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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout219-093WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϭϵϬϵϯϬ Ͳ^Ğƚ͗ϯϲϮϳϬJRBy Abby Bell at 1:43 pm, Dec 21, 2021
1H-11950029235910000 KRU WLIPROFFINAL FIELD24-Jun-211H-11750029236020000 KRU WLIPROFFINAL FIELD16-Jun-213H-31A50103202050100 KRU WLCUTTERFINAL FIELD31-Jul-213S-61150103207740000 KRU WLCUTTERFINAL FIELD11-Oct-211R-10150029214040300 KRU WLSAMPLINGFINAL FIELD30-Jun-213H-3750103208220000 KRU WLGLSFINAL FIELD29-May-213F-0450029214490000 KRU WLIPROFFINAL FIELD23-Feb-211J-10150029232860000 KRU WLPPROFFINAL FIELD2-Mar-211D-0250029204290000 KRU WLIPROFFINAL FIELD17-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD18-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD20-Feb-21MP-150029205730000 KRU WLSCMTFINAL FIELD28-Mar-211G-0250029208130000 KRU WLIPROFFINAL FIELD1-Apr-211C-19050029231360000 KRU WLIPROFFINAL FIELD30-Oct-212L-31850103206810000 KRU WLIPROFFINAL FIELD24-Jul-21
Originated:Delivered to:3-Aug-21HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAMEJOB TYPEDATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1C-27 50-029-22943-00 n/aKuparuk River Packer Setting Record Field- Final4-Jul-21 0 12 1D-135 50-029-22816-00 907261026 Kuparuk River Packer Setting Record Field- Final11-Jul-21 0 13 1D-135 50-029-22816-00 907276312 Kuparuk River Packer Setting Record Field- Final19-Jul-21 0 14 1E-34 50-029-22805-00 907273379 Kuparuk River Patch Setting Record Field- Final 17-Jul-21 0 15 1E-34 50-029-22805-00 907240278 Kuparuk River Multi Finger Caliper Field & Processed 29-Jun-21 0 16 1R-101 50-029-21404-03 907268285 Kuparuk River Leak Detect Log Field- Final 16-Jul-21 0 17 1R-101 50-029-21404-03 907269600 Kuparuk River Multi Finger Caliper Field & Processed 16-Jul-21 0 18 2K-04 50-103-20099-00 907266787 Kuparuk River Plug Setting Record Field- Final 14-Jul-21 0 19 2N-333 50-103-20525-00 906845070 Kuparuk River Cement Retainer Record Field- Final 2-Jul-21 0 110 2V-03 50-029-21040-00 907240668 Kuparuk River Plug Setting Record Field- Final 30-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:08/03/2021By Abby Bell at 2:10 pm, Aug 03, 2021PTD: 2190930E-Set: 35482
Originated: Delivered to:3-Aug-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 4-Jul-21 0 12 1D-135 50-029-22816-00 907261026 Kuparuk River Packer Setting Record Field- Final 11-Jul-21 0 13 1D-135 50-029-22816-00 907276312 Kuparuk River Packer Setting Record Field- Final 19-Jul-21 0 14 1E-34 50-029-22805-00 907273379 Kuparuk River Patch Setting Record Field- Final 17-Jul-21 0 15 1E-34 50-029-22805-00 907240278 Kuparuk River Multi Finger Caliper Field & Processed 29-Jun-21 0 16 1R-101 50-029-21404-03 907268285 Kuparuk River Leak Detect Log Field- Final 16-Jul-21 0 17 1R-101 50-029-21404-03 907269600 Kuparuk River Multi Finger Caliper Field & Processed 16-Jul-21 0 18 2K-04 50-103-20099-00 907266787 Kuparuk River Plug Setting Record Field- Final 14-Jul-21 0 19 2N-333 50-103-20525-00 906845070 Kuparuk River Cement Retainer Record Field- Final 2-Jul-21 0 110 2V-03 50-029-21040-00 907240668 Kuparuk River Plug Setting Record Field- Final 30-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:08/03/2021Wd͗ϮϭϵϬϵϯϬ Ͳ^Ğƚ͗ϯϱϰϴϭBy Abby Bell at 2:10 pm, Aug 03, 2021
ORIGINATED TRANSMITTAL DATE:11/11/2020
ALASKA E-LINE SERVICES TRANSMITTAL #:3199
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG
3199 1R-101 50-029-21404-03 GR/CCL 10/25/2020
DELIVERED TO DIGITAL FILE PRINTS CD's
Company & Address # of Copies # of Prints # of Copies
Conoco Phillips Alaska Inc.1 0 0
Attn: NSK-69
tom.osterkamp@conocophillips.com
Received By:
Print Name Signature Date
AOGCC 1 0 0
ATTN: Natural Resources Technician II
abby.bell@alaska.gov
Received By:
Print Name Signature Date
DNR 1 0 0
Natural Resource Tech II
DOG.Redata@alaska.gov
Recevied By:
Print Name Signature Date
Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska:
tom.osterkamp@conocophillips.com reception@ake-line.com
Received by the AOGCC 12/16/2020
PTD: 2190930
E-Set: 34405
Abby Bell Abby Bell 12/16/2020
ORIGINATED TRANSMITTAL DATE:11/11/2020
ALASKA E-LINE SERVICES TRANSMITTAL #:3199
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG
3199 1R-101 50-029-21404-03 GR/CCL 10/25/2020
DELIVERED TO DIGITAL FILE PRINTS CD's
Company & Address # of Copies # of Prints # of Copies
Conoco Phillips Alaska Inc.1 0 0
Attn: NSK-69
tom.osterkamp@conocophillips.com
Received By:
Print Name Signature Date
AOGCC 1 0 0
ATTN: Natural Resources Technician II
abby.bell@alaska.gov
Received By:
Print Name Signature Date
DNR 1 0 0
Natural Resource Tech II
DOG.Redata@alaska.gov
Recevied By:
Print Name Signature Date
Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska:
tom.osterkamp@conocophillips.com reception@ake-line.com
Received by the AOGCC 11/11/2020
PTD: 2190930
E-Set: 34238
Abby Bell Abby Bell 11/12/2020
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STATE OF ALASKA AUG 14 ^rjjq
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT ANDiCdWC
1a. Well Status: Oil ❑� Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑
20AAC 25.105 20AAc 25.110
GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions:
1b. Well Class:
Development Q Exploratory ❑
Service ❑ Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Abend.: 7/15/2019
14. Permit to Drill Number / Sundry:
219.093
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded:
7/7/2019
15, API Number:
50-029-21404-03-00 '
4a. Location of Well (Governmental Section):
Surface: 164' FNL, 139' FWL, Sec 20, T12N, R10EM UN
Top of Productive Interval:
423' FNL, 1085' FWL, Sec 20, T12N, R10E, UM
Total Depth:
2607' FSL,2295' FWL, Sec 29, T12N, R10E, UM
8. Date TD Reached:
711212019
16. Well Name and Number:
KRU 1R-101 '
9. Ref Elevations: KB:79.9
GL: 45.2 ' BF:
17. Field / Pool(s): ,
Kuparuk River FieldNVest Sak Oil Pool
10. Plug Back Depth Ni
N/A
18. Property Designation:
ADL 25635, ADL 25640 '
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 539630. y- 5991050 Zone- 4
TPI: x- 640778 y- 5990786 Zone- 4
Total Depth: x- 542056 y- 5983264 Zone- 4
11. Total Depth MD/TVD:
11871/3448
19. DNR Approval Number:
LONS 83.134
12. SSSV Depth MD/TVD:
NIA
20. Thickness of Permafrost MD/TVD:
1682/1682
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:
3678/3379
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 GRADE SETTING DEPTH MD SETTING DEPTH NHOLE SIZE CEMENTING RECORD D AMOUNT
CASING FT TOP BOTTOM TOP BOTTOM PULLED
16 62.5 H40 38 121 38 121 24 260sx CS II
9 618 36 J-55 37 4380 37 3481 121/4 1250sx PFE III, 420 sx PPC
7 26 J-55 35 6500 35 3509 8 1/2 65sx Class G
3112.21 6.5 L-80 3606 11871 3328 3448 4114 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): / Hf -I
SLOTTED LINER @: }f 14rzot
4052-11870 MD and 3481-3448 TVD
COMPLETION
DATE
1
VERIAILD
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
4.5 3628 3557/3294
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes ❑ No Ed
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED
27. PRODUCTION TEST
Date First Production:
7/2012019
Method of Operation (Flowing, gas lift, etc.):
GAS LIFT
Date of Test:
7/26/2019
Hours Tested:
1 7.5hrs
Production for
Test Period
Oil -Bbl:
160.6
Gas -MCF:
39.7
Water -Bbl:
0.3
Choke Size:
209
Gas -Oil Ratio:
247 SCF/BBL
Flow Tubing
Press. 2071
I Casino Press:
1 767osi
ICalculated
24 -Hour Rate
Oil -Bbl:
4
Gas -MCF:
127
Water -Bbl:
1
Oil Gravity - API (corr):
18.0
Form 10407 Revised 5/2017 I7L 10/ail/ WONTINUED ON PAGE 2Submit ORIGINIAL orp
4e 1a12_7117 RBDMS0"/ AN 2 0 2019
Winston, Hugh E (CED)
From: Long, William R <William.R.Long@conocophillips.com>
Sent: Wednesday, August 21, 2019 5:07 PM
To: Winston, Hugh E (CED)
Subject: RE: [EXTERNAL]KRU 1R-101 Well completion report
Huey,
Formation at TD: West Sak B Sand
Slotted Liner Ran: 14 -Jul -2019
Please let me know if you would like any additional information.
Thanks,
William Long
907-263-4372(office)
281-723-6000 (cell)
From: Winston, Hugh E (CED) <hugh.winston@alaska.gov>
Sent: Tuesday, August 20, 2019 3:57 PM
To: Long, William R <William.R.Long@conocophillips.com>
Subject: [EXTERNAL]KRU 1R-101 Well completion report
Hi William,
I am entering data for KRU 111-101 and your name was listed on the report as the contact person. There are two items
not listed on the report that I need to know
• The formation at TD
• The date the slotted liner was run
If you could please reply with this info and I will write it into the report and finish processing it. Thanks
Huev Winston
Statistical Technician
Alaska Oil and Gas Conservation Commission
huRh.winston@alaska.aov
907-793-1241
28. CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No ❑�
If Yes, list formations and intervals cored (MD/TVO, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
29. GEOLOGIC MARKERS (List all formations and markers encountered):
30. FORMATION TESTS
NAME
MD
TVD
Well tested? Yes ❑ No ❑�
If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Surface
Permafrost - Base
1682
1682
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
3798
3448
information, including reports, per 20 AAC 25.071.
Formation @ TPI -West Sak B
West Sak D
3655
3362
West Sak C
5215
3191
Wes+54k 8 I*-
Formation at total depth:
11871
3448
31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
oaleontoloaical report, oroduct on or well test results. r 20 AAC 25,070,
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: James Ohlin er Contact Name: William Lon
Authorized Title: Sta TD Engineer Contact Email: William. R.Longocop.com
Authorized Contact Phone: 263-4372
Signature: Date: f
INSTRUCTIONS
General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Saft 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, vitrinke 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
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3,6066 3.3284 45.79 SBR Deployment Seel with 6' seal bore
2.990
36120 3.332.6 45.80 CROSSOVER Crours over 3-112'x3-1 %Pin x Pin
2890
4051.1 3.4810 91.12R E - cross over 3-112'-2-718"
2391
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TSLEEVE
6. 8 5 3,495.9 92.07 DEPL H ermanent OCLL
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2.3]5
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Completion Details
Top(TVOI I Topmcl
Top MKBI MKBI 1°) lar, Deo Co.
Nominal
10 (nl
326 32610HANGER Tubing banger
4.500
3,556.9 3,294.1 14 PAPacker Baker FP @ 35>0'
45CKER
3.820
3,575.3 3,308.9 1 4576 NIPPLE jNfippIeGXSr1CcONI, 3.813" (PTp3813GX7169,SN: 2153]-01)
3958
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3626.7 3,342.8 45.82 WLEG
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2,5374 2,512.6 CamcO KB -2 1 GAS LIFT GLV BIN .1 8 1,50]0 711 019
2 3.50 .1 3,257.2 CamcO KB -2 1 GAS LIFT OV BKO-3 0. 13 6x302019
Notes: atenerel S Safety
End oath
Annomioa
8112
iNOTE: VIEW SCHEMATIC wIAlaska Scbematic190
NIPPLE: 3.5]S2
Liiv Tap Rican. G W0
WIRELINE GUIDE'. 3.e'61
1vin Top',3.0
Camas aprm: 3RUS S"
Carelr agwm: 3.a G- OKKB
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CO(IOCOPFIill)ps Well Attdbutr Max Angle! TD
Field theme WeIIM,e APVl1VlI WeIIMre 3Nlus ncl l'1 MD InA Act BIm InKB
Alaska. Inc. KUPARUK RIVER UNIT 500292160600 PROD 7.92 d,600.00 8,5]0.6
79
IRm.slareole lomsAM
Casing Strings
NACLeuMnuticooki
chain, Descnplion
CONDUCTOR
no fns m0n1 top RnkB, sOD,PtbMKB) Isar Depth flVD1... WULen p_Grade Top Thread
16 15.06 380 121.0 1210 62.50 H40 Welded
.........
MNGERI MS
Cain, Descnplion
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7 6.06 350 W0.0 5,330.8 26.00 J55 BTC
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61AF OPEN HOLE
6118 600 11,8495 12,170.5
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6 3.00 8,053.0 8,058.0 648).5
CONDUCTDB 396190
chsins DeSrnpron
3"OPEN HOLE
..TO ID.... rop tonal Set epth solea) Set Deem VrvVO)-. W,Len O._Grzde RRIThad
3 290 12170.5 12611.0
Tubing Strings
W LIErZ m
Tuein, oemnpdon shin, Mz... IDOn Top lnnB) set Depin ln.. sans Gavle lrvDl l... WrVNn1 Grade rop eonnec0on
TUBING 31/2 2.99 i,]t50 6285.4 5,175) 9.30 LUPO DUE MOD
Completion Details
GAS UFT: 3634.1
I Top
rop lone) tenant
Toil Nomina
CI Item Des eom ID lint
6,220.5 5,129.0
a4.05 NIPPLE CAMCO DS NIPPLE 2.812
PACKFfi3.5s
5,2591 1 5.1568
43.91 SEAL ASSV BAKER SEAL ASSEMBLY wILOCATOR COLLAR 3.000
Other In Hole (Wireline retrievable plugs,
valves, pumps, fish, etc.)
ToP( )
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IDM)
PoPPIE; a.5lsz
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3,3`72
45.7
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Baker Re Packer assem y. 3.79'M Decker, XO, 8 NS
)/1912019
2.310
Lw Tap vw.:3.m0.o
inner w; 9.WC0
Packer
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Assembly stung into PTSA.
3,800.03.324.2
4T78
Llnertop
Northern SolutdonP wai seals stabbed into liner top
7192019
2.310
seal bore. (Seals leak) 610' OAL. 4.5" GS b pull.
oMULmEGWDd3GpGU
3,600.0
33284
4579
Liner Top
OTD Liner top iram 101 stere. 2BUTseaI bare.
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2.990
fmwnl DOOM 3,E�.0 Ma
LINER IATFRAL 1m cm:
3,688.0
3,305.5
45.90
WHIPSTOCK
Delta Retrievable Whlpnpc , Onemed 1 H ,
8202019
0.000
36C661La11 o
OAL 18'
LMT Saii 389863116.0
WhoMODIt s.ee.0
3,7580
7,431.4
46.02
BRID E L
We a OF a nortl Big boy C I BP 10, 000psi dieereMal.
4222019
BRIDGE PLUG PERMENEM:
3.]540
PERMENENT
um Td.Z.0
Caevnl Sodded: Slots Po{B
4,7150
4,094.5
4757
JET CUT
Jet Cut
M]2019
0.000
8,470.0
5,3089
4375
BUCKLED L I
Caliper .5"Linerrs presently Buckled Detvmen
11/2008
2680
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6476-6786'RKB; Min ID=2.68"nrough this Section
2681'
1012311) -SL was able to drift 2.75' Gauge Ring through
buckled Liner area between 64)6-6)86' RKB M tag
7254'RKB
SURFAcE:3r sMo.s-
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5,M34
4.16
SANDSCREEN
NSOLO IION PRODUCTIONPACKER,
FLOW THROUGH KNUCKLE, OUADCO PRE -PACK
12018
0000
JET CUT: 4.7160
SCREEN. OAL 12', hi DO 25".
7,213.0
5,850.0
43.14PARTEOLIN
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1 013
0000
Gnstor..s.0154
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35"liner
8,053.0
8,4836
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WHIPSTOCK
FIL THRUWHIPSTOCKBLI 1
460QDCB
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8,095.0
6,516.3
38.93
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FLO-THRUWHIPSTOCKBLIPHI
412812008
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GASURT;5.7160
8,144.0
6,5544
38.83
FISH IRISH
GS Liner running lo0l', 53' long lo9t152001
11512001
Perforations 8 Slots
Gns uW: 6.1148
shot
Gen
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Bt (Me)
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(mane)
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(RKB)
unkedmne
Dam
pnoem
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core
NIPPLE:e9ae
3,688.0
3.7060
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3,398.0
6119/2019
0
CMT SOZ
N: 8"
POWERFLOW HMX 6SPF
8,185.0
10,2010
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- tR-01811-
4292008
0
SLOTS
.1
01
@ 4 circumferential
ISIOnedpipe-
adjacent rows, 3" centers
staggered 18 deg, 3' n0n-
sFxAssv: a.zse.t
signed ends
8,733.0
9,0190
A ,A-. R.
41302008
SLOTS
Shottealpipti
01811
@ 4 arc urferenual
adjacent rows, 3" centers
staggered 18 deg. T non-
UNER N BN3110.5150
SlOned ends
PRODUCTIONPOST&RK
O8'S00°
BUCKLED LIN ER. 8.4)00
9,1450
9,2400
A -5, 1R-
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4nW2008
0
SLOTS
Ione pi pG-Dt
id
@ 4 circumferential
adja cent rows, cen1on,
staggered deg, 3' non
deg,
6PD
SlOnad Ends
s
L I NEEN1,L30
PARTEDLINER. 1,3130
10,165511,816.6
- A-0, iR-
10!182000
32.0
SLOTS
.
4
018
curpipe-
ad 4 circumferential
@
adjacent had, centers
deg
smg9ered deg, 3' nan-
slotted ends
WHIPSTOCK; e,0i10
WINOON BLI-01; 9.Di4a
cement
squeezes
Top IND) Be. Vi
Topporn Ben mKB] (MB) IRKS) Dea Sled Date Lnm
.,Me
5,617.0 8,(100.0
4,]09.3 1 6,4425Cement VN419
PBI WHIPSTOCK 8.0960
SQueeS
3.685.0 33860.0
3.W3AI 3, S5 IProduction 8261 19 5. pig cement squeezed into surface pipe m
Casing Cement perh'm production suing
RdR;C1u0
3, 85.0 39660
3.3834 3,518.5 So ace Using 82612019 squeeze roots o. ppg camera inw su ett pipe rom
Cement the production string win perp shot in it
Mandrel Inserts
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as
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Run Grade
Com
5.015.4
4,297.5
CAMCO
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61m' OPEN HOLE B; IyBas
@,f7a6 _ _
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5)180
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GAS LIFT
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1500
1,2970
512272008
Belo
7
CIBP
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1R,6110
KUP PROD WELLNAME 1R-016 WELLBORE 1R-01
COn000P11llips
Alaska, IrK:.
CanmenL
SSSV. NIPPLE
NN4H'N SRRN.10:30:52AM
Mandrel Inserts
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on
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TaRmoI
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Make
MOON
OO (in)Sary
Valve
TYPa
LaRx
TYPa
Portslo
Ilnl
iHO Run
IPsll
Run Dale
Cam
5 6,174.7
5,0962
CAMCO
MMM
112
GAS LIFT
OPEN
OPen
3192019
Belo
I
wF
CIBP
CONDUCTOR; 3661310
GnB UFT 36n.a
GPSUFT:S.1
PACRER:3559.P
HU PIE.3.2
LYa rop PCYm, 3511.0
Ur..mP; 3Em.G
WIRELINE WIDE, 3GM 7
CmmSa.SBNG.
LINER LATERAL iM CTO;
],111.611.8]1 0
CMT603:36EBG370R0
WHIPSTOCK3GSB0
BRIDGE PLUG PERMENENT;
B. 5a 0
Uw TPP3.0
Cemem SgUeaae', 3690.
SURFRCE;32.04,393S�
JETCUT;4.I150
GM UFT: 5.0144
GnxM 80uxu; SG1T.O.
815 LIFT: 61160
GAS LIFT 6.174
NIPPLE; 6TSM 6
SOL. ;S.E9.1
LINER M1 6212]109150
PRODUCTION POST SRP,
SAGS
BUCF ED L I N E R; G,4TOO
GOING SCREEN: T NH0
PARTED L I N E N. 7,2130
..TOCK am O� L
LMNDyll el"N. E.G.
RUNS
IUN WMPBTOCK B.W5..
FISN', S,144.0��
SLOTS,&1ID."Moo
BLOTS; 91 19.09,2100
_
SLOTS, DINED. OSOIA"
SLM IO.I.E.MG1G6
61R OPEN HOLE 6,11 BI6S
S OPEN HOLE 6: 131TS`
126110
Operations Summary (with Timelog Depths)
1R-101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Tlme P -T -X
Operation
(MB)
End Depth (0KB)
6/30/2019
6/30/2019
0.50
MIRU
MOVE
RURD
P
Complete move check list
0.0
0.0
1900
19:30
6/30/2019
6/30/2019
2.00
MIRU
MOVE
RURD
P
Peak trucks arrive at 19:30 hrs, PJSM,
0.0
o.5-
19:30
21:30
hook up to sows, pull sub & pits off
well
6/30/2019
6/30/2019
2.00
MIRU
MOVE
MOB
P
Sub & pits spotted on edge of pad
0.0
0.0
21:30
23:30
6/30/2019
7/1/2019
0.50
MIRU
MOVE
RURD
P
Safe out areas, drop stairs & secure
0.0
0.0
23:30
00:00
landings
7/1/2019
7/1/2019
1.00
MIRU
MOVE
RURD
P
Peak arrives w/ truck, PJSM, pick &
0.0
0.0
00:00
01:00
drop reel from rig
7/1/2019
7/1/2019
2.30
MIRU
MOVE
RURD
P
Remove bales, LD mast, coil cable &
0.0
0.0
01:00
03:18
clear walk -ways
7/1/2019
7/1/2019
1.70
MIRU
MOVE
RURD
P
Staging equipment for spindles,
0.0
0.0
03:18
05:00
cleaning up welds for Tuboscope,
begin swapping to 2-5/8" gripper
blocks
7/1/2019
7/1/2019
7.00
MIRU
MOVE
RURD
P
Complete swapping injector gripper
0.0
0.0
05:00
12:00
blocks to 2 5/8" coil. Remove spindles
and pillow block reel bushings. Install
new pillow block bushings and
spindles. Remove BOPE hydraulic
hoses prep to remove stack
7/1/2019
7/1/2019
6.00
MIRU
MOVE
RURD
P
Remove BOPE stack and secure,
0.0
0.0
12:00
18:00
Configure replacement stack with test
valves and fluid return line. Prep for
reel install, Paint welds on crown, A
legs, injector, and reel house after
tuboscope inspection
7/1/2019
7/1/2019
2.00
MIRU
MOVE
RURD
P
Crew change. Get new BOPE stack
0.0
0.0
18:00
20:00
hanging in cellar. Clean up reel house.
Lubricate level wind and saddles
7/1/2019
7/1/2019
2.00
MIRU
MOVE
RURD
P
PJSM with Peak. Load new 2 5/8" coil
0.0
0.0
20:00
22:00
string. Set in saddles. Install
horseshoe clamps
7/1/2019
7/2/2019
2.00
MIRU
MOVE
RURD
P
PJSM. raise mast into position and
0.0
0.0
2200
0000
pin. Close wind walls. Normal up
winch lines
7/2/2019
7/2/2019
2.00
MIRU
MOVE
RURD
P
Shim reel & torque saddle clamps, MU
0.0
0.0
00:00
02:00
hoses on stack (kill & choke),
performing Quadco inspections
7/2/2019
7/2/2019
2.00
MIRU
MOVE
RURD
P
Button up reel, install stripper,
0.0
0.0
0200
0400
continue Quadco inspections
7/2/2019
7/2/2019
1.50
MIRU
MOVE
RURD
P
Continue Quadco inspections,stage
0.0
0.0
0400
0530
drilling line to Desiring, begin changing
out goose -neck rollers to 2-5/8"
7/2/2019
7/2/2019
2.50
MIRU
MOVE
RURD
P
Weld 2" pipe in 2-5/8" tag end (to
0.0
0.0
05:30
0800
install 2" grapple), continue Quadco
inspections, complete stripper install,
continue goose -neck roller swap
7/2/2019
7/2/2019
2.00
MIRU
MOVE
RURD
P
Allow pipe to cool & complete welding
0.0
0.0
08:00
10:00
passes, complete install of goose-
neck rollers, stage hydraulic oil for sub
side oil change, begin to change out
electrical panel in choke house,
service crown
7/2/2019
7/2/2019
2.00
MIRU
MOVE
RURD
P
RU 1" drill line spool, connect to
0.0
0.0
10:00
12:00
I
existing drill line, route through to
shieve
Page 1113 ReportPrinted: 7/1 612 01 9
Uperations Summary (with Timelog Depths)
1 R-101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
Dur(hn
Phase
op Code
Activity Code
Time P -T -x
Operation
(11KB)
End Depth(ftKB)
7/2/2019
7/2/2019
1.00
MIRU
MOVE
RGRP
P
Pulling new drill line through & wrap
0.0
0.0
12:00
13:00
on drum, on 3rd shieve Lewis Snake
connection failed to provide enough
friction, drill line unraveled through
sheavesto rig floor (all personell clear
of red zone, no damaged equipment)
7/2/2019
7/2/2019
7.20
MIRU
MOVE
RGRP
P
Clear line from floor, PJSM, laydown
0.0
0.0
13:00
14:12
E
I
I mast
7/2/2019
7/2/2019
2.30
MIRU
MOVE
RGRP
P
Pull line from mast & sheaves, pull old
0.0
0.0
14:12
16:30
line from spool
7/2/2019
7/2/2019
1.50
MIRU
MOVE
RGRP
P
Install inner reel iron, 3/8" cable
0.0
0.0
16:30
18:00
enroute to rig (to pull 1"drill line)
7/2/2019
7/3/2019
6.00
MIRU
MOVE
RGRP
P
Stage 3/8" wire rope, string through
0.0
0.0
18:00
00:00
crown and traveling blocks
7/3/2019
7/3/2019
3.00
MIRU
MOVE
RGRP
P
Raise mast, pull 1-1/8' new drill line
0.0
0.0
00:00
03:00
through crown and traveling blocks.
Remove 3/8" pull wire.
7/3/2019
7/3/2019
3.50
MIRU
MOVE
RGRP
P
Install new 1-1/8" drill line on draw
0.0
0.0
03:00
06:30
works drum & secure to deadman
7/3/2019
7/3/2019
4.00
MIRU
MOVE
RURD
P
Install stripper brass, install 2-5/8"
0.0
0.0
06:30
10:30
rams, change out sub side hydraulic
oil, test traveling blocks
7/3/2019
7/3/2019
2.30
MIRU
MOVE
RURD
P
MU inner reel iron
0.0
0.0
10:30
12:48
7/3/2019
7/3/2019
2.20
MIRU
MOVE
RURD
P
MU pressure bulkhead, remove BOP
0.0
0.0
12:48
15:00
flange (work to remove), replace
annular preventor, MU stripper to
injector
7/3/2019
7/3/2019
1.10
MIRU
MOVE
RURD
P
Continue MU pressure bulkhead
0.0
0.0
15:00
16:06
(much more time consuming than
WFD bulkhead, though appears to be
better layout for wiring when closing
housing)
7/3/2019
7/3/2019
1.90
MIRU
MOVE
RURD
P
MU MP line & returns line, dress tag
0.0
0.0
16:06
18:00
end of 2" for grapple, string stabbing
cable
7/3/2019
7/3/2019
3.00
MIRU
MOVE
RURD
P
Completed install of inner reel iron and
0.0
0.0
18:00
21:00
MP line.
7/3/2019
7/4/2019
3.00
MIRU
MOVE
RURD
P
PJSM, pull test grapple - good, pull 2-
0.0
0.0
21:00
00:00
5/" and stab through injector. Note 2-
5/8" much more rigid, residual bend
casues coil to rub on upper reel frame
crossmember and lower hing portio /
hydralic lines at the bottom of the
manta ray door. Rig down stabbing
equipment and clean work area. Ohm
wire, good test but failed to meg.
Trouble shot wire to best ability W/O
electrician.
7/4/2019
7/4/2019
5.00
MIRU
MOVE
RGRP
P
Rebuild stuffing box and rehead ODS
0.0
0.0
00:00
05:00
PDL. Reassemble and hang PDL with
heat tape and insulation blankets.
7/4/2019
7/4/2019
2.80
MIRU
MOVE
RURD
P
Complete PDL assembly & insulation,
0.0
0.0
05:00
07:48
Peak trucks arrive at 6:30AM, unhook
shop & disconnect PUTZ, skid shop
onto truck, complete prep for move
7/4/2019
7/4/2019
1.20
MIRU
MOVE
RURD
P
PJSM, jeep up, hook up to sows
0.0
0.0
0748
0900
7/4/2019
7/4/2019
3.00
MIRU
MOVE
MOB
P
Move from 1C -Pad to 1R -Pad
0.0
0.0
0900
1200
7/4/2019
7/4/2079
3.50
MIRU
MOVE
MOB
P
Sub & pits spotted & mats laid
0.0
0.0
12:00
15:30
Page 2113 Report Printed: 7/16/2019
i
' Operations Summary (with Timelog Depths)
1R-101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activay Code
Time P-1`4
Operation
(11Ka)
End Dept (flKB)
7/4/2019
7/4/2019
2.50
MIRU
MOVE
RURD
P
Begin RU checklist, MU scaffolding in
0.0
0.0
15:30
18:00
cellar, grease master, swab, & tangos
7/4/2019
7/4/2019
3.00
MIRU
WHDBOP
NUND
P
Set stack and continue to work RU
0.0
0.0
18:00
21:00
check list, Tighten flange bolts from
top of stack to master. DTH install
tiger tank hard line, test with air- good.
"' Rig accept @ 18:00
7/4/2019
7/4/2019
1.10
MIRU
WHDBOP
RURD
P
Gather RKB's, Valve check list,
0.0
0.0
21:00
22:06
energize Coomy. Bring on Sea water
and milling fluid.
714/2019
7/4/2019
1.20
MAU
WHDBOP
RURD
P
Hand cul 6' of pipe, 62-5/8", 1' of old
0.0
0.0
22:06
23:18
2" stub. Test E-line 126.5 ohms and
greater than 2000 good.Boot E-line
7/4/2019
7/5/2019
0.70
MIRU
WHDBOP
CIRC
P
Fluid pack coil - 54 bbls @ 1 bpm.
0.0
0.0
23:18
00:00
7/5/2019
715/2019
0.70
MIRU
WHDBOP
CIRC
P
Continue to fluid pack coil - 54 bbls @
0.0
0.0
00:00
00:42
1 bpm.
7/5/2019
7/5/2019
0.20
MIRU
WHDBOP
CIRC
P
Pump slack back on the reel, 3 cycles
0.0
0.0
00:42
00:54
to 4.7 bpm.
7/5/2019
7/5/2019
0.40
MIRU
WHDBOP
BOPE
P
Test inner reel valve / stripper 2501
0.0
0.0
00:54
01:18
2500 psi - good
7/5/2019
7/5/2019
1.70
MIRU
WHDBOP
CTOP
P
Un Stab injector, prep cutter, pipe to
0.0
0.0
01:18
03:00
stiff to guide safely into cutter, run pipe
into mouse hole through the cutter,
lower cart to reattach cutter. Cut pipe,
find wire at 10' cut 25' total, test wire -
good,
_35k
7/5/2019
7/5/2019
3.00
MIRU
WHDBOP
CTOP
P
Ream pipe, MU CTC,Pull test to
0.0
0.0
03:00
06:00
1
bs
7/5/2019
7/5/2019
1.20
MIRU
WHDBOP
CTOP
P
Head up a-line, Test UOC, 129 Ohms /
0.0
0.0
06:00
07:12
> 2K MOhms, clear floor, prep for
BOP test
715/2019
7/5/2019
0.90
MIRU
WHDBOP
CTOP
P
Grease Romeos, Bravo's, & SR valves
0.0
0.0
07:12
08:06
post N2 blow-down, PT coil-connector
(4200 psi)
7/5/2019
7/5/2019
2.40
MIRU
WHDBOP
CTOP
P
Test gas alarms, PU 4' riser on injector
0.0
0.0
08:06
10:30
(for 3" tools space-out), grease
manuals & HCR's, skid back cart, MU
night cap, inspect injector,
7/5/2019
715/2019
3.50
MIRU
WHDBOP
BOPE
P
Test BOP'S, 250 psi low, 2500 psi high
0.0
0.0
10:30
14:00
" Witness waived by Austin McLeod
of the AOGCC
7/5/2019
7/512019
3.50
MIRU
WHDBOP
BOPE
T
Observe hydraulic fluid on BOP's
0.0
0.0
14:00
17:30
when testing B6 & B8, bleed off to
trouble-shoot, bad part o-rings on
ODS 2-5/8" rams & VBR's, install new
o-rings
7/5/2019
7/5/2019
2.50
MIRU
WHDBOP
BOPE
P
Continue BOP test, Complete, No fail
0.0
0.0
17:30
20:00
passes.- 9.5 hrs total including 3.5 hrs
repairing leaking -rings in 2-5/8 and
VBR rams.
715/2019
7/5/2019
1.50
PROD1
WHPST
CTOP
P
PT TT line and ODS PDL to 1500 psi -
0.0
0.0
20:00
21:30
1
1
good, Flow check good.
715/2019
7/5/2019
1.50
PROW
WHPST
PULD
P
PU BHA#1, Window milling BHA, 0.6
0.0
105.0
21:30
23:00
1
I
° AKO, W 3.80 " mills under 1 joint R2
I
joint of PH-6, stab injector, tag up.
Page 3113 Report Printed: 7/1612019
Uperations Summary (with Timelog Depths)
1R-101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
StartTime
End Time
our Inn
phase
Op Code
Activity Code
Time P -T -X
Operabon
(VS)
End Depth(flxe)
7/5/2019
7/6/2019
1.00
PROD1
WHPST
TRIP
P
Open EDC, line up to tiger tank, park
105.0
1,616.0
23:00
00:00
inspect gooseneck alignment @ 130',
modify and continue in hole up to 70
ft/min. Pump to 4.25 bpm then reduce
rate to 1.75 bpm seawater while RIH.
Park @ 500' and inspect injector I
gooseneck alignment, reel. Adjusted
goose neck, continue in hole, traction
cylinders calmed down, RIH weight
smoothed out. Observe sharp CT
weight swings @ 1616'. Park and
inspect goose neck,
7/612019
7/6/2019
0.60
PROD1
WHPST
TRIP
P
Continue to RIH, SID @ 3689 with
1,616.0
3,689.0
00:00
00:36
2.86 WOB, top of WS.
7/6/2019
7/6/2019
0.20
PROD1
WHPST
TRIP
P
PU 40 k lbs, PUH to logging depth
3,689.0
3,430.0
00:36
00:48
7/6/2019
7/6/2019
0.30
PROD1
WHPST
DLOG
P
Swap to CCL mode, RIH logging @ 16
3,430.0
3,680.0
00:48
01:06
ft/min. Correct -2'to stubbing tally.
7162019
7/612019
1.10
PROD1
WHPST
CIRC
P
Park, adjust reel position to access
3,680.0
3,670.0
01:06
02:12
saddle clamps, lock out reel, inspect
reel, torque saddle clamp bolts and
hub bolts while displacing well to
seawater and then milling fluid. Close
EDC. PU Wt 42 k lbs
7/6/2019
7/612019
0.20
PRODt
WHPST
TRIP
P
RIH and dry tag WS @ 3687 W 1.8 k
3,670.0
3,685.9
02:12
02:24
WOB, PU Wt 42 k lbs REIN Set rate
at 2.85 bpm
7/6/2019
7/612019
3.60
PROD1
WHPST
WPST
P
CT 1954 psi @ 2.84 bpm in and 2.84
3,685.9
3,691.0
02:24
06:00
out, CT RIH Wt 20 k lbs, BHP 1785
psi, free spin diff 418 psi, WH 40 psi,
IA 0 psi, OA 617 psi
RIH, see motor work @ 3686.9', WOB
0.1 k lbs, Attempting to mill ahead
feeding tenths, cement acting very
hard. Theoretical
@ 3688', PU Wt 42 k lbs, PUH to
3677' RBIH, Start seeing WOB @
3687', milling ahead, metal in returns.
7/6/2019
7/6/2019
2.60
PROD1
WHPST
WPST
P
Milling, CWT = 12.21K, WOB = 3.3K,
3,691.0
3,992.4
06:00
08:36
2.81 bpm in, 2.78 bpm out, annular =
1790 psi (open choke), pump 2008
psi, avg ROP = 0.54 fph
7/6/2019
7/6/2019
2.40
PROD1
WHPST
WPST
P
Milling, CWT = 12k, WOB = 3.7K,
3,992.4
3,693.8
08:36
11:00
annular = 1790 psi, pump = 2091 psi,
good metal over shakers & dtich
magnet, avg ROP = 0.58 fph
7/612019
7/6/2019
2.10
PROD1
WHPST
WPST
P
Milling, CWT =12K WOB =3.6K,
3,693.8
3,694.5
11:00
13:06
annular = 1789 psi, pump= 2078 psi,
avg ROP = 0,33 fph (4 in/hr), likely
center of mill on 9-5/8"
7/6/2019
7/6/2019
1.60
PROD1
WHPST
WPST
P
Milling, CWT =14.3K, WOB =4K,
3,694.5
3,696.0
13:06
14:42
annular = 1786 psi, pump =1948 psi,
WOB falls off, call BOW @ 3696'
7/6/2019
7/6/2019
1.30
PROD1
WHPST
WPST
P
Continue at 1 fph to allow string
3,696.0
3,697.5
14:42
16:00
reamer to exit window
7/6/2019
7/6/2019
0.80
PROD1
WHPST
WPST
P
With string reaming out, begin pushing
3,697.5
3,718.0
16:00
1648
on it, milling rat -hole
7/6/2019
7/5/2019
3.20
PROD1
WHPST
REAM
P
Perform reaming passes, HS, 3"3,717.01
3,675.0
16:48
20:00
30L,180", saw some motor work and
did 180° a second time.
7/6/2019
7/6/2019
0.30
PROD1
WHPST
REAM
P
Dry drift 260 Ib bump on the WOB.
3,717.0
3,675.0
20:00
20:18
I
Back ream up one last time @ 180°
I
for good measure.
Page 4113 Report Printed: 711612019
operations Summary (with Timelog Depths)
1R-101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Siert Depth
start Time
Emil Time
Our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(WB)
End Depth (flKB)
7/6/2019
7/6/2019
0.30
PROD1
WHPST
TRIP
P
POOH W BH#1 window milling
3,675.0
183.0
20:18
20:36
assembly.
7/6/2019
7/6/2019
1.80
PROD1
WHPST
PULD
P
Park shallow, flow check - good,
183.0
0.0
20:36
22:24
Unstab, inspect pipe - good. LD BHA
#1 over dead well.
Mill 2.79 go, 2.78" no go
Reamer 2.79" no go
7/6/2019
7/6/2019
0.60
PROD1
DRILL
PULD
P
Jet the slack
183.0
0.0
22:24
23:00
7/6/2019
7/7/2019
1.00
PROD1
DRILL
PULD
P
PU BHA #2 Build drilling assembly
0.0
82.7
23:00
00:00
1over
a dead well.
7/7/2019
7/7/2019
0.40
PROD1
DRILL
PULD
P
Complet picking up BHA#2, check
82.7
82.7
00:00
00:24
pack offs, good, bump up and set
counters.
7/7/2019
717/2019
0.80
PRODt
DRILL
TRIP
P
RIH to 3660', drift run, PUH to logging
82.7
3,430.0
00:24
01:12
depth.
7/7/2019
717/2019
0.40
PROD1
DRILL
DLOG
P
Log CCL from 3430 to 3660' for tie in.
3,430.0
3,660.0
01:12
01:36
-4' correction.
7/7/2019
7/7/2019
0.20
PROD1
DRILL
TRIP
P
RIP and dry tag bolom @ 3718' PU
3,660.0
3,718.0
01:36
01:48
Wt 36 k Itis
7/7/2019
717/2019
3.10
PROD1
DRILL
DRLG
P
CT 2,082 psi @ 2.85 bpm in and 2.83
3,718.0
4,125.0
01:48
04:54
bpm out, BHP 1,825 psi targeting 8.65
ppg at the window. (10.4 ppg because
of Power Pro and rales - open choke).
CT Wt 16.8 k lbs, WOB - 500 lbs ROP
-200 f/ hr
3755' Stall x2, PU - 40k lbs
hard spot 3969'-3,983'
4039' Stall PU Wt 40 k Itis X2
Average ROP over interval 131 fUhr
717/2019
7/712019
1.50
PROD1
DRILL
WPRT
P
TD of build called @ 4125', PU Wt 38
4,125.0
82.0
04:54
06:24
k lbs, POOH, crew change, PJSM
7/7/2019
7/7/2019
1.00
PRODt
DRILL
PULD
P
PUD BHA#2 (holding 10.6 ppg at
82.0
0.0
06:24
07:24
window), inspect injector, bit came out
a 1-2
7/7/2019
7/7/2019
1.50
PROD1
DRILL
PULD
P
Lock -out reel & inspect, PD BHA #3
0.0
87.0
07:24
08:54
Lateral Assembly (NOV Agitator, 0.6°
AKO motor, New Hughes Dynamus
bit), check pack -offs, MU to coil, tag
up, set counters
717/2019
717/2019
0.90
PRODi
DRILL
TRIP
P
RIH w/ BHA#3, Peter O'Brian
87.0
3,640.0
08:54
09:48
adjusted injector/reel settings, close
EDC, shallow test tools, nothing on
transducer screen, though can see
horse -head & pipe shaking, carry on
717/2019
7/7/2019
0.50
PROD1
DRILL
DLOG
P
Log reservoir, drop pumps when
3,640.0
3,708.0
09:48
10:18
approaching window, -5' correction,
PUH to log CCL,
7/7/2019
7/7/2019
1.40
PROD1
DRILL
DLOG
P
Log CCL for confirmation
3,708.0
3,622.0
10:18
11:42
7/7/2019
7/7/2019
0.40
PRODt
DRILL
TRIP
P
LOG RA at 3687% Corrected TOWS=
3,622.0
4,125.0
11:42
12:06
3678', RA = 3687', BOW = 3688'
7/7/2019
7/7/2019
1.20
PRODt
DRILL
DRLG
P
Drilling, FS = 1130 psi @ 2.85 bpm,
4,125.0
4,260.0
12:06
13:18
CWT = 15K, WOB = OAK, annular =
1900 psi, pump = 2800 psi, dp = 1214
psi, 10.5 ppg at window (choke wide
open), stall at 4188', PUW = 30K, stall
again at 4288 psi, PUW = 33K, avg
ROP = 113 fph
Begin swapping to new mud system
(8.65 ppg @ 6% KCI), 100 psi WHIP
increase when taking to tiger tank,
new mud at bit 4192'
Page 5113
ReportPrinted: 7/1 612 01 9
- Uperations Summary (with Timelog Depths)
-
IR -101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
StartTime
End Time
Our (hr)
Phase
Op Code
Activity Corse
Time PJA
Operation
(WS)
End Depth (fixe)
7/7/2019
7/7/2019
1.50
PROD1
DRILL
DRLG
P
Drilling, CWT = 13.3K, WOB = 1.21K,
4,260.0
4,525.0
13:18
14:48
annular = 1893 psi (10.5 ppg @
window), MW in = 8.65 ppg, clays in
samples & large clay balls over
shaker, stall at 4502', PUW = 43K
WHIP = 40 psi, bypass MM, WHIP still
40 psi, swap to choke B, WHIP
remains 40 psi, bypass chokes &
WHP drops to 20 psi
7/7/2019
717/2019
0.30
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW = 35K
4,525.0
3,725.0
14:48
15:06
0.6 bbls of cutting retumed on the trip
7/7/2019
7/7/2019
0.30
PROD1
DRILL
WPRT
P
Wiper in-hole, RIW = 16K
3,725.0
4,525.0
15:06
15:24
7/7/2019
7/7/2019
1.30
PRODi
DRILL
DRLG
P
Drilling, FS = 1276 psi @2.85 bpm,
4,525.0
4,673.0
1524
16:42
CWT = 12.5K, annular =1902 psi,
pump = 2859 psi, 10.4 ppg at window,
difficult building, attempt more WOB to
build inclination, drop rate to 2.5 bpm,
stacked weight at 4670', PUW = 61 K,
difficult getting drilling stacking weight
7/7/2019
7/712019
1.80
PROD?
DRILL
DRLG
P
Working to drill, stacking weight, pump
4,673.0
4,689.0
16:42
18:30
sweeps, PUH allowing sweep to exit
bit.
Crew change pick u to check
parameters. CT 2,350 psi @ 2.5 bpm
in / out, Free spin 921 psi, BHP 1954
psi targeting 10.6 ppg at the window.
WH 96 psi, IA 420 psi, OA 809 psi.
7/712019
7/7/2019
1.40
PROD1
DRILL
DRLG
P
Break out drill ahead -200+ft/hr
4,689.0
5,005.0
18:30
19:54
1
1
1 Average ROP over interval 225.7 ft/hr
71712019
7/7/2019
0.30
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW = 30 k
5,005.0
4,200.0
19:54
20:12
0.8 bbls of cutting returned on the trip
7/7/2019
717/2019
0.40
PROD?
DRILL
WPRT
P
Wiper in-hole, RIW = 16 k
4,200.0
5,005.0
20:12
20:36
7/7/2019
7/8/2019
3.40
PROM
DRILL
DRLG
P
Stall twice at 5009 on restart. CT2357
5,005.0.
5,323.0
20:36
00:00
psi at 2.5 bpm, free spin diff 969 psi,
BHP 1960 targeting 10.6 ppg, WH 113
psi, - 50 % choke, CT Wt 15 k Ibs,
WOB 750 Ibs.
Average ROP over interval 93.5 ft/hr
7/8/2019
7/812019
1.20
PROM
DRILL
DRLG
P
Stall twice at 5009 on restart. CT2357
5,323.0
5,424.0
00:00
01:12
psi at 2.5 bpm, free spin diff 969 psi,
BHP 1960 targelting 10.6 ppg, WH
113 psi, - 50 % choke, CT Wt 15 k
lbs, WOB 750 lbs. Blead OA from 804
psi
Average ROP over interval 93.5 ft/hr
718/2019
7/8/2019
0.80
PROD1
DRILL
WPRT
P
PU Wt 40 k lbs - 3 rd wiper to window
5,424,0
3,712.5-
01:12
02:00
for fie in.
Hole clean,
1.7 bbls of cutting returned on the trip
7/8/2019
7/8/2019
0.10
PROD1
DRILL
DLOG
P
Log RA tag for -1.5' correction
3,712.0
3,728.0
02:00
02:06
718/2019
718/2019
0.60
PROD1
DRILL
WPRT
P
RBIH
3,728.0
5,424.0
02:06
02:42
7/8/2019
7/8/2019
2.30
PRODi
DRILL
DRLG
P
CT 2882 psi @ 2.9 bpm, free spin
5,424.0
5,615.0
02:42
0500
-
1260 psi, BHP 1984 psi, trgeting 10.6
ppg EMW @ the window, 11 ppg @
the bit. CT Wt 8 k lbs WOB 2-3 k lbs.
Average ROP over interval 83 ft/hr
7/8/2019
7/8/2019
1.70
PROM
DRILL
DRLG
P
Drilling, CWT=6.5K, WOB =2K,
5,615.0
5,870.0
05:00
06:42
annular = 2009 psi, pump 2600 psi,
10.6 ppg at the window
Page 6113 Report Printed: 711612019
-i Uperations Summary (with Timelog Depths)
1R-101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
start Time
End Tons
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(RKB)
End Depth(MB)
7/8/2019
7/8/2019
0.40
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW = 46K
5,870.0
4,985.0
06:42
07:06
7/8/2019
7/812019
0.40
PROM
DRILL
WPRT
P
Wiper in-hole, RIW = 14K
4,985.0
5,870.0
07:06
07:30
7/8/2019
7/8/2019
2.30
PRODi
DRILL
DRLG
P
Drilling, CWT = 17K, WOB = 0.6K,
5,870.0
6,117.0
07:30
09:48
annular = 2019 psi, pump = 2588 psi,
-100% returns, 10.65 ppg at window
7/8/2019
7/8/2019
1.10
PROD1
DRILL
DRLG
P
Drilling, CWT = 7.8K, WOB= 1.2K,
6,117.0
6,270.0
09:48
10:54
annular = 2029 psi, pump = 2548 psi,
pump sweeps
7/8/2019
7/8/2019
0.40
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW =55K
6,270.0
5,447.0
10:54
11:18
7/8/2019
7/8/2019
0.30
PROD1
DRILL
WPRT
P
Wier in-hole RIW = 11.5K
5,447.0
6,270.0
11:18
11:36
7/8/2019
7/8/2019
2.10
PROD1
DRILL
DRLG
P
Drilling, CWT = 10.25', WOB = 0.3K,
6,270.0
6,670.0
11:36
13:42
annular = 2030 psi, pump = 2600 psi,
10.6 ppg at window, began pumping
new mud system, new mud at the bit
at 6564', pump sweeps
Note: -85 psi WHIP when taking
returns to TT for mud swap, EDC at bit
= 11.9 ppg (1 -for -1 returns, with no
losses to formation)
718/2019
7/812019
1.30
PROD1
DRILL
WPRT
P
Wiper to window, PUW = 52K, pumps
6,670.0
3,643.0
13:42
15:00
sweeps timed or EOB, circulate BU
7/8/2019
7/8/2019
0.70
PROD1
DRILL
CTOP
P
Allow Peter O'Brian time to upate HMI
3,643.0
3,643.0
15:00
15:42
software & make reel/injector
adjustments
7/8/2019
7/8/2019
1.20
PROD?
DRILL
WPRT
P
RBIH, log RA for-4'correction
3,643.0
6,670.0
15:42
16:54
7/8/2019
718/2019
2.10
PROD1
DRILL
DRLG
P
Drilling, FS = 1298 psi @ 2.88 bpm,
6,670.0
7,070.0
16:54
19:00
CWT = 11 K, WOB = 0.1 K, annular =
2023 psi, pump = 2923 psi, 10.6 ppg
at wiindow, 11.1 ppg at bit, pump
sweeps
7/8/2019
702019
0.40
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW =40K
7,070.0
5,870.0
19:00
19:24
7/8/2019
7/8/2019
0.50
PROD1
DRILL
WPRT
P
Wiper in-hole, RIH = 11.5K
5,870.0
7,070.0
19:24
19:54
7/8/2019
7/8/2019
0.70
PROD1
DRILL
DRLG
P
Drilling, CWT= 8.5K WOB = 0.3K,
7,070.0
7,185.0
19:54
20:36
annular = 2023 psi, pump = 3211,
lower ROP (possible concretion),
break through & ROP increases
7/812019
7/8/2019
1.90
PROM
DRILL
DRLG
P
PUW = 44K, reduce rate in attempt to
7,185.0
7,472.0
20:36
22:30
build, able to build, increase rate back
to 2.85 bpm
Drilling, FS = 1000 psi @ 2.5 bpm,
CWT = 9K, WOB = 0.4K, annular =
2019 psi, 11.1 ppg at the bit, 10.6 ppg
at window
7/8/2019
7/8/2019
0.60
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW = 42K
7,472.0
5,964.0
22:30
23:06
1 bbl cuttings retuned on the wiper.
7/8/2019
7/8/2019
0.60
PROD1
DRILL
WPRT
P
Wiper in-hole, RIW = 11k
5,964.0
7,472.0
23:06
23:42
7/8/2019
7/9/2019
0.30
PROD1
DRILL
DRLG
P
CT 2585 psi @ 2.5 bpm, free spin diff
7,472.0
7,484.0
23:42
00:00
1095 psi, BHP 2040 targeting 10.6
ppg EMW at the window, 11.5 ppg @
the bit. WH 102 psi, IA240 psi, OA
567 psi. OBD, CT Wt k bs, WOB 3.7
k lbs.
Average ROP over interval 40 ft/hr
Page 7/13 Report Printed: 711612019
Operations Summary (with Timelog Depths)
1 R-101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Stan Time
End Tana
our (hr)
Phase
Op code
AdvAy Code
Tune P -T -X
Operatlon
(ftKB)
End Depth (lKB)
7/9/2019
7/9/2019
3.10
PROD1
DRILL
DRLG
P
Drilling,
7,484.0
7,870.0
00:00
03:06
Stall 7484 42 K lbs PU Wt,
7593' PU 53 k Ibs - diff sticking
signature
7712' PU 62 k lbs
7781' PU 41 k lbs
Average ROP over interval 124 ft/hr
7/9/2019
7/9/2019
1.90
FROM
DRILL
WPRT
P
PU Wt 48 k lbs, PUH on long wiper to
7,870.0
3,694.0
03:06
05:00
the window for tie in
Hole and window clean 1.9 bbls
returned on the trip out.
7/9/2019
7/9/2019
0.70
FROM
DRILL
CIRC
P
Jet the 7" and chase sweeps out of
3,694.0
3,710.0
05:00
05:42
hole, bottoms up
702019
7/9/2019
0.10
PRODi
DRILL
DLOG
P
Tie int othe RA tag for -5'
3,710.0
3,730.0
05:42
05:48
7/9/2019
7/9/2019
1.50
PRODi
DRILL
TRIP
P
RBIH, RIH Wt, 16 diminishing to 6 k
3,730.0
7,870.0
05:48
07:18
lbs
7/9/2019
7/9/2019
3.40
PRODi
DRILL
DDRL
P
CT 3,045 psi, (03 2.80 bpm, Free spin
7,870.0
8,280.0
07:18
10:42
1,293 psi, BHP 2,073 targeting 10.6
ppg EMW at the window. WH 80 psi,
IA 245, OA 571 psi. CT Wt 9 k lbs,
WOB 400 lbs WOB.
7936' temporarily stuck, worked pipe
to 80 k lbs, pulled free.
Average ROP over interval 120 ft/hr
7/9/2019
7/9/2019
0.30
FROM
DRILL
WPRT
P
PU Wt 49 k lbs, - wiper #1
8,280.0
7,449.0
10:42
11:00
7/9/2019
7/9/2019
0.40
PRODt
DRILL
WPRT
P
RBIH, CT Wt 6.6 k lbs diminishing to
7,449.0
8,280.0
11:00
1124
7/9/2019
7/9/2019
3.10
PROD1
DRILL
DDRL
P
CT 3,067 psi, @ 2.84 bpm, Free spin
8,280.0
8,533.0
11:24
1430
1,258 psi, BHP 2,073 targeting 10.6
ppg EMW at the window, 11.4 @ the
bit. WH 70 psi, IA 264, OA 575 psi.
CT Wt 4.4 k lbs, WOB 371 lbs WOB.
8,031'- Stuck, work pipe to 80k lbs,
pull free on forth try.
8416' drill into concretion, Stall x3
8420, pull 200' BHA wiper,
run out of push, pull wiper early
Average ROP over interval 82 R/hr
7/9/2019
7/9/2019
0.50
FROM
DRILL
WPRT
P
PU Wt 77 k lbs, -wiper#2
8,533.0
7,531.0
14:30
15:00
7/9/2019
7/9/2019
0.50
FROM
DRILL
WPRT
P
RBIH - 10 - 8 k lbs
7,531.0
8,533.0
15:00
15:30
7/9/2019
7/9/2019
1.40
PROM
DRILL
DDRL
P
CT 3,100 psi, @ 2.86 bpm, Free spin
8,533.0
8,786.0
15:30
16:54
1,193 psi, BHP 2,081 targeting 10.6
ppg EMW at the window, 11.4 @ the
bit. WH 66 psi, IA 278, OA 578 psi.
CT Wt 4 k lbs, WOB 400 lbs WOB.
Average ROP over interval 180 R/hr
7/9/2019
7/9/2019
2.20
PRODt
DRILL
WPRT
P
PU Wt 78 k lbs, -wiper, long wiper to
8,786.0
3,678.0
16:54
19:06
swab, pull through the window clean
7/9/2019
7/9/2019
1.00
PROD1
DRILL
WPRT
P
Continue wiper to the swab valve with
3,678.0
87.0
19:06
20:06
closed EDC. 24 k,
"' Note: notice slight increase in
densidy with bottoms up from the 7
inch
"' Note: 1.65 bbl cuttings returned per
WellWorc
7/9/2019
7I9I2019
0.75
PRODi
DRILL
TRIP
P
Tag up reset counters, RBIH w/closed
87.0
3,650.0
2006
20:51
EDC
Page 8113 ReportPrinted: 7/16/2019
Operations Summary (with Timelog Depths)
IR -101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
De
Step Time
Fid Tmre
( r)
Dur(ho
Phase
Op Cove
Aotivily Code
Time P -T -X
Operation
(rt
End Depth (VB)
7/9/2019
7/9/2019
0.20
PROD1
DRILL
DLOG
P
Log formation for depth control
3,650.0
3,715.0
20:51
21:03
correction of minus 6.0'
7/9/2019
7/9/2019
2.00
PROD1
DRILL
TRIP
P
Continue IH, observed RA marker with
3,715.0
8,786.0
21:03
23:03
no Correction
7/9/2019
7/9/2019
0.60
PRODt
DRILL
DRLG
P
BOBD, 2.8 bpm at 3,010 psi,
8,786.0
8,878.0
23:03
23:39
Diff --1,290, BHP=2,081, IA=323,
OA=579
"` Note: New Mud at the bit 8.788'
7/9/2019
7/10/2019
0.35
PROD1
DRILL
DRLG
P
PUH, PUW 45 k, Obtain New pump
8,878.0
8,910.0
23:39
00:00
parameters, 2.81 bpm at 2,809 psi,
Diff=1,168, BHP=2,077, IA=329,
01 Drilled ahead CR 8,785'-
8,898'
7/10/2019
7/10/2019
2.80
PRODt
DRILL
DRLG
P
OBD, 2.80 bpm at 2,856 psi, Diff
8,910.0
9,224.5
00:00
02:48
1,192 psi, WHP=135, BHP=2,074,
IA=342, OA=581
**Note: CR 9,101'-9,225'
" Note: Hard spot 8,926', and 8,949'
7/10/2019
7/10/2019
0.50
PROD1
DRILL
WPRT
P
Wiper up hole, PUW 44 it #1
9,224.5
8,000.0
02:48
03:18
0.7 bbls cutting returned on the trip
7/10/2019
7/10/2019
0.50
PROD1
DRILL
WPRT
P
Wiper back in hole, RIW 2 k
8,000.0
9,224.5
03:18
03:48
7/10/2019
7/10/2019
3.40
PROD1
DRILL
DRLG
P
BOBD, 2.84 bpm at 2,887 psi,
9,224.5
9,652.0
03:48
07:12
Diff -1,145 psi, WHP=104,
BHP=2,093, IA=298, OA=582
Average ROP - 125 ft/hr
CT Wt -10 k lbs at pick up
7/10/2019
7/10/2019
0.40
PROD1
DRILL
WPRT
P
Wiper up hole, PUW 46 k#2
9,652.0
8,633.0
07:12
07:36
1
1
1.3 bbis cutting returned on the trip
7/10/2019
7/10/2019
0.60
PROD1
DRILL
WPRT
P
Wiper back in hole, RIW -5 k
8,633.0
9,652.0
07:36
08:12
7/10/2019
7/10/2019
2.40
PROD1
DRILL
DRLG
P
CT 2500 psi @ 2.5 bpm (atempting to
9,652.0
10,054.0
08:12
10:36
turn up), Diff --911 psi, WHP=129,
BHP=2,100, CT Wt -10 k lbs, WOB
1.2 k lbs
Bump rate back to 2.8 bpm @ 9699'
Average ROP - 167 Whir
CT Wt -15k lbs at pick up
7/10/2019
7/102019
2.90
PROD1
DRILL
WPRT
P
Wiper up hole, PUW 42 k, long wiper
10,054.0
3,665.0
10:36
13:30
for tie in
3 bbls cutting returned on the trip
7/10/2019
7/102019
0.20
PROD1
DRILL
DLOG
P
Tie into the RA tag for -3.5' Correction
3,665.0
3,729.0
13:30
13:42
7/10/2019
7/10/2019
0.30
PROD1
DRILL
DLOG
P
Park at 3670.14 CTMD and 3332.46'
3,729.0
3,670.0
13:42
14:00
TVD with 1813 psi trapped. Bleed to
1669 psi, observe pressure fall to
1655 psi
7/10/2019
7/10/2019
2.30
PROD1
DRILL
TRIP
P
RBIH
3,670.0
10,054.0
14:00
16:18
7/10/2019
7/10/2019
1.20
PROD1
DRILL
DRLG
P
CT 2637 psi @ 2.5 bpm ( atempting to
10,054.0
10,230.0
16:18
17:30
turn up), Diff -937 psi, WHP=123,
BHP=2,100, CT Wt -10 k lbs, WOB
0.88 k lbs
Bump rate back to 2.8 bpm @ 10,068'
Average ROP - 146 Whir
"' Reduced pressure to 10.4 ppg at
the window, bi( ECD fell to 11.7
Page 9113 Report Printed: 7/16/2019
Operations Summary (with Timelog Depths)
1R-101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
sten Depth
Steri Time
End Time
Dur(hr)
Phase
op Code
Activity code
Time P -T -X
Operation
(ftKB)
End Depih(MB)
7/10/2019
7/10/2019
2.50
PRODi
DRILL
DRLG
P
Continue Drilling ahead, 2.5 bpm at
10,230.0
10,424.0
17:30
20:00
2,600 psi, Diff -900, WHP 63,
BHP=2.138, IA=110, OA=580
— Note: screen shots indicating that
Agitator isn't performing efficiently.
7/10/2019
7/10/2019
0.72
PRODt
DRILL
WPRT
P
Wiper up hole to 8,900', PUW 47 k
10,424.0
8,900.0
2000
20:43
7/10/2019
7/10/2019
1.30
PROD1
DRILL
WPRT
P
Wiper back in hole, work pipe towards
8,900.0
10,424.0
20:43
22:01
bottom, launch 20 bbl beaded pill
7/10/2019
7/11/2019
1.98
PROD1
DRILL
DRLG
P
BOBD 2.81 bpm at 2,672 psi,
10,424.0
10,643.0
22:01
00:00
Diff -1,150, WHP=63, BHP=2,086,
IA=347, 0A=590
••* Note: New mud at the bit 10,520'
7/11/2019
7/11/2019
1.00
PROD1
DRILL
DRLG
P
OBD, 2.8 bpm at 2,672 psi, Diff --940,
10,643.0
10,727.0
00:00
01:00
WHP=121, BHP=2,081, IA=280,
OA=593
Average ROP 84- ft/hr
7/11/2019
7/11/2019
0.80
PROM
DRILL
WPRT
P
Wiper up hole, PUW 48 k
10,727.0
9,200.0
01:00
01:48
Note: Increase of MWO 8.85 ppg
7/11/2019
7/11/2019
1.30
PROD1
DRILL
WPRT
P
Wiper back in hole, work pipe 10,510'
9,200.0
10,727.0
01:48
03:06
to bottom slowing running speed
7/11/2019
7/11/2019
1.50
PROM
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,672 psi, Diff --940,
10,727.0
10,880.0
03:06
04:36
WHP=121, BHP=2,081, IA=280,
OA=593, lower pump rate from 2.8
bpm to 2.5 bpm to build angle. obtain
new pump parameters 2.5 bpm at
2,521 psi, Diff --940, WHP=118,
BHP=2,080, IA=274, OA=583
Average ROP 102 - fl/hr
7/11/2019
7/11/2019
4.20
PROD1
DRILL
DRLG
P
Drilling, utalizing sweeps, pum 5x5 as
10,880.0
11,205.0
04:36
08:48
last one exits at surface.
Unable to build inc, can't increase
WOB, forced to wipe
Average ROP 77- Whr
7/11/2019
7/11/2019
4.20
PROD1
DRILL
DRLG
P
Drilling, utalizing sweeps, pum 5x5 as
10,880.0
11,205.0
08:48
13:00
last one exits at surface.
Unable to build inc, can't increase
WOB, forced to wipe
Average ROP 77- ft/hr
7/11/2019
7/11/2019
4.00
PRODi
DRILL
WPRT
P
Wiper up hole, PUW 48 k
11,205.0
3,652.0
13:00
17:00
Pulled a little over @ 10188' and
10160, RBIH, PU continue out of hole
- clean
Jet 7" pump bottoms up, shelter PLC
reboot and torque saddle clamps
pillow blocks on reel while circulating
bottoms up.
7/11/2019
7/11/2019
0.20
PROD1
DRILL
DLOG
P
Tie into RA tag for -5' correction
3,652.0
3,729.0
17:00
17:12
7/11/2019
7/11/2019
0.80
PROD1
DRILL
TRIP
P
CT 2744 psi @ 2.5 bpm, free spin 983
11,205.0
11,476.0
17:12
18:00
psi BHP 2135 psi targeting 10.4 ppg
EMW at the window.
CT snub limmil increased to -30 k,
WOB variable 0.4 to 2 k lbs. Having
trouble building inc. GEO request
more turn.
7/11/2019
7/11/2019
0.50
PROD1
DRILL
DRLG
P
OBD, 2.5 bpm at 2,521 psi, Diff --940,
11,476.0
11,512.0
18:00
18:30
WHP=161, BHP=2,048, IA=231,
OA=584
Page 10113 Report Printed: 7/16/2019
Operations Summary (with Timelog Depths)
IR -101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
De
Tim
Start Ti
End Time
Dur(hr)
Phase
Op Code
Activily Code
Time P -T -X
Operation
(n
End Depth (ftKB)
7/11/2019
7/11/2019
0.50
PROD1
DRILL
WPRT
P
Unable to build angle, pull short wiper,
11,512.0
10,722.0
18:30
19:00
line up and pump 50 bbl of new mud
from the reserve side,
7/11/2019
7/11/2019
0.50
PROD1
DRILL
WPRT
P
RBIH to bottom 1545 fpm w/neg 25-
10,722.0
11,512.0
19:00
19:30
30 k
7/11/2019
7/11/2019
1.50
PROM
DRILL
DRLG
P
BOBD. TF high side, 2.5 bpm at 2,681
11,512.0
11,573.0
19:30
21:00
psi, Diff --896, WHP=71, BHP=2,140,
IA=182, OA=594
7/11/2019
7111/2019
0.50
PROD1
DRILL
WPRT
P
Unable to keep weight on bit. and
11,573.0
10,835.0
21:00
21:30
continuing to drop angle, pull 1,500'
wiper up hole (800'), PUN 50 k
7/11/2019
7/11/2019
0.50
PROM
DRILL
WPRT
P
Wiper back IH, RIW -20-25 k
10,835.0
11,573.0
21:30
22:00
7/11/2019
7/12/2019
2.00
PROM
DRILL
DRLG
P
BOBO, 2.5 bpm at 2,681 psi, Diff --940,
11,573.0
11,674.0
22:00
00:00
WHP=74, BHP=2,175, IA=43,
OA=588, pushing minus 30 k, Avg
ROP 25-54 fph, w/0.5-0.9 k DHWOB
7/12/2019
7/12/2019
3.00
PROD1
DRILL
DRLG
P
OBD, 2.43 bpm at 2,733 psi, Diff --896,
11,674.0
11,790.0
00:00
03:00
WHP=64, BHP=2,185, IA=38,
OA=586, CTSW minus 22 k, with low
DHWOB 0.15-0.5 k
7/12/2019
7/12/2019
3.00
PROD?
DRILL
DRLG
P
OBD, 2.43 bpm at 2,845 psi,
11,790.0
11,871.0
03:00
06:00
Diff -924, WHP=61, BHP=2,225,
IA=27, OA=586, negaitive 30 k CTSW,
0.3 k DHWOB
7/12/2019
7/12/2019
3.80
PROD?
DRILL
WPRT
P
PU Wt 43 k lbs PUH on long wiper
11,871.0
3,660.0
06:00
09:48
Window and hole clean. - 3.8 bbls of
cuffing returned on the trip
7/12/2019
7/12/2019
0.30
PRODt
DRILL
CIRC
P
Jog 7" and pump a bottoms up
3,660.0
3,710.0
09:48
10:06
7/12/2019
7/12/2019
0.20
PROD1
DRILL
DLOG
P
Tie into RA for a -3.5' foot correction.
3,710.0
3,732.0
10:06
10:18
7/12/2019
7/12/2019
0.30
PROM
DRILL
DLOG
P
Park at 3658/3326 CTMD / TVD
3,732.0
3,658.0
10:18
10:36
respectively, trap 1741 psi, obsery
pressure bleed off to formation
Bleed off to1634 psi, pressure
returned to 1,650 then started
bleeding off to 1,648 psi.
7/12/2019
7/12/2019
3.20
PROD1
DRILL
TRIP
P
RBIH
3,658.0
11,872.6
10:36
13:48
2 ppb beads exit the nozzle @ 9,200'
cut rate to 0.54 bpm and RIH on
beads.
S/D twice @ 10,150' and again @
10,153' PU Wt 65 and 63 k lbs. -
Oriented 270, As drilled - 60 , rotated
TF and continued in hole.
Surface weight bouncing from slightly
positive to slightly negative +/- 1-2 k
@ TD
7/12/2019
7/12/2019
2.80
PROD1
DRILL
TRIP
P
PU Wt 42 k lbs, POOH pumping new
11,872.6
3,649.0
13:48
16:36
mud exporting returns outside to the
tiger tank.
Bring it inside after new mud all the
way around.
7/12/2019
7/12/2019
0.70
PROD1
DRILL
TRIP
P
PUH to surface on swab wiper, 2.73
3,649.0
88.0
16:36
17:18
bpm, AV's 225 ft/min at 110 ft/min
pulling speed
7/12/2019
7/12/2019
0.70
PROD1
DRILL
TRIP
P
Tag up and set counters, RBIH
88.0
3,673.0
17:18
18:00
PU Wt 30 k lbs above window
Continue in hole
7/12/2019
7/12/2019
0.23
11ROD1
DRILL
DLOG
P
Log formation for depth control minus
3,673.0
3,717.0
18:00
18:1 1
1
I
6.0', continue IH, PUW 30 k
Page 11113 ReportPrinted: 7/1612019
Operations Summary (with Timelog Depths)
1R-101
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depm
Start Time
End Time
our (hr)
Phew
Op Code
Activity Code
Time PJA
Opereeon
(MS)
Ertl Depen (ftK6)
7/12/2019
7/12/2019
3.25
PROD1
DRILL
TRIP
P
Observe RA marker with no
3,717.0
11,871.0
18:13
21:28
correction, continue IH, 10,200'slow
tripping speed down to 30 fpm, slow
down to 15 fpm from 11,200', confirm
TD 11,871',
7/12/2019
7/12/2019
0.75
PROD1
DRILL
TRIP
P
PUH, PUW 40 k, repostion vac trucks,
11,871.0
11,871.0
21:28
22:13
send Beaded LRP down coil
7/12/2019
7/13/2019
1.78
PROD1
DRILL
DISP
P
POOH while laying in beaded 9.8 ppg
11,871.0
6,821.0
22:13
00:00
completion pill, PUW 41 k, paint EOP
flag @ 9,830' (Yellow), 1,500 EOP
(White)
7/13/2019
7/13/2019
1.40
PROD1
DRILL
TRIP
P
Continue POOH while displacing well
6,821.0
2,400.0
00:00
01:24
to beaded completion fluid (9.8 ppg),
up to 2,400'
7/13/2019
7/13/2019
0.55
PROM
DRILL
TRIP
P
Continue POOH
2,400.0
87.0
01:24
01:57
7/13/2019
7/13/2019
0.50
PROM
DRILL
OWFF
P
At surface, check well for flow, PJSM
87.0
87.0
01:57
02:27
7/13/2019
7/13/2019
1.00
PRODI
DRILL
PULD
P
LD Drilling BHA on a dead well
87.0
0.0
02:27
03:27
••• Note: Inspect Coiled Tubing
observe (non -issue) long sratch 10'
above CTC 36" in length
7/13/2019
7/13/2019
1.00
COMPZI
CASING
BOPE
P
Function test BOPE - good
03:27
04:27
7/132019
7/13/2019
0.70
COMPZI
CASING
PUTB
P
Prep floor to run liner
0.0
0.0
04:27
05:09
7/13/2019
7/1312019
6.60
COMPZI
CASING
PUTB
P
Pick up lower completion, Run #1,
0.0
1,989.0
05:09
11:45
1989.58' under
7/132019
7/1312019
1.00
COMPZI
CASING
PUTB
P
PU BHA
1,989.0
2,038.0
11:45
12:45
7/132019
7/1312019
3.40
COMPZI
CASING
RUNL
P
RIH, tie in to window flag for +3 foot
2,038.0
11,872.0
12:45
16:09
correction, PU Wt 25k lbs. Continue
to RIH at 50 fUmin, reduce RIH speed
to 45-40 ft/min @ 10220.
Note TOL 9880' Baker counter off by
80' at TD, hard bottom, TO flag 5' past
horses head and Nabors top counter
on for the entire run in hole -
7/13/2019
7/13/2019
2.15
COMPZ1
CASING
PULD
P
PU Wt 29 k PUH - reset counters,
11,872.0
44.3
1609
18:18
purring over the lop
Paint yellow TO flag 6877.9'
7/13/2019
7/13/2019
0.20
COMPZI
CASING
Log the RA marker correction minus
44.3
18:18
18:30
9.5'
7/13/2019
7113/2019
0.75
COMPZI
CASING
Continue POOH, pumping across the
18:30
19:15
top
7/13/2019
7/13/2019
0.75
COMPZI
CASING
OWFF
P
At surface, check well for flow, PJSM
44.3
44.3
19:15
20:00
7/13/2019
7/13/2019
0.40
COMPZI
CASING
PULD
P
LD setting tools
44.3
0.0
20:00
20:24
7/1312019
7/13/2019
0.30
COMPZI
CASING
PUTB
P
Prep RF for liner OPS
0.0
0.0
20:24
20:42
7/13/2019
7113/2019
2.40
COMPZI
CASING
PUTB
P
PU/MU Liner Segment #2 w/101 jts of
0.0
1,036.5
20:42
23:06
slotted 2-718" slotted liner Wedge 533,
oper. torque 2,300 lbs, Jt #1-35
7/13/2019
7/14/2019
0.90
COM
CASING
PUTB
P
Continue PU Liner As #35-56
1,038.5
1,644.8
23:06
00:00
7/1412019
7/14/2019
3.00
COMPZI
CASING
PUTB
P
Continue PU Liner segment #2 joints
1,644.8
2,995.2
00:00
03:00
56-101
Page 12113 Report Printed: 711612019
Summary (with Timelog Depths)
1R-101
lipOperations
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Stan Time
End Time
our (hr)
Phase
Op Code
Activity Cade
Time P -T -X
Operation
(m(9)
End Depth (W13)
7/14/2019
7/14/2019
0.50
COMPZ1
CASING
PUTS
P
RD liner running equipment,
2,995.2
2,995.2
03:00
03:30
7/14/2019
7/14/2019
0.75
COMPZI
CASING
PULD
P
PUHMU CoilTrak tools, surface lest
2,995.2
3,045.6
03:30
04:15
(good), inspect pac-off, and INJH
counter (good)
7/14/2019
7/14/2019
2.60
COMPZ1
CASING
RUNL
P
Tag up reset counters, RIH
3,045.6
9,883.0
04:15
06:51
9686, PU Wt 38 k lbs
RIH and tag TOL @ 9883, run into it at
40 ft/minute, SID 12 k WOB stack -8 k
CT wt.
PU to 45 k lbs / -6 k WOB, Latched
up, SID 12 k WOB and stack -8 k CT
wt.
Pump on @ 1.5 bpm, diff to 887 psi,
PU Wt 26 k lbs, - released off liner
7/14/2019
7/14/2019
1.60
COMPZ1
CASING
TRIP
P
PUH, parked and reset counters,
9,883.0
76.0
06:51
08:27
POOH 60 ft/min purring over the top
7/14/2019
7/14/2019
1.00
COMPZ1
CASING
PULD
P
Flow check LD BHA
76.0
0.0
08:27
09:27
7/14/2019
7/14/2019
0.50
COMPZ1
CASING
PUTS
P
Prep floor to MU Liner, PJSM
0.0
0.0
09:27
09:57
7/14/2019
7/14/2019
6.00
COMPZ1
CASING
PUTS
P
PU upper completion, 95 joints of 2-
0.0
3,275.0
09:57
15:57
7/8"", 6.6#, L-80, 511 wedge, Slotted
liner crossed over to 15 joints of 3-
1/2", 9.2 #, L-80, wedge 511 Solid
Liner, under a BOT seal bore
deployment sleeve LOA 3275.26'
7/14/2019
7/14/2019
0.50
COMPZ1
CASING
PULD
P
PU BHA
3,275.0
3,324.0
15:57
16:27
7/14/2019
7/14/2019
1.50
COMPZ1
CASING
RUNL
P
Bump up, set counters, RIH
3,324.0
6,882.0
16:27
17:57
6688', PU Wt 45 k lbs, -12 WOB,
SID @ 6882', Stack 12 k WOB, -3 k
CT Wt, PU 50 k lbs, -23 k WOB
RBIH SID 12 k WOB, -3 k CT Wt,
Pump @ 1.87 bpm, 836 psi diff,
PU Wt 39 k lbs, WOB 1 k lbs - release
on depth.
7/14/2019
7/14/2019
0.50
COMPZ1
CASING
RUNL
P
PUH, reset counter
6,882.0
3,607.2
17:57
18:27
7/14/2019
7/14/2019
1.00
DEMOB
WHDBOP
DISP
P
Displace well to SW, POOH, LRS on
3,607.2
2,500.0
18:27
19:27
location spot in and RU Unit
7/14/2019
7/14/2019
0.30
DEMOB
WHDBOP
FRZP
P
Pump 40 bbl into coil, RD LRS and
2,500.0
2,500.0
19:27
19:45
sign ticket
7/14/2019
7/14/2019
0.50
DEMOB
WHDBOP
TRIP
P
POOH to surface
2,500.0
0.0
1945
20:15
7/14/2019
7/14/2019
1.50
DEMOB
WHDBOP
PULD
P
PUD, setting tools
0.0
0.0
20:15
21:45
•" Note: FTP=250 psi
7/14/2019
7/14/2019
1.50
DEMOB
WHDBOP
CTOP
P
MU Nozzle and jet stack and surface
0.0
0.0
21:45
23:15
lines
7/14/2019
7/15/2019
0.75
DEMOB
WHDBOP
CTOP
P
Unstab INJH, brake off nozzle, SO
0.0
0.0
23:15
00:00
BHI Upper Quick and cut a -line
7/15/2019
7/15/2019
1.00
DEMOB
WHDBOP
CTOP
P
Prep and bore -o -scope stack (found
0.0
0.0
00:00
01:00
chunk missing on variables)
7/15/2019
7/15/2019
2.00
DEMOB
WHDBOP
CTOP
P
Swap deployment rams, AnTech
0.0
0.0
01:00
03:00
mobize hands for re -head.
7/15/2019
7/15/2019
2.00
DEMOB
WHDBOP
CTOP
P
Swap out varibables, AnTech re -head
0.0
0.0
03:00
05:00
a -line
7/15/2019
7/15/2019
3.00
DEMOB
WHDBOP
CTOP
P
Work RD Checklist Pull stack @
0.0
0.0
05:00
08:00
1
I
1
0900.
I
***Rig release 0800
Page 13113 Report Printed: 7/16/2019
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BA ER 0 PRINT DISTRIBUTION LIST
F�UGHES
a GE company
COMPANY ConocoPhillips Alaska, Inc.
WELL NAME 1R-101
FIELD Greater KunarukArea
COUNTY North Slope Borough
BHI DISTRICT Alaska
AUTHORIZED BY Patrick Rider
EMAIL Patrick. Rider an. bakerhughes .com
219003
31106
;e sign and return one copy of this transmittal form to:
DcoPhillips Alaska, Inc.
Osterkamp (WNS Petroleum Technician)
G Street.
braze. Alaska 99510
LOG TYPE GR - RES
LOG DATE July 13, 2019
TODAYS DATE August 13, 2019
Revision
STATUS Final Replacement: No Details:
Rev. Requested by: ---
COMPANY
ADDRESS (FEDEX WILL NOT DELIVER TO P.O. B04
PERSON ATTENTION
4
FIELD I
FINAL
CD/DVD
FINAL
PRELIM
(las, dlis, PDF, META,
SURVEY
REPORT
LOGS
LOGS
CGM, Final Surveys)
(Compass)
# OF PRINTSOF
PKIN
# OF COPIES
I# OF COPIES
1# OF COPIES
I BP North Slope. 0 0 0
EOA, PBOC, PRB-20 (Office 109)
D&GWO Wells Admin Bread. Classmaker & Peggy O'Neill
900 E. Benson Blvd.
Anchorage, Alaska 99508
2 ConocoPhillips Alaska Inc. 0 0 0
Attn: Ricky Elgarico
ATO 708 A
700 G Street • \ A
Anchorage, AK 99510 AuCF�VEb
3 ExxonMobil, Alaska 0 0
Attn: Lynda M. Yaskell and/or Leonardo Elias CC
3201 C Street, Suite 505
Anchorage, AK 99503
e of Alaska - AOGCC
is Natural Resources Technician 11
W. 7th Ave, Suite 100
horage, Alaska 99501
t - Division of Oil & Gas ...
c Resource Evaluation
West 7th Avenue, Suite 1100
horage, Alaska 99501
Exploration (Alaska) Inc.
mtechnical Data Center, LR2-1
E. Benson Blvd.
�horage, Alaska 99508
TOTALS FOR THIS PAGE:
0
4 4
0 0
0
BA IGHES
BAT
U company
Date:
Abby Bell
AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska 99501
August 12, 2019
219093
3 109 3
Letter of Transmittal
Harvey Finch
Baker Hughes, a GE Company
795 East 941h Avenue
Anchorage, Alaska 99515
;Please find enclosed the directional survey data for the following well(s):
11-10L1PB2
1C -19L1
1R-101
RECEIVED
AUG 13 2019
AOGCC
(3) Total print
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Note: Please feel free to send us an email in place of return mail.
I
Harvey Finch, Baker Hughes, Wellplanner
Harvey.Finch@BakerHushes.com
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THE STATE
OfALASKA
GOVERNOR MIKE DUNLEAVY
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
�. aogcc.a laska.gov
Re: Kuparuk River Field, West Sak Oil Pool, KRU 1R-101
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-093
Surface Location: 154' FNL, 139' FWL, SEC. 20, T12N, R10E, UM
Bottomhole Location: 2259' FSL, 940' FWL, SEC. 29, T12N, R10E, UM
Dear Mr. Ohlinger:
Enclosed is the approved application for the permit to redrill the above referenced development
well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs
run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment
of this well.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Daniel T. Seamount, Jr.
Commissioner
,rJ
DATED this day of July, 2019.
STATE OF ALASKA
AL .(A OIL AND GAS CONSERVATION COMM. _ION
PERMIT TO DRILL
20 AAC 25.005
fS L'm:,dr rm yui 4i'sa„.tz
JUN 19 ZQ;9
1a. Type of Work:
11b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑
1 c. Spegify,K weft Is proposed for:
Drill ❑ Lateral ❑
Stratigraphic Test ❑ Development - Oil ❑� , Service - Winj ❑ Single Zone ❑�
Coalbe6 Gas ❑ Gas Hydrates ❑
Redrill El , Reentry ❑
I Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond: Blanket D Single Well ❑
11. Well Name and Number:
ConocoPhillips Alaska, Inc.
Bond No. 5952180
KRU 1 R-101
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 12,000 TVD: 3404
Kupamk River Field /
West Salk Oil Pool
4a. Location of Well (Governmental Section):
7. Property Designation:
Surface: 154' FNL, 139' FWL, Sec 20, T12N, R1 OE, UM
ADL 25640 lilt L Z 57(;35
Top of Productive Horizon:
8. DNR Approval Number: F 61_71q,
13. Approximate Spud Date:
388' FNL, 1004' FWL, Sec 20, T12N, RIDE, UM
LONS 83-134
7/1/2019
9. Acres in Property:
14. Distance to Nearest Property:
Total Depth:
2259' FSL, 940' FWL, Sec 29, T12N, R10E, UM
2459
15,930'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ff): 79.9
15. Distance to Nearest Well Open
Surface: x- 539830 y- 5991050 Zone- 4
GL / BF Elevation above MSL (ff): 45.2
to Same Pool: 290' (1R-02)
16. Deviated wells: Kickoff depth: 3690 feet
Maximum Hole Angle: 92 degrees
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Downhole: 1524 Surface: 1185
18. Casing Program: Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Hole Casing Weight Grade I Coupling Length
MD TVD MD TVD (including stage data)
4-1/4" 2-7/8" 6.5# L-80 HYD 533 8385
3615 3335 12,000 3404 Slotted
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured):
12,611 6683 3754 3756 3433 N/A
Casing Length Size Cement Volume MD TVD
Conductor/Structural 77.00 16" 280 sx CS II 115 115
Surface 4,343.00 9-5/8" 1250 sx PFE III, 420 x PFC 4380 3867
Production 6,444.00 7" 65 sx Class G 6479 5315
Perforation Depth MD (ft): Plugged Perforation Depth TVD (ft): Plugged
Hydraulic Fracture planned? Yes❑ No ❑1
20. Attachments: Property Plat ❑ BOP SketchDrilling
Diverter Sketch
Program Time v. Depth Plot Shallow Hazard Analysis
® Seabed Report H Drilling Fluid Program 20 AAC 25.050 requirementsg
21, Verbal Approval: Commission Representative: Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be I /
deviated from without prior written approval. Contact Name: William Long
Authorized Name: James Ohlinger Contact Email: William. R. Loll COP. com
Authorized Title: Sta D Engineer Contact Phone: 263-4372
Authorized Signature: Date:
Commission Use Only
Permit to Drill API Number: Permit Approval See cover letter for other
Number: 1q -� ?g 50- p 1L -i -fit -}--03_00 Date: ' 01 requirements.
,ter
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: E
Other:8oP 7-csto 2SSamples req'd: Yes ❑ No� Mud log req'd: Yes❑ NoRK
t oo sr9
%' y HzS measures: Yes ❑ NoN Directional svy req'd: Yes 2" No❑
/�-only svy req'd: Yes[:] NT
p1/ray 3rv�,acn cc `% IG JrowO/f}}CzvrforcStpSing �ezieption req'tluY<ess❑L< Nco/LhbavcIncltinhatieon
5, O30 1 post initial injection MIT req'd: Yes❑ NoCli M/s of well %n the ��(/Yi leoF a- LRS/-zgs
VUiBtSAlc1l/ynri OP wC//S wh-rr-t -1hCra;13 not ,SOa of l<m<t cc be YG the WSak �vrh ea✓
l/i51-/h mCChan/ca/ Mf<9ri Info /Y elvd.ny Vf- fJ/Ypssc�Srr- the Jrsj mr 5t h<
oV (<Or W61Ch r<cGw3 ttC/ b� f/-ob cG 1v GJ 1 /hr-" APPROVED BY <�«L /op -5 " 1 �j
Approved by: COMMISSIONER THE COMMISSION Date:7 / 3 / I /
�� z�/� Submit Form and
Form 0- Ot Revised 5/2017 i permit is valid for 24 n f d t of p oval per 20 AAC 25.005(g) Attachments in Duplicate
IN I.1 N 41 ���n AN GIZ.,ttl lq
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
June 17, 2019
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby submits applications for permit to drill one lateral out of the KRU 1 R-01 B
(PTD# 200-156) using the coiled tubing drilling rig, Nabors CDR3-AC.
CTD operations are scheduled to begin in early July 2019. The objective will be to drill one lateral KRU 1 R-101
targeting the West Sak B -sand interval. ,
Attached to the permit to drill application are the following documents:
- Permit to Drill Application Form (10-401) for 1 R-101
- Detailed Summary of Operations
- Directional Plan for 1 R-101
- Current wellbore schematic
- Proposed CTD schematic
If you have any questions or require additional information, please contact me at 907-263-4372.
Sincerely,
William R. Long
Staff Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
West Sak CTD Lateral
1R-101
Application for Permit to Drill Document
1. Well Name and Classification........................................................................................................ 2
(Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b))...................................................................................................................2
2. Location Summary .......................................................................................................................... 2
(Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2
3. Blowout Prevention Equipment Information................................................................................. 2
(Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2
4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2
(Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2
5. Procedure for Conducting Formation Integrity tests................................................................... 2
(Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2
6. Casing and Cementing Program.................................................................................................... 3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3
7.
Diverter System Information.......................................................................................................... 3
(Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3
8.
Drilling Fluids Program.................................................................................................................. 3
(Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3
9.
Abnormally Pressured Formation Information.............................................................................4
(Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4
10.
Seismic Analysis............................................................................................................................. 4
(Requirements of 20 AAC 25.005(c)(10)) ................................. ...... ................................................... ............ ............. .......................... .4
11.
Seabed Condition Analysis............................................................................................................ 4
(Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4
12. Evidence of Bonding...................................................................................................................... 4
(Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4
13. Proposed Drilling Program.............................................................................................................4
(Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4
Summaryof Operations...................................................................................................................................................4
LinerRunning...................................................................................................................................................................5
14. Disposal of Drilling Mud and Cuttings.......................................................................................... 5
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................5
15. Directional Plans for Intentionally Deviated Wells....................................................................... 5
(Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 5
16. Attachments....................................................................................................................................6
Attachment 1: Directional Plan for 1 R-101 lateral...........................................................................................................6
Attachment 2: Current Well Schematic for 1 R-01............................................................................................................6
Attachment 3: Proposed Well Schematic for 1R-101 lateral...........................................................................................6
Page 1 of 6 June 14, 2019
PTD Application: 1 R-101
Well Name and Classification
(Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))
The proposed lateral described in this document is IR -11011. The lateral will be classified as "Development -Oil'
well.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
The lateral will target the B sand package in the West Sak reservoir. See attached 10-401 form for surface and
subsurface coordinates of the 1R-101.
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 2,500 psi. The
nearest MDT in the West Sak formation was recorded to be 0.45 psi/ft in 2006. The maximum
potential surface pressure in IR -101, assuming a gas gradient of 0.1 psi/ft, would be 1185 psi. See
the "Drilling Hazards Information and Reservoir Pressure" section for more details.
- The annular preventer will be tested to 250 psi and 2,500 psi.
4. Drilling Hazards Information and Reservoir Pressure 33.3 '957-
(Requirements
sy(Requirements of 20 AAC 25.005 (c)(4)) Em
Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a))
The nearest formation pressure gradient measurement in the West Sak was 0.45 psi/ft with a MDT in 2006.
Based on this pressure gradient the downhole pressure at the window is estimated to be 1524 psi., Reservoir
pressure is not anticipated to have changed since no production or injection has occurred in the Wesl,Sak
for
m t—' he vicinity of this project.
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
Free gas is not anticipated while drilling the 1 R-101 lateral. If gas is detected in the returns the contaminated
mud can be diverted to a storage tank away from the rig.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c))
The major expected risk of hole problems in the 1 R-101 lateral will be lost circulation and differential sticking.
Reduced mud rheology will be used to minimize ECDs and attempt to prevent lost circulation and differential
sticking.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 1 R-101 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity
test is not required.
Page 2 of 6 June 14, 2019
PTD Application: 1R-101
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
Lateral Name
Liner Top
Liner Btm
Liner Top
Liner Btm
Liner Details
Btm
MD
MD
MD
TVDSS
TVDSS
Conductor
1R-101
3615'
12,000'
3253'
3322'
2-7/8", 6.5#, L-80, HYD 533 slotted;
Surface
121'
1640
670
Surface
-80, HYD 511 solid liner
Existing Casing/Liner Information
Category
OD
Weight
t
Grade
Connection
Top MD
Btm
MD
Top
TVD
Btm
TVD
Burst
psi
Collapse
psi
Conductor
16"
62.5
H-40
Welded
Surface
121'
Surface
121'
1640
670
Surface
9-5/8"
36
J-55
BTC
Surface
4381'
Surface
3868'
3520
2020
Production
7"
26.0
J-55
BTC
Surface
6500'
Surface
5331'
4980
4320
Tubing
4-1/2"
12.6
L-80
HYD 503
Surface
3628'
Surface
3344'
8430
7500
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a
diverter system is not required.
8. Drilling Fluids Program
(Requirements of 20 AAC 25.005(c)(8))
Diagram of Drilling System
A diagram of the Nabors CDR3-AC mud system is on file with the Commission.
Description of Drilling Fluid System
— Window milling operations: Chloride -based PowerVis mud (8.4 ppg)
— Drilling operations: Chloride -based PowerVis mud (8.4 ppg). This mud weight may not hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with NaCl completion fluid in order to provide
formation over -balance while running completions. If pressures higher than anticipated are
encountered NaBr completion fluids may also be used.
J Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases,
the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke.
BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment
Information".
In the 1 R-101 lateral we will target a constant BHP to match formation pressure. The constant BHP target will be
adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased
reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed
for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change
in depth of circulation will be offset with back pressure adjustments.
Page 3 of 6 June 14, 2019
PTD ADplication: 1R-101
Pressure at the 1R-101 Window, 3690' MD, 3387' 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 1R-01 was recently worked over and is now equipped with 4-1/2" tubing and 7" production
casing. The CTD sidetrack will utilize one lateral to target the West Sak B -sand to the south of 1 R-01.
A thru-tubing whipstock will be set pre -CTD inside the 7" casing at the planned kick off point of 3690' MD
CDR3-AC will use the whipstock to mill a window in the 7" and 9-5/8" casing strings. The 1 R-101 lateral
will exit through the casing at 3690' MD and TD at 12,000' MD, targeting the West Sak B sand to the
south. It will be completed with 2-7/8" slotted liner from TD up to the build and 3-1/2" solid liner from the
end of build to inside the parent wellbore.
Pre -CTD Work
1. RU E -line: Perforate 7" casing and set 4-1/2" x 7" thru-tubing whipstock.
2. RU CTU: Squeeze cement between 7" and 9-5/8" casing.
3. Prep site for Nabors CDR3-AC rig.
RRi Work
1. MIRU Nabors CDR3-AC rig using 2-5/8" coil tubing. NU 7-1/16" BOPE, test.
Page 4 of 6 June 14, 2019
Pumps On 3 bpm)
Pumps Off
C -sand Formation Pressur 8.65
1524 psi
1524 psi
Mud Hydrostatic .4
1479 psi
1479 psi
Annular friction i.e. ECD, 0.-035psi/ft)
129 psi
0 psi
Mud + ECD Combined
no chokepressure)
1608 psi
Overbalanced —84psi)
1479 psi
Underbalanced —45psi)
Target BHP at Window 8.65
1524 psi
1524 psi
Choke Pressure Required to Maintain
Target BHP
0 psi
45 psi
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AAC 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AAC 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AAC 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
Background
KRU well 1R-01 was recently worked over and is now equipped with 4-1/2" tubing and 7" production
casing. The CTD sidetrack will utilize one lateral to target the West Sak B -sand to the south of 1 R-01.
A thru-tubing whipstock will be set pre -CTD inside the 7" casing at the planned kick off point of 3690' MD
CDR3-AC will use the whipstock to mill a window in the 7" and 9-5/8" casing strings. The 1 R-101 lateral
will exit through the casing at 3690' MD and TD at 12,000' MD, targeting the West Sak B sand to the
south. It will be completed with 2-7/8" slotted liner from TD up to the build and 3-1/2" solid liner from the
end of build to inside the parent wellbore.
Pre -CTD Work
1. RU E -line: Perforate 7" casing and set 4-1/2" x 7" thru-tubing whipstock.
2. RU CTU: Squeeze cement between 7" and 9-5/8" casing.
3. Prep site for Nabors CDR3-AC rig.
RRi Work
1. MIRU Nabors CDR3-AC rig using 2-5/8" coil tubing. NU 7-1/16" BOPE, test.
Page 4 of 6 June 14, 2019
PTD Application: 1R-101
2. 1R-101 Lateral (West Sak B -sand -South)
a. Mill 3.80" window at 3690' MD.
b. Drill 4-1/4" bi-center lateral to TD of 12,000' MD.
c. Run 2-7/8" slotted liner and 3-1/2" solid liner with deployment sleeve from TD to 3615' MD.
3. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Ria Work
1. Set CTD liner top packer in production tubing tail.
2. Return well to production.
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the
Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the
Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator.
This pressure control equipment listed ensures reservoir pressure is contained during the deployment process.
During BHA deployment, the following steps are observed.
- Initially the swab valve on the tree is closed to isolate reservoir pressure. The lubricator is installed on the
BOP riser with the BHA inside the lubricator.
- Pressure is applied to the lubricator to equalize across the swab valve. The swab valve is opened and the
BHA is lowered in place via slick -line.
- When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir
pressure via the annulus. A closed ball valve and check valve isolate reservoir pressure internal to the
BHA. Slips on the deployment ram prevent the BHA from moving when differential pressure is applied.
The lubricator is removed once pressure is bled off above the deployment ram.
- The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to
the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is
made up to the riser, annular pressure is equalized, and the deployment ram is opened. The BHA and
coiled tubing are now ready to run in the hole.
During BHA undeployment, the steps listed above are observed, only in reverse.
Liner Running
- The 1 R-101 lateral will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids"
section for more details.
- While running liner, a joint of 2-5/8" non -slotted tubing will be standing by for emergency deployment. A
floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with
this emergency joint on every slotted liner run. The 2-5/8" rams will provide secondary well control
while running 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 DS4 Prudhoe Bay for disposal.
• Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18
or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable.
• All wastes and waste fluids hauled from the pad must be properly documented and manifested.
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200).
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
- The Applicant is the only affected owner.
Page 5 of 6 June 14, 2019
PTD Application: 1 R-101
- 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 KRU boundary at closest point)
Lateral Name Distance
1R-101 15, 930'
- Distance to Nearest Well within Pool
Lateral Name
Distance
Well
1R-101
290'
1 R-02
16. Attachments
Attachment 1: Directional Plan for 1R-101 lateral
Attachment 2: Current Well Schematic for IR -01
Attachment 3: Proposed Well Schematic for IR -101 lateral
Page 6 of 6 June 14, 2019
ConocoPhillips
ConocoPhillips Alaska Inc_Kuparuk
Kuparuk River Unit
Kuparuk 1R Pad
1 R-01
1R-101
Plan: 1 R-101_wp02
Standard Planning Report
07 May, 2019
BA UGHES
a GE comoanv
ConocoPhillips
Planning Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1R-01
Mean Sea Level
IR -01 @ 82.00usft (1 R-01)
True
Minimum Curvature
Project Kupawk 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 Paint
Map Zone: Alaska Zone 04 Using geodetic scale factor
BA ER
I UGHES
a GE company
Site Kupawk 1 R Pad
PLAN
ConocoPhillips
Database:
EDT 14 Alaska Production
Company:
ConocoPhillips Alaska Inc—Kupawk
Project:
Kupawk River Unit
Site:
Kupamk 1R Pad
Well:
1R-01
Wellbore:
1R-101
Design:
1R-101_wp02
ConocoPhillips
Planning Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1R-01
Mean Sea Level
IR -01 @ 82.00usft (1 R-01)
True
Minimum Curvature
Project Kupawk 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 Paint
Map Zone: Alaska Zone 04 Using geodetic scale factor
BA ER
I UGHES
a GE company
Site Kupawk 1 R Pad
PLAN
Depth From (TVD)
+NbS
(usft)
Site Position:
Northing:
5,991,050.01 usft
Latitude:
70' 23' 11.370 N
From: Map
Easting:
539,829.93 usft
Longitude:
149° 40'33.803 W
Position Uncertainty: 0.00 usft
Slot Radius:
0.000in
Grid Convergence:
0.31 °
Well IR -01
Well Position +N/ -S
+E/ -W
Position Uncertainty
Wellbore 1R-101
Magnetics Model Name
Design
Audit Notes:
Version:
Vertical Section:
0.00 usft Northing: 5,991,050.09 usft Latitude:
0.00 usft Easting: 539,829.76 usft Longitude:
0.00 usft Wellhead Elevation: usft Ground Level:
BGGM2018
1R-101_wp02
Sample Date Declination
1°I
4/3/2019 16.68
Phase:
PLAN
Depth From (TVD)
+NbS
(usft)
(usft(
-45.20
0.00
70'23'11.371 N
149' 40' 33.808 W
45.20 usft
Dip Angle Field Strength
(°) (nT)
80.90 57,425
Tie On Depth: 3,600.00
+E/ -W Direction
(usft) (I
0.00 180.00
5/72019 11:28:18PM Page 2 COMPASS 5000.14 Build 85D
ConocoPhillips BA ER
ConocoPhillips Planning Report BAT
a GE company
Database:
EDT 14 Alaska Production
Local Co-ordinate Reference:
Well 1R-01
Company:
ConocoPhillips Alaska Inc_Kuparuk
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1R-01 @ 82.00usft (1 R-01)
Site:
Kuparuk 1R Pad
North Reference:
True
Well:
1 R-01
Survey Calculation Method:
Minimum Curvature
Wellbore:
1R-101
Build
Turn
Design:
1R-101_wp02
Depth
Inclination
Plan Sections
Measured
TVD Below
Dogleg
Build
Turn
Depth
Inclination
Azimuth
System
+NAS
+El -W
Rate
Rate
Rate
TFO
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(°/100usft)
(°1100usft)
(°/100usft)
(°)
Target
3,600.00
45.78
111.33
3,242.20
-210.62
805.91
0.00
0.00
0.00
0.00
3,690.00
45.91
112.11
3,304.89
-234.52
865.89
0.64
0.14
0.87
77.19
3,719.00
49.97
112.11
3,324.31
-242.62
885.84
14.00
14.00
0.00
0.00
3,941.39
90.00
112.11
3,398.89
-319.68
1,075.51
18.00
18.00
0.00
0.00
4,100.00
90.00
140.66
3,398.89
-412.80
1,201.89
18.00
0.00
18.00
90.00
4,450.00
90.00
165.16
3,398.89
-722.03
1,360.06
7.00
0.00
7.00
90.00
4,600.00
90.00
154.66
3,398.89
-862.71
1,411.51
7.00
0.00
-7.00
-90.00
5,000.00
90.00
182.66
3,398.89
-1,251.01
1,489.39
7.00
0.00
7.00
90.00
5,175.00
90.00
170.41
3,398.89
-1,425.36
1,499.94
7.00
0.00
-7.00
-90.00
5,575.00
90.00
198.41
3,398.89
-1,820.21
1,469.49
7.00
0.00
7.00
90.00
5,975.00
90.00
170.41
3,398.89
-2,215.07
1,439.04
7.00
0.00
-7.00
-90.00
6,375.00
90.00
198.41
3,398.89
-2,609.93
1,408.59
7.00
0.00
7.00
90.00
6,775.00
90.00
170.41
3,398.89
-3,004.79
1,378.13
7.00
0.00
-7.00
-90.00
7,200.00
90.00
200.16
3,398.89
-3,423.25
1,339.43
7.00
0.00
7.00
90.00
7,600.00
90.00
172.16
3,398.89
-3,816.99
1,296.93
7.00
0.00
-7.00
-90.00
8,000.00
90.47
200.16
3,397.22
-0,210.73
1,254.45
7.00
0.12
7.00
89.00
8,400.00
90.88
172.16
3,392.40
-4,604.45
1,211.97
7.00
0.10
-7.00
-89.00
8,800.00
91.25
200.16
3,384.80
-4,998.13
1,169.50
7.00
0.09
7.00
89.00
9,200.00
91.57
172.15
3,374.74
-5,391.75
1,127.03
7.00
0.08
-7.00
-89.00
9,600.00
91.39
200.16
3,364.19
-5,785.35
1,084.56
7.00
-0.05
7.00
90.00
10,000.00
91.23
172.16
3,354.88
-6,178.99
1,042.09
7.00
-0.04
-7.00
-90.00
10,400.00
91.08
200.16
3,346.66
-6,572.65
999.62
7.00
-0.04
7.00
90.00
10,800.00
90.96
172.16
3,339.40
-6,966.33
957.14
7.00
-0.03
-7.00
-90.00
11,200.00
90.84
200.16
3,332.98
-7,360.03
914.66
7.00
-0.03
7.00
90.00
11,600.00
90.75
172.16
3,327.32
-7,753.73
872.18
7.00
-0.02
-7.00
-90.00
12,000.00
90.66
200.16
3,322.32
-8,147.45
829.70
7.00
-0.02
7.00
90.00
5/72019 11:28.. 18PM Page 3 COMPASS 5000.14 Build 85D
ConocoPhillips BA ER
ConocoPhillips Planning Report I IGHES
BAT
GE company
Database:
EDT 14 Alaska Production
Local Co-ordinate Reference:
Well 1R-01
Company:
ConocoPhillips Alaska Inc_Kuparuk
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1R-01 Q 82.00usft (1R-01)
Site:
Kuparuk 111 Pad
North Reference:
True
Well:
1R-01
Survey Calculation Method:
Minimum Curvature
Wellbore:
1R-101
Design:
1R-101_wp02
Vertical
Dogleg
Planned
Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination Azimuth
System
+N/ -S
+E/ -W
Section
Rate
Azimuth
Northing
Easdng
(usft)
C)
(°)
(usft)
(usft)
(usft)
(usft)
(°ROOusft)
(°)
(usft)
(usft)
3,600.00
45.78
111.33
3,242.20
-210.62
805.91
210.62
0.00
0.00
5,990,843.78
540,636.70
TIP
3,690.00
45.91
112.11
3,304.89
-234.52
865.89
234.52
0.64
77.19
5,990,820.21
540,696.80
KOP
3,700.00
47.31
112.11
3,311.76
-237.25
872.62
237.25
14.00
0.00
5,990,817.51
540,703.55
3,719.00
49.97
112.11
3,324.31
-242.62
885.84
242.62
14.00
0.00
5,990,812.21
540,716.79
End 14
cls, Start 18 dls
3,800.00
64.55
112.11
3,368.00
-268.19
948.79
268.19
18.00
0.00
5,990,786.98
540,779.87
3,900.00
82.55
112.11
3,396.20
-304.14
1,037.28
304.14
18.00
0.00
5,990,751.50
540,868.54
3,941.39
90.00
112.11
3,398.89
-319.68
1,075.51
319.68
18.00
0.00
5,990,736.17
540,906.85
4
4,000.00
90.00
122.66
3,398.89
-346.60
1,127.48
346.60
18.00
90.00
5,990,709.53
540,958.96
4,100.00
90.00
140.66
3,398.89
-412.80
1,201.89
412.80
18.00
90.00
5,990,643.74
541,033.71
End 18
dls, Start 7 dis
4,200.00
90.00
147.66
3,398,89
493.81
1,260.40
493.81
7.00
90.00
5,990,563.04
541,092.65
4,300.00
90.00
154.66
3,398.89
-581.36
1,308.61
581.36
7.00
90.00
5,990,475.77
541,141.32
4,400.00
90.00
161.66
3,398.89
-674.12
1,345.79
674.12
7.00
90.00
5,990,383.21
541,178.99
4,450.00
90.00
165.16
3,398.89
-722.03
1,360.06
722.03
7.00
90.00
5,990,335.38
541,193.51
6
4,500.00
90.00
161.66
3,398.89
-769.94
1,374.33
769.94
7.00
-90.00
5,990,287.55
541,208.04
4,600.00
90.00
154.66
3,398.89
-862.71
1,411.51
862.71
7.00
-90.00
5,990,195.00
541,245.71
7
4,700.00
90.00
161.66
3,398.89
-955.47
1,448.69
955.47
7.00
90.00
5,990,102.44
541,283.38
4,800.00
90.00
168.66
3,398.89
-1,052.08
1,474.29
1,052.08
7.00
90.00
5,990,005.98
541,309.48
4,900.00
90.00
175.66
3,398.89
-1,151.08
1,487.92
1,151.08
7.00
90.00
5,989,907.06
541,323.64
5,000.00
90.00
182.66
3,398.89
-1,251.01
1,489.39
1,251.01
7.00
90.00
5,989,807.15
541,325.64
8
5,100.00
90.00
175.66
3,398.89
-1,350.93
1,490.85
1,350.93
7.00
-90.00
5,989,707.25
541,327.64
5,175.00
90.00
170.41
3,398.89
-1,425.36
1,499.94
1,425.36
7.00
-90.00
5,989,632.88
541,337.12
9
5,200.00
90.00
172.16
3,398.89
-1,450.07
1,503.73
1,450.07
7.00
90.00
5,989,608.20
541,341.04
5,300.00
90.00
179.16
3,398.89
-1,549.72
1,511.29
1,549.72
7.00
90.00
5,989,508.60
541,349.14
5,400.00
90.00
186.16
3,398.89
-1,649.55
1,506.65
1,649.55
7.00
90.00
5,989,408.75
541,345.03
5,500.00
90.00
193.16
3,398.89
-1,748.07
1,489.88
1,748.07
7.00
90.00
5,989,310.15
541,328.79
5,575.00
90.00
198.41
3,398.89
-1,820.21
1,469.49
1,820.21
7.00
90.00
5,989,237.91
541,308.78
10
5,600.00
90.00
196.66
3,398.89
-1,844.05
1,461.96
1,844.05
7.00
-90.00
5,989,214.03
541,301.37
5,700.00
90.00
189.66
3,398.89
-1,941.37
1,439.20
1,941.37
7.00
-90.00
5,989,116.61
541,279.14
5,800.00
90.00
182.66
3,398.89
-2,040.73
1,428.48
2,040.73
7.00
-90.00
5,989,017.20
541,268.95
5,900.00
90.00
175.66
3,398.89
-2,140.65
1,429.95
2,140.65
7.00
-90.00
5,988,917.29
541,270.94
5,975.00
90.00
170.41
3,398.89
-2,215.07
1,439.04
2,215.07
7.00
-90.00
5,988,842.93
541,280.43
11
6,000.00
90.00
172.16
3,398.89
-2,239.78
1,442.83
2,239.78
7.00
90.00
5,988,818.24
541,284.35
6,100.00
90.00
179.16
3,398.89
-2,339.44
1,450.39
2,339.44
7.00
90.00
5,988,718.64
541,292.44
6,200.00
90.00
186.16
3,398.89
-2,439.27
1,445.75
2,439.27
7.00
90.00
5,988,618.80
541,288.34
6,300.00
90.00
193.16
3,398.89
-2,537.79
1,428.98
2,537.79
7.00
90.00
5,988,520.20
541,272.09
6,375.00
90.00
198.41
3,398.89
-2,609.93
1,408.59
2,609.93
7.00
90.00
5,988,447.95
541,252.09
12
6,400.00
90.00
196.66
3,398.89
-2,633.77
1,401.05
2,633.77
7.00
-90.00
5,988,424.08
541,244.68
6,500.00
90.00
189.66
3,398.89
-2,731.08
1,378.30
2,731.08
7.00
-90.00
5,988,326.65
541,222.45
6,600.00
90.00
182.66
3,398.89
-2,830.44
1,367.58
2,830.44
7.00
-90.00
5,988,227.25
541,212.26
6,700.00
90.00
175.66
3,398.89
-2,930.37
1,369.04
2,930.37
7.00
-90.00
5,988,127.34
541,214.25
51712019 11:28: 16PM Page 4 COMPASS 5000.14 Build 85D
ConocoPhillipsER
ConocOPhllllps Planning Report �F UGHES
aGEcompamy
Database:
EDT 14 Alaska
Production
Local Co-ordinate Reference: Well 1 R-01
Company:
ConocoPhillips
Alaska Inc_Kuparuk
TVD Reference:
Mean
Sea Level
Project:
Kuparuk River Unit
MD Reference:
iR-01
@ 82.00usft (1
R-01)
Site:
Kuparuk 1R Pad
North Reference:
True
Well:
1R-01
Survey Calculation
Method:
Minimum
Curvature
Wellbore:
1R-101
Design:
1R-101_wp02
Planned
Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination Azimuth
System
+N/ -S
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(e)
(`)
(usft)
(usft)
lush)
(usft)
(°/100usft)
(")
(usft)
(usft)
6,775.00
90.00
170.41
3,398.89
-3,004.79
1,378.13
3,004.79
7.00
-90.00
5,988,052.98
541,223.74
13
6,800.00
90.00
172.16
3,398.89
-3,029.50
1,381.92
3,029.50
7.00
90.00
5,988,028.29
541,227.66
6,900.00
90.00
179.16
3,398.89
-3,129.15
1,389.48
3,129.15
7.00
90.00
5,987,928.69
541,235.75
7,000.00
90.00
186.16
3,398.89
-3,228.98
1,384.85
3,228.98
7.00
90.00
5,987,828.84
541,231.65
7,100.00
90.00
193.16
3,398.89
-3,327.50
1,368.08
3,327.50
7.00
90.00
5,987,730.25
541,215.40
7,200.00
90.00
200.16
3,398.89
-3,423.25
1,339.43
3,423.25
7.00
90.00
5,987,634.36
541,187.26
14
7,300.00
90.00
193.16
3,398.89
-3,518.99
1,310.77
3,518.99
7.00
-90.00
5,987,538.48
541,159.13
7,400.00
90.00
186.16
3,398.89
-3,617.51
1,294.00
3,617.51
7.00
-90.00
5,987,439.88
541,142.88
7,500.00
90.00
179.16
3,398.89
-3,717.34
1,289.37
3,717.34
7.00
-90.00
5,987,340.03
541,138.78
7,600.00
90.00
172.16
3,398.89
-3,816.99
1,296.93
3,816.99
7.00
-90.00
5,987,240.43
541,146.87
1s
7,700.00
90.12
179.16
3,398.78
-3,916.64
1,304.49
3,916.64
7.00
89.00
5,987,140.83
541,154.96
7,800.00
90.24
186.16
3,398.47
-4,016.47
1,299.86
4,016.47
7.00
89.01
5,987,040.99
541,150.86
7,900.00
90.36
193.16
3,397.94
4,114.99
1,283.09
4,114.99
7.00
89.03
5,986,942.39
541,134.62
8,000.00
90.47
200.16
3,397.22
4,210.73
1,254.45
4,210.73
7.00
89.07
5,986,846.51
541,106.49
16
8,100.00
90.59
193.16
3,396.29
4,306.47
1,225.80
4,306.47
7.00
-89.00
5,986,750.63
541,078.36
8,200.00
90.70
186.16
3,395.17
4,404.99
1,209.04
4,404.99
7.00
-89.06
5,986,652.03
541,062.12
8,300.00
90.80
179.16
3,393.87
4,504.81
1,204.40
4,504.81
7.00
-89.14
5,986,552.20
541,058.02
8,400.00
90.88
172.16
3,392.40
4,604.45
1,211.97
4,604.45
7.00
-89.23
5,986,452.61
541,066.11
17
8,500.00
91.00
179.16
3,390.75
-4,704.09
1,219.54
4,704.09
7.00
89.00
5,986,353.02
541,074.21
8,600.00
91.10
186.16
3,388.92
4,803.90
1,214.90
4,803.90
7.00
89.12
5,986,253.20
541,070.11
8,700.00
91.18
193.16
3,386.92
4,902.40
1,198.14
4,902.40
7.00
89.24
5,986,154.62
541,053.87
8,800.00
91.25
200.16
3,384.80
4,998.13
1,169.50
4,998.13
7.00
89.38
5,986,058.75
541,025.74
18
8,900.00
91.36
193.16
3,382.52
-5,093.84
1,140.85
5,093.84
7.00
-89.00
5,985,962.89
540,997.61
9,000.00
91.45
186.16
3,380.05
-5,192.34
1,124.09
5,192.34
7.00
-89.16
5,985,864.32
540,981.38
9,100.00
91.53
179.16
3,377.45
-5,292.13
1,119.46
5,292.13
7.00
-89.33
5,985,764.51
540,977.28
9,200.00
91.57
172.15
3,374.74
-5,391.75
1,127.03
5,391.75
7.00
-89.51
5,985,664.95
540,985.38
19
9,300.00
91.56
179.16
3,372.01
-5,491.36
1,134.60
5,491.36
7.00
90.00
5,985,565.39
540,993.48
9,400.00
91.53
186.16
3,369.31
-5,591.15
1,129.97
5,591.15
7.00
90.19
5,985,465.58
540,989.38
9,500.00
91.47
193.16
3,366.69
-5,689.64
1,113.21
5,689.64
7.00
90.38
5,985,367.02
540,973.14
9,600.00
91.39
200.16
3,364.19
-5,785.35
1,084.56
5,785.35
7.00
90.56
5,985,271.16
540,945.01
20
9,700.00
91.38
193.16
3,361.78
-5,881.07
1,055.92
5,881.07
7.00
-90.00
5,985,175.31
540,916.88
9,800.00
91.35
186.16
3,359.40
-5,979.56
1,039.15
5,979.56
7.00
-90.17
5,985,076.74
540,900.64
9,900.00
91.30
179.16
3,357.08
-6,079.36
1,034.52
6,079.36
7.00
-90.34
5,984,976.92
540,896.54
10,000.00
91.23
172.16
3,354.88
-6,178.99
1,042.09
6,178.99
7.00
-90.50
5,984,877.34
540,904.64
21
10,100.00
91.22
179.16
3,352.75
-6,278.62
1,049.66
6,278.62
7.00
90.00
5,984,777.77
540,912.74
10,200.00
91.19
186.16
3,350.64
-6,378.43
1,045.03
6,378.43
7.00
90.15
5,984,677.95
540,908.64
10,300.00
91.14
193.16
3,348.60
-6,476.93
1,028.26
6,476.93
7.00
90.30
5,984,579.37
540,892.40
10,400.00
91.08
200.16
3,346.66
-6,572.65
999.62
6,572.65
7.00
90.44
5,984,483.50
540,864.26
22
10,500.00
91.07
193.16
3,344.77
-6,668.38
970.97
6,668.38
7.00
-90.00
5,984,387.63
540,836.13
10,600.00
91.05
186.16
3,342.91
-6,766.88
954.20
6,766.88
7.00
-90.13
5,984,289.05
540,819.89
10,700.00
91.01
179.16
3,341.11
-6,866.69
949.57
6,866.69
7.00
-90.26
5,984,189.22
540,815.79
10,800.00
90.96
172.16
3,339.40
-6,966.33
957.14
6,966.33
7.00
-90.39
5,984,089.64
540,823.89
5/72019 11:28: 16PM Page 5 COMPASS 5000.14 Build 85D
ConocoPhillips BA►(ER
Conoc0�ll��IpS Planning Report UGHES
aGEcompany
all
Database:
EDT 14 Alaska
Production
Hole
Depth
Local Coordinate Reference: Well 1 R-01
Diameter
Diameter
(usft)
Company:
ConocoPhillips
Alaska Inc_Kupaiuk
12,000.00
3,322.32 23/8"
TVD Reference:
Mean
Sea Level
Project:
Kuparuk River
Unit
MD Reference:
1 R-01
Q 82.00usft (1
R-01)
Site:
Kupamk 1 R Pad
North Reference:
True
Well:
1R-01
Survey Calculation Method:
Minimum Curvature
Wellbore:
111-101
Design:
1R-101_wp02
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination
Azimuth
System
+N/ -S
+EI -W
Section
Rate
Azimuth
Northing
Easting
(usft)
V)
(°)
(usft)
(usft)
(usft)
(usft)
('1100usft)
(°)
(usft)
(usft)
23
10,900.00
90.95
179.16
3,337.73
-7,065.97
964.71
7,065.97
7.00
90.00
5,983,990.05
540,831.99
11,000.00
90.93
186.16
3,336.09
-7,165.78
960.07
7,165.78
7.00
90.12
5,983,890.22
540,827.89
11,100.00
90.89
193.16
3,334.50
-7,264.29
943.31
7,264.29
7.00
90.23
5,983,791.64
540,811.65
11,200.00
90.84
200.16
3,332.98
-7,360.03
914.66
7,360.03
7.00
90.34
5,983,695.76
540,783.51
24
11,300.00
90.84
193.16
3,331.51
-7,455.76
886.01
7,455.76
7.00
-90.00
5,983,599.89
540,755.38
11,400.00
90.82
186.16
3,330.07
-7,554.27
869.25
7,554.27
7.00
-90.10
5,983,501.30
540,739.14
11,500.00
90.79
179.16
3,328.66
-7,654.09
864.61
7,654.09
7.00
-90.20
5,983,401.47
540,735.04
11,600.00
90.75
172.16
3,327.32
-7,753.73
872.18
7,753.73
7.00
-90.30
5,983,301.87
540,743.13
25
11,700.00
90.74
179.16
3,326.03
-7,853.37
879.75
7,853.37
7.00
90.00
5,983,202.28
540,751.23
11,800.00
90.72
186.16
3,324.75
-7,953.20
875.11
7,953.20
7.00
90.09
5,983,102.45
540,747.13
11,900.00
90.70
193.16
3,323.51
-8,051.71
858.35
8,051.71
7.00
90.18
5,983,003.86
540,730.89
12,000.00
90.66
200.16
3,322.32
-8,147.45
829.70
8,147.45
7.00
90.27
5,982,907.98
540,702.76
Planned
TD at 12000.00
Casing Points
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
(usft) Name
(in)
(in)
12,000.00
3,322.32 23/8"
2.375
3.000
5/72019 11:28:16PM Page 6 COMPASS 5000.14 Build 85D
�.
ConocoPhillips
BAT
BA
ER
ConocoPhillips
Planning Report
Local Coordinates
Depth
Depth
+Ni -S
+E/ -W
a GEcempaW
Database: EDT 14 Alaska Production
Local Co-ordinate Reference:
Well 1R-01
(usft)
Company: ConocoPhillips Alaska Inc_Kupawk
TVD Reference:
Mean Sea Level
-210.62
Project: Kuparuk River Unit
MD Reference:
1 R-01 @ 82.00usft (1 R-01)
3,304.89
Site: Kupawk 1R Pad
North Reference:
True
3,719.00
Well: 1R-01
Survey Calculation Method:
Minimum Curvature
End 14 dls, Start 18 dls
Wellbore: 1R-101
3,398.89
-319.68
1,075.51
Design: 1R-101_wp02
4,100.00
3,398.89
412.80
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+Ni -S
+E/ -W
(usft)
(usft)
(usft)
(usft)
Comment
3,600.00
3,242.20
-210.62
805.91
TIP
3,690.00
3,304.89
-234.52
865.89
KOP
3,719.00
3,324.31
-242.62
885.84
End 14 dls, Start 18 dls
3,941.39
3,398.89
-319.68
1,075.51
4
4,100.00
3,398.89
412.80
1,201.89
End 18 cls, Start 7 dls
4,450.00
3,398.89
-722.03
1,360.06
6
4,600.00
3,398.89
-862.71
1,411.51
7
5,000.00
3,398.89
-1,251.01
1,489.39
8
5,175.00
3,398.89
-1,425.36
1,499.94
9
5,575.00
3,398.89
-1,820.21
1,469.49
10
5,975.00
3,398.89
-2,215.07
1,439.04
11
6,375.00
3,398.89
-2,609.93
1,408.59
12
6,775.00
3,398.89
-3,004.79
1,378.13
13
7,200.00
3,398.89
-3,423.25
1,339.43
14
7,600.00
3,398.89
-3,816.99
1,296.93
15
8,000.00
3,397.22
-4,210.73
1,254.45
16
8,400.00
3,392.40
-4,604.45
1,211.97
17
8,800.00
3,384.80
-4,998.13
1,169.50
18
9,200.00
3,374.74
-5,391.75
1,127.03
19
9,600.00
3,364.19
-5,785.35
1,084.56
20
10,000.00
3,354.88
-6,178.99
1,042.09
21
10,400.00
3,346.66
-6,572.65
999.62
22
10,800.00
3,339.40
-6,966.33
957.14
23
11,200.00
3,332.98
-7,360.03
914.66
24
11,600.00
3,327.32
-7,753.73
872.18
25
12,000.00
3,322.32
-8,147.45
829.70
Planned TD at 12000.00
5/72019 11:28: 16PM Page 7 COMPASS 5000.14 Build 85D
`- ConocoPhillips BA. ICER`'
ConocoPhillips Anticollision Report IGHES
BAT
GE company
Company:
ConocoPhillips Alaska Inc Kuparuk
Project:
Kuparuk River Unit -2
Reference Site:
Kuparuk 1 R Pad
Site Error:
0.00 usft
Reference Well:
IR -01
Well Error:
0.00 usft
Reference Wellbore
1R-101
Reference Design:
1 R-101_wp02
Reference 1R-101_wp02
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Filter type:
NO GLOBAL FILTER: Using user defined selection & filtering criteria
Interpolation Method:
MD Interval 25.00usft Error Model:
Depth Range:
3,600.00 to 12,000.00usft Scan Method:
Results Limited by:
Maximum center -center distance of 1,396.32 usft Error Surface:
Levels Evaluated at: 2.79
Method:
Well 1 R-01
1R-01 @ 82.00usft (1R-01)
1 R-01 @ 82.00usft (1 R-01)
True
Minimum Curvature
2.00 sigma
EDT 14 Alaska Production
Offset Datum
ISCWSA
Tray. Cylinder North
Combined Pedal Curve
Added to Error Values
Survey Tool Program Date 5/7/2019
From TO
(usft) (usft) Survey (Wellbore) Tool Name Description
100.00 3,600.001R-01(1 R-01) GCT -MS Schlumberger GCT multishot
3,600.00 12,000.00 1R-101_Wp02(1 R-101) MWD MWD - Standard
Summary
Site Name
Offset Well - Wellbore - Design
Kuparuk 1 R Pad
1 R-01 - 1 R-01 -1 R-01
1R-01 - IR -01A- 1 R -01A
1R-01 - IR -01B- 1R -01B
1R-01 - IR -01131.1 - 1 R-01 BL1
1R-01 - 1R-01131-11-01 -1R-01131-1-01
1R-01 - 1R-01BL1-01PB7 - 1R-01BL1-01PB1
1R-01-1R-01BL1PB1-1R-01BL1PB1
1 R-02 - 1 R-02 -1 R-02
1 R-02 - 1 R-02 - 1 R-02
1 R-02 -1 R-02 - 1 R-02
1 R-03 - 1 R-03 -1 R-03
1 R-03 - 1 R -03A - 1 R -03A
1 R-03 - 1 R-03APB1 -1 R-03APB1
1 R-04 - 1 R-04 - 1 R-04
1 R-04 - 1 R-04 - 1 R-04
1 R-04 - 1 R-1 04A CTD Sidetrack -1 R -104A Wp03
1 R-04 - 1 R -104A CTD Sidetrack - 1 R-1 04A Wp03
1 R-04 - 1 R -104A CTD Sidetrack - 1 R-1 04A wp03
1 R-24 - 1 R-24 - 1 R-24
1 R-24 - 1 R-24 -1 R-24
1 R-25 - 1 R-25 -1 R-25
1 R-25 - 1 R-25 -1 R-25
1 R-25 -1 R-25 - 1 R-25
1 R-26 -1 R-126 CTD Sidetrack -1 R-261-1_wp00 (4 dls)
1 R-26 - 1 R-126 CTD Sidetrack -1 R-2611_wp00 (4 dls)
1 R-26 - 1 R-26 - 1 R-26
1 R-26 - 1 R-26 -1 R-26
1 R-26 - 1 R-26 - 1 R-26
1 R-27 -1 R-27 - 1 R-27
1 R-27 - 1 R-27 -1 R-27
1 R-27 - 1 R-27 -1 R-27
Kuparuk UGNU
Plan East Ugnu # 1 - Ugnu #1 - Plan #2
Reference Offset Distance
Measured Measured Between Between Separation Warning
Depth Depth Centres Ellipses Factor
(usft) (usftl (usft) fusel
3,910.72
3,950.00
88.39
82.55
15.132 CC, ES, SF
3,910.72
3,950.00
88.39
82.55
15.132 CC, ES, SF
3,910.72
3,950.00
88.39
82.55
15.132 CC, ES, SF
3,910.72
3,950.00
88.39
82.55
15.132 CC, ES, SF
3,910.72
3,950.00
88.39
82.55
15.132 CC, ES, SF
3,910.72
3,950.00
88.39
82.55
15.132 CC, ES, SF
3,910.72
3,950.00
88.39
82.55
15.132 CC, ES, SF
4,725.00
4,050.00
291.96
232.95
4.947 CC
4,735.81
4,075.00
292.80
232.40
4.848 ES
4,746.61
4,100.00
295.26
233.77
4.802 SF
3,600.83
4,125.00
1,138.10
1,088.24
22.825 CC, ES, SF
3,600.83
4,125.00
1,138.10
1,088.24
22.825 CC, ES, SF
3,600.83
4,125.00
1,138.10
1,088.24
22.825 CC, ES, SF
3,603.10
3,850.00
1,018.63
958.59
16.968 CC, ES
5,050.00
4,325.00
1,288.96
1,208.13
15.947 SF
11,325.00
10,200.00
892.51
546.79
2.582 Normal Operations, CC
11,350.00
10,250.00
894.17
545.03
2.561 Normal Operations, ES
11,575.00
10,725.00
914.29
546.49
2.486 Caution Monitor Closely, SF
4,025.00
3,225.00
1,294.98
1,242.80
24.819 CC, ES
4,089.50
3,675.00
1,395.08
1,331.42
21.915 SF
4,000.00
3,375.00
1,165.25
1,108.36
20.484 CC
4,010.98
3,425.00
1,166.00
1,107.56
19.952 ES
4,050.00
3,725.00
1,224.39
1,158.78
18.662 SF
4,509.51
3,750.00
700.49
639.26
11.440 CC
11,000.00
11,275.00
813.55
475.06
2.404 Caution Monitor Closely, ES
4,509.51
3,750.00
700.49
639.24
11.435 CC
4,596.36
3,825.00
701.95
635.69
10.595 ES
4,650.00
4,000.00
725.46
652.10
9.889 SF
4,400.00
3,475.00
1,133.08
1,075.24
19.588 CC
4,412.30
3,525.00
1,134.18
1,074.52
19.011 ES
4,650.00
3,925.00
1,218.21
1,144.41
16.507 SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
Out of range
5/712019 6:18:49PM Page 2 COMPASS 5000.14 Build 85D
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Well KRU XX -XX Nabors CDR3-AC: 4 -Ram BOP Configuration 2- Date June 2019
5/8" Coiled Tubing and 3" BHA
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Distances from top o
Excluding quick -test
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CL 2-5/8" Combi's
CL 3" Combi's
CL VBR's
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Flow Tee
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CL Master
LDS
Grounc
Tree Size
P7 --O 2J9-093
Loepp, Victoria T (CED)
From: Long, William R <William.R.Long@conocophillips.com>
Sent: Tuesday, July 2, 2019 3:47 PM
To: Loepp, Victoria T (CED)
Cc: Eller, J Gary; Starck, Kai; Ohlinger, James J
Subject: RE: [EXTERNAL]KRU 1 R-101 (PTD 219-093) West Sak CTD
Follow Up Flag: Follow up
Flag Status: Flagged
Victoria,
As discussed on the phone. We will be at the AOGCC office at 1pm tomorrow. See you then.
Thanks,
William
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Tuesday, July 2, 2019 3:13 PM
To: Long, William R <William.R.Long@conocophillips.com>
Cc: Eller, J Gary <1.Gary.Eller@conocophillips.com>; Starck, Kai<Kai.Starck@conocophillips.com>; Ohlinger, James 1
<James.J.Oh li nger@conocophil I i ps.co m>
Subject: RE: [EXTERNAL]KRU 1R-101 (PTD 219-093) West Sak CTD
Are all of you out of the office tomorrow early afternoon or do you have time to visit on this?
Victoria
From: Long, William R <William.R.Long@conocophillips.com>
Sent: Monday, July 1, 2019 5:32 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.Rov>
Cc: Eller, J Gary <J.Gary.Eller@conocophillips.com>; Starck, Kai <Kai.Starck@conocophillips.com>; Ohlinger, James 1
<James.J.Ohlineer@conocophillips.com>
Subject: RE: [EXTERNAL)KRU 111-101 (PTD 219-093) West Sak CTD
Victoria,
Due to the relatively shallow depths of the West Sak formation, surface pressures stay relatively low. Even IF the artic
pack cement failed and we had full reservoir pressure to surface, the pressure should remain safely contained within the
wellhead. The maximum predicted surface pressure for this well is 1185 psi. The OA was pressure tested to 1800 psi
last year. Since we are operating through tubing, the wellhead will stay in place throughout the project and even IF
pressure developed on the OA it should not affect drilling operations.
There is a lot to think through on these projects. Thanks for all the discussion. Please let me know if there are any items
we are not considering, anything we should discuss further, or any action needed.
Thanks,
William
From: Loepp, Victoria T (CED) <,j,,
Sent: Monday, July 1, 2019 2:57 PM
To: Long, William R < >
Subject: RE: [EXTERNAL]KRU SR -101 (PTD 219-093) West Sak CTD
William,
What is concerning is the OA may be open to the reservoir above the window with one barrier to surface, the arctic
cement, which there is limited information about. Does that concern you when drilling?
Victoria
From: Long, William R <William.R.Long@conocophillips.com>
Sent: Monday, July 1, 2019 2:39 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Cc: Starck, Kai<Kai.Starck@conocophillips.com>; Eller, J Gary <1.Garv.Eller@conocophillips.com>; Ohlinger, James J
<James.J.Ohlinger@conocophilli ps. com>
Subject: RE: [EXTERNAL]KRU 1R-101 (PTD 219-093) West Sak CTD
Victoria,
This is the first CTD project in the West Sak formation.
I have looked back through our files further on this well.
A MIT -OA was conducted on 21 -Oct -2018 to 1800 psi and passed.
A MIT -IA was conducted on 28 -Apr -2019, after the rig workover, to 2500 psi and passed.
When surface casing was originally ran on this well the shoe was tested to 12.5 ppg.
Do these existing tests answer your questions about the IA and OA?
CTD is a unique operation since primary well control is provided by the coiled tubing pack off and MPD choke, NOT the
fluid system, the window and the wellbore are in the same strata, and the fluid system is typically solids free without any
fluid loss additives. Because of the unique nature of CTD and through tubing operations I do not see any value to the
information gained by a formation integrity test for drilling operations. Since the test is not required by regulation and If
the test will not provide any value, I would prefer to NOT incur the nonproductive time, cost, and exposure of the
additional operation. One of the reasons that CTD can develop additional Alaskan oil and gas resources is our ability to
do so at a lower cost.
Thanks,
William R. Long
Staff CTD Engineer
ConocoPhillips
907-263-4372 (office)
281-723-6000 (cell)
W i Iliam.R.Long@ConocoPhillips.com
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.Rov>
Sent: Monday, July 1, 2019 10:59 AM
To: Long, William R<William.R.Lon>;@conocophillips.com>
Subject: [EXTERNAL]KRU 111-101 (PTD 219-093) West Sak CTD
William,
Would CPAI perform a pressure test while monitoring the IA/OA pressures?
While an FIT is not required for CTD operations by regulation, please comment on performing an FIT.
Will this be the first West Sak drilling with coil?
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
V ictoria.Loepp(Malaska.cov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Victoria Loepp at (907)793-1247 oryictoria.LoFoo a-alaska. ov
From: Long, William R <William R Lona@conocophillips.com>
Sent: Monday, July 1, 2019 10:25 AM
To: Loepp, Victoria T (CED) <victoria.loepp@@alaska.eov>
Cc: Eller, J Gary <1.Gary.Eller@conocophillips.com>; Ohlinger, James <James.J Ohlinaer conocophillips.com>; Starck,
Kai <Kai.Starck@conocophillips.com>
Subject: RE: [EXTERNAL)RE: KRU 1R-01 (PTD 200-156, Sundry 319-041) Perf and Squeeze Interval (319-041)
Victoria,
A cement evaluation log was not performed. The whipstock is cemented in place in the perforations and there is no
access.
This cement squeeze was designed only to stabilize the 7" x 9-5/8" annulus for window milling; on this producing well,
the cement squeeze never was intended to provide isolation. The window will be milled in the squeeze and provide
access and communication through the casing strings. Whether or not the squeeze passes a pressure test today, the
window will be milled through the squeeze as part of the CTD operation.
The IA was a trapped annulus during the squeeze. Pressure fluctuations in the IA were likely being driven by thermal
effects and ballooning.
Would be happy to discuss further if needed.
Thanks,
William R. Long
Staff CTD Engineer
ConocoPhillips
907-263-4372 (office)
281-723-6000 (cell)
William R.LonR@ConocoPhillips.com
From: Loepp, Victoria T (CED) <victoria.loepp@alaska-gov>
Sent: Monday, July 1, 2019 9:40 AM
To: Long, William R<William R Lonl;@conocophillips.com>
Subject: RE: [EXTERNAL]RE: KRU 111-03 (PTD 200-156, Sundry 319-041) Perf and Squeeze Interval (319-041)
William,
What are you attributing the IA pressure due to during the squeeze?
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. LoeopOa laska.aov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Victoria Loepp at (907)793-1247 or Victoria Loeoo4olaska.aov
From: Loepp, Victoria T (CED)
Sent: Monday, July 1, 2019 9:06 AM
To: Long, William R <William.R.LonR@conocophillips.com>
Cc: Ohlinger, James <James.J.Ohlintter@conocophiIli ps.com>; Starck, Kai<Kai.Starck@conocophillips.com>; Eller, J Gary
<J Gary Eller@conocophillips.com>
Subject: RE: [EXTERNAL]RE: KRU 111-01 (PTD 200-156, Sundry 319-041) Perf and Squeeze Interval (319-041)
William,
Was a cement evaluation log performed on the OA squeeze? Would like to talk about performing a cement eval log and
pressure testing the squeeze.
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria.Loe ppPalaska goy
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Victoria Loepp at (907)793-1247 or Victoria I r �1 OO Y(l1)Vi
From: Long, William R<William R Long conocophillips.com>
Sent: Sunday, June 30, 2019 9:45 PM
To: Loepp, Victoria T (CED) <victoria loepp@alaska.gov>
Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Starck, Kai <Kai.Starck conocophillips.com>; Eller, J Gary
<I Gary.Elie! �onocophillips.com>
Subject: RE: [EXTERNAL]RE: KRU 111-01 (PTD 200-156, Sundry 319-041) Perf and Squeeze Interval (319-041)
Victoria,
A pressure test was not performed after the squeeze procedure.
Pressure was present on the OA before the squeeze procedure and actually dropped between the first and second
hesitations during the squeeze. There is artic pack cement in the OA above the West Sak and I suspect OA pressure
changes are likely being driven by thermal effects and ballooning. Below is a table of pressures from our recent well
service reports.
DATE
ACTIVITY
TUBING (PSI)
IA (PSI)
OA I
6/19/2019
Perforate 7" for 7 x 9-5/8" Squeeze
0
0
530
6/20/2019
Set Whipstock
0
0
530
500
6/26/2019
Initial Pressures Prior to Coil Squeeze
332
0
Begin Pumping Cement
1000
365
566
First Hesitation Squeeze
1035
550
650
Second Hesitation Squeeze
1120
550
620
Final Pressures After Coil Squeeze
650
1250
620
6/30/2019
After Swapping GLV with Slickline
450
0
550
Please let me know if you would like any additional information
Thanks,
William R. Long
Staff CTD Engineer
ConocoPhillips
907-263-4372 (office)
281-723-6000 (cell)
William R LongpConocoPhillips.com
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Friday, June 28, 2019 9:38 AM
To: Long, William R <WilIiam R LongCa@conocophillips.com>
Subject: [EXTERNAL]RE: KRU 111-01 (PTD 200-156, Sundry 319-041) Perf and Squeeze Interval (319-041)
William,
After the squeeze procedure, was a pressure test conducted on the squeeze perfs? Was any pressure seen on the OA?
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria Loepp cbalaska.00v
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Victoria Loepp at (907)793-1247 or Victoria LoepDfalasko aov
From: Loepp, Victoria T (CED)
Sent: Friday, June 14, 2019 9:40 AM
To: Long, William R<William.R Long@conocophillips.com>
Subject: RE: KRU 111-01 (200-156) Sundry Perf and Squeeze Interval (319-041)
William,
The change outlined below is approved. Please include this approval with your copy of the approved sundry.
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria LoeppCrDalaska oov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Victoria Loepp at (907)793-1247 or V_ctoria Loepo@alaska aov
From: Long, William R <William R Lone@conocophillips.com>
Sent: Friday, June 14, 2019 8:56 AM
To: Loepp, Victoria T (CED) <victoria loepp@alaska.aov>
Cc: Ohlinger, James J <James.J.Ohllneef conocophillips.com>; Eller, J Gary <J.Garv.Eller@conocophillips.com>; Starck,
Kai <Ka L >
Subject: KRU 111-01 (200-158) Sundry Perf and Squeeze Interval (319-041)
Victoria,
We are preparing to do the pre -CTD work on KRU 111-01 prior to CTD operation into the West Sak formation. This
operation was previously approved in Sundry #319-041. We would like to reduce the planned 7" perforation interval for
squeezing to 20' and the cement volume to 10 bbls. (3690'— 3710' MD) After closer review of the operation we have
concerns with the cement gravity swapping with the larger perforation interval originally proposed. Please let me know
if any further documentation of this minor revision is required.
Thanks,
William R. Long
Staff CTD Engineer
ConocoPhillips
907-263-4372 (office)
281-723-6000 (cell)
William.R.Long(@ConocoPhillips.com
1R -01B
Present Well Condition
fix M mae
131' MD
8s135ismlwne el <381'
o. seta vD
r
155
oft H B473 MO (2880)
r cm,d FW6ahwvNeyH
H 9000 PNMnnee Small
UeeEe aaN mgYn] N4pgv
(tBpP3.
Arctic Pack cement m well
above the Wert Sak
tvrmatlon
P' ClHa dcul go shalkN3
enough to see arctic Pack
cement Bestguessu AP
cemen[gaes downto
MW MO (te. x500' ND
stove WSakk
Npple i491' 0..8]5' ID3
xo RBAW.2 imnbeh N 3833.
2913)
ro compMllon r1008)
TOP of 3-1/2" SIB- =08 H 8028' kb
cement `]]90'vla ark M9053 MO
CBL of] -6-00
1R -01B
Workover Setup
Oro l(OP MN MD.
a3Be'asm, NLae3
MIC
West 5ak for]natlon
(t p`320D'ND)
RWO will set a ]" CIBP and run
new ax^ completion
Post-RWO will Pert, set.
whipstock. And ae ueem wo Cr.
Seuee2e Perfs:. 3640'-3710' 0.8
6'
W HJ0 shoe
129 MD
J-55 5ewe 04381
M0.3888'ND
byi
Ba155
tlow M M 84)9' MD QWO)
DBL ot&0.65 ehewetl by of
menl e18080'. Pedametl emeY
e9ussxe eller mpnp wlnmw
(IB9a).
drnrlop peter
Top of 3-112"
cement `7790'vla
CBL of 2.6-00
1R -01B
Present Well Condition
Arctic Pack cement is well
above the West yak
formation
7' Cats don't go shallow
enough to see art¢ pack
cement Best guess a AP
cement goes down to
±3000' MD p e t5W ND
above WSakl
mppleat483(1875-0)
.4"M 6229(10-2813]
er 2AP P,t" at 6243'
CTD Gmpleton (2008)
2318'8ner by at Ms' MD
ipnock .18053' MO
IR -01B
Proposed P&A
(n Try m re.. TT pecker 8
avann M 72"M
(2) ()pen ma Mi or leg Nncn
TRANSMITTAL LETTER CHECKLIST
WELL NAME: K R U, IR -10
PTD: -g' 19— G q 3
Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: V,ADd y - a K RI VP_je!�! POOL: 4Jes+ 5 a J< i I
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing well Permit
LATERAL
No. , API No. 50 -
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50- -
-� from records, data and logs acquired for well
name on emit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals throw h tar et zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Comnanv Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
J
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150
PTD#:2190930 Company Con000Phillips Alaska Inc Initial Class/Type
Well Name: KUPARUK RNt7�R-101 Program DEV Well bore seg
DEV/ PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑
Administration
1
Permit fee attached . .................... . ... . . . . _
NA
2
Lease number appropriate----------------------- --- - ----- - --------
Yes
3
Unique well name and number _ _ _ _ _ _ _
Yes
4
Wall located in defined pool. ....... ..
Yes
5
Well located proper distance from drilling unit boundary
Yes
6
Well located proper distance from other wells... _ _
Yes
7
Sufficient acreage available in drilling unit _ _ _ _ ..
Yes
8
If deviated, is. wellbore plat included _ ..
Yes
_ Directional_ plan view and wellbore profile included.
9
Operator only affected party.. _ _ _ _ _
Yes
10
Operator has appropriate. bond in force .. _ _ _
Yes
11
Permit can be issued without conservation order. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes
Appr Date
12
Permit can be issued without administrative approval _ _ _ _ _
Yes
13
Can permit be approved before 15-day wait.. _
Yes
DLB 6/24/2019
...... ..
14
Well located within area and strata authorized by Injection Order # (put 10# in Comments) (For.
NA.
15
All wells. within 114. mile area of review identified (For service well only). _
NA_ _
16
Pre-produced injector; duration of pre-production less than 3 months _(For service well only)
NA. .
17
Nonconven. gas conforms to AS31.05.03QG..1.A),([,2.A-D) _ _ _ _ _ _ _ _ _ _ _
NA..
18
Conductor string. provided.....................................
NA..
_ _ _ Conductor set for KRU 1R-01
Engineering
19
Surface casing. protects all known USDWs . . . . . . . . ..... ..... .......
NA _
_ _ _ _ _ Surface casing set for KRU 1R-01.
20
CMT. voladequate to circulate on conductor & surf. csg .. . . ............ . _
NA
_ _ _ _ Surface casing set and fully cemented
21
CMT.voladequate to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
22
CMT_will cover all known productive horizons _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
No. _
.. .. Productive_ interval will be completed with. uncemented slotted liner.
23
Casing designs adequate for C, T, B &_ permafrost............ ...............Yes
.......
24
Adequate tankage or reserve pit _ _ _ _ _ _ _ _ _ _ ..
Yes .
_ _ _ Rig has steel tanks; allwaste_to approved disposal wells.
25
If a_re-dril[, has a 10-403 for abandonment been approved .... . . ...... . ........
Yes
_ _ _ _ _ PTD 200-156, Sundry 319-042
26
Adequate wellbore separation proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes
_ _ _ _ Anti-collision, analysis complete; no major risk failures
27
If diverter required, does it meet regulations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA
Appr Date
28
Drilling fluid_ program schematic & equip list adequate_ _ _ _ _ _ ....
Yes
_ _ _ Max formation pressure is 1524 psig(8.8 ppg EMW ); will drill w/ 8.4 ppg and maintain overbal w/ MPD _ .....
VTL 7/2/2019
29
BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ..
Yes
30
BOPE press rating appropriate; test to (put prig in comments)_ .. .............
Yes
_ _ MPSP is 1185 psig; will test BOPS. to 2500.psig........
31
Choke. manifold complies w/API RP-53 (May 84). ... _ ... _
Yes
32
Work will occur without operation shutdown. _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes
................ ......
33
Jsj presence of 1125 gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
No. _
.... .
34
Mechenical.condition of wells within AOR verified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA.......
.
35
Permit can be issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ _ _ ___ _ _ ___ _ _
Yes .......
IR-101 is the first West Sak Pool wellon.lR_ pad.. No WF historyon the pad.
Geology
36
Data presented on potential overpressure zones _ _
Yes __________
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___________
Appr Date
37
Seismic analysis of shallow gas zones_ _ _ _ _ ... _
NA_
DLB 6/24/2019
38
Seabed condition survey (if off-shore) ........... .......................
NA...
...... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _________
_. _ --
39
Contact name/phone for weekly_ progress reports [exploratory only] . . ........... . . . .
NA_ _
_ _ _ _ .. _
Geologic Engineering Public
Commissioner: Date: Commissioner: Date Commissioner Date
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