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C
WELL LOG TRANSMITTAL #905760400
To: Alaska Oil and Gas Conservation Comm.
Attn.: Natural Resource Technician
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RECEIVED
AUG 0 5 2019
RE: Multi Finger Caliper: 217-07 Ll -01 AOGCC
Run Date: 6/9/2019
219075
3 105 9
July 19, 2019
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
2F-07 Ll -01
Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom
50-029-21076-61
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Fanny Sari
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-275-2605
FRS_ANC@halliburton.com
Date: ff 0111
Signed:
BATER
a GE company
REGOVL
JUL 17 20;1)
AOGCC
Date:
July 16, 2019
Abby Bell
AOGCC
333 West 71h Ave, Suite 100
Anchorage, Alaska 99501
2 190 75
31 x,00
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):
2F-071-1
2F -07L1-01
(1) 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.
Harvey Finch, Baker Hughes, Wellplanner
Harvey.Finch@BakerHughes.com
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REL;LF'YLU
STATE OF ALASKA JUL 1 1 2019
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT ANIS
1a. Well Status: Oil El , Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑
20AAC 25.105 20AAC 25.110
GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions:
1b. Well Class:
Development Fv] Exploratory ❑
Service ❑ Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Aband.: 6/1112019
14. Permit to Drill Number/ Sundry:
219-075 -
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded:
6/612019
15. API Number:
50-029-21076-61-00 °
4a. Location of Well (Governmental Section):
Surface: 565' FSL, 1570' FEL, Sec 28, Tl lN, R9E, UM
Top of Productive Interval: IV E "W
1578' FSL, 751' FEL, Sec 27, T11. R9$ UM
Total Depth:
1517' FNL, 4991' FWL, Sec 27, T1IN, R9E, UM
8. Date TD Reached:
6/8/2019
16. Well Name and Number:
KRU 2F-071.1-01
9. Ref Elevations: KB: 127
GL: 96 BF:
17. Field / Pool(s):
Kuparuk River Field/Kupamk Rivier Oil Pool
10. Plug Back Depth MD/TVD:
1185016012
18. Property Designation:
ADL 25657, ADL256r'S
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 517658 • y- 5949448 • Zone- 4
TPI: x- 523752 y- 5950478 Zone- 4
Total Depth: x- 524204 y- 5952664 Zone- 4
11. Total Depth MDTFVD:
• 11984/6016 °
19. DNR Approval Number:
LONS 82-177
12. SSSV Depth MD1TVD:
1953/1832
20. Thickness of Permafrost MD/TVD:
144511163
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:
. 913016024 '
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/Caliper Log
23. CASING, LINER AND CEMENTING RECORD
WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT
CASING FT TOP BOTTOM TOP BOTTOM PULLED
16 62.5 H-40 31 109 31 109 24 150sx Cold Set II
95/8 36 J55 31 3727 31 2889 121/4 104 0 sx AS III, 710sx Class G
7 26 J-55 2 6 9051 26 6251 8 112 300sx Class G, 250sx AS[
2 3/8 4.6 L-80 8415 11850 5819 6012 3 Slotted Liner
24. Open to production or injection? Yes 0 No ❑
If Yes, list each interval open (MDlrVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
SLOTTED LINER
8416-11850 MD and 58195012 TVD.... 6/10/2019
COMPLETION
D T
(/ �q
VER, IFI�D
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
31/2 8434 840515812
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes ❑ No 2]
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED
27. PRODUCTION TEST
Date First Production:
6/26/2019
Method of Operation (Flowing, gas lift, etc.):
GAS LIFT
Date of Test:
7/9/2019
Hours Tested:
17
Production for
Test Period
Oil -Bbl: Sas-MCF:
741 t 536
Water -Bbl:
3631
Choke Size:
176
Gas -Oil Ratio:
722
Flow Tubing
Press. 136
Casino Press:
117
Calculated
24 -Hour Rate
Oil -Bbl:
525
Gas -MCF:
Water -Bbl:
2572
Oil Gravity -API (Corr):
NIA
Form 10-407 Revised 5/2017 V7-1- 1'13111
CONTJNUED ON PAGE 2
RBDMS!±4w JUL 16 2019
Submit ORIGINIAL only
ll
/�r
16111111'r16111116111111'rlira'/°r
28. CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No Q
If Yes, list formations and intervals cored (MDfTVD, 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
1445
1163
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
9127
6024
information, including reports, per 20 AAC 25.071.
Formation @ TPI -Kuparuk A5
TD
11984
6016
Formation at total depth:
Ku aruk A
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,
paleontolooical report. production or well test results, per 20 AAC 25,070,
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: James Ohlin er Contact Name: Shane Germann C�
Authorized Title: Staff CTD Engineer Contact Email: Shane.Germannt7a.comcom
Authorized Contact Phone: 263-4597
Signature: Date: % �/
INSTRUCTIONS
General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Form 10-407 Revised 5/2017 Submit ORIGINAL Only
2F-07 Final CTD
16" 62# HJO shoe
(Q 109' MD
95/8" 36# J-55 shoe
Q 3727' MD
C4 -band pedb
8554' - 8564' MD
A5/4/3 sand perfs
8638' -8657' MD
8674' - 8728' MD
8778'-878 'MD
T'26# J55
shoe @ 9051MD
updmd: rwuy-mrs sic
3-1/2" OTIS OLP SSSV (Locked Out 1/19/2000)
3-1/2" 9.3# J55 EIDE 8id Tubing to surface
3-1/2" Camco MMG gas IBt mandrel at 2068', 4749', 68071, 8374'
MO
Baker PBR @ 8391' MD (3" ID)
Baker FHL packer @ 8405' MD (3" ID)
D-Mpple at 8421" MD (milled to 2.80" ID)
3-1/2" Baker SOS @ 8433' MD
F2F-*7LI,639'' M10.639'MD
billet 0 9130' MDlotted liner
2F -07U-01
TO = 11,982' MD
SOL =11,850'MD TOL=8415'MD
2-3/8" slotted her, jet cut at top
KUP PROD WELLNAME 2F-07 WELLBORE 2F_07
ConoeoMill)ps Well Attribuf Max Angle 1 TD
lJ��� IO Name We11W1e FPV11Wl We110ore Status IVI) MD (r. Act atm (nk8)
NeSke. inC. KUPARUK RI VER UNIT 15002 001 PROD 588 2,400.00 90550
COKED OUT
3FLT. lucent.: 1e a PM
Last Tag
v.lnrw w+ni.lmletwtll
Annotation dined" ED I End Dam Weplwre Last Mosey
Last Tag: RKE 8.]960 5I18I20t9 2F-0) con.,
Last Rev Reason
.............................E.............
XANGEn: Zi.b
..
Annotatia,
End Data
WelfEore Last MOE By
ev Reason: HIGH EXPA NWHI .NIPPLE MILL D
52312019
2F-D7cOndije,
OUT, UPDATE TAG
Casing Strings
C -P, Description OD lint 1131s) 1YU(B) Set Depth Mi Ser Deptn 11 VDT.. -Len 11_. Gnea. Top Th -d
CONDUCTOR 16 1506 31.0 109.0 1000 62.50 H40 WELDED
cONOUcTGR3IS_Id.O
Casing Description oD lint IDtln) rop(hN BI SMDepelrMel sA Depen(1VDI... NNLen IL_Gratle Tap Tnread
SURFACE 9518 876 309 3)26.8 2,8880 36.00 J-55 BTC
Caing DescriptionoD lint wtin) top(KKBl annDepelrtKel Ser OWA lrv0)... WVLena I.r.e Top Puss.
PRODUCTION ] 528 260 910510 6,250.8 2600 J-55 BTC
Tubing Strings
SAEETsvm 1AApo
1.1ne, Description SeMg Ma... mpp Top (nNa) ser ln.. set lrvml... Wr01JM) Grade TOEConnmticn
1P,
.
TUBING 3112 2.99 23.6 8,434.1 5.831.5 9.30 J-55 EUEBrd
Completion Details
top rvD Tnp Md Normal
TOP Me) di Imm core ON
GAs uFr; $CCfi.S
23.6 236 0.07 HANGER FMC GEN II TUBING HANGER 3.500
1,953.0 1,832.1 42.90 SAFETY VLV OTIS OLP V (LOCKED V )CLTRA K U 2.812
PRESSURE
0,391.0 5,8026 M67 PBR BAKER PER 3.000
SUREACE anearMS-
74049 5,8120 48.03 PACKER BAKER FHL 3.000
8421.3 5.8229 4801 ITPPLE- CAMCO DNIPPLE, MILLED OUT TO 2.80"ON 5-16-19 2.800
GAS LIFT: 4,M4
MILLED OUT
8433.3 5,830.9 4800 SOS CAM EAR UT -TTL ELMO 8240'ON SWS PPROF 2.992
812912004
GAS LIFT: 6.aT4
Other In Hole (1Nireline retrievable plugs,
valves, pumps, fish, etc.)
TOPma)
Tep(WD) ropinel
(RKB) ri
Des
can gentians
to (in)
8,645.0
5,9]2.8 4]]
WHIPSTOCK
RTOWA LU E A N 52)2019
0000
GAa urr; e.n44
E
WHIPSTOCK, TOW AT 8645, 0" ORIENTATION, TIED
INTO K1 MARKER AT 8428' MO
Pett e.avTp
g, gp.0
6,1402 46.5]
FI H
2 KOT KICK SPRINGS LOST VIE WIDE, 3.5"LONG3232011
0.000
8,8940
6,142.9 4657
FISH
Original Completion PKR Left in hole during workover 102/19.4
PACI(ER: 9.4M8
Perforations & Slots
snoo
Das
iop(rvD)
Eft"MO)
IshomM
NIPPLE - MILLEOOUi', 8.431)
Uat LATERAL: sagas
11.8904- .-0]
r
TOP(MB)
Brm5e
(M(B)
LinkedZoneB,e
Dare
I
Can
8,554.0
8,5640
5.911.0
5,918.5
6,91
�, UNI
1 98]
4.0 IPERF
RIFTyp
IkOv haser, IE
EnelJ.
sos: e.4axa
8,65]0
5,960.1
5,980.8
A-5, 2F-0)
4I t
40 IPERF
90deg, Phasing,
,638.0
Schlum, Casing Gun
86]40
8,]280
5,992.3
8,028.9
A-0, 2F-0)
ILi984
40 IPERF
Oder. hang,
Schlum. Casing Gun
Ivsae ess4.oase4o_�
8.]840
6,063.1
6,06].
A3.2F-0)
M 1
401PERF
90 deg. Phasing,
,]]8.0
Schlum, Casing Gun
Mandrel Inserts
m
XTop (ND) Wive Iape, Pa131xe TRO Run
Top IRKe) IMS) IMke MIYeI OD 9n1 Sary Type Tape, IMI laq Run Dago Cont
1 2,065.5 1,9121 IMMH FMHO i GAS LIFT GLV BK RAN 1,255.0 3rJ 1
4,749.4 3,520.1 MMH FMHO 1 GAS LIFT OV BK 0.2111 00 313 Ot
680744,8031 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 211] 019
IPERF,S.WaO WO
4 8,3744 5,]916 MMH FMHO 1 GAS LIFT DMY 0.0 12 1 Gm1'd
WXIPSTOSa, e;Si
Eeln
r par
repair
Notes: General & Safety
End Dam
I Annotation
7122019
lout,: View Schematic wl Alaska Schemaric10.0
IPERF, 66>448.MO6
IPERF:STia L87s .per
FISH', a.W].D
FI.Keis 0
PRODUCTION', MOa0510
KUP PROD WELLNAME 2F-07 WELLBORE 2F -07L1
✓ Well AHribuf Max Angle T -7 -0 -
It TD
ConocoPhilhps Field Name we-RAPuuPo WenMre Si N Mon, as elm trtNB)
Alaska, Im, KUPARUK RIVER UNIT 60029210J660 PROD 634 MY.
10,6300
].I, TON3018 Y14Zl PM
Last Tag
VaNalxlviu oargav0
Annabtion
D"grogKal End Cap
I WNIOore
lmlMas By
Last Tag:
2E -01L1
1jenran
Rev Reason
..........__.................................. _Last
RAN ER.8
Annodibr
End pace
WeIIWrc
last Mad Oy
REV REASON CTD LATERAL
102U19
21-UILI
Small
Casing Strings
Casing Description o01m1 lO nnl
LI LATERAL 23/0 1.99
-,(.a) set Eagan lnNal n., Pep, vN.) wuLan 11-. Grede
9.129.9 10,639.0 4.60 L-80
roPTEreae
STL
Notre: Geneml & Safety
End Drip.
Annofatbn
A2/2nd
ISIC w/ Alaska Schemat
NOTE. Vaw SCM1e ic10.0
M CONDUCTOR; 31 0-IW.O
64FETY VLV; I.M.
. 11Fr:Z0665
SURFACE: ME-S.RRS—
WS UFT:4,iie.0
WS OFF. B.Nl.4
GAS LIFT. S.9]u
PSR: A.1. -
PURER
PU RER', 8.400.6
II
NIPPLE-MILIEO OUT; 6.4213-
.421JJ1
JMUTERALAre 9-
SDs: AM3
(PERF;8ESU0 1AN0
IPERF;S838OaAR.0
PRODUCTION; ffiLL0,G51 C
II
LILATERAL:VME-IDARRO
uperations Summary (with Timelog L vpths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
Ena lime
Dur (hr)
Phase
Op Cade
A Ay Code
Time P -T-%
operation
(MKS)
End DeP (MKB)
6/1/2019
6/1/2019
8.80
MIRU
MOVE
MOB
P
Trucks here @ 15:00. Pull off well,
0.0
0.0
14:00
22:48
Jeep up, rig down cellar. MOB to 2F
6/1/2019
6/1/2019
0.50
MIRU
MOVE
MOB
P
Arrive at 2F -Pad, drop jeeps
0.0
0.0
22:48
23:18
6/1/2019
6212019
0.70
MIRU
MOVE
MOB
P
Begin spotting sub
0.0
0.0
23:18
00:00
6/2/2019
6/2/2019
2.80
MIRU
MOVE
MOB
P
Complete spotting sub & pits, lay
0.0
0.0
00:00
02:48
plywood for sow (in front of pits), lay
mats
6/2/2019
6/2/2019
2.20
MIRU
MOVE
RURD
P
Begin RU check list, drop stairs,
0.0
0.0
02:48
05:00
secure landings, MU hard-line, begin
moving shop & 1/2 -Way House
6/2/2019
6/212019
4.50
MIRU
WHDBOP
NUND
P
Begin NU BOP, continue RU checklist.
0.0
0.0
05:00
09:30
RIG ACCEPT @ 05:00, Run BOP
BORE scope. Check tree bolts. two
loose bolts on each lower flange
6122019
62/2019
1.00
MIRU
WHDBOP
BOPE
P
Get shell test, Valve cm here service
0.0
0.0
09:30
10:30
tree
6/2/2019
6/2/2019
4.00
MIRU
WHDBOP
BOPE
P
Start full initial BOPE test. Test
0.0
0.0
10:30
14:30
witness waived by Jeff Jones,
AOGCC. Test complete. No fail /
passes
6/2/2019
612/2019
1.20
MIRU
WHDBOP
PRTS
P
Make up no=te. stab on injector.
0.0
0.0
14:30
15:42
Circulate coil. Line up and lest inner
reel valve, inner reel iron, and packoff
6/2/2019
62/2019
0.30
MIRU
WHDBOP
PULD
P
Unslab injector. Pull apart UQC and
0.0
0.0
15:42
16:00
install floats. Check motor high side
and houseing bend @ V
6/2/2019
6/2/2019
1.30
MIRU
WHDBOP
PRTS
P
PT Tiger tank & PDL's to 2500 PSI,
0.0
0.0
16:00
17:18
clear floor, PJSM
6/2/2019
6/212019
1.70
PRODi
WHPST
PULD
P
Crew change, PJSM PD BHA#1
0.0
77.0
17:18
19:00
Window Assembly (1.0° AKO
Weatherford motor, NS 2.80" String
Reamer, & 2.80" NS Long Shank Mill),
check pack -offs, MU to coil, tag up,
set counters
612/2019
6/2/2019
1.70
PROD1
WHPST
TRIP
P
RIH wl BHA #1 holding 1 -for -1 returns
77.0
8,425.0
19:00
20:42
6/2/2019
62/2019
0.30
PROD1
WHPST
DLOG
P
Difficulty logging K1, very eralic, pull
8,425.0
8,230.0
20:42
21:00
up to log HRZ, PUW = 39K,
6/2/2019
6/2/2019
0.20
PRODt
WHPST
DLOG
P
Log HRZ for +23' correction
8,230.0
8,285.0
21:00
21:12
6/2/2019
6/2/2019
1.30
PRODi
WHPST
DISP
P
Continue RIH, flush well -bore w/
8,285.0
8,600.0
21:12
22:30
seawater, displace to milling fluid,
Gose EDC
6/212019
6/212019
0.20
PRODi
WHPST
DLOG
P
Obtain SBHP: MID -bit = 8600,
8,600.0
8,600.0
2230
22:42
TVD sensor= 5910.9', pressure=
3802 psi, EMW = 12.37 ppg
6/2/2019
6/2/2019
0.10
PROD1
WHPST
TRIP
P
Continue RIH, RIW = 12K, dry tag WS
8,600.0
8,645.6
22:42
22:48
pinch point at 8645.4' (TOWS -8641),
PUW = 38K, bring up pumps, RBIH
6/2/2019
6/3/2019
1.20
PROD1
WHPST
WPST
P
Milling from 8645.6', FS = 766 psi @
8,645.6
8,647.3
22:48
00:00
1.9 bpm, CWT = 10K, WOB =.6K,
annular = 3808 psi, WHIP = 482 psi
Rerturns fell off to 1.7 bpm out at
8646.2', began holding 1 -for -1
Page 1/13 ReportPrinted: 6114/2019
Uperations Summary (with Timelog LGpths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Start Time
6/3/2019
EM Terre
6/3/2019
Phase
PROD1
Op CO a
WHPST
Activity Code
WPST
Time PJA
P
OPOMWO
Milling from 8647.3', CWT = 12.2K,
(8KB)
8,645.6
EM DePM MKB)
8,647.3
00:00
02:24
WOB = 2.2K, annular = 3815 psi,
WHP = 454 psi, pump = 4616 psi,
r2.40
BOW Called at 8648.7'
Continue control milling, CWT 12.7K,
WOB = 0.2K, pump = 4522 psi
6/3/2019
6/3/2019
PROD1
WHPST
MILL
P
String reamer ebds window, begin
8,647.3
8,670.0
02:24
04:48
pushing on it milling rat -hole, CWT
=10K, WOB = 3.21K
6/3/2019
6/3/2019
1.10
PROD1
WHPST
REAM
P
Perform reaming passes, HS X 2,
8,670.0
8,670.0
04:48
05:54
30R, 30L, & LS, Dry drift looks good.
RIH tag TD
Service ODS PDL swivel
6/3/2019
6/3/2019
1.40
PR0D1
WHPST
TRIP
P
POOH, PUW=29K. Stop @ 8627 open
8,670.0
65.0
05:54
07:18
EDC
72019
6/312019
1.40
PRODt
WHPST
PULD
P
Tag up and space out. PUD BHA #1.
65.0
0.0
07:18
08:42
Lay down tools. Mill out @ 2.79 no go.
String reamer out @ 2.80
6/3/2019
613/2019
0.70
PROD1
DRILL
CTOP
P
M/U Nozzle. Flush stack and rig. Blow
0.0
0.0
08:42
09:24
down Mico Motion
6/3/2019
6/3/2019
1.20
PRODt
DRILL
PULD
P
PJSM. PD BHA #2 from pre loaded
0.0
72.1
09:24
10:36
PDL. Make up to coil trek and surface
test. Check pack offs. Tag up and set
mounters
6/3/2019
6/3/2019
1.50
PROD1
DRILL
TRIP
P
RIH BHA#2, EDC open
72.1
8,225.0
10:36
12:08
6/3/2019
6/3/2019
0.30
PRODI
DRILL
DLOG
P
Log formation tie in for -11.5'
8,225.0
8,280.0
12:06
12:24
6/3/2019
6/3/2019
0.30
PROD1
DRILL
TRIP
P
Continue in hole. Slop @ 8627 shut
8,280.0
8,671.0
1224
12:42
EDC, PUW=33K. Continue in. Clean
pass through window tag up @ 8671
6/3/2019
6/3/2019
1.60
PROD1
DRILL
DRLG
P
8671', Drill ahead, 1.8 BPM @ 4014
8,671.0
8,760.0
12:42
14:18
PSI FS, BHP=3856. Couple of hard
spots in build. Do not have surveys.
Estimate AVG DLS @ 49°
6/3/2019
6/3/2019
1.70
PROD1
DRILL
TRIP
P
Call EOB, Pump 5 X 5 sweeps. Trip
8,760.0
64.5
14:18
16:00
out. Slow down and jet 7"
6/3/2019
6/3/2019
1.00
PRODt
DRILL
PULD
P
Tag up and space out. PJSM PUD
64.5
0.0
16:00
17:00
BHA#2
6/3/2019
6/312019
1.00
PROD?
DRILL
PULD
P
Late decision to run Ironsitle motor
0.0
0.0
17:00
18:00
since we would not be kicking off
billet. Lay down Inteq motor. Ironside
motors delivered one is at .03°
basically straight. Motor we picked up
is .8°
6/312019
6/3/2019
1.60
PROD1
DRILL
PULD
P
PD BHA #3 with .8° Ironside motor,
0.0
80.0
18:00
19:36
agitator, and RB HYC A#3. Make up to
coil and surface test. Complete
stripping on. DD confering with Geo
on plan. Might need to change angle.
Plan worked out. Tag up and space
out
6/3/2019
6/3/2019
2.80
PROD1
DRILL
TRIP
P
Trip in hole. A 500'shal5wtest
80.0
8,220.0
19:36
22:24
agitator. Pressures high 1.9 BPM @
5490 PSI pump pressure. Diff @
1815. New agitator is in string. Consult
town Trip back to surface. Prep to
PUD. Do some research on previous
Irondide motor runs. Within 350 PSI of
noted pressures on 3M-26. Suspend
PUD. Trip in well
Page 2113 Report Printed: 6/1412019
Vperations Summary (with Timelog L.pths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log seen Depth
Stan Time Ed Time Zoo F Pltete ActiNly Code Time PJ4 Operation (ftKB) End Depth MKS)
8,220.0 8,299.0
6/3/2019 6/312019 0.10 PR DLOG P Log formation for -11.5'
22:24 22:30
6/3/2019
613/2019
0.30
PROW
TRIP
P
Continue in well, 8585 PUW=35K
8,299.0
8,670.0
22:30
22:48
6/372019
6!3/2019
0.10
PROD1
VDRILL
DLOG
P
Log RA marker in 8649,
8,670.0
8,685.0
22:48
22:54
TOWS=8642.2, BOW=8648.7
6/3/2019
6/3/2019
o.10
PROD1
TRIP
P
Continue in well
8,685.0
8,760.0
22:54
23:00
6/312019
6!412019
1.00
PROD1
DRLG
P
8760', Drill, 1.9 BPM @ 5400 PSI FS,
8,760.0
8,922.0
23:00
00:00
BHP=3877. Differential 1730 PSI off
bottom, RIW=9.SK, DHWOB=1.9K,
swap to new mud system (at bit at
8862')drill to 8922', avg ROP = 162
fph
Slow drilling beginning at -9404', ...
6/4/2019
6/4/2019
2.10
PROD1
DRILL
DRLG
P
Drilling from 8922', CWT = 8.9K, WOB
8,922.0
9,203.0
00:00
02:06
= 1.9K, annular = 3907', WHP = 460
psi, pump = 5603' psi, stall at 9002',
PUW = 35K, pump 5 x 5 sweeps
Oscillate drill when possible (limit to
-160 fph)
Lost communication w/ HOT (al
9170'), PU off bottom, PUW = 41 K,
trouble shoot & reset tool, go back to
drilling
6/4/2019
6/4/2019
0.20
PROD1
DRILL
WPRT
P
Wiper up -hole to EOB, PUW = 39K
9,203.0
8,760.0
02:06
02:18
6/4/2019
6/4/2019
0.20
PR0D1
DRILL
WPRT
P
Wiper in-hole, RIW = 10.6K
8,760.0
9,203.0
02:18
02:30
614/2019
6/4/2019
2.00
PROD1
DRILL
DRLG
P
Drilling from 9203', FS = 1720 psi @
9,203.0
9,425.0
02:30
04:30
1.9 bpm, CWT =8.9K, WOB=1.6K,
annular = 3889 psi, WHIP = 561 psi,
pump = 5803 psi, gamma wrapped at
9255', stall at 9266', lower ROP
beginning at 9404' w/Ankerite in
samples, PUW = 38K
Continued issue w/ HOT, losing
gamma, pump 5x5 sweeps, drill to
9425', PUW = 38K
6/4/2019
6/4/2019
2.60
PROM
DRILL
TRIP
T
POOH to swap out tools, grab missed
9,425.0
80.0
04:30
07:06
surveys, pull through window at 10 fph
& 0.5 bpm, jog 7" casing, open EDC
`Pre -load DS PDL w/ drilling BHA
6/4/2019
6/4/2019
0.90
PROM
DRILL
PULD
T
PJSM, PUD BHA #3, inspect injector,
80.0
0.0
07:06
08:00
motor looked & blew down good
visually, bit came out a 2-1
6/4/2019
6/4/2019
1.20
PROM
DRILL
PULD
T
PD BHA#4 L1 Drill Assembly #2 (new
0.0
80.0
08:00
09:12
Inteq tools, same agitator, same
motor, & RB A3 bit)
6!4/2019
6/4/2019
1.60
PROD1
DRILL
TRIP
T
RIH w/ BHA#4, shallow test tools,
80.0
8,225.0
09:12
10:48
pumping 1.84 bpm, dip = 1450 psi,
pump = 4980 psi
6/4/2019
6/4/2019
0.30
PROD1
DRILL
DLOG
T
Log HRZ for -11'Corrector
8,225.0
8,273.0
1048
11:06
1
6/4/2019
6/4/2019
0.60
PRODt
DRILL
TRIP
T
Continue RIH
8,273.0
9,425.0
11:06
11:42
Page 3113 Report Printed: 611 412 01 9
' uperations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
smrt Dept,
Start Time
EM Time
Der(M
Phase
Op code
Activity Cafe
DRLG
Time P -T -X
P
Optttan
Drilling from 9425, CWT = 10.5K,
(III®)
9,425.0
EM Depth (011<13)
9,588.0
6/4/2019
6/4/2019
3.80
PROD1
DRILL
WOB = 3K, annular = 3983 psi, WHIP
11:42
15:30
= 600 psi, pump = 5066 psi, lower
ROP with Ankerite in samples,
reduced rate in effort to reduce
vibrations, effective, bring rate back t
1.9 bpm
6/4/2019
6/4/2019
1.40
PROD1
DRILL
DRLG
P
Drilling from 9588', CWT = 8.2K, WOB
9,588.0
9,825.0
15:30
16:54
= 1.6K, annular = 4015 psi, WHP =
547 psi
6/4/2019
6/4/2019
0.30
PRODt
DRILL
WPRT
P
PU Wt 40 k Itis PUH on wiper #1
9,825.0
9,031.0
16:54
17:12
6/4/2019
6/4/2019
0.30
PROD1
DRILL
WPRT
P
RBIH RIH Wt 5 k Ibs-0.39 bbis
9,031.0
9,825.0
17:12
17:30
cuttings returned on wiper
6/4/2019
6/4/2019
3.60
PROD1
DRILL
DRLG
P
PU to check parameters post crew
9,825.0
10,225.0
17:30
21:06
change. PU Wt 40 k lbs, RBIH, CT
RIH wt 6.6 k lbs,
CT 5214 psi @ 1.89 bpm in and 1.89
bpm out, FS diff 1389 psi. BHP 4049
psi, Holding 12.6+ppg EMW @ the
window, 12.9 ppg @ the bit. WH 557
psi, IA 924 psi, OA 46 psi. OBD, CT
Wt 2.9 k Itis, WOB 2.7 k lbs,
**10,087', Lost 0.1 bpm, losses slowly
healed
6/4/2019
6/4/2019
0.30
PROD1
DRILL
WPRT
PU Wt 40 k Ibs PUHon wiper #2
10,225.0
9,425.0
21:06
21:24
6/4/2019
6/4/2019
0.40
PROD1
DRILL
WPRT
RBIH - 0.40 bbis cuttings returned on
94250
10,225.0
21:24
21:48
wiper
6/4/2019
6/5/2019
2.20
PROD1
DRILL
DRLG
rp
CT 5218 psi @ 1.9 bpm in and 1.90
10,225.0
10,480.0
21:48
00:00
bpm out, FS diff 1413 psi. BHP 4062
psi, WH 554 psi, IA 896 psi, OA 50
psi. OBD, CT Wt 4 to -2 k Ibs. WOB
1.2 - 0.8 k lbs, - ROP limited to 160
ft/hr while rotating.
10,441', U, CT Wt 44 k lbs - stacking
out when RBIH, shaker unloading
cuttings
BOBD, free spin diff 1379 psi
10,447' PU 40 k lbs
6/5/2019
6/5/2019
0.20
PROM
DRILL
DRLG
P
Drill ahead
10,480.0
10,499.0
00:00
00:12
6/5/2019
615/2019
1.20
PROD?
DRILL
WPRT
P
PU for Geo wiper, 42k lbs
10,499.0
8,637.0
00:12
01:24
Pull wiper to window for tie in early to
shelter Geo wiper. Pump 5x5 and
chase to the window.
Slight neg WOB tug while pulling
through the window.
6/5/2019
6/5/2019
0.20
PROD1
DRILL
WPRT
P
Jet the 7" while pumping a bottoms
8,637.0
8,225.0
01:24
01:36
up.
6/5/2019
6/5/2019
0.30
PRODt
DRILL
DLOG
P
Tie into HRZ for+ 1.5' correction.
8,225.0
8,620.0
01:36
01:54
6/5/2019
6I5l2019
0.20
PROD1
DRILL
DLOG
P
RIH to 8620.48 CTMD 15 .37' TVD,
8,620.0
8,620.0
01:54
02:06
measure BHP, trap 3971 psi - 12.9
ppg
Bleed off once and pressure built back
in 3 minutes to 3970 psi - 12.9 ppg
6!512019
6/5/2019
1.10
PROD1
DRILL
TRIP
P
PU, Ct Wl 35 k Ibs -RBIH to bottom
8,620.0
10,499.0
02:06
03:12
0.65 bbis cuttings returned on long
wiper
Page 4113 Report Printed: 611412019
Operations Summary (with Timelog Lvpths)
®
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depm
Stan Tme
End Time
Ox (ht
Phase
Op Code
Activity Code
ORLG
Time P -T -x
P
Operation
CT 5350 psi @ 1.88 bpm in and 1.83
(MB)
10,499.0
End Depth(nKB)
10,606.0
6I5I2019
615/2019
1.50
PRODi
DRILL
bpm out, Free spin diff 1451 psi, WH
03:12
04:42
685 psi, IA 794 psi, OA 52 psi. BHP
4116 psi, targeting 12.8 ppg @ the
window. CT Wt 1.4 k lbs, WOB 1 A k
lbs
10,519', PU Wt 36 k Ibis
10,590', PU Wt 45 k lbs
6/5/2019
6/5/2019
1.90
PROD1
DRILL
DRLG
P
Drilling, from 10,606', annular= 4133
10,606.0
10,638.0
04:42
06:36
psi, WHP = 645 psi, pump = 5312,
PUW = 38K from 10,638', stack
weight RBIH at 10,628', stall at
10,638', PUW = 45K
6/5/2019
6/5/2019
0.30
PROD1
DRILL
WAIT
T
Fluid leaking past o -rings on QTS, PU,
---TO —6380
8,620.0
06:36
06:54
determine path forward
Plan Forward: PUH to window, allow
TO sweeps to exit at surface, shut
bag, obtain SBHP, await KWF, RBIH
to 9715' (deepest TVD of well), kill
well, POOH, replace o -rings
6/5/2019
6/5/2019
—4 60
PROD1
DRILL
GOND
T
At window, shut bag, obtain SBHP,
8,620.0
8,620.0
0654
11:30
MD = 8620', TVD sensor = 5922',
annular = 3986 psi, EMW = 12.94 ppg
Prep pits & move fluids, attempt to
increase KWF to 13.15 ppg (68 sacks
of K -Formate), allow SBHP to
continue during this time (12.95 ppg),
Continue weighting up KWF, working
to get past 13.05 ppg, get KWF to
13.07 ppg, town decision made to call
TD at 10,638' (due to increasing
pressure & lower than expected
resistivities)
6/5/2019
6/5/2019
6/51212:3
1.00
PROD1
DRILL
TRIP
P
Open bag, begin pumping 13.07 ppg
8,620.0
9,715.0
11:30
KWF, PUW = 39K, log RA for +1'
correction, RIH, stack weight at 9466',
complete RIH to 9715'
6/5/2019
6/5/2019
1.80
PR0D1
DRILL
DISP
P
POOH to 7183, PUW = 41K, KWF at
8,620.0
7,183.0
1230
14:18
surface, paint flags at 9150.26' , flow
check well, well is flowing, fluid out
needle valve measures 12.9 ppg by
hydrometer, hydrocarbons in returns,
pump addional 10 bbl
6/5/2019
6/5/2019
1.50
PROD1
DRILL
DISP
P
Pump additonal 10 bbl KWF in attempt
7,183.0
7,183.0
1418
15:48
to clean up column, flow check, well is
dead
Obtain SBHP, MD = 7151',
TVD sensor = 4982.92, annular =
3372 psi, EMW = 13.02 ppg, drops to
12.96 ppg.
6!5/2019
6/5/2019
0.60
PROD1
DRILL
COND
Transfer 13.13 ppg KWF from truck,t8,629.0
0
8,629.0
1548
16:24
build LRP, pump down to bit
6/5/2019
6/5/2019
—C)60
PRODt
DRILL
TRIP
RIH, stack weight at -8650',
9,700.0
1624
17:00
attempting 10L & 10 R no success,
attempt 20R with no success, pass
through window on 9th attempt at 5
fpm
6/5/2019
6/5/2019
2.30
PROD1
DRILL
DISP
Lay in 15 bbl 13.13 ppg LRP, follow
9,700.0
79.0
17:00
19:18
by KWF to surface (pumping pipe
discplacement)
Paint While Flag @ 7080'
Good 13.1 ppg KW returned to
surface
Page 5/13 Report Printed: 611412-0 1 9
operations Summary (with Timelog Dupths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Depth
Start Time End rime our (hr) Phase Op Code AcWtY COOS Time P -T -x operatw (nKa) End Depth MKa)
6/5/2019 6/5/2019 0.30 PROD1 DRILL OWFF Parkat surface and flowchck -good, 79.0 79.0
19:18 19:36 PJSM
6/5/2019
6/5/2019
1.00
PROD1
DRILL
PULD
POP off, QTS O-ring
79.0
0.0
19:36
20:36
delaminate,pictures in well file on S -
drive. Check pipe for wear and record
wall thickness 0.230" in all 4 axis. LD
BH#4.
Iron horse motor has -1/2" gap in
transmission to bit box, was - 1/4"
when it went in the hole.
6/5/2019
6/5/2019
0.40
COMPZI
CASING
PUTS
Prep floor for running liner, PJSM
79.0
0.0
20:36
21:00
6/5/2019
6/5/2019
2.20
COMPZ1
CASING
PUTS
Pick up L1 completion, 45 joints 4.6
0.0
1,509.1
21:00
23:12
#/fl slotted liner, Mixed R2/R3. Total
length of liner 1499.70' over a solid
bullnose under a linter top billet, LOA
1509.10', Kick while running liner drill.
6/5/2019
6/6/2019
0.80
COMPZI
CASING
PULD
PU BHA# 5, Ll liner running
1,509.1
1,553.3
23:12
00:00
assembly.
6/6/2019
6/6/2019
0.10
COMPZ1
CASING
PULD
P
Continue to PU BHA# 5, L1 liner
1,553.3
1,553.3
00:00
00:06
running assembly, check pack offs -
good.
6/6/2019
6/6/2019
1.40
COMPZI
CASING
RUNL
P
RIH W 1-1 completion
1,553.3
8,570.0
00:06
01:30
6/6/2019
6/6/2019
0.10
TOMPZ1
CASING
DLOG
P
1
Tie into white window flag for -16.8'
8,570.0
8,553.2
01:30
01:36
1
correction.
6/6/2019
6/6/2019
1.00
COMPZI
CASING
RUNL
P
Set WOB to -4.4 k lbs, PU Wt 39 k lbs,
8,553.2
10,640.0
01:36
02:36
RIH
S/D multiple times starting @ 10,557'
to TD PU's 44 k, Land liner on depth,
S/D -6 k CT Wt, on line with the pump
@ 1.5 bpm, diff pressure up to 1018
psi, PU Wt 34 k lbs, WOB -3 k lbs,
liner gone. lost 10 bbls KW on the trip
in
6/6/2019
6/6/2019
1.60
COMPZ1
CASING
TRIP
P
Park and reset counters. PU 34 k,
10,640.0
76.0
02:36
04:12
POOH
TOL 9,130'
Lost 5 bbls KW on the trip out
6/6/2019
6/6/2019
1.00
COMPZI
CASING
PULD
P
LD BHA #5 over a dead well, bit came
76.0
0.0
04:12
05:12
out 1-2
6/6/2019
6/6/2019
1.00
PROD2
STK
PULD
P
PU BHA#6, L1-01 sidtrack and drilling
0.0
80.0
05:12
06:12
lalteral assembly. Stider. 0.80° AKO
motor w BH P104 cutters, check pack -
offs, MU to coil, tag up, set counters
6/6/2019
6/6/2019
1.60
PROD2
STK
7RIP
RIH w/ BHA #6, shallow lest tools, can
80.0
8,235.0
06:12
07:48
pump through tools though unable to
capture decent screen from
transducer (pressuring up with KWF in
hole & coil), will retest on bottom, once
displaced to drilling fluid
6/6/2019
6/6/2019
0.30
PROD2
STK
DLOG
P
Log HRZ for -15' correction
8,235.0
8,307.0
07:48
08:06
6/6/2019
6/6/2019
0.90
PROD2
STK
DISP
P
Displace well to used drilling fluid,
8,307.0
8,635.0
08:06
09:00
PUW = 31 K, close EDC, shallow test
tools, capture screen from transducer
6/6/2019
6/6/2019
0.40
PROD2
STK
TRIP
P
Continue RIH, clean through window,
8,635.0
9,126.3
09:00
09:24
dry tag TOB at 9127.5', PUW = 31 K,
come up to 1.9 bpm, RBIH to KO billet
616/2019
6/6/2019
0.go
PROD2
STK
KOST
P
Tag TOB pumping at 9126.3', FS =
9,126.3
9,127.3
09:24
10:18
862 psi at 1.9 bpm, pump = 5056 ps,
annular = 4201 psi, WHP = 563 psi, 1
fph for 1 It, dp 880 psi
Page 6113 Report Printed: 6114/2019
Uperations Summary (with Timelog (Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start wpm
Sten Time EMTime Our(hr) Phew Op Cotle ANNry Code Time P -T -X Operation Mite) End Depth9,1 (8.3
P Milling at 2 fph for 1 ft 9,127.3 9,128.3
6/6/2019 6/6/2019 0.60 PROD2 STK KOST
1018 10:54
616/2019
6/6/2019
0.30
PROD2
STK
KOST
P
Milling at 3 fph for 1 ft
9,128.3
9,129.3
10:54
11:12
6/6/2019
6/6/2019
0.60
PROD2
STK
KOST
P
Increase to 9 fph for 5 ft
9,129.3
9,134.3
11:12
11:48
6/6/2019
6/6/2019
0.50
PROD2
DRILL
DRLG
P
Begin pushing on it, pump 5x5
9,134.3
9,165.0
11:48
12:18
sweeps, CWT = 8K, WOB = 1 K,
annular = 4096 psi, WHIP = 438 psi,
pump = 5055 psi, PUW = 32K
6/6/2019
6/6/2019
0.20
PROD2
DRILL
TRIP
P
Dry drift billet area up & down, clean
9,165.0
9,165.0
12:18
12:30
6/6/2019
6/6/2019
2.00
PROD2
DRILL
DRLG
P
Drilling, FS = 830 psi @ 1.87 bpm,
9,165.0
9,364.0
12:30
14:30
CWT = 9.3K, WOB = 1.3K, annular =
4111 psi, WHIP = 462 psi, pump =
5201 ps, IA = 476, OA = 50 psi, avg
ROP = 100 fph
Begin pumping new mud system, new
mud at the bit 9203'
6/6/2019
6/6/2019
1.50
PROD2
DRILL
DRLG
P
Drilling, CWT = 6.6K, WOB = 2.6K,
9,364.0
9,441.0
14:30
16:00
annular = 4107 psi, WHIP = 700 psi,
pump = 4774 psi, rate out a bit erratic,
swap to choke B, PUW = 48K from
9441, stall at 9441', PUW = 40K
6/6/2019
6/612019
1.20
PROD2
DRILL
DRLG
P
Drilling, CWT = T51K, WOB -=1 3,
9,441.0
9,521.0
16:00
17:12
annular = 4094 psi, WHIP = 705 psi,
pump = 4773 psi
6/612019
6/6/2019
0.30
PROD2
DRILL
WPRT
P
PU Wt 34 k lbs, PUH on wiper #1
9,521.0
8,700.0
17:12
17:30
6/6/2019
6/6/2019
0.30
PROD2
DRILL
WPRT
P
RBIH, set down@ 9,425', 3.4 k WOB
8,700.0
9,521.0
17:30
17:48
plus - 100 k CT Wt, PU clean and
continue in hole
- 0.3 bbls cutting returned on the trip.
6/6/2019
6/6/2019
2.70
PROD2
DRILL
DRLG
P
CT 4610 psi @ 1.9 bpm in and 1.9
9,521.0
9,930.0
17:48
20:30
bpm out, free spin diff 776 psi, WH
668, IA 650, OA 55 psi.
OBD, CT 4 k lbs, WOB variable to 2 k
lbs,
Average ROP over section 151 Whir
6/6/2019
6/6/2019
0.30
PROD2
DRILL
WPRT
P
PU Wt 36 k lbs, PUH on wiper #2
9,150.0
20:30
20:486/6/2019
6/6/2019
0.40
PROD2
DRILL
WPRT
P
RBIH, RIH Wt 9.2 to 7 k Ibs, hole
9,930.0
20:48
21:12
clean - 0.45 bbls cutting returned on
the trip.
r9,930.0
616/2019
6/7/2019
2.80
PROD2
DRILL
DRLG
P
CT 4746 psi @ 1.9 bpm in antl 1.9
10,170.0
21:12
00:00
bpm out, free spin diff 836 psi, WH
635, IA 798, OA 57 psi.
OBD, CT 2.8 to -3 k lbs, WOB variable
to 2 k lbs,
Average ROP over section 85 fUhr
6/7/2019
6/7/2019
1.90
PROD2
DRILL
DRLG
P
OBD, CT 2.8 to -3 k lbs, WOB variable
10,170.0
10,360.0
00:00
01:54
to 2 k lbs, BHP 4162 psi,
10266', PU Wt 41 k lbs, CT weight
declining, pump 5x5
Average ROP over section 100 Whir
6/7/2019
6/7/2019
0.60
PROD2
DRILL
WPRT
PPU
Wt 38 k lbs - PU hole on long
10,360.0
8,625.0
01:54
02:30
wiper to window - window clean
6/7/2019
6/7/2019
0.40
PROD2
DRILL
CIRC
P
Jet the 7", Circulate bottoms up PU Wt
8,625.0
8,630.1
02:30
02:54
35 k lbs.
Page 7113 Report Printed: 6/14/2019
operations Summary (with Timelog Depths)
2F-07
,.
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start oepm
Start Time
End Time
Our (hr)
Phase
Op Code
A ify Code
Tune P -T -X
OpenAlon
(eKB)
End Oepm (aKB)
6/712019
6/7/2019
0.20
PROM
DRILL
DLOG
P
Park@ 8630'/5929' CTMDfND and
8,630.1
8,630.1
02:54
03:06
measure BHP
time(min) P(psi) EMW(ppg)
initial 4093 13.27
1 4034 13.09 - bleed to
4005 psi
2 4005 12.99 - bleed to
3992 psi
3 3992 12.95
5 4000 12.97
6/7/2019
6/7/2019
0.10
PROM
DRILL
DLOG
P
Tie into the RA tag for a+1.5'
8,630.1
8,691.8
03:06
03:12
correction
6/7/2019
6/712019
0.70
PROM
DRILL
TRIP
P
RBIH, billet clean.
8,691.8
10,360.0
03:12
03:54
6/7/2019
6/7/2019
2.60
PROD2
DRILL
DRLG
P
CT 4800 psi, @ 1.89 in and 1.88 out,
10,360.0
10,603.0
03:54
06:30
free spin diff 818 psi, BHP 4183 psi,
targeting 12.95 ppg EMW at the
window. CT Wt -3 k lbs, WOB 1.9 k
Itis, PUW = 41 K from 10,603
617/2019
6/7/2019
1.00
PROD2
DRILL
DRLG
P
Drilling, CWT= -5.6K, WOB = 1K,
10,603.0
10,690.0
06:30
07:30
annular = 4199 psi, WHP = 620 psi,
pump = 4928 psi, pump 10x10 beaded
sweeps (1 ppb beads in HiVis), beads
hit the bit at 10,652'
6/712019
6/7/2019
0.80
PROD2
DRILL
DRLG
P
" Begin CR drilling targeting 150 fph
10,690.0
10,790.0
07:30
08:18
(Difficulty maintaining consistant ROP)
CWT = 1.6K, WOB = 1.3K, annular =
4235 psi, WHP = 634 psi, pump =
5058 psi
6/7/2019
6/7/2019
0.30
PROM
DRILL
WPRT
P
Wiper up -hole, PUW = 38K
10,790.0
9,940.0
08:18
08:36
6/712019
617/2019
0.40
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW = 7K
9,940.0
10,790.0
08:36
09:00
6/7/2019
6/7/2019
1.30
PROD2
DRILL
DRLG
P
"" CR drilling targeting 250 fph, unable
10,790.0
10,908.0
09:00
10:18
to maintain consistant ROP
FS = 790 psi @ 1.88 bpm, CWT = 5K,
WOB = 1.3K, annular = 4262 psi,
WHP = 609 psi, pump = 5099 psi,
PUW = 45K from 10,899'
6/7/2019
6/7/2019
1.10
PROD2
DRILL
DRLG
P
" CR drilling targeting 100 fph, pump
10,908.0
11,008.0
10:18
11:24
5x5 (1% 776 / 1 % LoTorq) —_71_,008.0
6/7/2019
6/7/2019
1.40
PROD2
DRILL
DRLG
P
" CR drilling targeting 200 fph
11,189.0
11:24
12:48
Pump tubed 5z5 sweeps, BHA wiper,
PUW = 42K, –65' drilled & then
difficulty maintaining 200 fph ROP,
PUW =41K
6/7/2019
6/7/2019
0.30
PROD2
DRILL
WPRT
P
Wiper up -hole, PUW =41K
11,189.0
10, 264.0
12:48
13:06
617/2019
6/7/2019
0.50
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW=2K
10,264.0
11,189.0
13:06
13:36
6/7/2019
6/7/2019
0.50
PROD2
DRILL
DRLG
P
" CR drilling targeting 150 fph
11,189.0
11,231.0
13:36
14:06
CWT = 0.3K, WOB = 0.5K, annular =
4280 psi, WHP = 594 psi, pump =
5008 psi, pumping sweeps as
required, prep to pump new mud
system
Page 8113 Report Printed: 6/14/2019
Operations Summary (with Timelog Lepths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start oeptn
Start Time
End Time
our (hr)
Phase
Op Code
Acdvfty Code
Time P -T -X
Operation
(ttKB)
End Depth (flKB)
6/7/2019
617/2019
1.50
PROD2
DRILL
DRLG
P
Slide drilling to drop inclination, pump
11,231.0
11,242.0
14:06
15:36
tubed sweeps, difficulty with weight
transfer, work to get drilling, multiple
PU's, dropping rate working to bottom,
pull BHAwiper, PUW = 40K, pump 10
bbl tubed pill, unable to get drilling,
begin pumping new mud system
6/7/2019
6/7/2019
0.50
PROD2
DRILL
DRLG
P
New mud at the bit at 11,242', CWT =
11,242.0
11,274.0
15:36
16:06
-4.6K, WOB = 1.3K, annular = 4273
psi, WHIP = 598 psi, pump 4640 psi,
stall at 11,274', PUW = 45K, bore
pressure spiked to 7600 psi, unable to
pump w/o pressuring up pump/bore,
6200 psi at 0.5 bpm
617/2019
6/7/2019
3.20
PROD2
DRILL
TRIP
P
POOH to inspectlreplace tools, dip =
11,274.0
65.0
16:06
19:18
3145 psi @ 0.8 bpm, unable to
increase rate without pressuring up,
open EDC in OH, POOH, jog 7",
continue to surface, park @ 500',
dose EDC, Pressure up BHA @ 0.3
bpm, immediately pressured up to
2500 psi, open EDC for PUD,
coontinue out of hole, bump up.
6/7/2019
6/7/2019
1.30
PROD2
DRILL
PULD
P
PUD BHA# 6. Blow air and water
65.0
0.0
19:18
20:36
through both the motor and the strider
agitator. No obvious issues.
"OTS O -rings cut badly, appears as
if stack is of centered up exactly, had
issues with quick union on PDL
because of alignment.
6/7/2019
6/7/2019
1.00
PROM
DRILL
CTOP
P
Reconfigure tools with one PDL, all
0.0
0.0
20:36
21:36
new coil trek
6/7/2019
6/7/2019
1.20
PROD2
DRILL
PULD
P
PD BHA V, 0.6° AKO inteq motor
0.0
78.0
21:36
22:48
with NOV agitator and BH RB
Dynamus bit.
6/7/2019
6/8/2019
1.20
PROD2
DRILL
TRIP
P
RIH, park @ 500', close EDC, test
78.0
5,922.0
22:48
00:00
agitator. Coil trak briefly flashed a
code, missed position, then flashed to
closed. Shallow agitator test good, diff
of 954 psi @ 1.83 bpm strong surface
vibrations felt in the ops cab.
6/8/2019
0.40
PROD2
DRILL
TRIP
P
Continue to RIH W BHA
5,922.0
8,235.0
00:24
6/8/2019
0.20
PROD2
DRILL
DLOG
P
Tie into the HRZ for a -14' correction.
8,2350
8,276.5
00:366/8/2019
F618/2019
DRILL
DLOG
P
Park@ 8600'/5910'CTMD/TVD and
8,276.5
8,600.0
00:48
measure BHP
time(min) P(psi) EMW(ppg)
initial 3991 12.98
1 3986 12.97
aO.20M
2 3984 12.96
3 3983 12.96
5 3982 12.96
6/8/2019
6/8/2019
D2
DRILL
TRIP
P
PU Wt 35 k lbs, confine to RIH.
8,600.0
11,274.0
00:48
01:54
Window and billet clean.
Page 9113 Report Printed: 611412019
Uperations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
smn o.pih
Sfen Time
End TM
Dur (hr)
Phase
op Code
Adiviy Cafe
Time P -T -x
Operation
(NCB)
EM DepM UMB)
6/8/2019
6/8/2019
3.00
PROD2
DRILL
DRLG
P
CT 4770 psi @ 1.88 in and 1.88 out,
11,274.0
11,503.0
01:54
04:54
Free spin diff 895 psi, BHP 4220 psi,
targeting 12.95 ppg EMW, WH 700
psi, IA 654 psi, OA 61 psi
CT Wt -4 k lbs, WOB 400 - 800 lbs
11,324' PU Wt 42 k lbs
11,365' returns fell to 1.26 bm then
healed to 1.8 bpm.
11,419' PU Wt 39 k lbs
11,442' PU Wt 41 k lbs
11,503' PU Wt 45 k lbs
Average ROP 76.3 ft/hr
6/6/2019
6/8/2019
2.40
PROD2
DRILL
DRLG
P
CT 4830 psi, 1.88 born in and 1.88
11,503.0
11,674.0
04:54
07:18
bpm out, free spin diff 895 psi, BHP
4239 psi, WH 699 psi, IA 709 psi, OA
62 psi, OBD, CT Wt -4 k lbs, WOB 0.7
k lbs, pump sweeps
6/8/2019
6/8/2019
1.50
PROD2
DRILL
WPRT
P
Wiper up -hole to window, PUW =44K,
11,674.0
8,445.0-
07:18
08:48
pump additional sweeps, clean past
billet & window, jog 7", ciruclate
bottoms up
6/8/2019
6/8/2019
0.40
PROM
DRILL
DLOG
P
Obtain SBHP, MD = 8463.7',
8,445.0
8,445.0
08:48
09:12
TVD sensor= 5818.8', annular=
3931 psi, EMW = 12.99 ppg
Lock -out reel, adjust wash -pipe
centralizer clamp
6/8/2019
6/8/2019
1.30
PROD2
DRILL
WPRT
P
Wiper in-hole, log RA for+2.5'
8,445.0
11,674.0
09:12
10:30
correclon, clean past window & billet,
RIW =
6/8/2019
6/8/2019
2.00
PROM
DRILL
DRLG
P
CR drilling, FS = 950 psi @ 1.8 bpm,
11,674.0
11,793.0
10:30
12:30
CWT = -4.2K, WOB = 1 K, annular =
4252 psi, WHP = 668 psi, pump =
4873 psi, avg ROP = 59 fph
6/8/2019
6/8/2019
0.90
PROD2
DRILL
DRLG
P
CR ddlling, CWT= -3.5K, WOB=1K,
11,793.0
11,831.0
12:30
13:24
annular = 4276 psi, WHP = 641 psi,
pump = 5020 psi, stall at 11,831',
PUW = 50K, difficulty working to
bottom, pull 500' wiper
6/8/2019
6/8/2019
0.40
PROD2
DRILL
WPRT
P
500'wiper, PUW =42K
11,831.0
11,831.0
13:24
13:48
6/8/2019
6/8/2019
3.20
PROD2
DRILL
DRLG
P
Drilling, CWT = -0.7K, WOB = 1.21K,
11,831.0
11,947.0
13:48
17:00
annular = 4306 psi, WHP = 617 psi,
pump = 5282 psi PUW = 53K @
11,876', BHA wiper from 11,877',
pump 5x5 sweeps, drill to TO of
12,000', pump sweeps
6/8/2019
6/8/2019
1.60
PROD2
DRILL
DRLG
P
Drilling, CWT= -4.3K, WOB =0.75K,
11,947.0
11,982.0
17:00
18:36
annular— 4300 psi, WHP = 620 psi,
pump = 5308 psi
6/8/2019
6/8/2019
1.30
PROD2
DRILL
WPRT
P
PU Wt 41 k lbs, TD called early after
11,982.0
8,631.0
18:36
19:54
faulting out of zone. - chase TD
Sweep to bit.
Paint EDP flag, White, @ 11,978'
Billet and window both clean
6/8/2019
6/8/2019
0.60
PROD2
DRILL
WPRT
P
Jog the 7" while pumping a bottoms
8,631.0
8,433.0
19:54
20:30
up.
6/8/2019
6/8/2019
1.50
PROM
DRILL
WPRT
P
POOH on swab wiper
8,433.0
64.0
20:30
22:00
6/8/2019
6/8/2019
1.00
PROM
DRILL
PULD
P
PUD BHA# 7, POP off, test AnTech
64.0
0.0
22:00
23:00
stabbing guide. So so results.
Continue to PUD BHA#7. QTS O -
rings only slightly cut.
Page 10/13 Report Printed: 6/14/2019
Uperations Summary (with Timelog [Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Stan Time
End Time
our (hr)
Phase
Op code
Ma city Code
Time P -T -X
Operation
(ftm)
EN Depth (f1K13)
6/8/2019
6/8/2019
0.50
PROD2
DRILL
BOPE
P
Function test the BOPE - Good
0.0
0.0
23:00
23:30
6/8/2019
6/9/2019
0.50
PROD2
DRILL
-(5T--OP
P
PU motor and strider agitator from
0.0
0.0
23:30
00:00
BHA# 6 (pulled for high differential
pressure)
6/9/2019
6/9/2019
1.10
PROD2
DRILL
CTOP
P
PU motor and strider agitator from
0.0
0.0
00:00
01:06
BHA# 6 (pulled for high differential
pressure) - Stab onto stump, pump
through tools @ 1.8 bpm, CT pressure
came up to 4372 psi and stabilized t
4250 psi. Popped off, dropped off
Inteq motor, stabbed back on with only
strider agitator, pump through strider
@ 1.80 bpm, CT pressure came up to
4312 psi and stabilized at 4357 psi.
Un Stabbed injector and LD tools.
6/9/2019
6/9/2019
0.60
PROD2
DRILL
PULD
P
PU HES Gamma and 24 arm caliper,
0.0
18.9
01:06
01:42
lubricate in stack against closed
master. Check pack offs, good.
6/9/2019
6/9/2019
1.60
PROD2
DRILL
TRIP
P
RIH with BHA# 8, caliper tool.
18.9
8,140.0
01:42
03:18
6/9/2019
6/9/2019
0.20
PROD2
DRILL
DLOG
P
Tie into HRZ for -1 9.5'correction
8,150.0
8,278.0
03:18
03:30
6/9/2019
6/9/2019
1.40
PROD2
DRILL
TRIP
P
PU Wt 35 k lbs. Continue to RIH,
8,278.0
11,933.0
03:30
04:54
whip stock clean in regards to CT Wt,
same with billet.
6/9/2019
6/9/2019
1.40
PROD2
DRILL
DLOG
P
Open arms, PU Wt 43 k lbs, PUH
11,933.0
8,700.0
04:54
06:18
logging caliper @ 40 ft/min.
6/9/2019
6/9/2019
2.40
PROD2
DRILL
TRIP
P
Close caliper arms, POOH w/ BHA #8,F72.0
18.0
06:18
08:42
PJSM
6/9/2019
6/9/2019
0.50
PROD2
DRILL
PULD
P
LD BHA #8
0.0
08:42
09:12
6/9/2019
6/9/2019
1.00
PROD2
DRILL
PULD
P
PD BHA #9 Well Kill Assembly (RES
72.0
09:12
10:12
tools from BHA *7, D331 slick -gauge
mill)
6/9/2019
6/9/2019
1.50
PROD2
DRILL
TRIP
P
RIH w/ BHA #9
8,230.0
10:12
11:42
6/9/2019
6/9/2019
0.50
PROD2
DRILL
DLOG
P
Log HRZ for -14' collection, PUW =
8,230.0
8,271.0
11:42
12:12
35K, close EDC
6/9/2019
6/9/2019
0.40
PROD2
DRILL
DLOG
P
Obtain SBHP, MD = 8631.6',
8,271.0
8,631.0
12:12
12:36
TVD sensor = 5935.35', annular =
3987, EMW = 12.92 ppg
6/9/2019
6/9/2019
1.80
PROD2
DRILL
TRIP
P
Continue RIH, stacked weight at
8,631.0
11,984.0
12:36
14:24
9447' (5 limes), attempt many TF's,
get through on 12th attempt at 40'R
@25 fpm, back ream once, RBIH at
DTF (50L), clean, confirm TO at
11,984', RIW = 5K at TD, PUW = 37K
MAD Pass: 9000'- 9100', 9350'-
19450', & 11,100' - 11,300'
6/9/2019
6/9/2019
3.60
PROD2
DRILL
DISP
P
Lay in LRP (built from drilling fluid) TO
11,984.0
85.0
14:24
18:00
to 10,100', 20 bbl LRP built from 13.0
ppg K -Formate, & 13.1 KWF to
surface. Paint flags @ 8371.9' and
4972.0'. Contiune out of hole.
6/9/2019
6/9/2019
1.00
PROD2
DRILL
RURD
P
Park, PJFM/flow check -good. Inspect
85.0
0.0
18:00
19:00
pipe, 0.216, 0.206, 0.207, and 0.212".
No observble flat spots. Some normal
wear back 13'. Will trim pipe on next
well. LD BHA# 9 over a dead well.
6/9/2019
6/9/2019
0.50
COMPZ2
CASING
PUTB P
Prep floor for running liner
0.0
0.0
19:00
19:30
Page 11113 Report Printed: 611412019
Operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Sten, Depm
Stan, Time
EndTm
Dur(hr)
Phase
Op Code
Actvfty Code
Tim P -T -X
Operation
(NCB)
End Depth (N®)
6/9/2019
6/10/2019
4.50
COMPZ2
CASING
PUTB
P
PU L1-01 completion, 111 joints
0.0
2,734.0
19:30
00:00
(3552.05') over a solid bull nose and
under a shorty, deployment sleeve.
LOA- 3559.38'
. on joint # 84 @ midnight
6/10/2019
6/10/2019
1.10
COMPZ2
CASING
RURD
P
Continue to PU Lt -01 completion, 111
2,734.0
3,559.4
00:00
01:06
joints (3552.05') over a solid bull nose
and under a shorty deployment
sleeve. LOA- 3559.38'
on joint # 84 @ midnight
6/10/2019
6/10/2019
1.10
COMM
CASING
PULD
P
PU BHA # 10, Lt -01 liner running
3,559.4
3,603.0
01:06
02:12
assembly, replace checks, stab
injector, check pack offs - good, bump
up, set counters.
6/10/2019
6/10/2019
3.80
COMPZ2
CASING
RUNL
P
RIH W L1-01 completion, Tie into
3,603.0
11,165.0
02:12
06:00
White window flag for -15.7', PU Wt
47 k lbs, Set WOB -14.99 k lbs.
RIH, S/D @ 11,097', PU Wt 52 k lbs,
WOB -20 k lbs, work liner down with
multiple set downs,
6/10/2019
6/10/2019
2.50
COMM
CASING
RUNL
P
Crew change, continue to attempt to
11,165.0
11,512.0
06:00
08:30
work liner past 11,165', PUH -200',
work to 11,177', work down to 11,396',
setting auto choke to 200 psi & bore to
-5000 psi, work to 11,512
6/10/2019
6/10/2019
2.00
COMPZ2
CASING
RUNL
P
Continue working liner to bottom, work
11,512.0
11,553.0
08:30
10:30
to 11,555', build & pump 30 bbl K -
Formate LRP, losses -137 bbl, unable
to make depth w/o pumping, keeping
-5000 psi bore pressure, reduce WHP
and rate to conserve KWF
6/10/2019
6/10/2019
0.70
COMM
CASING
RUNL
P
Continue working liner
11,553.0
11,553.0
10:30
11:12
6/10/2019
6/10/2019
0.80
COMPZ2
CASING
RUNL
P
Confer w/ town, park at 11,553', mix
11,553.0
11,553.0
11:12
12:00
50 bbl K -Formate LRP
" Coordinate w/ a -line for jet cutter
6/10/2019
6/10/2019
0.90
COMPZ2
CASING
RUNL
P
Pump LRP at 1 bpm to minimize
11,553.0
11,553.0
12:00
12:54
losses (0.65 bpm returns)
6/10/2019
6/10/2019
2.20
COMPZ2
7ffASING
RUNL
P
Attempt to work liner, unable to get
11,553.0
11,754.0
12:54
15:06
liner movinig pulling up to 78K multiple
times, squeeze away 5 bbl into OH,
attempt to move pipe, pop free, at
81 K, RIH to 11,715' & stack, get to
11,725', sgeeze away 5 bbl, continue
working liner to 11,754, bring on 83
bbl KWF
6/10/2019
6/10/2019
1.60
COMPZ2
CASING
RUNL
P
Confer wttown, park pipe, build 25 bbl
11,754.0
11,754.0
15:06
16:42
LRP (weight up), work liner
occasionaly awaiting LRP
6/10/2019
6/10/2019
2.30
COMPZ2
CASING
RUNL
P
Pump 25 bbl LRP, work pipe to
11,754.0
11,821.0
16:42
19:00
11,821', unable to make further down-
hole progress, release off liner per
plan
6/10/2019
6/10/2019
0.80
COMPZ2
CASING
RUNL
P
Attempt to log HRZ, latch back into
11,821.0
11,844.0
19:00
19:48
liner, fish moved down -hole, work pipe
to 11,844.5', TOL - 8285.16'
6/10/2019
6/10/2019
1.60
COMPZ2
CASING
TRIP
P
Release off liner, log HRZ for 0'
11,844.0
70.0
19:48
21:24
correction ,POOH
6/10/2019
6/10/2019
0.60
COMPZ2
CASING
PULD
P
PJ M, flow check, LD BHA#10
70.0
0.0
21:24
22:00
SLB a -line arrives as rig & spots up
6/10/2019
6/11/2019
2.00
COMPZ2
CASING
ELNE
P
PJSM, prep rig floor, begin RU a -line,
0.0
0.0
22:00
00:00
MU shives & tools
Page 12/13 Report Printed: 611412019
operations Summary (with Timelog bepths)
e
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
BIeM1 Depth
Slee Time
End Time
Dur (rhr)
Phase
Op Code
Activity Coda
Imre p -T -X
Operation
take)
End Depth (flKB)
6/11/2019
6/11/2019
0.50
COMPZ2
CASING
ELNE
P
Complete RU a -line & tools
0.0
0.0
00:00
00:30
6/11/2019
6/11/2019
4.00
COMPZ2
CASING
ELNE
P
RIH w/ e4ine & 1.68" jet cutter, tie in
0.0
8,393.0
00:30
04:30
and cut L1-01 liner @ 8415'
6/11/2019
6/11/2019
1.50
COMPZ2
CASING
ELNE
P
POOH W E -line.
8,393.0
0.0
04:30
06:00
6/11/2019
6/11/2019
0.50
COMPZ2
CASING
ELNE
P
RD E -line
0.0
44.0
06:00
06:30
6/11/2019
6/11/2019
1.00
COMPZ2
CASING
PULD
P
Prep floor to PU BHA 11, stab on,
0.0
44.0
06:30
07:30
bump up and set confers.
6/11/2019
1.40
COMPZ2
CASING
TRIP
P
RIH, lost 18 bbls KW on the trip in.
44.0
8,215.0
08:54
6/11/2019
0.20
COMPZ2
CASING
DLOG
P
Tie into the HRZ for-15'correction
8,215.0
8,249.409:06
r6111/201
6/11/2019
0.20
COMPZ2
CASING
TRIP
P
PU Wt 33 k lbs, RIH find TOL @
8,249.4
8,281.0
09:18
8281'. PU, -500 lbs WOB broke back
to-3651sb, CT Wt 33 k lbs.
RBIH, S/D 8280.5, PU 400 lbs WOB,
6/11/2019
1.50
COMPZ2
CASING
TRIP
P
POOH with fish - lost
8,249.4
174.0
09:18
10:48
6/11/2019
6/11/2019
0.70
COMPZ2
CASING
PULD
P
LD BHA #11
174.0
130.0
10:48
11:30
6/11/2019
6/11/2019
0.40
COMPZ2
CASING
PULD
P
LD 4 joints plus 1.41' cut stub -
130.0
0.0
11:30
11:54
6/11/2019
6/11/2019
0.50
COMPZ2
CASING
PULD
P
PU BHA# 12, circ BHA, time seawater
0.0
44.0
11:54
12:24
to nozzle W RIH
6/11/2019
6/11/2019
1.50
COMPZ2
CASING
PULD
P
RIH with circ BHA
44.0
8,220.0
12:24
13:54
6/11/2019
6/11/2019
0.20
COMP72
CASING
DLOG
P
Tie into HRZ for -14' correction
8,220.0
8,248.0
13:54
14:06
**Measure BHP of 3845 psi @
8260'/5588' MD/TVD - 13.2 ppg EMW
6/11/2019
6/11/2019
1.50
COMPZ2
CASING
DISP
P
POOH while Displacing well to
8,248.0
2,500.0
14:06
15:36
seawater,
6/11/2019
6/11/2019
1.50
DEMOB
WHDBOP
FRZP
P
Park while turning the coil over to
2,500.0
44.0
15:36
17:06
diesel. POOH while Freeze protecting
tubing to surface with 30 bbls of
diesel. Chase diesel out of coil with
seawater flush while pulling to surface.
6/11/2019
6/11/2019
1.50
DEMOB
WHDBOP
DISP
P
Bump up, space out. Final tubing
2,500.0
44.0
17:06
18:36
pressures T/110 = 1421/0/42 psi
6/11/2019
6/11/2019
1.00
DEMOB
WHDBOP
PULD
P
PUD and LD BHA, pull upper quick
44.0
0.0
18:36
19:36
float valves, flush stack and surface
lines, blow down stack and surface
lines
6/11/2019
6/11/2019
1.00
DEMOB
WHDBOP
RURD
P
Freeze protect tree, and bore -o -scope
0.0
0.0
19:36
20:36
stack, found 2-3/8" rams to be in
question.
6/11/2019
6/1112019
1.50
DEMOB
WHDBOP
RURD
P
Work on rig move check list, prep
0.0
0.0
20:36
22:06
cellar for nipple down, remove IA and
OAtranducers, unhook PUTZ, rig
down high pressure lines, prep rig for
move.
6/11/2019
6/11/2019
1.50
DEMOB
WHDBOP
NUND
P
Nipple down stack (BOPE)
0.0
0.0
22:06
23:36
6/11/2019
6/12/2019
0.41
DEMOB
WHDBOP
NUND
P
Check tree bolts, found loose bolts
0.0
0.0
23:36
00:00
(torque up)
"• RIG RELEASE @ 24:00 hrs
Page 13113 ReportPrinted: 611412019
ConocoPhillips
ConocoPhillips Alaska Inc_Kuparuk
Kuparuk River Unit
Kuparuk 2F Pad
2F -07L7-01
50-029-21076-61
Baker Hughes INTEQ
Definitive Survey Report
18 June, 2019
BA ER
t UGHES
EmmCany
ConocoPhillips
Comparry: ConocoPhillips Alaska Inc Kupamk
PmfeC: Kupamk River Unit
SM: Kupamk 2F Pad
Well: 2F-07
Wellborn: 2F -07L1-01
Design: 2F-071-141
Pmlect Kupamk River Unit, Nodh Shape Alaska, United States
Map System: US State Phone 1927 (Exact solution) System Data
Gee Datum: HAD 1927 (NAUCGN CONUS)
Map Zone: Alaska Zone 04
Well 2F-07
Conmolshlllips
Definitive Survey Report
Local CoaNlnaq Rahnnce:
MR 2F-07
TVD Reference:
2F-07 @ 127.00usR (2F-07)
MD Reference:
2F-07 @ 127.00ush (2F-07)
Norah Reference:
True
Survey Calculation Method:
Minimum CurvMum
Database:
EDT 14 Mesb Production
Well Position rW4 0.00 ush Nodhing:
rE1-W 0.00 cash Fasting:
Poaon. Uncenainry 0.00 at Wellhead Salience:
Mean Sea Level
21F-071.141
Using Well Relumncs Point
Using geodetic scale factor
5,949,"8.14usfl
Lffitude:
517,650.31 unit
Longlmde:
usfl
Ground Leval:
WMlbom
21F-071.141
Magnatks
Modal Name
Sample Data
Declination
(•)
BGGM2010
4nW2019
19.57
Design
2F-07LI-o1
Audit Notes:
Version:
10
Phase: ACTUAL
Tie On Depth:
9,120.86
Vertical Secti0n.
Depth From 4WD)
afMs
rEl-0f
lusm
(uau)
luanl
127.00
0.00
0,00
Dip Angle
1°)
8081
70° i6' 23.010 N
149- 51' 25.030 W
0.00 usfl
FIeM Shength
roe
57,411
6/182019 9:08 39AM Pape 2 COMPASS 500014 Budd BW
` ConocoPhillips, O
CO
nocoPhillips Definitive Survey Report
Company:
ConacoPhillips Alaska Inc_ Kupamk
Prelim
Kupamk Riwr Una
SM:
Kupamk 2F Pad
W W:
2F-07
Wan9ota:
2F4711-01
M IBn:
2F471141
survey Pm eam
Data
From
To
IuaS)
IuaM
Survey(Wellsom)
200.00
8,800.00
2F47 (2F-07)
8,642.00
8,732,17
2F471.1 MW INC (2F471.1)
8756.26
9,120.86
2F-0711 MMX)(2F-()71-1)
9,127.50
9,187.21
2F -01L1-01 MND-INC(2F-07L1-at)
9.216.47
11.956.35
21`-071.1-01 MM(2F-07L1-01)
survey
MD
Inc
Axl
TVD
TVDss
MWS
(uan)
V)
(1)
(uam
(USM
(use)
912086
8]79
10529
6,024.15
5,897.15
1,017.14
9.121.50
WA2
105.55
6.021.39
5,897,39
1.015.38
915T.N
9107
10350
6,@4.60
5,897.60
1.008.14
9,18721
93M
98.61
6,061.40
5,895.40
1.002.30
9,216.0
9350
85.69
6,021.57
5,09457
99024
9347.17
91.07
WAS
6,031119
5.89329
994.72
9377.27
Sam
92.41
6,01995
5,892.95
992.39
91066
saw
9184
6,01997
5.592.97
"I'M
9,336.63
6693
6910
6,7211.65
5,093..
So,M
9,366.01
Mai
06.49
6.mw
5.09550
94241
939144
0]83
83.38
6,o x8)
5,8%,94
994,91
9423.69
07.03
80.50
6.025.37
5,8953]
999,34
94572(1
69,14
7661
6,00828
5M,28
1004.25
9496.99
68.17
75.83
692699
5,Mew
1Worst
951175
06.65
73.76
602640
5,9(D.
1,016.90
9,549811
85.98
7112
603041
5,MAI
1020.32
9,57961
05.88
MM
603250
5,Mum
1,038.87
950009
87,51
65.66
6034.27
5,90727
105926
9W&V
0902
6045
603559
5808,59
1075.84
Local Coordinate Reference:
WO Reference'.
MD Reference:
hunt Reference:
Survey Calculation Method:
Database:
Tool Name
SEEKER MS
MW INC ONLY
MWDOWSG
MVICEINC ONLY
MWDOWSG
Map
MEI'm Non8in9
IUSM (ft)
6509.90 5,95047947
6.036.30 5,950,"nn
6,125,14 5.95047955
6,164.52 5 WMA05
6,18342 5,950460.78
6,213.89 5,95),457.34
6,243.89 5,95045506
6273.50 5,950,454.05
6,303.21 5950453.82
6,333.32 5959455.10
6.30.79 5,950.452.88
6,395.70 6,959462.36
6422.75 5,950.461:6
645178 5,950.42401
6481.44 5,950.482.14
6,511.23 5950491.84
6,539.42 5,850,502.25
6,566.73 5,955513.72
661TW 5am 539,40
WaH2F-07
2F-07@127,00uss(2F47)
2F47 ® 127.00..8 (2F47)
Thus
Minimum Curvature
EDT 14 Alaska Prop rohoa
Desclpsan
BNI Seeker mul ishot
MWDINC ONLY FILLER
OWSG MM - Standard
MWD-ING ONLY FILLER
ON5G MWD-StandaN
Survey
Stan Dam
1/12/2001
6142019
6152019
6192019
6110.2019
Map
Vertical
Seeking
DLS
Section Survey Tool Name
Ie)
1.11w)
Pp
523.745.20
1.34
1,017.14 MND MSG (a)
523,751.50
6.5o
101538 M NNC ONLY (4)
523.780 W
14.05
1,000.14 MN0.1NC ONLY (4)
57;809.45
1284
100238 MWD -INC ONLY (4)
523838.76
9.99
998.24 MWD MSG (5)
52388923
am
9948 MWO MSG (5)
523,69923
1378
99209 MWD MSG (5)
M.S.
277
99129 Man 05036 (5)
523,958.55
1301
991.05 emn, MSG (5)
523.988.66
8.64
892.20 MWDOWSG(5)
524.019.12
low
99491 MWDGWGG(5)
52405191
631
99934 MUD M93 (5)
634,07005
1050
1,00425 MMDOWSG(5)
52410707
998
1,010.84 MWDOWSG(5)
524,138]0
8.21
1,01690 MWD 05056(5)
524,166.46
a,"
10632 MMD MSG (5)
52410,.
9.95
1,038.87 MND MSG (5)
52422190
10.76
1,50038 MAT) MSG (5)
5N.2R.15
10,12
1,075.84 MND GWSG(5)
Survey
End Dab
61420 W
6152019
6192o19
611012019
Annotation
TIP
KOP
IntelPotatnCAzimuth
IntalPotatird zimuth
67192019 9:08'39AM Page 3 COMPASS 5000.14 Build BSD
Survey
ConocoPhiliips
ConocoPhillips
Definitive Survey Report
Co.,., Dpn..Phlllips Alaska lnc Kupamk
Local Co�orainate Reference:
lhe(12F-07
Prefect Kupamk River Unit
TVD Reference:
2F47 @ 127.ODush(2F-07)
Safe: Kuparuk 2F Patl
MD Reference:
2F47 @ 127.00ush(2F-07)
Wag: 2F-07
Noah Reference:
True
Wellbore: 2F-071141
Survey Calcination Methon:
Minimum CurvBWre
Daslgn: 2F-071141
Database:
EDT 14 Alaska Production
Survey
Annotation
gt%u O
6/18R019 9:08:39AM Pegs 4 COMPASS 5000.14 Bii1C 85D
Map
Map
Vertical
MD
Inc
Ael
TVD
NDSS
-NIS
-VJ
No
Easting
DLS
Section Survey Tool Name
(u511(
V)(
I'(
(usD(
(.on)
(use)
Joan)
(u51Q
I
Ih(
(h)
1-1100.)
(Ill
9200.63
an.
5730
6.035 Be
5,90669
1094.07
6647.22
5950.557 69
52430230
940
1,094.07 MID OWSG(6)
9)30.30
89.52
5415
6,03631
5,906.21
1,110.22
6,62124
5950.574.45
524,326]6
10.0
1110.22 MGM) OWSG(5)
9759.07
8951
5162
6,0845
5.909.45
1,128.62
6685.39
5,950.591.41
524,35037
&53
1128.62 KtM OWSG(5)
9,79 m
89.94
49.22
6.036.59
S..'s9
1,145.03
6,710.29
5,950.611.80
524,323.22
603
1,14602 MD
9,82000
90.12
46.59
6.0858
5.2cam
1, IST96
674086
5.950.MT9
524,395.24
606
1,167.96 MND OWSG(5)
9 B:A.19
a..
"Al
6,0832
5,600.37
1,180.80
626234
S.Mo 5 afi
54.412.12
7.47
1,189.08 MND M.(5)
also.
B9ee
41.50
6,05,6.23
5,900.8
121148
8,783.21
5.9WaTS41
524,432.99
985
1,211.0 MND MSG (5)
9,911211
0994
38.92
6,036.26
5903.8
123x82
6,80282
5,950,69665
524.49.54
850
1234.62 MNDOWW5)
9,940.95
08,99
36.90
6,036.54
5.900.54
1358.14
6831.10
5950,22116
53842576
750
1,250.14 MND MSG (5)
9,97151
88,25
33.82
6,03728
5,91028
1,28 .0
6638]2
5,950.747.11
52449337
10.36
1,28306 MAD MSG (5)
1002.,56
WG7
31.53
6.03SA4
5,91114
1,30.50
6,854.45
5.993,22150
524508.99
7.89
1,307.50 MND MSG(5)
10.MEM
8785
29.52
6,08.94
5.911.94
1.328.57
6.x6.89
5ax79269
52452139
620
1,38.57 MND MSG (5)
10,0024
80.80
22.19
6,04002
5913.02
1,36110
6,x4.46
5950825.26
524538.87
893
1.3151AO MND MSG (5)
10,09037
gl,n
26.27
6.0.19.80
5,91290
1,38640
6,89720
5.950.85058
5245515
loll
1,38640 MND MSG (5)
10,120.01
9228
24.00
6019.24
5.91V4
141221
6x928
59x,877.42
524.564.07
842
1,413.21 MWD MSG (5)
1015119
8223
2198
6,03724
5,91024
1,441.80
6,921.95
5.950.906.11
52457646
647
1,441.80 MWD MSG(5)
1018.,55
Sax
19.73
6,035.70
5,900,20
1,46928
6,93238
5,450933.53
5245x.54
709
1,46928 MWD MSG (5)
1021059
93.55
12.15
11033.91
5,90,91
1.49722
6,94182
5,&50962.00
524595.95
&62
1.492.22 MWD MSG (5)
10,24126
92.52
15.39
6032.28
59x20
1,522.12
6,950.45
59x,991.41
524604.46
6.66
1,47.12 MWD MSG (5)
1DVIA2
91.75
11.62
6,031.12
5.9417
1,556.12
880742
5.951,020.42
524611,41
1222
1,556.12 MWD MSG (5)
1032022
81.81
925
6x026
5.90)36
1,58474
6,962.92
5.95104905
52461605
710
1,58474 MWD MSG (5)
1032521
8200
6.91
6,029502
5,90242
1,609.89
6.9x.60
5,x102421
524,6381.@
11.18
1.609.89 MWD MSG (5)
1035602
91.63
4.83
15,.@0.46
5,901.46
1,64003
696970
5,951,104.35
524,623.45
802
1,64003 MWD MSG (5)
10.38562
93.78
2.84
6.x2.05
590006
1,669.52
6971.60
5.01 133.05
524,62536
989
1,66952 MWD MSG (5)
1041521
93.09
359,84
602505
588005
1,699.03
6,972.32
5,951,163.36
524,625.05
1014
1,6W03 MWD MSG (5)
10,4045
9292
35778
60219
588.53
1,n4.22
697184
5.xllee &1
524625.39
9.10
1,72422 MWD MSG (6)
10,470M1
89.39
353.70
6,omim
5.895.93
1.753.87
6,x9.65
5851218.19
524623.13
1708
1.253.82 MWDOWSG(5)
10.50061
9203.
352.02
6022.56
Bens Se
1,28404
69089
5,951248.34
524.619.8
1040
1,78404 MWD MSG (5)
1053054
93.22
MOM
6021.19
5894.19
1813.58
696123
5,951277.86
524,81052
760
1,813.58 MWD MSG (5)
1056523
9135
3213
601980
5.892.80
1.84755
6,954.37
6,961 311.81
74.60705
999
1.80.55 MO
1059551
9249
34100
6018.4
5891.79
1.8768
6,946.M
5,951.34110
52460004
10.78
1,876.65 MND OWSG(5)
Annotation
gt%u O
6/18R019 9:08:39AM Pegs 4 COMPASS 5000.14 Bii1C 85D
ConocO�hillips
ConotoPhillips
Definitive Survey Report
Compam/, ConowPhiMps Alaska Inc_Kupamk
Local Coarsinale Reference:
Mil 2F-07
Project: Kupamk River Unit
TVO Reference:
2F07@127.00us0(21`47)
Site: Kupaeuk 2F Pas
MO Reference:
2F-07@ 127.00usX(2F47)
Well: 2F-07
North Reference:
True
Massie: 2F4711-01
Survey Calculation MethoM
Minimum Cuivalure
Oes19n'. 2F-0711-01
Database:
EDT 14 Alaska Production
Annotation
6RMO19 9'08:39AM Pape 5 COMPA555000. 14 Buds 650
Map,
Map
Poetical
MD
Inc
An
T1ID
Man
91413
4sm
N o thi9
Saint,
DLC
Section Survey Tael Name
Iusn)
11J
1°I
(int")
Juan)
(uMt)
(-1q
In)
(R)
(9100.)
le)
10625.93
93.01
34180
6,017,33
589].33
law 91
6.93795
5,951,370.13
524,591.08
7.39
190591 MWD MSG (5)
1065095
8295
339.75
601603
SBB903
192950
6,ace.
5.951,393.71
52458281
651
1,929,50 MATT MSG (5)
1067117
8298
337E8
6014.98
SW7.98
1,948.32
6,Mal
5.951,41250
524.575.44
1022
1,940.32 MAD MSG (5)
10.70058
91'n
33756
0413.]/
5868]7
1,97549
6,911]
5,951.439.E4
524.564.18
4.30
1,91549 MWD OWBG(6)
10.740.49
9181
33656
6412.55
5,090.55
2,01223
e896.67
5.95147634
524548.56
2.51
201223 MAD OWSG(5)
1O.A7.50
9193
337,70
8.011.35
S 5435
2,04632
6,801,32
595151039
524.534.13
3.30
204632 MAD MSG (5)
1060671
92,50
33i T1
8010.13
5803.13
20]510
686951
5.9515N.M
524,522.25
2.19
207510 MWD MSG (5)
1084042
93.19
33666
6,008.53
5,241.53
2,10458
6.857.74
595156960
624,51041
SAS
210458 MAD OWSG(5)
10.900.68
9301
33228
6007.00
5890.06
2,13074
884710
5.01 59.3
524,19077
692
2,130.74 MAD MSG (5)
1090271
9261
337.24
6.00.33
5,878.33
2162.o9
ssm3 2
5,01'sNIV
524485.56
118
2,10209 MAD MSG (5)
10929.10
91.0
33629
6404.,'6
507.35
218650
682404
5901 MA2
524476.52
5.44
218650 MAD MSG (5)
10.45890
91.40
337,67
6.003,31
5,Mat
;22424
6812.79
5951678.14
524485.21
352
2.214.24 MAD MSG (5)
is.We..
9190
337.89
.,=.tt
5,875.11
224346
S8C099
5,95.14.90
524453.34
1.67
2,243.06 MAD MSG (5)
11020.32
90.90
338.27
6901.41
5,874.41
2270.97
678976
5,951.734.01
52444304
4.53
2,270.97 MADOWBG(5)
11,04359
80.21
337.01
6.001.23
5,87433
2292.49
6780.91
5,951,756.31
524.433.14
578
229249 MNDMSG(5)
11.00.40
90.61
337.50
8.000.97
5,873.97
2326,45
6)G670
5,85179023
524418.W
1.89
2.326.45 MWD Mi (5)
11,109.74
90.12
337.78
6.=.70
5,873]0
235359
6755.56
5,951,817.34
524,490.90
180
2.35359 MND MSG (51
11,14019
9046
337.85
emits
sainW
2381.79
6]4446
5,951845,51
524396.06
IA4
238179 MWD MSG (5)
11168.51
9101
337.58
k(KOAS
5,873.15
2408.91
8}3294
5,951amw
524,36491
336
2,40691 MWOOWB315)
11,198.43
8210
338.75
5.99921
5,BM21
3.433.87
6,]21,62
5,95190034
524.37373
465
2,436.67 MWD MSG (5)
11,25.34
90.06
338.70
6.93662
5,871.63
Z. Sal
6,71099
5,951,8211.18
524.362.83
209
2,490,54 MWD MSG (5)
1125531
9006
33952
5.060.60
587160
2,488.81
6701.74
5.951,952.42
M4.35,52
293
2.490,81 MWD MSG (5)
11202.38
80.95
341,43
5,990.83
5,871,83
2,514.33
6.692.69
5,961,977.92
62AW.
014
2,514.33 MWD MSG (5)
H3o9.S
8715
34152
SW975
5,8n75
2.SW.07
0,684.07
5,952.00363
524335.73
667
2,540.07 MVA) MSG (5)
14.34031
8684
343.20
ti,W156
5,074.36
2569.25
667461
5,95203278
4432641
5.82
2.669.25 MWDOWSGISJ
11,37074
8609
324,51
6402.71
6.67571
259655
6666.35
5,95246207
524,31286
574
2,598.55 MWDGWSG(5)
11400.42
8911
34548
6,003.42
5,65.42
1,62721
6858.67
5,952,090.71
524.31013
4.89
2627.21 MWD MSG (5)
11,429.92
8997
3228
6,003M
5,876.64
265.80
6651.72
5952119ffi
52430312
671
2655.80 MWD OWBG(5)
1145090
90.06
30.77
6,00363
5,85.63
266590
6,m09
5.95290935
52429641
1.58
288590 .0 MSG (5)
11.489.81
8954
34906
6,003.73
5.876,73
271445
66N.24
5.952.17789
524.29050
4.87
2,71445 MWD MSG (5)
11,52190
80.65
35.44
6,00.24
567724
274611
663352
5952209,53
524,284,71
503
2746.11 MWD MSG (5)
Annotation
6RMO19 9'08:39AM Pape 5 COMPA555000. 14 Buds 650
Annotation
l&s
IVIS 019 9'08:39AM Pap 6 COMPASS 5000.14 Boil 850
ConocoPhillips
�,
ConoCO�lllflPS
Definitive
Survey Report
ComPOry.
ConcouPhillips Mesita
Inc_Kupemk
Local Coordlnafe Wennce:
MMI 2F-07
Piojec :
Kupemk Rive, Unit
WO Reference:
2F-07 @ 127.00usp (2F-07)
SIIM
Kupamk 2F
Pad
MO Naflue"e:
2F-07 C 127.00uafi (2F-07)
Wall:
2F-07
North Rele¢ncw
True
Wellbpre:
21F-0711-01
Survey Calculation Method
Minimum
Curvature
De ign:
21F-0711-01
Database:
EDT 14
Mesita Producton
Slump,
_.
Map
Vertical
MO
Inc
Asl
TVD
miss
aNFs
aEJWy
NO
att
E(to
OLS
BeSurvey TRol Neme
(R6R)
r)
V)
(Ran)
(Mil"
(-0011
(uett)
RI
IR)
NloP)
(ft)
el
11,550.79
8911
35058
6.004.00
5,871.01
2]A 52
6,620.]]
5952]93
2]
24
5202]990
167
2,]]452 MWD OWSG 5
1157893
0085
350.62
6000.37
58]0.3]
2803.26
&6N,02
5,952.266.65
524,275.07
150
2,803.26 MWD Ouo G(5)
11,608.92
09AB
351.60
6.000,55
5870.06
24832.89
5,619.40
5,952.29627
524.270.39
449
2,832.89 MJlD0W5G(51
11,640.39
08,59
351,27
6,006,38
5,079.38
286302
6,61489
5,95232.130
524,265.
332
2,863.02 MWDOW6G(51
H670.10
07.08
35030
6,007.50
5,880.50
289232
6,610.13
5,952.355.67
524,Zfi0.98
604
289232 DMSG(5)
11,699,73
077.
35037
6,0118.83
5,801.83
2921.50
6,605.16
5,95230404
52425594
2.31
2.921.50 MWD OWSG(5)
11.73052
den
348.05
6.003.91
5.80291
2951.73
8.599.40
5,952.41505
5242W.11
Tail
2,951.73 MWDMW(5)
11,759.91
0983
34089
6,010.67
SM67
290051
6,593.53
5,95244102
52A.244.17
353
2,98051 MND OWW(5)
11,]9011
0040
34914
6,01130
5W.b
3.01015
6,58].]8
5,85247144
52423&35
1A0
3,010.15 MWDOWSGI5)
11,02043
0905
34934
6,012.N
5,8&.04
3,039.93
6,582.09
5,952.503.20
52423260
1.97
3.03993 MWDOVYW15)
11,04901
0975
34999
6,012.35
5,805.35
3,0&.82
8,576.80
595253208
524327.23
149
3,0013,82 MID MSG (5)
11.07967
87.82
34988
6.012.90
5.e85.90
3000.22
6,571.58
5.952561.46
524321.95
&47
3,CBe22 MWD OWSG (5)
11, 09.75
07.00
349.79
6.014.11
5,80].11
3,127.80
5.5%.27
5,852591.03
524,216.57
u36
3,127.80 MNOOWSG(5)
11.940.05
80.80
35002
6,014.99
5.887.99
341A62
11,56097
5.952620,&
524.21120
113
3.15762 MND OWSG(5)
11.966.35
0859
300.82
6,015.36
5,0&.36
3,1]3.69
6,55825
5.952.63&09
52420045
5.07
3.1]3.69 MWD ONSG(5)
11,96400
0959
30082
0,016.4
5.&9.04
3210.98
6,553.84
5,S52fiW.9
524.20197
0.00
3,20098 PROJECTED to TO
Annotation
l&s
IVIS 019 9'08:39AM Pap 6 COMPASS 5000.14 Boil 850
F�UGNES PRINT DISTRIBUTION LIST
a GE company
COMPANY ConocoPhillips Alaska, Inc.
WELL NAME 2F -07L1-01
FIELD Greater Kuoaruk Area
COUNTY North Slope Borough
BHI DISTRICT
Alaska
21 9075
30964
se sign and return one copy of this transmittal form to:
ocoPhillips Alaska, Inc.
i Osterkamp (WNS Petroleum Technician)
G Street.
Torage.Alaska 99510
LOG TYPE GR - RES
LOG DATE June 8, 2019
AUTHORIZED BY Patrick Rider
EMAIL Patrick. Ridera)bakerhughes.com TODAYS DATE July 2, 2019
Revision
STATUS Final Replacement: No Details:
Rev. Requested by: ---
COMPANY
ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX)
PERSON ATTENTION
IG
BP North Slope.
EOA, PBOC, PRB-20 (Ofnce 109)
D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill
900 E. Benson Blvd.
Anchorage, Alaska 99508
2 ConocoPhillips Alaska Inc.
Attn: Ricky Elgarico
ATO 708
700 G Street
Anchorage, AK 99510
3 ExxonNfohil, Alaska
Attn: Lynda M. Vaskell and/or Leonardo Elias
3201 C Street, Suite 505
Anchorage, AN 99503
FIELD I
FINALCD/DVD
FINAL
PRELIM
LOGS
(las, dlis, PDF, META,
SURVEY
I
REPORT
LOGS
CGM, Final Surveys)
(Compass)
# OF PRINTS
# OF COPIES
1# OF COPIES
I# OF COPIES
RECej\,I
01 01 0 10 0
4 State of Alaska - AOGCC 0 1 1 0 0
Attn: Natural Resources Technician 11
333 W. 7th Ave, Suite 100
Anchorage, Alaska 99501
5 DNR - Division of OB & Gas *** 0 1 0 1 0 0
Attn: Resource Evaluation
550 West 7th Avenue, Suite 1100
Anchorage, Alaska 99501
*1" Stamp "confidential" on all material deliver to DNR
6 RP Exploration (Alaska) Inc.
Petrotechnical Data Center, LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
0 0 0 0 0
TOTALS FOR THIS PAGE: 0 1 2 0 0
7
THE STATE
01ALASKA
GOVERNOR MIKE DUNLEAVY
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2F -07L1-01
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-075
Surface Location: 565' FSL, 1570' FEL, SEC. 28, TI IN, R9E, UM
Bottomhole Location: 1408' FNL, 121' FWL, SEC. 26, TI IN, R9E, UM
Dear Mr. Ohlinger:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
w .00gcc.alaska.gov
Enclosed is the approved application for the permit to drill the above referenced development well.
The permit is for a new wellbore segment of existing well Permit No. 184-020, API No. 50-029-21076-
00-00. Production should continue to be reported as a function of the original API number stated
above.
Per Statute AS 31.05.030(d)(2)(3) 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
DATED this/,? dad y of May, 2019.
STATE OF ALASKA
ALr,oRA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
9n AAC 96 nn5
MAY t j) 2019
1 a. Type of Work:
Drill ❑ Lateral ❑'
Redrill ❑ Reentry ❑
tb. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp ❑
Stratigraphic Test ❑ Development- Oil ❑� ' Service - Winj ❑ Single Zone ❑� •
I Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
1c. Specify if welt is proposed for:
Coalbed Gas ❑ Gas Hydrates ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond: Blanket ❑� • Single Well ❑
11. Well Name and Number:
ConocoPhillips Alaska, Inc.
Bond No. 5952180
KRU 2F -07L1-01
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 12050' TVD: 6001'
Kuparuk River Pool I
Kuparuk River Oil Pool -
4a. Location of Well (Governmental Section):
Surface: 565' FSL, 1570' FEL, Sec. 28, T11 N, R9E, UM
7. Property Designation:
ADL 25657 r/Vi- L
8. DNR Approval Number:
&41
13, Approximate Spud Date:
Top of Productive Horizon:
1567' FSL, 658' FEL, Sec. 27, T11 N, R9E, UM
LONS 82-177 4
5/21/2019
9. Acres in Property:
14. Distance to Nearest Property:
Total Depth:
1408' FNL, 121' FWL, Sec. 26, T11 N, R9E, UM
2560
17,015'
41b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 127' •
15. Distance to Nearest Well Open
Surface: x- 517658 y- 5949448 . Zone- 4
GL / BF Elevation above MSL (ft): 98'
to Same Pool: 1444'(2F-06)
16. Deviated wells: Kickoff depth: 9225 ' feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 95 degrees
Downhole: 4420 - Surface: 3823 -
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)
3" 2-3/8" 4.7# L-80 ST -L 3625'
8425' 5825' 12050' 6001' Slotted (Solid in Build)
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):
9055' 6254' N/A 8931' 6167' 8890'
Casing Length Size Cement Volume MD TVD
Conductor/Structural 109' 16" 150 Sx CS II 109' 109'
Surface 3727' 9-5/8" 1040 Sx AS III, 710 Sx Class G 3727' 2889'
Production 9051' 7" 300 Sx Class G, 250 Sx AS 1 9021' 6229'
Perforation Depth MD (ft): 8554'-8564', 8638'-8657', 8674'-8728', 1 Perforation Depth TVD (ft): 5912'-5919', 5968'-5981', 5992'-6029', 6063'-6067-
8778'-8784'
Hydraulic Fracture planned? Yes❑ No ❑�
20. Attachments: Property Plat F1 BOP SketchDrilling
Program
Time v. Depth Plot
Shallow Hazard Analysis
Diverter Sketch
a Seabed Report
® Drilling Fluid Program
Ld 20 AAC 25.050 requiremenisg
21. Verbal Approval: Commission Representative: Dale
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be�
deviated from without prior written approval. Contact Name: William R. Long
Authorized Name: James Ohlinger Contact Email: William.R.Lon COP.Copn
Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4372
Authorized Signature: Date:
Commission Use Only
Permit to Drill �` 7
Number: Z/ ` �� S
API Numbe /
50- (%"'�L �7�—��
Permit Approval G
Dale: ✓
I I
,t
I "I
See cover letter for other
requirements.
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Other: QOP flSJ" to - OUCJ R.S��% Samples req'd: Yes ❑�{/ No� Mud log req'd: Yes,❑_,/Noi/
ftvl n �l a r pr .-V frt t7•� W5 P io ZJ�G0�7 r1(�S measures: Yes L No❑ Directional svy req'd: Yes Lr] No❑
VGLr/�%hC•G fo 2OAt,-25-- 0/5- (b Spacing exception req'd: Yes E] No� Inclination -only svy req'd: Yes E] Nov
Y. b Post initial injection MIT req'd: Yes El NoM-�
G1.h/y rQ mi vi'/ q./orrq f'hG �ar—1 r�fi �q ff rQ/,
Tary» J3l�PJ��a�k 2��pro✓mac( -
APPROVED BY C �� ��� g
Approved by: COMMISSIONER THE COMMISSION Date: J
rr��1I 1�')1!.
F 1 f k - V7/ed 2(!17 SThis permit is valid f
rod�rt6
11��
/1
h(S yopl
1 Submit Form and
d� approval per 20 AAC 25.005(8) q c� enis ir�Dupl /
/47
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
May 13, 2019
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby submits applications for sundry and permits to drill two laterals out of the
KRU 2F-07 (PTD# 184-020) using the coiled tubing drilling rig, Nabors CDR3-AC.
CTD operations are scheduled to begin in May 2019. The objective will be to drill two laterals KRU 2F -07L1 and
2F -07L1-01 targeting the Kuparuk A -sand interval.
To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20
AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of
being limited to 500' from the original point.
Attached to the permit to drill applications are the following documents:
- Permit to Drill Application Forms (10-401) for 2F -07L1 and 2F -07L1-01
- Detailed Summary of Operations
- Directional Plans for 2F-071_1 and 2F -07L1-01
- Current wellbore schematic
- Proposed CTD schematic
Attached to the sundry application are the following documents:
- Sundry Application Form (10-403) for 2F-07
- Summary of Operations
- 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
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Kuparuk CTD Laterals
2F-071-1 and 2F-071-1-01
Application for Permit to Drill Document
1.
Well Name and Classification........................................................................................................ 2
Directional Plans for 2F-071-1 and 2F-071-1-01 laterals............................................................................6
(Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)). ....................... ........... ..............................................................................
2
2.
Location Summary ..........................................................................................................................
2
(Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2
3.
Blowout Prevention Equipment Information.................................................................................
2
(Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2
4.
Drilling Hazards Information and Reservoir Pressure..................................................................
2
(Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2
5.
Procedure for Conducting Formation Integrity tests...................................................................
2
(Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2
6.
Casing and Cementing Program....................................................................................................
3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................
3
7.
Diverter System Information..........................................................................................................
3
(Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3
8.
Drilling Fluids Program..................................................................................................................
3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3
9.
Abnormally Pressured Formation Information.............................................................................4
(Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4
10.
Seismic Analysis.............................................................................................................................
4
(Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4
11.
Seabed Condition Analysis............................................................................................................
4
(Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4
12. Evidence of Bonding......................................................................................................................4
(Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4
13. Proposed Drilling Program.............................................................................................................4
(Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4
Summaryof Operations...................................................................................................................................................4
LinerRunning...................................................................................................................................................................5
14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6
(Requirements of 20 AAC 25.005(c)(14)) ..................... .................................................................................................. ..... ................. .- 6
15. Directional Plans for Intentionally Deviated Wells....................................................................... 6
(Requirements of 20 AAC 25.050(6))...................................................................................................................................................... 6
16. Attachments....................................................................................................................................6
Attachment 1:
Directional Plans for 2F-071-1 and 2F-071-1-01 laterals............................................................................6
Attachment 2:
Current Well Schematic for 2F-07............................................................................................................6
Attachment 3:
Proposed Well Schematic for 2F-071-1 and 2F-071-1-01 laterals..............................................................6
Page 1 of 6 May 13, 2019
PTD Application: 2F -07L1 & 2F-071-1-01
1. Well Name and Classification
(Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))
The proposed laterals described in this document are 2F-071_1 and 2F-071-1-01. The laterals will be classified
as "Development -Oil' wells.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface
and subsurface coordinates of the 2F-071_1 and 2F -07L1-01.
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 4,000 psi. Using the
maximum formation pressure in the area of 4420 psi at the datum in 217-15 (i.e. 13.4 ppg EMW), the
maximum potential surface pressure in 2F-07, assuming a gas gradient of 0.1 psi/ft, would be 3823
psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details.
- The annular preventer will be tested to 250 psi and 2,500 psi.
4. Drilling Hazards Information and Reservoir Pressure
(Requirements of 20 AAC 25.005 (c)(4))
Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a))
The formation pressure in KRU 2F-07 was 3,927 psi at the datum (11.9 ppg EMW) on 5/3/2019. The maximum i
downhole pressure in the 2F-07 vicinity is 2F-15 at 4420 psi at the datum (13.4 ppg EMW) measured on
2/22/2014. —
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) /
The offset injection wells to 2F-07 have injected gas, so there is a possibility of encountering free gas while
drilling the 2F-07 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage
tank away from the rig.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c))
The major expected risk of hole problems in the 2F-07 laterals will be shale instability across faults. Managed
pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 2F-07 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity
test is not required.
Page 2 of 6 May 13, 2019
PTD ADolication: 2F -07L1 & 2F-071_1-01
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
Lateral Name
Liner Top
Liner Btm
Liner Top
Liner Btm
Liner Details
Btm
MD
MD
TVDSS
TVDSS
Conductor
16"
62.5
H40
Welded
Surface
2-3/8", 4.7#, L-80, ST -L slotted liner,
2F -07L1
9225'
12,100'
5888'
5943'
aluminum billet on to
36.0
J-55
BTC
Surface
3727'
2-3/8", 4.7#, L-80, ST -L slotted liner
2F-07LI-01
8425'
12,050'
5698'
5,874'
and solid liner; with deployment
J-55
BTC
Surface
9051'
Surface
sleeve on to
Existing Casing/Liner Information
Category
OD
Weight
(ppf)MD
Grade
Connection
Top MD
Btm
Top
TVD
Btm
TVD
Burst
psi
Collapse
psi
Conductor
16"
62.5
H40
Welded
Surface
109'
Surface
109'
1640
670
Surface
9-5/8"
36.0
J-55
BTC
Surface
3727'
Surface
2889'
3520
2020
Production
7"
26.0
J-55
BTC
Surface
9051'
Surface
6251'
4980
4320
Tubing
3-1/2"
9.3
J-55
EUE 8rd
Surface
8434'
Surface
5832'
6980
7400
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 (8.6 ppg)
— Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with 12.1 ppg NaBr completion fluid in order to provide
formation over -balance and shale stability while running completions. If higher pressures are
encountered the NaBr will be weighted up, or completion fluid will be switched to potassium formate.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation 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 2F-07 laterals we will target a constant BHP of at least 11.8 ppg EMW at the window. The constant BHP
target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions
if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be
employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates
or change in depth of circulation will be offset with back pressure adjustments.
Page 3 of 6 May 13, 2019
PTD Application: 2F-071_1 & 2F -07L1-01
Pressure at the 217-07 Window (8645' MD, 5973' 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 2F-07 is a Kuparuk A -Sand producer equipped with 3-1/2" tubing and 7" production casing. The
CTD sidetrack will utilize two laterals to target the A -sands to the northeast and southeast of 2F-07. The
laterals will target reservoir to the east that has been sheltered due to a large sealing fault
CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned
kick off point of 8645' MD. The 2F-071_1 lateral will exit through the 7" casing at 8645' MD and TD at
12100' MD, targeting the A sand to the southeast. It will be completed with 2-3/8" slotted liner from TD
up to 9225' MD with an aluminum billet for kicking off the 2F -07L 1-01 lateral.
The 2F -07L1-01 lateral will drill to a TD of 12050' MD targeting the A sand to the northeast. It will be
completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 8425' MD with a deployment
sleeve or swell packer and liner top packer if western side of the fault is swept.
Pre -CTD Work
1. RU Slickline: Dummy whipstock drift, C/O GLV's
2. RU E -line: Caliper
3. RU CTU: Mill out D -Nipple to 2.80" ID
4. Prep site for Nabors CDR3-AC rig.
Page 4 of 6 May 13, 2019
Pumps On 1.8 bpm)
Pumps Off
A -sand Formation Pressure 11.9
3696 psi
3696 psi
Mud Hydrostatic 8.6
2671 psi
2671 psi
Annular friction i.e. ECD, 0.08psi/ft)
692 psi
0 psi
Mud + ECD Combined
no chokepressure)
3363 psi
(Underbalanced -333 psi)
2671 psi
(Underbalanced -1025 psi)
Target BHP at Window 11.9 ppg
3696 psi
3696 psi
Choke Pressure Required to Maintain
Target BHP
333 psi
1025 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 2F-07 is a Kuparuk A -Sand producer equipped with 3-1/2" tubing and 7" production casing. The
CTD sidetrack will utilize two laterals to target the A -sands to the northeast and southeast of 2F-07. The
laterals will target reservoir to the east that has been sheltered due to a large sealing fault
CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned
kick off point of 8645' MD. The 2F-071_1 lateral will exit through the 7" casing at 8645' MD and TD at
12100' MD, targeting the A sand to the southeast. It will be completed with 2-3/8" slotted liner from TD
up to 9225' MD with an aluminum billet for kicking off the 2F -07L 1-01 lateral.
The 2F -07L1-01 lateral will drill to a TD of 12050' MD targeting the A sand to the northeast. It will be
completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 8425' MD with a deployment
sleeve or swell packer and liner top packer if western side of the fault is swept.
Pre -CTD Work
1. RU Slickline: Dummy whipstock drift, C/O GLV's
2. RU E -line: Caliper
3. RU CTU: Mill out D -Nipple to 2.80" ID
4. Prep site for Nabors CDR3-AC rig.
Page 4 of 6 May 13, 2019
PTD Application: 2F-071_1 & 2F -07L1-01
Rig Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. 217-07L 1 Lateral (A4 sand - South)
a. Set top of high expansion wedge at 8645' MD.
b. Mill 2.80" window at 8645' MD.
c. Drill 3" bi-center lateral to TD of 12,100' MD.
d. Run 2-3/8" slotted liner with aluminum billet from TD up to 9225' MD.
3. 2F -07L1-01 Lateral (A4 sand -North)
a. Kick off of the aluminum billet at 9225' MD.
b. Drill 3" bi-center lateral to TD of 12050' MD.
c. Run 2-3/8" slotted liner and solid liner through build with seal -bore deployment sleeve from
TD up to 8425' MD.
NOTE: A swell packer and liner top packer will be run in the build section of the lateral to isolate
the near wellbore region only if logs indicate high water cut near wellbore.
4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Rig Work
1. 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 2F-07 laterals will be displaced to an overbalancing fluid prior to running liner. See "Dulling Fluids'
section for more details.
- While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency
deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a
deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide
secondary well control while running 2-3/8" liner.
Page 5 of 6 May 13, 2019
PTD Application: 2F-071-1 & 2F-071-1-01
14. Disposal of Drilling Mud and Cuttings
(Requirements of 20 AAC 25.005(c)(14))
• No annular injection on this well.
• All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal.
• Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (113-18
or 113 disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable.
• All wastes and waste fluids hauled from the pad must be properly documented and manifested.
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200).
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
- The Applicant is the only affected owner.
- Please see Attachment 1: Directional Plans
- Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
- MWD directional, resistivity, and gamma ray will be run over the entire open hole section.
- Distance to Nearest Property Line (measured to KPA boundary at closest point)
Lateral Name
Distance
2F-071-1
12,370'
2F -07L1-01
17,015'
- Distance to Nearest Well within Pool
Lateral Name Distance Well
2F-071-1 1267' 2D-14
21F-071-1-01 1444 2F-06
16. Attachments
Attachment 1: Directional Plans for 2F -07L1 and 2F -07L1-01 laterals
Attachment 2: Current Well Schematic for 2F-07
Attachment 3: Proposed Well Schematic for 2F -07L1 and 2F -07L1-01 laterals
Page 6 of 6 May 13, 2019
Well KRU XX -XX Nabors CDR3-AC: 4 -Ram BOP Configuration 2,, Date April 24, 2019
Coiled Tubing and 2-3/8" BHA
Tree Size s FIs
Quick Test Sub to Ot
Top of 7" Otis
Distances from top o
Excluding quick -test
Top of Annular
CL Annular
Bottom Annular Flan
Ci BlindlSheam
CI.2" Combi's
CL 2-318" Combi's
0. 2" Combfs
CL of Top E
Top of Swa
CL Swab 1
Flow Tee
CL SSV
CL Master
LDS
Ground
tie
ConocoPhillips
ConocoPhillips Alaska Inc_Kuparuk
Kuparuk River Unit
Kuparuk 2F Pad
2F-07
2F-071-1-01
Plan: 2F-07L1-01_wp02
Standard Planning Report
02 May, 2019
BTGE company
�, ConocoPhillips BA ER
Co ol:80liiiips Planning Report BAT
a GE company
Database:
EDT 14 Alaska Production
Company:
ConocoPhillips Alaska Inc_Kupamk
Project:
Kuparuk River Unit
Site:
Kupamk 2F Pad
Well:
2F-07
Wellbore:
2F-071-1-01
Design:
2F-071-1-01_wp02
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 2F-07
Mean Sea Level
2F-07 @ 127.00usft (2F-07)
True
Minimum Curvature
Project Kupamk 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 Nall Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Site Kupamk 2F Pad
Site Position: Northing: 5,949,341.83usft Latitude: 70' 16'21.978 N
From: Map Easting: 517,392.56usft Longitude: 149' 51'33.576 W
Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.13 °
Well
2F-07
Dogleg
Build
Well Position
+NIS
0.00 usft
Northing:
+E/ -W
+El -W
0.00 usft
Easting:
Position Uncertainty
System
0.00 usft
Wellhead Elevation:
Wellbore 2F -07L1-01
7bc
s Model Name
BGGM201
[D_esign
2F-071-1-01_wp02
udit Notes:
eion:ertical Section:
5,949,448.14 usft
517,658.31 usft
usft
Sample Date Declination
(°1
8 4/23/2019 _.. 16.57
Phase: PLAN
Depth From (TVD) +NIS
(usft) (usft)
0.00 0.00
Plan Sections
Dogleg
Build
Turn
Measured
+Nl-S
+E/ -W
TVD Below
Depth
Inclination
Azimuth
System
(usft)
(')
(')
(usft)
9,225.00
91.62
102.55
5,888.08
9,300.00
86.80
96.80
5,889.12
9,600.00
90.46
67.01
5,896.30
9,875.00
90.46
39.51
5,894.12
10,175.00
95.15
9.83
5,879.46
10,450.00
90.37
342.71
5,866.22
10,800.00
86.11
17.48
5,876.98
11,025.00
90.78
355.45
5,883.08
11,150.00
95.26
343.77
5,876.49
11,500.00
91.00
18.56
5,857.38
11,750.00
87.52
353.80
5,860.62
12,050.00
87.52
23.83
5,873.61
Latitude:
Longitude:
Ground Level:
Dip Angle
C°
Tie On Depth:
+E/ -W
(usft)
0.00
70° 16'23.018 N
149° 51'25.830 W
0.00 usft
Field Strength
(nT)
80.81 57,411
9,225.00
Direction
(I
0.00
Target
&W019 9:07:23AM Peg@ 2 COMPASS 5000,14 Build 850
Dogleg
Build
Turn
+Nl-S
+E/ -W
Rate
Rate
Rate
TFO
(usft)
(usft)
(-/100usft)
('l100usft)
('/100usft)
(°)
1004.81
6,189.93
0.00
0.00
0.00
0.00
992.21
6,263.81
10.00
-6.43
-7.67
-130.00
1,034.00
6,557.35
10.00
1.22
-9.93
-83.00
1,196.92
6,775.60
10.00
0.00
-10.00
-90.00
1,466.06
6,899.35
10.00
1.56
-9.92
-81.00
1,737.52
6,881.58
10.00
-1.74
-9.85
-100.00
2,081.94
6,882.08
10.00
-1.22
9.95
97.00
2,303.99
6,907.21
10.00
2.08
-9.78
-78.00
2,426.53
6,884.76
10.00
3.58
-9.38
-69.00
2,770.51
6,891.90
10.00
-1.22
9.93
97.00
3,017.07
6,918.62
10.00
-1.39
-9.91
-98.00
3,309.86
6,964.04
10.00
0.00
10.01
90.00
Target
&W019 9:07:23AM Peg@ 2 COMPASS 5000,14 Build 850
Planned
ConocoPhillips
BA
ER
`,
ConocoPhillips
Planning Report
F�IGHES
a GE compa,V
Database: EDT 14 Alaska Production
Local Co-ordinate Reference:
Well 2F-07
Company: ConocoPhillips Alaska Inc_Kuparuk
TVD Reference:
Mean Sea Level
Project: Kuparuk River Unit
MD Reference:
2F-07 Q 127,00usft (2F-07) '
Site: Kupaluk 2F Pad
North Reference:
True
Well: 2F-07
Survey Calculation Method:
Minimum Curvature
Wellbore: 2F-07Li-01
Map
Design: 2F -07L t-01_wp02
Map
Depth Inclination
Planned
Survey
I- I
Measured
TVD Below
Vertical
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination
Azimuth
System
' +N/S
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(°)
(usft)
(usft)
9,225.00
91.62
102.55
5,888.08
1,004.81
6,189.93
1,004.81
0.00
0.00
5,950,467.37
523,845.25
TIP/KOP
9,300.00
86.80
96.80
5,889.12
992.21
6,263.81
992.21
10.00
-130.00
5,950,454.95
523,919.15
Start DLS
10.00 TFO
-130.00
9,400.00
88.02
86.86
5,893.64
989.02
6,363.53
989.02
10.00
-83.24
5,950,451.99
524,018.86
9,500.00
89.24
76.94
5,896.04
1,003.09
6,462.38
1,003.09
10.00
-83.14
5,950,466.29
524,117.67
9,600.00
90.46
67.01
5,896.30
1,034.00
6,557.35
1,034.00
10.00
-83.03
5,950,497.42
524,212.56
Start DLS
10.00 TFO
-90.00
9,700.00
90.46
57.01
5,895.51
1,080.87
6,645.53
1,080.87
10.00
-89.96
5,950,544.49
524,300.63
9,800.00
90.46
47.01
5,894.71
1,142.34
6,724.24
1,142.34
10.00
-89.96
5,950,606.14
524,379.18
9,875.00
90.46
39.51
5,894.12
1,196.92
6,775.60
1,196.92
10.00
-89.97
5,950,660.84
524,430.41
Start DLS
10.00 TFO
.81.00
9,900.00
90.85
37.04
5,893.83
1,216.54
6,791.09
1,216.54
10.00
-80.99
5,950,680.49
524,445.85
10,000.00
92.41
27.16
5,890.99
1,301.11
6,844.14
1,301.11
10.00
-80.88
5,950,765.18
524,498.69
10,100.00
93.97
17.27
5,885.42
1,393.43
6,881.84
1,393.43
10.00
-80.75
5,950,857.57
524,536.18
10,175.00
95.15
9.83
5,879.46
1,466.06
6,899.35
1,466.06
10.00
-80.72
5,950,930.24
524,553.51
Start DLS
10.00 TFO
.100.00
10,200.00
94.71
7.36
5,877.31
1,490.68
6,903.07
1,490.68
10.00
-99.90
5,950,954.87
524,557.18
10,300.00
92.98
357.49
5,870.60
1,590.24
6,907.29
1,590.24
10.00
-99.65
5,951,054.43
524,561.16
10,400.00
91.24
347.64
5,866.93
1,689.21
6,894.37
1,689.21
10.00
-99.80
5,951,153.35
524,548.01
10,450.00
90.37
342.71
5,866.22
1,737.52
6,881.58
1,737.52
10.00
-99.96
5,951,201.63
524,535.11
Start DLS
10.00 TFO
97.00
10,500.00
89.76
347.68
5,866.17
1,785.85
6,868.81
1,785.85
10.00
96.99
5,951,249.92
524,522.23
10,600.00
88.54
357.60
5,867.65
1,884.89
6,856.02
1,884.89
10.00
97.06
5,951,348.92
524,509.20
10,700.00
87.32
7.54
5,871.25
1,984.59
6,860.49
1,984.59
10.00
97.16
5,951,448.63
524,513.44
10,800.00
86.11
17.48
5,876.98
2,081.94
6,882.08
2,081.94
10.00
97.27
5,951,546.01
524,534.80
Start DLS
10.00 TFO
-78.00
10,900.00
88.19
7.68
5,881.96
2,179.29
6,903.80
2,179.29
10.00
-78.27
5,951,643.41
524,556.29
11,000.00
90.27
357.90
5,883.31
2,279.04
6,908.66
2,279.04
10.00
-78.10
5,951,743.15
524,560.91
11,025.00
90.78
355.45
5,883.08
2,303.99
6,907.21
2,303.99
10.00
-77.99
5,951,768.10
524,559.41
Start DLS
10.00 TFO
.69.00
11,100.00
93.47
348.45
5,880.30
2,378.15
6,896.73
2,378.15
10.00
-68.90
5,951,842.23
524,548.75
11,150.00
95.26
343.77
5,876.49
2,426.53
6,884.76
2,426.53
10.00
-68.84
5,951,890.58
524,536.67
Start DLS
10.00 TFO
97.00
11,200.00
94.65
348.75
5,872.17
2,474.90
6,872.93
2,474.90
10.00
96.78
5,951,938.91
524,524.73
11,300.00
93.43
358.70
5,865.11
2,573.93
6,862.04
2,573.93
10.00
96.63
5,952,037.91
524,513.61
11,400.00
92.22
8.63
5,860.18
2,673.48
6,868.42
2,673.48
10.00
96.74
5,952,137.46
524,519.76
11,500.00
91.00
18.56
5,857.38
2,770.51
6,891.90
2,770.51
10.00
96.84
5,952,234.54
524,543.00
Start DLS
10.00 TFO
58.00
11,600.00
89.61
8.66
5,856.86
2,867.58
6,915.40
2,867.58
10.00
-97.95
5,952,331.65
524,566.28
11,700.00
88.21
358.76
5,858.76
2,967.22
6,921.86
2,967.22
10.00
-98.07
5,952,431.30
524,572.50
11,750.00
87.52
353.80
5,860.62
3,017.07
6,918.62
3,017.07
10.00
-98.09
5,952,481.13
524,569.15
Start DLS
10.00 TFO
90.00
11,800.00
87.52
358.81
5,862.79
3,066.90
6,915.41
3,066.90
10.00
90.11
5,952,530.95
524,565.81
11,900.00
87.52
8.82
5,867.12
3,166.46
6,922.04
3,166.46
10.00
90.22
5,952,630.51
524,572.21
12,000.00
87.52
18.83
5,871.45
3,263.35
6,945.87
3,263.35
10.00
90.22
5,952,727.45
524,595.81
12,050.00
,
87.52
23.83
5,873.61
'
3,309.86
6,964.04
3,309.86
10.00
90.11
5,952,774.01
524,613.87
Planned TD at
12050.00
6/2/2019 9r0713AM Paps 2 COMPASS 5000.14 Build 850
ConocoPhillips
Database:
EDT 14 Alaska Production
Company:
ConocoPhillips Alaska Inc_Kupamk
Project:
Kuparuk River Unit
Site:
Kupamk 2F Pad
Well:
2F-07
Weilbore:
2F -07L1-01
Design:
2F-07Li-01_wp02
Casing Points
Measured
Vertical
Depth
Depth
(usft)
(usft)
12,050.00
5,873.61 2-3/8"
Plan Annotations
Hole
Measured
Vertical
Depth
Depth
(usft)
(usft)
9,225.00
5,888.08
9,300.00
5,889.12
9,600.00
5,896.30
9,875.00
5,894.12
10,175.00
5,879.46
10,450.00
5,866.22
10,800.00
5,876.98
11,025.00
5,883.08
11,150.00
5,876.49
11,500.00
5,857.38
11,750.00
5,860.62
12,050.00
5,873.61
ConocoPhillips
Planning Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Name
B FUG ES
a GE company
Well 2F-07
Mean Sea Level
2F-07 @ 127.00usft (2F-07)
True
Minimum Curvature
Casing
Hole
Diameter
Diameter
(in)
(in)
2.375
3.000
J
Local Coordinates
+N1 -S
+E/ -W
(usft)
(usft)
Comment
1,004.81
6,189.93
TIP/KOP
992.21
6,263.81
Start DLS 10.00 TFO -130.00
1,034.00
6,557.35
Start DLS 10.00 TFO -90.00
1,196.92
6,775.60
Start DLS 10.00 TFO -81.00
1,466.06
6,899.35
Start DLS 10.00TFO-100.00
1,737.52
6,881.58
Start DLS 10.00 TFC, 97.00
2,081.94
6,882.08
Start DLS 10.00 TFO -78.00
2,303.99
6,907.21
Start DLS 10.00 TFO -69.00
2,426.53
6,884.76
Start DLS 10.00 TFO 97.00
2,770.51
6,891.90
Start DLS 10.00 TFO -98.00
3,017.07
6,918.62
Start DLS 10.00 TFO 90.00
3,309.86
6,964.04
Planned TD at 12050.00
5/212019 9:07:23AM Page 4 COMPASS 8000,14 Build 860
ConocoPhillips BAKER
ConocoPhillips Anticollision Report F�UGI ES
Company:
ConocoPhillips Alaska Inc-Kuparuk
Project:
Kuparuk River Unit -2
Reference Site:
Kuparuk 2F Pad
Site Error:
0.00 usft
Reference Well:
2F-07
Well Error:
0.00 usft
Reference Wellbore
2F-071-1-01
Reference Design:
2F-07L1-01_wp02
Reference 2F-071-1-01_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:
9,225.00 to 12,050.00usft
Scan Method:
Results Limited by:
Maximum center -center distance of 1,392.30 usft
Error Surface:
Warning Levels Evaluated at: 2.79 Sigma
Casing Method:
Well 2F-07
2F-07 @ 127.00usft (2F-07)
2F-07 @ 127.00usft (2F-07)
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 5/2/2019
From
To
Reference
Offset
(usft)
(usft) Survey (Wellbore)
Tool Name
Description
200.00
8,600.00 2F-07 (2F-07)
SEEKER MS
BHI Seeker multishot
8,600.00
9,225.00 2F-071-1_wp02(2F-07L1)
MWD
MWD - Standard
9,225.00
12,050.00 2F-0711-01_wp02(2F-071-1-01)
MWD
MWD - Standard
Summary
Kuparuk 2F Pad -2F-07-2F-0711-2F-07L1_wp02
Reference
Offset
Distance
MS, 66(0.MWD
Measured
Measured
Between Between
Separation Warning
Site Name
Depth
Depth
Centres Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
(usft)
iusft) (usft)
Kuparuk 2F Pad
Distance
2F-06 - 2F-06 - 2F-06
Vertical
Measured
vertical
Out of range
2F-06 - 2F-06 - 2F-06
Aaimutb
Onset Wellbore
Centre
Out of range
2F-06 - 2F-06 - 2F-06
MNimum
Separation Waming
Depth
Out of range
2F-07-21F-071-1-2F-0711_wp02
9,525.00
9,550.00
77.89 75.17
28.691 CC, ES, SF
Offset Design
Kuparuk 2F Pad -2F-07-2F-0711-2F-07L1_wp02
onset site Error. 0.00 usft
Survey Program: 20NSEEKER
MS, 66(0.MWD
Offset Well EDor. 000 usft
Reference
Offset
Semi Major
Axis
Distance
Measured
Vertical
Measured
vertical
Reference
Offset
Aaimutb
Onset Wellbore
Centre
Between
Between
MNimum
Separation Waming
Depth
Depth
Depth
Depth
from North
.Nl-s
-EI-W
Centres
Ellipses
Separation
Factor
(usm
(part)
Nsm
lush)
(.aril
Wsm
1°I
(haft)
(usm
(usm
iusft)
luam
9,225.00
6,015.32
9,225.00
6,01506
0.00
0.00
109.08
1.004.81
6,189.93
0.24
o.01
0.22
1.052 Take Immediate Adlen
9,250.00
6,014.73
9,2W.W
6,014.26
0.08
0.11
107.25
999.73
6,214.40
0.47
0.22
0.25
1.892 Caution Monitor Closely
9,274.91
6,015.07
9,275.00
6,013.20
0.14
0.22
105.32
995.38
6,238.99
1.88
1.60
0.28
6.648
9,299.71
6,016.10
9,300.00
6,011.91
0.20
0.33
103.41
9s.74
6,263.69
4.23
3.92
0.31
13.580
9,324.54
6,017.43
9,325.00
6,010.39
0.26
0.46
102.31
98882
6,288.47
7.12
6.76
0.35
20.216
9,349.31
6,018.61
9,350.00
6,008.85
0.33
0.58
106.60
965.90
6,313.25
10.11
9.63
0.48
21.146
9,373.84
6,019.66
9,375.00
6,WT50
041
0.72
115.50
982.25
6,337.95
13.54
12.81
0.74
18.416
9,397.94
6020.57
9.400.00
6,006.38
0.48
0.85
125.03
977.87
8,362.53
18.03
16.97
1.06
17.009
9,421.41
6,021.33
9,425.00
6,005.42
0.56
0.99
133.18
972.76
6,386.0
23.99
22.59
1.40
17.153
9,444.00
6,021.96
9,450.00
6.004.68
0.64
1.14
139.34
966.93
6411.29
31.61
29.89
111
18A62
9,465.84
6,022.46
9,475.00
6,004.15
0.72
1.29
143.72
960.39
6,435.41
40.88
38.88
2.00
20.444
9,486.56
6,022:84
9.500.00
6,003.81
0.80
1.44
146.70
953.14
8,459.33
51.76
49.50
2.26
22.922
9,506.15
6,023.11
9,525.00
6,003.68
0.87
1.59
148.69
945.19
6483.03
64.12
61.63
2.49
25.719
9,525.00
6023.30
9,550.00
6,003.76
0.95
115
149.92
936.55
8,506.49
77.89
75.17
2.71
28.691 CC, ES, SF
9,541.79
6,023.41
9,575.00
6004.03
1.02
1.92
150.76
927.22
6.529.68
92.92
90.02
2.90
32.015
9,550.00
6,02143
11,000.00
6,050.39
1.05
17.19
163.11
-271.50
6.949.50
1,361.01
1.346.84
14.17
98.043
9,550.00
6,023.43
11,025.00
6,051.70
1.05
17.43
163.14
-295.89
6,944.17
1.382.45
1,368.26
14.19
97.435
9,557.79
6,023.45
9600.00
6004.50
1.08
2.08
151.20
917.20
6,552.58
109.14
108.06
3.08
35.452
9,559.66
6,023.45
10,975.00
6,048.82
1.09
16.98
162.10
-24739
6,955.53
1,339.96
1,325.94
14.02
95.596
9,583.98
6,023.45
10,950.00
8.046.97
1.11
16.77
161.61
-223.28
6,96224
1,319.46
1,305.50
13.96
94.513
9.572.59
6.023.44
9.62500
6,W5.16
1.14
2.26
151.42
906.52
6,575.17
126.44
123.20
3.23
39.088
CC - Min centre to center distance or covercent point. SF - min separation factor, ES - min ellipse separation
8/212019 7:61:34AM Page 2 COMPASS 5000.14 Build 850
0
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CimocliPh)lbps
Well Attributes Max Angle & MD TO
1'
AlaSka.lnc.
M.'ana, _Ha (1KB)
Field Name Wellbve PPINWI Wtllbne SlaNs Fax,
KUPARUK RIVER UNIT 500292103600 PROD 5.88 2.400.00 9,055.0
Cammenl H35 (lyml DaM Mndalbn EM OaIe K6GN(hl RIg RJease Date
SSSV: LOCKED OUT 75 121512016 LaM WO: 9/3011984 2900 131
g-07, ardWWORMPM
Last Tag
vmical enemxic nmap
AnnotAlon DepmrylNal Eiw Date wenlae lav Mae ny
Lest Tag: Ban utet. Sat Fill) 8,'5.0 93/2019 'Ru, zembaej
I
--
Last Rev Reason
FMSER`a _
arnoi Ere Me aval IxlMoe ey
Rev Reason: Updated Tag Deplb 5/3/2019 2F-0) zembaej
Casing Strings
Casing Deecriplirn 00(in) IDRnl Trp("Kn) aN Deplb (nKBI Stt Demt avId...Cki a... Gretle Tr210e
CONDUCTOR 16 15.06 31A 109.0 109.0 62.50 H-dD WELDED
Oazlno Dezcri...an GD(In) ID (M) Tcp (nNB) Set DepN (IIKBI set Depth (iVDL.. WULen g... Gretle Trp TFrcae
SURFACE 95/8 036 30.9 3,)26.8 2,8888 36-00 J-55 BTC
Casing Oezcnpllon GD(Inl ID sail Tap1XKB1 Set Legal MK51 set Depth ITVD1... Wln.en(L..Oratle Top Trreae
PRODUCTION 7 628 26.0 9.0510 6,250.8 2fi 00 J-55 BTC
CONDUCTOR, 31,0-1011.012
Tubing Strings
Tubing Description
$Icing Ma.. lO lint Fair $el DeplrmIsMD7th ToO11... W1(IbMI Gree, Trp Conneclun
TUBING
31/2 2.99 23.6 8,434.1 5,831.5 930 J-55 EUEBrd
SAFETYYLV t,MD
Completion Details
TOP Gna.) Topincl Nia iad
Fair (MK-) I.1 Item Das Cmn IDon)
23.6 23.6 007 HANGER FMC GEN It TUBING HANGER 3.500
11953.0 1,832.1 42.90 SAFETYVLV OTIS OLP SSSV (LOCKED OUT 1/192000) CL TRACK TUBING 2.812
GASLIFT: Zoaas
PRESSURE
0,391.0 5,802.6 48.03 PBR BAKER PER 3.000
.4 5, 1 4. -PAEK-Es BAKER FHL
7421.3 7822.9 48.01 NIPPLE CAMCO O NIPPLE 2350
,433.3 5,830.9 4&W SOP CAMCO SHEAR OUT - TTL ELMD 40 ONSWS PPROF 2.
8129QO04
aUFnrohesaaaAaa-
Otner in Hole (Wheline retrievable plugs, valves, pumps, fish, etc.)
TOP (N"
"Mian ItIKBI
Topincl
F) Dee Com Run Dale mlln)
GAS IJFi;I]Ia.I
8,890.0 6.1402
dg7' FISH KKOT KICK SPRINGS LOST 98"WIDE,3S'LONG 3/23/2011 0.000
8,896.0 6.1429
40.53 FISH ournal Completion ENE Left In hole during vmrkover 10211984
GAa LIFT: B,m]a
Perforations & Slots
ahm
Den
T-9".)
eurpr 1
Ishd:m
GP6I-1783744
Topuffaid
stmudgin
INGS
IAKB)
Lines Zcne
Dale
I
Type
Cmn
8,554.0
8,554.0
5,911.8
5,918.5
C -L UNIT B, 2F
1222/1983
4.0
(PERF
30 deg.'V Phasing. 21 CE
-07
Saki
,an s.aa10
8,638.0
0,657.0
5,968.1
5.980.8
A5.2F57
4CV1984
4.0
WERE
90 deg. Phasing, 4• SCNUm.
Casing Gun
8,674.0
8,728.0
5.992.3
6,028.9
",2F-0]
4/311984
4.0
WERE
90 deg. Phasing, 4• Schlum.
PACKER; seat/
Casing Gun
8,77 O
8,784.0
6,0611
6,D6).2
A -,2F-07
4l 1 Bl
.0
IPERF
90deg. Phasing, 4"SCNum.
Casing Gun
NOR.., .,.I a-
Mandrel Inserts
sl
.OS:b,All.3
NTop road VaFm Lack Fort TRORun
TOP(NKa) (KKa) Make Moeel Door) Saw TePe Type or, (ps4 Fontaine- Com
2,065.5 1,912.1 MMH FMHO 1 GASLIFT GLV BK 0.1881 1,256.0313012019
2 4,749.4 3,520.1 MMH FAHO 1 GASLIFT OV BK 0.250 1 0.031302019
6.807.4 4,803.1 MMH FM i 1 GASLIFT DMY BK .0 11 1201
mERF: 8.6408.%1.6
4 84374.4 5.791.6 MMH FORD I GASLIFT OMY 0.0 3)SOBOU, No
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TRANSMITTAL LETTER CHECKLIST
WELL NAME:
PTD:
/Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD:cit L<iv�IPOOL: l�j.�/�o* r� l\��Y� l
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
No. / d z1D , API No.
V1LATERAL
V
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50- -
from records, data and logs acquired for well
name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100
Well Name: KUPARUK RIV UNIT 2F -07L1 -Q1_ Program DEV Well bore seg Q
PTD#: 2190750 Company BP EXP_L_ORATION(ALASKA) INC Initial Class/rype
DEV / PEND GeoArea 890 Unit 11160 On/Off Shore 0t Annular Disposal ❑
Administration
1
Permit fee attached__.._. -----
NA__
.....................................................................
2
Lease number appropriate... _ _ _ . . . . . ........... . .
. Yes ....
_ _ Surf Loc & Top prod Int lie in ADLOo25657; TD lies _in ADL0025658._ _
3
Unique well. name and number _. ........ .............
Yes ..---------...---------.....
_....._... -----------.... --------...----..._
4
Well located in a. defined pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
_ Yes
... _ Kuparuk River Oil Pool, governed by Conservation Order No. 432D - . _ _ _ _ .........
5
Well located proper distance from drilling unit boundary _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
_ Yes
_ _ _ _ Conservation Order No. 432D has no interwell.spacing _restrictions. Wellbore will be. more than 500'
6
Well located proper distance from other wells. _ _ _ _ _ _ _ _ _
Yes
_ from an external property line_ where, ownership or landownership_ changes. As proposed, well will.
7
Sufficient acreage available in drilling unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes _
_ _ _ _ _ conform to. spacing_ requirements..
8
If deviated, is wellbore plat included _ _ _ _ _ _ _ _ _ ___ _ _ _ _
Yes
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
SFD 5/16/2019
13
Can permit be approved before 15 -day wait _ _ _ _ .... _ _ _ _
Yes _
_ _ _ _ _ _ _ _ .. _ _ _ ......
14
Well located within area and strata authorized by. Injection Order # (put 10# in. comments) (For.
NA . . .
. . . .......... _ _ _ ... _ _ _ _ ....
15
All wells.within 1/4 mile area of review identified (For service well only) _ _ _ _ _ ..
NA__ _
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -------
16
Pre -produced injector; duration of pre production lessthan3 months (For service well only) _ _
NA_ _ _
_________ _ _ _ _ _ _ _ _ ____ _ _ _ _ _ _ _ ____
17
18
Nonconven, gas.confonns to AS31,05.03Q0 .A).([.2.A-D) . . . . . . ............ . . . .
Conductor string.provided _ _ _ _ _ _ _ _ _ _ _ ____ _ _ _ _ _ _ _ _ _ _ _ _ __
NA. _ ...
NA.. _
- - - - - - - - - - .. - - - - --
_ _ _ _ Conductorset.forKRU_ 2F -Q7.
Engineering
19
Surface _casing protects all known USDWs _ _ _ _ .
NA. _ _
, . .
_ _ _ _ Surface casing set for KRU 2F-07,
20
CMT vol. adequate to circulate on conductor & surf_csg _ _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ ____
NA. _ _
_ _ Surface casing set and fully. cemented
21
CMT. vol adequate to tie-in long string to surf csg ....... _ _ _ _ _ _ _ _ _ ___ _ _ _ _ _
NA
....
22
CMT will cover all known productive horizons_ _ _ _ _ _
No
_ _ _ Productive. interval will be completed 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; all waste. to approved disposal wells. _
25
If a_re-drill, has_a 10.403 for abandonment been approved __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA_
26
Adequate wellbore separation proposed. _ _ _ _ _ _ _ .... _ _ _ _
Yes ..
_ .. Ant -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 4420 psig(13.4 ppg EMW); will drill w/ 8,6. ppg EMW and maintain overbal w/ MPD..
VTL 5/17/2019
29
BOPEs, do they meet regulation _ _ _ _ . - - - -
Yes _ _
_ _ _ ..
30
BOPE.press rating appropriate; test to (put psig in comments)__ _ _ _ _ _ _ _ _ _ _ _ _
Yes
_ .... MPSP is 3823 psig; will test BOPs_to 4000 psig.
31
Choke manifold complies w/API RP -53 (May 84).. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes
32
Work will occur without operation shutdown _ _ _ _ _ _ _ _ _ _______ _ _ _ _ _ _ _ ___
Yes
33
Is presence. of 1-12S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ...
Yes _
_ _ H2$ measures required.....
34
Mechanicalcondition of wells within AOR verified (For service well only.)____ ---
A.____
__------ ________..------- ___--------- ____ ......
35
Permit can be issued w/o hydrogen. sulfide measures - - - - - - - - - - - -- - - - - - --- - - -
No _ ......
Wells on 2F -Pad are_H2$cbearing._ H2S measures required._
Geology
36
Data presented on potential overpressure zones _ . _ _ . . . . . . .......... . . . .
Yes ...
_ .. _Max. potential res. pressure is 13.4 ppg EMW; expected res. pressure is 11.9 ppg EMW, Well will be
Appr Date
37
Seismic analysis of shallow gas zones ... . .. . . . .. . . . ....... . . . . . . . . ..
NA- - .
_ _ _ _ drilled using 8,6_ppg mud,_a coiled -tubing dg, and managed pressure drilling technique to control
SFD 5/16/2019
38
Seabed condition survey.(if off -shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___ _ _____ _ _ _ _ _ _ _
NA _
_ _ _ _ formation pressures and stabilize shalesections with.constant BHP of about11.8ppg EMW, _ _ .... .
39
Contact name/phone for weekly_ progress reports_ [exploratory only] _ _ _ _ _ _ _ _ _____
NA _
_ _ _ NOTE: Chance of encountering free.gas while drilling due to gas injection performed in this area... _
Geologic Date: Engineering Date Public Date
Commissioner: Commissioner: Commissioner
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