Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout218-080DATA SUBMITTAL COMPLIANCE REPORT
1/18/2019
Permit to Drill 2180800 Well Name/No. KUPARUK RIV UNIT 1H-21AL2-01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22355-62-00
MD 10910 TVD 6757 Completion Date 9/14/2018 Completion Status 1-0I1- Current Status 1 -OIL UIC No
REQUIRED INFORMATION
Mud Log Nov/ Samples No ✓ Directional Survey Yes
DATA INFORMATION
List of
Logs Obtained:
GR/Res
Well Log
Information:
Logi
GAMMA RES.las
Electr
Data
Digital
Dataset
Type
Med/Frmt
Number Name
ED
C
29764 Digital Data
ED
C
29764 Digital Data
ED
C
29764 Digital Data
ED
C
29764 Digital Data
ED
C
29764 Digital Data
ED
C
29764 Digital Data
ED
C
29764 Digital Data
ED
C
29764 Digital Data
ED
C
29764 Digital Data
ED
C
29764 Digital Data
ED C 29764 Digital Data
ED C 29764 Digital Data
ED C 29764 Digital Data
ED C 29764 Digital Data
ED C 29764 Digital Data
ED C 29764 Digital Data
ED C 29764 Digital Data
ED C 29764 Digital Data
Log Log Run Interval
Scale Media No Start S1
7530 10910
(from Master Well Data/Logs)
ON/
CH Received
Comments
10/8/2018
Electronic Data Set, Filename: 1H-21AL2-01
GAMMA RES.las
10/8/2018
Electronic File: 1H-21AL2-01 21VID Final.cgm
10/8/2018
Electronic File: 1H-21AL2.01 5MD Final.cgm
10/8/2018
Electronic File: 1H-21AL2-01 5TVDSS Final.cgm
10/8/2018
Electronic File: 1H-21AL2-01 21VID Final.pdf
10/8/2018
Electronic File: 1H-21AL2-01 5MD Final.pdf
10/8/2018
Electronic File: 1H-21AL2-01 5TVDSS Final.pdf
10/8/2018
Electronic File: 1H-21 AL2 -01 EOW - NAD27.pdf
10/8/2018
Electronic File: 1H-21AL2-01 EOW - NAD27.bd
10/8/2018
Electronic File: 1 H-21AL2-01 Final Surveys TD
10910.csv
10/8/2018
Electronic File: 1H-21AL2-01 Final Surveys TD
10910.xlsx
10/8/2018
Electronic File: 1H-21AL2-01 Survey Listing.txt
10/8/2018
Electronic File: 1H-21AL2-01 Surveys.txt
10/8/2018
Electronic File: 1H-21AL2-
01_25_tapescan_BHI_CTKbd
10/8/2018
Electronic File: 1H-21AL2-
01 _5_tapesca n_B H I_CT K. txt
10/8/2018
Electronic File: 1H-21AL2-01_output.tap
10/8/2018
Electronic File: 1H-21AL2-01 2MD Final.tif
10/8/2018
Electronic File: 1H-21AL2-01 51VID Final.tif
AOGCC Page 1 of 3 Friday, January 18, 2019
DATA SUBMITTAL COMPLIANCE REPORT
1/18/2019
Permit to Drill 2180800 Well Name/No. KUPARUK RIV UNIT 1H-21AL2-01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-22355-62-00
MD 10910 TVD 6757 Completion Date 9/14/2018
ED
C
29764 Digital Data
Log
C
29764 Log Header Scans
ED
C
29788 Digital Data
ED
C
29788 Digital Data
ED
C
29788 Digital Data
ED
C
29788 Digital Data
Log
C
29788 Log Header Scans
Well Cores/Samples Information
Name
INFORMATION RECEIVED
Completion Report Yr
Production Test Information Y /
Geologic Markers/Tops /9
COMPLIANCE HISTORY
Completion Date: 9/14/2018
Release Date: 7/5/2018
Description
comments:
Interval
Start Stop
Completion Status 1 -OIL
Current Status 1 -OIL UIC No
10/8/2018
Electronic File: 1H-21AL2-01 5TVDSS Final.tif
0 0
2180800 KUPARUK RIV UNIT 1H-21AL2-01
LOG HEADERS
10/12/2018
Electronic File: 1H-21AL2-01 EOW - NA027.pdf
10/12/2018
Electronic File: 1 H-21AL2-01 EOW - NAD27.W
10/12/2018
Electronic File: 1H-21AL2-01 EOW - NAD83.pdf
10/12/2018
Electronic File: 1H-21AL2-01 EOW - NAD83.txt
0 0
2180800 KUPARUK RIV UNIT 1H-21AL2-01
LOG HEADERS
Sample
Set
Sent Received
Number
Comments
Directional / Inclination Data Mud Logs, Image Files, Digital Data Y /6 Core Chips Y / 6A
Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files (9 Core Photographs Y /&
Daily Operations Summary �/Y Cuttings Samples Y / 1� Laboratory Analyses Y/19
Date Comments
AOGCC Page 2 of 3 Friday, January 18, 2019
DATA SUBMITTAL COMPLIANCE REPORT
1/18/2019
Permit to Drill 2180800 Well Name/No. KUPARUK RIV UNIT 1H-21AL2.01 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.029-22355-62.00
MD 10910 TVD 6757 ompi tion Date 9/14/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No
Compliance Reviewed By: _ Date: / h e h
AOGCC Page 3 of 3 Friday, January 18, 2019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
n17T n 9
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1a. Well Status: CIE] Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended[]
20AAc 25.105 2WC 25.110
GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions:
1b. Well Class:
Development 0 Exploratory ❑
Service ❑ Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Abend.: 9/14/2018
14. Permit to Drill Number / Sundry:
218-080
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded:
9AP2018 td
15. API Number:
50-029-22355-62-00
4a. Location of Well (Governmental Section):
Surface: 678' FNL, 793' FEL, Sec 33, T12N, R10E, UM
Top of Productive Interval:
754' FNL, 1789' FEL, Sec 34, T12N, R10E, UM
Total Depth:
433' FNL, 4820' FEL, Sec 35, T12N, R10E, UM
8. Date TO Reached:
9/12/2018
16. Well Name and Number:
KRU 1H-21AL2-01
9. Ref Elevations: KB:96
GL: 54 BF:
17. Field / Pool(s):
Kuparuk River Field/Kuparuk River Oil Pool
10. Plug Back Depth MD/TVD:
N/A
18. Property Designation:
ADL 25639 ROL. 256$$
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 649555 y- 5980024 Zone- 4
TPI: x- 553839 y- 5979978 Zone- 4
Total Depth: x- 556085 y- 5980316 Zone- 4
11. Total Depth MD/TVD:
1091016757
19. DNR Approval Number:
LONS 80-261
12. SSSV Depth MDfFVD:
1789/1783
20. Thickness of Permafrost MD/TVD:
162911626
5. Directional or Inclination Survey: Yes ❑� (attached) No ❑
Submit electronic and printed information per 20 AAC 25.050
13. Water Depth, if Offshore:
N/A (ft MSL)
21. Re-drill/Lateral Top Window MD/TVD:
8453/6730
22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days
of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential,
gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and
perforation record. Acronyms may be used. Attach a separate page if necessary
GR/Res
23. CASING, LINER AND CEMENTING RECORD
WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT
CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED
16 62.5 H-00 41 121 41 121 24 200 sx PF C Cmt
9518 36 J-55 40 4820 40 4247 12 114 930 sx PERM E, 450 sx Class G
7 26 J-55 39 8296 39 6947 81/2 299 sx Class G
2 318 4.7 L-80 7669 10500 6457 6729 3 Slotted LINER
24. Open to production or injection? Yes 0 No ❑
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
SLOTTED @:
7866 - 7955 MD and 6607 - 6639 TVD... 9/13/2018 ;,.OMPLETION
8041 - 10500 MD and 6692 - 6729 TVD ... 9/7/2018 DAT -
AAU
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD[TVD)
31/2 7693 766416453
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes E] No[]
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED
27. PRODUCTION TEST
Date First Production:
WAITING FOR HOOKUP
Method of Operation (Flowing, gas lift, etc.):
Date of Test:
Hours Tested:
Production for
Test Period
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Choke Size:
Gas -Oil Ratio:
Flow Tubing
Press.
Casinq Press:
Calculated
24 -Hour Rate
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Oil Gravitv - API (corr):
Form 10-407 Revised 5/2017 VTL /I/19//V CONTINUED ON PAGE 2 RBQMS, Submit ORIGINAL only
i( rgti �kg,12/11/1� �� OCTGCi 0 9 2118 y
28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑+
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this farm,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
29. GEOLOGIC MARKERS (List all formations and markers encountered):
30. FORMATION TESTS
NAME
MD
TVD
Well tested? Yes ❑ No ❑�
If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Surface
Permafrost - Base
1629
1626
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
8453
6730
information, including reports, per 20 AAC 25.071.
Formation @ TPI Xuparuk C Sand
TO
10910
6757
Formation at total depth:
Kuparuk C Sand
31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleantoloaical report. oroduction or wall test results. car 20 AAC 25070,
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: James Ohlin er Contact Name: William R. Lon �✓�
Authorized Title: Staff CTD Engineer Contact Email: William. R.Lon co .com
Authorized Contact Phone: 263-4372
Signature: Date:
INSTRUCTIONS
General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Form 10-407 Revised 5/2017 Submit ORIGINAL Only
18" Se H40 shoe
121' MD
94 8"36a J-55 sh
4820 MD
jKOP@78MMID I
C -sand per(s squeezetl w/ cemam
77613'. 7858' MD
7918'. 7948' MD
T' 28e J65
shoe @ 8298' MD
iH-21 Proposed CTD Schematic
C xi i84 -
TSAPM Peter
]6]0'RMI
C'TDSeeltgra4Mgm
evwe]8W MD
3-12" Cameo TRDP--4A-RO SSSV at 1789' MO (2.8121
3la'9.3%JS EUE 8M Tubing lo surface
3 W' Cameo MMG gas lift manna M2571', 4355', 5143', 5922',
6719.718T. 7602'
Baker 3-1&' PBR x17650' MD
BakeMB booker at 7664' MD (2 89" ID)
D -nipple at 7680" MD (Milletl out to 2.80" )
3-12" Baker SOS @ 7692' MD
7&8' MO
1H 21A M- V4V MD
innobge"� 0,=8355 MD
Anchored Not =3915'MD
KUP PROD 1H-21AL2-01
cmicicOi11llip5Well Attribut iMaxAngle TD
Field Name Wei IWre APWIN Well Wle stilus ncll°I MD lis ACIl prop
Alaska, lot KUPARUK RIVER UNIT 509292235562 PROD 632 84529Y 109100
1M21 A3201.tarme1o1.2z AM
Last Tag
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Last Rev Reason
End Date
Len MW By
Rev Reason
Rev Reason: Installed Liner Top Packer
91182018
2emba,
Casing Strings
coxoueioF: aiwzio
Casing Description
.0113)
lolinf Top (rtN91
Set Wpin BIXa) ssaDepm(NO1...wuLen ll... Glede
Top TM1reeO
A1101Liner
2318
1.99 7,668.9
10,5000 6,88.6 460
L-89
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Liner Detalls
Nominal lD
Top Top1TVDiUI
Topincll'1 Item Des
Lom
ina
GAS UR 25RI5
],668.9
6,456.5
3901 SBR(Seal
Deployment Sleeve Wl6' Snell Pennell (PBR)
2250
Bare
Receptacle)
eAsol 1.3u.e I EM
],818.1
,5 )
44.2) Swell Packer
Swell Parker -Halliburton
1.686
],959.8
Q6414
63-73 Swell Pecker
Swell Pacer - Halliboa.n
1.686
8,0210
6680.1
4950 5.0 Packer
Swell Packer-Hallibwon
1686
8,4
6729.1
9438 epoymenl
Snots Deployment Sleeve
1920
SURFACE: 9.2�Sa1.4�
Slees'
ws uFra 1.4
9.5]].0
6.731.2
91 Deploynam
Sleeve
Shorty Deployment Sleeve
1920
W6 UFT, alien 9
rasun:n,Tm9
ws LLR:214.T
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PACNER: 2,M.9
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NIPPLE:7...3
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IPERF:T,2S66T.8%l
PR.DUCTION:$.9Q2g63
PLt itis" 2491-11 gi.0
P11Liur; 6,95ZT11,iffio Ji
a.1LL 17.66861p5W.o
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Cixio hilfipS Well Attributer Max Angle& TD
Field N- r'J'pore AI'D WeIIM,e ablus ncl l°) Mol11N. Act Stl pos)
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1
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Casing Strings
Casma Description OD hn) 10 (in) Top (MRI selcePln lnNB set oeplI ITVDI-.. WULen lt_G,aae Top TM1sead
CONDUCTOR 16 15.06 41.0 121 J1 1210 62.50 Hd0 WELDED
1
CONDUCTOR; 4161210
Ceslnp Descnptlan OD(lnl mlin) Top lM1l(BI set Depth 11M41 Set DepinlNm... WIILen p... Omae Top TM1redO
SURFACE 95/8 8.92 40.2 4,8204 4247.1 36.00 J-55 BTC
CdalnO Descnpuon OD Ire, mM) TOP(NKRI $el oepm lnne) .1 Dep. ITVDL_wuLen (l... trade TOP rM1,eaa
BAFEtt VLV TM
PRODUCTION > 6.28 38.9 8,2963 6,947.0 26.00 J-55 AB -MOD
I
Tubing Strings
Tubi np Description Slang MS-112Dpnl TopinnBl set oePln(x.set Depth L..wtpwn) arae Top Connecron
TUBING }1/2 2.99 3].6 7,692.9 6.4]52 930 J-55 EUEBROMOD
GATUFT:Z57ps
Completion Details
Too HVDI Top mal Nominal
TcppaB) hush (-1 Ibm Des core ID (in)
euuFTi 4,Dse.ei Di
37.6 37.6 0.13 HANGER FMC GEN IV HANGER 3.500
1,789.3 1,783.2 14.33 SAFETY VLV CAMCO TRDPAA-RO SAFETY VALVE 2.812
76501 6,441.9 BAKER PBR eelSTROKE (TOP OF PBR HA 417 " M 3.0M
SQUARE THREAD FOR PKR RETRIEVAL)
7,6G3.9 6,452.7 39.00 PACKER BAKER HB RETRIEVABLE PACKER 2890
7.6803 6,465.4 39.01 NIPPLE CAMEO D NIPPLE NO GO (Milled out 1. 280"71121) 2800
7,6920 6,474.5 39.00 505 BAKER SHEAR OUT SUB 3.015
SURFACE:40.24=4�
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
W6 uFTi 6,143.4
rop 11VD) Top Incl
IT
Top MKel -p
(-) Des cam Run Dale 10(in)7,680.0
8, .6 3900 PLUG Cement Plug 7/122018 0000
ousuFT:4sre
7,626.0 6,5]8J 38.66,hyn xpansion NOMent SolUSors High Expansion Wedge &19Y2018 0.000
Wedge
Perforations & Slots
D'S UFT; 9,Tme
Shot
Top DI/Id
BW(TVD)
(zw11a11
Top pe(m
MMM
(XKB)
(Po(6)
United Zone
DNe
1
Type
Com
GAsuFT:11m7
],6]5.0
7,6]].0
6,4613
6,4628
]112018
3.0
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deg phasing
],]68.0
7,858.0
fi,533.5
6,6037
UNI -0, -
&1&1993
6.0
(PFRF
nerjet, deg.
3,111-21
phasing
],918.0
7,948.0
6,650.7
.6)4.2
-,UNI H
&2&1993
12.0
IPERF
SwS 4.5"H dap.
-21
phasing
Cement
Sque ores
GAS LIFT: 18002Top(No)
a-(TVDI
Top (KKB) Rlm(MNR) (M1KB)
("a; Des
Sbn Date Com
7,663.9 8,088.0 6,452.6
6IST 1amen! ]11412018
Squeeze
Mandrel Inserts
paR; 18m.1
SL
aU
CeremEpmu:ER,I. XNB
pACI(ERa.aef.8
PM) TRO Run
On TOPITVD) Vabe Tipp
N Top 0039) 280(6) Male Model OD (in) Sm Type Type (271) Run Dam Com
1 2,5705 2,495.5 CAMCO KBUG 1 GAS LIFT GLV BKS 8 1,2]10 61112018
TT
2 4,354.9 3,890.4 GAMCO KBUG 1 GAS LIFT OV BK5 0. 5 00 8/1/2018
NMnem SNlnbmbwr T,
3 5,143.4 4,495.7 CAMCO KBUG 1 GAS LIFT DMY BK5 . 00 00 8/5/2007
Penner Tamp
4 5,921.9 5,089.9 CAM KBUG 1 GAS LIFT DMY -SK 0000 00 &512007
PLUG;7.Moo
cM7 sozn,neo-T,er7.0
5 6,]09.9 5,]02. AMCO KBUG 1 MUFT DM 875 0000 00 511311999
6 7,182.] 6,0749 CAMCD KBUG 1 GAS LIFT DMY BK5 OOOO 0.0 5/1311999
7 7,6022 6,4047 CAMCD MMG-2 1112 GAS LIFT DMY RK 0.000 00 7/1811993
NIMLE: TIES
Notes: General & Safety
EM UahAnaMztbn
92b2010
NOTE: View Schematic wl Alaska Schem08C9.0
801'.M 0
IPERF: 7,78 G -7.O
AL2al user, las e-Iamp.OL�
x1211 E�Temm Welae: 7.M0
IPERF:],BI8 STSISii�
PRODUCTON. S0.30.3mS
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
stat Time
End Time
W inn
Phase
Op Cone
Activity Cone
Time P.T-x
Operation
(MKB)
End Depth (MKB)
8/17/2018
8/18/2018
12.00
MIRU
MOVE
MOB
P
Demob off 3H - Tucks on location @
0.0
0.0
12:00
00:00
16:00. Leave 3H pad 18:30, Arrive 1 H
24:00
8/18/2018
8/18/2018
5.00
MIRU
MOVE
MOB
P
On 1H pad, Remove jeeps. Prep cellar
0.0
0.0
00:00
05:00
for spotting rig. Spot dg. Work rig up
check list.
8/18/2018
8/18/2018
4.00
MIRU
MOVE
RURD
P
Safe out all landings and stairs, call
0.0
0.0
05:00
09:00
out scaffold for wellhead platform, call
grease crew, CID stem seal on B1
8/18/2018
8/18/2018
2.00
MIRU
MOVE
RURD
T
Operations limited due to rig issues on
0.0
0.0
09:00
11:00
same pad
***Note: Rig Accept time 0900"'
8/18/2018
8/18/2018
1.00
MIRU
WHDBOP
NUND
P
NIU BOP
0.0
0.0
11:00
12:00
8118/2018
8/18/2018
2.00
MIRU
WHDBOP
BOPE
P
Start BOP test, low 250 psi/high 3000
0.0
0.0
12:00
14:00
psi/annular 2500 psi, test waived by
Guy Cook (AOGCC)
8/18/2018
8/18/2018
1.50
MIRU
WHDBOP
PRTS
T
Problems with swab valve, call out
0.0
0.0
14:00
15:30
grease crew again
8/18/2018
8/1812018
5.50
MIRU
WHDBOP
ROPE
P
Continue with BOP test, Fail / Pass on
0.0
0.0
15:30
21:00
C2, C1. Fail and replace Rt, End of
BOPE test
8/1812018
8/18/2018
2.00
MIRU
WHDBOP
PRTS
P
Pressure test PDL's and TT line.
0.0
0.0
21:00
23:00
Install night cap and bleed off WHIP.
-
Started at 480 PSI. BIIed down in
steps to zero. Observe well. Dead for
ten minutes pressure slowly rising.
Bleed and watch. Go to pressure
deployment ops for Whipstock
8/18/2018
8/19/2018
1.00
PROD1
RPEQPT
PULD
P
PJSM, M/U BHA#1 with high
- 0.0
0.0
23:00
00:00
expansion whip stock
8/19/2018
8/19/2018
1.00
PRODt
RPEQPT
PULD
P
Continue pressure deployment BHA
0.0
-73-5-
00:00
01:00
#1 NS HEW Whipstock, Make up to
coil and surface test. Inspect pack offs
8/19/2018
8/19/2018
1.50
PROD1
RPEQPT
TRIP
P
RIH BHA#1, EDC open pumping min
73.5
7,565.0
01:00
0230
rale on seawater. Returns to TT
8/19/2018
8/19/2018
0.20
PROD1
RPEQPT
DLOG
P
Log K1 marker for +2.6'
7,565.0
7,595.0
02:30
0242
8/19/2018
8/19/2018
0.40
PROD1
RPEQPT
DLOG
P
Trip into 7650 run CCL log down to
7,595.0
7,850.0
02:42
03:06
7850
8/19/2018
8/19/2018
0.30
PROD1
RPEQPT
TRIP
P
PUH to whipstock setting depth @
7,850.0
7,833.7
03:06
03:24
7833.7, TOWS @ 7825. HS
Orientation. Set whipstock. See tool
shift - 230OPSI. Set down 2.5K -
Good
8/19/2018
8/19/2018
1.70
PROD1
RPEQPT
TRIP
P
PUH to 7819. Open EDC Flush well @
7,833.7
74.0
03:24
05:06
2 BPM, Start tripping out
8/19/2018
8119/2018
0.50
PROD1
RPEQPT
PULD
P
Tag up at surface, check well for Flow
74.0
74.0
05:06
05:36
(no -flow)
8/19/2018
8/19/2018
1.00
PROD1
RPEQPT
PULD
P
LD setting tools on a dead well
74.0
0.0
05:36
06:36
8/1912018
8/19/2018
0.30
PROD1
WHPST
PULD
P
PJSM, PD window milling BHA#2
0.0
76.9
06:36
06:54
8/19/2018
8/19/2018
0.20
PROD1
WHPST
PULD
P
Stab INJH, surface test Coiltrak tools,
76.9
7_69-
06:54
07:06
(good -test), check pac-offs (good)
8/19/2018
8/19/2018
1.40
PROD1
WHPST
TRIP
P
Tag up, reset counters to zero, RIH
76.9
7,565.0
07:06
08:30
with window milling BHA#2
8/19/2018
8/19/2018
0.20
PROD1
WHPST
DLOG
P
Log the K1 marker correction of plus
7,565.0
7,600.0
08:30
08:42
1.5'
8/19/2018
8/19/2018
0.60
PROD1
WHPST
DISP
P
Finish displacing well to milling fluid
7,600.0
7,600.0
08:42
09:18
Page 1/30 Report Printed: 911912018
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Slan DePM
SbM1Time
End The
Dur(hr)
Pre..
Op Code
AdWity Cade
Time P -T -X
Operation
(Po(a)
End Deplh(f")
8/19/2018
8/19/2018
0.20
PROD1
WHPST
TRIP
P
Continue IH, dry tag TOHEW (TOWS),
7,600.0
7,827.7
09:18
09:30
HEW 7827.3'
8/19/2018
8/19/2018
0.50
PROD1
WHPST
TRIP
P
PUW 45 k, no pumps, bring pump on-
7,828.7
7,828.7
09:30
10:00
line, RIH 1.0' past TOWS, PUH, shut
down pump, RBIH to confirm dry tag
HEW pinch point. 7828.7'.
8/19/2018
8/19/2018
2.00
PROD1
WHPST
MILL
P
PUH, and bring pump on line get
7,828.7
7,833.2
10:00
12:00
parameters, begin milling window @ 1
fph, 1.81 bpm at 4,056 psi,
BHP=3,629, WHP=419, IA=O, OA=48.
"'" Note: Center of the mill out of
casing 7,831.2'
8/1912018
8/1912018
3.50
PROD1
WHPST
MILL
P
Continue milling window off of
7,833.2
7,846.0
12:00
15:30
Northern Solutions HEW WS, 1.81
bpn at 4,000 psi, WHP=O, BHP=3,610,
IA=O, OA=50
*** Note: BOW @ 7,832'
8/19/2018
8/19/2018
0.10
PROD1
WHPST
TRIP
P
TD rat hole 21' from TOWS, pull up
7,846.0
7,829.0
15:30
15:36
hole, PUW 45 k
8/19/2018
8/19/2018
0.80
PROD1
WHPST
REAM
P
Ream window area from 7,844'-7,829'
7,829.0
7,846.0
15:36
16:24
8/19/2018
8/19/2018
0.20
PROD1
WHPST
REAM
P
Dry drift window area 7,814'to TD
7,846.0
7,846.0
16:24
16:36
7,846'
8/19/2018
8/19/2018
1.00
PROD1
WHPST
TRIP
P
POOH, pumping 1.81 bpm
7,846.0
83.0
16:36
17:36
8/19/2018
8/19/2018
1.40
PROD1
WHPST
PULD
P
At surface, Flow check Lay down
83.0
0.0
17:36
19:00
window milling BHA on dead well. Mill
out @ 2.79 Go. 2.80" NoGo.
8/19/2018
8/19/2018
0.60
PROD1
DRILL
PULD
P
M/U BHA#3 with RB HCC Bi center,
0.0
72.2
19:00
19:36
2.3+^ AKO motor, and USR, M/U to
coil and surface test. - Good
8119/2018
8/19/2018
1.60
PROD1
DRILL
TRIP
P
Trip in well, EDC open pumping min
72.2
7,565.0
19:36
21:12
rale.
8/19/2018
8/19/2018
0.10
PROD1
DRILL
DLOG
P
Log Ki for for +1'
7,565.0
7,586.0
21:12
21:18
8/19/2018
8/1912018
0.40
PROD1
DRILL
TRIP
P
Continue in well, @ 7810 perform 1 to
7,586.0
7,846.0
21:18
21:42
1 pressure test. Pump 1.78 BPM,
BHP=3633, WHP=O with open choke.
ECD=10.7 PPG. Shutdown pump.
Close EDC. Clean pass through
window, Tag up and drill from 7846
8/19/2018
8/1912018
1.60
PROD1
DRILL
DRLG
P
7846', Drill, 1.74 BPM @ 3751 PSI FS,
7,846.0
7,912.0
21:42
23:18
BHP=3648
8119/2018
8/19/2016
0.10
PROD1
DRILL
WPRT
P
BHA wiper/ weight check, PUW=50K
7,912.0
7,912.0
23:18
23:24
8/19/2018
8/2012016
0.60
PROD1
DRILL
DRLG
P
7912', Drill, 1.75 BPM @ 3788 PSI
7,912.0
7,930.0
23:24
00:00
FS, BHP=3660
8120/2018
8/20/2018
3.80
PROD1
DRILL
DRLG
P
7930', Drill 1.75 BPM @ 3788 PSI FS,
7,930.0
8,054.0
00:00
03:48
BHP=3660
8/20/2018
8/20/2018
0.20
PROD1
DRILL
WPRT
P
8054 BHA Wiper trip, PUW=50K,
8,054.0
8,054.0
03:48
04:00
RIW=17.5K
8120/2018
8/20/2018
3.20
PROD1
DRILL
DRLG
P
8054', Drill 1.76 BPM @ 3970 PSI FS,
8,054.0
8,150.0
04:00
07:12
j
j BHP=3694
8/2012018
8/20/2018
1.50
PROD1
DRILL
TRIP
P
TD Build Section, 1 0x1 0 sweep,
8,150.0
73.0
07:12
08:42
1
1
POOH
8/2012018
8/20/2018
0.70
PROD1
DRILL
PULD
P
Tag up, space out, PUD build section
73.0
73.0
08:42
09:24
1
BHA#3
Page 2130 Report Printed: 911912018
Operations Summary (with Timelog Depths)
1H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Steri Tune
ErW Tyne
Dur (M
Phese
OP Gods
ALA* Code
Tine ?-T-X
Operation
(11K13)
End Depth (nKe)
8/20/2018
8/20/2018
0.80
PROD1
DRILL
PULD
T
"'BHA hung up in well, trouble pulling
73.0
73.0
09:24
10:12
High Bend motor with SL, line up to
pump thru the kill line and tango's, no
success, close rams, bleed pressure
from PDL, unstab, hook up suface
power to tools, rotate TF 90° Left.
Work tools free
8/20/2018
8/20/2018
0.70
PR5D1
DRILL
PULD
P
Continue PUD
73.0
0.0
10:12
10:54
8/20/2018
8/20/2018r0.20
PROD1
DRILL
PULD
P
PJSM, PD lateral drilling BHA #4
0.0
78.2
10:54
12:06
w/0.5°- ako motor/ NOV Agitator
8/2012018
8/202018
PROD1
DRILL
TRIP
P
RIH, 568'tesl Agitator (great -test)
78.2
7,565.0
12:06
13:24
820/2018
8/20/2018
PROD1
DRILL
DLOG
P
Log the K1 correction of plus 1.5'
7,565.0
7,593.0
13:24
13:36
8/20/2018
8120/2018
PROD1
DRILL
TRIP
P
Continue IH,
7,593.0
7,845.0
13:36
13:42
8/20/2018
8/20/2018
.
PROD1
DRILL
DLOG
P
Log the RA @ 7833.5'
7,845.0
8,150.0
13:42
13:48
820/2018
8202018
5.30
PROD1
DRILL
DRLG
P
BOBO, 1.79 bpm @ 4,400 psi,
8,150.0
8,577.0
13.1,250,
48
19:06
Diff -WHP=open choke,
BHP=3,813, IA=O, OA=51
8/20/2018
8/2012018
0.50
PROD1
DRILL
WPRT
P
Wiper to the window, PUW 51 k
8,577.0
7,900.0
19:06
19:36
812012018
8/2012018
0.50
PROD1
DRILL
WPRT
P
Wiper back in hole, RIW 17 k
7,900.0
8,577.0
19:36
20:06
8/20/2018
8/20/2018
2.70
PROD1
DRILL
DRLG
P
BOBO, 1.80 bpm @ 4,245, Diff -1,230
8,577.0
8,950.0
20:06
22:48
psi, WHP=open choke, BHP=3,780,
IA=208, OA=59
8/20/2018
812012018
0.50
PROD1
DRILL
WPRT
P
Wiper up to the window, PUW 60 k
8,950.0
7,565.0
22:48
23:18
8120/2018
8/20/2018
0.20
PROD1
DRILL
HOG
P
log the K1 marker correction of plus
7,565.0
7,589.0
23:18
23:30
5.0'
8/20/2018
8/20/2018
0.30
PROD1
DRILL
WPRT
P
Continue IH, Jog the 7", 7,700'-7,815',
7,589.0
7,815.0
23:30
23:48
closed EDC,
820/2018
8/21/2018
0.20
PROD1
DRILL
WPRT
P
Continue wiper back in hole, Tough
7,815.0
7,880.0
23:48
00:00
spot 7880. Multiple setdowns with
clean pickups, PUW=62K. Worked
through @ .5 BPM 10 FPM. Continue
to bottom
812112018
8/21/2018
0.60
PROD1
DRILL
WPRT
P
Continue wiper trip back to bottom
7,880.0
8,951.0
00:00
00:36
8/21/2018
8/21/2018
1.00
PROD1
DRILL
DRLG
P
8951', Drill, 1.78 BPM @ 4456 PSI
8,951.0
9,119.0
00:36
01:36
FS, BHP=3780PSI, RIW=18.6K
8/21/2018
8/21/2018
0.10
PROD1
DRILL
WPRT
P
BHA Wiper, PUW=60K
9,119.0
9,119.0
01:36
01:42
8/21/2018
8/2112018
1.70
PROD1
DRILL
DRLG
P
9119, Drill, 1.78 BPM @ 4425 PSI FS,
9,119.0
9,325.0
01:42
03:24
BHP=3838
8/21/2018
8/21/2018
0.70
PROD1
DRILL
WPRT
P
Pull 800 -wiper, PUW=70K, 10K
9,325.0
9,325.0
03:24
04:06
overpulls @ 8890, 8690, & 8570.
Clean on way in
8/21/2018
3.80
PROD1
DRILL
DRLG
P
9325', Drill, 1.79 BPM @ 4480 PSI
9,325.0
9,745.0
07:54
FS, BHP=3781
8121/2018
1.10
PRODt
DRILL
WPRT
P
Wiper to window, work through light
9,745.0
7,050.0
09:00
area 8088 to 8196
r8121/201
8/2112018
0.90
PROD1
DRILL
WPRT
P
Pull into 7", recip and jet, pump
7,050.0
7,845.0
09:54
sweeps, circ to surface, RBIH, set
down at 7828, TOW, PUH spin bit, set
down 7786. Go through window
8/2112018
0.10
PROD1
DRILL
DLOG
P
Log RA for+7'
7,845.0
7,870.0
09:54
10:00
Page 3130 Report Printed: 9/1 912 01 8
Operations Summary (with Timelog Depths)
Alex, -
IH -21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Tema
Eno Tome
Dur (hr)
Phase
Op Code
hctivKy Code
Thee P -T-%
Operation
(hKB)
End Depth (Po(B)
8/21/2018
8/21/2018
1.10
PROD?
DRILL
WPRT
P
Continue in hole, initial set down Q
7,870.0
7,896.0
10:00
11:06
7871 work down to 7888. multiple
setdowns to 7896, Unable to pass
7896 at different speeds and pump
rates. Back ream up at 180° still
unable to pass.
8/21/2018
8/21/2018
0.60
PROD1
DRILL
WPRT
P
Pull up hole to cased pipe. Circ
7,896.0
7,839.0
11:06
11:42
bottoms up. Check shaker. Nothing
there. Discuss plan forward
8/21/2018
8/21/2018
1.40
PRODI
DRILL
TRIP
T
Trip out for clean out BHA
7,839.0
84.0
11:42
13:08
8/21/2018
8/21/2018
1.40
PRODI
DRILL
PULD
T
PJSM, PUD BHA #4
84.0
0.0
13:06
14:30
8/21/2018
8/21/2018
0.90
PROD1
DRILL
PULD
T
PJSM, PD BHA #5 with 1.5° AKO
0.0
68.3
14:30
15:24
motor, D-331 with rigdge set cutter,
and agitator, Make up to coil and
surface test. Check packoffs, Tag up
8/21/2018
8/21/2018
1.10
PROD1
DRILL
TRIP
T
RIH BHA #5, Surface test agitator Q
68.3
7,565.0
15:24
16:30
1
1
500', open EDC and continue in
8/21/2018
8/21/2018
0.50
PROD1
DRILL
TRIP
T
Tie in to Kt marker, RIH
7,565.0
7,860.0
16:30
17:00
8/21/2018
8/21/2018
1.60
PROD1
DRILL
TRIP
T
stacked out twice, able to work
7,894.0
8,490.0
17:00
18:36
through, increase pump rate, rih to
stall, continue to work area, clean at
7896, On to 8490
8/21/2018
8/21/2018
1.50
PRODI
DRILL
TRIP
T
pumped bottoms up sweep, puh to 7",
8,490.0
7,858.0
18:36
20:06
taking 3 cleaning passes, attempt to
dry drift through trouble area 7840 to
7858, online, continue to tag at
different depths each time.
8/21/2018
8/21/2018
2.90
PROD1
DRILL
TRIP
T
pump bottoms up and clean area
7,858.0
7,820.0
20:06
23:00
above problem area, Min at full pump
speed, tagged several times in same
area (7840-7950) continue to pump
sweeps and try to clean trouble area
6/21/2018
8/22/2018
1.00
PROD1
DRILL
TRIP
T
puh to above window, circ buttoms up,
7,820.0
7,840.0
23:00
00:00
attempt to drift back through window,
sveral time tagging at top of window,
orient 15 degrees left, now able to drift
window, online with pumps at full rate,
rih.
8/22/2018
8/22/2018
2.00
PROD1
DRILL
TRIP
T
RIH at full pump rate, still tag several
7,820.0
7,820.0
00:00
02:00
time, rih to 6450, pump sweeps, puh
into the 7"gain, rbih smooth other then
one tag at 7858, rih to 8450 again,
puh to window.
8/22/2018
8/22/2018
2.00
PROW
DRILL
TRIP
T
rih and tagged at top of whip stock,
7,820.0
8,450.0
02:00
04:00
puh to lie in, +7.5 ft, rbih, small lag at
window, rih with full pump rate, mill
through small tag at 7890, rih continue
to work area. PUH above window, dry
drift to 6000, no tags, online full rate,
rih to 8450, start trip run for inflatable.
8/22/2018
8/22/2018
1.30
PRODI
DRILL
TRIP
T
POOH, one overpull at top of window
8,450.0
68.0
04:00
05:18
on bit, fill appears to be cleaned out,
POOH
8/22/2018
8/22/2018
1.50
PROD1
DRILL
PULD
T
PJSM, PUD BHA#5
68.0
0.0
05:18
06:48
8/22/2018
8/22/2018
1.20
PROD?
DRILL
PULD
T
PD BHA#6 2 1/8" Inflatable plug, M/U
0.0
68.0
06:48
08:00
to coil and surface lest tool -AII good,
Check pack offs
8/22/2018
8/22/2018
1.70
PROD1
DRILL
TRIP
T
RIH BHA #6 IFC plug
68.0
7,565.0
08:00
09:42
Page 4130 Report Printed: 9119/2018
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Tune
EM Time
Dur(hn
Phase
Op Cods
AcW y Code
Time P -T-%
Operation
(Po<a)
End Depth (Poke)
8/22/2018
812212018
0.10
PROD1
DRILL
DLOG
T
Log K1 for +1.5'
7,565.0
7,591.0
09:42
09:48
8/22/2018
8/22/2018
0.50
PROD1
DRILL
TRIP
T
Continue in hole. Stop and shut EDC
7,591.0
8,450.0
09:48
10:18
@ 7771. Clean pass through window.
Clean trip down to 8450
8/22/2018
8/22/2018
0.60
PROD(
DRILL
OTHR
T
At septh depth, Pull stretch out of coil.
8,450.0
8,450.0
10:18
10:54
Slowly pressure up inflatable to 1500
PSI. wait ten minutes. Bring pumps
online @ 1700 PSI pressure falls off
and we are circulating. Packer will not
pressure up. able to move packer up
and down hole. Attemp pumping
Faster. No pressure
8/22/2018
8/22/2018
2.00
PROD1
DRILL
TRIP
T
Trip out with BHA #6
8,450.0
71.0
10:54
12:54
8/22/2018
8/22/2018
1.10
PROD1
DRILL
PULD
T
At surface, Tag up and space out,
71.0
0.0
12:54
14:00
PUD BHA#6. Element is damaged on
inflatable packer. Pictures on S drive.
Lay down packer
8/22/2018
8/22/2018
1.30
PROD1
DRILL
OTHR
T.
Discuss options and alternatives.
0.0
0.0
14:00
15:18
Formulate plan forward
8/22/2018
8/22/2018
1.00
PRODi
DRILL
PULD
T
WU BHA V. 1° WFT motor and 2.80
0.0
65.3
15:18
16:16
1
1
1 crayola mill to dress window
8/2212018
8/22/2018
2.00
PROD(
DRILL
TRIP
T
Trip in hole
65.3
7,555.0
16:18
18:18
8/22/2018
8/22/2018
0.10
PROD1
DRILL
TRIP
T
Kt tie, =1 , Close EDC, dh
7,555.0
7,555.0
18:18
18:24
8/22/2018
8/22/2018
1.80
PROD1
DRILL
MILL
T
dh to 7829, dress window several time
7,555.0
7,833.0
18:24
20:12
with 2.79 crayola mill and dry drift per
plan forward
8/22/2018
8/22/2018
1.20
PROD1
DRILL
TRIP
T
Trip out of hole for BHA#8 inflatable
7,833.0
71.0
20:12
21:24
plug.
8/22/2018
8/22/2018
1.20
PROD1
DRILL
PULD
T
At surface, Tag up and space out,
71.0
0.0
21:24
22:36
PUD BHA#7.
8/22/2018
8/23/2018
1.40
PROD!
DRILL
PULD
T
PD BHA#8 2.5" Inflatable plug, M/U to
0.0
71.0
22:36
00:00
coil and surface test tool -All good,
Check pack offs
8/23/2018
8/23/2018
1.90
PROD1
DRILL
TRIP
T
trip in hole with BHA #8
71.0
7,555.0
00:00
01:54
8/232018
8/23/2018
0.20
PROD1
DRILL
DLOG
T
tie into K1, +1 correction
7,555.0
7,587.0
01:54
02:06
8/23/2018
823/2016
1.60
PRODi
DRILL
OTHR
T
tagged up at 8368, !ft short, Pull
7,587.0
8,368.0
02:06
03:42
stretch out of coil. Slowly pressure up
inflatable to 1500 PSI. wait ten
minutes. Bring pumps online, continue
to pressure up to shear at 2300 psi
over circ psi, pull 18k over window pu
wt, shear off inflatable.
8/23/2018
8/23/2018
1.50
PROD1
DRILL
TRIP
T
POOH
8,368.0
68.0
03:42
05:12
8/23/2018
8/23/2018
1.50
PROD1
DRILL
PULD
T
Tag up and space out, PJSM PUD
68.0
0.0
05:12
06:42
1
1
1
BHA#8 Packer running tools
8/23/2018
8/23/2018
1.00
PROD(
DRILL
PULD
T
PD BHA#9 OH anchored billit. M/U to
0.0
72.9
06:42
07:42
coil track and surface test tool, Check
packoffs
8/23/2018
8/23/2018
1.70
PROD1
DRILL
TRIP
T
RIH BHA #9
72.9
7,565.0
07:42
09:24
8123/2018
8/23/2018
0.20
PROD(
DRILL
DLOG
T
Log K1 for+1' correction
7,565.0
7,603.0
09:24
09:36
Page 5130 ReportPrinted: 9/19/2018
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
ell De
SW Tme
End Thne
Duf h
(d
Phase
op COEe
Activity Cotla
Time P -T -X
Operation
Erb Depth (IIKa)
8/23/2018
8/23/2018
0.50
PROM
DRILL
TRIP
T
Continue in hole, Shut EDC @ 7756.
7,603.0
8,327.0
09:36
10:06
Clean pass through window and down
to 8327, Set whipstock @ 210° TOWS
@ 8315, See tool shift @ 5111, Set
down 2K
8/23/2018
8/23/2018
1.70
PROD1
DRILL
TRIP
T
POOH, PUW=53K
8,327.0
74.0
10:06
11:48
8/23/2018
8/23/2018
1.10
PROM
DRILL
PULD
T
At surface, Tag up and space out,
74.0
0.0
11:48
12:54
1
1
1 PUD BHA#9 Anchor billet selling tools
8/2312018
1.00
PROD2
STK
PULD
P
PD BHA#10 from Pre loaded PDL
0.0
80.5
12:54
13:54
with .5-AKO motor, Strider agitator,
18123/2018
and new HCC bi-center bit with
Dynamus cutters.
8/23/2018
8/23/2018
1.70
PROD2
STK
TRIP
P
Trip in hole, Shallow test Strider tool
80.5
7,565.0
13:54
15:36
@ 500', Continue in well.
8/23/2018
8/23/2018
0.10
PROD2
STK
DLOG
P
Log K1 for +1' correction
7,565.0
7,594.0
15:36
15:42
8/23/2018
8/2312018
0.40
PROM
STK
TRIP
P
Continue in well, Dry tag TOB @
7,594.0
8,315.0
15:42
16:06
1
18315', PUH, PUW=54
8/23/2018
8123/2018
1.90
PROM
STK
KOST
P
Pumps on 1.83 BPM @ 4286 PSI FS,
8,315.0
8,318.0
16:06
18:00
BHP=3742. Start milling off billet @
8315.3. Mill per procedure
8/23/2018
8/23/2018
2.00
PROM
DRILL
DRLG
P
8318', Drill, 1.70 BPM @ 4145 PSI
8,318.0
8,421.0
18:00
20:00
FS, BHP=3724
-
8123/2018
8/23/2018
0.20
PROD2
DRILL
DRLG
P
PU to 8160 and dry drift billet
8,421.0
8,421.0
20:00
20:12
8/23/2018
8/2312018
2.00
PROD2
DRILL
DRLG
P
8421', Drill 1.72 BPM @ 4376 PSI FS,
8,421.0
8,546.0
20:12
22:12
BHP=3945
8/23/2018
8123/2018
0.20
PROD2
DRILL
WPRT
P
PU to lower flow and try to get through
8,546.0
8,546.0
22:12
22:24
stringer, srart mu swap
8/23/2018
8/24/2018
1.60
PROD2
DRILL
DRLG
P
8546' Drill 1.60 BPM @ 4368 PSI FS,
8,546.0
8,662.0
22:24
00:00
BHP=4176, trouble getting direction to
drop
8/24/2018
8/24/2018
1.50
PROD2
DRILL
DRLG
P
8662' Drill 1.60 BPM @ 4358 PSI FS,
8,662.0
8,690.0
00:00
01:30
BHP=4192 still having trouble getting
direction to drop, consult with town,
decission made to trip for BHA.
8/24/2018
8/24/2018
1.90
PROD2
DRILL
TRIP
T
Trip for BHA
8,690.0
69.0
01:30
03:24
8/24/2018
8/24/2018
1.10
PROD2
DRILL
PULD
T
Tag up and space out, PJSM, PUD
69.0
0.0
03:24
04:30
BHA#10
8124/2018
8/24/2018
1.00
PROD2
DRILL
PULD
T
PD BHA#11 with .7"AKO motor, M/U
0.0
80.5
04:30
05:30
to coil and surface test
8/24/2018
8/2412018
1.40
PROM
DRILL
TRIP
T
Trip in BHA# 11, Test agitator @ 500',
80.5
7,565.0
05:30
06:54
Continue in well
8/24/2018
8/24/2018
0.10
PROD2
DRILL
DLOG
T
Log K1 for +2.5'
7,565.0
7,593.0
06:54
07:00
8/24/2018
8/242018
0.70
PROD2
DRILL
TRIP
T
Continue in well, Stop at 7807 for
7,593.0
8,690.0
07:00
07:42
static, Annular pressure = 4200 PSI,
6524.6 TVD, 12.385 EMW. Continue
in. Clean pass through window
8/24/2018
8/24/2018
2.50
PROD2
DRILL
DRLG
P
8690', Drill, 1.81 BPM @4577 PSI FS,
8,690.0
8,863.0
07:42
10:12
BHP=4429
824/2018
824/2018
0.70
PROD2
DRILL
WPRT
P
8863, Pull wiper to window with
8,863.0
7,805.0
10:12
10:54
sweeps. Pull up through window and
jet 7"
8/24/2018
824/2018
1.00
PROM
DRILL
PRTS
P
7805 Obtain static pressure, Bleed
7,805.0
7,805.0
10:54
11:54
down AP to 3800 PSI in three steps.
Climbed from 3800 to 3905 in 30
minutes. 6523.1 TVD, 11.51 EMW
8/242018
8/24/2018
0.50
PROD2
DRILL
TRIP
P
Continue wiper trip back to bottom.
7,805.0
8,862.0
11:54
12:24 1
1
1
1
1
1
Clean
Page 6130 ReportPrinted: 911912018
Summary (with Timelog Depths)
11-1-21
lipOperations
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
I End Time
Dur (hr)
Phase
Op Code
AcW4 Code
Time P-T-%
Operalion
(ftKB)
End Depth (110)
8/24/2018
8/24/2018
2.40
PROD2
DRILL
DRLG
P
8862', Drill, 1.79 BPM @ 4232 PSI
8,862.0
8,985.0
12:24
14:48
FS, BHP=4101
8/24/2018
8/24/2018
0.10
PROD2
DRILL
WPRT
P
Pull mini wiper, PUW=55K
8,985.0
8,985.0
14:48
14:54
8/24/2018
8/24/2018
2.90
PROD2
DRILL
DRLG
P
8985', Drill, 1.79 BPM @ 4254PSI FS,
8,985.0
9,098.0
14:54
17:48
BHP=4084
8/24/2018
8/24/2018
0.20
PROD2
DRILL
WPRT
P
Pull mini wiper, PUW=55K
9,098.0
9,098.0
17:48
18:00
8/24/2018
8/24/2018
4.00
PROD2
DRILL
DRLG
P
9098', Drill, 1.79 BPM @ 4254PSI FS,
9,098.0
9,260.0
18:00
22:00
BHP=4084
8/24/2018
8/24/2018
0.90
PROD2
DRILL
WPRT
P
wiper trip to 8460, PU wt 55k
9,260.0
9,860.0
22:00
22:54
8/24/2018
8/25/2018
1.10
PROD2
DRILL
DRLG
P
9260', Drill, 1.80 BPM @ 4480 PSI
9,260.0
9,310.0
22:54
00:00
FS, BHP=4100
j
8/25/2018
6/25/2018
3.00
PROD2
DRILL
DRLG
P
9310', Drill, 1.80 BPM @ 4480 PSI
9,310.0
9,414.0
00:00
03:00
FS, BHP=4100
8/25/2018
&25/2018
0.20
PROD2
DRILL
WPRT
P
Wiper trip to 9314', PU WT 59K
9,414.0
9,414.0
03:00
03:12
8/25/2018
8/25/2018
PROD2
DRILL
DRLG
P
9414', Drill, 1.80 BPM @ 4430 PSI
9,414.0
9,467.0
03:12
03:12
FS, BHP=4138
8/25/2018
8/25/2018
1.50
PROD2
DRILL
DRLG
P
9467, motor stall, puh, .90 bpm =4356
9,467.0
9,467.0
03:12
04:42
circ psi, unbable to clear bit, dh to tag
8/25/2018
6/25/2018
3.20
PROD2
DRILL
TRIP
T
POOH for motor swap
9,467.0
75.0
04:42
07:54
8/25/2018
6/25/2016
2.10
PROD2
DRILL
PULD
T
Tag up space out, PJSM PUD BHA
75.0
0.0
07:54
10:00
#11. Lay down motor, Sttyder agitator,
and FVS. Test in mouse hole. All seem
normal. Run water through coil track
no obstruction
8/25/2018
8/25/2018
1.40
PROD2
DRILL
PULD
T
PJSM, P/U motor, bit, agitator, and
0.0
78.1
10:00
11:24
FVS. PD BHA#12. Pull checks out of
UQC and change out. Make up to coil
and surface test tool. Pump at surface
to ensure BHA functional. Tag up and
set counters
8/25/2018
8/25/2018
1.40
PROD2
DRILL
TRIP
T
RIH BHA#12, Shallow test agitator at
78.1
7,565.0
11:24
1248
500'- Good. Continue in
8/25/2018
8/25/2018
0.10
PROD2
DRILL
DLOG
T
Log K1 for+1.5'
7,565.0
7,592.0
12:48
1254
8/25/2018
8/25/2016
1.40
PROD2
DRILL
TRIP
T
Continue in well. Wt check @7790
7,592.0
9,469.0
12:54
14:18
49K, Clean pass through window.
Stacking @ 8889, 9087, 9117, and
9176. Set down @ 9269 and 9376.
reduce rate to .6 to get through
8/25/2018
6/25/2018
6.20
PROD2
DRILL
DRLG
P
9469, On bottom drilling, 1.78 BPM @
9,469.0
9,813.0
14:18
20:30
4670 PSI FS, BHP=4165. Ratty with
low ROP
8/25/2018
8/25/2018
0.10
PROD2
DRILL
WPRT
P
100 ft wiper, PU WT is 61K
9,813.0
9,813.0
20:30
20:36
8/25/2018
8/25/2018
1.00
PROD2
DRILL
DRLG
P
9813', Drill, 1.78 BPM @ 4694 PSI
9,813.0
9,870.0
20:36
21:36
FS, BHP=4216
8/25/2018
8/26/2018
2.40
PROD2
DRILL
WPRT
P
9870' wiper, PU 800", 2 overpulls
9,870.0
7,710.0
21:36
00:00
around 9320 of 12k, some trouble
getting back to bottom through this
area. No WT on bit, Decide to POOH
to TTL to clean up 7", PU WT is 58K.
8/26/2018
8/26/2018
1.40
PROD2
DRILL
WPRT
P
Clean out 7"
7,710.0
7,570.0
00:00
01:24
8/26/2018
8/26/2018
0.10
PROD2
DRILL
DLOG
P
Tie in to K! +6.5
7,570.0
7,570.0
01:24
01:30
8/26/2018
8/26/2018
1.30
PROD2
DRILL
TRIP
P
RIH, Clean through window, set down
7,570.0
9,670.0
01:30
02:48
1
I
I
at 8755', Clean for remainder to 9870.
Page 7130
ReportPrinted:
9/1912018
Operations Summary (with Timelog Depths)
1 H-21
'
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Stat Time
EMrm
Da(hr)
Phase
Op Code
A�vlty Code
Time P -T -X
Operation
(aice)
End DepM(MB)
8/2612018
8/26/2018
1.20
PROD2
DRILL
DRLG
P
9870', Drill, 1.78 BPM @ 4622 PSI
9,870.0
10,015.0
02:48
04:00
FS, BHP=4239
8/26/2018
8/26/2018
0.20
PROD2
DRILL
WPRT
P
10015 PU for short wiper 100'
10,015.0
10,015.0
04:00
04:12
8/26/2018
8/26/2018
1.10
PROD2
DRILL
TRIP
T
Short trip to 9930, survey issues due
10,015.0
10,015.0
04:12
05:18
to magnetic storm. Start obtaining
usable surveys. RBIH to drill
8/26/2018
8/26/2018
2.10
PROD2
DRILL
DRLG
P
10015 Drill, 1.81 BPM @ 4764 PSI
10,015.0
10,172.0
05:18
07:24
FS, BHP=4202
8/26/2018
8/26/2018
0.20
PROD2
DRILL
WPRT
P
10172 Pull BHA wiper, PUW=61K
10,172.0
10,172.0
07:24
07:36
8/26/2018
8/26/2018
1.00
PROD2
DRILL
DRLG
P
10172', Drill, 1.77 BPM @ 4747
10,172.0
10,260.0
07:36
08:36
8/26/2018
8/26/2018
2.00
PROM
DRILL
WPRT
P
Pull 1 000'wiper with sweeps,
10,260.0
10,260.0
08:36
10:36
PUW=58K. Hard to get back to bottom
8/26/2018
8/26/2018
2.00
PROD2
DRILL
DRLG
P
10260', Drill, 1.79 BPM @ 4737 PSI
10,260.0
10,353.0
10:36
12:36
FS, BHP=4215
8/26/2018
8/26/2018
0.30
PROD2
DRILL
WPRT
P
Stacking, Pull BHA Wiper, PUW=63K
10,353.0
10,353.0
12:36
12:54
8/26/2018
8/26/2018
3.50
PROD2
DRILL
DRLG
P
10353', Drill, 1.8 BPM @ 4239 PSI
10,353.0
10,488.0
12:54
16:24
FS, BHP=4239 PSI, RIW=-.4,
DHWOB=I.6K
8/26/2018
8/26/2018
0.20
PROD2
DRILL
WPRT
P
Pull BHA Wiper, PUW=56K,
10,488.0
10,488.0
16:24
16:36
RIW=6.5K
8/26/2018
8/26/2018
2.50
PROD2
DRILL
DRLG
P
10488', Drill, 1.8 BPM @ 4241 PSI
10,488.0
10,573.0
16:36
19:06
FS, BHP=4237 PSI, RIW=-.4,
DHWOB=I.6K
8/26/2018
8/27/2018
4.90
PROD2
DRILL
WPRT
P
Wiper, PU WT=70K, PUH to TTL,
10,573.0
10,573.0
19:06
00:00
Time new mud swap for RIH, RBIH
several trouble areas going through
the C2, new mud at nozzle, big
improvment, rih to bottom
8/27/2018
8/27/2018
2.40
PROD2
DRILL
DRLG
P
10573', Drill, 1.79 BPM @ 4600 PSI
10,573.0
10,647.0
00:00
02:24
1 FS, BHP=4225
8/27/2018
8/27/2018
0.10
PROD2
DRILL
WPRT
P
Pull BHA Wiper, PUW=63K,
10,647.0
10,647.0
02:24
02:30
1 RIW=6.5K
8/27/2018
8/27/2018
1.30
PROD2
DRILL
DRLG
P
10647', Drill, 1.79 BPM @ 4600 PSI
10,647.0
10,671.0
02:30
03:48
FS, BHP=4225
8/27/2018
8/27/2018
0.10
PROD2
DRILL
WPRT
P
Pull BHA Wiper, PUW=61 K,
10,671.0
10,671.0
03:48
03:54
RIW=6.5K
8/27/2018
8/27/2018
0.50
PROD2
DRILL
DRLG
P
10671', Drill, 1.79 BPM @ 4419 PSI
10,671.0
10,676.0
03:54
04:24
FS, BHP=4230
8/27/2018
827/2018
0.40
PROD2
DRILL
WPRT
P
PU for GEO Wiper
10,676.0
10,676.0
04:24
04:48
8/27/2018
8/27/2018
2.70
PROD2
DRILL
DRLG
P
10676', Drill, 1.79 BPM @ 4412 PSI
10,676.0
10,700.0
04:48
07:30
FS, BHP=4228
6/27/2018
827/2018
2.90
PROD2
DRILL
TRIP
P
10,700, Trip for bit, Pump sweeps, jet
10,700.0
75.0
07:30
10:24
7" chase to surface
8/27/2018
8/27/2018
1.50
PROD2
DRILL
PULD
P
Tag up and space out, PJSM. Run
75.0
0.0
10:24
11:54
blocks to free ice. PUD BHA#12. Lay
down FVS, Agitator, motor, and bit. Bit
out 3-3 with chipped reamers and
nose
8/27/2018
8/27/2018
0.50
PROD2
DRILL
BOPE
P
P/U test joint. Perform Bi weekly
0.0
0.0
11:54
12:24
function lest on stack
8/27/2018
8/27/2018
1.30
PROD2
DRILL
PULD
P
P/U FVS, Agitiator, motor, and Hyc bi
0.0
78.0
12:24
13:42
center bit, PD BHA#13. M/U to coil
trak and surface test tool, Tag up and
set counters
8272018
8/27/2018
1.50
PROD2
DRILL
TRIP
P
Trip in hole, BHA#13, Shallowtest
78.0
7,565.0
13:42
15:12
agitator- Good. Continue in
Page 8/30 ReportPrinted: 911912018
Druffng Operations Summary (with Timelog Depths)
1 H-21
LortocoPhillips
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Start Time
End Thre
our (m)
Phase
Op code
Activity GD18
Time P -T -X
Operation
P(B)
End Depth(MkB)
8/27/2018
8127/2018
0.10
PROD2
DRILL
DLOG
P
Log Kt for+1 foot
7,565.0
7,595.0
15:12
15:18
8/27/2018
8127/2018
1.40
PROD2
DRILL
TRIP
P
. Set down @ 7966 and 8058 requiring
7,595.0
10,700.0
15:18
16:42
pick up. Stacking but no set downs,
RIH
8/27/2018
8127/2018
1.20
PROD2
DRILL
DRLG
P
10700', Drill, 1.79 BPM @ 4869 PSI
10,700.0
10,720.0
16:42
17:54
FS, BHP=42236
8/27/2018
812712018
0.10
PROD2
DRILL
WPRT
P
PU for mini wiper, PU WT=65K
10,720.0
10,720.0
17:54
18:00
8/27/2018
8/27/2018
5.20
PROD2
DRILL
DRLG
P
10720', Drill, 1.79 BPM @ 4776 PSI
10,720.0
10,984.0
18:00
23:12
FS, BHP=4212
8/27/2018
8/27/2018
0.20
PROD2
DRILL
WPRT
P
100' Wiper, PU WT is 64K
10,984.0
10,984.0
23:12
23:24
8/27/2018
8/28/2018
0.60
PROD2
DRILL
DRLG
P
10984', Drill, 1.79 BPM @ 5016 PSI
10,984.0
10,994.0
23:24
00:00
FS, BHP=4253
8/2812018
8/28/2018
2.00
PROD2
DRILL
DRLG
P
10984', Drill, 1.79 BPM @ 5016 PSI
10,994.0
11,100.0
00:00
02:00
FS, BHP=4253
8/2812018
8/2812018
1.80
PROD2
DRILL
WPRT
P
850" wiper, PU WT is 65K, pulled
11,100.0
11,100.0
02:00
03:48
heavy at 10980,10425 and 10305
8/28/2018
8/28/2018
3.10
PROD2
DRILL
DRLG
P
11,100', Drill, 1.79 BPM @ 5196 PSI
11,100.0
11,216.0
03:48
06:54
FS, BHP=4333
8/28/2018
8/28/2018
0.20
PROD2
DRILL
WPRT
P
Short wiper, PU WT is 72K
11,216.0
11,216.0
06:54
07:06
8/28/2018
8/26/2018
1.70
PROD2
DRILL
DRLG
P
11,216% Drill, 1.79 BPM @ 5126 PSI
11,216.0
11,244.0
07:06
08:48
FS, BHP=4310
8/28/2018
8/28/2018
0.20
PROD2
DRILL
WPRT
P
Short wiper, PU WT is 72K, Hard time
11,244.0
11,244.0
08:48
09:00
getting back down
8/26/2018
8/28/2018
2.50
PROD2
DRILL
DRLG
P
11,244', Drill, 1.79 BPM @ 5308 PSI
11,244.0
11,293.0
09:00
11:30
FS, BHP=4310
TD uncomfirmed 11,293'. PU Wt, 60 k
lbs
8128/2018
8/28/2018
0.90
PROD2
DRILL
CIRC
P
Stage sweeps to bit while RBIH to TD
11,244.0
11,293.0
11:30
12:24
8/28/2018
8/28/2018
2.70
PROD2
DRILL
WPRT
P
PUH on swab wiper trip chasing
11,293.0
7,700.0
12:24
15:06
sweeps to surface.
Slight increase in string weght and
motor work from 10,400-10,000.
RBIH, all clean, continue to POOH.
Pull heavy, 68 k lbs, @ 9,917' RBIH,
stack out -2, PUH, CT wt to 74 k lbs,
RBIH, stack out -5 k, PU to 75 k lbs,
RBIH stack out -8 k, PU ,clean, PU 75
k, RBIH, all clean, PUH, all clean.
Pump additional sweeps, Pull 75 k Ibis
CT wt, no WOB, @ 8090 in the build,
continue out of hole.
larg neg WOB @ 7947', 7907', & 7817'
with small Ct Wt overpulls, continue
up hole, window clean.
Make two passes to the tubing tail
cleanin up the 7" RBIH
8/28/2018
8/28/2018
0.20
PROD2
DRILL
TRIP
P
RIH to clean up build.
7,700.0
7,840.0
15:06
15:18
Set down in window - 7818', PU 45 k
lbs, RBIH 19 fUmin, pumps down while
transiting the window, clean.
8128/2018
8/28/2018
0.20
PROD2
DRILL
DLOG
P
Tie into the RA tag for+13' correction.
7,840.0
7,860.0
15:18
15:30
Page 9/30 Report Printed: 9119/2018
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Srea Trcne
Erb Tpre
Dur(ly)
Phase
Op Code
Activity Code
Time P -T -X
Oparadon
M(B)
End Depth(N(B)
8/28/2018
8/28/2018
0.30
PROD2
DRILL
WPRT
P
Continue to RIH in an atempt to clean
7,840.0
8,295.0
15:30
15:48
up the build section. Multiple set
downs and WOB spikes with
asociated coil wt spikes, 7956', 7960',
7995',8024',8119',
8/28/2018
8128/2018
1.50
PROD2
DRILL
WPRT
P
Pump 2x 10x10 sweeps, spaced apart
8,295.0
7,751.0
15:48
17:18
and chased up hole while pulling to
surface.
Slight neg WOB @ 8193', and 8160'.
7899' pulled -18 k WOB, worked pipe.
Window clean.
8/28/2018
6/28/2018
1.37
PROD2
DRILL
WPRT
P
Continue POOH (Swab Wiper),
7,751.0
79.0
17:18
18:40
1
1
pumping 1.71 bpm @ 4,989 psi
8/28/2018
8/28/2018
1.33
PROD2
DRILL
TRIP
P
Tag up, reset counter, set depths, RIH,
79.0
7,560.0
18:40
20:00
pumping 0.43 bpm @ 2,174 psi
8/28/2018
8/28/2018
0.20
PROD2
DRILL
DLOG
P
Log the Kt marker correction of plus
7,560.0
7,594.0
20:00
20:12
1.0', PUW=46 k
8/28/2018
8/2812018
0.22
PROD2
DRILL
TRIP
P
Continue IH
7,594.0
7,805.0
20:12
20:25
6/28/2018
8/28/2018
0.40
PROD2
DRILL
TRIP
P
Obtain Static Pressure, bleed down to
7,805.0
7,805.0
20:25
20:49
11.6 ppg (3835 psi), 20 min 10.6
(3,601 psi)
8/28/2018
8/28/2018
2.50
PROD2
DRILL
TRIP
P
Continue IH towards bottom, (7,964',
7,805.0
11,293.0
20:49
23:19
7,994', & 8,029), confirm TD 11,293'
8/28/2018
8/28/2018
0.50
PROD2
DRILL
CIRC
P
PUW=68 k, send liner pill down coil
11,293.0
11,293.0
23:19
23:49
8/28/2018
8/29/2018
0.18
PROD2
DRILL
TRIP
P
POOH, laying in 11.7 ppg beaded liner
11,293.0
10,946.0
23:49
00:00
running pill
8/29/2018
8/29/2018
1.15
PROD2
DRILL
TRIP
P
Continue POOH, laying in 11.7 ppg
10,946.0
7,720.0
00:00
01:09
beaded liner running pill up to 7,720'
8/29/2018
8/29/2018
1.50
PROD2
DRILL
TRIP
P
Continue POOH, displacing well to
7,720.0
79.0
01:09
02:39
11.7 ppg completion fluid
8/29/2018
8/29/2018
0.50
PROD2
DRILL
OWFF
P
Al surface, check well for flow, PJSM
79.0
79.0
02:39
03:09
for LD tools.
8/29/2018
8/29/2018
1.25
PROD2
DRILL
PULD
P
LD drilling BHA on a dead well.
79.0
0.0
03:09
04:24
Note: Inspected Coil (0.120")
8/29/2018
8/29/2018
1.00
COMPZ2
CASING
PUTS
P
Prep RF for liner ops
0.0
0.0
04:24
05:24
8/29/2018
8/29/2018
3.10
COMPZ2
CASING
PUTS
P
Make up lower completion, non ported
0.0
1,545.0
05:24
08:30
bull nose, 50 joints, 4.6 ppf L-80
slotted liner, (1545'), under a shorty
deployment sleeve, min ID
Crew change w 19 joints in the hole,
made up safety joint for hand over.
Joint # 48 (31.76') slightly bent,
decided to swap out, replaced with
joint # 51 ( 31.77').
8/29/2018
8/29/2018
1.30
COMPZ2
CASING
PUTS
P
PJSM, MU BHA# 14, AL1 lower liner
1,545.0
1,590.0
08:30
09:48
running assembly, skid cart, inspect
pack offs - replaced, pull and replace
upper checks, stab injector, bump up,
reset counters.
8/29/2018
8/29/2018
1.60
COMPZ2
CASING
RUNL
P
RIH pumping min rate, CT Wt 8.63 k
1,545.0
7,954.0
09:48
11:24
lbs at surface.
Pu Wt 52 k lbs, Tie into flag for -8.3'
correction.
Continue to run in hole.
Lost 7 bbls on the trip in.
Page 10130 ReportPrinted: 911912018
Operations Summary (with Timelog Depths)
IH -21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Depth
startTime
End Time
Dur(hr)
Phase
Op r:oae
AcGvM1y Code
Time P -T -X
operation
ud(a)
End Depth (9101)
8/29/2018
8/29/2018
1.10
COMM
CASING
RUNL
P
Set down, 7954, slid through
1,545.0
8,495.0
11:24
12:30
Set down again 7986', tried multiple
attempts and multiple speeds and S/D
weights, tried rolling the pump.
No apparent progress. CT PU Wt 52
k lbs, WOB -13 it Ibs until it breaks
free and returns to -5.6 k lbs. 17 S/D's
Picked up above original S/D, RIH,
slight bobble and bouoed through.
SID @ 8355' slowly slid through,
8398', 6460'
8/29/2018
8/29/2018
0.60
COMPZ2
CASING
RUNL
P
SD @ 8495', PIU, Pulled -23 k WOB,
8,495.0
8,500.0
12:30
13:06
-
cycled pipe to 74 K Ct Wt, pulled free,
RBIH, setting down and draging heavy
when PU to 75 k lbs. PUH to 8325'
RBIH, lost ground, SID 8438'. Work
pipe, -9 to -20 k WOB, CT Wt 48 - 68 it
lbs when POOH. start making hole
again slowly
8/29/2018
8/29/2018
2.10
COMPZ2
CASING
RUNL
P
Working pipe up to 80 k CT wl, - 24 K
8,500.0
9,432.0
13:08
15:12
1
1
WOB, on pickups, RIH, SID PU
8129/2018
8/29/2018
5.00
COMPZ2
CASING
RUNL
P
Continue working pipe towards
9,432.0
9,677.0
15:12
20:12
bottom, PUW 60 k, PUDHWOB=minus
12k
8/29/2018
8/2912018
0.80
COMPZ2
CASING
RUNL
P
Continue IH @ 30 fpm to bottom
9,677.0
11,293.0
20:12
21:00
11,288'
8/29/2018
8/2912918
0.20
COMPZ2
CASING
RUNL
P
PUW=62 k, set back down, minus 2.5
11,293.0
11,293.0
21:00
21:12
k, bring pump up to 1.5 bpm @ 3,900
psi, 0.75 bpm returns, PUW= 48 k,
liner is gone, remove liner length from
counters,
8129/2018
6/29/2018
0.75
COMPZ2
CASING
CIRC
P
Finish building and circulate 11.7 ppg
11,293.0
11,293.0
21:12
21:57
beaded liner running pill.
8/29/2018
8/29/2018
1.00
COMPZ2
CASING
TRIP
P
POOH, laying in 11.7 ppg beaded liner
11,293.0
7,545.0
21:57
22:57
running pill to 7,650'
8129/2018
8/29/2018
0.20
COMPZ2
CASING
DLOG
P
Log K1 marker correction of plus 16.5'
7,545.0
7,563.0
22:57
23:09
8129/2018
8/30/2018
0.85
COMPZ2
CASING
TRIP
P
POOH to surface
7,563.0
2,465.0
23:09
00:00
8/30/2018
8/3012018
0.25
COMPZ2
CASING
TRIP
P
Continue POOH
2,465.0
44.2
00:00
00:15
8/30/2018
8/30/2018
0.50
COMPZ2
CASING
OWFF
P
At surface, check well for flow, PJSM
44.2
44.2
00:15
00:45
for liner ops
8/30/2018
8/30/2018
0.25
COMM
CASING
PULD
P
LD setting tools
44.2
0.0
00:45
01:00
8/30/2018
8/302018
0.25
COMPZ2
CASING
PUTB
P
Prep RF for liner ops
0.0
0.0
01:00
01:15
8/30/2018
8/30/2018
2.00
COMPZ2
CASING
PUTB
P
PU/MU ALU liner segment #2 w/30 jts
0.0
940.9
01:15
03:15
of slotted liner and ported bullnose
8/30/2018
8/30/2018
0.75
COMPZ2
CASING
PULD
P
PU/MU Coiltrak tools and BOT 3" GS,
940.9
985.1
03:15
04:00
stab INJH, surface test CTT (good -
test)
8/30/2018
8/30/2018
3.00
COMPZ2
CASING
RUNL
P
Tag up reset counters, RIH
985.1
9,751.0
04:00
07:00
window flag correction -6.43'
Wt check above the window - 49 k lbs
Tie into the 1<1 for a +5.5' correction,
continue to RIH, tag bottom @ 9751'
PU wt 54 k lbs, RBIH, stak 2 k lbs,
Release off liner, PU 43 it lbs,
`"' TOL 8310'
8/30/2018
8/30/2018
1.10
COMPZ2
CASING
CIRC
P
PUH, correct depths, circulate 18 bbl
9,751.0
8,795.0
07:00
08:06
1
beaded liner running pill to GS
Page 11130 Report Printed: 911912018
Operations Summary (with Timelog Depths)
11-1-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Depth
SW Time
EM Tuna
Dix thr)
Phase
Op Code
Advity CMe
Tyne P-T-X
Operadon
(110)
EM DeA (WB)
8/30/2018
8/30/2018
0.50
COMPZ2
CASING
DISP
P
PU 48 k lbs, POOH hole laying in
8,795.0
7,540.0
08:06
08:36
beaded liner running pill to 7,663'
8/30/2018
8/30/2018
0.20
COMPZ2
CASING
DLOG
P
Tie into the K1 for a +2.5' correction
7,540.0
7,565.5
08:36
08:48
8/30/2018
8/30/2018
1.50
COMPZ2
CASING
TRIP
P
Continue to POOH
7,565.5
50.0
08:48
10:18
8/30/2018
8/30/2018
0.70
COMPZ2
CASING
PULD
P
Bump up, space out, Flow check, LD
50.0
0.0
10:18
11:00
1
1
BHA# 15
8/30/2018
8/30/2018
0.50
COMPZ2
CASING
PUTB
P
Prep floor to run liner, PJSM
0.0
0.0
11:00
11:30
8/30/2018
8/30/2018
1.20
COMPZ2
CASING
PUTB
P
PU AL1 section#3 completion,3
0.0
863.8
11:30
12:42
pups, 27 joints, ( 863.78'), under
shorty with a ported bullnose. Kick
drill, AAR, PJSM. clear flow.
8/30/2018
8/30/2018
1.20
COMM
CASING
PULD
P
PU BHA #15-AL1 section#3
863.0
908.0
12:42
13:54
completion, check pack offs, skid cart
stab on bump up space out.
8/30/2018
8/30/2018
220
COMPZ2
CASING
RUNL
P
RIH WBHA #13. Tie into flag for-0.2'
908.0
8,812.0
13:54
16:06
correction, PU 48 k lbs, continue to
RIH. drive by the Kt for a +0.5'
correction. Continue in hole, tag up,
8812', PU Wt 53 k lbs, RBIH, set down
2 k lbs WOB, online w pump, PU Wt
42 k lbs.
"`TOL 7947'
8/30/2018
8/30/2018
1.40
COMPZ2
CASING
TRIP
P
Park, reset counters, POOH.
8,812.0
59.9
16:06
17:30
8/30/2018
8/30/2018
0.50
COMM
CASING
OWFF
P
At surface, check well for flow, Crew
59.9
59.9
17:30
18:00
change, PJSM
8/30/2018
8/30/2018
0.50
COMM
CASING
PULD
P
LD setting tools
59.9
0.0
18:00
18:30
8/30/2018
8/30/2018
0.50
COMPZ2
CASING
PULD
P
PU/MU, Open hole anchored billet w/
0.0
72.9
18:30
19:00
BOT J-hydraulic setting tool
8/30/2018
8/30/2018
0.25
COMPZ2
CASING
PULD
P
PU/MU, Coiltrak tools, stab INJH,
72.9
72.9
19:00
19:15
perform surface lest (good-test)
8/30/2018
8/30/2018
2.00
COMPZ2
CASING
RUNL
P
RIH, with BHA#17 Open Hole
72.9
7,565.0
19:15
21:15
Anchored Billet, @ 80 fpm/20 fpm
ewelry
8/30/2018
8/30/2018
0.20
COMPZ2
CASING
DLOG
P
Log the K1 marker no correction,
7,565.0
7,608.0
21:15
21:27
PUW 50 k
8/30/2018
8/30/2018
0.20
COMPZ2
CASING
RUNL
P
Continue IH, tagging TOL @ 7,947 psi
7,608.0
7,947.0
21:27
21:39
8/30/2018
8/30/2018
0.20
COMPZ2
CASING
RUNL
P
Set down 4.5 k DHWOB, PUW 49 k,
7,947.0
7,947.0
21:39
21:51
repeat, PUH to 0.3 k DHWOB, bring
pump up 1.4 bpm, seen tool shift
3,077 psi, creep in hole back to 4.5 k,
7,947', PUW 44 k
8/30/2018
8/30/2018
1.20
COMPZ2
CASING
TRIP
P
POOH
7,947.0
53.3
21:51
2303
8/30/2018
8/30/2018
0.50
COMM
CASING
OWFF
P
Atsurface, check well for flow, PJSM
53.3
53.3
23:03
23:33
8/302018
8/31/2018
0.46
COMPZ2
CASING
PULD
P
LD setting tools
53.3
0.0
23:33
00:00
8/31/2018
6/312018
1.00
FROM
DRILL
CTOP
P
MU Noule, stab INJH, jet surface
0.0
0.0
00:00
01:00
lines and stack, while displacing coil to
FW.
Sim-ops: grease valves and bop
equipment.
8/31/2018
8/31/2018
0.75
FROM
DRILL
CTOP
P
Valve shop on location, service tree,
0.0
0.0
01:00
01:45
1
RD nozzle, remove BHI upper quick,
cuttremove CTC, boot a-line
Page 12130 ReportPrinted: 9119/2018
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Shift Depth
Stan Time
End Tena
Dur(lid
Phase
Op Code
Activity Code
Time PJA
Operation
CWJ3)
End Depth(flKe)
8/31/2018
8/31/2018
0.25
PRODS
DRILL
CTOP
P
Stab INJH, use both pumps, pump
0.0
0.0
01:45
02:00
slack
8/31/2018
8/31/2018
0.25
PRODS
DRILL
CTOP
P
Test inner reel valve and pac-off,
0.0
0.0
02:00
02:15
unstab INJH
8/31/2018
8/31/2018
0.50
FROM
DRILL
CTOP
P
PJSM, RU coiled tubing cutter
0.0
0.0
02:15
02:45
8/31/2018
8/31/2018
1.00
PRODS
DRILL
CTOP
P
Cut Coiled tubing back to locate wire
0.0
0.0
02:45
03:45
(140))
8/31/2018
8/31/2018
2.45
PROD3
DRILL
CTOP
P
Install CTC, pull lest to 35 k good,
0.0
0.0
03:45
06:12
install UCQ, pressure test good,
tested wire 1700Mohms, 69.8 ohms.
8/31/2018
8/3112018
1.30
FROM
WHDBOP
CTOP
P
Prep for BOP test, grease and service
0.0
0.0
06:12
07:30
valves, flood up. shell test - 3000 psi.
8/31/2018
8/3112018
6.50
FROM
WHDBOP
BOPE
P
Prep for BOP test, grease and service
0.0
0.0
07:30
14:00
valves, flood up. shell test - 3000 psi.
" Start test 7:30
Tree swab leaking slighlty
Annular test took 52 minutes to trouble
shoot some issues.
8/31/2018
813112018
1.00
FROM
WHDBOP
CTOP
P
Clear floor from BOP testing, Valve
0.0
0.0
14:00
15:00
check list.
8/31/2018
8131/2018
0.50
FROM
DRILL
SVRG
P
Took 30 minutes, rig service timet o
0.0
0.0
15:00
15:30
allow for Washington crane inspector
to finish work on injector.
8/31/2018
8131/2018
1.20
FROM
DRILL
CTOP
P
Skid cart, install nozzle, slab injector,
0.0
0.0
15:30
16:42
tum reel over to kill weight fluid.
PJSM, Open up to well, fill 3 bbls,
flow check - good, unstab injector, skid
cart.
8/31/2018
8131/2018
0.70
FROM
STK
PULD
P
PU BHA#18,AL2 lateral drilling
0.0
72.2
16:42
17:24
assembly, Re Run Baker dynamus bit
under a 0.4+°AKO motor.
8/3112018
8/31/2018
0.50
FROM
STK
TRIP
P
RIH
72.2
507.0
17:24
17:54
8/31/2018
8/31/2018
0.50
FROM
STK
TRIP
T
BHI MWD, check shots reviled
507.0
72.2
17:54
18:24
incontinency with the Hydraulic
orienting Tool, Pull back to surface
8/31/2018
8/31/2018
0.50
FROM
STK
PULD
T
PJSM, swap out HOT tools
72.2
0.0
18:24
18:54
8/31/2018
8/31/2018
0.25
FROM
STK
PULD
P
MU UQC, surface test tools (good-
0.0
72.2
18:54
19:09
test), stab INJH, tag up reset counters
8/31/2018
8/31/2018
1.50
FROM
STK
TRIP
P
RIH
509.0
7,565.0
19:09
20:39
8/31/2018
8/31/2018
0.20
FROM
STK
DLOG
P
Log the K1 marker no correction
7,565.0
7,598.0
20:39
20:51
8/31/2018
8/31/2018
0.65
FROM
STK
DISP
P
Finish displacing well to drilling fluid
7,598.0
7,805.0
20:51
21:30
8/31/2018
8/31/2018
0.20
FROM
STK
TRIP
P
Close EDC, PUW 48 k
7,805.0
7,805.0
21:30
21:42
8131/2018
8/31/2018
0.30
FROM
STK
TRIP
P
Continue IH through window dry tag
7,805.0
7,935.0
21:42
2200
TOB @ 7,935', PUH, attempt to roll TF
180', RIH, stack out, PBUH, roll TF as
drilled, park 7,932'
8/31/2018
8/31/2018
1.25
FROM
STK
KOST
P
Bring pump online 1.75 bpm at 4,195
7,935.0
7,937.0
22:00
23:15
psi, WHP=274, BHP=4074, ]A=O,
OA=47, kickoff billet as per RP
8/31/2018
8/31/2018
0.25
PRODS
DRILL
DRLG
P
Drill Ahead, 1.75 bpm at 4,140 psi,
7,937.0
7,939.3
23:15
23:30
Diff=516 psi, WHP=304, BHP=4,055
psi, IA=O, OA=49
Page 13/30 Report Printed: 911912018
Operations Summary (with Timelog Depths)
1H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Stmt Time
End TM
Dur (hr)
Phase
Din Cade
Wvdy Code
Time P -T -X
Operation
011®)
End Depth (WB)
8/31/2018
8/31/2018
0.20
PRODS
DRILL
DRLG
P
Stack out weight, shutdown pump,
7,939.3
7,939.3
23:30
23:42
PUH 56 k to 7,930', RBIH, dry tag
7,939.3'
8/31/2018
9/1/2018
0.30
PRODS
DRILL
DRLG
P
PUH 7,930', PUW 52 k, bring pump on
7,939.3
7.939.6
23:42
00:00
-line 1.77 bpm at 4,288 psi, Diff -464
psi, WHP=261, BHP=4,037, IA=O,
OA=49
9/1/2018
9/1/2018
1.00
PRODS
DRILL
DRLG
P
OBD, 1.77 bpm at 4,177 psi, Diff=467,
7,939.6
7,951.9
00:00
01:00
1
WHP=316, BHP=4,067, IA=O, OA=52
9/1/2018
9/1/2018
2.00
PRODS
DRILL
DRLG
P
OBD, 1.79 bpm at 4,154 psi, Diff -467
7,951.9
7,966.0
01:00
03:00
psi, WHP=314, BHP=4,054, IA=O,
OA=53
9/1/2018
9/1/2018
1.75
PRODS
DRILL
DRLG
P
OBD, 1.76 bpm at 4,151 psi, Diff=467
7,966.0
7,972.0
03:00
04:45
psi, WHP=295, BHP=4,076, IA=7,
OA=57
""' Note: Bit balling PUH creep in hole
slowly, continue drilling ahead slowly
@ 20 fph
9/1/2018
9/1/2018
2.00
PROD3
DRILL
DRLG
P
OBD, 1.77 bpm at 4,250 psi, Diff -'4137
7,972.0
8,028.0
04:45
06:45
psi, WHP=329, BHP=4,039, IA=19,
OA=58
Pump 5x5 sweep
9/1/2018
9/1/2018
1.00
PRODS
DRILL
DRLG
P
OBD, CT 4403 psi, WH 317 psi, 4145
8,028.0
8,100.0
06:45
07:45
psi annular, IA 54 psi, OA 60 psi
Ratty drilling cleaned up, ROP 70 fUhr,
CT Wt 16 k lbs, WOb 1.9 k lbs
Some aluminum, clean cuttings,
stickier than normal.
Pump 5x5 sweep in anticipation of TD.
9/1/2018
9/1/2018
0.30
PRODS
DRILL
WPRT
P
TO build early per DD and Geo.
8,100.0
7,957.0
07:45
08:03
PU 52 k lbs, sweeps out the bit, chase
up hole to M, while slowly PUH.
Orient low side for billet, small neg
WOB tug while orienting, small neg
WOB spike passing the billet at min
rate.
RBIH, dry drift billet, small WOB spike
below the billet, assuming BHA
binding up.
9/1/2018
9/1/2018
1.70
PRODS
DRILL
TRIP
P
PU, 50 k lbs,
7,957.0
71.0
08:03
09:45
POOH, billet clean again. Pull through
window clean.
Slow pass at rate cleaning up 7" to TT,
Pull into tubing, Open EDC.
POOH for let drilling BHA
9/1/2018
9/1/2018
2.30
PRODS
DRILL
PULD
P
PJSM, discussed high bend motor,
71.0
0.0
09:45
12:03
bump up, attempt to pull tool, hung up
from the outset, PJSM, pop off, orient
tool 180', reattempt with DS PDL
winch, its a little faster, tool pulled free
with no issue. - 1 hr added time due
to hang up. PUD BHA #19.
9/12018
9/1/2018
1.30
PRODS
DRILL
PULD
P
PU BHA#20, AL2 lateral drilling
0.0
80.0
12:03
13:21
assembly, O.6° AKO, W HYC -
SR321 M -A1 11 mm w 3D nose cutters,
test good, skid cad, stab injector,
Pump up, set counters
9/1/2018
9/12018
1.40
PRODS
DRILL
TRIP
P
RIH, close EDC, Test agitator @ 1.7
80.0
7,565.0
13:21
14:45
bpm and 500'- good, continue in hole.
9/1/2018
9/1/2018
0.20
PRODS
DRILL
DLOG
P
Tie into the K1 for a 0.5' correction,
7,565.0
7,590.0
14:45
14:57
9/1/2018
9/1/2018
0.50
PRODS
DRILL
TRIP
P
CT PU Wt, 44 k lbs, continue to RIH,
7,590.0
8,101.0
14:57
15:27
window and billet both clean, build
clean.
Page 14130
ReportPrinted: 911912018
„ Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Tune
Dumr)
phase
Op Code
Activity code
Imre P -T-%
opened.
S'(KKBcej�
End Depth (MB)
9/1/2018
9/1/2018
1.90
PR5D3
DRILL
DRLG
P
CT 4176 psi @ 1.77 bpm, annular
8,101.0
8,220.0
1527
1721
4124 psi, Free spin diff 960 psi.
OBD, CT Wt 15.6 k lbs. WOB 2.0 k
lbs, ROP 70 Mr.
9/1/2018
9/1/2018
4.50
PRODS
DRILL
DRLG
P
OBD, 1.80 bpm at 4,851 psi,
8,220.0
8,505.0
1721
21:51
Diff --1,100 psi, BHP=4,155, IA=212,
OA=57
9/1/2018
9/1/2018
0.25
PRODS
DRILL
WPRT
P
Wiper up hole to 8,100'w/sweeps,
8,505.0
8,100.0
21:51
22:06
PUW=53 k
9/12018
9/1/2018
0.25
PRODS
DRILL
WPRT
P
Wiper back in hole, RM
8,100.0
8,505.0
22:06
22:21
9/1/2018
92/2018
1.65
PRODS
DRILL
DRLG
P
BOBD, 1.82 bpm @ 4,707 psi,
8,505.0
8,612.0
22:21
00:00
Diff --1,000 psi, WHP=263,
BHP=4,134, IA=213, OA=57, Avg.
ROP=60 fph/2.6 k DHWOB
9/2/2018
9/2/2018
1.30
PRODS
DRILL
DRLG
P
OBD, 1.79 bpm at 4,977 psi,
8,612.0
8,692.0
00:00
01:18
Diff=1,000 psi, WHP=251,
BHP=4,170, IA=346, OA=60
9/2/2018
92/2018
0.80
PROD3
DRILL
DRUG
P
OBD, 1.78 bpm at 5,339 psi,
8,692.0
8,768.0
01:18
02:06
Diff=1,100 psi, WHP=256,
BHP=4,156, IA=365, OA=60,
Avg.Rop=65 fph/2.4 k DHWOB
9/22018
922018
1.80
PRODS
DRILL
DRLG
P
OBD, 1.80 bpm @ 5,209 psi,
8,768.0
8,930.0
02:06
03:54
Diff --1,050 psi, WHP=275,
BHP=4,221, IA=396, OA=61, Avg.
R0P=112 fph
9/2/2018
9/2/2018
1.00
PRODS
DRILL
WPRT
P
Wiper up hole to the window, PUW 53
8,930.0
7,840.0
03:54
04:54
k, jog the 7” casing with sweeps up to
—0
7,707'. circulate BU.
9/2/2018
9/2/2018
20
PROD3
DRILL
DLOG
P
Log the K1 marker correction of plus
7,840.0
7,877.0
04:54
05:06
4,5'
RW2018
92/2018
0.50
PRODS
DRILL
WPRT
P
Wiper back in hole, RUN 14 k
7,877.0
8,930.0
05:06
05:36
Seeing same MWD issues as
yesterday, tool is rolling as we near
the window and billet.
Possibly geometry issues, not
electrical.
92/2018
9/2/2018
2.40
PRODS
DRILL
DRLG
P
Free spin diff 970 psi*, initially 1,100
8,930.0
9,153.0
05:36
08:00
psi dropped once we were on bottom
for a bit.
IA470 psi, OA64 psi, CT 5142 psi, @
1.78 bpm, Annular 4172 psi
CT Wt - 6 k lbs, WOB 1-2 k lbs, ROP
60 - 150 ft/hr • some siderite chips in
the cuttings samples
Average ROP over section - 93 Nhr
9/2/2018
9/2/2018
0.20
PRODS
DRILL
WPRT
P
PU Wt 54 k lbs, Geo wiper to 9,47',
9,153.0
9,153.0
08:00
08:12
RBIH, RIH Wt 12 k lbs
.
. - 1,700' on the mud, solids @ 0.7,
inlet density up to 8.87 ppg
Geo asked for 16' decrease in TVD in
the next 100' feet,
9/2/2018
9/2/2018
2.30
PRODS
DRILL
DRLG
P
CT 4953 psi, @ 1.78 bpm, Annular
9,153.0
9,299.0
08:12
10:30
4195 psi, Free spin diff 950psi
OBD, CT Wt 0-2 k lbs, WOB 1.6 k lbs,
ROP 100 ft/hr
BHA wipers, PU's - 50 k lbs, hard
stringers. resistivity increasing from
9180' on.
Lots of tool face changes, Pick ups
climbed from 50 to 68 k. Pump
sweeps.
Pick ups still climbing,..
Average ROP over section - 63 fUhr
Page 15130 ReportPrinted: 9/1912018
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Siad Oeplh
SWTime
End Time
Durthd
Phase
Op Code
Actv'ily Code
Time P -T -x
Operation
(MB)
End DepN(flKB)
9/2/2018
9/212018
0.50
PRODS
DRILL
WPRT
P
PU Wt 71 k lbs, Pull wiper early. #1
9,299.0
8,100.0
10:30
11:00
-1.2 k WOB pull @ 9257', we'd had
issues passing this spot earlier on
BHA wipers
Seeing free spin diff fluctuate from 960
psi to 1200 psi.
It doesn't appear to be motor work,
agitator kicking in and out??
9/2/2018
9/2/2018
0.70
PRODS
DRILL
WPRT
P
RBIH
8,100.0
9,299.0
11:00
11:42
SD - 8686' PU 52 k, RBIH, 500 lb
WOB spike at 8700,
SD,- 8960', PU 50 k,
SD,- 92281, PU 50 k,
9/2/2018
9/2/2018
3.40
PRODS
DRILL
DRLG
P
CT 5121 psi, @ 1.79 bpm, Annular
9,299.0
9,490.0
11:42
15:06
4142 psi, Free spin diff 1140psi
OBD, CT Wt -2-2 k lbs, WOB 1.3 k lbs,
ROP 100 ft/hr Pick ups —52-62 k lbs.
Start exporting mud outside - 12:49 -
in prep for mud swap.
Started new mud @ 14:30
'."New mud at the bit - 9487'
Average ROP over section - 76 ft/hr
9/2/2018
912/2018
2.20
PRODS
DRILL
DRLG
P
PU to get new parameters
9,490.0
9,564.0
15:06
17:18
CT 4744 psi, @ 1.8 bpm, Free spin
940 psi - annular 4190 psi
OBD CT -4-0 k lbs, WOB 1.6 to 2 k
lbs. ROP 60 - 10 ft(hr
On somthing hard starting 9546'
9/2/2018
9/2/2018
1.50
PROD3
DRILL
DRLG
P
BOBD, 1.77 bpm at 4,180 psi,
9,564.0
9,621.0
17:18
18:48
Diff --1,100 psi, WHP=403,
BHP=4,165, IA=317, OA=62
9/2/2018
9/2/2018
0.20
PRODS
DRILL
WPRT
P
Pull Geo Wiper up hole PUW 61 k
9,621.0
9,520.0
18:48
19:00
9/2/2018
9/2/2018
0.20
PRODS
DRILL
WPRT
P
Wiper back in hole, RIW 12.4 k
9,520.0
9,621.0
19:00
19:12
9/2/2018
9/2/2018
2.50
PRODS
DRILL
DRLG
P
BOBO, 1.79 bpm at 4,650 psi,
9,621.0
9,702.0
19:12
21:42
Diff --1,120 psi, WHP=401,
BHP=4,167, IA=320, OA=62
9/2/2018
9/212018
1.25
PRODS
DRILL
WPRT
P
Wiper to the window, PUW 55 k, jog
9,702.0
7,840.0
21:42
22:57
the 7" with sweeps
9/2/2018
9/212018
0.20
PRODS
DRILL
DLOG
P
Log the RA marker correction of plus
7,840.0
7,864.0
22:57
23:09
6.0'
9/2/2018
9/2/2018
0.20
PRODS
DRILL
WPRT
P
Wiper back in hole, RIW 14 k
7,864.0
9,702.0
23:09
2321
9/2/2018
9/3/2018
0.65
PRODS
DRILL
DRLG
P
BOBD, 1.77 bpm at 4,583 psi, Diff
9,702.0
9,714.0
23:21
00:00
886, WHP=324, BHP=4,188, IA=292,
OA=61
9/3/2018
9/3/2018
1.25
PRODS
DRILL
DRLG
P
OBD, 1.77 bpm at 4,609 psi,
9,714.0
9,737.0
00:00
01:15
Diff=1,138 psi, WHP=332,
BHP=4,197, IA=311, OA=61
9/3/2018
9/3/2018
1.20
PRODS
DRILL
DRLG
P
OBD, 1.78 bpm at 4,690 psi, Diff --863,
9,737.0
9,745.0
01:15
02:27
WHP=362, BHP=4,182, IA=374,
OA=62
9/3/2018
9/3/2018
2.00
PROD3
DRILL
DRLG
P
OBD, 1.7 bpm at 4,576 psi, Diff=863
9,745.0
9,789.0
02:27
04:27
psi, WHP=367, BHP=4,190, IA=424,
OA=62
9/312018
9/3/2018
1.70
PRODS
DRILL
DRLG
P
OBD, 1.82 bpm at 4,727 psi, Diff -883
9,789.0
9,843.0
04:27
0609
psi, WHP=346, BHP=4,197, IA=489,
OA=63
Page 16130 ReportPrinted: 911912018
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Siad Time
Entl Tune
Dur (hr)
Phase
Op Cade
Activit' code
Tim P-TA
Operabon
sal Depen
(WB)
End Dept, (M)
9/3/2018
9/3/2018
2.50
PRODS
DRILL
DRLG
P
PU to check parameters, CT Wt 52 k
9,843.0
9,908.0
06:09
0839
lbs, IA 531 psi, OA 66 psi
CT 4780 psi @ 1.80 bpm, Annular
4232 psi, free spin 960 psi
OBD, CT Wt -2 k lbs, WOB 1 k lbs,
ROP 10-60
9852' on something hard, high
vibrations, drilled through
9861'- PU CT 52 k lbs, Choke acting
up, swap to choke B, choke B acting
up, blow down A. same issues on
both, drill ahead
9/3/2018
9/3/2018
0.20
FROM
DRILL
WPRT
P
On PU, rebooted the coke controler,
9,908.0
9,908.0
08:39
08:51
same issue, RBIH
Running off choke A in manual mode.
9/3/2018
9/3/2018
2.70
FROM
DRILL
DRLG
P
OBD, Ratty drilling, hard srtringers
9,908.0
9,987.0
08:51
11:33
with CT Wt -5k and 2 k WOB, ROP 2-
10 ft/hr for 1-2 feet
followed by CT Wt -41K, WOB 0.8 k
lbs & 40-100 ft/hr for 10-15'.
Average ROP over interval 29 ft/hr
9/3/2018
9/3/2018
2.00
FROM
DRILL
DRLG
P
PU WT 57 k lbs, bypass screens, RIH
9,987.0
10,018.0
11:33
13:33
Wt 9 k lbs, CT 4240 psi, 1.71 bpm,
Free spin 830 psi. WH 380 psi,
annular 4218 psi. OBD, CT Wt A k
lbs, WOB 1,4k lbs, ROP9.2
Pump 15 bbls of 1 ppb beads,
noticed .5 k lbs increase in WOB when
on the hard stuff, no other observable
benifits, CT weight, ROP, etc. Tried
same pill with 4% lubes, less of a
result. Beads in returns are causing
annular flucuations that are hard to
manage with the choke on manual.
9/3/2018
9/3/2018
4.00
FROM
DRILL
DRLG
P
Drill ahead hard stringers followed by
10,018.0
10,100.0
13:33
17:33
soft.
OBD, CT 4900 psi r@ 1.78 pbm,
Annular 4271 psi. WH 360 psi, IA 638,
OA 70 psi
CT Wl-4 k lbs, WOB 0.8 k lbs, ROP 8
Average ROP 20 ft/hr over interval.
9/3/2018
9/3/2018
1.80
FROM
DRILL
WPRT
P
Wiper to the window, PUW 50 k, jog
10,100.0
7,710.0
17:33
1921
the T with sweeps, up to 7,710'
9/3/2018
9/3/2018
0.15
PRODS
DRILL
SVRG
P
Reboot Choke software, (5 min)
7,710.0
7,840.0
19:21
19:30
9/3/2018
9/3/2018
0.20
PROD3
DRILL
DLOG
P
Log the RA marker correction plus 4.0'
7,840.0
7,868.0
19:30
19:42
9/312018
9/3/2018
0.80
FROM
DRILL
WPRT
P
Wiper back in hole, RIW 12 k
7,868.0
10,100.0
19:42
20:30
913/2018
9/3/2018
1.15
FROM
DRILL
DRLG
P
BOBD, 1.78 bpm at 4,837 psi,
10,100.0
10,125.0
20:30
21:39
Diff--863, WHP=308, BHP=4,216,
IA=548, OA=68
Average ROP 17 ft/hr over interval.
Page 17130 ReportPrinted: 9/1912018
Operations Summary (with Timelog Depths)
1 H-21
lip
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
sten Time
End Tone
Dur(hr)
Phase
OP Co
Activity CWe
Tyne P-T4
Operation
Stan Depth
WB)
End Depth (WB)
9/3/2018
9/3/2018
1.80
PROD3
DRILL
WPRT
P
Wiper up hole to the window, PUW 47
10,125.0
7,710.0
21:39
23:27
k
`"' Note: Pull heavy @ 7,896'- 7,906'
MD, CTWS=65 k, DHWOB= minus 12
k, RBIH to the EOB, PUH w/sweeps,
cleanup area between billet and
winodw, jog the 7" with sweeps,
18
9/4/2018
0.56
PRODS
DRILL
TRIP
P
POOH
7,710.0
5,571.0
23:27
23:27
00:00
9/4/2018
914/2018
1.25
PRODS
DRILL
TRIP
P
Continue trip to surface
5,571.0
78.2
00:00
01:15
9/4/2018
9/4/2018
1.75
PROD3
DRILL
PULD
P
PUD (ODS-PDL) AL2 drilling BHA#20
78.2
0.0
01:15
03:00
Note: Checks failed, change of
scope meeting in the ops cab,
continue PUD w/failed checks
checklist.
9/412018
9/4/2018
1.50
PROD3
DRILL
PULD
P
PD, pre-loaded DS PDL BHA#21,
0.0
78.1
03:00
04:30
stab INJH, surface test Coiltrak tools
(good-test)
914/2018
9/42018
1.50
PROD3
DRILL
TRIP
P
Tag up reset counters, RIH
78.1
7,298.0
04:30
06:00
9/4/2018
9/4/2018
0.20
PRODS
DRILL
DLOG
P
Tie into the K1 for no correction.
7,298.0
7,585.0
06:00
06:12
9/4/2018
9/4/2018
1.50
PRODS
DR ILL
TRIP
P
PU Wi 43 k lbs, continue in hole,
7,585.0
10,125.0
06:12
07:42
window and billet clean. Still having
erratic orienteer issues between the
window and the billet. WOB spike @
8187', 4 k & 8540, 1 k. Had to slow
down running speed from 50 to 17 ft/
min - 9100
SD - 9245', 9759' 10024',
9/4/2018
914/2018
2.30
PROD3
DRILL
TRIP
P
IA 152 psi, OA 59 psi, CT 5200 psi @
10,125.0
10,251.0
07:42
10:00
1.77 bpm, free spinn 1100 psi, WH
301 psi, Annular 4282 psi. RIH Wt 8 k
lbs
OBD, CT Wt 3 k lbs, WOB 2 k lbs,
ROP 30-160 ft/hr
Average ROP over interval - 54 fUhr
9/4/2018
9/42018
2.80
PROD3
DRILL
TRIP
P
OBD, CT Wt-3 k lbs, WOB 0.6 k Ibs,
10,251.0
10,360.0
10:00
12:48
ROP 40 ftlhr
Surface and WOB slowly falling off.
tried new mud pill, no change in
parameters.
PU weights - 55-59 k lbs
Average ROP over interval - 39 fUhr
9/4/2018
9/42018
1.20
PRODS
DRILL
TRIP
P
start pumping 1 ppb beaded pills built
10,360.0
10,425.0
12:48
14:00
of used mud. beaded pill at the bit @
10360'.
Weights and ROPs improved.
PU weights - 50 k lbs
Average ROP over interval - 54 fUhr
9/4/2018
9!4/2018
2.20
PROD3
DRILL
TRIP
P
Managed to break through what ever
10,425.0
10,525.0
14:00
16:12
was below us and get turned down
below 92'.
CT Wt -6 to -1 k lbs, WOB 2 to 0.6 k
lbs,
ROP 20 to 90 ft1hr
Settled in at - 86°
PU Wt's 50 k lbs
Average ROP over interval - 45 fUhr
9/4!2018
9!4/2018
0.30
PRODS
DRILL
TRIP
P
PU on wiper trip #1 PU Wt 55 k lbs -
10,525.0
9,526.0
16:12
16:30
1000'
Page 18/30 - ReportPrinted: 9/1912018
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Srert Time
9/4/2018
Eno Time
9/4/2018
Dur(h)
Phase
0 Code
P
Addvi Code
y
Time P -T-
X Operation
Srah Depth
(flKB)
End Depth (WB)
16:30
18:00
1.50
PROD3
DRILL
TRIP
P
RBIH
9,526.0
10,522.0
SD, 9561', PU, 50 k lbs, slow RIH
speed to -25 fUmin, continue in hole
Pump beaded sweep.
9/4/2018
9/4/2018
1.00
PROD3
DRILL
WPRT
P
Pull wiper to the casing, PUW 63 k,
10,522.0
7,705.0
18:00
19:00
(Town working on well plan changes)
9/4/2018
9/4/2018
0.40
PROD3
DRILL
WPRT
P
Jog the 7" x 2, PUW 42 k
7,705.0
7,840.0
19:00
19:24
9/4/2018
9/4/2018
0.20
PROD3
DRILL
DLOG
P
Log the RA, plus 6', PUW 43 k
7,840.0
7,868.0
19:24
1936
9/4/2018
19:36
9/4/2018
2.50
PROD3
DRILL
WPRT
P
Wiper back in hole, RIW= 0 k, send 5
7,868.0
10,525.0
22:06
x5 sweep with beads, work pipe back
to bottom.
9/4/2018
9/5/2018
1.90
PROD3
DRILL
ETR LG
P
BOBD, 1.79 bpm at 5,262 psi,
10,525.0
10,610.0
22:06
00:00
Diff=1,150 psi, WHP=283,
BHP=4,260.IA=575, OA=66
9/5/2018
9/5/2018
1.00
PROD3
DRILL
DRLG
P
OBD, 1.77 bpm at 5,478 psi,
10,610.0
10,630.0
00:00
01:00
Diff=1,200, WHP=298, BHP=4,313,
IA=622, OA=67
9/5/2018
9/5/2018
1.00
PROD3
DRILL
DRLG
P
OBD, 1.77 bpm at 5,472 psi,
10,630.0
10,667.0
01:00
02:00
Diff --1,300 psi, WHP=283,
BHP=4,302, IA=622, OA=67
9/5/2018
02:00
9/5/2018
02:30
0.50
PROD3
DRILL
-RP-RT
P
PUW 80 k, Pull 1,000' wiper up hole to
10,667.0
9,660.0
9,660'
9/5/2018
02:30
9/5/2018
03:42
1.20
PROD3
DRILL
WPRT
P
Wiper back in hole, RN2-6 k CTSW
9,660.0
10,667.0
9/5/2018
9/5/2018
2.30
PROD3
DRILL
DRLG
P
BOBD, 1.75 bpm at 5,437 psi,
10,667.0
10,712.0
03:42
06:00
Diff- 1,211 psi, WHP=277,
BHP=4,419, IA=566, OA=69
9/5/2018
06:00
9/5/2018
1.90
PR0D3
DRILL
DRLG
P
Drill ahead with poor weight transfer
10,712.0
10,756.0
0754
Average over interval 23 fUhr
9/5/2016
9/5/2018
0.60
PROD3
DRILL
WPRT
P
PU Wt 65 k on BHA wiper- 106'
10,756.0
10,756.0
07:54
08:30
Pull to 10,665' try to RBIH, S/D, PU 46
k lbs, to 10,650', RBIH
9/5/2018
9/5/2018
2.00
PROD3
DRILL
DRLG
P
Drilling ahead with poor weight
10,756.0
10,821.0
08:30
1030
transfer CT Wt -8 k lbs, WOB 2.4 k lbs
after a pick up but falls to 200 lbs
quickly after a pick up. Having issues
turning around after picking up. PU
weights climbed to 70 k. Mix and
pump 1 ppg beaded pill in new mud w
4% total lubes. ROP increased, RIH
ease increased, PU's fell to 55 k lbs.
Able to turn up and break through
hard layer that we'd been getting
deflected off.
Average over interval 32 f1hr
9/5/2018
9/5/2018
0.60
PR0D3
DRILL
WPRT
P
PU W153k on 1000' wiper#2
10,821.0
9,823.0
10:30
11:06
Pull to 10,665'try to RBIH, S/D, PU 46
k lbs, to 10,650', RBIH
9/5/2018
11:06
9/5/2018
0.60
PROD3
DRILL
WPRT
P
RBIH RIH Wt fell from 13 k lbs at turn
9,823.0
10,821.0
11:42
around to 6 k lbs by 10,500' and 4 k
lbs
at 12 ft/min and TD
9/5/2018
9/5/2018
3.30
PROD3
DRILL
DRLG
P
CT 5,420 psi @ 1.72 bpm, annular
10,821.010,932.0
11:42
15:00
4370 psi, WH 240 psi, Free spin diff
11,70 psi.
WOB -8 to 0 k lbs, WOB 2 to 0.6 k lbs,
ROP 80 to
Average over interval 33 ft/hr
Page 19/30 Report Printed: 9/19/2018
Operations Summary (with Timelog Depths)
1H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Siad Time
Entl Time
Dur (hr)
Phase
Op Code
r mdy Code
Tune P -T-%
operaaon
(fixe)
End Depth (MB)
9/5/2018
9/5/2018
2.50
PRODS
DRILL
DRLG
P
OBD, CT 5533 psi, @ 1.73 bpm, WH
10,932.0
11,007.0
15:00
17:30
287 psi, annular 4278 psi.
CT Wt -7.5 k lbs, WOB 1.3 k lbs, ROP
35f/m..
Bleed IA from 745 to 586 psi - diesel.
Average over interval 30 fUhr
9/5/2018
9/5/2018
5.75
PRODS
DRILL
DRLG
P
OBD, 1.8 bpm at 5,265 psi, Diff -1,207
11,007.0
11,130.0
17:30
23:15
psi, WHP=246, BHP=4,268, IA=574,
OA=74
- Note: Losses 0.6 bpm slowly
healing up to 0.1 bpm loss rate
11,110'
9/5/2018
9/5/2018
0.25
PROD3
DRILL
DRLG
P
TD AL2 Lateral, PUH slowly, PUW 55
11,130.0
11,130.0
23:15
23:30
k, circulate beads down coil.
9/5/2018
9/612018
0.50
PRODS
DRILL
WPRT
P
Perform Swab wiper, laying in beads
11,130.0
9,641.0
23:30
00:00
as we POOH to surface.
9/6/2018
9/6/2018
2.00
PRODS
DRILL
WPRT
P
Continue POOH
9,641.0
3,500.0
00:00
02:00
9/6/2018
9/6/2018
1.10
PRODS
DRILL
WPRT
P
Perform jog back in hole 500'
3,500.0
78.1
02:00
03:06
9/6/2018
9/6/2018
0.40
PRODS
DRILL
SVRG
P
Tag up, inspect INJH, repair CTES
78.1
78.1
03:06
03:30
counter, reset counters
9/6/2018
9/6/2018
1.25
PRODS
DRILL
TRIP
P
RBIH, to confirm TD
78.1
7,570.0
03:30
04:45
9/6/2018
9/6/2018
0.20
PRODS
DRILL
DLOG
P
Log the K1 marker correction of plus
7,570.0
7,753.0
04:45
04:57
1.0'
9/6/2018
9/6/2018
0.20
PRODS
DRILL
CTOP
P
Obtain Static BHP 11.39 ppg pressure
7,753.0
7,753.0
04:57
05:09
continued to drop, sensor Depth
6,484.67', AP=3,840
916/2018
9/6/2018
1.90
PRODS
DRILL
TRIP
P
Continue to RIH, Window clean, 705
7,753.0
11,128.0
05:09
07:03
Ib WOB bobble while passing the billet
and a nother @ 8519'. Coil weight fell
off rapidly from 9700'to 10,213' where
we sat down. PU 45 k lbs. continue to
RIH reducing tripping speed to - 14
ft/.min. WOB climbed stedily from
10,500'to 10,700'then fell off quickly.
Tqag bottom at 11128', PU 43 k lbs,
S/D again with same results.
9/6/2018
9/6/2018
3.10
PRODS
DRILL
DISP
P
PU 43 k lbs, Stage beaded liner
11,128.0
70.0
07:03
10:09
running pill to the bit, POOH laying in
liner running pill to 7,680' followed by
11.7 ppg KW fluid.
Painted yellow TD flag @ 10176'
Saw slight neg WOB spikes as we
pulled through both the billet and
window.
Painted white window flag Q 6778'
9/6/2018
9/6/2018
1.30
PRODS
DRILL
DISP
P
PJSM, bump up, flow check- good,
70.0
0.0
10:09
11:27
PUD BHA#21 Bit came out graded 1-3
LT, lost tooth on gauge reamers.
Well light, no losses.
9/6/2018
9/6/2018
0.30
COMPZ3
DRILL
BOPE
P
Perform BOP function test.
0.0
0.0
11:27
11:45
9/6/2018
9/6/2018
0.50
COMM
CASING
PUTS
P
Prep floor for running liner. PJSM.
0.0
0.0
11:45
12:15
9/6/2018
9/6/2018
1.70
COMPZ3
CASING
PUTS
P
Pick up an run 30 joints (937.63') 2-3/8
0.0
938.9
12:15
13:57
ST -L 4.6 Ib/fl L-80 slotted liner with a
non -ported bullnose under a shorty
deployment sleeve. AL2 completion
run #1 length over all - 938.87'- kick
drill, AAR, clean floor from running
liner.
Page 20130 ReportPrinted: 911912018
Summary (with Timelog Depths)
1 H-21
lipOperations
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Tme
Dur (hr)
Phase
Op Code
A Vdy Cade
Time P -T -X
Operation
(WS)
End Depth(flke)
9/6/2018
9/6/2018
1.00
COMPZ3
CASING
PULD
P
PU/MU BHA#22,AL2 completion
938.0
983.1
1357
14:57
run #1, swap checks, skid cart, stab
on, test good, bump up, set counters,
9/6/2018
9/6/2018
1.30
COMPZ3
CASING
RUNL
P
RIH w AL2 completion run #1
983.1
7,673.0
14:57
16:15
9/6/2018
9/6/2018
0.20
COMPZ3
CASING
DLOG
P
PU 45 k lbs, tie into window flag for-
7,673.0
7,683.0
16:15
16:27
4.4' correction
9/6/2018
9/6/2018
1.30
COMPZ3
CASING
RUNL
P
Continue to RIH, carried 16 k coil wt
7,683.0
11,128.6
16:27
17:45
all the way to bottom.
Tag up, PU 53 k lbs, pumps on PU 43
k lbs.
9/6/2018
9/6/2018
2.25
COMPZ3
CASING
TRIP
P
Reset counters, POOH painting flags.
11,128.6
44.2
17:45
20:00
9/6/2018
9/6/2018
0.50
COMPZ3
CASING
OWFF
P
Check well for flow, PJSM
44.2
44.2
20:00
20:30
9/6/2018
9/6/2018
0.25
COMPZ3
CASING
PULD
P
LD setting tools on a dead well
44.2
0.0
2030
20:45
9/6/2018
9/612018
2.25
COMPZ3
CASING
PUTB
P
PJSM, PU/MU AL2 #2 Liner segment
0.0
1,376.4
2045
23:00
45 jts of slotted liner, w/ported
bullnose, and shorty deployment
sleeve.
9/6/2018
9/6/2018
0.75
COMPZ3
CASING
PULD
P
PJSM, PU/MU Coillrak tools (good-
1,376.4
1,420.6
23:00
23:45
test)
9/6/2018
9/7/2018
0.25
COMPZ3
CASING
RUNL
P
RIH-, with BHA #23, AL2 liner segment
1,420.6
23:45
00:00
#2 w/45 jts of slotted liner, shorty
deployment sleeve, and ported
bullnose.
9!7/2018
9/7/2018
1.00
COMPZ3
CASING
RUNL
P
Continue IH with BHA #23
2,596.0
7,705.0
00:00
01:00
9/7/2018
9/7/2018
0.15
COMPZ3
CASING
RUNL
P
Weight check PUW 49 k, correct to
7,705.0
7,705.0
01:00
01:09
-
the EOP flag minus 8.0'
9!7/2018
9/7/2018
0.35
COMPZ3
CASING
RUNL
P
Continue IH
7,705.0
9,067.0
01:09
01:30
9/7/2018
9/7/2018
0.75
COMM
CASING
RUNL
P
Work pipe down hole, PUW 50-58 k
9,067.0
9,343.0
01:30
02:15
9n12018
9/7/2018
0.30
COMPZ3
CASING
RUNL
P
Continue RIH
9,343.0
10,189.1
02:15
02:33
9/7/2018
9/7/2018
1.30
COMPZ3
CASING
RUNL
P
Set down 10,189.13', PUW 58 k, set
10,189.3
8,812.7
02:33
03:51
back down 5.4 k, Bring pump on 1.45
bpm at 3,291 psi, 1.06 bpm returns,
PUW 39 k, remove liner length from
counters, finish building liner running
pill.
9/7/2018
9/7/2018
2.30
COMPZ3
CASING
TRIP
P
POOH, laying in 15 bbl beaded liner
8,812.7
40.0
03:51
06:09
running pill
9/7/2018
9/7/2018
0.60
COMPZ3
CASING
PULD
P
Bumped up, flow check good, hole
50.0
0.0
06:09
06:45
static.
9/7/2018
9/7/2018
0.30
COMPZ3
CASING
PUTB
P
Prep floor for liner running, PJSM.
0.0
0.0
06:45
07:03
9/7/2018
9/7/2018
1.00
COMPZ3
CASING
PUTB
P
Pick up an run 10 joints (312.94') 2-3/8
0.0
324.8
07:03
08:03
ST -L 4.6 Ib/ft L-80 slotted liner with a
non -ported bullnose under an
anchored liner top billet. AL2
completion run #3 length over all -
324.76 ' - clean floor from running
liner.
9/7/2018
917/2018
1.00
COMPZ3
CASING
PULD
P
PU BHA #24, stab on, set counters
324.8
385.7
08:03
09:03
9/7/2018
9/7/2018
1.70
COMPZ3
CASING
RUNL
P
RIH w AL2 -01 section #3, EDC open,
385.7
7,785.0
09:03
10:45
1
I
Page 21/30 Report Printed: 911912018
Operations Summary (with Timelog Depths)
1H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Siert nme
End Tvne
Dur(h)
Phase,
Op Code
Activity Ce
Tmie P -T -X
Operation
(RKB)
End Depth(ftKB)
9/7/2018
9/7/2018
0.20
COMPZ3
CASING
DLOG
P
Tie in to window flag, -25' correction,
7,785.0
7,785.0
10:45
10:57
discuss and compare, not making a
correction, continue on to the K1.
PU Wt 43 k lbs. Park Close EDC. RIH
to K1
9/7/2018
9/7/2018
0.10
COMPZ3
CASING
RUNL
P
Continue to RIH wAL2-01section #3,
7,785.0
7,885.0
10:57
11:03
EDC open,
9/7/2018
9/7/2018
0.10
COMPZ3
CASING
DLOG
P
Log Kt + 1' correction.
7,885.0
7,909.0
11:03
11:09
9/7/2018
9/7/2018
0.60
COMPZ3
CASING
RUNL
P
RIH, tag up 8817.5 PU 48 k lbs, RBIH
7,909.0
8,812.0
11:09
11:45
S/D 3.67 K lbs WOB, on line with the
pumpPU 42 k lbs,
Set Anchored billet slips oriented LS
9/7/2018
9/7/2018
1.70
COMPZ3
CASING
TRIP
P
POOH
8,812.0
60.0
11:45
13:27
9/7/2018
9/7/2018
1.00
COMPZ3
CASING
PULD
P
Flow check, inspected pipe 27' back to
60.0
0.0
13:27
14:27
coil connector wall thickness 1.81".
LD BHA#24 over a dead well. - Crew
change.
9/7/2018
9/7/2018
1.00
PROD4
STK
PULD
P
PU BHA#25, AL@ -01 latteral drilling
0.0
80.0
14:27
15:27
assembly, check pack offs,
9/7/2018
9/7/2018
1.60
PROD4
STK
TRIP -
P
RIH, shallow test occilator tool, light
80.0
7,565.0
15:27
17:03
vibration fell on the coil at surface.
Monitored frequency on pipe shed
computer @ 1.5 bpm - 3500 CT
pressure, 875 diff and 1.8 bpm - 5400
CT pressure, 1684 psi diff. Continue
to RIH.
9/7/2018
9/7/2018
0.20
PROD4
STK
DLOG
P
Tie into K1 for zero correction
7,565.0
7,595.0
17:03
17:15
9/7/2018
9/7/2018
1.20
PROD4
STK
TRIP
P
Continue to RIH, displacing well to
7,565.0
7,595.0
17:15
18:27
drilling fluid,
9/7/2018 -
9/7/2018
0.15
PROD4
STK
TRIP
P
Dry tag TOB @ 8,492'
7,595.0
8,492.0
18:27
18:36
9/7/2018
9/7/2018
1.50
PROD4
STK
KOST
P
PUH, and start kicking off billtet @
8,492.0
8,496.6
18:36
20:06
8491.5', 1.75 bpm at 5,172 psi,
WHP=181, BHP=4,216, IA=4, OA=54
9/7/2018
9/7/2018
0.15
PROD4
STK
KOST
P
Stall Motor, PUH 57 k, minus 2.3 k
8,496.6
8,473.0
20:06
20:15
DHWOB
9/7/2018
9/7/2018
0.15
PROD4
STK
KOST
P
RBIH, RIW 15 k, 1.81 bpm @ 5,337
8,473.0
8,496.0
20:15
20:24
psi, Diff -1,230 psi, WHP=100,
BHP=4,095, IA=5, OA=54
9/712018
9/7/2018
0.15
PROD4
STK
KOST
P
Stall Motor, PUW 47 k, PUH to 8,478'
8,496.0
8,478.0
20:24
20:33
9/7/2018
9!7/2018
0.15
PROD4
STK
KOST
P
RBIH, 1.8 bpm @ 5,387 psi,
8,478.0
8,500.0
20:33
20:42
Diff --1,210, WHP=124, BHP=4,235,
IA=8, OA=54
9/7/2018
9/7/2018
0.60
PROD4
STK
DRLG
P
Drill ahead
8,500.0
8,504.0
20:42
21:18
9/7/2018
9/7/2018
0.15
PROD4
STK
DRLG
P
PUH, PUW 51 k, dry drift kickoff point
8,504.0
8,504.0
21:18
21:27
(clean)
9/7/2018
9/7/2018
0.45
PROD4
STK
DRLG
P
BOBD, 1.8 bpm at 5,337 psi,
8,504.0
8,511.1
21:27
21:54
Diff --1,200, WHP=138, BHP=4,124,
IA=24, OA=56
9/7/2018
9/8/2018
2.10
PROD4
STK
WPRT
T
Stall motor, PUW=70 k, seems we are
8,511.1
8,511.1
21:54
00:00
detained, unable to turn orienter, work
pipe, still stuck, make call to town
team, discuss plan forward, bring
pump on-line, 1.5 bpm at 4,830 psi,
motor no longer stalled, circulate 5x5
around,
Page 22130 Report Printed: 9/1912018
. Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Start Time
End Time
Dur (hr)
(
phase
O Code
D
Actlhb Cede
Time P -T -X
Opendion
(ftKB)
End Depth (WS)
9/8/2018
9/8/2018
1.00
PROD4
STK
TRIP
T
Continue working pipe, spot lube pill
8,511.1
8,511.0
00:00
01:00
around BHA, continue working pipe.
still detained.
9/8/2018
9/8/2018
1.00
PROD4
STK
TRIP
T
Circulate lube pill up hole, work pipe,
8,511.0
8,511.0
01:00
02:00
still detained. Rotate HOT, torque
seen on coil. no movement on motor.
9/8/2018
9/8/2018
0.75
PROEM
STK
TRIP
T
Circulate 2nd 5x5 sweep
8,511.0
8,511.0
02:00
02:45
918/2018
9/8/2018
1.10
PROD4
STK
TRIP
T
Work pipe, Pull 86 k, minus 16.5 k
8,511.0
8,511.0
02:45
03:51
DHWOB
9/8/2018
9/8/2018
0.50
PROD4
STK
TRIP
T
Continue POOH
8,511.0
7,753.0
03:51
04:21
9/8/2018
9/8/2018
1.60
PROD4
STK
TRIP
T
Open EDC, coutinue POOH
7,753.0
70.0
04:21
05:57
9/8/2018
9/8/2018
1.50
PROD4
STK
PULD
T
Bump up, PUD BHA# 25. Bit had
70.0
0.0
05:57
07:27
chipped reamers but did not have
damage indicating we had spun it
against liner or slips.
9/8/2018
9/8/2018
1.40
PROD4
STK
PULD
T
LD pre loaded BHA in DS PDL,
0.0
96.1
07:27
08:51
dropped T weight bar and 1.4' knuckle
out of PDL. PU BHA# 26 to the HOT.
Hung off three pups, LOA 23.66' with a
ported bull nose over the hole (9.84',
7.84', 5.66'). Picked J setting tool /
billet / open hole anchors. PD, BHA,
stab on, verify EDC open, bump up
set counters.
9/8/2018
9/8/2018
2.60
PROD4
STK
TRIP
T
RIH,
96.1
7,600.0
08:51
11:27
9/812018
9/8/2018
0.20
PROD4
STK
DLOG
T
Tie into the K1 for no correction.
7,600.0
7,620.0
11:27
11:39
9/812018
9/8/2018
0.60
PROEM
STK
TRIP
T
Continue to RIH with anchored billet
7,620.0
8,509.0
11:39
12:15
into 7" Q 7806', PU Wt 45 k lbs, close
ECD, RIH to 8504', PU 46 k lbs, RBIH,
Bit depth 8502.5', PU to neutral
weight, online w pumps, shear - 4300
psi, RIH in attempt to stack weight.
Push to bit depth of 8509' with -500
lbs WOB.
" Note TOB @ 8474'
9/8/2018
9/8/2018
1.50
PROD4
STK
TRIP
T
POOH
8,509.0
71.0
12:15
13:45
9/8/2018
9/8/2018
1.10
PROD4
STK
PULD
T
Bump up space out, PUD BHA # 26
71.0
0.0
13:45
14:51
9/8/2018
9/8/2018
1.10
PROD4
STK
SVRG
T
Wait on arrival of billet w open hole
0.0
0.0
14:51
15:57
anchors.
9/8/2018
9/82018
1.60
PROD4
STK
PULD
T
PU & PD BHA# 27. Open hole
0.0
75.5
15:57
17:33
anchored billet w 2 pups 7.72', & 1.57'
with a ported bull nose. check pack
offs
9/82018
9/82018
1.75
PROD4
STK
TRIP
T
RIH, with BHA#27
75.5
7,580.0
17:33
19:18
9/8/2018
9/8/2018
0.20
PROD4
STK
DLOG
T
Log the K1 marker correction of plus
7,580.0
7,605.0
19:18
19:30
0.5', PUW 43 k, close EDC
9/8/2018
9/8/2018
0.50
PROD4
STK
TRIP
T
Continue IH, set down 8,474',
7,605.0
8,473.1
19:30
20:00
9/8/2018
9/8/2018
0.25
PROD4
STK
TRIP
T
PUW 49 k, set back down 2.2 k, PUH
8,473.1
8,452.3
20:00
20:15
46 k, 0.5 k DHWOB, bring pump up to
shear 4,900 psi
9/8/2018
918/2018
1.75
PROD4
STK
TRIP
T
PUH=48 k, POOH
8,452.3
61.2
20:15
22:00
9'812018
9/8/2018
0.92
PROD4
STK
PULD
T
Tag up space out, PUD & LD setting
61.2
0.0
22:00
22:55
tools
Page 23130
Report
Printed:
9 /1 912 01 8
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Tine
our (1y)
Mase
Op CodeACHrily
Code
Time P -T-%
Operetlon
Stat Depth
(ItKB)
End Depth(11KB)
9/8/2018
9/8/2018
0.30
PROD4
STK
PULD
T
Reconfigure BHA (MU motor and bit)
0.0
0.0
22:55
23:13
9/8/2018
9/9/2018
0.78
PROD4
STK
PULD
T
PD kickoff drilling BHA #28
0.0
0.0
23:13
00:00
9/9/2018
9/9/2018
0.50
PROD4
STK
PULD
T
MU Upper Quick, surface test Coiltrak
0.0
78.1
00:00
00:30
-
tools (good -test)
9/9/2018
9/9/2018
1.50
7R004
STK
TRIP
T
RIH, w/drilling BHA# 28, test agitator
78.1
7,570.0
00:30
02:00
1
1
1 @ 500' (good -test)
9/9/2018
9/9/2018
0.15
PROD4
STK
DLOG
T
Log the K1 marker correction of zero
7,570.0
7,590.0
02:00
02:09
9/9/2018
9/9/2018
0.20
PROD4
STK
TRIP
T
Continue IH
7,590.0
8,452.5
02:09
02:21
1
9/9/2018
9/9/2018
0.15
PROD4
STK
TRIP
T
Dry tag TOB @ 8452.5'
8,452.5
8,436.0
02:21
02:30
9/9/2018
9/9/2018
0.15
PROD4
STK
TRIP
T
Bring pump on-line @ 1.80 bpm at
8,436.0
8,453.7
02:30
02:39
5,294 psi, Diff=1,360 psi, WHP=336,
IA=O, OA=49
9/9/2018
9/9/2018
0.30
PROD4
STK
KOST
T
Attempt to find billet, 150° ROHS as
8,453.7
8,455.0
02:39
02:57
per RP, chase WOB to 8,455'
9/9/2018
9/9/2018
1.50
PROD4
STK
KOST
P
Start time milling 1.79 bpm @ 5,475
8,455.0
8,458.0
02:57
04:27
psi, Diff=1344 psi, WHP=149,
BHP=4,157, IA=O, OA=53
9/9/2018
9/9/2018
1.60
PROD4
DRILL
DRLG
P
Start drilling ahead 16 fph 1.79 bpm at
8,458.0
8,565.0
04:27
06:03
5,438 psi, Diff --1,360 psi, WHP=149,
BHP=4,173, IA=11, OA=55
9/9/2018
9/9/2018
0.20
PROD4
DRILL
WPRT
P
PU 48 k lbs, PUH, to 8412', billet
8,565.0
8,565.0
06:03
06:15
clean, RBIH dry drift, window clean.
9/9/2018
9/9/2018
1.10
PR0D4
DRILL
DRLG
P
CT 4205 psi @ 1.77 bpm, Free spin
8,458.0
8,565.0
06:15
07:21
diff 1348 psi, IA95 psi, OA 58 psi.
OBD, CT wt 15 k lbs, WOB 1.8 k lbs,
ROP 40 - 300 ft/ hr.
9/9/2018
9/9/2018
1.40
PROD4
DRILL
DRLG
P
Having difficulty dropping angle. cut
8,458.0
8,720.0
07:21
08:45
rale from 1.8 to 1.5 bpm. Targeting
higher WOB.
8688' WOB diming, held WOB - 3-4 k
Ib to 8562'. Allowed to mill off, time
drilled to 8720'
9/9/2018
9/9/2018
1.00
PROD4
DRILL
DRLG
P
PU to acquire new parameters, Ct
8,720.0
8,756.0
08:45
09:45
4558 psi @ 1.5 bpm, annular 4206
psi.
OBD, targeting 3-4 k LBS WOB.
Drilled ahead with angle slowly
dropping.
9/9/2018
9/9/2018
6.10
PROD4
DRILL
DRLG
P
PU and incresae pump rate to 1.78
8,756.0
8,860.0
09:45
15:51
bpm.
Ct 5405 psi @ 1.78 bpm, free spin diff
1240 psi, annular 4244 psi.
OBD, Ct Wt 15 k lbs, WOB 3.5 k lbs,
ROP 10 ft/hr
Drilled through two sections of
wrapped gamma @ 8760', and 8810'
9/9/2018
9/9/2018
1.00
PROD4
DRILL
DRLG
P
ROP climbed rapidly from 25 to over
8,860.0
8,935.0
15:51
16:51
120 ft1hr.
CT 5815 psi, @ 1.79 bpm, Annular
4148 psi, IA 457 psi, OA 67 psi
CT Wt 1.4 k lbs, WOB 3.4 k lbs, ROP
61 f thr
Chase sweeps to the bit.
9/9/2018
9/9/2018
0.35
PROD4
DRILL
WPRT
P
PU 53 k lbs, wiper#1,NOV agitator
8,935.0
8,477.0
16:51
17:12
working!, swap computers
9/9/2018
9/9/2018
0.80
PROD4
DRILL
WPRTP
Wiper back in hole, RIW 15 k
8,477.0
8,935.0
17:12
18:00
Page 24130 ReportPrinted: 9/1912018
Operations Summary (with Timelog Depths)
IH -21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End! Tune
Dwthr)
PleaseOp
Cafe
Activity Catle
Time RT -X
DPeraGan
Start Depth
(MB)
End Depth(MB)
9/912018
9/9/2018
3.75
PROD4
DRILL
DRLG
P
BOBD, 1.76 bpm @ 5,647 psi,
8,935.0
9,436.0
18:00
21:45
Diff=1,390 psi, WHP=181,
BHP=4,244, IA=356, OA=67,
Avg.ROP=80 fph
*** Note: New Mud Qa 9,089'
9/9/2018
9/912018
0.50
PROD4
DRILL
WPRT
P
Wiper up hole to the window, PUW 53
9,436.0
8,100.0
21:45
22:15
k
9/9/2018
9/9/2018
0.15
PROD4
DRILL
WPRT
P
Perform Jog in hole 100' @ 50 fpm
8,100.0
8,204.0
22:15
22:24
9/9/2018
9/9/2018
0.80
PROD4
DRILL
WPRT
P
Continue wiper up hole, PUW 16 k,
8,204.0
7,845.0
2224
23:12
jog clean 7" with sweeps
9/9/2018
9/9/2018
0.20
PROD4
DRILL
DLOG
P
Log the RA marker correction of plus
7,845.0
7,869.0
23:12
23:24
7.0'
9/9/2018
9/10/2018
0.60
PROD4
DRILL
WPRT
P
Continue Wiper back in hole, RIW 15
7,869.0
9,436.0
23:24
0000
k
9/10/2018
9/10/2018
0.30
PROD4
DRILL
DRLG
P
BOBD, 1.79 bpm at 5,160 psi,
9,436.0
9,556.0
00:00
00:18
DifF1,305 psi, WHP=438,
BHP=4,338, IA=218, OA=64,
*** Note: Needing to get build and
turn.
9/1012018
9/10/2018
0.15
PROD4
DRILL
WPRT
P
PUW 52 k. BHA wiper up hole, PUW
9,556.0
9,556.0
00:18
00:27
1
1
52 k
9/10/2018
9/10/2018
0.20
PROD4
DRILL
DRLG
P
BOBD, 1.78 bpm at 5,065 psi,
9,556.0
9,583.0
00:27
00:39
1
Diff --1,365, WHP=357, BHP=4,272,
IA=353, OA=66
9/10/2018
9/10/2018
0.15
PROD4
DRILL
WPRT
P
PUW 52 k, work pipe x 3, not able to
9,583.0
9,583.0
00:39
00:48
build angle or tum to the east.
9/10/2018
9/10/2018
0.20
PROD4
DRILL
DRLG
P
BOBD, 1.78 bpm at 5,065 psi,
9,583.0
9,614.0
00:48
01:00
Diff --1,365, WHP=357, BHP=4,272,
IA=353, OA=66, CTSW - 5 k
911012018
9/10/2018
0.15
PROD4
DRILL
WPRT
P
PUW 52 k, work pipe x 3, not able to
9,614.0
9,614.0
01:00
01:09
build angle or tum to the east.
9/10/2018
9/10/2018
0.50
PROD4
DRILL
DRLG
P
BOBD, 1.79 bpm at 5,090 psi,
9,614.0
9,639.0
01:09
01:39
Diff --1,360 psi, WHP=357,
BHP=4,257, IA=357, OA=66
9/10/2018
9110/2018
0.20
PROD4
DRILL
WPRT
P
PUW 52 k, work pipe x 3. getting tum,
9,639.0
9,725.0
01:39
01:51
1
1
1
still having trouble building angle.
9/10/2018
9/10/2018
0.30
PROD4
DRILL
DRLG
P
BOBD, 1.79 bpm at 5,090 psi,
9,725.0
9,820.0
01:51
02:09
Drff=1,360 psi, WHP=357,
BHP=4,257, IA=357, OA=66
9/10/2018
9/10/2018
0.15
PROD4
DRILL
WPRT
P
PUW 55 k, work pipe x 3, not able to
9,820.0
9,820.0
02:09
02:18
build,
9/1012018
9/10/2018
0.30
PROD4
DRILL
DRLG
P
BOBD, 1.79 bpm at 5,035 psi,
9,820.0
9,836.0
02:18
02:36
Diff --1,208 psi, WHP=366,
BHP=4,337, IA=360, OA=66
9/10/2018
9/10/2018
0.40
PROD4
DRILL
WPRT
P
1,000', wiper up hole, PUW
9,836.0
8,841.0
02:36
03:00
9/10/2018
9/10/2018
0.30
PROEM
DRILL
WPRT
P
Wiper back in hole, RIW 14 k, make
8,841.0
9,818.0
03:00
03:18
call to town for plan forward, decision
was made to POOH for correction run.
9/10/2018
9/10/2018
3.00
PROD4
DRILL
TRIP
T
Pump 5x5 sweep, POOH to surface
9,818.0
76.9
03:18
06:18
9/10/2018
9/10/2018
1.20
PROD4
DRILL
PULD
T
Bump Up, PUD following failed EDC
76.9
0.0
06:18
07:30
procedure, LDBHA
9/10/2018
9/10/2018
0.70
PROD4
DRILL
PULD
T
PD BHA #29 0.8* AKO w RR HC
0.0
78.2
07:30
08:12
P104 cutter bit, stab injector, bump up,
set counters.
9/10/2018
9/10/20181.50
PROD4
DRILL
TRIP
T
Verify SSSV pressure, RIH, dose
78.2
7,570.0
08:12
09:42
EDC. shallow test agitator - good.
continue in hole.
Page 25130 Report Printed: 911912018
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Sort rme
End Tone
Der(hr)
Phase
Op Code
Activity Code
Tme P -T -X
Operation
Stott
End Depth
9110/2018
9/10/2018
0.20
PROEM
DRILL
DLOG
T
Tie into the K1 +0.5' cortection.
7,570.0
1.6
7,631.6
09:42
09:54
9/10/2018
9/10/2018
0.80
PROD4
DRILL
TRIP
T
PU Wt, 44 k lbs, RIH,
7,631.6
9,836.0
09:54
10:42
9/10/2018
9/10/2018
0.40
PROD4
DRILL
DRLG
T
CT 4750 psi, Q 1.8 bpm, free spin
9,636.0
9,877.0
10:42
11:06
857 psi, annular 4180 psi,WH 255 psi,
Is 110 psi, OA 60 psi.
OBD, CT Wt 9 k lbs, WOB 1.5 k lbs,
ROP 50-200 Mr. Directional driller
attempted to steer south, dropped
angle rapidly. PU 50 k lbs, reduced
rate to 1.50 bpm attempting to target
increased WOB, near bit inc
continuing to fall rapidly.
9/10/2018
9/10/2018
0.90
PROD4
DRILL
WPRT
T
PU Wt 50 k lbs. Geo wiper. Rig Geo
9,877.0
9,877.0
11:06
12:00
and DD greed to put 90% into turn to
the south, RBIH, Drill ahead, PU, 50 k
lbs, Geo wiper #2, Last survey to the
left. RBIH, PU, to resurvey, RBIH.
9/10/2018
9/10/2018
0.20
PROD4
DRILL
DRLG
T
CT 3967 Q 1.49 bpm, free spin 654
9,877.0
9,962.0
12:00
12:12
psi, WH 276 psi, annular 4198 psi
Ct Wt 7 k lbs, WOB .57 k lbs, ROP
200 ft/hr.
9/10/2018
9/10/2018
0.30
PROD4
DRILL
WPRT
T
PU 50 k lbs, DD wiper to discuss close
9,962.0
9,962.0
12:12
12:30
approach. Discuss w engineering
potential close approach to hard line
on the north. Decision made to drill
ahead. RBIH
9/10/2018
9/10/2018
2.00
PROD4
DRILL
DRLG
T
OBD, CT 3900 psi Q 1.50 bpm, free
9,877.0
10,195.0
12:30
14:30
spin 580 psi, Annular 4299 psi, WH
364 psi
CT 1.8 k lbs, WOB 0.44 k lbs, ROP
115 ft/hr
13:50 and 10,141' increase rate to
1.78 bpm, WH 316, Annular 4307 psi,
CT -7 k lbs, WOB 0.34 k lbs, ROP 110
ft/sec.
Pump 5 x 5 sweep Average ROP over
interval - 160 fRrc
9/10/2018
9/10/2018
0.20
PROD4
DRILL
WPRT
T
PU 53 k lbs, Pull to 9994'- 201' wiper
10,195.0
10,195.0
14:30
14:42
RBIH
9/10/2018
9/10/2018
1.40
PROD4
DRILL
DRLG
T
RBIH Wt k lbs, Ct 4847 psi, Q 1.81
10,195.0
10,270.0
14:42
16:06
bpm, free spin 887 psi, WH 257 psi,
Annular 4219 psi.
OBD, CT Wt -6.4 k Ibs, WOB 0.9 k Ib,
ROP 33 f thr.
9/10/2018
9/10/2016
0.20
PROD4
DRILL
WPRT
T
PU 53 k Ibs,- 1000' wiper
10,195.0
8,992.0
16:06
16:18
Pull through low spot Q 9150'
Pump 10 bola 1 ppg beds
9/10/2018
9/10/2018
0.80
PROD4
DRILL
WPRT
T
RBIH, S/D 9090' PU 58 lbs, to 9031',
8,992.0
10,195.0
16:18
17:06
RBIH,
SD Q 9588' W WOB.
SD Q 9679'
9/10/2018
9/10/2018
2.00
PROD4
DRILL
DRLG
T
RBIH Wt 4 k lbs, Ct 4847 psi, Q 1.81
10,195.0
10,404.0
17:06
19:06
bpm, free spin 887 psi, WH 257 psi,
Annular 4219 psi.
OBD, CT Wt -6.4 k lbs, WOB 0.9 k Ib,
ROP 30 - 170 ft/hr.
Still drifting north, turn straight up,
reduce pump rate, try sweeps to get
more WOB.
No sucess,
9/10/2018
9/10/2018
3.10
PROD4
DRILL
WPRT
T
PU Wt 53 k lbs, POOH for higher bend
10,404.0
74.4
19:06
22:12
motor.
Page 26130 Report Printed: 91=1912=01 8
Operations Summary (with Timelog Depths)
1 H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
nine P.T-X
Operation
start Depth
(meal
End Depth (110)
9/10/2018
9/10/2018
1.30
PROD4
DRILL
PULD
T
PUD BA #29,
74.4
0.0
22:12
23:30
9/10/2018
9/11/2018
0.50
PROD
DRILL
PULD
T
PD BA#30,1.2'AKO
0.0
74.4
23:30
00:00
9/11/2018
9!11/2018
0.50
PROD4
DRILL
PULD
T
Stab INJH, check pac-offs (good)
78.2
78.2
00:00
00:30
9/11/2018
9/11/2018
1.25
PROD4
DRILL
TRIP
T
RIH, with BHA# 30
78.2
7,570.0
00:30
01:45
9/11/2018
9/11/2018
0.20
PROD4
DRILL
DLOG
T
Log the K7 marker with no correction,
7,570.0
7,590.0
01:45
01:57
1
1 PUW 48 k, close EDC
9/11/2018
9/11/2018
1.25
PROD4
DRILL
TRIP
T
Continue IH, steering through 9,090'
7,590.0
10,404.0
01:57
03:12
and 9,590' area.
9/11/2018
9/11/2018
1.00
PROD4
DRILL
DRLG
T
OBD, 1.79 bpm at 5,231 psi,
10,404.0
10,472.0
03:12
04:12
Diff=1,350 psi, WHP=213,
BHP=4,342, IA=36, OA=58
9111/2018
9/11/2018
0.40
PROD4
DRILL
WPRT
T
Wiper up hole, PUW=53k
10,472.0
9,925.0
04:12
04:36
9/11/2018
9/11/2018
0.40
PROD4
DRILL
WPRT
T
Wiper back in hole, RIW 5 k
9,925.0
10,472.0
04:36
05:00
9/11/2018
9/11/2018
0.80
PROD4
DRILL
DRLG
T
BOBO, 1.79 bpm at 5,466 psi,
10,472.0
10,491.0
05:00
05:48
Diff -1,244 psi, WHP=221,
BHP=4,351, IA=181, OA=58
9/11/2018
9/11/2018
1.50
PROD4
DRILL
WPRT
T
Wiper up hole, PUW=53 k, jet the 7"
10,491.0
7,806.0
05:48
07:18
1
with sweeps
9/11/2018
9/11/2018
0.15
PROD4
DRILL
WPRT
T
After dicussing with town team,
7,806.0
7,565.0
07:18
07:27
decision was made to RBIH to drill
ahead
9/11/2018
9/11/2018
0.20
PROD4
DRILL
DRLG
P
Log the K1 correction plus 6.0'
7,565.0
7,598.0
07:27
07:39
9/11/2018
9/11/2018
1.40
PROD4
DRILL
WPRT
P
Continue RIH
7,598.0
10,491.0
07:39
09:03
9/11/2018
9/11/2016
3.80
PROD4
DRILL
DRLG
P
BOBD, 1.78 bpm at 5,293 psi,
10,491.0
10,610.0
09:03
12:51
Diff=1,272 psi, WHP=109,
BHP=4,292, IA=263, OA=64
9/11/2018
9111/2018
1.70
PROD4
DRILL
WPRT
P
BHA wiper up hole, PUW 58 k
10,610.0
10,510.0
12:51
14:33
9/11/2018
9/11/2018
0.50
PROD4
DRILL
DRLG
P
BOBD. 1.80 bpm at 5,213 psi,
10,510.0
10,666.0
14:33
15:03
Diff -960 psi, WHP=159, BHP=4,316,
IA=519, OA=69, trying to hold 85°-87°
9/11/2018
9/11/2018
1.00
PROD4
DRILL
DRLG
P
OBD. 1.80 bpm at 5,213 psi, Diff --960
10,666.0
10,738.0
15:03
16:03
psi, WHP=164, BHP=4,318, IA=520,
OA=69
9/11/2018
9/11/2018
1.50
PROD4
DRILL
DRLG
P
OBD. 1.80 bpm at 5,213 psi, Diff -960
10,738.0
10,771.0
16:03
17:33
psi, WHP=167, BHP=4,323, IA=522,
OA=69
9/11/2018
9/11/2018
0.90
PROD4
DRILL
WPRT
P
10771. BHA Wiper, PUW=60K, Stack
10,771.0
10,771.0
17:33
18:27
out trying to get to bottom. Continue
wiper to 10496. Pump sweeps. Work
back to bottom
9/11/2018
9/11/2018
2.80
PROD4
DRILL
DRLG
P
10771', Drill, 1.76 BPM @ 5150 PSI
10,771.0
10,850.0
18:27
21:15
FS, BHP=4415, RIW=-6K,
DHWOB=2K
9/11/2018
9/1112018
0.10
PROD4
DRILL
WPRT
P
10850'. BHA wiper, PUW=65K
10,850.0
10,850.0
21:15
21:21
9/11/2018
9/11/2018
1.00
PROD4
DRILL
DRLG
P
10850', Drill, 1.78 BPM @ 528OPSI
10,850.0
10,881.0
21:21
22:21
FS, BHP=4400, RIW=-4K
018
9/11/2018
0.10
PROD4
DRILL
WPRT
P
10881, P/U and restart, PUW=61K
10,881.0
10,881.0
22:21
22:21
22:27
9/11/2018
9/12/2018
1.55
PROD4
DRILL
DRLG
P
10881', Drill, 1.78 BPM @ 5210 PSI
10,881.0
10,907.0
2227
00:00
FS, BHP=4390
Page 27/30 Report Printed: 9/19/2016
. Operations Summary (with Timelog Depths)
1H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start7rre
End Tone
Dur (hr)
Phew
p Cafe O
AchuRy Cane
Tire P -T -X
Operation
start Depth
(ftKB)
End Depth (M(9)
9/12/2018
9/12/2018
0.20
PROD4
DRILL
DRLG
P
Dilling, 1.78 BPM @ 5210 PSI FS,
10,907.0
10,910.0
00:00
00:12
BHP=4390PSI
9/12/2018
9/12/2018
0.60
PROD4
DRILL
WPRT
P
10910', Call TD, PUH pumping 10 X
10,910.0
10,910.0
00:12
00:48
10 Sweeps
9/12/2018
9!12/2018
-3 10
PROD4
DRILL
WPRT
P
Sweeps out, Chase to swab,
10,910.0
65.0
00:48
0354
PUW=58K
9/12/2018
9/12/2018
-1.50
PROD4
DRILL
WPRT
P
Tag up at surface, Set counters, RBIH
65.0
7,570.0
03:54
05:24
9/12/2018
9/1212018
0.15
PROD4
DRILL
DLOG
P
Log the K1 correction 0.5'
7,570.0
7,591.0
05:24
05:33
1
9/12/2018
9/12/2018
0.15
PROD4
DRILL
TRIP
P
Continue IH to above window.
7,591.0
7,800.0
05:33
05:42
9/12/2016
9/12/2018
0.20
PROD4
DRILL
CTOP
P
Obtain pressure survey 6,520.79
7,800.0
7,800.0
05:42
05:54
SensorrfVD, 11.32 ppg and slowly
falling
9/12/2018
9/12/2018
2.50
PROD4
DRILL
TRIP
P
Continue IH confirm TO 10,908', (line
7,800.0
10,908.0
05:54
08:24
up liner pill down the coil
9/12/2018
9/12/2018
1.45
PROD4
DRILL
TRIP
P
POOH laying in beaded 11.55 ppg
. 10,908.0
6,500.0
08:24
09:51
completion fluid, painting EDP flags
9/12/2018
9/12/2018
1.20
5ROD4
DRILL
TRIP
P
Continue POOH, displacing well to
6,500.0
78.2
09:51
11:03
11.55 ppg completion fluid to surface
9/12/2018
9/12/2018
0.50
PROD4
DRILL
OWFF
P
At surface, check well for flow, PJSM
78.2
78.2
11:03
11:33
9/12!2018
9/1212018
0.50
PROD4
DRILL
PULD
P
LD drilling BHA, Flush and blow down
78.2
0.0
11:33
12:03
tools
9/12/2018
9/1212018
0.25
COMPZ4
CASING
PUTB
P
Prep Rig Floor for Liner Ops
0.0
0.0
12:03
12:18
9/12/2018
9/12/2018
1.30
PROD4
CASING
RUNL
P
PU/MU.30Its of slotted liner, shorty
0.0
923.0
12:18
13:36
deployment sleeve, and non -ported
bullnose.
9/12/2018
9/12/2018
0.50
PROD4
CASING
PULD
P
PU/MU Coiltrak tools surface test
923.0
967.3
13:36
14:06
-1
(good -test)
9/12/2018
9/12!2018
65
PROD4
CASING
RUNL
P
RIH, with AL2 -01 Liner segment#1 w/
967.3
8,474.0
14:06
15:45
30 Its of slotted liner
9/12/2018
9/12/2016
0.20
PR0D4
CASING
RUNL
P
Log the K1 marker correction of plus
8,474.0
8,523.0
15:45
15:57
6.0' (correction at flat minus 4.0)
9/12/2018
9/12/2018
0.60
PROD4
CASING
RUNL
P
Continue IH
8,523.0
10,500.8
15:57
16:33
9/12/2018
9112/2018
0.20
PROD4
CASING
RUNL
P
PUW 55 k, RBIH to 10,500.8', bring
10,500.8
9,577.8
16:33
16:45
pump online 1.4 bpm, PUW 41 k,
remove liner length from counters -
9/12/2018
9/12/2018
2.25
PROD4
CASING
RUNL
P
POOH, Paint EDP flag 6600'
9,577.8
55.0
16:45
1900
_Ell
9/12/2018
2/20-18
0.50
PR0D4
CASING
PULD
P
At surface, Flow check well, Lay down
55.0
0.0
19:00
19:30
BHA#31 L2-01 1st liner run setting
tools
9/12/2018
9/12/2018
0.50
15ROD4
CASING
SVRG
P
Change out mechanical disconnect on
0.0
0.0
19:30
20:00
1safetyjoint
9/12/2018
9/12/2018
2.00
PROD4
CASING
PUTS
P
PIU AL2 -01 intermediate liner run with
0.0
1,112.8
20:00
22:00
ported bull nose, 36 Jts slotetl liner,
and shorty deployment sleeve
9/1212018
9/12/2018
0.60
5ROD4
CASING
PULD
P
M/U Coiltrak to liner. M/U coil to tools
1,112.8
1,157.0
22:00
22:36
and surface test. Tag up and set
counters
9/12/2018
9/13/2018
1.40
PROD4
CASING
RUNL
P
Trip in hole BHA#32, AL2 -01
1,157.0
7,749.0
22:36
00:00
intermediate compleion, EDC closed
pumping 11.4 revised KWF
9/13/2018
9/13/2018
0.70
PROD4
CASING
RUNL
P
Continiue in well BHA#32
7,749.0
8,660.0
00:00
00:42
1
intermediate liner segment
9/13/2018
9/13/2018
0.10
PROD4
CASING
BLDG
P
Log K1 for +3.5'correction
8,660.0
8,680.0
00:42
00:48 1
Page 28130 Report Printed: 9/1912018
Operations Summary (with Timelog Depths)
1H-21
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Lop
S/2rime
End rme
D, IN)
anew
Op cone
AdiNly coact
rune a -T-%
Operetim
Stag Depth
(MB)
end oepth(%�6)
9/13/2018
9/13/2018
0.30
PROD4
CASING
RUNL
P
Continue in well. Cean pass through
8,680.0
9,577.0
00:48
01:06
window. tag TOL @ 9577, PUW=53K,
DHWOB=-4K
9/13/2018
9/13/2018
0.20
PROD4
CASING
RUNL
P
Set back down, 11.4 PPG New NaBr
9,577.0
8,456.0
01:06
01:18
out of GS. Pump 1.55 BPM @ 4910
PSI. Lift off liner, PUW=43K,
DHWOB=-1.2 PUH 10 feet. Subtract
liner length left in hole. Circ 10 BBIs in,
9113/2018
9/13/2018
1.90
PROD4
CASING
TRIP
P
Trip out of well, Paint EOP flag @
8,456.0
47.1
01:18
03:12
6900'
9/13/2018
9/13/2018
0.70
PROD4
CASING
PULD
P
At surface, Flow check well, PJSM lay
47.1
0.0
03:12
03:54
down tools on dead well
9/13/2018
9/13/2018
2.60
PROD4
CASING
PUTB
P
PJSM, PIU tubing, BHA#33 AL2 -01
0.0
794.9
03:54
06:30
upper liner segment with ported bull
nose, 14 its slotted liner, HAL Swell
Packer, 1 it solid liner, HAL Swell
Packer, 3 jts slotted liner, HAL Swell
Packer, 5 its solid liner, and
deployment sleeve w/6' SBR
9/13/2018
9/13/2018
0.70
PROD4
CASING
PULD
P
M/U Coiltrak to liner. M/U coil to tools
794.9
839.1
06:30
07:12
and surface test. Tag up and set
counters
9/13/2018
9/13/2018
1.50
PR054
CASING
RUNL
P
TIH BHA #33 AL2 -01 upper liner
839.1
7,942.0
07:12
08:42
segment
9/13/2018
9/13/2018
0.10
PROD4
CASING
RUNL
P
Correct depth at window flag, -2.7'
7,942.0
7,942.0
08:42
08:48
correction, wt check 45k
9/13/2018
9/13/2018
0.10
PROD4
CASING
TUG -1-P
Continue TIH, log K1 +3' correction,
7,942.0
8,466.8
08:48
08:54
1
tag TOL @ 8466.77'
9/13/2018
9/13/2018
0.20
PROD4
CASING
RUNL
P
Pump 1.4 BPM, 1167 psi differential
8,466.8
7,670.5
08:54
09:06
to release off liner, 34k up weight
9/13/2018
9/13/2018
1.80
DEMOB
CASING
TRIP
P
Displace well to SW pumping .64
7,670.5
2,700.0
09:06
10:54
BPM/1200 psi, recover 11.4 PPG
NaBR and TOOH to 2700'
9/13/2018
9/13/2018
1.00
DEMOB
CASING
TRIP
T
Standby for LRS due to poor road
2,700.0
2,700.0
10:54
11:54
conditions
9/13/2018
9/13/2018
0.75
DEMOB
WHDBOP
FRZP
P
PJSM w/LRS, PT lines to 4000 psi,
2,700.0
2,700.0
11:54
12:39
line up LRS to pump 35 bbls diesel FP
into coil
9/13/2018
9/13/2018
0.75
DEMOB
WHDBOP
FRZP
P
TOOH to surface
2,700.0
44.2
12:39
13:24
9/13/2018
9/13/2018
1.50
DEMOB
WHDBOP
PULD
P
Close Swap valve, LD, setting tools,
44.2
0.0
13:24
14:54
MU nozzle,
"' Note: Final Tubing presure 670 psi
9/13/2018
9/13/2018
2.30
DEMOB
WHDBOP
CTOP
P
Stab INJH, PJSM, w/ Haliburton N2,
0.0
0.0
14:54
17:12
IR/D
PT surface line to 4,000 psi,
Blowdown CT sluing. Bleed off N2,
HES N2
9/13/2018
9/13/2018
0.80
DEMOB
WHDBOP
CTOP
P
Unstab injector, remove UOC and cut
0.0
0.0
17:12
18:00
a -line
9/13/2018
9/13/2018
2.00
DEMOB
WHDBOP
CTOP
P
PJSM, remove inner reel iron,
0.0
0.0
18:00
20:00
pressure bulkhead, and wash pipe,
continue loading out pits
9/13/2018
9/13/2018
2.00
DEMOB
WHDBOP
CTOP7---
PJSM, R/U CT grapple and
0.0
0.0
20:00
22:00
unstabbing cable. Unstab CT from
injector
pull back to storage reel and
secure to reel
9/13/2018
9/13/2018
1.50
DEMOB
i
WHDBOP
CTOP
P
PJSM, R/U to pick storage reel. Prep
0.0
0.0
22:00
23:30
reel sump. Pull king pin
9/13/2018
9/14/2018
0.50
DEMOB
WHDBOP
CTOP
P
PJSM with Peak, Pick reel and plac on
0.0
0.0
23:30
00:00
Peak sow bed truck
9/14/2018
9/14/2018
1.00
DEMOB
MOVE
CTOP
P
Continue CT sting change
0.0
0.0
00:00
01:00
Page 29130 Report
Printed: 9/19/2018
- —umiy ieei, stao cou into 0.0 0.0
:DO 12:00 INJH, Nipple down Stack, Work rig
move check list,
** Rig released 12:00 noon '*'*
Operations Summary (with Timelog Depths)
1 H-21
Rig:
NABORS CDR3-AC
Job: DRILLING SIDETRACK
Time Log
Start Time
9/14/2018
End Time
9/14/2018
Our (hr)
5.00
Phase
DEMOB
Op Code
Activity Code
Time P-T-Xsta'
Operation
Depth
(ftKB)
End Depth(fiKa)
01:00
06:00
MOVE
CTOP
p
Reel installed, Shim reel to carrier,
0.0
0.0
Tourque saddle lamps Pull stuffing box
for brass change out. Remove pump
in sub and quick test sub for tubo
inspection.
9/14/2018
9/14/2018
6.00
DEMOB
Mr1VF
FT—n'0
- —umiy ieei, stao cou into 0.0 0.0
:DO 12:00 INJH, Nipple down Stack, Work rig
move check list,
** Rig released 12:00 noon '*'*
ConocoPhillips
ConocoPhillips (Alaska) Inc.
Kuparuk River Unit
Kuparuk 11-1 Pad
1H-21AL2-01
50-029-22355-62
Baker Hughes INTEQ
Definitive Survey Report
02 October, 2018
BA ER
I UGHES
fmmpany
r,
Conocoldhillips
Corpocoi
Definitive Survey Report
Company: ConocuPhi9ips(Alaskal Inc.
Local Caordinah Reference:
Mil 111-21
Projoa, Kuparuk River Unit
M Reference:
1H-21 ® 961 (1H-21)
Slee: Kuparuk 1H Pad
MO Reference:
1H-21 rd Mai (1 H81)
Well: 111d1
North Reference:
True
Wellbore: IH -21
Survey Calculation Method:
Minimum Curvature
Design: 1H-21
Database:
EDT 14 Alaska Production
Project Kupamk River Uni North Slope Abska, United SUM.
Map System: US State Plane 1927 (Exact solution)
System DMmll: Mean See Level
Geo Datum: NAD 1927(NADCON CONUS)
Using Well Reference Point
Map Zone: Alaska Zone 04
Using ge0detic scale factor
Well 1H-21
Well Position +WS ODD ush
NortMng: 5.950,024.57us8
Lactude:
70°21'22.356N
+EI -W 0.00 .,it
Easting: 549,555.22ush
Lenghud¢:
149°35'51.196W�i
Position Uncertainty 0.00 it
Wellhead Elevation: Usk
Ground Level:
MAD ush
Wellbore 11+-21AL -Dl
Magnetics Model Name Somali Date
DesOmtb.
Dip Angle
Field Strength
(°)
1°I
Inn
BGGM2018 911/2018
17.01
00.91
57.446
Design 1H-21AL2-01
i
Audit Notes:
Version: 1.0 Phase: ACTUAL
no On Depth: 8,45013
Vertical Scalon: Depth From (ND)
+MIS
+ V
Directbn
(.on)
(usual
IIwM
1'1
41 60
0 0o
0.0
90.00
tOR20f3 2,6TV7PM Page 2 COMPASS 500014 Stood SAO
ConocoPhillips
a?IS�?9
COnOCOPhillips
Definitive
Survey Report
Company:
ConowPhilips(Alasko) Inc.
Lo cal Cocrdtnate
Rehrence:
Wb1111-1-21
Project:
Kupamk Riwr Unit
rvO Rehrence:
11-1-21@W.00us8(1
H-21)
$a.:
Kupamk 1H
Pad
MO Radiant..:
11-141 C 96.00usn(11-1-21)
Well:
11-1-21
North Reference.
Tme
-
Wellbom:
IH-21
Survey Calculation Method
Minimum Curvature
Deel9n:
1H-21
Database:
EDT 14 Alaska Producti0n
Survey P.,.m
Wb
From
To
Survey Survey
(UM)
W-M
survey(1 Bala)
Tool Name
Ceacrtp0on
StartOala End Dab
102.20
],80].30
1H415rvy 1-SUB
_GCT-Ni
OCT-MS
Schlumb.,.r GCT muOishot
4/9&1993 4no/1993
7,826.00
],8]8.23
1H-21AMWD-INC (1H-210)
MWD-INC_ONLY
MWDINL ONLY FILLER
8)19)2018 6/1912018
],90]21
],90],21
1H-21A MM (I H-21A)
MWD
MWD-Sbndard
8119/2018 SWAN118
],935.00
8,45036
1H-21Al2 MM (1
H-21Al2)
MWD
MWD-Standard
812912018 9/5will
11,453.00
10,87039
1H-21AL-31 M"(11-1-21AI241)
MWD
MWD- Standard
91612018 911212018
Sun.
_. _..
MO
hat
Axl WD
rvsin
Mll5
+&4N
("I'M
17
1'1 IMsnl
lusttl
IDsnl
loan)
Mouthing
EastDLS
Moil)
S dw survey Tool Nm
ae Annotation
Int
Int
on
I
8.45028
Mae
9342 6.730.50
6,634.50
-74.68
42EfLR
59]99]821
553835.93 1316
4,280,72 MWD(4)
TIP
9,.53.97
96,32
9347 8.75.20
6,634.
-74.85
4,283A4
5,979,978.07
553.838.85 10.74
4,28344 MWD(6)
SOP
8.4130,31
92.55
96.33 6)1..09
6,63209
-]],17
4.310.56
5,979.11M.
553,975]8 17,31
431056 MD (5)
851O.
9112
W.43 6,726.93
6,0090
-8124
4,33997
5,9]919204
SSA09521 10.79
4,33997 MND(5)
-
8,540,14
9249
102.56 6725.05
6629.88
26.99
4,Wool
5,979986.50
553,924.79 10.69
4,Moral 61M(o
8.57055
.1'.
10648 6.72453
6620.73
-8460
4,38683
5,979,95908
553,954.5 13.05
4,390.93 I J (5)
a.69D.85
92.43
Tides 8,723.60
6627.60
4q 24
4,427.62
5ontra'863
553,98300 1309
4427,62 MNO(5)
8.63143
92.66
112.22 8,722.40
6626A0
-11540
445696
597997997
554,011.52 527
4456,. MD (6)
8,660.74
9218
11463 6]2132
8.625.32
-127,05
448294
5,9]49Pd9
554.0.46 8.23
4.48294 MWD(5)
8,69023
91,87
116,. 5)97.2]
662427
M.
4.50951
5,979.91461
554.5,11 695
4,5..51 "D (5)
8,]195]
91..
117.87 6,]1939
6,a23.39
-15324
4535.57
5979.901,35
554.012] 422
4,53557 NIM(5)
0]4949
8609
11].79 8.71926
ND.25
6,61316
-161.
4,562.03
59]9,007%
511].01 906
54
4,55203 MD (5)
0,7]969
8]n
116.16
6,624..
49789
4,589.91
5,979,874.05
554144.97 747
4588.93 MD
I 8.009.63
06.84
112.01 6,2178
6,625.70
-19310
4,616.14
5.979,81
5541]2.08 11.29
4,616.14 MWD (5)
j 6840.54
Mas
109.40 6MS3
6.62753
-204.39
4,644.92
5,979.85.@
561.200.94 11,03
4.6m.92 MWD (5)
S0,0]0.25
..53
10674 8,]253]
6,629.30
-213.59
4.6Y111
5,9]9,841,91
554II919 695
46]311 MWD(5)
o Mae
8563
10297 6]2733
6,63133
-22110
4.701,79
5anam.52
554.25].91 13.30
4,MI,79 MWD(51
8 Mail
9194
10130 6.T28.10
663210
12.71
4,736.96
5979827.22
5642.113 18.07
4736.96 MD
8984.99
07.08
99.60 6.IIa 34
6632.34
-23]9]
4765,48
5979,013.15
554.32160 17,M
4,755.40 MD
10/22018 2:57.07PM
Pape 3
COMPASS 500014 Budd 85D
�.
ConocoPhlllips
1w
ConocoPhillips
w,•
DefinDive Survey Report
Company.
ConOmPhlllips(Alaska)
Inc.
Local Doorduote Reference:
Vell 1H-21
Project:
Ku,ouk Rive,
Une
TVD Reference:
1&21 96.00use(1H-21)
are:
Kuparuk lH
Pad
MD Reference:
111-21 ® 96.00usg (111-21)
Wel:
11+21
North Reference:
True
Wellbore:
IH-21
Survey Calculation Method
Mmimumcumature
Design:
1H-21
Database:
EDT 14
Alaska Production
Survey
Vertical
MD
Inc
Ab
TVD
ND83
♦WS
♦E14N
DI.S
1°7
(9
(usm
(ace)
(Rap
Norkleg
lace)
EawOng
a
Section gurvey Teolwme
Annotation
(e)
(RI
(•nwl
DU
8.995.31
8706
9]48
6728.65
6,63365
-2364]
4,795 43 5,9]9.81)85
551.35166
7.58
4,79543 MWD(5)
9,M5.61
86.12
93.87
6]3225
663625
2430.1
4845.41 5,9]9.013.22
554.40186
B.w
4,845.41 MM (5)
9,0]68]
84.CG
91.27
6]34.92
6.630.92
644.83
4,67652 5,9]9,81202
554,32]]
10.59
4,876.52 MWD(5)
910].05
87 I2
to"
6,737.27
6,6412]
-245.26
4,906.60 5,979,011.79
554,46285
10,24
4,9L".60 MWD 15)
'
9,13].61
89.88
69.67
6,]39.10
6,642.10
-2,526
4,937.14 5.979.011.90
554493.40
864
4,93214 MAID (5)
9,171.M
91.84
88.83
6,]3].59
6,64169
-20401
4,970.61 5,970,81264
5".526.80
637
4,9]0.61 MND(5)
j
9.2117.91
9366
%.35
J)3 83
6639113
-243.7
5,807.36 5,9]9,814]5
554,66.59
10.65
5,037.355 6AYD(5)
9,238.52
94.06
01-M
6.73391
663].91
-238.60
5.035.73 5,9]9,01631
554591.93
1492
5,65.73 M (5)
9261 fi7
0982
75 An
8.733.66
6,637,08
-234.57
5,06029 5(179,82350
554,61646
26.02
5,M.N Am (5)
9,29]50
9200
]3.%
B.MEC
6,8ffi50
-225.w
505.21 6.979 833,30
554651.31
083
5,09521 MWD (5)
8,331.0]
89.94
06.70
6.731.04
6,83594
-21373
5,15.38 5,9]9,844]]
554.682.42
21.50
512639 MWD (5)
9.355.01
90A
6502
6]3180
6,6%.w
-281,6
5.14697 5.9]965504
551.704.92
].4]
5,1469] MWD(5)
9.391.3]
90.68
59.55
6.]31.3]
663637
-187$8
5.18043 5,979.87177
554,]36.2]
15.38
5,180.43 MSW(5)
9421,01
09.82
55.43
6.731.24
6635.24
.1]1.1]
5,205,43 5,979.88.06
554,761.16
1413
5,205.43 mAo(5)
9450.ee
90.95
5217
6.731."
6,63504
-153.53
5,229.6 5,979aD&65
554,]85.14
11.61
5,229.6 MD (5)
9,]]91
89.39
45.90
6,733.95
8.834.96
-135.03
5,249.94 5,979,923,"
554805.13
569
5,X9.94 AWD(6)
9.511.05
90.22
41.0
6]310]
6636.8
-111.09
5,2884 5,9]9.94].58
554.05.17
13.75
5,27284 MD (5)
6516.6
89.42
%.35
6,731.18
6.635.18
-84.16
5.29522 5,9]9.9]5."
654,050.36
14.8
5,5522 mo (6)
9.598.81
91.01
34.8
6,]31.@
6,63502
4991
5,31975 5980.00186
54848
5.15
5,319.75 "D (5)
9,621,10
93.80
39.5
6.729.8
6,633.72
-24.08
5,33904 5,980.05.01
554,093.]9
1422
5,339." Am (5)
j 9.85105
Met
39.33
6."an
6633.72
L82
5,357." 5.980,059.19
559,912.47
M"
5,357,88 MWD (5)
j
9.89.37
0].39
93.48
6]31,24
6635.24
20.36
5,376.5 5,98908052
554,931.02
1502
5,37658 MWD (5)
9,711.50
0600
47.91
6,]32.54
663650
1206
5,393.55 5,98D 103.118
55A953.84
13.91
5,399.55 AMID (5)
9,739.73
90.40
52.42
6,732.93
6.636.93
80.8
5,42121 5,980,121.33
550,97539
18.80
5,@1.21 MD (5)
9,]11,8
91.17
5585
6,73249
6,63648
79.5
5,447.06 5,960.140.15
55,801.11)
11.02
5,MT.M M (5)
9902]1
918
Sam
6)31.69
6,63589
96.37
5,4nAll 5,980,157.14
5502].12
998
6473.19 MWD(!)
9.835.11)
91A7
6051
6.73117
6635.17
112.]]
5,501.11 5, ami n.8
555,054.93
5.90
5,80111 "AND (5)
98531
Salle
57.6
6.7310
6,635.03
128.04
5,527.91 5,9w,189.90
5m 081.6
11.57
5,!2]91 MAD (5)
ga.21
89.w
59.5
6.731.51
6.83551
1"36
5.55341 5,980205.65
555.18"
VO
5.55341 MD (5)
9.926.5
6.06
6168
6732.0
665.00
159.17
557954 5.981),220.62
555JM304
606
5,579.54 "D (5)
9.98.21
69.51
65.32
673239
6,65.39
172.96
568.24 5980.234.6
55.1605
t1.a5
5,607.24 M (5)
11) 182:6I.97PM
Page4
COMPASS 5000.141toWBSD
�.
ConocoPhillips
Cor1000Plillips
Definitive Survey Report
Dampaw. ConocoPhl9ips(Alaska) Ina
Local Coordaiafe Reference:
Wall 1H.21�-
Prokot K.Rnuk Rover line
MReference:
1H-21 a 96.00us0(11,141)
Site: Kuparuk l H Pad
MO Reference:
188-21®96.00ue8(11431)
Well: 111-21
North Reference:
True
Welll,ore: 1H-21
Survey Calculation Method:
Minimum Cunture
Design: 1H-21
Datil,...:
EDT 14 Alaska Production
Survey
10 18 2:57.97PAi
Papa 5
�1 WHES
Mnofishon
COMPASS 5000.14 Build 850
Map
withan
(ad
MO
.to1°I
Iz
Atl
M
M
M"
Mild
rEFM
NorthingpEea
mp
DLS
Survey Tool Name
haul
haul
(-a
ml
ml
1^nga
ml
9.90535
B9B5
6002
6732.55
6BN 55
183.85
56330B
5980,2456E
555,103.41
13.25
5,63308 MWD(5)
10,01489
8091
]2]0
6,mel
6638.81
183.57
5,66108
5%0255.59
555,214.34
1242
5%1.09 Mbn(5)
10,04467
9018
76.54
6]32.59
683559
201.47
5689.18
5,943,263.65
555,242.99
1283
5,%9]8 MMI[) (5)
10.075.E
9073
79.29
673247
6635.47
207.80
5,71972
5,980.27026
555288
690
5,7198 MND(5)
10,1059
0997
82.69
6,73242
6,636.42
212.3
5.74962
5,90027522
555,30275
10.94
S749b2 MWD (6)
10.13656
90.15
Well
6732.30
6636,38
215.83
517W.
5,980,278.61
555.333,57
9.76
5,78046 MWD(5)
10,165.29
90.92
90.4
6.732.11
6636.12
21692
5,809.14
5,9W,279.09
55,51..24
15.3
5.809]4 MWD(5)
10.197,61
%.15
89.62
6]3181
6.63581
217.01
5,041.46
EM2W.19
555,]4.55
274
5.141.48 MWn(5)
10224.80
W.37
14,35
6'3169
6,635.69
217,97
5,014.71
5,84.28133
555.421.79
1202
5,808]1 WAR) (5)
1025985
89E6
84g7
6,73168
6.635.88
20.64
5.90.96
5,980,284A3
555,456.01
695
5.90.95 mm (5)
10,285,21
Wi
1.3,74
5731.W
6635.4
A359
5,920.77
5,98028735
555.481.01
1.41
5.08..77 MIND (6)
10.310.16
8973
&5.62
6,731.99
6635,99
2ABI
595361
5.980,28.83
555,605.63
7.83
5,95361 MND(5)
10.34483
8025
8.68
6732.13
6636.13
227,93
5.98832
5,94,73208
555,54122
656
5,98822 MVYn(5)
10,369.53
8917
861.4
S.M28
6,636X
229.09
6,01289
5,980.293.41
`35,563.09
530
8,012.89 M (5)
10,39949
1.19.%
84.43
6,Mn
6.636.77
23134
6042.76
5,980,295W
55559573
644
0.04278 MAD (5)
10,4308
91.25
W,N
8,73274
6,636.74
2..44
6073%
5.94.300.15
5556264
14413
60T3% "D(5)
10,44925
9535
W..l
6.731.68
6535.68
238.40
6,0918
5,9W,303.24
555,644,09
22.E
6,091.97 Mi (5)
10.4808
9249
84.61
6'73.54
663354
242.38
8,12305
5,94,38.42
555.854
15.17
6,123.05 MFMD(5)
10,5105
93.19
92.42
6,720.8
6,63207
243,15
8,152.66
SBW.30638
555.705.54
2640
8,15268 IMUD(5)
10,540.76
93.35
98.8
S.3 34
6,630.34
24021
6182.8
5,980.30565
S55735.M
2053
6,1028 MWD(5)
10 570.45
07.12
102.%
8.725.22
6.630.22
234.64
6,21202
5.980,36027
555,754,65
35.4
6,21202 MND(5)
10,60035
8935
11021
8727.13
6,63113
2584
6,240.53
5.980,291.96
555,793.51
AA
6,24053 MWO(5)
10.63101
0551
11107
6728.51
6,63251
214,81
626009
5,99028.83
555022.14
IS.%
6,2504 MND(5)
10.66095
85,15
10628
67.3989
6,634.69
24.54
628.15
59W.270.84
555.84,5
2105
8,297.15 MVX)(5)
10,695.80
BSA
90.60
6'MA
6,637.29
18.4
6,330,88
5,9802630
555044
ASS
9,33000 MNO(5)
10'2039
84,62
9307
6.73546
6839.46
14.54
6,355.38
5.98O.APA3
655900.56
2288
6,35530 MWD(5)
1074.73
8382
480
6.736S2
6,642.52
t4.W
6,38555
698028141
55593822
21.38
6,35.55 "D(5)
10,780.44
8429
0005
6,741.60
8,04560
198.[8
SCAN
S,9W,265.4
555.9(603
2198
8.414.88 MAD(5)
10.810A
84.01
7316
67M65
6640,66
24.%
6,443.65
5,980.22.13
555,996.95
AS.
6,44385 MND(5)
10.84055
8348
65.8
6,747.95
6651.95
21544
647191
5980,28279
Ni
24.09
6,47191 MID (5)
10,80E
8294
6000
6'51,62
605562
228.861
6,490.18
5.980.296.A
556051.12
1996
6,49818 MID (5)
10 18 2:57.97PAi
Papa 5
�1 WHES
Mnofishon
COMPASS 5000.14 Build 850
n
ConocoPhillips
Definitive Survey Report
Local Corordnate Reference:
Well 111-21
ConocoPhillips
I Golparan
ConocoPhillips (Alaska) Inc.
11-21 @ W.00usX (1 H-21)
Kuparuk Rrver Unit
iPre}ae
Sill:
Kuperuk 111 Pee
i Well:
1H-21
I Wabon:
1H-21
Drlen:
111-21
Survey
n
ConocoPhillips
Definitive Survey Report
Local Corordnate Reference:
Well 111-21
M Reference:
111-21 @ 96.00use (11121)
MO Refinance:
11-21 @ W.00usX (1 H-21)
North Reference:
Tme
Survey Calculation What:
Mnimum Curvature
Dalbau:
EDT 14 Alaska Pmaluction
MD Lrc Asl WE TVDa3 we ♦F/Y/ Nanking Smart, 1XIS Secton Survey Tool Name
(oaD) 11 PI (uae) (-am la:e) Iuap (e) (e) PnoM) lel
MA10.00 82. 6000 6.156.92 6 R 92 MY oo 653227 5900,31623 55fi.5W 0.00 653227 PROJECTED to TO
Annotation
1O 01S 2:5707PM Page6 COMPASS 5000.14 BuSC SEO
To:
E
a G£ compam
Date:
October 11, 2018
Meredith Guhl
AOGCC
333 West 711 Ave, Suite 100
Anchorage, Alaska 99501
From:
21808(
29788
Letter of Transmittal
Michael Soper/ Yosha Ragbirsingh
Baker Hughes, a GE Company
795 East 94t1 Avenue
Anchorage, Alaska 99515
Please find enclosed the directional survey data for the following well(s):
KUPARUK RIVER UNIT
3H -31A
3H-31AL1
IH -21A
iH-21AL1
1H-21AL2
1H-21AL2-01
(14) Total prints
GREATER MOOSES TOOTH UNIT
MT6-03PH
MT6-03
MT6-05P61
MT6-05PB2
MT6-05
MT6-05L1
MT6-08PB1
MT6-08
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Note: Please feel free to send us an email in place of return mail.
Michael Soper, Baker Hughes, Project Engineer
Michael.Soper@BHGE.com
Yosha Ragbirsingh, Baker Hughes, Survey Manager
Yosha.Ragbirsingh@BHGE.com
ConocoPhillips
ConocoPhillips (Alaska) Inc.
Kuparuk River Unit
Kuparuk 1H Pad
1 H-21AL2-01
50-029-22355-62
Baker Hughes INTEQ
Definitive Survey Report
02 October, 2018
BA, ((ER
UGHES
a GE company
�- ConocoPhillips
ConocoPhillips Definitive Survey Report
Company:
ConocoPhillips (Alaska) Inc.
Local Co-ordinate Reference:
Well 1H-21
Project:
Kuparuk River Unit
TVD Reference:
1H-21 @ 96.00usft (1H-21)
Site:
Kuparuk 1 H Pad
MD Reference:
1H-21 @ 96.00usft (1H-21)
Well:
1H-21
North Reference:
True
Wellbore:
1H-21
Survey Calculation Method:
Minimum Curvature
Design:
1 H-21
Database:
EDT 14 Alaska Production
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
Well
1H-21
Well Position
+N/ -S 0.00 usft
Northing: 5,980,024.57 usft
Latitude:
+E/ -W 0.00 usft
Easting: 549,555.22 usft
Longitude:
Position Uncertainty
0.00 usft
Wellhead Elevation: usft
Ground Level:
Wellbore
1H-21 AL2 -01
Magnetics
Model Name Sample Date
Declination
(I
Dip Angle
(I
BGGM2018 9/1/2018
17.01
80.91
Design
1H-21 AL2 -01
Audit Notes:
Version:
1.0 Phase: ACTUAL
Tie On Depth: 8,450.26
Vertical Section:
Depth From (TVD)
.N/ -S
+E/ -W
(usft)
(usft)
(usft)
41.60
0.00
0.00
Direction
(1)
90.00
BA ER
F�UGHES
70' 21' 22.356 N
149' 35' 51.196 W
54 40 usft
Field Strength
(nn
57,446
10/2/2018 2: 57: 07PM Page 2 COMPASS 5000.14 Build 85D
®"
ConocoPhillips
ConocoPhillips
BA EGHESR
Definitive Survey Report
7I
Company:
ConocoPhillips(Alaska) Ina
Local Co-ordinate Reference:
Well 1 H-21
Project:
Kuparuk River Unit
Site:
Kuparuk 1H Pad
TVD Reference:
1 H-21 Q 96.00usft
(1 H-21)
Well:
1H-21
MD Reference:
1H-21 @ 96.00usft (1H-21)
North Reference:
True
Wellbore:
1H-21
Design:
1H-21
Survey Calculation Method:
Minimum Curvature
Database:
EDT 74 Alaska Production
Survey Program
Date
From
To
(usft)
(usft)
Survey (Wellbore)
Tool Name
Survey Surve y
102.20
7,807.30
1H-21 Srvy 1 - SLB
GCT -MS (1H-27)
Description
Start Data End Date
GCT -MS
Schlumberger GCT multishot
- 7,826.00
7,876.23
1H -21A MWD-INC
(11-1MWD-INC_ONLV
4/28/1993 4/28/1893
MWD -INC
i
7,907.27
7,907.21
-)
8/19/2018 8/19/2018
MWD
MWD- Standard
7,935.00
8,450.26
1H-21AL2 MWD (1 H-21AL2)
8/19/2018 6/21/2018
MW D
MWD -Standard
8,453.00
70,870.29
1H-21AL2-01 MWD
(i H-21AI-2-01)MWD
6/29/2018 9/5/2078
MWD -Standard
9/6/2018 9/12/2018 I
Survey
MD
Inc Azi
TVD
TVDSS
+N7 -S
+EFW Map.
Map
Vertical
(usft)
V) (%
tusft)
(usft)
(usft)
(usft) Northingi
DLS
Ea(ft)ng
Se(ctt' n
8,450.26
96.03 93.42
6,730.50
(8)
(°1100')
Survey Tool
Name Annotation I
8,453.00
96.32 93.4]
6,730.20
6,634.50
-]4.68
4,280.72 5,9]9,978.21
553,835.93 13.16
8280.72
MWD (4)
8,480.31
92.55 96,33
6,728.09
6,634.20
-74.85
4,283.44 5,979,978.07
553,83865 10.74
4,283.44
MWD (5)
TIP
6,632,09
-77.17
4,310.% 5,979,975.92
553,865.78 17.31
KOP
8,510.02
91.72 99.43
6,726.98
6,630.98
4,383.56
MWD (5)
8,540.14
92.49 102.56
6,725.88
6,629.86
-81.24
4,339.97 5,979,972.04
553,895.21 10.79
4,339.97
MWD (5)
i
8,570.55
91.84 106.48
6,724.73
A6.98
4 ,369.51 5,979,966.50
553,924.79 1069
4,369.51
MWD (5)
9 8,600.85
92.43 110.65
6,723.60
6,628.73
-94.60
4,398.93 5,979,959.06
553,954.25 13.06
4,398.93
MWD (5)
'
8,631.43
92.06 112.22
6,722.40
6,627.60
-104.24
4,427.62 5,979,949.63
553,983.00 13.89
4,427.62
MWD (5)
8,660.74
92.18 114.63
6,626.40
-115.40
4,456.06 5,979,93866
554,011.52 537
4,456.06
MWD(5)
8,690.23
91.87 116.66
6,721.32
6,625.32
-127.05
4,482.94 5,979,927.19
554,038.46 8.23
4,482.94
MWD (5)
E 8,719.57
91.60 117.87
6,720.2]
6,719.39
6,624.27
-139.80
4,509.51 5,979,914.61
554,065.11 6.96
4,509.51
MWD (5)
8,749.49
88.89 117.79
6,719.26
6,623.39
-153.24
4,535.5] 5,979,901.35
554,091.27 422
4,535.57
MWD (5)
fYj
8,779.69
87.33 116.16
6,720.25
6,623.26
-167.20
4,562.03 5,979,887.56
554,117.81 9.06
4,562.03
MWD (5)
6,624.25
-180.89
4,588.93 5,979,874.05
554,144.80 7.47
8,809.63
86.84 112.81
6,721.78
6,625.78
-193.28
4,616.14
4,588.93
MWD (5)
8,840.54
86.65 109.40
6,723.53
6,627.53
5,979,861.84
554,172.08 1129
4,616.14
MWD (5)
d 8,870.25
86.53 106.74
6,725.30
6,629.30
-204.39
4,644.92 5,979,850.92
554,200.94 11.03
4,644.92
MIND (5)
8,899.99
85.63 102.88
6,727.33
-213.59
4,673.11 5,979,84791
554,229.19 8.95
4,673.11
MWD(5)
+)
8,935.99
91.94 10L30
6,728.10
6,631.33
-221.18
4,701.79 5,979,834.52
554,25].91 73.30
4,701.]9
MWD (5)
/ 8,964.99
87.08
6,632.10
-228.71
4.736.96 5,979,827.22
554,293.13 18.07
4,736.96
MWD (5)
99.60
6,728.34
6,632.34
-233.97
4,765.48 5,979,822.15
554,321.68 17
75
4,765.48
MVJD (5)
101212018 2r57,07PM
- - - - '- - -
Page 3
COMPASS 5000.14 Build 850
ConocoPhillips
ConocoPhillips
n
Definitive Survey Report
Company:
C010-Phillips(Alaska)
Inc.
Project:
1
Kuparuk River Unit
Local Co-ordinate Reference:
Well 1H-21
Site:
Kuparuk 1H
Pad
TVD Reference:
1H-21 @ 96.00usft
(1H-21)
Well:
1 H-21
MD Reference:
1 H-21 @ 96.00usft
(1 H-21)
Wellbore:
1H-21
North Reference:
True
Design:
1H-21
Survey Calculation Method:
Minimum
Curvature
._�.
Database:
EDT 14
Alaska Production
Survey
s
(usft)
Inc
(°)
Azl
TVD
TVDSS
+N/ -S
E/ -W Map
Map
Vertical
S
(•)
(nett)
(nsft)
(ueR)
Northing
(aaR)
Ea(Sftt)
Section
8,995.31
?
87.97
97.48
6,729.65
6,633.65
(•1100.)
Survey Tool Name
9,045.61
86.12
93.8]
6,732.25
-238.47
4,795.43 5,979,817.85
554,351.66
7.58
9,076.87
84.06
6, 636.25
-243.43
4,845.41 5,979,813.22
4,795.43 MWD (5)
91.27
6,734.92
6,638.92
-244.83
4,676.52
554,401.66
8.06
4,845.41 MWD(5)
9,10].05
87.02
90.38
6,737.27
6,641.27
-245.26
5,9]9,812.02
554,432.7]
10.59
4,876.52 MWD (5)
9,137.61
89.88
89.67
6,738.10
6,642.10
4,906.60 5,979,811.79
554,462.85
70.24
4,906.60 MWD (5)
9,171.09
91.84
88.83
6,737.59
6,641.59
-245.28
4,937.14 5,979,811.90
554,493.40
9.64
4,937.14 MWD
9,207.93
93.66
85.35
6,73$.83
6,639.83
-244.84
4,970.61 5,979,812.60
554,526.86
6.37
(5)
4,970.61
9,236.57
94.0
81.08
6,733.91
-242.97
5,007.36 5,979,814.75
554,563.59
10,65
MWD (5)
9,261.6]
89.82
75.80
6,637.97
-239.60
5,035.73 5,979,818.31
554'581'93
5,007.36 MWD (5)
6,733.08
6,637.08
-234.57
5,060.29
14.92
5,035.73 MWD (5)
9,297.89
92.00
73.55
6,732.50
6,636.50
5,979,823.50
554,616.46
26.82
5,060.29 MWD (5)
9,331.07
89.94
66.70
6,731.94
6,635.94
-225.00
5,095.21 5,979,833.30
554,651.31
8.63
$,095.21
9,35$.81
90.71
65.02
6,731.80
-213.73
5,126.39 5,979,844.77
554,6(12.42
27.$8
MWD (5)
9,391.37
90.68
59.55
6,635.80
-203.62
5,148.9] 5,979,855.04
554,]04.92
5,126.39 MWD (5)
9,421.01
89.82
6,731.3]
6,635.37
-187.09
5,180.43 5,979,8]1.77
7.4]
5,148.97 MWD (5)
55.45
6,737.24
6,635.24
-171.77
5,205.43
559,736.27
75.38
5,180.43 MWD (5)
p[ 9,450.88
90.95
52.17
6,731.04
6,835.04
5,979,887.86
554,761.16
14.13
5,205.43 MWD (51
9,477.91
I
89.39
45.96
6,730.96
6,634.96
-153.53
5,229.53 5,979,905.65
554,785.14
11.61
5,229.53
9,511.05
9022
41.48
6,731.07
-135.83
$,249.94 5,979,92348
554,80543
23.69
MWD (5)
9,546.69
89.42
36.3$
6,635.07
-111.89
5,272.84 5,979.W 58
554,828.17
5,249.94 MWD(5)
9,588.83
91.01
6,731.18
6,635.18
-x'16
5,295.22 5,979,97544
13.75
5,272.84 MWD (5)
34.87
6,731.02
6,635.02
49.91
5,379.75
554,850.36
74.57
5,295.22 MWD (5)
9,621.10
93.60
38.66
6,729.72
6,633]2
5,980,009.86
554,8]4.6]
5.15
5,319.75 MWD (5)
( 9,651.05
86.43
39.33
6,729.72
6,633.72
-24.08
5,339.09 5,980,03581
554,89379
14.22
5,339.04 MWD
I9,679.37
87.39
43.48
6,731.24
6,635.24
-0.82
5,357.58 5,980,059.19
554,912.47
24.09
(5)
5,357.88
9,711.50
,
88.00
47.91
6,732.54
6,636.54
20.38
5,376.58 5,9W,080.52
554931.02
15.02
MWD(5)
5,376.58
9,739.73
90.40
52.42
6,732.93
42.80
5,399.55 5,98(1,103.08
554,953.84
13.91
MWD (5)
9,771.63
91.17
6,636.93
60.88
5,421.21 5,980,121.30
554,975.39
5,399.55 MWD ($)
55.85
6,732.49
6,636.49
79,56
18.09
5,421.27 MWD (5)
9,802.71
91.07
58.64
6,731.89
6,635.89
9637
5,447.06 5,980,140.15
555,001.10
11.02
5,447.06 MWD (s)
9,835.10
91.47
fi0.51
6,731.17
5,473.19 5,981,157.14
555,027.12
8.98
9,866.37
89.05
57.83
6,635.17
112.7]
5,507.11 5,980,173.72
555,054.93
5,473.19 MWD (5)
f 9,896.21
89.08
6,731.03
6,635.03
128.76
5,527.91 5,980,189.88
5.90
5,501.77 MWD (5)
59.26
6,731.51
6,635.57
144.36
5,553.41
555,081.01
11.57
5,527.91 MWD (5)
d` 9,92625
89.05
61.66
6,732.00
6,636.00
5,980,205.65
555,1 W.01
478
5,553.41 MWD(5)
9,957.21
89.51
6532
6,732.39
6,63639
159.17
5,57954 5,980,220.62
555,133.04
606
5,579.54
17298
5,60].24 5,980,23462
555.160.65
MWD(5)
10/2/2078 25O7PM
11.85
5,607.24 MWD (5)
Page 4
B ER
I�UGHES
Annotation
COMPASS 5000.14 Build 850
ConocoPhillips
ConocoPhillips
Definitive
Survey Report
Company:
ConocoPhillips (Alaska) Inc.
Project:
Kupamk
River Unit
Local Co-ordinate Reference:
Site:
Kuparuk
1H Pad
TVD Reference:
Well
1 H-21
Well:
1H-21
MD Reference:
1 H-21
@ 96.00usft (1H-21)
' Wellbore:
1H-21
North Reference:
1 H-21
@ 96.00usft
(1 H-21)
Design:
1H_ 21
Survey Calculation Method:
True
"^"--
Minimum
Curvature
Database:
Survey
EDT 14
Alaska Production
MD
(usft)
Inc
(°)
Azi
TVD
TVDSB
+N/'8
Map
9,985.25
89.85
(°)
69.02
(usft
(usft)
(waft)
+E/ -W
(usft)
Northing
Map
Easting
DLS
Vertical
10,014.89
89.91
6,732.55
6.636,55
183.85
(°/100')
Section
SUry
10,044.67
90.18
72.70
6,732.61
6,636.61
193.57
5,633.08
5,980,245.6fi
555,186.41
13.25
(ft)
76.59
6,732.59
6,636.59
5,661.08
5,980,255.56
555,214.39
5.633.08 MWp
10,075.29
9025
7928
6.732.47
201'47
5,689.78
5,980,263.65
12'42
5,661.08 MWD
10,105.57
89.97
82.59
6,636.47
207.80
5,719.72
555,242.99
12.%
5,689.78 MWD
10,136.58
90.15
6,732.42
6,636.42
212.65
5,980,270.26
555,272.89
8.98
1016$29
85.61
6,]32.38
6,636.38
215.83
5,74962
5,980,275.22
555,302.75
5,719.72 MWD
10,19]61
90.92
90.06
6,732.11
6,636.12
5,780.46
5,%0,278.61
555,333.5]
10'�
5,749.62 MWD
90.15
89.62
6,]31.81
6,63581
216.92
5,809.14
5,980,279.89
555,362.24
9.76
5,780.46 MWDI
10,224.88
90,37
%.%
6,731.68
217.01
5,841.46
5,980,280.19
15.73
5,809.14 MWD(
10,25925
89.66
84.07
6,731.68
6,635.69
217.97
5,668.]1
5,980,281.33
555,399.55
2.74
5,841.46 MWD(
10,285.21
89.82
6314
6,635.68
220.84
5,902.96
555,421,79
12.02
5,866.71 MWD ;
10,310.16
89.29
85.62
6,731.99
6.635'80
223.59
5,928.77
5,980,287.35
555,455,01
6.95
5,902.96 MWD(:
10,344.83
90.25
8].66
6,732.13
6,635.99
225.91
5,953.61
5,980,289.83
555,481.81
5,928.77 MWD(!
t 10,369.53
89.1]
%,%
6.732.26
6,636.13
227.83
5,%8.22
5,980,292.08
555,506.63
7.41
].83
5,953.61 MWD (5
7 10,399.49
88.86
84.43
6,636.26
229.09
6,012.89
555,541.22
6.56
5,998.22 MWD 5
10,430,8]
9126
6,732.77
6.636.77
231.34
5,980,293.41
555,565.88
5.30
10,49825
80.58
6,732.74
6,63674
23544
6.042.76
$,%0,295,86
555,595.73
6,012.89 MWD IS.
10,480.6]
95.35
80.81
6,731.68
6,635.68
6,073.86
5,980,300.15
555,626.60
844
6.042'76 MWD(5)
92,46
8461
80.61
6.729.54
6,633.54
238.40
6,091.97
03.24
555,649.89
14.46
6,09197 MWD
10,510.35
93.19
6,728.07
242.38
6,123.05
5,980,307.42
22.29
6,091.97 MWD (s)
10,540.76
93.35
98.67
6,632.0]
243.15
6,152.66
555,675.94
15.17
6,123.05 MWD 5
( )
10,5]0.46
87.12
102.%
6,726.34
6,726.22
6,630.34
240.21
6,182.87
5,980,308.38
5,%0,305.65
555,705.56
26.90
6,152.66 MWD
10,60025
89.35
6,63022
226'14
555,735.76
20.53
(5)
10,631.01
110.21
6.631.13
226.14
6,21202
27
555,764.95
6,782.87 MWD 5
85.51
113.07
6,728.51
6,632.51
6,240.53
5,%0,29L96
555,793.51
25.50
6,212.02 MWD (5)
10,66095
86.15
106]8
6730.69
214.61
6,269.09
5,980,280.83
25,39
6,24053 MWD (5)
10,695.66
85.29
%.60
6,634.69
204.64
6,297.15
555,822.14
15.56
6,269.09 MWD (5)
10,720.39
84.62
6,733.29
6,637.29
19704
5,9&1,27084
555,850.26
21.06
10,750.73
93.07
6,]35.46
6,639.96
6,330.88
5,980,263.4]
555,884.05
6,29].15 MM (5)
10,780.44
83.82
86.60
6,738.52
6,642.52
194.54
6,355.38
5,9W,26113
555,908.56
23.63
6,330.88 MAID (5)
8429
80.05
6,741.60
199.63
6,385.55
5,980,261.41
22.94
6,355.38 MWD (s)
10,810.39
84.01
73.16
6.744'66
6,645.60
198.06
6,414.88
5,98.26504
5,938.72
21.38
6,385.55 MWD (5)
10,840.55
8348
6587
6,64866
20496
6,443.65
555,%8.03
21.%
6,414.88 MWD (5)
10,870.29
82.34
6,747.95
6,651.95
215.44
5,980,272.13
555,9%.95
22.90
6000
6]5162
6,655.62
6,471.91
5,980,262.79
556,029.94
6,443.85 MWp (6)
102/2018 2:57.'07PM
228.86
6,498.18
5960,296.39
556,051.12
24.09
6,471.91 M WD (5)
19.%
6,49818 MWD (5)
Page 5
UGHES
COMPASS 5000,14 Build 85D
ConocoPhillips
ConocoPhillips
Company:—"^
Definitive Survey Report
ER
tWHES
ConocoPhillips (Alaska) Inc—�—
Project: Kuparuk River Unit
Local Co-ordinate Reference:
—
Site: Kuparuk 1H Patl
TVD Reference:
Well 11-1-21--"'^`—•-----.�..,.,.._,_�,
___
Well: iH-27
MD Reference:
1 H-21 @ 96 00usft (1 H-21)
Wellbore: iH-21North
Reference:
1H-21@9600usft(1 H-21)
Design: 1H_ 21
Survey Calculation Method:
True
Database:
Minimum Curvatura
Survey ...... ., ... _._,.. ...
EDT 14 Alaska P1cd= icn
MD Inc Azi TVD TVDSS +N/ -S
(usft (°) (°)
Map
(usk
10,910.00 8234 ) (usft) (usft)
60.00
+E/ -W
Northing
(usk) 9
Map
Vertical
Easting
6,756.92 6,660.92 248.54
(ft)
6.532 2]
100 Section
(°/100') Survey cool Name
s,9ao,31s.zs
6, (n)
sss,oes.os
Annotation
000 6,532.27 PROJECTED to TD
10/2/2018 2:57.'07PM
Page e
COMPASS 5000.14 BuBd 850
I`
BA ER PRINT DISTRIBUTION LIST
F UGHES
a GE company
COMPANY ConocoPhlllips Alaska, Inc.
WELL NAME 1H-21AL2-01
FIELD Greater Kuparuk Area
COUNTY North Slope Borough
BHI DISTRICT
Alaska
218080
29 76 4
>e sign and return one copy of this transmittal form to:
3coPhillips Alaska, Inc.
Osterkamp (WNS Petroleum Technician)
G Street.
forage, Alaska 99510
LOG TYPE GR - RES
LOG DATE September 12, 2018
AUTHORIZED BY Patrick Rider
EMAIL Patrick.RiderC@bakerhgghes.com TODAYS DATE October 4, 2018
Revision
STATUS Final Replacement: No Details:
Rev. Requested by: —
COMPANY
ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX)
PERSON ATTENTION
V
I BP North Slope_
LOA, PBOC, PRW20(Office 109)
D&G WO Wells Admin Brenda Glasemaker & Peggy O'Neill
900 E. Benson Blvd.
Anchorage, Alaska 99508
2 ConocoPhillips Alaska Inc.
Attn: Ricky Elgarico
ATO 708
700 G Street
Anchorage, AK 99510
3 F.xxonMobil, Alaska
Attn: Lynda M. Yaskell and/or Leonardo Elias
3201 C Street, Suite 505
Anchorage, AK 99503
4: State of Alaska -AOGCC
Ann: Natural Resources Technician 11
333 W. 7th Ave, Suite 100
'Anchorage, Alaska 99501
FIELD I FINAL CD/DVD
FINAL
PRELIMLOGS (las, dlis, PDF, META,
I
SURVEY
REPORT
LOGS CGM, Final Surveys)
(Compass)
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Attn: Resource Evaluation
550 West 7th Avenue, Suite 1100
Anchorage, Alaska 99501
** Stamp "confidential" on all material deliver to DNR
6 BP Exploration (Alaska) Inc.
Petrotechnical Data Center, IR2-1
900 E. Benson Blvd
Anchorage, Alaska 99508
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,Oepp,Victoria T (DOA)
From:
Sent: Loepp, Victoria T (DOA)
To: Tuesday, July 10, 2018 2:13 PM
Subject: 'Long, William R'
KRU 1H-21AL2-01(PTD 218-080) PTD Approval Modifications
William,
Pio
Please make the following modifications to the approved PTD 218-080:
Annular preventer test pressure is 2500 psig
A variance to 20 AAC 25.015(b) is granted to allow the kickoff
Point to be any point along the parent lateral.
subsequent Form Required: 10-407
Include this approval with the original approved PTD.
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
state of Alaska
Oil 8, Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loe alaska. py
CONFIDENTIAL/ry NOTICE' CE: this a -mail message
information. The unCC)' State of Alaska and is for including any attachments,
auth ole use contains information from the Alaska Oil ontl
recipient of this e- oozed review, use or disclosure of such nfhe intendetl recipient s
YOU, contact Vict ma L Please delete it, witho ormotion ma () It may Contain confidential antl as Conservation
oepp at (907)793-1247ut first saving or forwartlin i}, y violate state or fed /or privileged
or Victoria Loe g antl, so that the federal law. It you are an unintended
@alaska, ov AOGCC is aware of the mistake in sending it to
THE STATE
°fALASKA
GOVERNOR BILL WALKER
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-21AL2-01
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 218-080
Surface Location: 678' FNL, 793' FEL, SEC. 33, T12N, R10E, UM
Bottomhole Location: 433' FNL, 843' FWL, SEC. 35, T12N, R10E, UM
Dear Mr. Ohlinger:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.00gcc.olaska.gov
Enclosed is the approved application for the permit to redrill the above referenced development well.
The permit is for a new wellbore segment of existing well PermitNo. 218-077, API No. 50-029-22355-
01-00. 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,
Hollis S. French
l Chair
DATED this5 day of July, 2018.
STATE OF ALASKA
ALA OIL AND GAS CONSERVATION COMMIJ 1N
PERMIT TO DRILL
9n AAr` q5 nnS
JUN 2 0 20118
1a. Type of Work:
Drill ❑ Lateral Q
Redrill ❑ Reentry ❑
lb. Proposed Well Class: Exploratory -Gas D Service - WAG ❑ Service - Disp ❑
Stratigraphic Test F-1Development- Oil ❑� ' Service - Winj ❑ Single Zone ❑�
Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
ic. Spe - e' for:
Coalbed Gas ❑ - Ga§'Hydrates ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
5. Bond: Blanket ❑✓ • Single Well ❑
Bond No. 5952180 •
11. Well Name and Number:
Kuparuk Riv Unit 1H-21AL2-01
3. Address:
PO Box 100360 Anchorage, AK 99510-0360
6. Proposed Depth: •-r PS Z 72-A
MD: 11,150' TV S 6632'
12. Field/Pool(s):
Kuparuk River
Kuparuk River Oil
4a. Location of Well (Governmental Section):
Surface: 678' FNL, 793' FEL, Sec 33, T12N, R10E, UM
Top of Productive Horizon:
752' FNL, 1850' FEL, Sec 34, T12N, R10E, UM
Total Depth:
433' FNL, 843' FWL, Sec 35, T12N, RIDE, UM
7. Property Designation: ,6DZ
f}9� zS AADL 25639 ,
8. DNR Approval umber:
LOINS 80-261
13. Approximate Spud Date:
7/11/2018 .
9. Acres in Property:
2560
14. Distance to Nearest Property:
7200' -
4b. Location of Well (State Base Plane Coordinates - NAD 27):
Surface: x- 549555 • y- 5980025 • Zone- 4
10. KB Elevation above MSL (ft): 96 '
GL / BF Elevation above MSL (ft): 54.4 •
15. Distance to Nearest Well Open
to Same Pool: 978' to 1H-13
16. Deviated wells: Kickoff depth: 8400 feet
Maximum Hole Angle: 95 degrees
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Downhole: 3275 ' Surface: 2645 .
18. Casing Program: Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Hole Casing Weight Grade I Coupling Length
MD TVD MD TVD (including stage data)
Liner
3" 2-3/8" 4.69 L-80 ST -L 3475'
7675'• 6365' • 11,150' • 6632' Un -Cemented
Perforation Depth MD (ft):
7768-7858,7918-7948
Perforation Depth TVD (ft):
6534-6604,6651-6674
Hydraulic Fracture planned? Yes❑ No Q
119. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
8315 6962 N/A
8207
6877
N/A
Casing Length Size
Cement Volume
MD
TVD
Conductor/Structural 121' 16"
200 SX PF C CMT
121'
121'
Surface 4779' 9-5/8"
930 SX PERM E, 450 SX G
4820'
4247'
Intermediate
Production 8258' 7"
299 SX CLASS G CMT
8295'
6947'
Liner
Perforation Depth MD (ft):
7768-7858,7918-7948
Perforation Depth TVD (ft):
6534-6604,6651-6674
Hydraulic Fracture planned? Yes❑ No Q
20. Attachments: Property Plat F-1 BOP SketchDrilling
Diverter Sketch
e
Program
Seabed Report
Time v. Depth Plot Shallow Hazard Analysis
e Drilling Fluid Program B 20 AAC 25.050 requirements e✓
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.
Authorized Name: James Ohlinger
Authorized Title: Staff CTD Engineer
Contact Name: William R. Long
Contact Email: William.R.LOD
Contact Phone: 907-263-4372
COP.com
Authorized Signature: Date: G/.�P/Y
Commission Use Only
Permit to Drill J� API Number: —/ Permit Approval See cover letter for other
Number: Zl�-C�f�' 50-(�Z�%�Z23Ss' �2"'� Date: 'I ' 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: 31wavo.L.Y V1135r-r '30='30=� 1
$ Samples req'd: Yes ❑ WE Mud log req'd: Yes E] No [r�
H,S measures: Yes [�No❑ Directional svy req'd: Yes [_Bl No El
Spacing exception mq'd: Yes El No ( / Inclination -only svy req'd: Yes ❑ No F
Post initial injection MIT req'd: Yes ❑ No ❑
APPROVED BY I
Approved by: COMMISSIONER THE COMMISSION Date: `� t
Submit Form and
r \worm 70-401 Revised 512017 This permit is valid f n o approle
ovval er 20%` ACC 25.005(g) Attachments in Duplicate
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
June 27, 2018
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 four laterals out of the KRU 1 H-21
(PTD# 193-046) using the coiled tubing drilling rig, Nabors CDR3-AC. .
CTD operations are scheduled to begin in July 2018. The objective will be to drill four laterals, KRU 1H -21A, 1H-
21AL1, 1H-21AL2, and 1H-21AL2-01, 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 this application are the following documents:
- Permit to Drill Application Forms (10-401) for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01
- Detailed Summary of Operations
- Directional Plans for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01
- Current wellbore schematic
- Proposed CTD schematic
If you have any questions or require additional information, please contact me at 907-263-4372.
Sincere/ly,
William R. Long
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Kuparuk CTD Laterals
1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01
Application for Permit to Drill Document
1.
Well Name and Classification
........................................................................................................
(Requirements of 20AAC 25.005(f) and 20AAC 25.005(b))...................................................................................................................2
2
.......................4
2.
Location Summary ............................................................
.......................................................
(Requirements of 20 AAC 25.005(c)(2))
2
..................................................................................................................................................2
3.
Blowout Prevention Equipment Information
.................................:...............................................
(Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................
2
................................................................................................................................................4
2
4.
Drilling Hazards Information and Reservoir Pressure
..................................................................
(Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2
2
................................................................................................................................................4
Summary of Operations .................................................
5.
Procedure for Conducting Formation Integrity tests
4
...................................................................
(Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................
2
14.
Disposal of Drilling Mud and Cuttings
2
6.
Casing and Cementing Program
6
....................................................................................................
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3
3
15.
Directional Plans for Intentionally Deviated Wells
7.
Diverter System Information
7
................................................... .......................
(Requirements of 20AAC 25.005(c)(7))..................................................................................................................................................3
3
16.
Attachments
8.
Drilling Fluids Program..........................................................
...........................................
(Requirements of 20 AAC 25.005(c)
3
(8)) .....................................................................................:............................................................
3
9.
Abnormally Pressured Formation Information
.............................................................................4
(Requirements of 20AAC 25.005(c)(9))..................................................................................................................................................4
10.
Seismic Analysis.............................................................................................................................
(Requirements of 20 AAC 25.005(c)(10)) ...........................................
4
.......................4
11.
Seabed Condition Analysis.......................................................
........................................
(Requirements of 20 AAC 25.005(c)(1 i))
4
................................................................................................................................................4
12.
Evidence of Bonding......................................................................................................................
(Requirements of 20AAC 25.005(c)(12))
4
................................................................................................................................................4
13.
Proposed Drilling Program.............................................................................................................
(Requirements of 20AAC 25.005(c)(13))
4
................................................................................................................................................4
Summary of Operations .................................................
..............................................................
LinerRunning....................................................................
4
6
14.
Disposal of Drilling Mud and Cuttings
..........................................................................................
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................
6
6
15.
Directional Plans for Intentionally Deviated Wells
.......................................................................
(Requirements of 20 AAC 25.050(b))
7
......................................................................................................................................................
7
16.
Attachments
....................................................................................................................................7
Attachment 1: Directional Plans for 1H -21A, 11-1-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals
.....................................7
Attachment 2: Current Well Schematic for 1 H-21
............................................................................................................7
Attachment 3: Proposed Well Schematic for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals .......................7
Page 1 of 7
June 27, 2018
PTD Application: 1H -21A, 1H-41AL1, 1H-21AL2, and 1H-21AL2-01
1. Well Name and Classification
(Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))
The proposed laterals described in this documentare 11-1-21A, 11-1-21AL1, 1H-21AL2, and 1H-21AL2-01. All
laterals will be classified as "Development -Oil" 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 forms for surface
and subsurface coordinates of each of the laterals.
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 3,000 psi. Using the
maximum formation pressure in the area of 3,275 psi at the datum in 21-1-12 (i.e. 10 ppg EMW), the
maximum potential surface pressure in 1H-21, assuming a gas gradient of 0.1 psi/ft, would be 2,645
psi. Seethe "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 H-21 was measured to be 2,978 psi at the datum (9.1 ppg EMW) on
5/16/2015. The maximum downhole pressure in the 1H-21 vicinity is the 1H-12 at 3,275 psi at the datum or 10
ppg EMW.
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of
encountering gas while drilling the 1 H-21 laterals. If significant 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 H-21 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 H-21 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
June 27, 2018
PTD Application: 111-1-21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01
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
Top MD
Btm MD
MD
MD
TVDSS
TVDSS
Liner Details
111-21A
8200'
11,500'
6538'
6526'
2W, 4.7#, L-80, ST -L slotted liner;
TVD
Surface
TVD
121'
si
16
si
670
S urface40
aluminum billet on to
1H-21ALl
7925'
11,550'
6536'
6644'
2%", 4.7#, L-80, ST -L slotted liner;
4247'
3520
2020
Production
7-
aluminum billet on to
1H-21AL2
8400'
11,100
6640'
6494'
2W, 4.7#, L-80, ST -L slotted liner;
4980
4320
Tubin
3-1/2"
9.3
aluminum billet on to
1H-21AL2-01
7675'
11,150 •
6365'
6632'
2%", 4.7#, L-80, ST -L slotted liner;
10,540
-
de to ment sleeve on to
Existing Casing/Liner Information
Category
OD
Weigh
Grade
Connection
Top MD
Btm MD
Top
Btm
Burst
Collapse
Conductor
16"
62.5
H-40
Welded
Surface
121'
TVD
Surface
TVD
121'
si
16
si
670
S urface40
9-5/8"
36
J-55
BTC
Surface
4820'
Surface
4247'
3520
2020
Production
7-
26
J-55
AB -MOD
Surface
8296'
Surface
6947'
4980
4320
Tubin
3-1/2"
9.3
J-55
EUE 8rd MOD
Surface
7693'
Surface
6475'
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 Power -Vis milling fluid (8.6 ppg)
— Drilling operations: Water based Power -Pro drilling mud (8.6 ppg). This mud weight may not
hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using
MPD practices described below.
— Completion operations: BHA's will be deployed using standard pressure deployments and the well will
be loaded with 11.4 ppg NaCl/NaBR completion fluid in order to provide formation over -balance and
maintain wellbore stability while running completions. If higher formation pressures are encountered
the completion brine will be weighted up with sodium bromide or potassium formate.
Managed 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 5000 psi rated coiled tubing
pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout
Prevention Equipment Information".
r
In the 1 H-21 laterals we will target a constant BHP of 11.4 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
Page 3 of 7 June 27, 2018
PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01
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.
Pressure at the 1 H-21 Window 7825' MD 6578' 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
Background
KRU well 1H-21 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production. casing. The CTD
sidetrack will utilize laterals to target the Kuparuk sands to the north and east of the existing 1H-21
wellbore. The laterals will increase throughput and recovery from a potentially sheltered corner of a fault
block.
Prior to CTD operations, E -Line will punch holes in the 3-1/2" tubing tail below the production packer and
the "D" nipple will be milled out to 2.80" ID. The existing perforations will be squeezed with cement and
the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing.
Following the cement squeeze Nabors CDR3-AC will drill a pilot hole and set a mechanical whipstock in
the 2.80" pilot hole. The whipstock will be used to cut a window in the 7" casing and drill CTD laterals.
Page 4 of 7 June 27, 2018
Pumps On 1.8 bpm)
Pumps Off
Formation Pressure 9.1
3113 psi
3113 psi
Mud Hydrostatic 8.6
2942 psi
2942 psi
Annular friction i.e. ECD, 0.080psi/ft)
626 psi
0 psi
Mud + ECD Combined
no chokepressure)
3568 psi
overbalanced -455psi)
2942 psi
underbalanced -171psi)
Tar et BHP at Window 11.4
3899 psi
3899 psi
Choke Pressure Required to Maintain Target BHP
331 psi
957 psi
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AAC 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AAC 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AAC 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
Background
KRU well 1H-21 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production. casing. The CTD
sidetrack will utilize laterals to target the Kuparuk sands to the north and east of the existing 1H-21
wellbore. The laterals will increase throughput and recovery from a potentially sheltered corner of a fault
block.
Prior to CTD operations, E -Line will punch holes in the 3-1/2" tubing tail below the production packer and
the "D" nipple will be milled out to 2.80" ID. The existing perforations will be squeezed with cement and
the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing.
Following the cement squeeze Nabors CDR3-AC will drill a pilot hole and set a mechanical whipstock in
the 2.80" pilot hole. The whipstock will be used to cut a window in the 7" casing and drill CTD laterals.
Page 4 of 7 June 27, 2018
PTD Application: 1H -21A, 1H-21AL7, 1H-21AL2, and 1H-21AL2-01
Pre -CTD Work
1. RU Slickline: Drift tubing with dummy whipstock.
2. RU E -line: Punch holes in the 3'/z" tubing tail below the production packer.
3. RU Pumping Unit: perform injectivity test down the tubing.
4. RU Service Coil: Mill out "D" nipple and cement squeeze the perforations up to the holes in the
tubing tail.
5. RU Slickline: Drift tubing with dummy whipstock. Tag top of cement and pressure test cement.
6. Prep site for Nabors CDR3-AC.
Rig Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. Mill 2.80" cement pilot hole.
3. Set monobore whipstock.
4. IH -21A Lateral (C sand - North)
a. Mill 2.80" window at 7825' MD.
b. Drill 3" bi-center lateral to TD of 11,500' MD.
c. Run 2%" slotted liner with an aluminum billet from TD up to 8200' MD.
5. 1H-21AL1 Lateral (C sand - North)
a. Kick off of the aluminum billet at 8200' MD.
b. Drill 3" bi-center lateral to TD of 11,550' MD.
c. Run 2%" slotted liner with aluminum billet from TD up to 7925' MD.
6. 1H-21AL2 Lateral (C sand - East)
a. Kickoff of the aluminum billet at 7925' MD.
b. Drill 3" bi-center lateral to TD of 11,100' MD.
c. Run 2%" slotted liner with aluminum billet from TD up to 8,400' MD.
7. IH-21AL2-01 Lateral (C sand - East)
a. Kickoff of the aluminum billet at 8400' MD.
b. Drill 3" bi-center lateral to TD of 11,150' MD.
c. Run 2%" slotted liner with deployment sleeve from TD up to 7675' MD.
8. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC.
Post -Rig Work
1. Return to production.
Page 5 of 7
June 27, 2018
PTD Application: 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01
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
- 1 H-21 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling
Fluids Program') prior to running liner.
While running 2V slotted liner, a joint of 2%" 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%" rams will provide
secondary well control while running 2% 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 (1 R-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).
Page 6 of 7
June 27, 2018
PTD Application: 11-11-21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
- The Applicant is the only affected owner.
- Please see Attachment 1: Directional Plans
- Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. -
- MWD directional, resistivity, and gamma ray will be run over the entire open hole section.
Distance to Nearest Property Line (measured to KPA boundary at closest point)
Distance
Distance
5,900'
IIH-21PAL2-Ol
5,900'
IH -12
7,200'
790'
7,200'
- Distance to Nearest Well within Pool
Lateral Name
Distance
Well
1 1 1-21A
790'
IH -12
1 H-21 AL1
790'
1H 12
1 1 1-21AL2
978'
1H-13
1 H-21AL2-01
978'
IH -13
16. Attachments
Attachment 1: Directional Plans for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals.
Attachment 2: Current Well Schematic for 1H-21.
Attachment 3: Proposed Well Schematic for 1H -21A, 1H-21AL1, 1H-21AL2, and 1H-21AL2-01 laterals.
Page 7 of 7
June 27, 2018
ConocoPhillips
1 H-21 @ 9a.00t
Project: KuParuk River Unit
Site: Kuparuk lH Pad
Well: 111-21
Wellbore: 1H.21A
Plan: 1 H-21A_WP03 011.2111H31A)
IH-IDI/IH-IDI
MxemhtO •n.e caro WELLBORE DETAILS: IH -21A
Map�elk NOM: t]q•
Mee�.xe n.N Parent Wellbore: IH -21
sx.wln naasaem Tie on MD: 9807.30
Wp Mpla. Beg1•
Oele: M/1g8
Matel'.aWM]pt
: -a INIE) Rektdwe: M 1H-21, T. NMN
VwNA (ND) ReWe—: 1H-21 A W-tQttVl (111-21)
S Iw (VS)RHeme Slot - (UADN. OWE)
Mwsue'1 NA Reference'. 1H-21®9SOpua11I1H21j
CeIIWallon MIrw MHlnum (Inott e
BA (ER
1 IUGHES
GE,.tn,,
1H•21 Proposed CTD Schematic
16" 62# H40 shoe
@ 121' MD
F9 -5_/8"_36_#J_55 - shoe
@ 4820' MD
7825'
C -sand perts
7768' - 7858' MD
7918' - 7948' MD
hole
MD
7' 26# J-55
shoe @ 8296' MD
Modified by 1JO 6/21/18
3-1/2" Camco TRDP=4A-RO SSSV at 1789' MD (2.812")
3-1/2" 9.3# J-55 EUE 8rd Tubing to surface
3-1/2" Camco MMG gas lift mandrel at 2571', 4355', 5143', 5922',
6710', 7183', 7602'
Baker 3-1/2" PBR at 7650' MD
BakerHB packer at 7664' MD (2.89" ID)
D -nipple at 7680" MD (2.75" min ID. No -Go)
3-1/2" Baker SOS @ 7692' MD
1H-21A(North)
Top of billet @ 6200' MD
rtH-21AL1(North)
DH Anchor billet ® 7925' MD
iH-21AL2 (East)
Top of Billet @ 8,400 MD
of liner @ 7,675' MD
Cono�oPhillips
p
Project: Kuparuk RNer Unit
Site: Kuparuk iH Pad Site: Kupa
Wellbore: 1H•21AL2-01
Plan: 111-2 A1_Wp02014-21/111-21AU-01)
^"'"'^'^'OT"'Noie
uN:w¢ norm. l>a
MN F.
i
DIpR a 4g'
Dare.wvmle
umEN BGOMAI
WELLBORE DETAILS: IH-21ALZ01
REFERENCE INPoRIMTIOM
6100
`•rp
W1 Ga[
UGHES
mmpaM
On MD: 840000
Pa�nWellbore: iH-21AL2
^am(w R.k' m: VM11K21.T.NMI:pts
vers (m) 't'.W.n s<elM
ttb S aelmme SM
NI IO�reN,0.WE3 211
t Vm NIM Rdn 1H.21 96W ft 1H-
WAa. memum 0
WELL DETAILS: IH -21
+N/ -S +E/ -W Northing Easting Latitude Longitude
0.00 0.00 5980024.57 549555.22 70° 21'22,356 N 149° 35' 51.196 W
Sec MD Inc Azi TVDSS +N/ -S W Dleg TFace VSect Annotation
1 8400.00 94.49 83.58 6640.47 .72.52 4223.01 0.00 0.00 4223.01 TIP/KOP
2 8650.00 79.34 92.38 6653.90 -63.63 4471.52 7.00 150.00 4471.52 Start 7 cls
3 8850.00 86.53 104.50 6678.56 -92.86 4667.32 7.00 60.00 4667.32 3
4 9240.00 91.92 77.73 6683.93 -100.31 5053.53 7.00 281.00 5053.53 4
5 9415.00 93.78 89.85 6675.19 .81.42 5226.96 7.00 81.00 5226.96 5
6 9515.00 94.97 82.93 6667.55 -75.15 5326.40 7.00 280.00 5326.40 6
7 9740.00 89.48 68.15 6658.78 -19.14 5543.41 7.00 250.00 5543.41 7
8 10015.00 89.50 87.40 6661.25 38.80 5810.91 7.00 90.00 5810.91 8
910300.00 92.93 67.74 6655.14 99.18 6087.77 7.00 280.00 6087.77 9
10 10500.00 92.84 81.76 6645.01 152.18 6280.00 7.00 90.00 6280.00 10
11 10695.00 91.12 68.21 6638.25 202.56 6467.78 7.00 263.00 6467.76 11
1210995.00 91.04 89.21 6632.53 260.94 6760.28 7.00 90.00 6760.28 12
13 11150.00 89.15 99.90 6632.27 248.64 6914.56 7.00 100.00 6914.56 Planned TD at 11150.00
Mean I
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6000
6100
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6200
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6700
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ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kup1
Kuparuk River Unit
Kuparuk 1H Pad
1 H-21
1 H-21AL2-01
Plan: 1 H-21 AL2-01_wp02
Standard Planning Report
25 June, 2018
BT�a
GHES
GE company
ConocoPhillips BA ER
ConocoPhillips Planning Report BAT
GE .m,,
Database:
EDT Alaska Sandbox
Company:
ConocoPhillips (Alaska) Inc. •Kupi
Project:
Kupamk River Unit
Site:
Kupamk 1H Pad
Well:
1H-21
Wellbore:
1 H-21 AL2 -01
Design:
1H-21AL2-01_wp02
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 H-21
Mean Sea Level
1H-21 @ 96.00usft(11-1-21)
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
She Kuparuk 1 H Pad
1H-21
+N/S
+EAW
-
0.00 usft Northing:
0.00 usft Easting:
0.00 usft Wellhead Elevation:
5,980,024.57 usft
549,555.22 usft
usft
Site Position:
Northing:
5,979,968.84 usft
Latitude: 70° 21'21.831 N
From: Map
Easting:
549,197.16 usft
Longitude: 149° 36' 1.675 W
Position Uncertainty: 0.00 usft
Slot Radius:
0.000in
Grid Convergence: 0.38 °
Well
Well Position
Position Uncertainty
1H-21
+N/S
+EAW
-
0.00 usft Northing:
0.00 usft Easting:
0.00 usft Wellhead Elevation:
5,980,024.57 usft
549,555.22 usft
usft
- - -
Latitude:
Longitude:
Ground Level:
70° 21'22.356 N
149° 35'51.196 W
54.40 usft
Wellbore
1H-21AL2-01
-- -
- -
Magnetics
Model Name
Sample
Data
Declination
Dip
Angle
Field
Strength
V)
(°)
(nT)
BGGM2018
9/1/2018
17.01
80.91
57.446
Design
1H-21AL2-01_wp02----
Autlh Notes:
Version:
Phase:
PLAN
Tie On Depth:
8,400.00
Vertical Section:
Depth From (TVD)
+N/S
+E/ -W
Direction
(usft)
(waft)
(usft)
(^)
-54.40
0.00
0.00
90.00
Plan Sections
Measured
TVD Below
Dogleg Build
Turn
Depth Inclination
Azimuth
System
+N/ -S
+E/•W
Rate Rate
Rate
TFO
(usft) (°)
C)
(usft)
(usft)
(usft)
(°/looft) (°1100ft)
(°/100ft)
(°)
Target
8,400.00
9449
83.58
6,640.47
-72.52
4,223.01
0.00
0.00
0.00
0.00
8,650.00
79.34
92.38
6,653.90
-63.63
4,471.52
7.00
-6.06
3.52
150.00
8,850.00
86.53
104.50
6,678.56
-92.86
4,667.32
7.00
3.59
6.06
60.00
9,240.00
91.92
77.73
6,683.93
-100.31
5,053.53
7.00
1.38
-6.87
281.00
9,415.00
93.78
89.85
6,675.19
-81.42
5,226.96
7.00
1.06
6.93
81.00
9,515.00
94.97
82.93
6,667.55
-75.15
5,326.40
7.00
1.19
-6.92
280.00
9,740,00
89.48
68.15
6,658.78
-19.14
5,543.41
7.00
-2.44
-6.57
250.00
10,015.00
89.50
87.40
6,661.25
38.80
5,810.91
7.00
0.01
7.00
90.00
10,300.00
92.93
67.74
6,655.14
99.78
6,087.77
7.00
1.20
-6.90
280.00
10,500.00
92.84
81.76
6,645.01
152.18
6,280.00
7.00
-0.04
7.01
90.00
10,695.00
91.12
68.21
6,638.25
202.56
6,467.78
7.00
-0.89
-6.95
263.00
10,995.00
91.04
89.21
6,632.53
260.94
6,760.28
7.00
-0.02
7.00
90.00
11,150.00
89.15
99.90
6,632.27
248.64
6,914.56
7.00
-1.22
6.89
100.00
6252018 4:10:38PM Page 2 COMPASS 5000.14 Build 85
✓
COnOCOP�I1llIp5
ConocoPhillips
i
BA ER
Planning Report
F IGHES
E company
Database: EDT Alaska Sandbox
Local Co-ordinate Reference:
Well 11-1-21
Company: ConomPhillips (Alaska) Inc. -Kup1
TVD Reference:
Mean Sea Level
Project: Kuparuk River Unit
MD Reference:
1 H-21 @ 96.00usft (1 H-21)
Site: Kuparuk 1H Pad
North Reference:
True
Well: 1H-21
Survey Calculation Method:
Minimum Curvature
Wellbore: 1H-21AL2-01
+N/ -S
+E/ -W
Design: 1 H-21AL2-01_wp02
Rate
Azimuth
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination
Azimuth
System
+N/ -S
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(1)
(1
(usft)
(usft)
(usft)
(usft)
(°HOOft)
(°)
(usft)
(usft)
8,400.00
94.49
83.56
6,640.47
-72.52
4,223.01
4,223.01
0.00
0.00
5,979,980.00
553,778.21
TIP/KOP
8,500.00
88.43
87.08
6,637.92
-64.39
4,322.58
4,322.58
7.00
150.00
5,979,988.78
553,877.72
8,600.00
82.37
90.59
6,645.95
-62.35
4,422.18
4,422.18
7.00
150.09
5,979,991.47
553,977.28
8,650.00
79.34
92.38
6,653.90
-63.63
4,471.52
4,471.52
7.00
149.81
5,979,990.52
554,026.63
Start
7 die
8,700.00
81.11
95.45
6,662.39
-67.00
4,520.67
4,520.67
7.00
60.00
5,979,987.48
554,075.79
8,800.00
84.71
101.50
6,674.74
-81.64
4,618.75
4,618.75
7.00
59.48
5,979,973.49
554,173.96
8,850.00
86.53
104.50
6,678.56
-92.86
4,667.32
4,667.32
7.00
58.73
5,979,962.59
554,222.60
3
8,900.00
87.20
101.06
6,681.30
-103.90
4,716.00
4,716.00
7.00
-79.00
5,979,951.87
554,271.35
9,000.00
88.58
94.19
6,684.98
-117.16
4,814.99
4,814.99
7.00
-78.81
5,979,939.28
554,370.41
9,100.00
89.97
87.33
6,686.25
-118.48
4,914.91
4,914.91
7.00
-78.56
5,979,938.61
554,470.33
9,200.00
91.37
80.47
6,685.08
-107.87
5,014.28
5,014.28
7.00
-78.47
5,979,949.88
554,569.61
9,240.00
91.92
77.73
6,683.93
-100.31
5,053.53
5,053.53
7.00
-78.55
5,979,957.70
554,608.81
4
9,300.00
92.57
81.88
6,681.57
-89.70
5,112.53
5,112.53
7.00
81.00
5,979,968.70
554,667.73
9,400.00
93.63
88.81
6,676.16
-81.60
5,211.99
5,211.99
7.00
81.16
5,979,977.46
554,767.13
9,415.00
93.78
89.85
6,675.19
-81.42
5,226.96
5,226.96
7.00
81.54
5,979,977.73
554,782.09
5
9,500.00
94.79
83.97
6,668.83
-76.86
5,311.56
5,311.56
7.00
-80.00
5,979,982.86
554,866.65
9,515.00
94.97
82.93
6,667.55
-75.15
5,326.40
5,326.40
7.00
-80.44
5,979,984.66
554,881.49
6
9,600.00
92.91
77.33
6,661.71
-60.62
5,409.91
5,409.91
7.00
-110.00
5,979,999.74
554,964.89
9,700.00
90.46
70.77
6,658.76
-33.17
5,505.96
5,505.96
7.00
-110.38
5,980,027.82
555,060.74
9,740.00
89.48
68.15
6,658.78
-19.14
5,543.41
5,543.41
7.00
-110.58
5,980,042.10
555,098.10
7
9,800.00
89.48
72.35
6,659.33
1.12
5,599.87
5,599.87
7.00
90.00
5,980,062.74
555,154.42
9,900.00
89.49
79.35
6,660.24
25.55
5,696.77
5,696.77
7.00
89.96
5,980,087.80
555,251.14
10,000.00
89.50
86.35
6,661.12
37.98
5,795.93
5,795.93
7.00
89.90
5,980,100.89
555,350.21
10,015.00
89.50
87.40
6,661.25
38.80
5,810.91
5,810.91
7.00
89.84
5,980,101.80
555,365.18
8
10,100.00
90.54
81.54
6,661.22
46.98
5,895.47
5,895.47
7.00
-80.00
5,980,110.54
555,449.68
10,200.00
91.75
74.65
6,659.22
67.59
5,993.24
5,993.24
7.00
-80.00
5,980,131.80
555,547.30
10,300.00
92.93
67.74
6,655.14
99.78
6,087.77
6,087,77
7.00
-80.14
5,980,164.60
555,641.60
9
10,400.00
92.91
74.75
6,650.04
131.86
6,182.28
6,182.28
7.00
90.00
5,980,197.31
555,735.89
10,500.00
92.84
81.76
6,645.01
152.18
6,280.00
6,280.00
7.00
90.36
5,980,218.27
555,833.46
10
10,600.00
91.97
74.81
6,640.81
172.46
6,377.77
6,377.77
7.00
-97.00
5,980,239.19
555,931.09
10,695.00
91.12
68.21
6,638.25
202.56
6,467.78
6,467.78
7.00
-97.29
5,980,269.89
556,020.89
11
10,700.00
91.12
68.56
6,638.15
204.40
6,472.43
6,472.43
7.00
90.00
5,980,271.76
556,025.52
10,800.00
91.11
75.56
6,636.21
235.18
6,567.49
6,567.49
7.00
90.01
5,980,303.16
556,120.37
10,900.00
91.08
82.56
6,634.29
254.13
6,665.59
6,665.59
7.00
90.14
5,980,322.76
556,218.34
10,995.00
91.04
89.21
6,632.53
260.94
6,760.28
6,760.28
7.00
90.28
5,980,330.20
556,312.97
12
11,000.00
90.98
89.56
6,632.44
260.99
6,765.28
6,765.28
7.00
100.00
5,980,330.28
556,317.97
11,100.00
89.76
96.45
6,631.80
255.75
6,865.08
6,865.08
7.00
100.01
5,980,325.70
556,417.79
11,150.00
1 89.15
99.90
6,632.27 r
248.64
6,914.56
6,914.56
7.00
100.05
5,980,318.92
556,467.31
Planned TD at 11180.00
6252018 4:10:38PM Page 3 COMPASS 5000.14 Build 85
ConocoPhillips
BAT
ConocoPhillips Planning Report IGHES
6F cor,,pa,
Database:
EDT Alaska Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Site:
Kuparuk 1H Pad
Well:
1H-21
Wellbore:
1 H-21AL2.01
Design:
1H-21AL2-01_wp02
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 11-1-21
Mean Sea Level
1H-21 @ 96.00usft (1H-21)
True
Minimum Curvature
Targets
Target Name
-hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting
-Shape (1) (1) (usft) (usft) (usft) (usft)
(usft) Latitude
1H-21AL2-01_T01 000 0.00 6,680.00 -7,918.431,144,719.73 5,979,679.00
- plan misses target center by 1137834.48usft at 11150.00usft MD (6632.27 TVD, 248.64 N, 6914.56 E)
- Point
1H-21AL2-01_704 0.00 0.00 6,660.00 -7,742.851,145,996.04 5,979,863.00
- plan misses target center by 1139109.51 usft at 11150.00usft MD (6632.27 TVD, 248.64 N, 6914.56 E)
- Point
1H-21AL2-01_T03
0.00 0.00 6,660.00
-7,842.641,145,509.32
5,979,760.00
- plan misses target center by 1138623.51 usft at 11150.00usft
MD (6632.27 TVD, 248.64 N, 6914.56 E)
- Point
- Polygon
1H-21 CTD Polygon Nor
0.00 0.00 0.00
-7,723.091,143,764.91
5,979,868.00
- plan misses target center by 1136897.64usft at 11150.00usft
MD (6632.27 TVD, 248.64 N, 6914.56 E)
- Polygon
25.79 1,403.34
5,979,904.07
Point
Point 1
0.00
0.00 0.00
5,979,868.00
Point 2
0.00
9.13 132.08
5,979,878.00
Point
0.00
272.48 84.80
5,980,141.01
Point
0.00
1,101.34 -31.78
5,980,969.00
Point
0.00
2,179.05 -272.73
5,982,044.99
Point
0.00
3,319.39 -304.25
5,983,184.98
Point
0.00
3,223.79 90.17
5,983,092.00
Point
0.00
1,937,50 110.73
5,981,806.00
Point
0.00
811.57 385.37
5,980,682.02
Point 10
0.00
-70.95 447.59
5,979,800.02
Point 11
0.00
-231.58 388.53
5,979,639.02
Point 12
0.00
-332.56 231.84
5,979,537.01
Point 13
0.00
-325.97 -11.14
5,979,542.00
Point 14
0.00
0.00 0.00
5,979,868.00
1H-21AL2-01 T06
0.00 0.00 6,633.00
-7,542.581,147,016.49
5,980,070.00
- plan misses target center by 1140128.55usft at 11150.00usft MD (6632.27 TVD, 248.64
N, 6914.56 E)
- Point
1H-21 CTD Polygon Ea=
0.00 0.00 0.00
-7,722.411,143,812.92
5,979,869.00
- plan misses target center
by 1136945.64usft at 11150.00usft
MD (6632.27 TVD, 248.64 N, 6914.56 E)
- Polygon
Point 1
0.00
0.00 0.00
5,979,869.00
Point
0.00
25.79 1,403.34
5,979,904.07
Point
0.00
397.55 3,275.00
5,980,288.17
Point
0.00
-885.89 3,166.56
5,979,004.16
Point
0.00
-735.54 1,440.34
5,979,143.07
Point
0.00
-321.02 -2.11
5,979,548.00
Point
0.00
0.00 0.00
5,979,869.00
1H-21AL2-01205
0.00 0.00 6,641.00
-7,621.041,146,479.90
5,979,988.00
- plan misses target center by 1139592.52usft at 11150.00usft MD 16632.27 TVD, 248.64 N, 6914.56 E)
- Point
Longitude
1,694,191.00 701 5'51.470 N 140' 23' 17.012 W
1,695,466.00 701 5'51.284 N 140° 22'39.884 W
1,694,980.00 701 5'51.036 N 140-22-54.
1,693,235.00 701 5'54.778 N 140' 23'43.370 W
1,693,235.00
1,693,367.00
1,693,317.99
1,693,195.94
1,692,947.89
1,692,908.83
1,693,303.84
1,693,332.90
1,693,614.96
1,693,683.01
1,693,625.02
1,693,469.01
1,693,226.02
1,693,235.00
1,696,485.00 701 5'51.716 N 1401 22'9.939 W
1,693,283.00 701 5' 54.714 N 1401 23'41.999 W
1,693,283.00
1,694,686.00
1,696,554.98
1,696,455.04
1,694,728.03
1,693,283.01
1,693,283.00
1,695,949.00 70° 5'51.749 N 1401 22'25.568 W
1H-21AL2-01_T02 0.00 0.00 6,677.00 -7,882.691,145,214.02 5,979,718.00 1,694,685.00 7015'51.085N
-plan misses target center by 1138328.51 usft at 11150.00usft MD (6632.27 TVD, 248.64 N, 6914.56 E)
Point
Casing Points - - --
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name (in) (in)
11,15000 6,632.27 23/8" 2.375 3.000
1401 23'2.7731
J
6252018 4:10:38PM Page 4 COMPASS 5000.14 Build 85
o-'
ConocoPhillips
ConocoPhillips
BA�C
-- - —--i
Planning Report
Vertical
Local Coordinates
Depth
Depth
UIEGRHES
+E/ -W
(usft)
a GEmmpa,
Database: EDT Alaska Sandbox
Local Co-ordinate Reference:
Well 1H-21
8,400.00
Company: ConocoPhillips (Alaska) Inc. -Kup1
TVD Reference:
Mean Sea Level
TIP/KOP
Project: Kuparuk River Unit
MD Reference:
1H-21 @ 96.00usft (1H-21)
4,471.52
Site: Kupamk 1H Pad
North Reference:
True
-92.86
Well: 1H-21
Survey Calculation Method:
Minimum Curvature
6,683.93
Wellbore: 1H-21AL2-01
5,053.53
4
9,415.00
Design: 1 H-21AL2-01_WP02
-81.42
5,226.96
5
Plan Annotatlons
-- - —--i
Measured
Vertical
Local Coordinates
Depth
Depth
+N/.S
+E/ -W
(usft)
(usft)
(usft)
(usft)
Comment
8,400.00
6,640.47
-72.52
4,223.01
TIP/KOP
8,650.00
6,653.90
-63.63
4,471.52
Start 7 cls
8,850.00
6,678.56
-92.86
4,667.32
3
9,240.00
6,683.93
-100.31
5,053.53
4
9,415.00
6,675.19
-81.42
5,226.96
5
9,515.00
6,667.55
-75.15
5,326.40
6
9,740.00
6,658.78
-19.14
5,543.41
7
10,015.00
6,661.25
38.80
5,810.91
8
10,300.00
6,655.14
99.78
6,087.77
9
10,500.00
6,645.01
152.18
6,280.00
10
10,695.00
6,638.25
202.56
6,467.78
11
10,995.00
6,632.53
260.94
6,760.28
12
11,150.00
6,632.27
248.64
6,914.56
Planned TD at 11150.00
6252018 4:10:38PM Page 5 COMPASS 5000.14 Build 85
ConocoPhillips Ba. KER
ConocoPhillips Travelling Cylinder Report '1 IGHES
aGEcompany
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1H Pad
Site Error:
0.00 usft
Reference Well:
1H-21
Well Error:
0.00 usft
Reference Wellbore
1H-21AL2-01
Reference Design:
1H-21AL2-01_wp02
Local Co-ordinate Reference:
Well 1 H-21
TVD Reference:
1H-21 @ 96.00usft (1H-21)
MO Reference:
1H-21 @ 96.00usft (1 H-21)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Output errors are at
1.00 sigma
Database:
EDT Alaska Prod
Offset TVD Reference:
Offset Datum
Reference
1H-21AL2-01_wpO2
Filter type:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method:
MD Interval 25.00usft Error Model: ISCWSA
Depth Range:
8,400.00 to 11,150.00usft Seen Method: Tray. Cylinder North
Results Limited by:
Maximum canter -center distance of 1,310.84 usft Error Surface: Pedal Curve
Survey Tool Program
Date 6/25/2018
Casing Hole
Depth
From
TO
(usft)
(usft) Name
(usft)
(usft) Survey (Wellbore)
Tool Name
Description
102.20
7,807.301H-21 Srvy 1-SLBGCT-MS(1H-21)
GCT -MS
Schlumberger GCT multishot
7,807.30
7,925.00 1H-21A_wp03(1H-21A)
MWD
MWD -Standard
7,925.00
8,400.00 1H-21 AL2_wp02(1 H-21AL2)
MWD
MWD- Standard
8,400.00
11,150.00 1H-21 AL2-01_wp02(I H-21AL2-01)
MWD
MWD - Standard
Casing Points _---�
Measured
Vertical
Casing Hole
Depth
Depth
Diameter Diameter
(usft)
(usft) Name
(") C)
121.00
121.00 16"
16 24
4,820.00
4,246.83 9 5/8"
9-5/8 12-114
11,150.00
6,728.27 23/8"
2-3/8 3
Summary
KuparuklHPad- 1H -13 -1H -13-1H-13
Reference
Offset
Centre to
No -Go
Allowable
Measured
Measured
Centre
Distance
Deviation
Warding
Site Name
Depth
Depth
Distance
(usft)
from Plan
Rererenrx
Offset Well - Wellbore • Design
(usft)
(usft)
(usft)
(usft)
Kupamk 1 H Pad
Meeeu.d Vertlwl
Meawred
Vertlral
Reference Onset
Tooeace+
1 H-05 - 1 H-05 - 1 H-05
Casing- GenimW
NO Go
All.ble
Depth Depth
Depth
Deplh
1 H-05 - 1 H-105 - 1 H-105
Azhnutn
+led
'Vw
Hole Sim centre
Cute..
Out of range
1 H-09 -1 H-09 -1 H-09
(uen)
luem
(.eft) Ivertl
r)
fvenl
Out of range
1 H-102 - 1 H-102 - 1 H-102
laenl
hien)
1005959 6,757,43
6.50000
5,56861
Out of range
1 H-102 - 1 H-10211 - i H-10211
-521.16
5,910.33
5 1.29e.59
335.36
1,066.11 Pass-fegor Rek
Out of range
1 H-102 - 1 H-10212 - 1 H-10212
5,603.77
$2.76 54.19
109.63
-522.01
5,930.19
Out of range
1 H-102 - 1 H-10213 -1 H-1021-3
105378 Pass -Mitpr Risk
Out of range
1 H-102 - 1 H-10214 - 1 H-10214
Out of range
IH -11 - IH -11 - 1 H-11
Out of range
1 H-12 - 1 H-12 - 1 H-12
Out of range
1H -13 -1H -13-1H-13
10,695.00
9,525.00
1,013.20
362.85
676.72
Out of range
Pass - Major Risk
1 H-15 - 1 H-15 - 1 H-15
1H-21-1H-21AL2-1H-21AL2wp02
8,711.75
8,725.00
79.40
1.45
78.52
Out of range
Pass - Minor 1/10
Rig: 1 H-108 - 1 H-1 08A - 1 H-1 08A wp07
Out of range
Offset Design
KuparuklHPad- 1H -13 -1H -13-1H-13
survey Program: 97
-GCT -MS
oneet Ste amm: em vM
Rule Assigned Major Rrsk
Onset Well error 0.00 usft
Rererenrx
Offset
Semi Mel, Axis
Meeeu.d Vertlwl
Meawred
Vertlral
Reference Onset
Tooeace+
onset Minx. Lent.
Casing- GenimW
NO Go
All.ble
Depth Depth
Depth
Deplh
Azhnutn
+led
'Vw
Hole Sim centre
Cute..
Warping
Deviation
(u ) ward
(uen)
luem
(.eft) Ivertl
r)
fvenl
Ivem
rl luanl
laenl
hien)
1005959 6,757,43
6.50000
5,56861
5263 5400
110.16
-521.16
5,910.33
5 1.29e.59
335.36
1,066.11 Pass-fegor Rek
10,073.26 6,757.40
8525.00
5,603.77
$2.76 54.19
109.63
-522.01
5,930.19
5 128822
33566
105378 Pass -Mitpr Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
6252018 10.10.27AM Page 2 COMPASS 5"..14 Build 85
TRANSMITTAL LETTER CHECKLIST
,
WELL NAME: /Y,-2-
PTD:
Development _ Service _ Exploratory _ Stratigraphic Test -Non-Conventional
ver' POOL:
FIELD:
Check Box for Appropriate Letter /Paragraphs to be Included in Transmittal Letter
rFTTRR
OPTIONS
TEXT rvn�a=.�••-----
segm��en�t of g well
MULTI
The permit is for a new wellbore
No. 1 7 , API No. 50 -l
of the original
LATERAL
Production should continue to be reported as a function
(If last two digits
in API number are
API number stated above.
between 60-69all
In accordance with 20 AAC 25.005(f), records, data and logs
well
tnum
acquired for the pilot hole must be clearly an API er (50
Pilot Hole
name from records, data and logs acquired for well
name on ennit .
The permit is approved subject to full compliance with 20 AAC 25.055.
issuance of a conservationame)Operator
Approval to produce/inject is contingent upon
io
exception.
(spacn
Spacing Exception
order approving a spacing
the liability of any p theg exception that may
assumes
occur. greater
All dry ditch sample sets submitted to the AOGCC must be in no
Dry Ditch Sample
sample intervalsow the
df 10' Sam rom l le intervals throu permafrost
than 30,tar etozo zones.
sam lesare first c au
Please note the following special condition of this permit:
testing of coal bed methanelowdesigned for
is not allowed
production or production
after (Comoa_Tnvlvidnd
Non -Conventional
(nam_ a of well) until e baseline data on
implemented a water well testing program
the AOGCC
Well
water quality and quantity. (Comya_�nv Name) must contact
water well testin ro ram.
to obtain advance approval of such
o ewell proposed by
Regulation 20 AAC 25.071(a) authorizes the AOGC Toam
well logs to be run. In addition to theh cationthe following well logs are
Nam me) the attached app
(Comyaw
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(13) and Regulation 20 AAC 25.071,
to the
iGCC
run must be onment of thd s well
composite�curvens for �mnlleoon,
u pension or abandgs
Revised 2/2015
Well Name: KUPARUK RIV. UNIT 11_H -21A_ L2-(�1
D#:2180800 Com an ----"�-- _-- _ --- _Proram DEV _
p y C9Nen.gas onfo ASL SKA INC. ._ lnitial Classfrype 9 _------ _ Well bore seg
—_-D) __ DEV/PEND.- GeoArea 890 -
Administration '17 Nonconven, gas conforms to AS31.05.03Q(r 1 A),(1.2.A-D) — — Unit 11160 _ On/Off Shore On Annul I Di
^
Appr Date
MGR 7/5/2018
Geology
Appr Date
SFD 7/2/2018
Geologic
Commissioner:
Permit fee attached
- - - NA ----- — ar sposal
� � - � - - - - - - - - - - - -
NA
Lease number appropriate _ _ _ _
.Unique well name and number -
1
Surf Loc 8 Top Prod Int lie in ADL0025639, TO has in ADL0025638.
2
Yes
3
-
Well located proper distance from drilling unit. boundary
4
KUPARUK RIVER,- KUPARUK. RIV OIL -490100
5
Yes
6
Sufficient acreage available in drilling unit
7
Conservation Order No. 432D has no interwell. spacing. restrictions. Wellbore will be more than 500'
-
8
-
9
Operator only affected pally. - - � -
10
Appr Date
11
SFD 7/2/2018
12
- _ _.. _....
Permit
Permit. can be issued without conservation order
13
- - - - - - - -
14
- Yes
15
-approval -.._----
-Can Permit be approved roved before 15 -day wait --- -
16
--
18
Engineering
19
NA
20
Pre -produced injector, duration of pre production less than 3 months (For service well only) .
21
22
Appr Date
MGR 7/5/2018
Geology
Appr Date
SFD 7/2/2018
Geologic
Commissioner:
Permit fee attached
- - - NA ----- — ar sposal
� � - � - - - - - - - - - - - -
NA
Lease number appropriate _ _ _ _
.Unique well name and number -
_ Yes
Surf Loc 8 Top Prod Int lie in ADL0025639, TO has in ADL0025638.
Well located in. a defined. pool - - - - - - - - -
Yes
- - - - -
-
Well located proper distance from drilling unit. boundary
Yes
KUPARUK RIVER,- KUPARUK. RIV OIL -490100
- _ _
Well located proper distance from other wells
Yes
Kuparuk River Oil Pool, governed by Conservation Order No. 432D
Sufficient acreage available in drilling unit
Yes
Yes
Conservation Order No. 432D has no interwell. spacing. restrictions. Wellbore will be more than 500'
-
If deviated, is wellbore plat. included - - -
-
- from an external property line where ownership or landownership. changes As proposed,. well
Operator only affected pally. - - � -
- - Yes
will
conform to s requirements.
- spacing 9 r - q -
Operator has- -
bond in force
Yes
- _ _.. _....
Permit
Permit. can be issued without conservation order
Yes -
- - - - - - - -
_ - - - - -
Permit can be issued without administrative
- Yes
-approval -.._----
-Can Permit be approved roved before 15 -day wait --- -
Yes
- _ -
Yes
Well located within area and. strata authorized by Injection Order # (put 10# in Comments) (For NA
All wells. within 1/4mile area of review identified (For service well only)- - . -
NA
Pre -produced injector, duration of pre production less than 3 months (For service well only) .
- NA.
Conductor stringprovided
—_ —._—
Surface casing, protects all. known USDWs - - - -
NA
- - - -
- - Thru tubing CTD Sidetrack from existing wellbore-
-
CMT vol adequate. to circulate conductor &surf csg
NA _ -
.. - Thru tubing CTD Sidetrack from existing wellbore
- - - _ _ - _ - _
CMT. vol adequate to tie-in.long string to surf csg
s
NA -
_ _ Thru tubing CTD Sidetrack from existing wellbore
_ _ _ _
CMT will cover -all known.productive horizons - .
NA
- . - -
- - Thru tubing CTD Sidetrack from existing wellbore
- - - - - - - - - -
Casing designs adequate for C, T, B &
NA..
- - -
-
- . - Slotted liner completion, all of lateral in zone. - - -
- -permafrost. - _ _ -
Adequate tankage or reserve pit
. Yes -
- - - - - - - - - - - - -
._-__-.-
If a re -drill, has a 10-403 for abandonment been a
- PP -roved ------
Yes -
- - - - - - - -
-
Adequate wellbore separation proposed-
.Yes
- ---- --- --- _
If djverter required, does it meet regulations - --.
Yes-
_ -.-
-
Drilling fluid program schematic &equip listadequate.
- -
_ Thru tubing CTD Sidetrack from existing wellbore
_.. -. _. -_._.
BOPEs,-do they meet regulation - -
- Yes
_
ROPE Press ratio a - - - - -
P g appropriate; test to(putpsig in comments)- _ -
Yes
Yes.
-
- - - _ - _
Choke manifold complies w/API. RP -53 (May 84)-
_
ROPE test to 3000 psi.
--
- - -._-.__
Work will occur without operation _shutdown.
Yes.
-..
-
..
--
Is presence of H2S gas. probable,
Yes
- -------------- ---Yes
- ------------
Mechanicalconditionof wells within AOR verified (For. service well only) - -
NA
_ - - -.- _
Permit can be issued w/o hydrogen sulfide measures
- - - - -
_ _
- - - - - - - - - - - - - - _
Data presented on potential overpressure zones
No
- , Wells_on.1H Pad are H2S-bearing. H2S measures required,
- - _ - -
Seismic analysis of shallow gas -zones _
Yes - . - ..
- _ _ _ _ _
- Expected reservoir pressure is .
ppg EMW, with a maximum up to —10.0 ppg EMW:
- - - - - -
Seabed condition survey (if off_ -shore
NA - .
Well will be drilled usingi.8.6 ppg mud, a coiled. -tubing rjg, and managedpressuredrilling-
- -
name/phone for weekly progress reports [exploratory only] -
NA -
NA
- . technique to control formation pressures and stabilize shale.sections. NOTE: Chance of
-
_
- - - - - -
- - - -
. encountering gas while drilling this_wellbore due. to gas. injection performed in this area,
Date: Engineering Public
Commissioner Date Com er Date
