn
TUBING 2007 W0 312 2.99 269 9,232.9 6,38)5 970 L-80 8rd
Completion Details
'up Fri Topincl Nominal
Top IKKB) DIKE) (°) Item Des Com m(in)
269 269 0.00 HANGER FMC Tubing HANGER 3500
2,237.6 2,021c 4335 AFETVVLV 3.5-TRMAXX-5E Safely Valve (Senal#HYSJ03) 2812
9,1355 6,313) 3906 PBR Baker PBR seal assembly (greed 4020#) W1239'spamout 3000
9,151.5 6325.8 3954 PACKER Baker FHL Packer (pinned 60M# shear) 3000
9,1932 6357.6 4 7 NIPPLE 2.813"X Nipple 2.813
91231.9 63867 41.80 OVERSHOT Baker Tubing Stub Overshot + lspace out 3.610
Tubing oncnp0an SlrinB Ma... ID IN Top (ryKBI see Depth (I.. ser D[pth (rvDI (... w191M) esus Top connection
TUBING 1993 WO 5314 437 9,2322 9,281.5 6,423.4
Completion Details
Top IT 81
Tepinm TOP In
IrtKa) r
Nwninel
Item Dea cum to lin)
92552
6404 0 42.38
SBR BAKER1 10BR11A un"Arm. TBG son, snowing SBR OD/10) 4.375
Tubing Description auh, Ma... IO ('rn) Top TftMg Sel Depllr lrt.. Set Depth lNe)I... W[(16'rtl G,Me Top Connectun
TUBING Onginal 3112 2.99 9201.5 9,387.2 6,490) 9.20 K-55 BTC
Completion Details
top(NO) Top Incl Nominal
Top 1INa) (flKa) 1°I Item Oea Co. to (in)
92815 64234 1 43.04 PACKER BAKER FHL PACKER 3000
9,3493 6,472.1 44.hit NIPPLE NIPPLEN O, MILLED TO 80'ON Olt Nipple 2800
behind pipe: 1C-06 11-02 CTO liner.
9.3809 D,494 31 4593 SDS 2.992
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Tep(NDI I Top Incl
TOpIKKe) are, (I
oe. no.
Run mo
men)
92)40 64129 42.85
Liner Top Liner Upinbrnmherbore: TD L1 2LineF
Op.
9rH2019
1992.
10.026.0 69464 44.00
FisM1 Vann Gun Le Irom original ped. 101'long
62511981
Perforations & Slots
Toppi
Bon ata
T�Make) l
Btm ITBVi 1
unlrM loos
ppip
Snot
Dens
andtaXt
Tapecw
9410.0
9485.
,5144
TD, 14,C-
3,1C-06
1x31/1981 1
12.0
Mandrel Inserts
st
an
H Tap(ryNB)
Tap(TVp)
RKE)
Make
Moeal
00 (in)
aery
Valve
Type
blc3
Typ¢
pM 4ize
pnl
TPO Pun
Ipso
4un1
90792
6269.2
CamcD
MMG
1112
GAB LIFT
DMV
BK
0000
0011
Notes: General & Safety
E Dare"pageant
112311933 NOTE'. WORKO R
41116dirpit NOTE: WAIVERED WELL: T x IA COMMUNICATION
lZ1112010 NOTE. VIEW SCHEMATIC WAAlaska Schemalic9.0
KUP SVC WELLNAME 1C-06 WELLBORE 1C -06L7
Conoco`Phillips weW NOeAm"a WRNIT SMax Angle T TD
At. WeS¢(ee
AI8$kdInc. SffJOJIgfidfilCVFl(°I MDp19
1m flMB1
AWMIMS
IOIN(1:+5 11,11.1
IC{X+. +oz3rm1a+z023e PM
Casing Stange
vmbJxb,e&NRWI
cnelne 0e:cnpoun
LI LINER
m(Inl
2318
IOIIN
199
TQPMKB) $el DeiEhett B) 8e1Deplh(TVD)_. wuLen p_. G+xae
9,46].0 11566.3 6,536.6 460 L-80
too Tmeae
STL
Liner Details
xomi nID
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Art, Uperations Summary (with Timelog Depths)
1 C-06
mr
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Stan Time
I End Time
Cur (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(WB)
End Depth(flKB)
9/11/2019
9/11/2019
2.75
MIRU
MOVE
MOB
P
move from 1G-113 to 1G-103
0.0
0.0
0000
02:45
9/11/2019
9/11/2019
2.00
MIRU
MOVE
MOB
P
On location, removejeeps, 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
04:45
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-
connect).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
10:00
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
BOPE
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
9/11/2019
9/11/2019
1.80
MIRU
RIGMNT
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
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
RIGMNT
CTOP
P
Check pack offs. Install floats in UQC
0.0
0.0
02:45
03:45
9/12/2019
9/12/2019
1.00
SLOT
WELLPR
PULD
P
P/U BHA#1. FCO with straight motor
0.0
0.0
03:45
04:45
and 2.80" D-331 mill. Load into PDL.
Hang motor in well
9/12/2019
9/12/2019
1.75
SLOT
WELLPR
PULD
P
PJSM. PD BHA#1, surface test tools
0.0
0.0
0445
0630
(good), stab INJH, tag up reset
counters.
9/12/2019
9/12/2019
3.00
SLOT
WELLPR
TRIP
P
RIH to 2,000', adjust gooseneck,
0.0
2,837.0
06:30
0930
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
CLOG
P
Log CCL 9,280'to 9,450'@ 20 fpm,
9,280.0
9,450.0
11:36
1218
pumping 1.9 bpm/3,688 psi
Page 1122 ReportPrinted: 10/23/2019
Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
start Time
End Time
Dur (hp
Phase
Op Code
Activity Code
Time P -T -X
Operation
(ftKa)
End Depth (W)
9/12/2019
9112/2019
1.40
SLOT
WELLPR
TRIP
P
POOH, chasing milling Fluid to surface,
9,450.0
500.0
12:18
13:42
@ 746' notice scale and sand on
shaker
9/12/2019
9/12/2019
0.30
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
15:36
9/12/2019
9112/2019
0.50
PROD1
RPEQPT
PULD
P
PIU NS HEW BHA
0.0
0.0
15:36
16:06
9/12/2019
9112/2019
0.30
PROD1
RPEQPT
PULD
P
PD, BHA#2 NS/HEW
0.0
73-5-
16:06
16:24
9/1212019
9/12/2019
1.00
PROD1
RPEQPT
PULD
T
Tool tagging up shallow in PDL. Lay
73.5
0.0
16:24
17:24
down tool to inspect. HEW hanging up
on no go plate. Modify HEW
9/1212019
9112/2019
1.30
PROD1
RPEQPT
PULD
P
PD BHA#2 Northern SoullionsHEW
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
PROD1
RPEQPT
TRIP
P
RIH, BHA#2 Whipstock, EDC open
73.5
9,210.0
18:42
20:42
9/12/2019
9/12/2019
0.20
PROD1
RPEQPT
DLOG
P
Log K1 for+ 1.5' correction.
9,210.0
9,242.0
20:42
20:54
PUW=39K
9/12/2019
9/12/2019
0.30
PROD1
RPEQPT
TRIP
P
Continue into set depth @ 9438.78'.
9,242.0
9,438.0
20:54
21:12
Oriented to high side. Close EDC.
Pressure up setting tool. See tool shift
@ 3900 PSI. Set down 4K. Good
9/1212019
9/12/2019
1.80
PROD1
RPEQPT
TRIP
P
Trip out after seting whipstock, EDC
9,438.0
80.0
21:12
23:00
open
9/1212019
9112/2019
0.60
PROD1
RPEQPT
PULD
P
Tag up and space out. PJSM PUD
80.0
0.0
23:00
23:36
1
IBHA#2
9/1212019
9113/2019
0.40
PROD1
RPEQPT
PULD
P
PIU NS setting tool. M/U mill motor,
0.0
0.0
23:36
00:00
pup, 2.80 NS window mill and 2.79
String reamer
9/13/2019
9/13/2019
1.30
PROD1
WHPST
PULD
P
Pressure deploy BHA#3 with WFT V
0.0
76.6
00:00
01:18
fixed bend motor, NS 2.80 window
mill, NS 2.79 string reamer and 10'
pup. Make up to coil and surface test.
9/13/2019
9/13/2019
1.60
PROD1
WHPST
TRIP
P
RIH BHA#3
76.6
9,210.0
01:18
02:54
9/13/2019
9/13/2019
0.10
PROD1
WHPST
DLOG
P
Log K1 for+.5'
9,210.0
9,238.0
02:54
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
9/13/2019
9/13/2019
5.25
PROD1
WHPST
WPST
P
Bring pumps on 1.79 BPM @ 3631
9,433.0
9,435.3
03:24
06:39
PSI FS, BHP=3927. Call milling pinch
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)
9/13/2019
9/13/2019
1.50
PROD1
WHPST
TRIP
P
POOH, chasing sweep to
9,459.0
73.5
12:42
14:12
surface.PJSM
9/1312019
9/13/2019
1.20
PRODI
WHPST
PULD
P
Tag up at surface, PUD milling BHA
73.5
0.0
14:12
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 noule,
0.0
0.0
15:24
15:42
stab INJH, get stack and surface lines,
unstab INJH, brake no&e off,
9/13/2019
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
1
ako motor
Page 2122 Report Printed: 10/2312019
Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Depth
Start Time
End Time
Dur (hr)
Phew
Do Code
Activity Code
Time P -T -X
Operation
(ftKB)
End Depth(&KB)
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
9/13/2019
9/13/2019
0.10
PROD1
DRILL
DLOG
P
Log Kt for +35 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
9,460.0
18:54
19:06
window. Bobble at BOW
9/13/2019
9/13/2019
0.60
PRODi
DRILL
DRLG
P
9460', Drill, 1.8 BPM @ 3742 PSI FS,
9,460.0
9,495.0
19:06
19:42
BHP=3841
9/13/2019
9/13/2019
0.40
PRODi
DRILL
WPRT
P
Stall, PUW=40K. PUH through
9,495.0
9,200.0
19:42
20:06
window. tie into K1
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
9/13/2019
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
PRODi
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
9/14/2019
9/14/2019
0.40
PROD1
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
PROD!
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
PROD1
DRILL
PULD
P
At surface, Tag up and space out.
72.0
72.0
02:36
03:18
PUD BHA #4.
9/14/2019
9/14/2019
1.70
PROD1
DRILL
PULD
T
Pull BHA into lubricator assembley
72.0
72.0
0318
0500
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 lop. 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
9/14/2019
1.00
PRODi
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
PRODt
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 whifley on PDL, well is dead,
PJSM
9/14/2019
9/14/2019
0.50
PRODt
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
PRODt
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
PRODt
DRILL
DISP
T
Displace coil to 12.0 ppg KWF wtih
80.3
488.0
08:21
09:21
open EDC
9/14/2019
9/14/2019
1.50
PRODt
DRILL
TRIP
P
RIH, surface test agitator@ 488',
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
1 1
I
I
Page 3/22 Report Printed: 1012312019
Uperations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start oepm
Stan Tiros
End Time
Dur (hr)
Phase
Op Code
A ity Code
Time P-T-%
Operaton
(110)
End Depth(ftKB)
9/14/2019
9/14/2019
1.75
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
PROD1
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
9/1412019
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
PRODi
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
PRODt
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
PRODt
DRILL
WPRT
P
Pull BHA wipe, grab survey,
10,270.0
10,270.0
17:09
17:15
PUW=45K
9/14/2019
9/14/2019
1.85
PRODt
DRILL
DRLG
P
10„270', Drill, 1.8 BPM @ 4425 PSI
10,270.0
10,428.0
17:15
19:06
FS, BHP=3943
9/14/2019
9/14/2019
0.10
PROD1
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
PRODt
DRILL
DRLG
P
10,428', Drill, 1.8 BPM @ 4219 PSI
10,428.0
10,554.0
19:12
21:24
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
PROD1
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
PROD?
DRILL
DLOG
P
Log RA marker for+4' correction
9,445.0
9,480.0
22:30
22:36
9/14/2019
9/14/2019
0.50
PRODt
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
10,586.0
23:06
00:00
FS, BHP=3925
9/15/2019
9/15/2019
0.80
PRODt
DRILL
DRLG
P
1586', Drill 1.8 BPM @ 4361 PSI FS,
10,586.0
10,638.0
00:00
0048
1 BHP=3951
9/15/2019
9/15/2019
0.10
PRODt
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
PROM
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
9115/2019
9/1512019
2.30
PROD1
DRILL
DRLG
P
1081', Drill 1.80 @) 4360 PSI FS,
10,810.0
10,954.0
03:30
05:48
BHP=3955
9115/2019
9/1512019
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
9/1512019
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
PRODt
DRILL
DRLG
P
BOBD, 1.88 bpm at 4,882 psi,
10,954.0
11,095.0
06:24
07:24
Dlff=1,252 psi, WHP=218,
BHP=3,995, IA=22, OA=87
9/15/2019
9/15/2019
0.50
PRODi
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 4/22 Report Printed: 10/2312019
operations Summary (with Timelog Depths)
IC -06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Sten Depth
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operetion
MKe)
End Depth (MB)
9/15/2019
9/15/2019
1.90
PROD1
DRILL
DRLG
P
BOBO, 1.88 bpm at 4,885 psi,
11,095.0
11,264.0
07:54
09:48
Diff --1,250, WHP=234, BHP=3,995,
IA=22, OA=87
9/15/2019
9/15/2019
0.85
PROD1
DRILL
WPRT
P
Lost all returns, pull wiper to the
11,264.0
9,180.0
09:48
10:39
window, PUW 52 k
9115/2019
9/15/2019
0.20
PROD1
DRILL
DLOG
P
Log K1 marker (+3.0)
9,180.0
9,233.6
10:39
10:51
9/15/2019
9/15/2019
0.60
PROD1
DRILL
WPRT
P
Wiper back in hole, RIW 17 k, no
9,233.6
11,264.0
10:51
11:27
returns, close choke, continue RIH
630 psi WHP, 11.7ppg ECD
9115/2019
9/15/2019
0.85
PROD1
DRILL
DRLG
P
BOBD, 1.88 bpm at 4,435 psi,
11,264.0
11,350.0
11:27
12:18
Diff -1,250, WHP=234, BHP=3,995,
IA=22, OA=87
9/15/2019
9/15/2019
1.00
PROM
DRILL
DRLG
P
BOBO, snubbing -5 k CTSW,
11,350.0
11,376.0
12:18
13:18
DHWOB=0.4-1.3 k 1.63 bpm at 4,060
psi, Diff -970, WHP=251, BHP=4,050,
IA=8, OA=84
9115/2019
9/15/2019
3.25
PROD1
DRILL
DRLG
P
BOBO, 1.58 bpm at 4,430 psi,
11,376.0
11,664.0
13:18
16:33
Diff -970, WHP=251, BHP=4,050,
IA=8, OA=84
9115/2019
9/15/2019
0.50
PROD1
DRILL
WPRT
P
Wiper up hole, PUW 52 k
11,664.0
10,664.0
16:33
17:03
9115/2019
9/15/2019
0.30
PROD1
DRILL
WPRT
P
Wiper back in hole, RIW 6 k
10,664.0
11,664.0
17:03
17:21
9115/2019
9/15/2019
1.40
PROD1
DRILL
DRLG
P
BOBD, 1.81 BPM @ 4865 PSI FS,
11,664.0
11,808.0
17:21
18:45
BHP=4093, Choke shut
9115/2019
9/1512019
0.10
PROD1
DRILL
WPRT
P
BHA wiper, PUW=49K
11,808.0
11,808.0
18:45
18:51
9/15/2019
9/15/2019
3.15
PROD1
DRILL
DRLG
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
PROM
DRILL
WPRT
P
11962, Call TO @ X -Y coordinate.
11,962.0
9,420.0
22:00
00:00
Pump 10 X 10 Sweeps. Open choke
at 7 inch. Pumping 1.8 Returns @ 1.2
BPM
9/16/2019
9/16/2019
1.90
PROD1
DRILL
WPRT
P
On wiper trip to swab. Unloaded
9,420.0
70.0
00:00
01:54
cuttings @ - 500'. Jog back in hole to
1000'. Continue out of well.
9116/2019
9/16/2019
1.70
PRODt
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
9/16/2019
0.10
PRODt
DRILL
DLOG
P
Log K1 for -1' correction
9,200.0
9,280.0
03:36
03:42
9/16/2019
9/16/2019
0.40
PROD1
DRILL
TRIP
P
RIH to 9401. Get static pressure.
9,280.0
9,401.0
03:42
04:06
sensor depth TVD 6473.6, Start test a
3843 annular, Bled down to 3731 PSI
in 10 minutes. Down to 11.1 PPG MW
9/16/2019
9/16/2019
1.00
PRODt
DRILL
TRIP
P
Continue in hole to confirm TD
9,401.0
11,964.0
04:06
05:06
@11,964, RIW=14.3, PUW=45K, Trip
out pumping 8.5 Beaded liner pill
9/16/2019
9/16/2019
0.90
PRODt
DRILL
TRIP
P
POOH, pumping 8.5 ppg beaded liner
11,964.0
9,539.0
05:06
06:00
pill
9/16/2019
9/16/2019
2.00
PROD1
DRILL
TRIP
P
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
PROD1
DRILL
OWFF
P
At surface, check well for flow, PJSM
80.3
80.3
08:00
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
09:30
9/16/2019
9/16/2019
0.35
COMPZ1
CASING
PUTS
P
Prep RF for liner operations
0.0
0.0
09:30
09:51
9/16/2019
9/16/2019
3.20
COMPZI
CASING
PUTS
P
Start PU Lt slotted liner completion
0.0
2,101.3
09:51
13:03
w/53 joints and Liner lop billet
Page 5122 ReportPrinted: 10/2312019
Gperations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
seem Depm
Sten Time
End Time
Dur(hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(ftKB)
End Depth(ftKB)
9/16/2019
9/16/2019
0.90
COMPZ1
CASING
PULD
P
PJSM, PU CoilTrak tools.
2,101.3
2,145.5
13:03
13:57
9/16/2019
9/16/2019
1.75
COMPZI
CASING
RUNL
P
Tag up, reset counters, RIH 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
COMPZ1
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
17:12
1730
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
COMPZ1
CASING
RUNL
T
Standby for beaded liner running pill
11,568.0
11,568.0
17:30
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
Line up down CT, Pump 1.5 BPM.
11,568.0
70.0
21:12
22:54
Release oft 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
22:54
23:54
dead well. No Flow lest 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
COMPZ1
CASING
TRIP
T
Stop at 480', Shallow test agitator.
480.0
9,185.0
00:00
01:36
lContinue
in well
9/17/2019
9/17/2019
0.30
COMPZI
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
02:42
02:48
Iight.Been agotaling 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
COMPZ1
CASING
CIRC
T
Set down on fish. 19K. Continue to
9,467.0
9,467.0
02:48
03:18
agitate down. 1.7 BPM, Recovering
KWF from well DHWOB-3.5K,
Page 6122 Report Printed: 1012312019
Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Slaty Depth
Start Time
EM Time,
Dur (hr)
Phase
Op coat
Ac Wiry CMe
Time P-T-X
Operadw
(ftKa)
EM Depth (WB)
9/17/2019
9/17/2019
0.50
COMPZI
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
COMPZI
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
3650PSI. 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
9/17/2019
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
9/17/2019
1.25
COMPZI
CASING
CIRC
T
Continue agitating with 8-9k CTSW
9,467.0
9,467.0
07:15
08:30
stacked out 8 k, build 50 bbl 8.5 ppg
beaded lubed pill
9/17/2019
9/17/2019
1.75
COMPZI
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, stackoul again 2.5k agitate
some more.
9/17/2019
9/17/2019
1.40
COMPZI
CASING
TRIP
T
Unable to move liner assembly, POOH
9,467.0
45.3
11:33
12:57
9/17/2019
9/17/2019
1.20
COMPZI
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
PROM
STK
PULD
P
PU/MU/PD Drilling/Build L1-01 lateral
0.0
62.6
14:09
15:09
9/17/2019
9/17/2019
1.50
PROD2
STK
TRIP
P
Tag up, reset counters, RIH
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
16:54
17:12
stacked out 1.6 k
9/17/2019
9/17/2019
0.20
PROD2
STK
KOST
P
PUH, PUW 38 k, obtain
9,467.0
9,467.0
17:12
17:24
parametersl.80 bpm 4,132 psi,
DiW=428 psi, WHP=354, BHP=3,861,
IA=17, OA=81
9/17/2019
9/17/2019
2.10
PROD2
STK
KOST
P
Kickoff billet as per RP, time mill 1', 2',
9,467.0
9,470.0
17:24
19:30
and 3'
9/17/2019
9/17/2019
0.30
PROD2
STK
KOST
P
Push on it to 9,472', seem to be
9,470.0
9,472.0
19:30
19:48
stacking weight, PU to PUW 35 k,
continue kicking off with controled
WOB
9/17/2019
9/17/2019
1.10
PROD2
DRILL
DRLG
P
Drill ahead, 1.78 bpm at 4,234 psi,
9,472.0
9,557.0
19:48
20:54
Diff--709, WHP=354, BHP=3,863,
IA=17, OA=81
9/17/2019
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
9/17/2019
0.20
PROD2
DRILL
WPRT
P
Dry drift kickoff point (clean), continue
9,250.0
9,557.0
21:12
21:24
IH
9/17/2019
9/17/2019
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
PROM
DRILL
TRIP
P
Continue out of well
5,841.0
62.0
00:00
01:06
9/18/2019
9/18/2019
1.10
PROM
DRILL
PULD
P
At surface, Tag up and space out,
62.0
0.0
01:06
02:12
PJSM PUD BHA#8.
Page 7/22 Report Printed: 10/23/2019
Operations Summary (with Timelog Depths)
1c-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan oepth
Start Time
End Time
Dur(hr)
Phase
Op cow
Acevily Code
Tim P -T-%
Operetion
(ftKB)
End Depth (ftKB)
9/18/2019
9/18/2019
0.50
PROD2
DRILL
BOPE
P
Pick up BOPE test joint perform Bi-
0.0
0.0
02:12
02:42
weekly BOPE function test
9/18/2019
9/18/2019
0.80
PROD2
DRILL
PULD
P
PD BHA#9 from pre loaded PDL. .7'
0.0
78.3
02:42
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
RIH BHA #9, Shallow lest agitator@
78.3
9,205.0
03:30
05:24
1
1
500'
9/182019
9/18/2019
0.10
PROD2
DRILL
DLOG
P
Log Kt 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 dean. 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
05:54
08:42
BHP=3977
9/18/2019
9/18/2019
0.60
PROD2
DRILL
WPRT
P
10020', Wiper trip to window, perform
10,020.0
9,451.0
08:42
09:18
1
1
1 MAD pass 9725 to 9451
9/18/2019
9/18/2019
0.10
PROD2
DRILL
DLOG
P
9451 Log RA marker for+2' correction
9,451.0
9,476.0
09:18
09:24
9/18/2019
9/18/2019
0.20
PROD2
DRILL
WPRT
P
9476 RBIH to drill
9,476.0
10,020.0
09:24
09:36
9/18/2019
9/182019
2.20
PROD2
DRILL
DRLG
P
10020', Drill. 1.8 BPM @ 5595 PSI
10,020.0
10,420.0
09:36
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
11:48
12:30
9/18/2019
9/182019
2.10
PROD2
DRILL
DRLG
P
10420', Drill, 1.8 BPM @ 5773 PSI
10,420.0
10,559.0
12:30
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
14:36
14:42
9/18/2019
9/18/2019
1.40
PROD2
DRILL
DRLG
P
10559', Drill, 1.8 BPM @ 5844 PSI
10,559.0
10,759.0
14:42
16:06
FS, BHP=4032. LSRV up to 57K.
Consult mud eng. Get LSRV back to
plan
9/18/2019
9/18/2019
0.10
PROD2
DRILL
WPRT
P
10759', Pick up to get new pressures,
10,759.0
10,759.0
16:06
16:12
1 PUW=37K
9/18/2019
9118/2019
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
1
DHWOB=3.1 K
9/18/2019
9/16/2019
0.90
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 Kt 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
10,820.0
17:42
18:30
6.51K WOB at BOW, got through on
second attempt
9/18/2019
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, WHIP = 122 psi, 11.4 ppg @
widnow, pump = 5870 psi, rip = 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
Wiper up -hole, PUW=40K
11,218.0
10,270.0
22:36
23:00
9/182019
9/18/2019
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
9/192019
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, WHIP = 101 psi, pump =
6118 psi
Page 8122 ReportPrinted: 1 012 312 01 9
Uperations Summary (with Timelog Depths)
IC -06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Lag
Start Depth
StartTime
EM Tme
Duf(hp
Phase
Op Code
Activity Code
Time PJA
Operabon
rKB)
End Depth(flKB)
9/19/2019
9/19/2019
2.50
PROD2
DRILL
DRLG
P
Drilling, FS = 1300 psi @ 1.8 bpm,
11,268.0
11,544.0
00:00
02:30
CWT = 6.7K @ 1.91K 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
02:30
03:24
FS = 1284 psi @ 1.8 bpm, CWT = 4K
@ 1.71K 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
03:24
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
03:42
04:06
at -11,554'(1.1K)
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
04:06
06:54
CWT = 8.7K @ 1.21K 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
PROM
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
9/19/2019
0.20
PROD2
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
08:30
09:18
9/19/2019
9/19/2019
2.20
PROD2
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
PROD2
DRILL
WPRT
P
11880', Pull 100' BHAwiper,
11,880.0
1,188.0
11:30
11:42
PUW=43K
9/19/2019
9/19/2019
3.10
PROD2
DRILL
DRLG
P
11,880', Drill, 1.81 BPM @ 5580 PSI
1,188.0
12,034.0
11:42
14:48
FS, BHP=4003, RIW=-5K.
BDHWOB=3K
9/19/2019
9/19/2019
0.40
PROM
DRILL
WPRT
P
Pull 250'wiper, PUW=38K
12,034.0
12,034.0
14:48
15:12
9/19/2019
9/19/2019
2.00
PROD2
DRILL
DRLG
P
12,034', Drill, 1.80 BPM @ 5780 PSI
12,034.0
12,138.0
15:12
17:12
FS, BHP=4102, RIW=2K,
DHWOB=2.2K
9/19/2019
9/19/2019
0.30
PROD2
DRILL
DRLG
P
Drilling, 1.8 bpm, annular= 4160 psi,
12,138.0
12,150.0
17:12
17:30
WHP = 215 psi, pump = 6040 psi,
pumping beads to aid in weight
transfer (20 bbl in straight drilling fluid)
9/19/2019
9/19/2019
0.30
PROD2
DRILL
WPRT
P
Wiper up -hole, PUW = 39K
12,150.0
11,153.0
17:30
17:48
9/19/2019
9/19/2019
0.50
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW = 8.81K
11,153.0
12,150.0
17:48
18:18
9/19/2019
9/19/2019
2.80
PROD2
DRILL
DRLG
P
Drilling, FS = 1338 psi @ 1.8 bpm,
12,150.0
12,270.0
18:18
21:06
CWT = 8.3K @ 1.31K WOB, annular =
4089 psi, WHP = 181 psi, pump =
6164 psi, difficult drilling when back on
bottom, struggling w/ weight transfer,
snubbing to -51K & 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, WHIP =
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: 10123120191
Operations Summary (with Timelog Depths)
1 C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
sten Depth
sort Tim
EndTme
Dur (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operetlon
Me)
End Depth (ftKB)
9/20/2019
9/20/2019
3.00
PROD2
DRILL
DRLG
P
Drilling, annular =4129 psi, WHP =
12,379.0
12,471.0
00:00
03:00
146 psi, pump = 6160', drilling through
low ROP interval, WOB = 2.6K @ 17
fph, break out
Pump 50 bbl tubed pill (2% 77611 %
LoTorq), hits bit at 12,417'), limited
bennefit
9/2012019
9/20/2019
2.30
PROD2
DRILL
DRLG
P
Drilling, CWT= -6K, WOB =0.6K,
12,471.0
12,550.0
03:00
05:18
annular = 4137 psi, WHP = 128 psi,
pump = 6103 psi, continue pumping
beaded pills
9/2012019
9120/2019
1.60
PROD2
DRILL
WPRT
P
Wiper to window and jet 7 inch casing
12,550.0
9,205.0
05:18
06:54
X2, PUW=39K
9/20/2019
9/2012019
0.10
PROD2
DRILL
DLOG
P
Log tie in for+6'
9,205.0
9,224.0
06:54
07:00
9120/2019
9/20/2019
1.90
PROD2
DRILL
WPRT
P
Wiper trip back in hole
9,224.0
12,550.0
07:00
08:54
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
9120/2019
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 Bow rate to 1.7. Free spin
now 5685. Mud @ 40K LSRV
9/2012019
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 *9, bit
73.5
0.0
16:18
17:24
1
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, RS
Baker P104 bit), slide in cart, change
out pack -offs, MU to coil, tag up, set
counters
9/2012019
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
9/2012019
9/20/2019
0.20
PROD2
DRILL
DLOG
T
Log Kt for +4.5' correction, PUW =
9,200.0
9,234.0
20:12
2024
1
1
35K
9/2012019
9/20/2019
1.10
PROD2
DRILL
WPRT
T
Continue RIH
9,234.0
12,685.0
20:24
21:30
9/2012019
9120/2019
0.80
PROD2
DRILL
DRLG
P
Drilling, FS = 1043 psi @ 1.8 bpm,
12,685.0
12,732.0
21:30
22:18
CWT = 7K @ 1.81K WOB, annular =
4157 psi, WHP = 50 psi, pump = 5150
psi, -96% returns
Swap to PowerPro system (system
#4), new mud at bit, 12,686'
9/20/2019
9121/2019
1.70
PROD2
DRILL
DRLG
P
New mud all the way around, PU for
12,732.0
12,800.0
22:18
00:00
new parameters, FS = 1177 @ 1.8
bpm, CWT = 5.3K @ 1 K WOB,
annular = 4107 psi, WHP = 247 psi,
pump = 5128 psi, quickly begin
snubbing at -81K,
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
9121/2019
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: 1012312019
Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Slav Depth
Start Time
End Time
Dur (hr)
Phase
Op Cade
Activity Corte
Time P-T-X
Operedcn
tftKB)
End Dept (eKe)
9/21/2019
9/21/2019
2.00
PROD2
DRILL
DRLG
P
Drilling, FS = 1072 psi Q 1.8 bpm,
12,860.0
12,908.0
02:00
04:00
CWT=-6.9K@ 1.4K WOB, annular=
4131 psi, WHP = 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
9/21/2019
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, WHP = 262 psi,
pump = 5238 psi, returns -97%, pump
10 x 10 w/ beads
9/21/2019
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 Q 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 BBIs beaded pills.
ROP with beads above 40 FPH
9121/2019
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
9/21/2019
9/21/2019
3.30
PROD2
DRILL
TRIP
T
Trip out to inspect I swap out BHA,
13,165.0
78.0
16:12
19:30
PJSM
9/21/2019
9/21/2019
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
dosed), 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)
9/21/2019
9/22/2019
2.50
PROD2
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
9/22/2019
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)
9/2212019
9/22/2019
1.70
PROD2
DRILL
TRIP
T
78.0
9,200.0
00:24
02:06
1
IRIHw/BHA#ll
Shallow test agitator: MD = 5030', 1.8
bpm, pump = 5350 psi, dp = 1421 psi
9/22/2019
9/22/2019
0.10
PROD2
DRILL
DLOG
T
Log K1 for +3.5' correction, PUW =
9,200.0
9.232.0
02:06
02:12
33K
Page 11/22 ReportPrinted: 10/23/2019
r Operations Summary (with Timelog Depths)
r HC
110-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(flKe)
End Depth (Mlin
9/22/2019
9/22/2019
1.80
PROD2
DRILL
TRIP
T
Continue RIH w/ BHA#11, clean
9,232.0
13,165.0
0212
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
PROD2
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=.SK, ROP=40 FPH. Pump
many beaded pills 50 BBIs
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
spacerwhile batching up another one
9/22/2019
9/22/2019
0.10
PROD2
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
PROM
DRILL
DRLG
P
Drilling, CWT =-2K @ 0.2K WOE,
13,494.0
13,523.0
18:06
20:12
annular =4267 psi, WHP =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
9/22/2019
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 _SRV 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 Report Printed: 10/23/2019
Uperations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Time
End Time
our (hr)
Phase
Op Cade
Acb%* Code
Time P-T-X
Operabon
start Depth
(W13)
End Depth (WB)
9/23/2019
9/23/2019
2.00
PROD2
DRILL
DRLG
P
Drilling, snubbing to -8K, 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 (LoVis x Beaded HiVis),
avg ROP = —20 fph
9/23/2019
9/23/2019
2.50
PROD2
DRILL
DRLG
P
Drilling, annular =4211 psi, WHP=
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, WHP=
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, Get surveys, PUW=38K
13,698.0
13,698.0
06:12
06:18
9123/2019
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
9/23/2019
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
9/23/2019
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', Drill, 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
13,804.0
15:12
15:18
9/23/2019
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
9/23/2019
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. Get 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
LVF in pill pit, relaxed to 3549 psi
annular, attempt to pull free, no good,
pump 20 bbl LVF with pipe in tensioin
at 55K CWT, WHP is down to 9 psi
when pumping at 1.8 bpm (possible
partial pack-off), 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 ReportPrinted: 10/23/2019
. , Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
n De
Start Depth
start Time
End Time
Dr (hr)
Phase
O Code
Op
Activity Code
My
Time P -T -x
Opeation
End Depth (WB)
9/23/2019
9/23/2019
1.20
PROD2
DRILL
CIRC
T
Pipe free, 1.8 bpm in & 1 bpm out, pull
13,817.0
13,500.0
19:30
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
Perform swab wiper, lay in 40 bbl
13,500.0
78.0
20:42
00:00
beaded pill, jog 7" casing
9/24/2019
9/24/2019
1.80
PROD2
DRILL
TRIP
P
RBIH to confirm TD
78.0
9,200.0
00:00
01:48
9124/2019
9/24/2019
0.20
PROD2
DRILL
DLOG
P
Log K1 for+3' correction, RIH to
9,200.0
9,231.0
01:48
02:00
window
9/2412019
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,
9,415.0
13,822.0
02:30
04:18
clean through window & past billet,
clean to bottom, confirm TD at 13822',
PUW = 35K
9/24/2019
9/2412019
4.10
PROD2
DRILL
TRIP
P
Lay in LRP & KWF to surface, paint
13,822.0
78.0
04:18
08:24
flags, 12760 & 8280
9/24/2019
9/24/2019
0.50
PROD2
DRILL
PULD
P
At surface, Flow check well - Good.
78.0
78.0
08:24
08:54
PJSM lay down BHA on dead well.
9/24/2019
9/24/2019
0.70
PROD2
DRILL
PULD
P
Unstab injector, Inspect CT for wall
78.0
0.0
08:54
09:36
thickness. Lay down BHA#11.
ronhorse motor bearing end seems to
have excessive gap.
9/2412019
9/2412019
0.80
COMPZ2
CASING
RURD
P
Prep floor to run liner
0.0
0.0
09:36
10:24
9/24/2019
9/24/2019
2.00
COMPZ2
CASING
PUTB
P
M/U BHA#12, Lt -01 lower liner
0.0
1,093.3
10:24
12:24
segment with non ported bullnose, 36
jts slotted 2 3/8" liner, and shorty
deployment sleeve
9124/2019
9/24/2019
0.70
COMPZ2
CASING
PULD
P
M1U coil track to liner. M/U to injector
1,093.3
1,137.6
12:24
13:06
and surface test. Tag up and set
counters
9/24/2019
9/2412019
2.30
COMPZ2
CASING
TRIP
P
RIH BHA#12, EDC closed pumping .2
1,137.6
9,337.0
13:06
15:24
1
1
1
BPM
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
9124/2019
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', Log 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
9124/2019
2.80
COMPZ2
CASING
TRIP
P
Tip out of hole. Paint flag @ 7944.2
12,429.0
57.0
17:06
19:54
912412019
9/24/2019
0.50
COMPZ2
CASING
PULD
P
Tag up, Perform 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
RURD
P
Rig up floor for liner ops
0.0
0.0
20:24
21:00
Page 14/22 Report Printed: 1 012 312 01 9
Uperations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
our (hr)
phase
Op Code
Activity Cade
Tlme P -T -X
Opereeon
(IB(B)
End Depth (WB)
9/24/2019
9/25/2019
3.00
COMPZ2
CASING
PUTB
P
Pickup Ll -0l upper liner segment
0.0
1,375.0
21:00
00:00
with non -ported bullnose, 45 As
slotted 2 3/8" liner, 6' pup joint, and
aluminum liner top billet, begin PU
BHA #13 Liner Tools
9/25/2019
9/2512019
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
912512019
9125/2019
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, Pl1W = 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-
9125/2019
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
1
1
1 change, carry on LD tools
9/25/2019
9/25/2019
1.20
PROD3
WHDBOP
CTOP
P
MU nozzle, jet stack, break off nozzle,
0.0
0.0
06:12
07:24
dear dg floor, displace coil to fresh
water
9/25/2019
9/2512019
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
PRODS
WHDBOP
CTOP
P
Fluid pack lines, line up valves for test,
0.0
0.0
09:00
0918
1
1
1 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 AOGC% PU test jnl,
continue w/ test, filling the hole w/ MP
line
`250 low / 3500 high
9/25/2019
9/25/2019
0.30
PROD3
WHDBOP
BOPE
P
Perform draw down test
0.0
0.0
14:30
14:48
9/25/2019
9/25/2019
0.50
PROD3
WHDBOP
PRTS
P
LD test jnt, clear rig floor
0.0
0.0
14:48
15:18
9/25/2019
9/2512019
1.20
PROD3
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
PROD3
STK
PULD
P
PU BHA#14 KO Build/Tum Assembly
0.0
78.0
16:30
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
PROD3
STK
TRIP
P
RIH
78.0
9,204.0
17:42
19:24
9/25/2019
9125/2019
0.20
PROD3
STK
DLOG
P
Tie into the K1 for+3' correction
9,204.0
9,220.0
19:24
19:36
9/25/2019
9125/2019
0.10
PRODS
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
Tum well over to drilling fluid ramping
9,411.0
9,401.0
19:42
20:54
up rale targeting 11.4 ppg, 20:47, mud
weight out dropping to drilling fluid
density, PU Wt 33 klbs, 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 15/22 Report Printed: 1012312019
Operations Summary (with Timelog Depths)
IC -06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
Dur(hn
Phase
Op Code
Activity Cecile
Time P -T -x
Operabon
(fiKB)
End Depth (111<13)
9/25/2019
9/25/2019
0.10
PRODS
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, 0A 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.
9/25/2019
9/25/2019
0.90
PR0D3
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 ft/hr for 1' - seeing some aluminum
back at he shaker from initial milling
bottoms up.
9/25/2019
9/26/2019
1.50
PR0D3
STK
KOST
P
2ft/hr for V- WOB 0.65 k lbs, Ct Wt 8
11,337.2
11,338.0
22:30
0000
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
PR0D3
STK
KOST
P
Continue to time drill ahead@ 2 ft/hr
11,338.0
11,338.2
00:00
00:06
9/26/2019
9/26/2019
0.20
PROD3
STK
KOST
P
Increase rate to 3 ft/hr
11,338.2
11,339.2
00:06
00:18
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
Itis, 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 146 k lbs.
9/26/2019
9/26/2019
2.70
PR0D3
DRILL
TRIP
P
POOH, PJSM
11,630.0
72.0
05:00
0742
9/26/2019
9/26/2019
1.30
PR0D3
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 nozzle (aluminum in
nozzle)
9/26/2019
9/26/2019
1.00
PR0D3
DRILL
PULD
P
PD BHA#15 (NOV agitator, 0.6° AKO
0.0
78.0
09:00
1000
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
PR0D3
DRILL
TRIP
P
RIH w/ BHA#15, shallow test, dip =
78.0
9,200.0
10:00
11:42
940 psi @ 1.8 bpm
9/26/2019
9/26/2019
0.10
PR0D3
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
PR0D3
DRILL
TRIP
P
Continue RIH, weight bobble @
9,232.0
11,630.0
11:48
12:42
1
11,383' (2K)
9/26/2019
9/26/2019
2.20
PR0D3
DRILL
DRLG
P
Drilling, FS = 1060 psi, @ 1.9 bpm,
11,630.0
11,795.0
12:42
14:54
CWT = 12K @ 1.8 WOB, annular =
4085 psi, WHP = 25 psi, pump = 5108
psi, avg ROP = 75 fph
Page 16122 Report Printed: 10/23/2019
Uperations Summary (with Timelog Depths)
,.
1 C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Stan Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(%KB)
End Depth (ftKB)
9/26/2019
9/26/20191.70
FIR 3
DRILL
DRLG
P
Drilling, annular =4105 psi, WHP=42
11,795.0
11,898.0
14:54
16:36
psi, pump = 5030 psi, -97% returns,
avg ROP = -61 fph
9/26/2019
9/26/2019
2.50
PROD3
DRILL
DRLG
P
Drilling, annular = 4106, WHP=34
11,898.0
12,030.0
16:36
19:06
psi, 11.4 ppg at window, lower ROP in
hard spots (possibly Siderite as seen
on the L1 & 11-01)
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- R/hr
9/26/2019
9/26/2019
0.30
PROD3
DRILL
WPRT
P
PU wt 40 k Is, Pull up hale on wiper
12,030.0
11,360.0
19:06
19:24
#1
Saw -1.3 k WOB tug @ 11,380 onn
way up hole.
9/26/2019
9/26/2019
0.20
PRODS
DRILL
WPRT
P
RBIH
11,360.0
12,030.0
19:24
19:36
0.22 bbls of cutting returned on the trip
9/26/2019
9/27/2019
4.40
PROD3
DRILL
DRLG
P
Ct 4740 psi @ 1.90 by in and 1.90
12,030.0
12,348.0
19:36
00:00
bpm out, Free spin diff 1111 psi, BHP
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
ft/hr
12,171' PU Wt 44 k lbs
12,239' PU Wt 45 k lbs
12,301' PU Wt 44 k lbs
12,326' PU Wt 41 k lbs
9/27/2019
9/27/2019
1.70
PROD3
DRILL
DRLG
P
Continue to drill ahead
12,348.0
12,480.0
00:00
01:42
12,404' PU Wt 39 k lbs
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
fUhr
9/27/2019
9/27/2019
1.70
PRODS
DRILL
DRLG
P
ROP slowed significantly
12,480.0
12,513.0
01:42
03:24
CT Wt -5 k lbs, WOB 12 k lbs, ROP -
20 ft/hr
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
9/27/2019
9/27/2019
0.50
PRODS
DRILL
WPRT
P
Jet 7" and chase bottoms up.
9,420.0
9,200.0
04:36
05:06
9/27/2019
9/27/2019
0.20
PROD3
DRILL
DLOG
P
Tie into the K1 for 5' correction.
9,200.0
9,230.0
05:06
05:18
9/27/2019
9/27/2019
0.20
PROD3
DRILL
WPRT
P
Measure BHP, stabilizes at 11.2 ppg
9,230.0
9,410.0
05:18
05:30
EMW
9/27/2019
9/27/2019
1.10
PROD3
DRILL
WPRT
P
RBIH to drill & reaquire sand, begin
9,410.0
12,513.0
05:30
06:36
seeing weight & motor -work beginning
at 12,479' (1.3K WOB), a bit ratty to
bottom
9/27/2019
9/27/2019
1.80
PROD3
DRILL
DRLG
P
Drilling, FS = 1106 psi @ 1.9 bpm,
12,513.0
12,549.0
06:36
0824
CWT = 1.61K @ 2.2K WOB, annular=
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: 10/23/2019
Uperations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
Dur (m)
Phase
Op Code
Acvity Code
Time P -T -X
Operation
(ftQ)
EM Depth (MB)
9/27/2019
9/27/2019
2.60
PRODS
DRILL
DRLG
P
Drilling break at - 12,549', CWT =-2K
12,549.0
12,653.0
08:24
11:00
@ 0.6K WOB, annular = 4133 psi,
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
PRODS
DRILL
DRLG
P
Drilling, CWT 2K @ 1.5K WOB,
12,653.0
12,693.0
11:00
12:30
annular = 4179 psi, WHIP = 290 psi,
pump = 5445 psi, PUW = 43K from
12,693', -90% returns, reduce rate &
speed to get back to bottom, avg ROP
= 27 fph
9/27/2019
9/27/2019
2.10
PRODS
DRILL
DRLG
P
Drilling, CWT = 4K @ 0.51K WOB,
12,693.0
12,753.0
12:30
14:36
pump 5 x 15 beaded (lo/hi) to
moderate effect, PUW = 46K @
12,720', mud foaming up (pump
efficiency fluctuating), add defoamer
to mud, rate out dawn to 1.3 bpm,
climbs back to 1.76 bpm out, avg ROP
= 29 fph
Pump 50 bbl beaded pill
9/27/2019
9/27/2019
1.30
PRODS
DRILL
DRLG
P
Beads exiting bit at 12,753', PUW =
12,753.0
12,813.0
14:36
15:54
46K, much improved weight transfer,
increase in ROP, up to 90 fph, avg
ROP = 46 fph
69K PUW from 12,786
9/27/2019
9/27/2019
0.20
PRODS
DRILL
WPRT
P
Wiper up -hole, PUW = 39K, 60 fpm,
12,813.0
12,000.0
15:54
16:06
clean through high gamma interval
9/27/2019
9/27/2019
0.40
PRODS
DRILL
WPRT
P
Wiper in-hole, preemtively reduce rate
12,000.0
12,813.0
16:06
16:30
to 1.25 bpm running through high
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 = 0.51K
9/27/2019
9/27/2019
1.80
PRODS
DRILL
DRLG
P
Drilling, FS = 1173 psi @ 1.9 bpm,
12,813.0
12,863.0
16:30
18:18
beads exiting bit, CWT = 4.3K, @1.1K
WOB, annular = 4177 psi, WHIP = 129
psi, pump = 5536 psi
9/27/2019
9/27/2019
5.40
PRODS
DRILL
DRLG
P
Crew change, PU to grab parameters
12,863.0
13,035.0
18:18
23:42
CT 5166 psi @ 1.80 bpm in and 1.64
bpm out, Free spinn 1077 psi, BHP
4208 psi,
CT Wt to-6klbs, WOB 1.2 k -0.3k
lbs. Struggling with weight transfer,
100' BHAwipers 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 beniftt but still
picking up more than drilling.
Average ROP over section 31 ft/hr
9/27/2019
9/28/2019
0.30
PRODS
DRILL
WPRT
P
PU Wt 37 k lbs, pull wiper to rasing
13,035.0
12,048.0
23:42
00:00
9/28/2019
9/28/2019
1.20
PRODS
DRILL
WPRT
P
Continue to PUH, dragging low side,
12,048.0
9,404.0
00:00
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 18/22 Report Printed: 10123120191
Uperations Summary (with Timelog Depths)
1c-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
stmt Time
End Time
Dur Irv)
Phase
Op Code
Activity Code
Time P -T -X
Operalion
Start Depth
(eKB)
End Depth (111<13)
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
9128/2019
0.20
PRODS
DRILL
DLOG
P
Tieinlothe Kl marker for+12'
9,199.0
9,242.7
01:36
01:48
correction.
9128/2019
9/28/2019
1.50
FROM
DRILL
WPRT
P
RBIH
9,242.7
13,035.0
01:48
03:18
WOB spikes to - 1.5 k Itis @ 10,264'
and 11,136'
WOB spike to 2.9 k lbs 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
912812019
9/2812019
2.90
FROM
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, fA 46, OA 107 psi.
OBD, CT Wt 5.2 k lbs, WOB 2.8 k lbs,
13,056- PU Wt 44 k lbs, Free spin diff
1065 psi w new mud all the way
around.
928/2019
9/28/2019
3.70
PROD3
DRILL
DRLG
P
Drilling, CWT =3.2@0.2 WOB,
13,103.0
13,181.0
06:12
09:54
annular =4206 psi, WHIP =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
928/2019
9/28/2019
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% losses), 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
FROM
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
9/28/2019
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'
912812019
928/2019
1.90
FROM
DRILL
CIRC
P
RBIH to window, circulating awaiting
5,000.0
9,400.0
12:48
14:42
fluid to dg, trucks arrive at dg, begin
unloading
`" Log Kt 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
At 12,763', 1.86 bpm in, 0.97 bpm out,
confer w/ town, decison made to
POOH & circulate pending rig move
9/2812019
9/28/2019
1.10
FROM
DRILL
TRIP
T
POOH to window to circulate pending
12,762.0
9,328.0
16:06
17:12 1
1
1
1
rig move
9/28/2019
928/2019
4.30
PRODS
DRILL
WAIT
T
Circulate waiting on trucks
12,762.0
9,328.0
17:12
21:30
Page 19122 Report Printed: 10/2312019
Operations Summary (with Timelog Depths)
1C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Stars Time
End Time
Dur(hr)
Phase
Op Code
Activity Code
Time P -T -X
Operaton
(OKB)
End Depro(lu(B)
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 Q 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
bbl lube pill down the back side.
9/28/2019
9129/2019
1.50
PRODS
DRILL
TRIP
T
RIH, window clean, slacked WOB on
9,300.0
12,914.0
22:30
00:00
lower billet, again - 11,336'
stacked out coil, no WOB 12,579'
9129/2019
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
lbs, any pumping sticks the coil
diferentially.
9/29/2019
9129/2019
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 lbs
9129/2019
9/29/2019
1.00
PRODS
DRILL
DRLG
T
Attempt to pick up, stuck.
13,261.0
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
9129/2019
0.80
PROD3
DRILL
CIRC
T
Pump 7 bbls LVT, with 4 bbl out,
13,261.0
13,261.0
05:36
06:24
9/2912019
9129/2019
1.00
PROD3
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 = 6528.2', WHP
= 815 psi)
Work pipe, no good, pump .45 bpm
LVT 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 WHIP no
flow through WT valve
9/29/2019
9/29/2019
1.30
PROD3
DRILL
CTOP
T
Load LVF 16 bbl into pill pit, build 60
13,261.0
13,261.0
07:24
08:42
bbl 1%/1% 776/LoTorq & 1.5 ppb
beaded pill
9/29/2019
9/29/2019
1.10
PRODS
DRILL
CTOP
T
Bullhead 16 bbl LVT followed by
13,261.0
13,261.0
08:42
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
9129/2019
1.40
PROD3
DRILL
TRIP
P
Pipe free, pull to window
13,261.0
9,390.0
09:48
11:12
9129/2019
9/29/2019
0.10
PRODS
DRILL
CIRC
P
Pump Q 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
PROD3
DRILL
WPRT
P
RBIH to 13,150', RIW = 8K -10K at
9,180.0
13,150.0
11:36
12:54
13,160'
Page 20122 ReportPrinted: 10/23/2019
Operations Summary (with Timelog Depths)
1 C-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Tinre
Our hr
( )
Phew
Op Cotle
ANv'ey Code
Time P-T X
Operation
Start Depth
(rt Ka)
End Dept (ftKB)
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 Kt for+6.5' correction, clean
counter wheel
9/29/2019
9/29/2019
1.20
PRODS
DRILL
DISP
P
Bull-head 50 bbl LRP to 13,160' (11.4
7,890.0
7,890.0
14:54
16:06
ppg), 1.25 bpmm, WHP = 1207 psi
9/29/2019
9/29/2019
2.30
PRODS
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 radiay 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 rig vac and water hose.
9/292019
9129/2019
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
PUTB
P
Ll-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
PUTS
P
Continued to PU lower Lt-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
PUTS
P
Clear / dean 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 L1-02 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.
9/30/2019
9/30/2019
5.50
COMPZ3
CASING
RUNL
P
RIH with lower L1-02 completion, drive
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, tlp =
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
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
spots, pump managed pressure, KWF
arrives at rig
Page 21122 Report Printed: 1012312019
Uperations Summary (with Timelog Depths)
1c-06
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Steil Time
EndTime
our rv)
Phase
Op Code
Actihty code
Time P -T-%
Operation
m<13)
End Depth (NCB)
9/30/2019
9/30/2019
0.90
COMM
CASING
PUTS
P
PJSM, clear floor, off-load KWF, prep
0.0
0.0
12:36
13:30
to run liner
9/30/2019
9/30/2019
2.90
COMPZ3
CASING
PUTS
P
PU Upper Completion (ported BN, 67
0.0
2,039.0
13:30
16:24
jnts slotted liner, & shorty deployment
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
9/3012019
9130/2019
2.60
COMPZ3
CASING
RUNL
P
RIH Wupper Lt -02 completion -67
2,085.0
11,320.0
17:00
19:36
joints of 4.6#, L-80, ST -L Slotted R2
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 35 k lbs, WOB 0 k - liner released
- TOL 9274'
9/30/2019
9/30/2019
1.90
COMPZ3
CASING
DISP
P
PUH after releasing liner, reset
11,320.0
43.0
19:36
21:30
counters, line up down the coil with
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
COMPZ3
CASING
DISP
P
LRS lined up to the coil, Load with 30
43.0
43.0
21:30
22:00
bbls diesel, S/D, RD LRS, Pump
additional 5 bbls seawater to the coil.
9130/2019
9130/2019
1.00
COMPZ3
CASING
PULD
P
PUD BHA # 17, liner running
43.0
0.0
22:00
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
23:00
23:42
diesel to the well - FP.
Prior to pumping w column of
seawater - 8.55 ppg, WH was 707 psi.
Unload coil trek 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
00:00
1011/2019
10/1/2019
0.30
DEMOB
WHDBOP
CIRC
P
Continue to Jet stack
0.0
0.0
00:00
00:18
10/1/2019
10/1/2019
0.20
DEMOB
WHDBOP
CIRC
P
Flush, blow down, bleed off, unstab
0.0
0.0
00:18
00:30
injector
10/112019
1011/2019
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 -0 -
scope stack.
10/1/20111
10/1/2019
2.50
DEMOB
WHDBOP
NUND
P
Work RD checklist, ND BOP'S
0.0
0.0
03:30
06:00
" Rig released at 0600 hrs on 1011/19
Page 22/22 ReportPrinted: 1 0123/2 01 9
ConocoPhillips
ConocoPhillips Alaska Inc_Kuparuk
Kuparuk River Unit
Kuparuk 1C Pad
1C -06L1
50-029-20564-60
Baker Hughes INTEQ
Definitive Survey Report
17 October. 2019
Baker Hughes S
",
CowcoPhllfips
ConocoPhillips
Definitive Survey Report
Sysam Datum:
Compan, ConowPhdilps Alaska Inc_Kupemk
Local Coordinate Rareni
Milic4
Project: Kupamk River Unit
TVD Refinence:
lC-06®94.0ousft(1P06)
am: Kupank IC Pad
MO Reference:
1C-06@94.00usft(1C4g6)
Well: 1,0-06
North Reference:
Time
WeIIOOR: lC-06L1
Survey Calculation Method
Minimum Curvature
Dal 1C -05L1
Database:
EDT 14 Alaska Production
Project Kupamk River Unit, Nmlh Slope Alaska, United Slates
Map System:
US State Plane 1927 (Exact soluli0n)
Sysam Datum:
Mean Sea Level
Geo Di
NAD 1927 (NADCON CONUS)
Using Well Reference Point
Map Zane:
Alaska Zone 04
eNh1
Using geodetic soaks factor
Well
1C-06
Well Position
'Ni 0.00 tuft
Northing:
596860.Wusft
♦FY4N 0.00 usfl
Ending:
561 BW.00usft
Position Uncettaety
000 usfl
Wellhead EMvatlon:
usfl
Wesson,
lC-06L1
Dare
Magnetics
Model Name
Sample Data
Dearallon
To
(°)
Survey
BGGM2018
10/1/2019
16.44
Design 1,0-061.1
Audit Notes
Larhude: 70° 19' 31.647 N
Longitude: 149-29-54+042W
Sound Level: 0.00 usfl
Olp Angle Faa Shagged
Ini)
00.86 57,404
Version:
1.0
Phase: ACTUAL
Ta On Depll 9,400.00
Vertical Section:
Depth From[ ll
eNh1
a AN
Direction
low"
Iasi
lis l
11
33.50
0.00
D.00
100.00
Survey Program
Dare
From
To
Survey
Survey
(dirt)
(gat")
sumylw.rlenl
Test Name
Deasilp[bn
&art Dela
End Date
10040
9,40080
1,0416(1,0-06)
GYO-CT-0MS
Dismiss contakeing We
8125/2000
9430.00
9,490.53
1 C41611 MM -INC D C41611)
M1 INQONLY
MWD-INCONLY_FILLER
9113/2019
9/142019
9.52137
11,924.11
1C416L1 all (I CA L1)
MWD OWSG
Di all - Standard
91142019
911512019
10,122019 1:54:31teM
Pape 2
COMPASS 500014 Build 854
Survey
ConocoPhillips
corlocO illlps
Definitive Survey Report
Baker Hughes
Map
Map
Company ConwnPhilips Meatus lnc Kupamk
Local C.-oninate Reference:
Wall 1006
Project: Kupamk River Unit
TVD Reference:
10-06(094.00ush(IC46)
site: Kupamk lC Pad
MD Reference:
1C46®94.00u.tt(1C-06)
Well: 1C-06
North Reference:
T..
Wellborn: 1C -06L1
Survey Calculation MetbodE
Minimum Curvature
Oe5,9n: iC46L1
Database:
EDT 14 Alaska Pmnuclon
Survey
IMM019 f:64'36PM P.,3 COMPASS SOW, 14809E 65H
Map
Map
Vertical
MO
Inc
NI
TVD
1V055
-NIS
V.wOLs
No
Eazting
Section Survey Tool Name
AnnotationAnnotation(urtt)
I'I
('I
(us(U.")
(uslt)
(YSh)
(urtt)
IN) Ih(
(tt)
(°HBo')
(tt)
9400,00
46.50
56.05
6 5054
641354
5,320.83
3.13107
59]430595
554951]0
338
2,159.94 MWD -INC GNLY(2)
TIP
9,43000
4664
5)64
6,528.17
5434.17
5,3E61
3,14979
5.9]421].69
564.96942
197
2,175.94 MMWNC_GNLV(2)
KOP
B.4fi063
x4.24
5]64
6,54]65
6,453.65
5345.24
3.16..73
5,974=sli
WAN 24
24.62
2.193.37 MJu11JNCONLY(2)
Interodated Acimutb
949053
6687
9.84
656166
6.46].%
5,359.10
3.19187
5,974.244.90
566.112]
4881
2,21275 NTN4WC ONLY(2)
Inta,.I.tod Rzimuib
9521.37
83.11
57.26
6,569.31
6,475.31
5.37534
3,217.02
5.974 261.16
565.36.29
46.19
2,234.73 MND MiiG(3)
9.551.49
94.86
52.46
6,559.84
6,47584
5,39264
3.241.60
5,9]42]6.66
ranation
4213
2,255.93 NAND MSG (3)
9.58144
94.95
3.16
6,56]2]
64]3.2]
5,413.39
3.MSS
5,9!439..59
%5,001.Po
44,25
2,273.35 MNDOWSG(3)
9,611.37
9415
2466
6,564.88
6,470.88
5,435,65
3,2]66]
5,9]4,324.8]
563.497.41
4837
2,284.46 MND MSG (3)
9,"1.67
9326
11.3
6,%292
6.4(6.92
5,467.36
3,28793
5,974353.76
S r1WA3
4478
2,288.50 MND MSG (3)
9,67149
92.76
356,3
6561.34
646)34
5,49699
3.289.97
5974,30340
565,10823
4788
2,285.45 MND MSG (3)
9,70151
943
340.18
6,55946
646446
55ID35
3.2"A2
6,974,412.60
SSS,t02."
5552
2,274.51 MVID MSG (3)
9.73125
04.97
325.84
6557.06
6463.05
5,552.60
3rM"
5.974438.85
5%,088.43
4775
2,256.]4 MND MSG (3)
9763.%
9341
=41
6,554.70
6460.]0
5,570.70
3251.8
5,974,4"]8
5%,068.6]
17A2
2WCWS MWD MSG (3)
9384.15
91.20
317.41
6.553.49
64%49
5,601"
323135
5,974,49.%
565046.%
1233
220.48 MWD MSG (3)
9.823.86
9160
31559
6552]8
6 46]6
small
3,21001
5,974.50]2
597,020."
637
21%81 MWD MSG (3)
9664.23
90.66
313211
6552,16
6450.16
564432
3.189.12
5,.745'6.]8
565,006.17
843
2160.55 MWD MSG (3)
9,685.9
92.18
31308
6,551.38
6457.38
5,665.65
3,1"26
5,9]4551 .01
56,1883.14
4.80
2134.32 MWD MSG (3)
'.
9.91402
939
31223
6,550.07
6456"
568490
3.14535
5,974570.[®
5",%206
4.232
2,110A0 MWD MSG (3)
9%4.95
5926
30"54
6,549.24
6.45524
671028
3,11331
5,94.595,21
564,92983
20%
294A3 MWD MSG (3)
9.987.31
NAS
302%
6549.60
645560
5,]38.24
3,08639
5,94.61294
5",90276
524
2044.80 MWD MSG (3)
10,.1591
%.34
39754
6,"B."
645564
5,743.27
3,06206
5,974,W7]]
504.8]8.31
6.65
2018.23 MWD MSG (3)
10,047.65
91.50
208.18
6.5,18,13
6,455.13
5,758.93
3,03433
5,94,64319
S",8•A35
8.20
1,98610 MWD MSG (3)
t00PN
93,20
6742
6.547.87
6453.87
6 M
3,007.59
5,94.657.2
564W3.61
645
1,959A3 MWD MSG (3)
10,107.79
94.30
29739
6545%
6,451,69
6]%."
2,901.10
5,94.Ma
5".79709
342
1,93105 MWD MSG (3)
10,138.31
92.58
29557
6.544.%
6,45006
580020
2,95390
5,94,68179
5"769.70
7,W
1,90183 MWD MSG (3)
10 ,92.98
93.13
293.29
6,542.34
6,440.34
5,814.52
2,922.36
5,94,69] 65
564,730.9
6.76
1,85630 MWD MSG (3)
10,197.71
92.97
281.81
6,541.0
644723
5,694.01
209957
5,974707,16
5",]15.18
731
1.644.18 MWD MSG (3)
10230."
%.14
290.51
65316
6,445.76
5,63583
2,86910
59]4,]10.73
5".6",69
551
161213 NW() MSG (3)
10359.%
82.9
2899
6.538,3
6444,30
584513
2841.96
5974.9.640
5"65741
363
178368 MWD MSG 13)
103N,fi
%,02
MM
6.536,85
6,44286
565282
2,821.62
5974,735.42
SM 63720
10.99
(]6260 NM MSG (3)
IMM019 f:64'36PM P.,3 COMPASS SOW, 14809E 65H
Survey
ND
ConocoPhillips
M
TVD
TVD55
aNi
ConocoPhillIp5
Definitive Survey Report
Map
Company: ConosoPhiips Alaska Inc Kupamk
Local C.ndlnate Rafae e:
We111C416
Project: Kuperuk River Unit
TVD Reference:
1C-06@94.NusX(1 C-06)
Site: Kuparvk 1C Pas
ND Reference:
1C46@94.00usX(1 C-08)
Well: 1C46
Norm Reference:
Tone
Welibere: 10-0811
Survey Calculation Method:
Minimum Curvature
Design: tC-06L1
peak,...:
EDT 14 Alaska Production
Survey
ND
1.
M
TVD
TVD55
aNi
.0m.0mNap
Map
OLS
Vertical
NY
Ea
Section Survey Tool Name
(Yell)
11(`)
(usM1)
(usM1)
(usM1)
(Ysin
(III
1.R)
(tlnB
(X)
("11.00')
(M1)
10,31044
9634
28995
6,533 B2
fi43962
586292
27940T
5,974.745.19
564609.38
5.86
173354 MWO GWSG(3)
103310]
96.59
25&85
6,531.43
6,437.43
5,81
2.77415
5.974.75184
564,59000
535
1.71332 MWD GWSG(3)
10.35651
9&42
280.51
6528.11
6.434.11
5.877.81
27W.85
5,970750.8
Sea Sk "
731
1,688.8 MJN OWSG(3)
10.39035
WD.S7
290.18
( 1.52
6,426.52
5.888.86
271936
5,974,770.51
564,534.47
8.00
1,655.46 rias) SG (3)
10,41597
8916
293,85
6.516.13
6.424.13
5.597.71
25073
5,64,779.16
56,510.76
6.08
1,63(1.[5 MJN OWBG(3)
10,46012
9261
291,45
6.513.61
fi419,61
5,91354
2,65419
5,9]4,794.68
564,469]0
14.98
1.637.55 MJN OWSG(3)
10,409.59
81
291.47
6,51323
6,419.23
5,924.32
262737
5,974,805.21
56.442.18
1202
1.55511 MND MEW (3)
10.59.43
87.97
291.34
6.513.78
6,419]0
5.931.56
2600.91
5,974,81230
554023.60
453
1,639.27 MaD OWSG(3)
1058.32
81
209.59
6,514.80
8,4.41.87
5.942.00
2500.92
697,SM 51
SM 395W
SM
1,555.69 AND OWBG(3)
10,589.41
81
280.82
11.515.6
6.421.90
5.952.14
255261
5,804,113241
564.87.21
059
1,480.25 MND OW6G(3)
10,580,87
Wi.&
291
6,5166
6422.94
5,859.53
253238
5,974 839.63
4141.]46.92
5.68
1,459.05 mcovasG(3(
10,623.49
84.40
2918
6,519.43
6425.43
5,97104
2502.07
5,9741150.89
56.81152
8.12
1,42720 MNOMSG (3)
10,65762
81.80
291.28
6,523.53
6429.53
5,941.34
2470.50
5,904863.93
554.284%
062
1393.90 MNDOWSG(3)
10,677.41
82.93
291
6.526.16
6,48.16
59tli
245230
5904,%9.83
564.2%.6
6.09
1,374.03 MWDOWSG(3)
10717]5
85.79
289.62
6,SM. 12
6,0612
66424
2414.53
5,904553.37
SW,22&T2
To
133532 MNOMSGO)
10,04353
Sa.
2813.21
653255
6MSSS
Ili
2,390.24
5,97,89140
554,204.30
10.83
1,309.85 lai OWSG(3)
10771.55
So 4
281
.San'.
6441.02
.'G2OSB
236336
5,974,899.69
564177.32
5.83
138183 MWD OW3G(3)
10,802.73
0107
254.03
6,539.95
6,44596
60801
2.333.6
5.974.907.47
5".147.80
11.20
1,251.50 MWD 01 (3)
10,832.24
01.58
2828
6544.41
6,45041
6035.%
2,8545
5,974.91390
56k,119.43
5,76
1,21237 MWD Cannot (3)
10,07921
82.55
281.35
6.56.90
5456.90
8,6528
2.259.94
5.974,92310
564,07381
300
1,105.86 MWD 01 (3)
1089710
83.44
28124
6.55308
645908
604003
2,24255
5,9749.4.43
56.056.39
5.02
1,150.13 MNA 01 (3)
10.3459
WAS
.181
6555..1
646101
6,05520
22O592
5,974933W
561
12.76
1,12018 MWD OWSG(3)
10.95411
88.53
28.10
6,556.67
646267
6,061.94
2.178.30
5,974,98.10
Ni
5.53
1,606S MWD 0MG(3)
106293
90.00
279.6
5,557.41
6463.04
6,055.00
2,14&59
5,974.943W
5".96229
5.28
1.052,44 MWD Okki(3)
11010.35
90.28
27..54
6,566.98
646'188
8,00100
212452
S97494T73
6o 98.7
2o0
1029.02 MND OWSG(3)
11,050.37
91.69
29.87
.'5%,.
6462.29
6,000]8
20.4508
5974,1 18
50898.71
3.68
9.19.01 MND OWSG(3)
11.089.89
9243
277.41
6,55.12
61
6,082.69
2,05296
5,904.958.%
553,8%.55
8.19
91 MND GW6G(3)
11.119.59
9307
276.77
6.553.74
6459]4
6.086.23
2024.51
5974,962.13
553.83655
3.15
936.89 MND OW6G(3)
1114791
9305
26.31
81
8.458.10
6.0699
199543
5904,.54.
%3,505.6
1.57
67.67 MND 05966(3)
817501
8677
273.8
655173
649.03
6,09189
196704
5,904,86732
So 791.26
18113
Sol MND 05956(3)
11.973
B9A5
203.
6552.
6458.25
6.093.05
193378
5874969.06
563747.29
200
648.21 MND MSG 13)
Baker Hughes S
Ann0tetlOn
10/17/2019 1:54:36PM Pact 4 COMPASS 5000.14 Bi 85H
Co11ocoPLllIps
Conocolphillips
Definitive Survey Report
Company: Ca .... Phillips Alaska Inc Kuparuk
Local Co-andmate Reference:
Pmjecc Kupamk River Unit
TVD Reference:
5ge: Kuparuk 1C Pad
MD Relerence:
Well: 1C418
North Reference:
Wellbore: 1641611
Survey Calculavon Maned:
Design: 144181-1
Dafesaze:
Survey
0841116-06
1006 94,00usfl (16-06)
10436 @ 94.01 (1C-06)
True
Minimum Cunnit re
EDT 14 Alaska Pmduc6.n
Baker Hughes
Annotation
1N17R019 1:54:36PW Pages COM54SS SOOD 149add66H
Map
Map
MD
Inc
All
TVD
TVDee
4164
-WAV
Northing
Ea(ting
DLS
Senmal
Se(11) Survey Tool Name
loan)
I'I
1'1
luzrc)
Illml
lustry
lusrtl
Inl
IRI
1'IteD)
IRI
11262.01
90,80
273.28
655215
8,458.15
6,056.05
1,881.59
5,974,971.57
563,6950
2.58
794.29 MWD OWSG 13)
11.33641
9237
274.59
6.55065
6.456.95
6099.83
1838.31
5,874974.18
563AK7.
471
151,15 MND MSG r3)
11,32043
9362
216311
6549.15
6.455.75
6,1.199
1015.42
5.974,976.16
5.520.65
eS5
M2 . MWD MSG (3)
11,3%,09
9508
27611
6,546.89
6,452.89
6106 02
1,77809
5,974.97888
563,591.52
388
69078 MWD MSG (3)
11,39283
Was
27446
6544.w
645108
6,10847
1,75161
5.974,.492.11
563.56503
9.42
664.28 MWD MSG (3)
11.419.63
97.02
27392
6,54081
6,448.81
8,11041
LMoe
5,974,963,04
563,530.49
2.08
637.01 MWD 00886 (3)
11,44865
94.98
27449
6,537.57
6.443.87
6.11252
169510
5,974,986.70
553,50006
685
60612 AND OWSG (3)
11,400125
91,23
274.01
6,533.01
6,44201
5.114.83
1,5603.45
5,974,901.65
5113,47822
12.45
511]1 MWD M. (3)
11510123
90.37
27423
6,53560
6,441.65
6,117.31
1,634.81
5080900.60
56344832
350
54787 MNVDOWSGG)
11,543.48
88.13
2820
6,536.03
6442.03
6,11930
160110
5,814,991.61
563.415.12
8.83
514.85 MWD MSG (3)
11,570.71
89.32
273.61
0,535.84
6,44264
6,12D.60
1,51459
5,974.99278
563387.93
6.55
487.84 Mean MSG (3)
11601.51
91.50
275.00
6536.42
644242
6,123.12
1.54390
5,974.995.08
563.357.2
1003
457.17 MWD MSG (3)
1153149
91.64
279.12
6535.54
0,441.54
6.12201
1,514.19
6914,99870
563.32146
1113
42724 MAD MSG (3)
11660.05
90.49
281.34
6534,96
6,440.96
6,13208
1,486.09
5,875,00354
563,28835
SAO
39869 MAD MSG (3)
11)0408
Was
285.0
6,53491
6440.97
6,142.50
1,44242
5,975,0136D
563,255.59
853
353.07 MND OWSG(3)
11,735R
90.88
290.81
6534.93
8,440.93
6,15100
1,412.88
5975,021.93
508.25.99
0.92
323.29 MND OWSG(3)
11,76527
9160
288.49
6,534.34
0,44034
6,160.05
1384.73
0,975033.67
563191.11
6.30
291.0, MWD MSG (3)
11,19600
9245
3Mt92
653325
64..25
6,17043
1355.75
5.975040.81
561,156.70
835
26166 MND MSG (3)
1182545
9252
29336
653189
6,437.98
6,18130
1,328.85
5975.05153
563.141.8
8..
235.21 MND MSG (3)
11.65188
9011
8258
6531,23
6,431.23
8,191.8
1,304,43
5.915,08167
563,117+2
122
209.43 MWD 00356 (3)
11,86459
89.05
290.52
6531.28
6437.20
0.20381
1,273.82
5.975,07351
553.00652
6.15
MA9 AND MSG (3)
11.92411
9215
Men
6,53087
6,436,87
0.21604
1,236.63
5.975.065.23
553,049.12
10.11
13620 MWDOVSGM)
11,06400 •
9215
MOD
6529.37
6435.37
6,22816
1,isev
5,975,ogs.M
563,011.11
o.w
9012 PROJECTED 10 TD
Baker Hughes
Annotation
1N17R019 1:54:36PW Pages COM54SS SOOD 149add66H
BA ER 0PRINT DISTRIBUTION LIST
F UGHES
a GE company
COMPANY ConocoPhillips Alaska, Inc.
WELL NAME
1C -06L]
FIELD Greater Kuparuk Area
COUNTY North Slope Borough
BHI DISTRICT
Alaska
AUTHORIZED BY Patrick Rider
EMAIL Patrick.Rider�hes.com
STATUS Final Replacement: No
COMPANY
ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX)
PERSON ATTENTION
V
t BP North Slope.
EOA, PBOC, PRB-20 (Office 109)
D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill
900 E. Benson Blvd.
i!Anchorage, Alaska 99508
21 91 17
31368
Please sign and return one copy of this transmittal form to:
ConocoPhillips Alaska, Inc.
Tom Osterkamp (WNS Petroleum Technician)
700 G Street.
Anchorage, Alaska 99510
to acknowledge receipt of this data.
LOG TYPE GR- RES
LOG DATE September 15, 2019
TODAYS DATE October 22. 2019
Revision
Details:
Rev. Requested by: ---
FIELDI
FINAL
CD/DVD
FINAL
PRELIM
LOGS
(las, dlis, PDF, META,
SURVEY
REPORT
LOGS
CGM, Final Surveys)
(compass)
# OF PRIN I
U1 Imool
# OF COPIES
l#0FC5PIES
# OF COPIES
4 4
2 ConocoPhillips Alaska Inc.
Attn: Ricky Elgarico
ATE, 708 OCT 2 3 2019
700 G Street
Anchorage, AK 99510 AO G C G
3 Exxon Mobil, Alaska
Attn: Lynda M. Yaskell and/or Leonardo Elias
3201 C Street, Suite 505
Anchorage, AK 99503
4 State of Alaska - AOGCC 1I i
Attn: Natural Resources Technician 11
333 W. 7th Ave, Suite 100
Anchorage, Alaska 99501
5 DNR - Division of Oil & Gas ***
Attn: Resource Evaluation
550 West 7th Avenue, Suite 1100
Anchorage, Alaska 99501
*** StamD "confidential" on all material deliver to DNR
6 BP Exploration (Alaska) Inc.
Petrotechnical Data Center, LRbI
900 E. Benson Blvd.
Anchorage, Alaska 99508
TOTALS FOR THIS PAGE: 0 1 2 0 0
Baker Hughes P I Date:
Abby Bell
AOGCC
333 West 7tn Ave, Suite 100
Anchorage, Alaska 99501
October 18, 2019
21 91 17
Letter of Transmittal3 3
Harvey Finch
Baker Hughes
795 East 94" Avenue
Anchorage, Alaska 99515
Please find enclosed the directional survey data forth e following we] I(s):
1C -06L1
1C -06U-01
1C -06U-02
RECEIVED
OCT 2 1 2019
AOGCC
(3) Total print
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Harvey Finch, Baker Hughes, Wellplanner
Harvey.Finch@bakerhughes.com
ConocoPhillips
ConocoPhillips Alaska Inc_Kuparuk
Kuparuk River Unit
Kuparuk 1C Pad
IC -06L1
50-029-20564-60
Baker Hughes INTEQ
Definitive Survey Report
17 October, 2019
Baker Hughes
21 91 17
31337
ConocoPhillips
ConocoPhillips Definitive Survey Report Baker Hughes
Company:
ConocoPhillips Alaska Inc—Kuparuk
Project:
Kuparuk River Unit
Site:
Kuparuk 1C Pad
Well:
1C-06
Wellbore:
1C -06L1
Design:
10-061-1
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 1 C-06
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well Position
+N/ -S
0.00 usft
Northing:
To
-El-W
0.00 Usti
Easting:
Position Uncertainty
10000
0.00 usft
Wellhead Elevation:
Wellbore
1C-061-1
1C-0611 MWD-INC(1C-061-1)
9.521.37
Magnetics
Model Name
Survey
Sample Date
Tool Name
BGGM2018
Start Date
10/1/2019
Design 1C-061-1
Audit Notes:
Version: 10 Phase: ACTUAL
vertical Section: Depth From (TVD)
(usft)
33 50
Survey Program
Date
From
To
+E/ -W
(usft)
(usft)
Survey (Wellbore)
10000
9.400.00
1C-06(1 C-06)
9,43000
9490.53
1C-0611 MWD-INC(1C-061-1)
9.521.37
11.924.11
1 C-0611 MWD (1 C -06L1)
Well 1 C-06
1C-06 @ 94.00usR (1C-06)
1C-06 @ 94 00usft(1 C-06)
True
Minimum Curvature
EDT 14 Alaska Production
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
5,968, 860 O0usft Latitude: 70" 19' 31 647 N
561, 864.00 usft Longitude: 149° 29'54 042 W
usft Ground Level: 0.00 usft
Declination Dip Angle Field Strength
(1) V) (nT)
16.44 80.86 57,404
Tie On Depth: 9r,100 00
+N/ -S
+E/ -W
Direction
(uaftj
(usft)
(1)
0.00
0.00
100.00
Survey
Survey
Tool Name
Description
Start Date
End Date
GYD-CT-CMS
Gyrodata cont casing Ms
8/25/2000
MWD-INC_ONLY
MWD-INC_ONLY_FILLER
9/13/2019
9/14/2019
MWD OWSG
OWSG MWD - Standard
9/14/2019
9/15/2019
10/17/2019 1 54'36PM Page 2 COMPASS 5000. 14 Build 85H
Survey
ConocoPhillips
ConocoPhillips
Definitive Survey Report
Baker Hughes a
Company: ConocoPhillips Alaska Inc_Kuparuk
Local Co-ordinate Reference:
Well 1C-06
Project Kuparuk River Unit
TVD Reference:
1C-06 @ 94.00usft (I C-06)
Site: Kuparuk 1C Pad
MD Reference:
1006 @ 94.00usft (1C-06)
Well: 1C-06
North Reference:
True
Wellbore: IG -061.1
Survey Calculation Method:
Minimum Curvature
Design: 1C-061-1
Database:
EDT 14 Alaska Production
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N1S
+E1 -W
Nortfting
Easting
DLS
Section
(usft)
(')
(y
(usft)
(usft)
(usft)
(usft)
('7100')
Survey Tool Name
Annotation
(ft)
(ft)
(ft)
9,400.00
46.50
56.85
6,507.54
6.413.54
532083
3.13147
5,974 205.95
564,951.20
3.38
2,15994 MWO-INC _ONLY (2)
TIP
9430.00
4664
57.64
6.528.17
6,434.17
5,332.61
3,14979
5974,217.89
554,969.42
1.97
2,17594 MWD-INC_ONLY (2)
KOP
9.460.62
54.24
57.64
654165
6,45365
5,345.24
3,169.71
5,974,230.68
564,96924
24.82
2,193.37 MWD -INC -ONLY (2)
Interpolated Azimuth
9.490.53
68.87
57.64
6,561.86
6,467.86
5,359.28
3,191.87
5,974,244.90
565,011.27
48.91
2,212.75 MWD -INC ONLY (2)
Interpolated Azimuth
9,521.37
8311
57.26
6,569.31
6,475.31
5,375.34
3,217.02
5,974261 16
5 .()W 29
46.19
2,234.73 MWD OWSG(3)
9,551.49
94.86
5246
6.559.84
6,475.84
5,392.64
3241.60
5,974,27866
565.060.72
42.13
2,25593 MWD OWSG(3)
9,58144
94.95
39.16
6,567.27
6,473.27
5,413.39
3,262.95
5,974,299.59
565,081.90
4425
2,273.35 MWD OWSG(3)
9.611.37
94.15
24.66
6,564.88
6,470.88
5,438.65
3,278.67
5,974,324.97
565,09741
4837
2,284.45 MWD OWSG(3)
9,64167
9326
11.09
6.562.92
6,468.92
5,467.36
3,287.93
5,974,353.76
565,106.43
44.79
2,288.58 MWD OWSG(3)
9.671.49
92.76
356.80
6,561.34
6,467.34
5496.99
3.289.97
5,974,38340
566108.23
47.88
2,285.45 MWD OWSG(3)
9.70151
94.39
340.18
6.559.46
6465.46
5,52625
3.284.02
5.97441260
565,102.04
5552
2,27451 MWD OWSG(3)
9,731.25
94.83
325.94
6,55].05
6,46305
5,552.60
3,270.63
5,974,438.85
565,088.43
47.75
2,256.74 MWO OWSG(3)
9,763.95
93.41
320.41
6,550]0
6,46070
5,578.70
3,251.08
5,974A6,1 78
565,068.67
17.42
2,232.96 MWD OWSG(3)
9,794.15
91.20
317.41
6,553.49
6,459.49
5,601.44
3.231.25
5,974.487.35
565.048.66
12.33
2.20948 MWD OWSG(3)
9,82386
9160
315.59
6,552.76
6,458]6
5,622.96
3,21081
5974,508.72
565.028.04
6.27
2,18561 MWD OWSG(3)
9.854.23
90.68
313.20
6,55216
6,458.16
5.694.22
3.189.12
5,974,529.78
%5oW.17
8.43
2,160.56 MWD OWSG(3)
9.885.57
92.18
31306
6,551.38
6,457.38
5,665.65
3,166.26
5,974.551.01
564,983.14
4.80
2134.32 MWO OWSG(3)
9,914.02
93.07
312.23
6.550.07
6.456.07
5684.90
3,14535
5974,570.09
564,962.08
4.32
2,11040 MWD OWSG(3)
9,954.95
89.26
304,54
6,549.24
6,455.24
5.710.29
3,11331
5974,595.21
564,929.83
20.96
2,074.43 MWD OWSG(3)
9.987.31
89.48
302.86
6549.60
6,455.60
5,728.24
3,086.39
5,974,612.94
564,902.76
5.24
2,044.80 MWD OWSG(3)
10.015.91
90.34
300.54
6,549.64
6,455.64
5,743.27
3,052.W
5,974627 77
564,878.31
8.65
2,018.23 MWD OWSG(3)
10.047.85
91.50
298.19
6549.13
6,455.13
5,758.93
3,03423
5974,643.19
564,850.36
8.20
1,968.10 MWD OWSG(3)
10,077.99
93.29
297.42
6,547.87
6,453.87
5,77297
3.00759
5,974,657.02
564.823.61
6.46
1.95943 MWD OWSG(3)
10,10779
94.30
297.29
6,545.90
6,451.90
5,786.64
2,981.18
5,974,670.46
564,797.09
3.42
1,93105 MWD OWSG(3)
10.13831
92.58
295.57
6,544.06
6,450.06
6,8W.20
2,9&103
5,974,683.79
564,769.70
7.%
1901.83 MWD OWSG(3)
10,172.96
93.13
29329
6.542.34
6,448.34
5,814.52
2.922.38
5,974,69785
564,738.07
6.76
1.%8.30 MWD OWSG(3)
10.197.71
9200.
29191
654123
6.44723
5,824.01
2.89957
5974,707.16
564,715.18
7.21
1,844.19 MWD OWSG(3)
10,23043
93.14
290.51
6,539.76
6.44576
5.835.83
2%9.10
5.974,71873
564,684.62
5.51
1,812.13 MWD OWSG(3)
10,259.35
92.67
289.57
6,538.30
6,444.30
554573
2,84196
5,974.728.40
564,657.41
3.63
1,78369 MWD OWSG(3)
10,280.79
9502
289.70
6,536.%
6,442.86
5,85292
2,82182
5.974.735.42
564,637.20
10.98
1,76260 MWD OWSG(3)
10/17/2019 1:54r36PM
Page 3
COMPASS 5000.14 Build 85H
ConocoPhillips
ConocoPhillips Definitive Survey Report Baker Hughes v,
Company:
ConocoPhillips Alaska Inc_Kuparuk
Local Co-ordinate Reference:
Well 1C -O6
Project:
Kuparuk River
Unit
TVD Reference:
1C -O6 @ 94.00usft (1C
-O6)
Site:
Kuparuk 1C Pad
MD Reference:
1C-06 @ 94.00usft (1C-06)
Well:
10-06
North Reference:
True
Wellbore:
1C-0611
Survey Calculation Method:
Minimum
Curvature
Design:
IC -061.1
Database:
EDT 14
Alaska Production
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
*NIS
+EI -W
DLS
("sit)
(`)
0
(usft)
(usft)
(usft)
(usft)
Northing
Easting
(-/100')
Section
Survey Tool Name(ft)
(
(ft)
(ft)
10,310.44
9674
28995
6.533.82
6,439.82
5,862.92
2,79407
5,974,745.19
564609.38
5.86
1.733.54
MWD OWSG(3)
10.331.07
96.59
288.85
6.53143
6.437.43
5.669.73
2.77475
5.974.75184
564,590.00
535
1713.32
MWD OWSG(3)
10,356.51
98.42
2WS1
6528.11
6.434.11
58T/.81
2.75085
5,974,759.72
564,566.04
7.31
1,688.39
MWD OWSG(3)
10,390.35
100.57
290.18
6,522.52
6,428.52
5,888.86
2.719.36
5,974]70.51
564,534.47
800
165546
MWD OWSG(3)
10,41597
99.16
290.85
6,518.13
6,424.13
5,89771
2.69573
5,974,77916
554510-76
608
1,63065
MWO OWSG(3)
10,460.12
92.61
291.45
6.513.61
6,419.61
5.913.54
2,654.79
5,974,79466
56446970
14.90
1,587.58
MWD OWSG(3)
10,46959
88.86
291.47
6.513.23
6,419.23
5,924.32
2,627.37
5,974,80521
564,442.19
12.72
1,558.71
MWD OWSG(3)
10.509.43
87W
291.34
6,51378
6,419.78
5,931.56
2,608.91
5,974,81230
564,423.67
4.53
1,53927
MWD OWSG(3)
10.539.32
87.85
289.59
6,514.87
6.420.87
5,942.00
2.580.92
5,974,82251
564,395.60
5.86
1,509.89
MWO OWSG(3)
10,56941
8297
28982
6.515.97
6.421.97
5.952.14
2,552.61
5,974,83241
564,367.21
0.86
1,48025
MWD OWSG(3)
10590.97
86.84
290.29
6.516.94
6.422.94
5.959.53
2,532.38
5974,83963
564,346.92
5.68
1459.05
MWD OWSG(3)
10.623.49
8,140
291.30
6,519.43
6.425.43
5,971.04
2.502.07
5974,85089
564,316.52
8.12
1,427.20
MWD OWSG(3)
10,657.62
81.60
291.28
6,523.53
6429.53
5,91KI24
2,470.50
5,974,862.93
564,284.86
762
1,393.97
MWD OWSG(3)
10677.41
82.93
290.66
6,526.16
6,432.16
5,990.39
2,452.20
5,97486983
564,266.50
6.09
1,37473
MWD OWSG(3)
10,717.75
8579
289.52
6.53012
6,436.12
6,004.24
2,414.53
5,974,883.37
564.228.72
7.82
1,335.22
MWD OWSG(3)
10,74353
83.38
288.21
6,53255
6,438.55
6,012.54
2,390.24
5,974,89147
564.204.37
1063
1.309.86
MWD OWSG(3)
10771.99
83.45
286.54
6,535.82
6441.82
6,020.98
2,36326
5,974,899.69
564,177.32
5.83
1281.83
MWD OWSG(3)
10,802.73
81.07
284.03
6.539.%
6,445.96
6,029.01
2,33388
5.974,907 47
564.147.88
1120
1.251.50
MWD OWSG(3)
10,832.24
81.58
282.39
6,544.41
6.45041
6,03568
2.30546
5.W4,91390
564,119.43
576
1.222.37
MWD OWSG(3)
10,879.23
82.55
281.36
6550.90
6.456.90
6.045.26
2.25994
5.974,923 10
564,073.81
3.00
1,175.86
MWD OWSG(3)
10,89710
83.44
281.24
6,553.08
6,45908
6,048.73
2,242.55
5,974,926.43
564056.39
5.02
1,158.13
MWD OWSG(3)
10,934.59
88.19
281.81
6,555.81
6.461.81
6,056.20
2,20592
5,974,933.60
564,019.71
1276
1,120.76
MWD OWSG(3)
10,964.71
8853
280.18
5556.67
6,462.67
6,W194
2176.37
5,974,939.10
563,990.11
5.53
1,090.66
MWD OWSG(3)
10,992.93
90.00
279.94
6,55703
6,463.04
6,066.87
2,148.59
5,974,943.80
563,962.29
5.28
1,062.44
MWD OWSG(3)
11,01735
90.28
279.54
6,556.98
6,46298
6.071.00
2,12452
5.974,947.73
563,938.20
2.00
1,038.02
MND OWSG(3)
11057.37
9189
279.97
6,656.29
6,462.29
6,077.78
2,08508
5.974,954.18
563,898.71
368
998.01
MND OWSG(3)
11,089.89
9243
277.41
6.555.12
6461.12
6,082.69
2.05296
5,974,958.83
663,866.55
8.19
965.52
MWD OWSG(3)
11.118.59
93.07
276.77
6.553.74
6.45974
6.096.23
2.024.51
5,974,962 13
563,838.08
3.15
936.89
MWD OWSG(3)
11,14791
93.05
276.31
6.552.18
6.458.18
6.089.57
1.99543
5,974,96523
563.808.97
157
907.67
MWD OWSG(3)
11,175.71
8877
273.30
6,%173
8,45773
6,091.89
1%774
5,974,967.32
563781.26
18.82
880.00
MWD OWSG(3)
11,20973
89.45
273.30
6.552.26
6,456.26
6,093.85
1933.76
5.974.96900
563,747.29
2.00
846.21
MWD OWSG(3)
Annotation
10/172019 1:54:36PM Page 4 COMPASS 5000.14 Build 85H
ConocoPhillips
ConocoPhillips Definitive Survey Report Baker Hughes a
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:
IC -06 @ 94.00usft (1C -O6)
Well:
1C-06
North Reference:
True
Wellbore:
11C-061-1
Survey Calculation Method:
Minimum Curvature
Design:
1C-061.1
Database:
EDT 14 Alaska Production
Survey
Annotation
10/1712019 1:54:36PM Page 5 COMPASS 5000.14 Build 85H
Map
Map
Vertical
MD
Inc
Ari
TVD
TVDSS
4N/ -S
-E/-W
DLS
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
Northing
Easting
('1100')
Section
Survey Tool Name
(ft)
Iftl
(ft)
11.262.01
90.80
27328
6.552.15
6,458.15
6,036.85
1,88159
5,974,971.57
563,69508
2.58
794.29
MM OWSG(3)
1130541
92.37
274.59
6.550.95
6.456.95
6.099.83
1.838.31
5974,974.19
563,65178
4.71
751.15
MWD OWSG(3)
11,328.43
93.62
27620
6.54975
6455.75
6.101.99
1.815.42
5.974,97616
563,628.88
685
728.24
MWD OWSG(3)
11,366.09
95.08
276.11
6,546.89
6,452.89
6,106.02
1,778.09
5,974,979.88
563,591.52
388
690.78
MWD OWSG(3)
11,392.83
96.99
274.46
6,544.08
6,450.08
6,108.47
1,75161
5,974,982.11
563,565.03
9.42
654.28
MWD OWSG(3)
11,41963
97.02
273.92
6,540.81
6,446.81
6,11041
1.725.08
5,974,98384
563.538.49
200
637.81
MWD OWSG(3)
1144965
94.98
274.19
6,537.67
6,443.67
6,11252
1.695.30
5,974 98!170
563.508.69
685
608.12
MWD OWSG(3)
11,480.25
9123
274.87
6,536.01
6,442.01
6.114.93
1.664.85
5,974,987.86
563.478.22
12.45
57771
MWD OWSG(3)
11,510.23
90.37
274.23
6535.60
6.441.60
6.117.31
1634.97
5,974,990.00
5!Ki, 832
3.58
54787
MND OWSG(3)
11,503.48
88.13
272.28
6,536.03
6,442.03
6,11920
1,60178
5,974,991.61
56341512
8.93
514.85
MWD OWSG(3)
11,570.71
89.32
273.61
6,536.64
6.44264
6.12060
1,574.59
5,974,992.78
563,387.93
6.55
487.84
MWO OWSG(3)
11,601.51
91.50
275.80
6.536.42
6.442.42
6,123.12
1.543.90
5,974,995.06
563,357.22
10.03
457.17
MWD OWSG(3)
11,631.49
91.84
279.12
6,535.54
6,441.54
6,127.01
1514.19
5,974,998.70
56332748
11.13
427.24
MWD OWSG(3)
11,660.05
90.49
281.34
6,534.96
6,440.96
6,132.08
1486.09
5,975,00354
5633299.35
9.10
398.69
MWD OWSG(3)
11704.96
8948
285.50
6,534.97
6440.97
6,142.50
144242
5.975,013.60
563.255.59
953
353.87
MWD OWSG(3)
11.735.72
9068
286.87
6,534.93
6,440.93
6,151.08
1,41288
5,975,02193
563.225.99
5.92
323.29
MWD OWSG(3)
11765.27
91.60
288.49
6.534.34
6,440.34
6,160.05
1,364.73
5,975,03067
563.19777
6.30
294.01
MWD OWSG(3)
11.796.08
92.45
290.92
6,533.25
6,439.25
6,170.43
135575
5,975,040.81
563,16870
6.35
263.66
MWD OWSG(3)
11.825.15
92.52
293.36
6,531.99
6.437.99
6.181.38
1.328.85
5,975,05153
563,14172
8.39
235.27
MWD OWSG(3)
11.85168
9077
292.58
6,53123
6,437.23
6.191.72
1,304.43
5.975,061 67
563,117,22
7.22
203.43
MWD OWSG(3)
11884.59
89.05
290.52
6,531.28
6,437.28
6,2021 81
1,27382
5,975.073.51
563,086.52
8.15
177.19
MWD OWSG(3)
11,924.11
9215
28800
6.530.87
6,436.87
6,216.84
1,236.53
5,975,06623
563,049.12
10.11
138.20
MWD OWSG(3)
11,964.00
9215
288.00
6,529.37
6,435.37
6,229.16
1,19861
5,975,09824
563.011.11
0.00
98.72
PROJECTED to TD
Annotation
10/1712019 1:54:36PM 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
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
v .aogcc.alaska.gov
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C -06L1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-117
Surface Location: 1375' FNL, 858' FWL, SEC, 12, TI 1N, R10E, UM
Bottomhole Location: 228' FNL, 1135' FWL, SEC. 01, T1 IN, 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,
essie L. Chmielowski
Commissioner
DATED this L 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.gov>
Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.eov>; Winston, Hugh E (CED) <hugh.winston@alaska.aov>
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 -06L1
219-117
10-401
KRU 1C-061-1-01
219-118
10-401
KRU 1C -06L1-02
219-119
10-401
KRU 1C-061-1
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.¢ov>
Sent: Wednesday, January 15, 2020 8:37 AM
To: Germann, Shane <Shane.Germann@conocophillips.com>
Cc: Brooks, Phoebe L (CED) <phoebe. brooks @alaska.eov>; Winston, Hugh E (CED) <huPh.winston@alaslca.rov>
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. LoeooGDa laska. 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.aov>
Cc: Brooks, Phoebe L (CED) <phoebe.brooks @alaska.lzov>; Ohlinger, James J
<James.J.Ohlineer@conocophillips.com>
Subject: KRU 1C-06 Sundry Issues
Victoria,
It has been brought to my attention that the KRU IC -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 (Ll, 1-1-01, and L3-02) 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. ,..A OIL AND GAS CONSERVATION COMh. _.JN
PERMIT TO DRILL
9n AAc 95 005 /I1Gui
rnU t h
z -
SPP
1a. Type of Work:
Drill ❑ Lateral ❑°
Redrill ❑ Reentry ❑
11b. Proposed Well Class: Exploratory - Gas ❑
Stratigraphic Test ❑ Development - Oil ❑
I Exploratory - Oil ❑ Development - Gas ❑
Service - WAG V1 Service - Disp ❑
Service - Winj r Single Zane ❑°
Service - Supply ❑ Multiple Zone ❑
1c. Specify if well is proposed for:
CoalbedGas ❑ Gas Hydrates ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
5. Bond: Blanket ❑� Single Well ❑
Bond No. 5952180
11. Well Name and Number:
KRU 1 C -06L1
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
6. Proposed Depth:
MD: 13,000' TVD: 6498'
12. Field/Pool(s):
Kuparuk River Pool /
Kuparuk River Oil Pool
4a. Location of Well (Governmental Section):
Surface: 1375' FNL, 858' FWL, Sec. 12, T11 N, R10E, UM
Top of Productive Horizon:
1323' FNL, 1269' FEL, Sec. 01, T11 N, R10E, UM
Total Depth:
228' FNL, 1135' FWL, Sec. 01, T11N, R10E, UM
7. Property Designation:
ADL 25649
8. DNR Approval Number:
LONS 79-016
13. Approximate Spud Date:
9/10/2019
9. Acres in Property:
2560
14. Distance to Nearest Property:
6830' "
4b. Location of Well (State Base Plane Coordinates - NAD 27):
Surface: x- 561864 y- 5968860 Zone- 4
10. KB Elevation above MSL (ft): 94
GL / BF Elevation above MSL (ft): 55
15. Distance to Nearest Well Open
to Same Pool: 1079' (1C-19)
16. Deviated wells: Kickoff depth: 9,430 feet
Maximum Hole Angle: 98 degrees
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Downhole: 3888 Surface: 3235
18. Casing Program: Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Hole Casing Weight Grade I Coupling I Length
MD TVD MD TVD (including stage data)
3" 2-3/8" 4.7# L-80 ST -L 3100'
9900' 6546' 13,000' 6498' Uncemented Slotted Liner
19. PRESENT WELL CONDITION SUMMARY (T0 be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured):
10,243' 7102' N/A
Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured):
10,127' 7019' 10,026'
Casing Length Size
Cement Volume MD TVD
Conductor 33' 16"
425 sx PF 65' 65'
Surface 3255' 10-3/4"
340 sx AS 11 3287' 2685'
Production 10,196' 7"
535 sx Class G 10,226' 7090'
Perforation Depth MD (ft): 9410-9485
Perforation Depth TVD (ft): 6514-6566
Hydraulic Fracture planned? Yes❑ No R
P Sketch
20. Attachments: Property Plat ❑ DiveSOrter Sketch
Drilling Program
B Seabed Report
ev. Depth Fluid Prog ot atm
B Drilling
B 20 AAC 25.050 requ Shallow Hazard emlysis
entse
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. erfnann CO .Conn
Authorized Title: Staff CTD Engineer 6 Contact Phone: 907-263-4597
Authorized Signature: Date: /�✓T/%
Commission Use Only
Permit to Drill
Number: — 11::7-
a
API Number:Permit
50- 0-M — o 56 — 6
-o0
Approval
Date: Q'
See cover letter for other
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:
Other: Sep f� t * Samples req'd: Yes ❑ No2e Mud log req'd: Yes ❑ No[�
350o�yp_ a /meq/, !� ,�,/
in h u / 17 r pr�Vln 7 � r /`Q' 7, ✓ d C2 p- S 19 HzS measures: Yes [� No,❑,/ Directional svy req'd: Yes L+J No❑
Spaci exception req'd: Yes ❑ N,5?' Inclination -only svy req'd: Yes❑ No�
Post initial injection MIT req'd: Yes El No❑
APPROVED BY
Approved by: — COMMISSIONER THE COMMISSION Date: O ��
/(p `9 Submit Form and
Form 1 01 Revised 5/2017 s p rmit{s valid 2 t r e f approval per 20 AAC 25.005( ) Attachments in Du licate
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-061-1, 1C-061-1-01, and 1C -06L1-02, 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 -06L1-01, 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 907-263-4597.
Sincerely,
/k
V�J'
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........................................................................................................
2
(Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))..............................................................._.... ................. ................ ........
..... 2
2.
Location Summary ..........................................................................................................................
2
(Requirements of 20 AAC 25.005(c)(2)) ............... ..................................................................................................... --- ..... _..............
2
3.
Blowout Prevention Equipment Information.................................................................................
2
(Requirements of 20 AAC 25.005(c)(3))............................................................................................................................. _..................2
4.
Drilling Hazards Information and Reservoir Pressure.................................................................. 2
(Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2
5.
Procedure for Conducting Formation Integrity tests................................................................... 2
(Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2
6.
Casing and Cementing Program.................................................................................................... 3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3
7.
Diverter System Information..........................................................................................................
3
(Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3
8.
Drilling Fluids Program..................................................................................................................
3
(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............................................................................................................................. 4
(Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4
11.
Seabed Condition Analysis............................................................................................................4
(Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................
4
12.
Evidence of Bonding...................................................................................................................... 4
(Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4
13.
Proposed Drilling Program.............................................................................................................4
(Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4
Summaryof Operations...................................................................................................................................................4
LinerRunning...................................................................................................................................................................5
14.
Disposal of Drilling Mud and Cuttings..........................................................................................
6
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................
6
15.
Directional Plans for Intentionally Deviated Wells.......................................................................
6
(Requirements of 20 AAC 25.050(b))......................................................................................................................................................
6
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 1C-06............................................................................................................7
Attachment 3: Proposed Well Schematic for 1C-061-1, 1C-061-1-01, & 1C-061-1-02 laterals...........................................7
Page 1 of 7 January 30, 2019
i I
PTD Application: 1C-vdL1, 1C-061-1-01, & 1C-061-1-02
1. 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 -06L1-01, & 1C-061-1-02. All laterals will be
classified as "Development' wells.
2. 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 1C-06 vicinity is to the south in the 1C-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 1 C-06 have injected gas, so there is a possibility of encountering free gas while
drilling the 1 C-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 1 C-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.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 1 C-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-u6L1, 1C-061-1-01, & 1C -06L1-02
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
Lateral Name
Liner Top
Liner Btm
Liner Top
Liner Btm
Liner Details
Btm MD
MD
MD
TVDSS
TVDSS
Conductor
1C -06L1
9900'
13,000'
6452'
6404'
2-3/8", 4.7#, L-80, ST -L slotted liner;
Surface
65'
1640
670
Surface
aluminum billet on to
IC -06L11-01
11,250'
14,300'
6439'
6405'
2-3/8", 4.7#, L-80, ST -L slotted liner,
2685'
3580
2090
Production
7"
aluminum billet on to
1C-061_1-02
9320'
13,900'
6357'
6528'
2-3/8", 4.7#, L-80, ST -L slotted liner;
4980
4320
Tubing
3-1/2"
9.3
de to ment sleeve on to
Existing Casing/Liner Information
Category
OD
Weight
Grade
Connection
Top MD
Btm MD
Top
TVD
Btm
TVD
Burst
psi
Collapse
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' 1
Surface
7090'
4980
4320
Tubing
3-1/2"
9.3
L-80
EUE-8rd
Surface
9381' 1
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.
JManaged 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 secondary well control as detailed in section 3
I "Blowout Prevention Equipment Information".
d 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-u6L1, 1C-061_7-01, & 1C-061-7-02
Pressure at the 1C-06 Window (9430' MD, 6528' TVD) Using MPD
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AAC 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AAC 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AAC 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
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 IC -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 1C-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 1 C -06L1-01 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 IC -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 1C-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 1 C -06L1-01 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-061_1, 1C-061_1-01, & 1C-061-1-02
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. 1 C -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. Kick off 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 5 of 7 August 29, 2019
PTD AoDlication: 1C -06L1. 1C-061-1-01. & 1C-061-1-02
- 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 1 B 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))
IA
- 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 -06L7
6830'
1 C-061-1-01
2694'
1C -06L1-02
2806'
- Distance to Nearest Well within Pool
Lateral Name
Distance
Well
1C -06L1
1079'
1C-19
1C -06L1-01
1139'
1C-111-2-02
1C -06L1-02
1204'
1C -19L1
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. It is 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.
1C -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-061_1 to IC -07A center to center distance is roughly 1223'.
Page 6 of 7
August 29, 2019
PTD Application: 1C-061-1, 1C-061_1-01, & 1C-061-1-02
IC -19 & IC -19L1
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 1C-191_1 (PTD #219-086)
drilled in 2019 and completed with 2-318" 4.7 ppf L-80 slotted liner. 1C -19L1 is located in the C sand to the north
of 1C-19. The 1C -06L1 to 1C-19 center to center distance is roughly 1079'. The 1C -06L1-02 to 1C -19L1 center
to center distance is roughly 1204'.
IC -111-2-02
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 1 C-11 L2-02 is a C sand lateral completed with 2-318" 4.7 ppf L-80 slotted liner. The 1 C-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 1C -06L1-01 to 1C-11 L2-02 center to center distance is roughly 1139'.
17.Attachments
Attachment 1: Directional Plans for 1C-061-1, iC-061-1-01, & 1C -06L1-02 laterals
Attachment 2: Current Well Schematic for 1C-06
Attachment 3: Proposed Well Schematic for lC-06L1,1C-06L1-01,&1C-06L1-02laterals
Page 7 of 7 August 29, 2019
Well KRU XX -XX Nabors CDR3-AC: 4 -Ram BOP Configuration 2" Date April 24, 2019
Coiled Tubing and 2-3/8" BHA
Quick Test Sub to Ot
Top of 7" Otis
Distances from top o
Excluding quick -test
Top of Annular
CL Annular
Bottom Annular Flan•
CL Blind/Shears
CL 2" Combi's
CL 2-3/8" Combi's
CL 2" Combi's
CL of Top
Top of Swa
CL Swab 1
Flow Tee
CL SSV
CL Master
LDS
Ground
Tree Size 3 118
ire
ConocoPhillips
ConocoPhillips Alaska Inc_Kuparuk
Kuparuk River Unit
Kuparuk 1C Pad
IC -06
IC -061-1
Plan: 1 C-061-1 _wp02
Standard Planning Report
15 August, 2019
BA UGHES
a GE company
ConocoPhillips BA ER
ConocoPhillips Planning Report F�UGHES
a GEcempany
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 -06L1
Design:
1C-0611_wp02
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well IC -06
Mean Sea Level
1C-06 @ 94.00usft (iC-136)
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
he Kuparuk 1C Pad
1C-06
Measured
Build
'site Position:
Northing:
5,968,522.48 usft
Latitude:
70° 19'28.285 1
r0m: Map
Easting:
562,372.05 usft
Longitude:
149° 29' 39.293 V
'osition Uncertainty: 0.00 usft
Slot Radius:
0.000 in
Grid Convergence:
0.48 °
Weg
1C-06
Measured
Build
Tum
Depth
Well Position
+N/ -S
0.00 usft
Northing:
5,968,860.00 usft
Latitude:
70° 19'31.647 1
56.85
+1
0.00 usft
Easting:
561,864.00 usft
Longitude:
149° 29' 54.042 V
cation Uncertainty
93.00
0.00 usft
Wellhead Elevation:
usft
Ground Level:
0.00 usf
Wellbore
Magnetics
Design
Audit Notes:
Version:
Vertical Section
1C-061-1
Modef Name
BGGM2018
Sample Date
10/1/2019
1C -061-1_w1302
Phase:
Depth From (TVD)
(usft)
-60.50
Plan Sections
Measured
Build
Tum
Depth
Inclination
Azimuth
(usft)
V)
(I
9,400.00
46.50
56.85
9,430.00
46.64
57.64
9,459.00
51.86
57.64
9,556.95
93.00
57.64
9,775.00
94.91
325.79
10,175.00
95.27
297.68
10,575.00
90.00
270.14
10,800.00
83.41
284.48
11,050.00
89.58
300.90
11,300.00
98.24
285.64
11,700.00
85.16
260.82
12,100.00
90.39
288.36
12,200.00
96.12
292.39
12,550.00
89.44
268.77
13,000.00
89.52
300.28
Declination Dip Angle Field Strength
P) V) (nT)
16.44 80.86 57.404
PLAN Tie On Depth:
N/S +E/ -W
(usft) (usft)
0,00 0.00
9,400.00
Direction
V)
100.00
TVD Below
Dogleg
Build
Tum
System
+i
+E/ -W
Rate
Rate
Rate
TFO
(usft)
(usft)
(usft)
(°/100usft)
(°1100usft)
(°111
(1)
6413.54
5,320.83
3,131.47
0.00
0.00
0.00
0.00
6,434.17
5,332.61
3,149.79
1.97
0.47
2.63
76.56
6,453.09
5,344.37
3,168.34
18.00
18.00
0.00
0.00
6,482.03
5,393.28
3,245.54
42.00
42.00
0.00
0.00
6,462.69
5,583.79
3,285.28
42.00
0.88
-42.12
-85.00
6,426.48
5,846.35
2,991.02
7.00
0.09
-7.03
-88.00
6,407.75
5,941.28
2,606.99
7.00
-1.32
-6.88
-100.00
6,420.75
5,969.69
2,384.88
7.00
-2.93
6.37
115.00
6,436.13
6,065.67
2,155.61
7.00
2.47
6.57
70.00
6,418.98
6,163.97
1,927.45
7.00
3.46
-6.10
-60.00
6,406.93
6,185.97
1,532.21
7.00
-3.27
-6.21
-117.00
6,422.75
6,217.80
1,137.78
7.00
1.31
6.88
80.00
6,417.08
6,252.52
1,044.24
7.00
5.73
4.03
35.00
6,399.88
6,316.02
703.19
7.00
-1.91
-6.75
-105.00
6,404.05
6,427.46
273.05
7.00
0.02
7.00
90.00
Target
811512019 9:39:53AM Page 2 COMPASS 5000.14 Build 85H
Planned Survey
ConocoPhillips
BAT
BA ER
ConocoPhillips
Planning Report
Measured
6Emmpany
Database: EDT 14 Alaska Production
Local Co-ordinate Reference:
Well 1C-06
Company: ConocoPhillips Alaska Inc_Kuparuk
TVD Reference:
Mean Sea Level
Map
Project: Kuparuk River Unit
MD Reference:
1C-06 @ 94.00usft (1C-06)
Azimuth
Site: Kuparuk 1C Pad
North Reference:
True
Section
Well: 1C-06
Survey Calculation Method:
Minimum Curvature
Easting
Wellbore: 1C-061-1
(•)
(•)
(usft)
Design: 1C-06L1_wp02
(usft)
(usft)
(°1100usft)
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination
Azimuth
System
+N/ -S
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(•)
(•)
(usft)
(usft)
(usft)
(usft)
(°1100usft)
(°)
(usft)
(usft)
9,400.00
46.50
56.85
6,413.54
5,320.83
3,131.47
2,159.94
0.00
0.00
5,974,205.95
564,951.20
TIP
9,430.00
46.64
57.64
6,434.17
5,332.61
3,149.79
2,175.94
1.97
76.56
5,974,217.89
564,969.42
KOP
9,459.00
51.86
57.64
6,453.09
5,344.37
3,168.34
2,192.16
18.00
0.00
5,974,229.79
564,987.87
Start
Build 42.00
9,500.00
69.08
57.64
6,473.22
5,363.39
3,198.36
2,218.43
42.00
0.00
5,974,249.06
565,017.73
9,556.95
93.00
57.64
6,482.03
5,393.28
3,245.54
2,259.69
42.00
0.00
5,974,279.34
565,064.65
Start
DLS 42.00 TFO -85.00
9,600.00
94.40
39.58
6,479.23
5,421.57
3,277.63
2,286.39
42.00
-85.00
5,974,307.88
565,096.51
9,700.00
95.83
357.42
6,469.89
5,513.85
3,308.55
2,300.82
42.00
-86.18
5,974,400.41
565,126.67
9,775.00
94.91
325.79
6,462.69
5,583.79
3,285.28
2,265.76
42.00
-90.11
5,974,470.15
565,102.82
Start
DLS 7.00 TFO
.88.00
9,800.00
94.97
324.04
6,460.54
5,604.17
3,270.97
2,248.12
7.00
-88.00
5,974,490.41
565,088.34
9,900.00
95.16
317.01
6,451.71
5,681.01
3,207.68
2,172.45
7.00
-88.15
5,974,566.72
565,024.43
10,000.00
95.27
309.98
6,442.61
5,749.52
3,135.49
2,089.46
7.00
-88.77
5,974,634.62
564,951.69
10,100.00
95.30
302.95
6,433.40
5,808.67
3,055.46
2,000.38
7.00
-89.41
5,974,693.10
564,871.18
10,175.00
95.27
297.68
6,426.48
5,846.35
2,991.02
1,930.37
7.00
-90.06
5,974,730.25
564,806.44
Start
DLS 7.00 TFO
.100.00
10,200.00
94.96
295.95
6,424.25
5,857.59
2,968.80
1,906.54
7.00
-100.00
5,974,741.30
564,784.13
10,300.00
93.70
289.05
6,416.69
5,895.72
2,876.73
1,809.25
7.00
-100.15
5,974,778.67
564,691.76
10,400.00
92.38
282.16
6,411.38
5,922.56
2,780.61
1,709.93
7.00
-100.68
5,974,804.72
564,595.43
10,500.00
91.02
275.29
6,408.41
5,937.72
2,681.88
1,610.06
7.00
-101.04
5,974,819.06
564,496.58
10,575.00
90.00
270.14
6,407.75
5,941.28
2,606.99
1,535.69
7.00
-101.25
5,974,822.00
564,421.67
Start
DLS 7.00 TFO
116.00
10,600.00
89.26
271.73
6,407.91
5,941.68
2,581.99
1,511.01
7.00
115.00
5,974,822.20
564,396.68
10,700.00
86.31
278.09
6,411.78
5,950.22
2,482.50
1,411.54
7.00
114.99
5,974,829.91
564,297.12
10,800.00
83.41
284.48
6,420.75
5,969.69
2,384.88
1,312.03
7.00
114.74
5,974,848.57
564,199.36
Start
DLS 7.00 TFO
70.00
10,900.00
85.84
291.08
6,430.12
6,000.08
2,290.14
1,213.45
7.00
70.00
5,974,878.18
564,104.38
11,000.00
88.33
297.63
6,435.21
6,041.24
2,199.22
1,116.76
7.00
69.38
5,974,918.58
564,013.13
11,050.00
89.58
300.90
6,436.13
6,065.67
2,155.61
1,069.57
7.00
69.05
5,974,942.65
563,969.33
Start
DLS 7.00 TFO
-60.00
11,100.00
91.33
297.87
6,435.73
6,090.20
2,112.05
1,022.41
7.00
-60.00
5,974,966.82
563,925.57
11,200.00
94.82
291.78
6,430.36
6,132.10
2,021.48
925.94
7.00
-60.02
5,975,007.97
563,834.67
11,300.00
98.24
285.64
6,418.98
6,163.97
1,927.45
827.80
7.00
-60.35
5,975,039.06
563,740.38
Start
DLS 7.00 TFO
-117.00
11,400.00
95.02
279.38
6,407.42
6,185.46
1,830.53
728.63
7.00
-117.00
5,975,059.75
563,643.31
11,500.00
91.74
273.19
6,401.51
6,196.37
1,731.37
629.08
7.00
-117.72
5,975,069.84
563,544.06
11,600.00
88.44
267.01
6,401.35
6,196.54
1,631.43
530.63
7.00
-118.09
5,975,069.19
563,444.14
11,700.00
85.16
260.82
6,406.93
6,185.97
1,532.21
434.75
7.00
-118.10
5,975,057.80
563,345.02
Start
DLS 7.00 TFO
80.00
11,800.00
86.41
267.72
6,414.28
6,176.03
1,433.04
338.81
7.00
80.00
5,975,047.04
563,245.94
11,900.00
87.71
274.61
6,419.42
6,178.07
1,333.26
240.19
7.00
79.49
5,975,048.26
563,146.15
12,000.00
89.04
281.49
6,422.26
6,192.06
1,234.34
140.35
7.00
79.14
5,975,061.43
563,047.14
12,100.00
90.39
288.36
6,422.75
6,217.80
1,137.78
40.78
7.00
78.94
5,975,086.37
562,950.37
Start
DLS 7.00 TFO
35.00
12,200.00
96.12
292.39
6,417.08
6,252.52
1,044.24
-57.37
7.00
35.00
5,975,120.32
562,856.56
Start
DLS 7.00 TFO
-106.00
12,300.00
94.27
285.61
6,408.02
6,284.91
950.13
-155.67
7.00
-105.00
5,975,151.93
562,762.20
12,400.00
92.36
278.86
6,402.24
6,306.05
852.63
-255.36
7.00
-105.61
5,975,172.26
562,664.53
12,500.00
90.42
272.14
6,399.82
6,315.63
753.18
-354.96
7.00
-106.00
5,975,181.02
562,565.02
8/152019 9:39:53AM Page 3 COMPASS 5000.14 Build 85H
ConocoPhillips gA ER
ConocoPhillips Planning Report F U JHES
aGEcompany
Database:
EDT 14 Alaska Production
Depth
Company:
ConocoPhillips Alaska Inc_Kuparuk
Project:
Kupamk River Unit
6,404.05 2-3/8"
Site:
Kuparuk 1 C Pad
Rate
Well:
10-06
Easting
Wellbore:
1C-061.1
(usft)
Design:
1C-06Ll_wp02
(usft)
Planned Survey
6.316.02
703.19
Measured
TVD Below
I Depth
Inclination Azimuth
System
(usft)
(1) (1)
(usft)
12,550.00
89.44 268.77
6,399.88
Start OLS 7.00 TFO 90.00
6,326.53
12,600.00
89.44 272.27
6,400.37
12,700.00
89.45 279.27
6,401.34
12,800.00
89.47 286.27
6,402.28
12,900.00
89.49 293.27
6,403.19
13,000.00
89.52 300.28
6,404.05
Planned TD at 13000.00
7.00
Casing Points
Measured
Vertical
Depth
Depth
(usft)
(usft)
13,000.00
6,404.05 2-3/8"
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 C-06
Mean Sea Level
1C-06 @ 94.00usft (IC -06)
True
Minimum Curvature
Casing
Diameter
Name (in)
2.375
Plan Annotations
Vertical
Dogleg
Toolface
Map
Map
-NIS
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(usft)
(usft)
(°/100usft)
(1)
(usft)
(usft)
6.316.02
703.19
-004.26
7.00
-106.17
5,975,181.00
562,515.03
6,316.48
653.20
-453.57
7.00
90.00
5,975,181.05
562,465.04
6,326.53
553.77
-553.23
7.00
89.97
5,975,190.28
562,365.55
6,348.63
456.31
-653.05
7.00
89.90
5,975,211.57
562,267.92
6,382.44
362.27
-751.53
7.00
89.83
5,975,244.60
562,173.61
6,427.46
273.05
-847.21
7.00
89.77
5,975,288.88
562,084.03
Casing
Diameter
Name (in)
2.375
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+N/ -S
+E/ -W
(usft)
(usft)
(usft)
(usft)
Comment
9,400.00
6,413.54
5,320.83
3,131.47
TIP
9,430.00
6,434.17
5,332.61
3,149.79
KOP
9,459.00
6,453.09
5,344.37
3,168.34
Start Build 42.00
9,556.95
6,482.03
5,393.28
3,245.54
Start DLS 42.00 TFO-85.00
9,775.00
6,462.69
5,583.79
3,285.28
Start DLS 7.00 TFO -88.00
10,175.00
6,426.48
5,846.35
2,991.02
Start DLS 7.00 TFO -100.00
10,575.00
6,407.75
5,941.28
2,606.99
Start DLS 7.00 TFO 115.00
10,800.00
6,420.75
5,969.69
2,384.88
Start DLS 7.00 TFO 70.00
11,050.00
6,436.13
6,065.67
2,155.61
Start DLS 7.00 TFO-60.00
11,300.00
6,418.98
6,163.97
1,927.45
Start DLS 7.00 TFO-117.00
11,700.00
6,406.93
6,185.97
1,532.21
Start DLS 7.00 TFO 80.00
12,100.00
6,422.75
6,217.80
1,137.78
Start DLS 7.00 TEO 35.00
12,200.00
6,417.08
6,252.52
1,044.24
Start DLS 7.00 TEO-105.00
12,550.00
6,399.88
6,316.02
703.19
Start DLS 7.00 TFO 90.00
13,000.00
6,404.05
6,427.46
273.05
Planned TD at 13000.00
Hole
Diameter
(in)
8/152019 9:39:53AM Page 4 COMPASS 5000.14 Build 85H
ConocoPhillips
Company:
ConocoPhillips Alaska Inc Kuparuk
Project:
Kuparuk River Unit_I
Reference Site:
Kupawk 1C Pad
Site Error:
0.00 usft
Reference Well:
1C-06
Well Error:
0.00 usft
Reference Wellbore
1C-061-1
Reference Design:
1C-0611_wp02
Reference 1C-06L1_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:
9,400.00 to 13,000.00usft
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 8114/2019
From To
(usft) (usft) Survey (Wellbore) Tool Name
100.00 9,400.00 1C-06(1 C-06) GVD-CT-CMS
9,400.00 13,000.00 1C-06LI_wpO2(1C-061-1) MWD OWSG
Summary
Site Name
Offset Well - Wellbore - Design
Kuparuk 1C Pad
1 C-04 - 1 C-04 - 1 C-04
1 C-04 - 1 C-04 - 1 C-04
1 C-04 - 1 C-04 - 1 C-04
1 C-04 - 1 C -04A- 1 C -04A
1 C-04 - 1 C -04A- 1 C -04A
1 C-04 - 1 C -04A- 1 C -04A
1C-04-1C-04ALl-1C-04ALl
1 C-04 - 1 C-04ALl - 1 C-04ALl
1C-04-1C-04AL1-1C-04ALl
IC -05- IC -05 - 1C-05
1C-05- 1C-05- 1C-05
1 C-05 - 1 C-05 - 1 C-05
1 C-06 - 1 C-06 - 1 C-06
1C-06- 1C-06- 1C-06
1 C-06 - 1 C-06 - 1 C-06
IC -06- 1 C-061-1-01 - 1 C-06L1-01_wp02
1C-06-1C-061.1-02-1C-06LI-02_wp02
1C-07 - 1C-07- 1C-07
1C-07 - 1C-07- 1C-07
1 C-07 - 1 C -07A- 1 C -07A
1 C-07 - 1 C -07A- 1 C -07A
1 C-07 - 1 C-07ALl - 1 C-07AL1
1 C-07 - 1 C-07AL1 - 1 "7ALI
1 C-07 - 1 C-07ALI PBi - 1 C-07ALl PBI
1C-07-1C-07ALI PB1-1C-07ALl PBI
1C-07-1C-07APB1-1C-07APBI
1C-07-1C-07APB1-1C-07APB1
1 C-08 - 1 C-08 - 1 C-08
1 C-08 - 1 C-08 - 1 C -OB
1 C-08 - 1 C-0811 - 1 C-0811
1 C-08 - 1 C-08LI - 1 C-081.1
1 C-08 - 1 C-08LI-01 - 1 C-0811-01
1 C-08 - 1 C-081.1-01 -1 C-0811-01
1C-08 - 1 C-081.1 PBi - 1 C-081-1 PB1
1 C-08 -1 C-081.1 PBi - 1 C-081-1 PBI
8/142019 10:23:36AM
Well 1C-06
1C-06 @ 94.00usft (1C-06)
1 C-06 @ 94.00usft (1 C-06)
True
Minimum Curvature
2.00 sigma
EDT 14 Alaska Production
Offset Datum
ISCWSA
Tray. Cylinder North
Combined Pedal Curve
Added to Error Values
Description
Gyrcdata contcasing m/s
0 WSG MWD - Standard
Reference Offset Distance
Measured Measured Between Between Separation
Depth Depth Centres Ellipses Factor
(usft) (usftl (usftl (usft)
9,425.00
9,425.00
0.00
-65.65
9,449.98
9,450.00
0.61
-69.10
9,700.00
10,025.00
433.44
427.77
10,207.04
10,250.00
119.82
113.63
10,207.04
10,250.00
119.82
113.63
12,800.00
11,321.00
1,222.40
949.91
12,821.68
11,300.00
1,222.64
949.39
Page 2
min ellipse
Warning
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
0.000 STOP Drilling, CC, SF
0.009 STOP Drilling, ES
76.508 CC, ES, SF
19.346 CC, ES, SF
19.346 CC, ES, SF
Out of range
Out of range
4.486 CC
4.474 ES, 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
COMPASS 5000.14 Build 85H
ConocoPhillips
Company:
ConocoPhillips Alaska Inc—Kuparuk
Project:
Kuparuk River Unit -1
Reference Site:
Kuparuk 1C Pad
Site Error:
0.00 usft
Reference Well:
1C-06
Well Error:
0.00 usft
Reference Wellbore
IC -061.1
Reference Design:
iFO6L1_wp02
Summary
Site Name
Offset Well - Wellbore - Design
Kuparuk 1C Pad
10-104 - 1C-104 - 1 C-104
1C-104 - iC-1041-1 - 1C-10411
1 C-104 - 1 C-1041-1 - 1 C-0041-1
1 C-104 - 1 C-104PB1 - 1 C-104PB1
1C-104- 1C-104PB1 - 1C-104PB7
1 C-109 - 1 C-109 - 1C-109
1 C-109 - 1 C-109 - 1 C-109
16109 - 1 C-10911 - 10- 1 09LI
16109 - 1 C-109LI - 1 C-1091-1
1 C-111 - 1 C-111 - 1C-111
1 C-111 - 1C-111 - 1C-111
1C-111 -1 C-111 -1 C-111
1C-117 - 1C-117 - 1C-117
1C-117 - 1C-117 - 1C-117
1C -119 -1C -119-1C-119
1C -119-16119-1C-119
IC -12. 1C-12 - 1C-12
1C-12- 1C-12- 1C-12
IC -121 - 1C-121 - 1C-121
1C-121 - 1C-121 - 1C-121
1C-121 - 1C-121 - 1C-121
1C-123 - 1C-123- 1 C-123
1C-123 - 1C-123- IC-123
1C-123 - 1C-123- 1C-123
1C -13-1613-1C-13
1C-150 - 1 C-150 - 1C-150
1C-150 - 1C-150 -1C-150
IC -151 - 1 C-151 - 1 C-151
IC -152- 1C-152 - 1C-152
16152 - IC -152 - 1C-152
1C-153- 16153 -1 C-153
1C.153 -1 C-153 - 1C-153
1C-154 - 1C-154 - 1C-154
1C-154 - 1C-154 - 1C-154
1C-154 - 1C-154 - 1C-154
1C-155 - 1C-155- 1C-155
1C-155 - 1C-155 - 1C-155
1C -16-1C-16-1616
1C -16 -1C -16-1C-16
1C -16 -1C -06-1C-16
1616 -1C -16-1C-16
IC -170- 1 C-170 - 1C-170
1C-170- 1C-170 - 1C-170
1C-170-1C-170PB1-1C-170PB1
1C-170 - 1C-170PB1 - 1 C-170PB1
1C-172 - IC -172- 1C-172
1C-172 - 1C-172- 1C-172
1C-172 - 1C -172A- 1 C -172A
IC -172 - 1 C-172AL1 - 1 C-172AL1
1C-172 - 1 C-172AL2 - 1 C-172AL2
IC -172 - 1 C-172AL2PB1 - 16172AL2PB1
IC -172 - 16172AL2PB2 - 16172AL2PB2
ConocoPhillips
Anticollision Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1C-06
1 C-06 @ 94.00usft (1 C-06)
IC -06 @ 94.O0usft (1C-06)
True
Minimum Curvature
2.00 sigma
EDT 14 Alaska Production
Offset Datum
Reference Offset Distance
Measured Measured Between Between Separation Warning
Depth Depth Centres Ellipses Factor
(usft) (usft) (usft) (usft)
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
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
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
81142019 10:23:36AM Page 3 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-061_1
Reference Design:
1C-06Ll_wp02
ConocoPhillips
Anticollision Report
Local Coordinate Reference:
Well iC-06
TVD Reference:
1C -o6 @ 94.00usft (1C-06)
MD Reference:
1C-06 @ 94,00usft (1 C-06)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Output errors are at
2.00 sigma
Database:
EDT 14 Alaska Production
Offset TVD Reference:
Offset Datum
Summary
Kuparuk
lC Pad-
1C -O6 -1C -O6 -1C -O6
Reference
Offset
Distance
Survey Program:
100-Gy0.0ROM5
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
Kuparuk 1C Pad
Distance
Measured
1 C-174 - 1 C-174 - 1C-174
Measured
Vertical
Reference
Offset
Out of range
1 C-18 - 1 C-18 - 1 CA 8
Centre
Between
Between
Minimum
Out of range
I C-18 - 1 C-18 - 1 C-18
Depth
Depth
Depth
Out of range
IC-19-iC-19-1C-19
9,680.00
9,650.00
1,074.67
817.78
4.183 CC
IC-19-iC-19-1C-19
9,680.00
9,650.00
1,074.67
852.53
4.838 CC
1C -19 -1C -19-1C-19
9,680.00
9,650.00
1,074.67
817.78
4.183 CC
1C -19 -1C -19-1C-19
9,684.80
9,725.00
1,075.56
851.80
4.807 ES
1C -19 -1C -19-1C-19
9,690.00
9,750.00
1,076.31
816.62
4.145 ES,SF
1C -19 -1C -19-1C-19
9,690.00
9,750.00
1,076.31
851.84
4.795 SF
1C-19-1C-19-iC-19
9,690.00
9,750.00
1,076.31
816.62
4.145 ES,SF
1C -19 -1C -191_1-1C-191-1
9,680.00
9,650.00
1,074.67
803.47
3.963 CC
1C -19 -1C -191-1-1C-191-1
9,680.00
9,650.00
1,074.67
803.47
3.963 CC
1C-19 - 1C-191_1 - 1C-191-1
9,690.00
9,750.00
1,076.31
802.09
3.925 ES,SF
1C -19 -1C -191_1-1C-191-1
9,690.00
9,750.00
1,076.31
802.09
3.925 ES, SF
Plan: 1 C-156 - Plan: 1 C-156 - 1 C-156wp07
3.16212
0.61
_69.10
69.71
Out of range
Plan: 1 C-158 - Plana C-158 - 1 C-158wp02
6.555.94
9,475.00
5559.06
0.68
Out of range
Plan: 1 C-158 - PIan:1 C-158 - 1 C-158wp02
5,349.88
3,1T,65
3.60
-0.02
Out of range
Prelim: 1C-157- Plan: IC -157- 1 C-157wpO6
9,474.49
6,555.94
8,475.00
6.559.00
Out of range
Prelim: 1 C-157 - Plan: 1 C-157 - 1 C-157wpO6
-127.69
5,369.88
3.177.65
3.60
Out of range
Offset Design
Kuparuk
lC Pad-
1C -O6 -1C -O6 -1C -O6
onset shat Icor. 0.00 do
Survey Program:
100-Gy0.0ROM5
Offset WMI Error. 0 00 usll
Reference
Offset
hemi Major
Axis
Distance
Measured
Vertical
Measured
Vertical
Reference
Offset
AaimNb
Offset Wellbore
Centre
Between
Between
Minimum
separation blaming
Depth
Depth
Depth
Depth
from North
-NIS
-EI-W
Centres
Ellipses
Separation
Factor
Part
(usnl
lusin
(usft)
)usft)
(usft)
V)
(usft)
(ugh)
rysRl
pil
)usft)
9,42500
6,524.73
9425.99
6,524.73
6.55
028
3164
5,330.67
3,14672
0.00
-269
2.90
0.000 STOP Drilling
9,425.00
6.52473
942500
6,524.73
82.93
02.94
3164
5,330.67
3.148.72
0.00
6565
6565
0.000 STOP Drilling, CC, SF
9,449.98
5541.42
9,450.00
8,541.89
066
0.55
-128.49
5.340.35
3,162.12
0.61
-3.39
4.00
0.153 STOP Drilling
9.449.98
6.54142
9,450.00
6,541.89
82.98
03.18
-128.49
5.340.35
3.16212
0.61
_69.10
69.71
0.009 STOP Drilling, ES
9.474.49
6.555.94
9,475.00
5559.06
0.68
0.93
.127.69
5,349.88
3,1T,65
3.60
-0.02
162
0,994 STOP Drilling
9,474.49
6,555.94
8,475.00
6.559.00
83.00
03.42
-127.69
5,369.88
3.177.65
3.60
63.00
86.80
0.054 STOP Drilling
9,497.33
6,566.24
9.500.00
6.576.07
0.69
1.10
-126.74
5,359.25
3,193.33
10.63
7.89
2.74
3.874
9,497.33
6,566.24
@500.00
6.5715.07
03.02
83.66
-IM.74
5,359.25
3,193.33
10.63
-51.34
61.97
0.172 STOP Drilling
9517.58
6,572.43
9525.00
8,593.14
0.70
1.38
-125.92
5,368.58
3,209.03
21.34
1992
2.02
10.560
9.517.58
5572.43
9,525.00
6,593.14
83.04
aide
-125.92
5368.58
3.209.03
21.34
-36.03
57.37
0.372 STOP Drilling
9,534.91
6,575.40
9.550.00
5610.25
0.71
1.66
-125.14
5,378.02
3,224.62
35.10
31.88
3.21
10.921
9,534.91
6.575.40
9550.00
6.610.25
83.07
84.13
-125.14
5,378.02
3,224.62
35.10
-18.34
53.43
0.657 STOP Drilling
9,55000
6.57622
9575.00
6,627.40
0.73
1.93
-124.53
5,307.55
3,240.11
51.22
47.43
3.80
13.492
9,550.00
6,576.22
957500
5,69.40
83.10
84.37
-124.53
5,387.55
3,240.11
5122
0.57
Sass
1,011 Take Immediate Action
9.56347
6,575.67
9,600.00
6,844.59
0.74
2.21
-19.07
5.397.18
3.255.50
69.06
64.91
4.16
16.619
9,56147
6.575.67
9.600.00
6.644.59
83.13
84.61
12707
5,307.18
3,255.50
Saw
20.20
48.87
1.413 Take Immediate Action
9,579.24
6.574.71
9.62500
6,661.84
0.77
2.48
13468
5,406.07
3,270.79
87.45
83.18
4.27
20.473
9,579.24
6.574.71
8.81
6,661.84
83.16
04.85
-134.88
5,408.07
3,270.79
87.45
38.22
49.23
1.776 Caution Monitor Closely
9.594.06
6.573.67
9,650.00
6.679.16
0.81
2.75
-143.02
5.416.56
3.285.90
106.20
101.78
4.42
24.021
9.594.06
6,573.67
9.650.00
6,679.16
83.19
65.09
143.02
5.416.56
3.285.98
106.20
55.90
50.30
2.111 Caution Monitor Closely
9,607.71
6.572.62
9.675.00
6.696.57
0.85
3.03
-150.96
5,426.27
3,301.08
125.36
120.78
4.59
27.333
9,607.71
6.57262
9.675.00
6.696.57
83.23
85.33
-150sl
5,426.27
3.301.08
125.36
73.49
51.07
2.417 Caution Mondor Closely
9.620.00
6,571.60
9,700.00
6.71405
0.00
330
-15095
5.435.99
3,316.07
W99
140.23
4.75
MASS
9.820.00
5571.80
9,700.00
6)14.05
8326
85.57
-158.35
5,435.99
3,316.07
144.99
91.27
53.72
2.699 Normal Operations
9,831.21
6.570.62
9.725.00
6.731.60
090
3.57
-165.28
5445.65
133103
16508
160.17
4.91
33,620
CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
8/142019 10:23:36AM Page 4 COMPASS 5000.14 Build 85H
WELL DETAILS: 1C-06 - -
1015o Paraa TD at 1430000 {�
+N/ -S +E1 -W Northig@ Easting Latitude Longitude 6114 61-1IC 0 - _ rDPd 6Oe Ienllmax
0.00 0.00 5968860.00 561864.00 70' 19'31.647 N 149° 29154.042 W 9800
_ IC 064
seeInc I + - Wag ace a Annotation I rD an 3900 o0:
1 9400.00 46.50 56.85 6413.54 5320.83 3131.47 0.00 0.00 2159. 4 TIP 9450 - -- -- -- -- -------- - -To
1(2_0611(7-06U-02
2 9430.00 46.64 57.64 6434.17 5332.61 3149.79 1.97 76.56 2175. 4 KOP
3 9459.00 51.86 57.64 6453.09 5344.37 3166.34 18.00 0.00 2792.6 Start Build 42.00 9100- -
I
Stai DLS 100 TF Bo
4 9556.95 93.00 57.64 6482.03 5393.28 3245.54 42.00 0.00 2259. 9 Start DLS 42.00 TFO -115.00 i
s ,a DLS oo TF 35,0 Sun LS o 00 rra -Ino
5 9775.00 94.91 325.79 6462.69 5583.79 3285.28 42.00 -85.00 2265. 6 Start DLS 7.00 TFO -811.00 875oj --- -- - - --- "
6 10175.00 95.27 297.68 6426.48 5846.35 2991.02 7.00 -88.00 1930. 7 Start DLS 7.00 TFO -1 0.00 ._ i 1 °
7 10575.00 90.00 270.14 6407.75 5941.28 2606.99 7.00 -100.00 1535. 9 Stall DLS 7.00 TF011 .00 8400' P
8 10800.00 83.41 284.48 6420.75 5969.69 2384.88 7.00 115.00 1312.3 Start DLS 7.00 TFO 7 00 3 Swn X S 7 00 T1�0 10YAD sun DLS 7 oo TFo -60.
0
9 11050.00 89.58 300.90 6436.13 6065.67 2155.61 7.00 70.00 1069. 7 Start DLS 7.00 TF0.6.00 8050 + ,Sian DLS 00 TF 90 oq 51.rx 700 FO 00
10 11300.00 98.24 285.64 6418.98 6163.97 1927.45 7.00 -60.00 827.0 Start DLS 7.00 TFO -1 7.00
11 11700.00 85.16 260.82 6406.93 6185.97 1532.21 7.00 -117.00 434. 5 Start DLS 7.00 TFO 8 noa
00 t Do° 1170 s oo
12 12100.00 90.39 288.36 6422.75 6217.80 1137.78 7.00 80.00 40. 8 Start DLS 7.00 TFO 35.00 z Plan, d TD at 1 001 sun n15 i oo rFO -100
---
13 12200.00 96.12 292.39 6417.08 6252.52 1044.24 7.00 35.00 -57.7 Stan C 7350'
DLS 7.00 TFO -1 5.00 o -' - '-
14 12550.00 89.44 268.77 6399.86 6316.02 703.19 7.00 -105.00 404. 6 Start DLS 7.00 TFO 9 00 F; l ` sun D1s roo TFo -ss.° .
15 13000.00 89.52 300.28 6404.05 6427.46 273.05 7.00 90.00 -847. 1 Planned TD at 130001 D 7000
Sian IRS 4200 TEO 850
0 6650 - ...... .
0 1 -0611 06L 1fA /1C 0
6300Sam Bu d42.0
P
F
Mean
IC OSLI_T03IC-061-1 701
IC -0611 902 IC -06 CII) Pa�vgon Donn
R
West( -)/East(+) (350 usft/in)
Vertical Section at 100.00° (150 usft/in)
I
Protect: Kupamk River Unit_1
Wei Kupamk lC Pad
M.a°.,m xmn tsa
aee�r�=ne°
WELLBORE DETAILS: 1C-0611
REFERENCE INFORMATION
Parent Wellbore: 14-06
Rela. wansaaa..I uom
c>%u.1
Well: iC-06
Tie on MD: 9400.00
DD)
VaMNa(N01 Rekrerae: Meen see revel
seaoon Rekrercx. sgl.rymx, 8roE7
r�
ComxoPhillips
Wellbore: 1C481-1
Plan:
op aryl¢: W 8a�
c
rysl
Manual NR kr l o Bwao m(ICael
10-06L1_wp9t(1C-06I1C-061-1)
Mace mi
_.
CeWeBm FkVad'. Menus Cu,aa.
WELL DETAILS: 1C-06 - -
1015o Paraa TD at 1430000 {�
+N/ -S +E1 -W Northig@ Easting Latitude Longitude 6114 61-1IC 0 - _ rDPd 6Oe Ienllmax
0.00 0.00 5968860.00 561864.00 70' 19'31.647 N 149° 29154.042 W 9800
_ IC 064
seeInc I + - Wag ace a Annotation I rD an 3900 o0:
1 9400.00 46.50 56.85 6413.54 5320.83 3131.47 0.00 0.00 2159. 4 TIP 9450 - -- -- -- -- -------- - -To
1(2_0611(7-06U-02
2 9430.00 46.64 57.64 6434.17 5332.61 3149.79 1.97 76.56 2175. 4 KOP
3 9459.00 51.86 57.64 6453.09 5344.37 3166.34 18.00 0.00 2792.6 Start Build 42.00 9100- -
I
Stai DLS 100 TF Bo
4 9556.95 93.00 57.64 6482.03 5393.28 3245.54 42.00 0.00 2259. 9 Start DLS 42.00 TFO -115.00 i
s ,a DLS oo TF 35,0 Sun LS o 00 rra -Ino
5 9775.00 94.91 325.79 6462.69 5583.79 3285.28 42.00 -85.00 2265. 6 Start DLS 7.00 TFO -811.00 875oj --- -- - - --- "
6 10175.00 95.27 297.68 6426.48 5846.35 2991.02 7.00 -88.00 1930. 7 Start DLS 7.00 TFO -1 0.00 ._ i 1 °
7 10575.00 90.00 270.14 6407.75 5941.28 2606.99 7.00 -100.00 1535. 9 Stall DLS 7.00 TF011 .00 8400' P
8 10800.00 83.41 284.48 6420.75 5969.69 2384.88 7.00 115.00 1312.3 Start DLS 7.00 TFO 7 00 3 Swn X S 7 00 T1�0 10YAD sun DLS 7 oo TFo -60.
0
9 11050.00 89.58 300.90 6436.13 6065.67 2155.61 7.00 70.00 1069. 7 Start DLS 7.00 TF0.6.00 8050 + ,Sian DLS 00 TF 90 oq 51.rx 700 FO 00
10 11300.00 98.24 285.64 6418.98 6163.97 1927.45 7.00 -60.00 827.0 Start DLS 7.00 TFO -1 7.00
11 11700.00 85.16 260.82 6406.93 6185.97 1532.21 7.00 -117.00 434. 5 Start DLS 7.00 TFO 8 noa
00 t Do° 1170 s oo
12 12100.00 90.39 288.36 6422.75 6217.80 1137.78 7.00 80.00 40. 8 Start DLS 7.00 TFO 35.00 z Plan, d TD at 1 001 sun n15 i oo rFO -100
---
13 12200.00 96.12 292.39 6417.08 6252.52 1044.24 7.00 35.00 -57.7 Stan C 7350'
DLS 7.00 TFO -1 5.00 o -' - '-
14 12550.00 89.44 268.77 6399.86 6316.02 703.19 7.00 -105.00 404. 6 Start DLS 7.00 TFO 9 00 F; l ` sun D1s roo TFo -ss.° .
15 13000.00 89.52 300.28 6404.05 6427.46 273.05 7.00 90.00 -847. 1 Planned TD at 130001 D 7000
Sian IRS 4200 TEO 850
0 6650 - ...... .
0 1 -0611 06L 1fA /1C 0
6300Sam Bu d42.0
P
F
Mean
IC OSLI_T03IC-061-1 701
IC -0611 902 IC -06 CII) Pa�vgon Donn
R
West( -)/East(+) (350 usft/in)
Vertical Section at 100.00° (150 usft/in)
I
ConocoPhillips
Project: Kuparuk Ritter Unit 1
Site: Kupal IC Pad
IEmW¢b*ry. neon
M. -re -.1m'. `t I,
WELLBORE DETAILS 1C-061.1
REFERENCE INFORM411ON
CoaSreu lWf1 RNe�mn. wn +ca. T. xwln
Well: 1C-68
Ca9re�.F.b
see,ym.5]t09.]s�i
Parent Wellbore: iC-O6
Veniosl Mol Rele�erm:lCm®940WrnIfCml
w>mee. eo.es'
Tie on MD:9400:00
sxtion lv6l gMNca: Shl-lomx, o.00E7
Wellbore: iC-061.7
tCO6piI OCmI
Mmwiee*��
Plan: IC-061.1_wp02 (1C -06/1C-061.1)
x � ci�i
C4 N
wrocl mintrilljrri
JER
ES
IN-10i11141ef1 z, nl-IN4/IfI-IOM1I
1��17
41110
T
— -- — +�
13%1
12j00� IS�h
r
iv-uuc nC�ni
11500, ✓` _._ L _ _' ._._ ,.-__
x ✓nr Irl ♦ 1 t dKitic 11-03 lm U'/ c19LI
w 1 all -r
x'10000 _. 4pn -
3 i-ly er-hI io wey 'esq- I
9500 .1..
+ 9000
t LI I(I+
pR500"d--
IIn L+,
O 7500 _
I
651 10
6000.,
10 U, - 1
00
4sno- r, lea>u: .
-ir.e.ac.ru
3500 � 1
-5000 1500 4000 4500 -31100 -2500 -2000 -1500 -1000 -500 0 5110 1000 1500 2000 2500 3000 35W 4000 4500 5000 5500 6000 6500 7000 7500 8000 NJpi liti, Komi 11 II m Ilil:O
West( -)/East(+) (500 usft/in)
1C-06 ® 94.00ustl (iC-06)
AM A KUP INJ WELLNAME 1C-06 WELLBORE 1C_06
�0��'I�M
1�"
Naska.lfn.
Well Attributes Max Angle&MD TD
mDlnxal .tel elm (nxal
Freie rvama wNm,e apuuva wellm,alaw: !Vex
KUPARUK RIVER UNIT WO2920564W INJ 8.00 6,200.00 102630
SSSV: TROP x95 (pMal
Let. K.Op1h1 Valliant
Dale An La am O In
I Cm. m 1 M! 9!139'. 55 AM
Last Tag
Vareve ,amnlaumull
Annohlion Depin rarer En e oaM VhNMre LasLMoe By
-
HANCEB �e�
c0.VOucT.Bl3x.os5o
sAFETy KQ 29318
sunFACE', 31.1119.9-
OA511FT. 9019.8
PBP: 9.135.5
PACKER; 41515
NIPPLE, 41a3P
OVERSHOT; 8.3318
SBXi&Na.3
PACKeai ¢ms
NIPPLE.9,.a
PM:94fO69.Ja50�
FUM1: 1. a
PRODJCTION:]8.61923i9
J;
Last Tag: RKB 9,788.0 ]/8/2019 1C-06 no
Last Rev Reason
Mnablion End lane AMIIMrt WtMo1 By
BE, Reason Tag A.,a 1CAfi ferguep
Casing Strings -
ea:ine Description DD lln m(n) Top (nKSI semepm (nMe ser oepm lTVDL-wWen(1, Grade
CONDUCTOR 16 15.06 32.0 65.0 fi50 62.58 H-00
TopThread
WELDED
,ging Dea Mon ODIinI ID (n Tap IM1KBI Se[neplM1 (nKB) $N OepIM1 jNpI.. WY(m(I... Grave
SURFACE 10214 9.95 31.3 3.287.0 2.685.1 45.50 K55
Top inreatl
BUTT
Canne Oesiolon 0rTion ID fin) Terpeak, SN Di unk, Set event nW1...-P 11... Omee
PRODUCTION 7 6.28 29.6 10,225.8 7,090.1 26.00 KS5
Top 11 -in
BTC
Tubing Strings -
nxiay or. -prix„ snide Ma... to llnl Top lake) $el oapm (n...e oepm (Tv" b.. wllmml Grade Top Connxl-
TUBING 2001 W0 31/2 299 269 9,2329 6,3825 9.30 L-00 Bur
Completion Details
Top(I.) Topmol Nomura
Top IXKBI trust rI nem Dea Lour mpn)
26.9 26.9 0.00 HANGER FMC Tubing HANGER 3.500
2,237.6 2,0210 43.75 SAFETYVLV 3.S TRMAKX-SE Safely Vaive(Serial 4 HYS-]03) 2.812
9,135.5 6.313.4 39.06 PBR Baker PBR sear arearn y(pinned 40M4) W1239s4aceoul 3 N
9,1515 sn5.8 3954 PACKER Baker FHL Pecker (pinned 60MN shear) 3.000
9,193.2 6,357.6 4079 NIPPLE 2.81 W X Nipple 2.813
9,231.9 6,386,7 41.60 OVERSHOT Baker Tubing Stub Overshot I )'space out 3610
T.Ling Oeacnplion ranine la. -ID 11n) Top IXKB) SN ho 51, (M1. $R Oepix (TWIT... w111bYg Grave Top Connection
TUBING 1993WO 53/4 4.37 9.2322 9.281 66236
Completion Details
mplNol mp urn
Top@Ke) (nee) (•I
Nem De;
Lour
e,
NV ial
92552 6,4040 42.38
SBR
BAKER EL -1 SUN (no lull joint, TBG string snowing SBR ODdD)
4.3]5
Tutinp Deecnplian
TUBING Original
Stn np Ma.. u-ur) Tap IT) Set Dep1n 1X.. 5e1 DepIn INO I� V.x 11Nh G,atle iop Gonneclan
3112 299 9,281.5 9,387.2 6498.] 9.20 K-55 BTC
Completion Dotal
s
Top1TVDI Tap lr,cl Nominal
Top XKBI IhKBI (') Nem Oc C00 1011nI
1
9281.5 662 43. d PACKER BAKER THE PACKER 3.1100
9.349.3 64].1 44.9 M1111 CAMCO D NIPPLE NO GO 2751)
9,380.9 6,494.3 45.93 SOS "Ire,
Other In Hole (Windings retrievable plugs, valves, pumps, fish, etc.)
iop (nKB
Toplrvo Top and
(hKBI 1'l Des Lom Run Oale ID fiat
I 0A269
6,946.4 44.00 FisM1 Vann Gun Leh from original ped. 10V long 392511981
Perforations & Slots
TOP IRHeI
BIm IXKBI
Top(ND)
MNBI
dun (Tool
IIMBI
Ureeni
Oah
saw
Den
I+naMe
1
TyR
Cwn
9,4100
9,485.0
6,514.0
6, 5.8
UNIT O,C<, C-
3, ICA6
1/ 1
1 .0
Mandrel Inserts
s1
au
N Tpp1M1KB)
Tcp (TVpI
IfMBI
Meka
Mdbl
Oe pn)
5ery
Vere
Typ
Tga.
Typa
Pon -'E
(lnl
TRORen
IMl
flan DeM
Cem
11 9,019.2
6,269.2
Camco
MIMP I
1(1
GAS LIFT
DMY
BK
0.000
0.0
111112001
Notes: General & Safety
end Dme Amomaion
1123/1993 NOTE. WORKOVER
d/212009 NOTE WAIVEREDWEL- T x IA COMMUNICATION
12282010 INU TE VIEW SCHEMATIC w/Naek, Schernic9.0
IC -0a,
Using
TWOCSand
op of Cement
Topof Cement
Topof UnserR
Cement Operatmns
well ft.
Sawas
She
dl ool(MD
MD
(TVUSS
Isawn"lnetl
Reservoir Salus
Zonal lsola8on
Svmma
Integrity
SC -06
Injector open to only C -Send
MITA passed @300D pd 7/26/19
Mothertwre
Shut -In
7-
9411'
5225'
3680'
Log
through perfration.
Packer at 9292' and TOC at 5225'
535 sx Gass G cement
MUOA peand @3800 7/26/19
IC -07A
Producer open only to C -Sand
Mothertxee prforationscement
MITOApa.d@3800psi5/9/14
(1C-07
1�21'
through CTD sidetrack completed
squeezed. Packer at 8546'and TOC
CMIT-TilA passed@2500 psi 3/30/09
Motherttore
ProduG
T
8859'
3100'
2517'
WE
with slotted liner,
AMY
a50sx Class G cement
TIFLNosed! 8/6/16
Producer open only a C -Sand
through motherhpre perforations
ant CTD sidetrack completed
MITIA passed @2750 psl 9/7/17
IC.19&IC-IRIlProdudng
7"
10,144'
6459'
9281'
5800'
Log
with dotted liner.
Packerst10,035'and TOCat9281'
2Msx ClanGcement
MITOAailet5/28/07
Proposed CTD Schematic
16" 65# H40 shoe
@ 65' MD
10-3/4" 46# K-55
shoe 3287' MD
@
C -sand peels
9410' - 9485' MD
7" 26# K-55 shoe @
10,226' MD
Modified by SIG 8/20/19
3-1/2" TRMAXX-5E SSSV @ 2238' MD
3-1/2" 9.3#L-80 EUE 8rd Tubing to surface
3-1/2" Camco MMG gas lift mandrel @ 9079'
Baker 3-1/2" PBR @ 91 36'MD (3.0" ID)
Baker FHL packer @ 91 52'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-061-1-02 wp02
TD - 13,900' MD
Liner top - 9320' MD
iC-0611.01 wp02
TD - 14,300' MD
Billet/Liner top -11,250' MD
0' MD
top - 9900' MD
Loepp, Victoria T (CED)
From: Loepp, Victoria T (CED)
Sent: Monday, September 9, 2019 5:19 PM
To: Germann, Shane
Subject: Re: PTD's for KRU 1C-06 Laterals
They're in process. Not much lead time on these permits.
Sent from my Phone
On Sep 9, 2019, at 2:59 PM, Germann, Shane <Shane.Germanngconocophillips.com> wrote:
Victoria,
I'm checking in to see what the status is for the PTD's for the KRU 1C-06 laterals (iC-061-1, U-01, & Ll -
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
ConocoPhillips Alaska
Office: 907-263-4597
Cell: 406-670-1939
700 G St, ATO 664, Anchorage, AK 99501
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,-L1-01,-L1-02(PTD 219-117,219-118,219-119) 1/4 mile AOR
Shane,
Please send a well plat showing the X 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)
(� L
Plat 1: Wells within .5 miles i;� X �j M
ASRC-NPR7 �-\
i
ASRRC-
ASRC-NPR3
AA092347
' > AA087888
i m
'o
iU
S
AA081817 '
/ ASRC-AA092344
ConocoPhillips
AUska
a FW Pours
OHSI We Frac Pon Buhr
QHNf Aldo Well Trerk 80
Y1Ma wdm Track Me!
— Well Tray.
I i P open Inlerrs
Alplrle PA
L _ i 11n1 Boundary
O CPAI Lease
ASRC-NPR!
CD5-98 N AA081817 t I
Lease Plat { 0 02 04 0.e 0.8 1
m Miles
2
W
Fracture Stimulation Area of Review
Top of A Sen!
Cement Operm4orts
Top of A I" 1
Top aI Cement
Top WCemm1
1o0 of Cemenl
Msen04 Stales
tonal Itela40n
Mn60niraf InlPBnty
fATUS
csr s W.0.1 04 i.
OA POW (MDQ
(MD) i
IND55)
Wtermi•tt0 Ry
Smftrn•ry
I INDSS) �.
IN.!'D187
7,W) '
6,S8Y
v Ie:
'+< opn falx Mer ly •ynean
IDC 6.585' L Maur @ 8.119'
18h. of IS8pP8mUc
i
3sw¢
pei4r<t ste0 to .iw
ONE
7 -SW
91Y
rement
],659'
71!50
1801
kH aan'r'<�r.era
1IX 31 lSQ b Pwrfr @ 37. Aa•
penwr tntw to l�
CINE
1SA'
IS,bN'
az �,t8m'u4n
- ---�—
— — _ —� —1<t6Ow
611. .112 1oee Nx G
1/25M.
7518'
9.055 I ?.SIS
6.655
6.511
kL
! open 1p:e Lr�erfm:Realmn
TOC 6.6$S' L Maur ba 7.M
cemem b 101no1156ctau
Orcsswe 4stW lu7.5001
ACTIVE
C; <rmrm
wta, SO mmt
From:
Germano, Shane
To:
Dover. David L (CED)
Subject:
RE: [ExTERNAL]PTD"s for KRU 1C-06 Laterals
Date:
Wednesday, September 4, 2019 1:32:30 PM
Attachments:
1C-06 CTD Well Plans xlsx
Hi Dave,
I attached the well plan surveys for each lateral in the excel file. There is a tab for each lateral. We
don't have any plans to preproduce this one. Let me know if you need anything else.
Thanks,
Shane Germann
Coiled Tubing Drilling Engineer
Conoc.oPhlllips Alaska
Office: 907-263-4597
Cell: 406-670-1939
700 G 5t, ATO 664, Anchorage, AK 99501
From: Boyer, David L (CED) <david.boyer2@alaska.gov>
Sent: Wednesday, September 4, 2019 12:48 PM
To: Germann, Shane <Shane.Germann@conocophillips.com>
Subject: [EXTERNAL]PTD's for KRU 1C-06 Laterals
Hi Shane,
Can you please e-mail over the well package digital survey files for the 3 laterals to be drilled from
KRU 1C-06 mother -bore in Excel or ASCII format? Also, we need to know if these injectors will be
preproduced and if so, for how long?
Thank you,
Dave Boyer
AOGCC
Transform Point. 06 x
L. �
Source coordinate system Target coordinate system
State Plane 1927 Alaska Zone 4 Albers Equal Area (-1541
Datum: Datum:
NAD 1927 - North America Datum of 1927 (Mean) NAD 1927- North America Datum of 1927 (Mean)
I Easting I Now
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Type values into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd.0 to
copy and Ctrl+Vto paste. Then click on the appropriate anon button to transform the points to the desired coordinate system.
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Back Finish Cancel Help�i
TRANSMITTAL LETTER CHECKLIST
WELL NAME: 1 C— 06 L 1
PTD: D�' 6 9 - 1 1 z--
Development ✓Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: K u K R- p - POOL: L1 Ll m n c, u ' GC `I V2 K o i .I
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. J$1 — O2 S, API No. 50- 024 tf-00 -O C7•
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50-_-
from records, data and logs acquired for well
name on permit .
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be 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
I
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
vcomposite
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:.KUPABUKRIV� AC_ 61-1 Program SER Well bore seg
PTD#: 2191170 Company ConocoPhills Alaska Inc Initial Class/Type
SER/PEND GeoArea 890 Unit 11150 _ On/Off Shore On Annular Disposal
Administration
1
Permit fee attached_
NA
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I2
_
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. pian 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 9/4/2019
_ _ _ _ _ . . . . .................-
14
Well located within area and strata authorized by Injection Order # (put. IO# 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 preproduced per eriocoPhillips. . . . . . . . . . . . . . . ................. .
17
Nonconven. gas conforms to AS31,05.030([J.A),lj.2.A-D) - - - - - - - - - - - - -
NA- _
_ _ _ _ _ . - _ ...............
- -
18
Conductor string. provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ -
NA- -
- - _ _ - Conductor set for. KRU 1C-05 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ______________
Engineering
19
Surface.casing protects all known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -
NA
Surface casing set for KRU 10706. _ - - _ _ _ .....
20
CMT, vol adequate. to circulate on conductor & surf csg _ _ _ _ _ _ _ _ - _ _ _ _ _
NA
Surface casing set and fully cemented _ _ _ _ _ ..............
21
CMT-vol adequate to tie-in long string to surf csg - - - - - - - - ........
NA
22
CMT will cover all known productive horizons _ _ _ - _ _ _ _ . . . . .........
No
- Productive. interval will be completed withuncementedslotted liner
23
Casing designs adequate for C, T, B &. permafrost. ..... . .........
Yes
24
Adequate tankage. or reserve pit _ - _ _ _ _ _ _ - ......... ..... .
Yes
Rig has steel tanks; all waste-t0 approved disposal wells
25
If ate-drill, has.a 10-403 for abandonment been approved - - _ _ ..
NA.
26
Adequate wellbore separation proposed .. _ _ _ _ - - - _ - - - -
Yes
_ _ Anti-collision analysis complete; no major risk failures - . . . ..........
27
if diverfef required, does it meet. regulations _ _ _ _ _ _ _ _
NA
Appr Date
28
Drilling fluidprogramschematic & equip list adequate- - - _ _ _ _ _ _
Yes
Max formation pressure is 3888 psig(11.9 ppg EMW ); will driltw/ 8,6. ppg EMW and maintain overbal w/ MPD
VTL 9/10/2019
29
BOPEs, do they meet regulation - - - - - - - - _
Yes
30
.BOPE_press rating appropriate; test to -(put psig in comments)_ _
Yes
Max formation. pressure is 3235 psig; will test BOPS to 3500 psig____
31
Choke manifold complies w/API. RP-53 (May 84).... _
Yes
32
Work will occur without operation shutdown. . . . . . ......... . . . . . . . .
Yes
33
Is presence of 112S gas probable _ .. _
Yes
_ 112S measures required......
34
35
Mechanical condition of wells within AOR verified (For service well only) _ _ .. _ - _
Permit. can be issued w/o hydrogen sulfide measures ....................
Yes _
No..
- _ _ - - - 1C-07A, 1C-19,-1C-191-1 and-1C-111-2-02; mach integdty verified-
_ _ _ Wells-on-1C-Pad are 112S-bearing, H2$ measures required..
Geology
36
Datapresentedon potential overpressure zones _ _ - - _ - - - _ - _ _
Yes _
_ - _ _ - . .............. ... .
Appr Date
37
Seismic analysis of shallow gas. zones__ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA- -
- - _ _
DLB 9/4/2019
38
Seabed condition survey(ifoff-shore) _ _ ___________ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA-
39
Contact name/phone for weekly.progress reporfa.[exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA- -
W
Geologic
Engineering
Public
Commissioner:
Date :
Commissioner:
Date Commissioner Date
om
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