Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
JUL 11 2019
WELL COMPLETION OR RECOMPLETION REPORT A40166.%
Ia. Well Status: Oil ❑Q • Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑
20A 025.05 20AAC 25.10
GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions:
1b. Well Class:
Development Exploratory ❑
Service ❑ Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comps Susp., or
Abend.: 6/11/2019
14. Permit to Drill Number/ Sundry:
219-074 '
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded:
6/3/2019
15. API Number:
50-029-21076-60-00 '
4a. Location of Well (Governmental Section):
Surface: 565' FSL, 1570' FEL, Sec 28, T11N, R9E, UM
Top of Productive Interval: *1 6 (40-
1595' FSL, 1219' FEL, Sec 27, T11, R9:, UM
Total Depth:
4769' FNL, 56' FWL, Sec 26, Tt'I N, R9E. UM
8. Date TO Reached:
6/5/2019
16. Well Name and Number:
KRU 2F -07L1
9. Ref Elevations: KB:127
GL:98 . BF:
17. Field / Pool(s):
Kuparuk River Field/Kuparuk River Oil Pool
10. Plug Back Depth MDITVD:
NIA
18. Property Designation:
ADL 25657, ADL 25656
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 517658 • y- 5949448 • Zone- 4
TPI: x- 523284 y- 5950493 Zone- 4
Total Depth: x- 524564 y- 5949413 Zone- 4
11. Total Depth MDIfVD:
- 10638/6038 -
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 0 (attached) No ❑
Submit electronic and printed information per 20 AAC 25.050
13. Water Depth, if Offshore:
NIA (ft MSL)
21. Re-drill/Lateral Top Window MD/TVD:
• 864515973 -
22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days
of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential,
gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and
perforation record. Acronyms may be used. Attach a separate page if necessary
GR/Res
23, CASING, LINER AND CEMENTING RECORD
WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT
CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED
16 62.5 H-40 31 109 31 109 24 1 50s Cold Set II
95/8 36 J-55 31 3727 31 2889 121/4 104 0 sx AS 111, 710sx Class G
7 26 J-55 26 9051 26 6251 81/2 300sx Class G, 250sx AS 1
23/8 4.6 L-80 9130 10639 6024 6038 3 Slotted Liner
24. Open to production or injection? Yes ❑r No ❑
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
SLOTTED LINER @:
9139-10639 MD and 6025-6038......6/512019 COMPLETION
D TE
Zai
VER, IFI D
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
3 112 8434 8405/5812
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes ❑ No �
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD) AMOUNT 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
ITest Period
Oil -Bbl: Sas-MCF:
741536
Water -Bbl:
3631
Choke Size:
176
Gas -Oil Ratio:
722
Flow Tubing
P ess. 136
Casino Press:
117
Calculated
24 -Hour Rate
Oil -Bbl:
2
Gas -MCF:
1 380
Water -Bbl:
2
Oil Gravity- API (cerr):
1 NIA
AA
�.A
Form 10407 Revised 5/2017 V7_7_ 10131 `T ONTI U )N PAGE 2 Submit ORIGINIAL onl
�o�r % RBDMSd!UJUL 16 2019 orf r> G
28. CORE DATA Conventional Corals): Yes ❑ No ❑� - Sidewall Cores: Yes ❑ No ❑�
If Yes, list formations and intervals cored (MD/TVD, FromrFo), 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 ❑I -
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
8642
5971
information, including reports, per 20 AAC 25.071.
Formation @ TPI -Kuparuk A5
TD
10638
6038
Formation at total depth:
Kuparulk 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. productionr 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 66
Authorized Title: Staff CTD Engineer Contact Email: Shane.Germann co .com
Authorized7/////fContact 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 10407 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 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Form 10-407 Revised 5/2017 Submit ORIGINAL Only
2F-07 Final CTD Schematic
16'62# H-40 shoe
a 109' MD
9-&8'36#J-55 sh
G 3727' MO
uosaea: +wort-zo+e s�o
3-1/2" OTIS OLP SSSV (Locked Out 1/19/2000)
3-1/Z'9.39 J55 EUE 8rd Tubing to surface
3-1/2" Camra MMG gas IM mandrel at 2066', 4749', 68071, 8374'
MD
Baker PBR a 8391' MD (3" ID)
Baker FHL packer Q 8405' MD (3" ID)
3-1/2" Baker SOS @ 8433' MD
2F-071.1
TO = 10,639' MD
BOL =10.639' MD
Top of billet @ 9130' MD
2-3/8" slatted liner
21F-071.1-01
TO = 11,982' MD
SOL =11,850'MD TOL=8415'MD
2-3/8" slotted liner, jet cut at top
C4 -sand pads
a"
8554'- 85 MD
KOP @ 8645' MD
A5/4/3 -sandperfs
8638'- 8657' MD
_
674'- 8728' MD
778'- 8784' MD
7" 26# J55
shoe @ 9051' MD
uosaea: +wort-zo+e s�o
3-1/2" OTIS OLP SSSV (Locked Out 1/19/2000)
3-1/Z'9.39 J55 EUE 8rd Tubing to surface
3-1/2" Camra MMG gas IM mandrel at 2066', 4749', 68071, 8374'
MD
Baker PBR a 8391' MD (3" ID)
Baker FHL packer Q 8405' MD (3" ID)
3-1/2" Baker SOS @ 8433' MD
2F-071.1
TO = 10,639' MD
BOL =10.639' MD
Top of billet @ 9130' MD
2-3/8" slatted liner
21F-071.1-01
TO = 11,982' MD
SOL =11,850'MD TOL=8415'MD
2-3/8" slotted liner, jet cut at top
KUP PROD WELLNAME 2F-07 WELLBORE 2F-07
Well Altribut Max Angle l TD
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Alaska, Inc.
KUPARUe WeII APIU Well raSbtus 8 MD(, 9.0550lKKm
NUPARUK RIVER UNIT 50029210)600 PROD 588 2,d00.w 9.055.0
Camme,rt H151ppm) Dah AnnobNon End pay KB�GM IX He Releaea Dale
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Last Tag: RKB I 8,]95.0 I i
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OUT, UPDATE TAG
Casing Strings
CaaIng Descrlphon o1)(m) IDpn) TopinrcBl seme'H LIKED Sed heLVD)... WVL.u(I_.Grade Top Tneeea
CONDUCTOR 16 15.06 310 109.0 109.0 62.50 H-40 WELDED
�.n10
CONDUCTOR :M6W
Can, Deacnption 00 did IDpn) Top I11NB1 8el0eptl, MRB1 Set Loan (I'AS.--II-Sto TopTn—
SURFACE 998 876 30.9 3,726.8 2,888.8 3601) J-55 BTC
Oaeing DeMoodenOO 1101 1,S) Top(IKa) Set Depth Man 5a Depth LVD)... I.M. g...Go,le TOPI.
PRODUCTION J 6.28 260 9,051.0 6250.8 26W J-55 BTC
Tubing Strings
sAFSTY NLV: 1.p5a.0
Toeing Description snmg Ma... 11)1101 Top (rtKal set pepm (rt.. 5e1 Depin lrvp) (... wtIICM) ansae Top ccnnecnon
TUBING 3112 2.99 23fi 8,434.1 5,8315 9.30 J-55 EUESrO
Completion Details
Top LVD) TNP incl Norei—I
Top THIS) Ihtta) I°I hem ees Co. 10 tin)
GaSLIFT: Z.
23.6 23.6 __U7 HANGER FMC GEN II TUBING HANGER 3500
1,953.0 1,832.1 4. FEW VLV LP SSSV(LO K D 2000 LTRA 2812
PRESSURE
8,391.0 38026 4803 PBR BAKER PBR 3000
SuRFecE aGat.S_
8.404.9 5,812.0 —48—OT PA KER BAKER FHL 30W
8.421.3 5,822.9 4801 NIPPLE- CAMCO D NIPPLE, MILLED OUT TO 280"ON 616-19 28W
GAS UFT. a ]464
MILLED OUT
8,4333 5,6309 48.00 SOS AM EAR OUT -TTL ELMD@820' ONSW PPR 2.992
8292004
GSUFT.emla
Other In Hole (Wireline retrievable plugs,
valves, pumps, fish, etc.)
T,dHKB)
Top RD)
INKe)
ropmcd
(.1
out
Com
Run DIM IDpn)
8,645.0
5.972.8
4]70
WHIP T K
N LU N H ANSI N
923201 0.000
ws uFT; e.nu
OWA 0' ORIENTATION, TIED
ARTOWAT8646,
INTO K1 MARKER AT 6426' MD
INTO
PBS : Sams
88900
61402
4657
FISH
2 HOT KICK SPRINGS LOST 5.8'WIDE, 3.5"LONG
3232011 0.(00
8,894.0
6.142.9
66.5]
FISH
Original Completion PKR Leh in hole During workover
110IW1964
PACKER, a4W B
Perforations 8 Slots
sent
Dena
NIPPIE-MIUEt. S, sa.
ua+IATERu, S4ua
n eso4
—I
Top
am,6Me)
rep RD)
5MBI
B.Di
(mcel
unbemoe
IDM
IehOWa
1
type
cam
8.554.
SET
,564.0
5,9118
5, 1 .5
74.UNI B, 2F
-0)
1 198]
40 (PERF
30 Geg.'V Phasing,2LIP
EnerJel
.....a—
--8,6=8,85].0
5,968.1
5,980.8
A -5,21F47
1984
40 (PERF
M deg. hasmg C4
Schlum, Casing Gun
8,674.
8,]280
5,992.3
6,028.9
AJ, 2F-07
0 1984
40 .PERF
Gag. ang
Sudan, Casing Gun
IPERF. Sss4.oese4.o—
8,]] .
0784.0
6,063.1
8,067.2
A-3, 2F-07
413/19&
4.0 (PERF
Geg. hasing, 4"
Schlum. Casing Gun
Mandrel Inserts
m
NTap (N0) Vane tach Purti— TRO0.un
Top1)UlB) Ydi Mab .1 CB U.) Sery Type Type (ln) (psl Run Dole Com
1 2,0655 1,912.1 IMMH FMHO 1GAS LIFTGLV BK 0.188 1,2560 930.2019
7---4.749 3,520.1 MMH FMHO 1 LIFT OV BK 0250 CO 3130/2019
3 6,80).4 4,803.1 MMH FMHO 1 GAS LIFT 10MY BK 0000 00 2.1).2019
IPERR.Sae.a as
WNIPsrOCKaesoti—
6 8,344 5,]91.6 MMH FMHO 1 GA LIFT DMY 00 1 019 ml
durin
g pkr
repair
Notes: General 8 Safety
On! Dy" Annotation
7212019 NOTE: View SChematlCwl Alaska SChemagc10.0
IPERF:BaILCPINM Op
IPERF:B)1S.041i
FISN:9,ffil
FISH', 8SS4.0
PRODUCTION.D3000510
ConocoPhillips
Alaska. Im
KUP PROD WELLNAME 2F-07 WELLBORE 2F -07L1-01
asl
2smuat. 71106MM9 2n4:a PM
Last Tag
vereulz AvraOc I.)
Anaalaibn
Oeptn MKS) Eno Deh
WenEorc
Las, Maley
Last Tag'
2F-0lLt-01
Iennall
Last Rev Reason
MnaMnon
EM DnIeWeI1Mee
LaslMW ay
MONGER: De
REV REASON : CTDIATERAL
1'12019
2F-D7L1-61
Iennall
Casing Strings
caane0esonpiron oO pn) lO pn)
11-01 LATERAL 2418 1.99
rop lne9) Sal oepin nNai set DeplN Ta IN widen D... Gnae
8A149 11,864 6.012)L-80
rov rllreM
STL
Notes: General & Safety
Ena rale
I
Annstation
)/212019 INUIL
View$CnEmallCwl Alaska Scnemalici6a
cCNDUCTOR;at O.imO
SAFEW VLV, I MO
WS LIFT; ]f655
sURFgCE, �.&3, Y�63�
G0SLIFT;4,iN94
WSU".6,,8074
WS1RT:II37aa
saa a.%10
PACKER; B,aM
II
NIPPLE - MILLED WT', 9, 421
PRO W CTION: 9i.68,O51O
114a IATENq 8,4149-
n,8Er4
operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Sort Depth
Sian'rine
End Time
Dur (hr)
Phase
op Code
Activity Code
Time P -T -X
operation
(flKB)
End Dapth (MR)
6/1/2019
6/112019
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
6/112019
0.50
MIRU
MOVE
MOB
P
Arrive at 2F -Pad, drop jeeps
0.0
0.0
22:48
23:18
6/1/2019
6/2/2019
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
602019
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 & 112 -Way House
6/2/2019
6/2/2019
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
6/212019
6/2/2019
1.00
MIRU
WHDBOP
BOPE
P
Get shell test, Valve cm here service
0.0
0.0
09:30
10:30
tree
612/2019
6/2/2019
4.00
MIRU
WHDBOP
BOPE
P
Start full initial ROPE test. Test
0.0
0.0
10:30
14:30
witness waived by Jeff Jones,
AOGCC. Test complete. No fail /
passes
6/212019
6/212019
1.20
MIRU
WHDBOP
PRTS
P
Make up nozzle. stab on injector.
0.0
0.0
14:30
15:42
Circulate coil. Line up and test inner
reel valve, inner reel iron, and packoff
61212019
612/2019
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 @ 1 °
6/2/2019
6/2/2019
1.30
MIRU
WHDBOP
PRTS
P
PT Tiger an & PDL's to 2500 PSI,
0.0
0.0
16:00
17:18
Gear floor, PJSM
6/2/2019
6/2/2019
1.70
PROD1
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
6/2/2019
6/2/2019
1.70
PROD1
WHPST
TRIP
P
RIH w/ BHA#1, holding 1 -tor -1 returns
77.0
8,425.0
19:00
20:42
6/2/2019
6/2/2019
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
PROD1
WHPST
DLOG
P
Log HRZ for+23'correction
8,230.0
8,285.0
21:00
21:12
612/2019
6/2/2019
1.30
PROD1
WHPST
DISP
P
Continue RIH, flush well -bore w/
8,285.0
8,600.0
21:12
22:30
seawater, displace to milling fluid,
close EDC
6/212019
612/2019
0.20
PRODt
WHPST
DLOG
P
Obtain SBHP: MID _bit = 8600,
8,600.0
8,600.0
22:30
22:42
TVD sensor = 5910.9', pressure-
ressure=3802
3802psi, EMW = 12.37 ppg
6/212019
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
PRODi
WHPST
WPST
P
Milling from 8645.6', FS = 766 psi @
8,645.6
8,647.3
22:48
00:00
1.9 bpm, CWT = 1 OK, WOB =.6K,
annular = 3808 psi, WHP = 482 psi
Rerturns fell off to 1.7 bpm out at
8646.2', began holding 1 -for -1
Page 1113 ReportPrinted: 611412019
Uperations Summary (with Timelog Depths)
/
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Tim
Dur (hr)
Phase
Op Code
Acbmly Code
Time P-T-X
Operation
(flKS)
End Depth (Rol)
6/3/2019
6/3/2019
2.40
PROD1
WHPST
WPST
P
Milling from 8647.3', CWT= 12.2K,
8,645.6
8,647.3
00:00
02:24
WOB = 2.21K, annular = 3815 psi,
WHIP = 454 psi, pump = 4616 psi,
BOW called at 8648.7'
Continue control milling, CWT 12.7K,
WOB = 0.21K, pump = 4522 psi
6/3/2019
6/3/2019
2.40
PRODi
WHPST
MILL
P
String reamer ei#s window, begin
8,647.3
8,670.0
02:24
04:48
pushing on it milling rat-hole, CWT
=1 OK, WOB = 3.2K
6/3/2019
6/312019
1.10
PRODt
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
6/312019
1.40
PRODi
WHPST
TRIP
P
POOH, PUW=29K. Stop @ 8627 open
8,670.0
65.6-
05:54
07:18
EDC
6/3/2019
6/312019
1.40
PROD1
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
6/312019
0.70
PROD1
DRILL
CTOP
P
M/U Noule. Flush stack and rig. Blow
0.0
0.0
08:42
09:24
down Mico Motion
6/3/2019
6/312019
1.20
PROD1
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
counters
6/3/2019
6/312019
1.50
PRODt
DRILL
TRIP
P
RIH BHA *2, EDC open
72.1
8,225.0
10:36
12:06
6/3/2019
6/312019
0.30
PROD1
DRILL
DLOG
P
Log formation tie in for-11.5'
8,225.0
8,280.0
12:06
12:24
6/3/2019
6/312019
0.30
PROD1
DRILL
TRIP
P
Continue in hole. Stop @ 8627 shut
8,280.0
8,671.0
12:24
12:42
EDC, PUW=33K. Continue in. Clean
pass through window tag up @ 8671
6/3/2019
6/312019
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
6/312019
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
1
1
1 BHA #2
6/3/2019
6/3/2019
1.00
PRODi
DRILL
PULD
P
Late decision to run Ironside 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°
6/3/2019
6/3/2019
1.60
PRODi
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 lest. 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' shallow test
80.0
8,220.0
1936
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 2/13 Report Printed: 6114/2019
Operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
Dur(h)
Phase
Op Code
Activity Code
Time P -T -x
Operation
rtKB)
End Depth(flKB)
6/3/2019
6/3/2019
0.10
PROM
DRILL
DLOG
P
Log formation for -11.5'
8,220.0
8,299.0
2224
22:30
6/3/2019
6/3/2019
0.30
PROD1
DRILL
TRIP
P
Continue in well, 8585 PUW=35K
8,299.0
8,670.0
22:30
22:48
6/3/2019
6/3/2019
0.10
PROD1
DRILL
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
0.10
PROD1
DRILL
TRIP
P
Continue in well
8,685.0
8,760.0
22:54
23:00
6/3/2019
6/4/2019
1.00
PROD1
DRILL
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=9.5K, DHWOB=I.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
PROM
DRILL
DRLG
P
Drilling from 8922', CWT= 8.91K, 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 (at
9170'), PU off bottom, PUW = 41 K,
trouble shoot & reset tool, go back to
drilling
6/4/2019
6/4/2019
0.20
PRODt
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
PROD1
DRILL
WPRT
P
Wiper in-hole, RIW = 10.61K
8,760.0
9,203.0
02:18
02:30
6/4/2019
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 = 1.61K,
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
PRODt
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
PROD1
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
PROD1
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, & RS A3 bit)
6/4/2019
6/4/2019
1.60
PRODt
DRILL
TRIP
T
RIH w/ BHA #4, shallow test tools,
80.0
8,225.0
09:12
10:48
pumping 1.84 bpm, dp = 1450 psi,
pump = 4980 psi
6/4/2019
6/4/2019
0.30
PRODt
DRILL
DLOG
T
Log HRZ for -11' correction
8,225.0
8,273.0
10:48
11:06
6/4/2019
6/4/2019
0.60
PROD1
DRILL
TRIP
T
Continue RIH
8,273.0
9,425.0
11:06
11:42
Page 3113 Report Printed: 6/14120191
Uperations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
sten Depen
Start Time
End Time
Der(hr)
phase
Op Code
Activity Code
Time P -T -x
Operation
(fiKB)
End Depth(flKB)
6/4/2019
6/4/2019
3.80
PROD1
DRILL
DRLG
P
Drilling from 9425, CWT = 10.51K,
9,425.0
9,588.0
11:42
15:30
WOB = 3K, annular = 3983 psi, WHIP
= 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
PROM
DRILL
DRLG
P
Drilling from 9588', CWT = 8.2K, WOB
9,588.0
9,825.0
15:30
16:54
= 1.61K, annular = 4015 psi, WHP =
547 psi
6/4/2019
6/4/2019
0.30
PROD1
DRILL
WPRT
P
PU Wt 40 k lbs 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 lbs - 0.39 bbls
9,031.0
9,825.0
17:12
17:30
cuttings returned on wiper
6/4/2019
6/4/2019
3.60
PRODi
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 lbs, 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
P
PU Wt 40 k lbs PUH on wiper #2
10,225.0
9,425.0
21:06
21:24
6/4/2019
6/4/2019
0.40
PROD1
DRILL
WPRT
P
RBIH - 0.40 bbls cuttings returned on
9,425.0
10,225.0
21:24
21:48
wiper
6/4/2019
6/5/2019
2.20
PROD1
DRILL
DRLG
P
CT 5218 psi Q 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 lbs, 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
PROD1
DRILL
DRLG
P
Drill ahead
10,480.0
10,499.0
00:00
00:12
6/5/2019
6/5/2019
1.20
PROW
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.
615/2019
6/5/2019
0.20
PRODt
DRILL
WPRT
P
Jet the 7" while pumping a bottoms
8,637.0
8,225.0
01:24
01:36
1
1
1
up.
6/512019
6/5/2019
0.30
PROM
DRILL
DLOG
P
Tie into HRZ for+ 1.5' correction.
8,225.0
8,620.0
01:36
01:54
6/5/2019
61512019
0.20
PROM
DRILL
DLOG
P
RIH to 8620.48 CTMD / 5922.37' 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
6/5/2019
6/5/2019
1.10
PROD1
DRILL
TRIP
P
PU, Ct Wt 35 k lbs - RBIH to bottom
8,620.0
10,499.0
02:06
03:12
0.65 bbls cuttings returned on long
wiper
Page 4/13 Report Printed: 611 412 01 9
.' Operations Summary (with Timelog Depths)
s 2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Stan Time
End Time
Dtx (hr)
Phase
op code
Activity Code
Time P -T -X
0pmalion
(M1KB)
End Depth (eKB)
6/5/2019
6/5/2019
1.50
PROD1
DRILL
DRLG
P
CT 5350 psi @ 1.88 bpm in and 1.83
10.499.0
10,606.0
03:12
04:42
bpm out, Free spin diff 1451 psi, WH
685 psi, IA 794 psi, OA 52 psi. BHP
4116 psi, targeting 12.8 ppg @ the
window. CT Wt 1.4 k lbs, WOB 1.4 k
lbs
10,519', PU Wt 36 k lbs
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, WHIP = 645 psi, pump = 5312,
PUW = 38K from 10,638', stack
weight RBIH at 10,628', stall at
10,638', PUW = 45K
6/5/2019
6/512019
0.30
PROD1
DRILL
WAIT
T
Fluid leaking past o -rings on QTS, PU,
10,638.0
8,620.0
06:36
06:54
determine path forward
Plan Forward: PUH to window, allow
TD 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
6/512019
4.60
PROD?
DRILL
COND
T
At window, shut bag, obtain SBHP,
8,620.0
8,620.0
06:54
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
1.00
PROD1
DRILL
TRIP
P
Open bag, begin pumping 13.07 ppg
8,620.0
9,715.0
11:30
12:30
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
PROD1
DRILL
DISP
P
POOH to 7183, PUW = 41 K, KWF at
8,620.0
7,183.0
12:30
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
6/512019
6/512019
1.50
PRODt
DRILL
DISP
P
Pump additonal 10 bbl KWF in attempt
7,183.0
7,183.0
14:18
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
PROM
DRILL
COND
Transfer 13.13 ppg KWF from truck,
7,183.0
8,629.0
15:48
16:24
1
1
build LRP, pump down to bit
6/5/2019
6/5/2019
0.60
PROM
DRILL
TRIP
RIH, stack weight at -8650',
8,629.0
9,700.0
16:24
17:00
attempting 1 OL & 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 White Flag @ 7080'
Good 13.1 ppg KW returned to
surface
Page 6113 ReportPrinted: 6/1412019
Operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(W)
End Depth mK8)
6/5/2019
6/5/2019
0.30
PRODi
DRILL
OWFF
Park at 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
COMPZI
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 lop 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.
616/2019
6/6/2019
0.10
COMPZI
CASING
PULD
P
Continue to PU BHA# 5, Li 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 L1 completion
1,553.3
8,570.0
00:06
01:30
6/6/2019
6/6/2019
0.10
COMPZ1
CASING
DLOG
P
Tie into while window flag for -16.8'
8,570.0
8,553.2
01:30
01:36
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 TO 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
COMPZI
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 bible 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
latteral 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
TRIP
P
RIH w/ BHA#6, shallow test 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
5/6/2019
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
6/612019
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
6/6/2019
6/6/2019
0.90
PROD2
STK
KOST
P
Tag TOB pumping at 91263, 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 ft, dp 880 psi
Page 6113 ReportPrinted: 6/14/2019
Operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Steri Tme
End Tine
our (M
Phase
Op Code
Activity Code
Time P -T -X
Operation
(WB)
End Dep1h(ftKB)
6/6/2019
6/6/2019
0.60
PROD2
STK
KOST
P
Milling at 2 fph for 1 ft
9,127.3
9,128.3
10:18
10:54
6/612019
6/612019
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
6/612019
0.60
PROD2
STK
KOST
P
Increase to 9 fph for 5 It
9,129.3
9,134.3
11:12
11:48
6/6/2019
616/2019
0.50
PROW
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, WHP = 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, WHP = 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'
6/612019
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, WHP = 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 = 8.5K, WOB = 1.3,
9,441.0
9,521.0
16:00
17:12
annular = 4094 psi, WHP = 705 psi,
pump = 4773 psi
6/6/2019
61612019
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
6/612019
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 fl/hr
6/612019
6/6/2019
0.30
PROD2
DRILL
WPRT
P
PU Wt 36 k lbs, PUH on wiper #2
9,930.0
9,150.0
20:30
20:48
6/6/2019
6/6/2019
0.40
PROD2
DRILL
WPRT
P
RBIH, RIH Wt 9.2 to 7 k lbs, hole
9,150.0
9,930.0
20:48
21:12
clean - 0.45 bbls cutting returned on
the trip.
6/6/2019
6/7/2019
2.80
PROD2
DRILL
DRLG
P
CT 4746 psi @ 1.9 bpm in and 1.9
9,930.0
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 ft/hr
6/712019
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 ft/hr
6/72019
6/712019
0.60
PROD2
DRILL
WPRT
P
PU Wt 38 k lbs - PU hole on long
10,360.0
8,625.0
01:54
02:30
1
wiper to window - window clean
6/7/2019
6/72019
0.40
PROD2
DRILL
CIRC
P
Jet the 7", Circulate bottoms up PU Wt
8,625.0
8,630.1
02:30
02:54
I
35 k lbs.
Page 7/13 Report Printed: 6/14/2019
Operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
our (hr)
Phew
Op Code
Activity Code
Time PJA
Operation
(110)
End Depth(flKB)
6/7/2019
6/7/2019
0.20
PROD2
DRILL
DLOG
P
Park@ 8630'/5929' CTMD7fVD and
8,630.1
8,630.1
02:54
03:06
measure BHP
time(min) Pipet) 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
617/2019
0.10
PROD2
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
617/2019
0.70
PROD2
DRILL
TRIP
P
RBIH, billet dean.
8,691.8
10,360.0
03:12
03:54
6!7/2019
6/712019
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
lbs, PUW = 41K from 10,603
6/7/2019
6/7/2019
1.00
PROD2
DRILL
DRLG
P
Drilling, CWT = -5.6K, WOB = 1 K,
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'
6/7/2019
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 consistent ROP)
CWT = 1.6K, WOB = 1.3K, annular =
4235 psi, WHP = 634 psi, pump =
5058 psi
6/7/2019
6/7/2019
0.30
PROD2
DRILL
WPRT
P
Wiper up -hole, PUW = 38K
10,790.0
9,940.0
08:18
08:36
617/2019
6/7/2019
0.40
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW = 7K
9,940.0
10,790.0
08:36
09:00
617/2019
6/712019
1.30
PROD2
DRILL
DRLG
P
" CR drilling targeting 250 fph, unable
10,790.0
10,908.0
09:00
10:18
to maintain consistent 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)
6/72019
6/7/2019
1.40
PROD2
DRILL
DRLG
P
"CR drilling targeting 200 fph
11,008.0
11,189.0
11:24
12:48
Pump tubed 5x5 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
6/7/2019
6/7/2019
0.50
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW=2K
10,264.0
11,189.0
13:06
13:36
677/2019
6/7/2019
0.50
PROM
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 8/13 Report Printed: 6/1412019
Operations Summary (with Timelog Depths)
2F-07
I&
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
start Time
End Mme
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operedon
(ftKB)
End Depth (ftKB)
6/7/2019
6/7/2019
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 BHA wiper, PUW = 40K, pump 10
bbl lubed 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 = 1.31K, 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
6/7/2019
6/7/2019
3.20
PROD2
DRILL
TRIP
P
POOH to inspect/replace tools, dp =
11,274.0
6-5 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',
close 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.
" QTS O -rings cut badly, appears as
if stack is of centered up exactly, had
issues with quick union on PDL
bemuse of alignment.
6/7/2019
6/7/2019
1.00
PROD2
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#7, 0.6° AKO inteq motor
0.0
78.0
21:36
22:48
with NOV agitator and BH RB
Dynamus bit.
6/7/2019
6/812019
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
dosed. Shallow agitator test good, diff
of 954 psi @ 1.83 bpm strong surface
vibrations felt in the ops cab.
6/8/2019
6/8/2019
0.40
PROD2
DRILL
TRIP
P
Continue to RIH W BHA #7
5,922.0
8,235.0
00:00
00:24
6/8/2019
6/82019
0.20
PROD2
DRILL
DLOG
P
Tie into the HRZ for a -14' correction.
8,235.0
8,276.5
00:24
00:36
6/8/2019
6/8/2019
0.20
PROD2
DRILL
DLOG
P
Park@ 8600'/5910' CTMD/TVD and
8,276.5
8,600.0
00:36
00:48
measure BHP
time(min) P(psi) EMW(ppg)
initial 3991 12.98
1 3986 12.97
2 3984 12.96
3 3983 12.96
5 3982 12.96
6.82019
6118/2019
1.10
PROD2
DRILL
TRIP
P
FU 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: 6/1 412 01 8
i Operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
start Time
End Time
our (hr)
Phase
Op Code
AcvvityCode
Time P -T -X
Operation
(WIR)
End Depth (MB)
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' retums fell to 1.26 bm then
healed to 1.8 bpm.
11,419' PU Wt 39 k Ibs
11,442' PU Wt 41 k Ibs
11,503' PU Wt 45 k lbs
Average ROP 76.3 ft/hr
6/8/2019
6/8/2019
2.40
PROD2
DRILL
DRLG
P
CT 4830 psi, 1.88 bom 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
PROD2
DRILL
DLOG
P
Obtain SBHP, MD = 84637,
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
correcton, clean past window & billet,
RM =
6/8/2019
6/8/2019
2.00
PROD2
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 = 1K, annular =
4252 psi, WHIP = 668 psi, pump =
4873 psi, avg ROP = 59 fph
6/8/2019
6/8/2019
0.90
PROD2
DRILL
DRLG
P
CR drilling, 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
618/2019
3.20
PROD2
DRILL
DRLG
P
Drilling, CWT = -0.7K, WOB = 1.2K,
11,831.0
11,947.0
13:48
17:00
annular = 4306 psi, WHIP = 617 psi,
pump = 5282 psi PUW = 53K @
11,876', BHAwiperfrom 11,877',
pump 5x5 sweeps, drill to TD 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, WHIP = 620 psi,
pump = 5308 psi
6182019
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
PROD2
DRILL
WPRT
P
POOH on swab wiper
8,433.0
64.0
20:30
22:00
618/2019
6/8/2019
1.00
PROD2
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 V. QTS 0 -
rings only slightly cut.
Page 10113 Report Printed: 6/1412019
Operations Summary (with Timelog Depths)
d. 2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Stan rime
End Time
our (hr)
Phasa
Op Code
Aceviry Code
Time P-T-X
Operation
(RKB)
End Dept (flKB)
6/8/2019
6/8/2019
0.50
PROD2
DRILL
BOPE
P
Function lest the BOPE - Good
0.0
0.0
23:00
23:30
6/8/2019
6/9/2019
0.50
PROD2
DRILL
CTOP
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 -19.5' 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 anus, PU Wt 43 Is lbs, PUH
11,933.0
8,700.0
04:54
0618
logging caliper @ 40 ft/min.
6/9/2019
6/9/2019
2.40
PROD2
DRILL
TRIP
P
Close caliper arms, POOH w/ BHA#8,
8,700.0
18.0
06:18
08:42
PJSM
6/9/2019
6/9/2019
0.50
PROD2
DRILL
PULD
P
LD BHA#8
18.0
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
0.0
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
72.0
8,230.0
10:12
1142
6/9/2019
6/9/2019
0.50
PROD2
DRILL
DLOG
P
Log HRZ for-14' correction, PUW =
8,230.0
8,271.0
11:42
1212
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
1236
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
350'-
MAD Pass: 9000'- 9100', 9350'-
1
1
1
19450',
9450', & 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 obsemble 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
1900
19:30
Page 11113 ReportPrinted: 6/14/2019
Operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Sten Tlme
End Time
Dw(m)
Phase
Op Cade
Activiy Cade
Time P -T -X
Operation
(ttKB)
End Depth(flKB)
6/9/2019
6/10/2019
4.50
COMPZ2
CASING
PUTB
P
PU L1-01 completion, 111 joints
0.0
2,734.0
1930
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 L1-01 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
COMPZ2
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 -157, 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
COMPZ2
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
COMPZ2
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
CASING
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', sqeeze 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 w/town, 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- 6285.16'
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
PJSM, 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 chives & tools
Page 12113 Report Printed: 611412019
Operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
stan,nme
End Time
our (hr)
Phase
Op Code
Activity Code
Time P-TA
Operation
(WB)
End Depth (WB)
6/11/2019
6111/2019
0.50
COMPZ2
CASING
ELNE
P
Complete RU a-line & tools
0.0
0.0
00:00
00:30
6/11/2019
6/1112019
4.00
COMPZ2
CASING
ELNE
P
RIH w/ e-line & 1.68" jet cutter, tie in
0.0
8,393.0
00:30
04:30
and Cul 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
COMM
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, slab on,
0.0
44.0
06:30
07:30
bump up and set conters.
6/11/2019
6/11/2019
1.40
COMPZ2
CASING
TRIP
P
RIH, lost 18 bbls KW on the trip in.
44.0
8,215.0
07:30
08:54
6/11/2019
6/11/2019
0.20
COMPZ2
CASING
DLOG
P
Tie into the HRZ for- 15' correction
8,215.0
8,249.4
08:54
09:06
6/11/2019
6/11/2019
0.20
COMPZ2
CASING
TRIP
P
PU Wt 33 k lbs, RIH find TOL @
8,249.4
8,281.0
09:06
09:18
8281'. PU, -500 lbs WOB broke back
to -365 Isb, CT Wt 33 Is lbs.
RBIH, SID 8280.5, PU-400 Itis WOB,
6/11/2019
6111/2019
1.50
COMPZ2
CASING
TRIP
P
POOH with fish -lost
8,249.4
174.0
09:18
10:48
6111/2019
6111/2019
0.70
COMPZ2
CASING
PULD
P
LD BHA#11
174.0
130.0
10:48
11:30
6/11/2019
6111/2019
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
611112019
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
6/1112019
6/11/2019
0.20
COMPZ2
CASING
DLOG
P
Tie into HRZ for -14' correction
8,220.0
8,248.0
13:54
14:06
"Measure BHP of 3845 psi
826075588' 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,
6111/2019
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 TWO = 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 2-318" rams to be in
question.
6/11/2019
6/11/2019
1.50
DEMOB
WHDBOP
RURD
P
Work on dg move check list, prep
0.0
0.0
20:36
22:06
cellar for nipple down, remove IA and
OA tranducers, unhook PUTZ, rig
down high pressure lines, prep dg for
move.
6/11/2019
6/1112019
1.50
DEMOB
WHDBOP
NUND
P
Nipple down stack (BOPE)
0.0
0.0
22:06
23:36
6111/2019
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 13/13 Report Printed: 6114/2019
I
ConocoPhillips
ConocoPhillips Alaska Inc_Kuparuk
Kuparuk River Unit
Kuparuk 2F Pad
2F -07L1
50-029-21076-60
Baker Hughes INTEQ
Definitive Survey Report
18 June, 2019
BA. ICER
UGHES
Fmmpw
ConocoPhillips
BAS A
ConocoPhillips
Definitive Survey Report
Company ConocoPhillips Alaska
Local Coordinate Reference: Wall 2F-07
Project: Inc_Kuparvk Kupawk River Unit
TVD Reference: 2F-07 @ 127.00us0 (2F-07)
SM: Kupabk 2F Pad
MO Reference: 2F-07 W 127.01(2F47)
Well: 2F47
North Reference Troe
Wellbd.d 2F -07L1
Survey Calculation Named: Minimum Curvature
Dalen: 2fri
Database: EDT 14 Akska Production
Project Kupa.k River Unit, Norm Slope An.". United Stales
Map System: US State Plane 1927 (Exact solution)
System Datum: Mean Sea Level
Geo Dab.: NAD 1927(NADCON CONUS)
Using Aell Reference Peinl
Map Zone: Alaska ZaroW
Using geodetic scale factor
Wei 2F-07
Well Position asi O.OD an
Northing: 5.849,446.14uah
Lialtude:
70°16'23.018N
+W -W 0.00 unit
Emant: 517,658.31ush
Longitude:
149°51'25.B30W
Fashion Uncedalmy 0.00 uah
Wellhead Eleva0on: Usk
Ground Leval:
0.00 unit
Matters 2F-0711
Magnatlds Mo&l Name Sampo Dab
Deadhead. Dip Angle
Fleld Stfen9tlt
(9
(I
Inn
BGGM2010 4T3I2019
18.57
80.81
57.411
Uesign 2F -07L1
Audit Nates:
Version: 1.0 Phase'. ACTUAL
Te On Depth: 8.600.00
Vertical 5ee0od Depth From[TVD)
eW$ +E4Y
pleaded
(usft)
tui luso)
PI
127 00
0.00 0.00
160.00
Survey Program Date
From To
Survey
Sunday
hush) (-am Survey(Wellbo.)
Tool Name Description
Sort Deb
EM Data
200.00 0,600.00 2F-07121`-07)
SEEKER MS BHI Seeker deadhead
111212001
6,642.00 8,732.17 2F-0711 MWD-INO(]F-0711)
MWD-IN000NLY MWDINC_ONLY_FILLER
61412019
612019
8756.25 10,585.80 2F4171.1 MWD DF -071.1)
MWD OWSG OVi MM - Standard
61512019
WSWI;
&10,2019 9:07:54AM
Page 2
COMPAS55000. f4 &tiW 850
Survey
ConocoPhillips
Conoc( Phillips
Definitive Survey Report
Company ConocoPhillips Alaska Inc_Kupemk
Local Co-onimate Reference:
Wa112F-0T
Project, Kuparuk River unit
WO Reference.
2F -O7 Qi1127.00usft DF4)])
SRe: Kupamk 2F Pad
MD Reference:
2F-07@127.01uah(2F47)
Well: 2F47
Nonh Reference:
This
Wellbore: 2F-0711
Survey Calculation Methal
Minimum Curvature
Duslgn: 2F -07L1
Database'.
EDT 14 Alaska Production
Survey
Annotation
TIP
KOP
Interpolated Azimuth
Interyolaud Azimuth
InteRlolated Azimuth
6/182019 9O754AM Page3 COMPASS WOO 14 Build 056
Map
Map
Vertical
MD
M)
TVD
TVO55
♦NIS
9E1 -W
Northing
Easting
DL5
Section Survey Tool Name
(..I"1%
11
1°I
lusnl
lucnl
(ush)
lush)
IRI
Ihl
I°1100'1
IRI
8,660.00
47,97
80.23
5842.%
5,81555
1O26fie
5,597.02
5,950.48].85
523,253.16
038
-1,026.66 MWDINC_ONLY (2)
8,642.00
47]2
79.93
6lln. 5
5043.75
1,032.05
5029.49
5&`0,493.
52328381
0.80
-1,032.05 MWDMC ONLY (2)
8.8]3.48
55M
81,50
5,990.3"
5.3.35
105.00
5,052.78
5,9611.497.M
523.300.09
2414
-1,036.. MW0.1NC ONLY(2)
am.15
7063
SCID
600301
5,876.81
1,Otizo
567088
5,9..50095
523.3N.17
52.04
-103960 MW0.1NC ONLY (2)
6]32.1]
slow
84.80
6,.9.98
5,882.96
1,04287
5,][6.87
59-0,504.29
523.%R.25
4935
-1,042.87 MVVWNL ONLY (2)
8,75630
9634
8504
6,.9.]0
5882.70
1,045.17
5niO.91
5960.505.64
5233186.18
47.85
-1,045.17 MWD OW3G (3)
8789.15
9378
8.09
6,0..60
5,07880
1,048.04
57WS4
595050860
523.418.80
7.80
-1.04804 MWD OWfiG(3)
8822.3¢
86%
8,10
6,0..8
5,87804
1,050.94
6796.62
5,950,512.57
523,451.07
1492
-1050.04 MMAD MSG (3)
8.850.%
as'.
%,61
6,0].53
5,88053
1.O53.n
5,824.77
5,9`50.514.92
523.480.01
13.45
-105322 MW0 OW6G (3)
8000.81
8227
8128
6,010.0
5.88383
1,055.07
5854.47
5953,516.8
523.60911
10.93
-1,0550] MWD OVWSG (3)
8,81493
838
91.%
6,015.22
5,888.22
105541
5,8%.50
5.950,517.20
523.54373
12.57
-1,055.41 MWD GWSO (3)
8,845.W
8545
WW2
6.80.29
5,091.29
105379
5,91897
5,960,515]1
523.574.
12.41
-1,053.]9 MWD ONSG (3)
8,974.71
8865
97,30
6,019.79
5882.]8
1,Oaltso
CWS8
5,9.,51278
43.603.11
14.55
-1,050. MWD OW6G (3)
9,000.01
69.
10.68
6,25029
5,08339
1,046.85
69R%
5.050508.88
523.48.10
13.50
-1,8685 MIND MSG (3)
9030.49
06.37
1.B7
692.97
5,893.97
1.040.34
602.62
5950,50240
523.057.85
11.01
-1,80.34 MWD MSG (3)
901M
0]]0
18.58
6022%
5,095.te
1,032.59
6.O33.W
5,950.48]0
523,60634
2.80
-1,032.59 MWD OWSG(3)
9,06037
88.16
106.47
6.023..
5896.07
1025.25
6,060.43
5,950,407.51
523,71511
3.53
-1,45.25 MWD DWSG (3)
9.1211.86
8]]9
105.29
6.024.15
5887,15
1,017.14
6,050.90
5.950,4]9.4]
523]45.20
1.34
-1,01114 MWDO MSG (3)
9.148.95
akt 6
lwGdkt
6,02490
5.897,90
1.08.18
6.1128
5.950.4]1.5]
523.]]3.19
650
-1009.18 MWD OW6G(3)
%tau.
e]]9
10]8
6.45.69
5.89869
notion
6147.10
5,950.462.36
523.80243
0.89
499.90 MWD OM6G (3)
9 2102
8].05
10.5
6,4703
590003
90.21
6,175.19
5,95`,452]4
523.83054
296
990.21 MWD OWSG (3)
9244.05
86.55
14.9
6,0211.91
5,901.91
979.16
6,206.8
5,960,441.M
523.%2.32
1.53
679.16 MWD OWSG (3)
UM.7O
8745
1%]7
6,03031
5,803.31
970.4
6,=11
5,00,43318
523,807.51
3.64
-97052 MWD OWSG (3)
9.38.63
67.6,4
1%.61
6031.67
5,98.67
959.65
6,28.23
5,950.422.38
523,919.0
152
.5866 MWD OWBG (3)
9,330.81
07.00
11O17
6,.2.4
5,90562
90.97
6,2..91
5.950.413.76
523.93".3"
5.
950.97 MMD PNSG I3)
9.36,0.8
OOSG
11249
6.033.48
5,9%.48
9,116
6316.59
5,950.48.4
523.9728
IU3
-940.16 MWD OWSG (3)
9.389.95
80.50
112.12
6,63.16
5907,16
41190
6.3"3.03
5.950,391.91
43,999.31
1.68
-SWS8 MWD OWSG (3)
9.420.51
80.31
11331
6,05.55
590055
917.21
63]195
5.SSd38021
524.47.45
B1.
.1721 MWD OWSG(3)
940.43
85.12
1150
607.78
591D.78
9895
63on.16
5960.360.8
524,054.69
711
98.98 MWD ONSG (3)
940555
84.%
114.87
5,D4O8
5,91394
80.21
6,430.87
5,950.353.35
44053.43
170
-090.21 MWD OWSG (3)
Annotation
TIP
KOP
Interpolated Azimuth
Interyolaud Azimuth
InteRlolated Azimuth
6/182019 9O754AM Page3 COMPASS WOO 14 Build 056
ConmoPhillips
GonocoPhillips
Definitive Survey Report
Compiler
OonowPhillips Alaska
lnc_Kupamk
Local Co-ordinate Reference:
WbIl 2F47
Protect:
Kupamk River Unit
ND Reference:
2F-07®127.00usfl
DF -07)
Sete:
Kupamk 2F Pad
MD Reference:
2F-07(]
127.00usn(2F47)
Well:
2F-07
Nonn Relerence:
Thus,
We11Eom:
2F-07LI
Survey Calculation Method:
Minimum Curvature
Design:
2F -07L1
Database:
EDT 14 Alaska Pmduction
Survey
i
Map
Map
Vertical
MD
Inc
Aal
TVD
TVDSS
9W4
.F7-WUS
NOrteing
posting
6edlen Survey ]001 Name
Annotation
IueM
1°I
1°I
luznl
luznl
luso)
(us")
Int
Int
1°1+907
Int
9.511.88
0601
115.56
6,042,92
591592
879.03
645.
5.950,342,23
52411022
8.93
-B>903 MWDOWSG(3)
r
9.554,57
saw
118.88
6,0".50
5,917.56
859.52
6,49255
5,950n101
524,148.18
906
-859152 MWDMSG(3)
9,573.12
88.25
11936
6.045.
5,918,03
no.
6,alM]4
5950.31302
524.184.39
4,46
850.49 MWDMSG(3)
9,601147
87.12
M.
6,04514
5,91983
03607
San.
5,950,3.28
524.188.11
552
4836.87 MWD MSG (3)
�
9,632.45
87]0
1]165
6,04759
5,92059
020.9
6,559.67
5950.283,62
524,215.36
7.29
820.17 MWD MSG (3)
j
' 9.888.95
57.24
125.15
8,04920
E.W.
mm
6,5..93
5,950.IDJ.38
524245.69
6.98
-200.00 MWD OW6G (3)
9,715.0
91.12
13036
6,049A5
ESZ145
77161
6626.39
5,950,23521
52428221
1547
-77161 MWD MSG (3)
9,74503
91.14
130.53
6.0alad
5,921,60
752.19
6,649.16
5950,215.85
524.305.03
3.32
452.19 MND MSG (3)
9,77341
90.37
13103
6.04033
5,921.23
733.66
6,670.65
5950197.37
524.326.56
323
-M.88 MWD MSG (3)
-
8888.75
09,36
13,17
6,040.31
5,921,31
710.42
6,697.28
5950,94.21
524.35324
289
-710.42 MWD MSG (3)
9,838,69
6932
132.88
6,015.88
5921.
WhX
6,719,50
5950.154.211
524.37550
605
-690.. MND MSG (3)
9,677,92
09.n
134.41
8.046.99
5,921.%
88328
6.74787
5,9..127.17
524403.93
3.78
-66325 MNOOWSG(3)
9'...
09.36
137.35
6.049.17
5922.9
646,60
6,763.83
5,950.11074
524419.93
1291
-646.88 MND OWSG(3)
9.94501
91.94
139."
6.048.60
5,921.88
61320
6,793.67
5.0,07721
524.449,85
739
813.20 MND MSG (3)
9,97549
9261
141n
6047.48
5,SWAS
589.97
6.81210
5,950,054.03
524,46(.33
14.59
58997 MNDOWSGD)
t0,W993
9018
14832
6,046.64
5,918.64
581,42
A3133
5,950,02554
524,487.63
15.10
56142 ratio MSG (3)
10.03893
91.23
150.04
8.831
5,919.31
538.24
6,645.17
5,950,00239
524501.51
7.46
53a24 MND M53 (3)
10AM'SO
9283
155.12
6.04500
5,91800
50555
6,862.13
5.949.869,73
524,518.55
14"
50555 MND MSG (3)
10,11095
91,76
158.43
6,043.51
5,916.51
471,32
8,876.48
5.048.935.54
524,532.95
11,93
471.32 MV03 MSG (3)
10,156.16
9280
lase.
6404"10
5,91470
428.22
8,88993
5.848,892.48
524,545.52
14.43
42823 MMD MSG (3)
10.189.11
8,20
16813
6,040.55
5,81355
395.10
689716
5,949,860.38
524553.
9.91
58610 MPoDOMO(3)
10221A1
k,46
170.80
804000
5,913.08
354,32
8,9.90
5,949,62862
524,550.65
881
-364.32 MADOWSGO)
10.ZGS7
9304
1R.
603812
5,912.12
33309
8,907.35
5,94878741
524584.10
lose
-333.09 MWDOWSG(3)
10.283.51
91.88
17424
6037.07
5,91067
30277
6,91076
5,949,767.09
524,567.65
616
-30277 ~ MSG (3)
10,311,76
9055
9503
6,03732
5.910.32
274.65
6,913A0
5,949,738.98
5249035
4,82
-274.65 WAD MSG (3)
10.34492
as.
9&52
6,03749
5,81049
241,58
691504
5,94970.92
4452.07
6.79
-24158 MWD MSG (3)
10,37k05
91.
17&27
6,03730
5,91020
21049
6,99.5
5949,674.84
44,574.36
11,5
-210 K) MWD MSG (3)
10,40563
91,10
179.36
6,036.49
5,909.50
two
6.99.86
564064528
583,57504
460
-180.93 MND MSG (3)
10,435.15
Was
14621
6,.506
5909w
151.41
6.91797
5948615.]7
44,57521
332
-151,41 MND MSG (3)
10463.15
W.I.
18 S7
6n`G.
5,90639
123.42
6.91770
5,949.587.78
52457501
6.10
-123.42 MWD MSG (3)
ID 49379
92.00
"62..
6034.25
5907.25
4.81
Be.
594955/9
524574.30
390
-Wal MWD MSG (3)
6/182019 907:54A44
P,,44
COMPASS 5000.14 8.210850
ConocoPhlllips .
Ciampi Definitive Suryey Report
Company'.
Con..Phillips Abska lnc_Kupamk
Local Co-ordinate Reference:
Wall 2F-07
Pmjc.t
Kupamk River Unit
TVD Reference:
21F-07(-31127,00ush(2F-07)
SHe:
Kupamk 2F Pad
MO Reference:
2F-07@ 127.00us0(2F47)
Well:
2F-07
North Reference:
Time
Welli
2F47L1
Survey Calculation Method:
Minimum Curnlure
DeslOn:
21
Database:
EDT 14 Alaska Production
Survey
Map
Vertical
MD
Inc AD,
TVD
TVDSS
.1,1141.1,1141•EM
Nonhln9
au DLS
Ea.rin8 Section Survey Tool Name
1..11)
1°I (°1
(use)
(..e)
(..ft)
juslo
hl
f-1101
(ft) hl
1653583
8803 183]9
6033.89
5,900.89
6083
6,91528 5,949,525.18
5345]2]1 10.35 50.82 MWOOWSG (3)
10554.15
87.08 104.45
6,03481
5,907.01
32.59
6,91325 5,9494%95
524.5eL78 7 94 -3259 MVA MSG (3)
1058500
8]63 185.10
6,03627
5,909.27
109
6,91062 5,949465.
52456022 2.00 -1,09 MWD 0W6G(3)
10638.00
8703 105.10
6.038.42
S,9N.42
S086
690..98 5,949,41149
524,563.]9 000 5006 PROJECTED to TD
Annotation
6r18rz019 9:0754AM Pepa5 COMNS55000. 14 Build BSD
2 190 74
30999
Letter of Transmittal
AO GC
BA ER Date:
F IGHES July ls, 2019
BAT
GEcompany
To:
Abby Bell
AC G CC
333 West 7`h Ave, Suite 100
Anchorage, Alaska 99501
From:
Harvey Finch
Baker Hughes, a GE Company
795 East 94`h Avenue
Anchorage, Alaska 99515
Please find enclosed the directional survey data for the following well(s):
2F -07L1
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
WA
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21 9074
BA M PRINT DISTRIBUTION LIST 30"'
F�GHES
a GE company
COMPANY ConocoPhillips Alaska, Inc.
WELL NAME 2F -07L1
FIELD Greater Kuparuk Area
COUNTY North Slope Borough
BHI DISTRICT
ce sign and return one copy of this transmittal form to:
DcoPhillips Alaska, Inc.
Osterkamp (WINS Petroleum Technician)
G Street.
is raee. Alaska 99510
LOG TYPE GR - RES
LOG DATE June 5, 2019
AUTHORIZED BY Patrick Rider
EMAIL Patrick.Rider@bakerhuahes.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
V
1 BP North Slope.
EOA, PBOC, PRB-20 (Office 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 Exxo Mobil, Alaska
Attn: Lynda M. Vaskell and/or Leonardo Elias
3201 C Street, Suite 505
Anchorage, AK 99503
FIELD
FINAL
CD/DVD
FINAL
PRELIM
LOGS
(las, dlis, PDF, META,
SURVEY
REPORT
LOGS
CGM, Final Suryeys)
(Compass)
# OF PRINTS
# OF COPIES
1# OF COPIES
1# OF COPIES
01 01 0 10 0
Rp^A
`1UGCC
4. State of Alaska -AOGCC 0 1 7 0 0
Ann: Natural Resources Technician 11
333 W. 7th Ave, Suite 100
Anchorage, Alaska 99501
5 DNR - Division of Oil & Gas *** 0 1 0 1 0 10
Attn: Resource Evaluation
550 West 7th Avenue, Suite 1100
Anchorage, Alaska 99501
** Stamp "confidential" on all material deliver to DNR
6'BP Exploration (Alaska) Inc.
Petrotechnical Data Center, LR2-I
1900 E. Benson Blvd.
Anchorage, Alaska 99508
01 01 0 101 0
TOTALS FOR THIS PAGE: 0 1 2 0 0
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 217-07LI
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-074
Alaska Oil and Gas
Conservation Commission
Surface Location: 565' FSL, 1570' FEL, SEC. 28, TI IN, R9E, UM
Bottomhole Location: 794' FNL, 70' FWL, SEC. 35, TI IN, R9E, UM
Dear Mr. Ohlinger:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
w .aogcc.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)(B) and Regulation 20 AAC 25.071, composite curves for well logs
run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment
of this well.
This permit to drill does not exempt you from obtaining additional permits or an approval required by
law from other governmental agencies and does not authorize conducting drilling operations until all
other required permits and approvals have been issued. In addition, the AOGCC reserves the right to
withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an
applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an
AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension
of the permit.
Sincerely,
Daniel T. Seamount, Jr.
Commissioner
DATED this t7 day of May, 2019.
i STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
2019
1 a. Type of Work:
jib. Proposed Well Class: Exploratory - Gas ❑
Service - WAG ❑ Service - Disp ❑
1c. Specify if well is proposer/ fbr:
Drill ❑ Lateral Q
Stratigraphic Test ❑ Development- Oil
Service - Wini ❑ Single Zone ❑' •
Coalbed Gas ❑ Gas Hydrates ❑
Redrill ❑ Reentry ❑
I Exploratory -oil ❑ Development - Gas ❑
Service - Supply ❑ Multiple Zone ❑
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 -
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 12100' TVD: 6070'
Kuparuk River Pool /
Kuparuk River Oil Pool ,
4a. Location of Well (Governmental Section):
7. Property Designation:
Surface: 565' FSL, 1570' FEL, Sec. 28, T11N, R9E, UM
ADL 25657 /4pc ZS7S
Top of Productive Horizon:
8. DNR Approval Number: {9
13. Approximate Spud Date:
1596' FSL, 1217' FEL, Sec. 27, T11 N, R9E, UM
LONS 82-177
5/21/2019
9. Acres in Property:
14. Distance to Nearest Property:
Total Depth:
794' FNL, 70' FWL, Sec. 35, T11 N, R9E, UM
2560
12,370'
4b. 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: 1267' (2D-14)
16. Deviated wells: Kickoff depth: 8645 ' feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 94 degrees
Downhole: 4420 Surface: 3823
18. Casing Program: Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Hole Casing Weight Grade Coupling Length
MD TVD MD TVD (including stage data)
3" 2-3/8" 4.7# L-80 ST -L 2875'
9225' 6015' 12100' 6070' Slotted
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured):
Effect. Depth MD (it): Effect. Depth TVD (ft): Junk (measured):
9055' 6254' N/A
8931' 6167' 8890'
Casing Length Size
Cement Volume MD TVD
Conductor/Structural 78' 16"
150 Sx CS II 109' 109'
Surface 3696' 9-5/8"
1040 Sx AS III, 710 Sx Class G 3727' 2889'
Production 9025' 7"
300 Sx Class G, 250 Sx AS 1 9051' 6251'
Perforation Depth MD (ft): 8554'-8564', 8638'-8657', 8674'-8728',
Perforation Depth TVD (ft): 5912'-5919', 5968'-5981', 5992'-6029', 6063'-6067'
8778'-8784' 1
Hydraulic Fracture planned? Yes El No ❑4 -
20. Attachments: Property Plat ❑ riling Program
Diverter Sketch BP Sketch ❑❑ DSelabed Report
th lot Shallow Hazard Anaysis
® Drilling Fliv. d Program 20 AAC 25.050 requ emlents�
21. Verbal Approval: Commission Representative:
Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Contact Name: William R. Long
Authorized Name: James Ohlinger
Contact Email: William. R. Lon COP.com
Authorized Title: Staff TD Engineer
Contact Phone: 907-263-4372
Authorized Signature:
Date: /41117
Commission Use Only
Permit to Drill ""�`
Number: ���_(�!y
API —Number.
o� /
50-e,7Z!-<--1 CJ�w-
-6-n
Permit Approval
Date:
11
t
1�
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 hydrates, or gas contained in shales: —/
Other: 130,0 f<St to yop0y 51Samples req'd: Yes,_❑,( NoLtQ Mudlogreq'd:Yes,❑,/No L1j
�h h v/a ✓ t�z' ✓(v7f7r TtS t ZS G C),Ps HSmeasures: Yes u No❑ Directional svy req'd: Yes LTJ No❑J
SpacingZoeption req'd: Yes ❑ Noy Inclination -only svy req'd: Yes E] No L�
1
rCG%Yl a-�J� J ro ✓zo
FOP f � f'ct c �c
Post initial injection MIT req'd: Yes El No�
APPROVED BY [
Approved by:4?�4�
COMMISSIONER THE COMMISSION Date: J
V T_1_ 5//7/17 Submit Form and
Form 10-401 Revised 5/2017• _ �� This ppermit is Valid form t I t if `pproval per 20 AAC 25.005(g) Attachme0ts in Duplicate 6
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-071_1 and
2F -07L1-01 targeting the KuparukA-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 21F-071-1 and 2F -07L1-01
- Detailed Summary of Operations
- Directional Plans for 2F-071_1 and 2F-071-1-01
- 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
21F-071-1 and 2F -07L1-01
Application for Permit to Drill Document
1. Well Name and Classification........................................................................................................ 2
(Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))...................................................................................................................2
2. Location Summary.......................................................................................................................... 2
(Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2
3. Blowout Prevention Equipment Information................................................................................. 2
(Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2
4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2
(Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2
5. Procedure for Conducting Formation Integrity tests................................................................... 2
(Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2
6. Casing and Cementing Program.................................................................................................... 3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3
7.
Diverter System Information.......................................................................................................... 3
(Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3
8.
Drilling Fluids Program.................................................................................................................. 3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3
9.
Abnormally Pressured Formation Information.............................................................................4
(Requirements of 20 AAC 25.005(c)(0))..................................................................................................................................................4
10.
Seismic Analysis............................................................................................................................. 4
(Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4
11. Seabed Condition Analysis............................................................................................................ 4
(Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4
12. Evidence of Bonding...................................................................................................................... 4
(Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4
13. Proposed Drilling Program............................................................................................................. 4
(Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4
Summaryof Operations...................................................................................................................................................4
LinerRunning...................................................................................................................................................................5
14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................6
15. Directional Plans for Intentionally Deviated Wells....................................................................... 6
(Requirements of 20 AAC 25.050(b))......................................................................................................................................................6
16. 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 21F-071-1-01 laterals..............................................................6
Page 1 of 6 May 13, 2019
PTD Application: 2F-071_1 & 2F-071-1-01
Well Name and Classification
(Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b))
The proposed laterals described in this document are 21F-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 10401 form for surface
and subsurface coordinates of the 2F-071_1 and 21F-071-1-01.
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 2F-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 217-07 was 3,927 psi at the datum (11.9 ppg EMW) on 5/3/2019. The maximum
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)) d
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 Application: 2F -07L1 & 2F -07L1-01
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
MD
TVDSS
TVDSS
Conductor
16"
62.5
H40
Welded
Surface
2-3/8", 4.7#, L-80, ST -L slotted liner;
2F-071_1
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 -07L1-01
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
Grade
Connection
Top MD
Btm
MD
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
ELIE 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 -07L1 & 2F-071-1-01
Pressure at the 2F-07 Window (8645' MD, 5973' ND) 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 -07L1 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 pp
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 -07L1 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: 21F-071-1 & 2F -07L1-01
Rig Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. 2F -07L1 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. Kickoff 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 "Drilling 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 -07L1 & 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 (1 R-18
or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable.
• All wastes and waste fluids hauled from the pad must be properly documented and manifested.
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (6704200).
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-071-1-01
17, 015'
- Distance to Nearest Well within Pool
Lateral Name
Distance
Well
2F -07L1
1267
2D-14
2F-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 Aprll 24, 2019
Coiled Tubing and 2-3/8" BHA
Quick Test Sub to Ot
Top of 7" Otis
Distances from top o
Excluding quick -test
Top of Annular
CL Annular
Bottom Annular Flan
CL Blind/Shears
CL 2" Combl's
CL 2-318" Combrs
CL 2" Combi's
CL of Top
Top of Swa
CL Swab 1
Flow Tee
CL SSV
CL Master
LDS
Ground
Tree Size 3 FIs
ane
ConocoPhillips
ConocoPhillips Alaska Inc—Kuparuk
Kuparuk River Unit
Kuparuk 2F Pad
2F-07
2F -07L1
Plan: 2F-07L1_wp02
Standard Planning Report
02 May, 2019
BT�a
GHES
GE company
ConocoPhillips
Database:
EDT 14 Alaska Production
Company:
ConocoPhillips Alaska Inc_Kupawk
Project:
Kuparuk River Unit
Site:
Kuparuk 2F Pad
Well:
2F-07
Wellbore:
2F-071-1
Design:
2F-07L1_wp02
ConocoPhillips
Planning Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 2F-07
Mean Sea Level
2F-07 Q 127.00usft (2F-07)
True
Minimum Curvature '
Project Kuparuk River Unit, North Slope Alaska, United States
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
BA. �(ER
IGHES
BAT
GE company
Site Kupawk 2F Pad
usft
Northing:
0.00
Site Position:
Northing:
5,949,341.83usft
Latitude: 70'16'21.978N
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
Well Position +NI -S
+EI -W
Position Uncertainty
0.00
usft
Northing:
0.00
usft
Easting:
0.00
usft
Wellhead Elevation:
Wellbore 2F-071-1
Magnetics Model Name Sample Date
BGGM2018 4/23/2019
Design 2F-07L1_wp02
Audit Notes:
Version: Phase:
Vertical Section: Depth From (TVD)
(usft)
0.00
5,949,448.14 usft Latitude:
517,658.31 usft Longitude:
usft Ground Level:
Declination Dip Angle
16.57 80.81
PLAN
'
NIS
(usft)
0.00
Tie On Depth:
+EI -W
(usft)
0.00
700 16'23.018 N
149" 51'25.830 W
0.00 usft
Field Strength
mT)
57,411
8,600.00
Direction
(°)
180.00
5/2/2019 9:04:55AM Page 2 COMPASS 600014 Build 850
Plan Sections
BA ER
BAT
a GEcompary
Measured
ConocoPhillips
ConocdPhlllips
Planning Report
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 @ 127.00usft (2F-07)
Site: Kuparuk 2F Pad
North Reference:
True
Well: 2F-07
Survey Calculation Method:
Minimum Curvature
Wellbore: 2F -07L7
(°)
(usft)
Design: 2F-07L1_wp02
(usft)
(°1100usft)
Plan Sections
BA ER
BAT
a GEcompary
Measured
TVD Below
Dogleg
Build
Turn
Depth
Inclination
Azimuth
System
+N/ -S
+EI -W
Rate
Rate
Rate
TFO
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(°1100usft)
(°/100usft)
(°I100usft)
(°)
8,600.00
47.97
80.23
5,815.56
1,026.68
5,597.82
0.00
0.00
0.00
0.00
8,645.00
47.70
79.90
5,845.77
1,032.44
5,630.68
0.81
-0.60
-0.73
-137.94
8,674.00
53.50
79.90
5,864.17
1,036.37
5,652.73
20.00
20.00
0.00
0.00
8,755.11
90.00
79.90
5,889.14
1,049.65
5,727.29
45.00
45.00
0.00
0.00
9,150.00
90.00
107.54
5,889.14
1,024.27
6,117.54
7.00
0.00
7.00
90.00
9,325.00
93.76
95.88
5,883.39
988.82
6,288.47
7.00
2.15
-6.67
-72.00
9,575.00
89.13
112.76
5,877.03
927.22
6,529.68
7.00
-1.85
6.75
105.00
9,825.00
85.00
129.79
5,889.92
798.15
6,742.26
7.00
-1.65
6.81
104.00
10,075.00
89.68
146.68
5,901.61
612.56
6,907.90
7.00
1.87
6.75
75.00
10,375.00
92.56
167.49
5,895.69
337.85
7,024.07
7.00
0.96
6.94
82.00
10,575.00
88.90
181.00
5,893.14
139.37
7,044.06
7.00
-1.83
6.76
105.00
10,875.00
83.64
201.39
5,912.85
-152.67
6,986.42
7.00
-1.75
6.79
105.00
11,100.00
89.18
186.61
5,927.00
-369.89
6,932.37
7.00
2.46
-6.57
-70.00
11,275.00
93.36
175.09
5,923.10
-544.50
6,929.77
7.00
2.39
-6.58
-70.00
11,575.00
89.58
195.75
5,915.33
-841.38
6,901.56
7.00
-1.26
6.89
100.00
11,900.00
85.76
173.30
5,928.73
-1,162.96
6,876.01
7.00
-1.17
-0.91
-100.00
12,100.00
85.88
159.27
5,943.38
-1,356.25
6,923.18
7.00
0.06
-7.02
-90.00
Target
&2/2019 9:04:55AM Pape 3 COMPASS 3000.14 Build BSD
ConocoPhillips IlA <E€Y
Conoc('; lhl 1ps Planning Report F�UGHES
a GE company
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 @ 127.00usft (2F-07)
Site:
Kuparuk 2F Pad
North Reference:
True
Well:
2F-07
Survey Calculation Method:
Minimum Curvature
Wellbore:
2F -07L1
Design:
2F-07L1_wp02
Dogleg
Toolface
Planned
Survey
I
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination
Azimuth
System
+N/.S
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(_)
(e)
(usft)
(usft)
(usft)
(usft)
('1100usft)
(')
(usft)
(usft)
8,600.00
47.97
80.23
5,815.56
1,026.68
5,597.82
-1,026.68
0.00
0.00
5,950,487.85
523,253.15
TIP
8,645.00
47.70
79.90
5,845.77
1,032.44
5,630.68
-1,032.44
0.81
-137.94
5,950,493.68
523,285.99
KOP
8,674.00
53.50
79.90
5,864.17
1,036.37
5,652.73
-1,036.37
20.00
0.00
5,950,497.66
523,308.03
Start Build 45.00
8,700.00
65.20
79.90
5,877.40
1,040.28
5,674.71
-1,040.28
45.00
0.00
5,950,501.63
523,330.00
8,755.11
90.00
79.90
5,889.14
1,049.65
5,727.29
-1,049.65
45.00
0.00
5,950,511.12
523,382.55
Start DLS
7.00 TFO
90.00
8,800.00
90.00
83.04
5,889.14
1,056.30
5,771.68
-1,056.30
7.00
90.00
5,950,517.88
523,426.92
8,900.00
90.00
90.04
5,889.14
1,062.33
5,871.43
-1,062.33
7.00
90.00
5,950,524.14
523,526.65
9,000.00
90.00
97.04
5,889.14
1,056.16
5,971.18
-1,056.16
7.00
90.00
5,950,518.20
523,626.40
9,100.00
90.00
104.04
5,889.14
1,037.87
6,069.43
-1,037.87
7.00
90.00
5,950,500.15
523,724.69
9,150.00
90.00
107.54
5,889.14
1,024.27
6,117.54
-1,024.27
7.00
90.00
5,950,486.66
523,772.82
Start DLS
7.00 TFO
-72.00
9,200.00
91.08
104.21
5,888.67
1,010.59
6,165.62
-1,010.59
7.00
-72.00
5,950,473.09
523,820.93
9,300.00
93.23
97.55
5,884.91
991.74
6,263.69
-991.74
7.00
-72.03
5,950,454.47
523,919.03
9,325.00
93.76
95.88
5,883.39
988.82
6,288.47
-988.82
7.00
-72.28
5,950,451.61
523,943.82
Start DLS
7.00 TFO
105.00
9,400.00
92.39
100.95
5,879.36
977.87
6,362.53
-977.87
7.00
105.00
5,950,440.83
524,017.90
9,500.00
90.53
107.70
5,876.81
953.14
6,459.33
-953.14
7.00
105.27
5,950,416.34
524,114.74
9,575.00
89.13
112.76
5,877.03
927.22
6,529.68
-927.22
7.00
105.44
5,950,390.58
524,185.14
Start DLS
7.00 TFO
104.00
9,600.00
88.71
114.46
5,877.51
917.20
6,552.58
-917.20
7.00
104.00
5,950,380.62
524,208.07
9,700.00
87.03
121.26
5,881.22
870.53
6,640.87
-870.53
7.00
103.97
5,950,334.17
524,296.46
9,800.00
85.40
128.08
5,887.83
813.81
6,722.89
-813.81
7.00
103.72
5,950,277.64
524,378.60
9,825.00
85.00
129.79
5,889.92
798.15
6,742.26
-798.15
7.00
103.26
5,950,262.03
524,398.01
Start DLS
7.00 TFO
75.00
9,900.00
86.38
134.87
5,895.57
747.80
6,797.53
-747.80
7.00
75.00
5,950,211.82
524,453.39
10,000.00
88.25
141.63
5,900.26
673.32
6,864.00
-673.32
7.00
74.62
5,950,137.50
524,520.03
10,075.00
89.68
146.68
5,901.61
612.56
6,907.90
-612.56
7.00
74.30
5,950,076.85
524,564.06
Start DLS
7.00 TFO
82.00
10,100.00
89.92
148.41
5,901.70
591.47
6,921.31
-591.47
7.00
82.00
5,950,055.79
524,577.53
10,200.00
90.90
155.34
5,900.98
503.33
6,968.42
-503.33
7.00
81.99
5,949,967.77
524,624.83
10,300.00
91.86
162.28
5,898.58
410.17
7,004.53
-410.17
7.00
82.04
5,949,874.71
524,661.16
10,375.00
92.56
167.49
5,895.69
337.85
7,024.07
-337.85
7.00
82.21
5,949,802.43
524,680.86
Start DLS
7.00 TFO
105.00
10,400.00
92.10
169.18
5,894.67
313.39
7,029.12
-313.39
7.00
105.00
5,949,777.99
524,685.97
10,500.00
90.27
175.94
5,892.60
214.31
7,042.06
-214.31
7.00
105.07
5,949,678.95
524,699.14
10,575.00
88.90
181.00
5,893.14
139.37
7,044.06
-139.37
7.00
105.21
5,949,604.02
524,701.32
Start DLS
7.00 TFO
105.00
10,600.00
88.45
182.69
5,893.72
114.39
7,043.25
-114.39
7.00
105.00
5,949,579.04
524,700.57
10,700.00
86.65
189.47
5,898.00
15.10
7,032.68
-15.10
7.00
104.96
5,949,479.74
524,690.23
10,800.00
84.91
196.27
5,905.37
-82.06
7,010.49
82.06
7.00
104.67
5,949,382.53
524,668.28
10,875.00
83.64
201.39
5,912.85
-152.67
6,986.42
152.67
7.00
104.17
5,949,311.88
524,644.38
Start DLS
7.00 TFO
-70.00
10,900.00
84.25
199.73
5,915.49
-175.95
6,977.69
175.95
7.00
-70.00
5,949,288.58
524,635.70
11,000.00
86.69
193.15
5,923.40
-271.50
6,949.50
271.50
7.00
-69.83
5,949,192.97
524,607.74
11,100.00
89.18
186.61
5,927.00
-369.89
6,932.37
369.89
7.00
-69.31
5,949,094.55
524,590.84
Start DLS
7.00 TFO
-70.00
11,200.00
91.58
180.03
5,926.34
-469.66
6,926.58
469.66
7.00
-70.00
5,948,994.78
524,585.29
11,275.00
93.36
175.09
5,923.10
-544.50
6,929.77
544.50
7.00
-70.04
5,948919.96
524588.65
52/2019 9r04t55AM Papa 4 COMPASS 5000.14 Build 86D
ConocoPhlllips BA_ ( R10,
cm0cOP(1((((p5 Planning ReportUGHES
a GE company
Database:
EDT 14 Alaska Production
Company:
ConowPhillips Alaska Inc-Kuparuk
Project:
Kuparuk River Unit
11,400.00
Site:
Kuparuk 2F Pad
11,500.00
Well:
2F-07
11,575.00
Wellbore:
2F-071-1
Start DLS
Design:
2F-07L1wp02
11,600.00
Planned Survey
194.03
/l l �
Measured
187.13
TVD Below(
86.89
180.23
11,900.00
Depth Inclination Azimuth System 17 +N/ -S
(usft) (') (1 (usft) (usft)
Start DLS
7.00 TFO
100.00
11,300.00
93.05
176.81
11,400.00
91.81
183.71
11,500.00
90.54
190.59
11,575.00
89.58
195.75
Start DLS
7.00 TFO
-100.00
11,600.00
89.27
194.03
11,700.00
88.07
187.13
11,800.00
86.89
180.23
11,900.00
85.76
173.30
Start DLS
7.00 TFO
-90.00
12,000.00
85.79
166.28
12,100.00
85.88
159.27
Planned TD at 12100.00
Casing Points
Plan Annotations
Local Co-ordinate Reference: Well 2F-07
-669.24
Casing
TVD Reference:
Mean Sea Level
Depth
7.00
MD Reference:
2F-07 cQ 127.00usft (2F-07)
524,590.25
North Reference:
True
12,100.00
6,918.65
Survey Calculation Method:
Minimum Curvature
7.00
100.39
Vertical
Dogleg Toolface
Map
Map
+E/_W Section
Rate Azimuth
Northing
Easting
(usft) (usft)
('1100usft) (')
(usft)
(usft)
5,921.70 -569.39 6,931.54 569.39 7.00 100.00 5,948,895.07 524,590.47
5,917.46
-669.24
Casing
6,931.08
669.24
Depth
7.00
100.10
5,948,795.23
524,590.25
5,915.41
-768.38
12,100.00
6,918.65
768.38
3.000
7.00
100.39
5,948,696.07
524,578.05
5,915.33
-841.38
6,907.90
6,901.56
841.38
139.37
7.00
100.53
5,948,623.04
524,561.14
5,915.59
-865.54
6,929.77
6,895.14
865.54
-1,162.96
7.00
-100.00
5,948,598.87
524,554.77
5,917.91
-963.75
6,876.79
963.75
7.00
-99.98
5,948,500.62
524,536.66
5,922.32
-1,063.39
6,870.38
1,063.39
7.00
-99.82
5,948,400.98
524,530.48
5,928.73
-1,162.96
6,876.01
1,162.96
7.00
-99.52
5,948,301.43
524,536.34
5,936.11
-1,261.05
6,893.67
1,261.05
7.00
-90.00
5,948,203.40
524,554.23
5,943.38
- -1,356.25
6,923.18
1,356.25
7.00
-89.48
5,948,108.27
524,583.97
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
(usft) Name
(in)
(in)
12,100.00
5,943.38 2-3/8"
2.375
3.000
Measured
Depth
(usft)
8,600.00
8,645.00
8,674.00
8,755.11
9,150.00
9,325.00
9,575.00
9,825.00
10,075.00
10,375.00
10,575.00
10,875.00
11,100.00
11,275.00
11,575.00
11,900.00
12,100.00
Vertical
Depth
(usft)
5,815.56
5,845.77
5,864.17
5,889.14
5,889.14
5,883.39
5,877.03
5,889.92
5,901.61
5,895.69
5,893.14
5,912.85
5,927.00
5,923.10
5,915.33
5,928.73
5,943.38
Local Coordinates
-NI-S
+El -W
(usft)
(usft)
1,026.68
5,597.82
1,032.44
5630.68
1,036.37
5,652.73
1,049.65
5,727.29
1,024.27
6,117.54
988.82
6,288.47
927.22
6,529.68
798.15
6,742.26
612.56
6,907.90
337.85
7,024.07
139.37
7,044.06
-152.67
6,986.42
-369.89
6,932.37
-544.50
6,929.77
-841.38
6,901.56
-1,162.96
6,876.01
-1,356.25
6,923.18
Comment
TIP
KOP
Start Build 45.00
Start DLS 7.00 TFO 90.00
Start DLS 7.00 TFO -72.00
Start DLS 7.00 TFO 105.00
Start DLS 7.00 TFO 104.00
Start DLS 7.00 TFO 75.00
Start DLS 7.00 TFO 82.00
Start DLS 7.00 TFO 105.00
Start DLS 7.00 TFO 105.00
Start DLS 7.00 TFO -70.00
Start DLS 7.00 TFO -70.00
Start DLS 7.00 TFO 100.00
Start DLS 7.00 TFO -100.00
Start DLS 7.00 TFO -90.00
Planned TO at 12100.00
5/2/2019 9:04:55AM Pays 5 COMPASS 5000.14 Build 850
ConocoPhillips BA ER
conocoPhillips Anticollision Report F�UGHES
a GE Wmpary
Company:
ConocoPhillips Alaska lnc Kuparuk
Project:
Kupamk 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
Reference Design:
2F-07L1_wp02
Reference 2F-07L1_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:
8,600.00 to 12, 100.00usft
Scan Method:
Results Limited by:
Maximum center -center distance of 1,397.30 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 5/1/2019
From To
(usft) (usft) Survey (Wellbore) Tool Name Description
200.00 8,600.00 2F-07 (2F-07) SEEKER MS BHI Seeker multishot
8,600.00 12,100.00 2F-07L1_wp02(2F-07L1) MWD MWD - Standard
Summary
Kuparuk 2F Pad - 2F-07 - 2F-07 - 2F-07
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
(usftl
lusftl
(usft)
(usft)
Distance
Kupamk 2F Pad
Measured
vertical
Measured
verbal
2F-06 - 2F-06 - 2F-06
Onset
Asannth
Offset WNleore Contra
Between
Out of range
2F-06 - 2F-06 - 2F-06
Separation Warning
Depth
Depth
OepM
Out of range
2F-06 - 2F-06 - 217-06
from North
e1415
eU.w
Out of range
2F -07 -2F -07-2F-07
8,913.31
9,000.00
200.43
193.39
28.481 CC, ES, SF
2F-07-2F-07L1-01-2F-071-1-01_wpO2
9,527.07
9,550.00
78.90
76.16
28.853 CC, ES, SF
Offset Design
Kuparuk 2F Pad - 2F-07 - 2F-07 - 2F-07
Onset Site Error: 0.00 usft
Survey Program: 200
SEEKER MS
Offset Well Error: 0.00 usft
Reference
Offset
Semi Major
Axis
Distance
Measured
vertical
Measured
verbal
Reference
Onset
Asannth
Offset WNleore Contra
Between
between
Minimum
Separation Warning
Depth
Depth
OepM
Deput
from North
e1415
eU.w
Centres
Ellipses
Separation
Factor
(usftl
(usft)
loan)
(usft)
(usft)
(usm
CI
(usft)
(usa)
(usft)
(usft)
(use)
8,625.00
5,959.32
8,62&W
5,959.32
0.24
0.47
-176.49
1,029,86
5,816.10
0,00
-1.01
1.01
0.000 STOP Dinning
8,650.W
5,976.10
8.650.00
5,976.13
0.43
0.94
-100.05
1,033.09
5,634.32
0.05
-1.08
1.12
0,090 STOP Drilifg
8,674.88
5,991,69
8,675.00
5,992.99
0.43
1.41
-98.68
1,036.36
5,652.48
1.62
-0.24
1.85
0.872 STOP Drilling
0,698.61
6,003.81
8)00.00
6,009.90
0.44
1.88
-98.92
1,039.69
5,670.60
6.75
3,90
2.85
2.371 Caution Mondor Closely
8,719.88
6,011.30
8)25,00
6,026.87
0.45
2.35
-99.08
1,093.011
5,688.59
16,19
12.53
3.66
4.419
8,738.04
6,015.00
8,750,00
6,043.92
0.46
2.81
-99,17
1,046.45
5,706.62
29.18
24.90
4.29
6.808
8,753.26
6,016.11
8,775,00
8,061.04
0.47
3.27
-99.31
1,049,86
5,724.51
44.94
40.20
4.74
9.483
8,770.04
6,016,20
8,800.0
6,078.23
0.49
3.74
-98.24
1,053.31
5,742.33
62.05
57.02
5.03
12.338
8,788.60
5,016.14
8,825,00
6,095.46
0.50
4.20
-90.38
1,056.73
5,760.12
79,34
74.06
5.28
15.027
8.808.66
6.016,14
8,850.00
6,112.65
0.52
4.65
-94+70
1000,09
5,777.5
96.56
91.03
5.54
17.444
8,824.67
6,016,14
8,875.W
6,129.84
0.55
5,11
-92.96
1,063.41
5,795.80
113.79
108.00
579
19,660
8,842.61
6,016.14
8,900.00
6,147.03
0.57
5.57
-91.18
1,086.73
5,813.65
131,04
12SW
9,04
21.698
8,860.46
6,016.14
8,925,00
6,164.22
0.00
5.03
-89.38
1,070,06
5,831.50
148.33
142.04
6.29
23.582
8,878.20
6,016.14
8,950,00
6,181.40
0.83
6.49
-87.56
1,073,38
5,849,35
165.55
159.11
6.54
25.330
0,895.82
8,016,14
8,975.00
6,198.59
0,66
6.95
-85.74
1,076.71
5,867.19
183.01
176.22
6,79
26.958
8,913.31
5,016.14
9,000,W
6,21$.78
0.69
7.41
-83.93
1,00.03
S,a85,04
200.43
193.39
7.04
28.481 CC, ES, SF
8,930.64
6.016.14
9,025,W
6,232.98
0.73
7.87
-82.11
1,03.35
5,902,89
217.90
210.61
7.28
29.913
8,947.81
6,016.14
9,050.00
6,250.15
0.76
8.33
-W.31
11086.68
5,920.74
235.43
227.90
7,53
31.262
8,951.22
6,016.14
9,055.00
5,253.59
0,77
8.42
-79.96
1,07.34
5,924.31
238.94
231.38
7.58
31.522
CC - Min centre to center distance or covergent point, SF - min Separation factor, ES - min ellipse separation
5112019 2:50:31PM Page 2 COMPASS 5000.14 Build 85D
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,f- KUP PROD WELLNAME 2F-07 ELLBORE 2F-07 '
Conoc&hillips
Alaska, Ino.
Well Attributes Max Angle&MD TD
hvGName WelWare A%NLM WellMre Sblps
KUPARUK RIVER UNIT 5002921WfiW PROD
net r) MD mK61 Rslebn ORKS1
5.88 2,400.00 9,055.0
Comment N35Ippad b Mnobtbn L-RDale KadN ml flip ---Bete
Joe
SSSV'. LOCKED OUT 75 12112016 Last WO'. 9)30/1984 29.00 3011986
2F-0],&0/1019]55..20 PM
Last Tag
Wnieyuaemet-whol,
MmMion OepLM1 mKBI End OAe WelWre Iaa MM ay
Iasi Tag: ARE But. S' of VIIIA8,779.0 SI312019 2F-0] rembaej
-- -- -
--
Last Rev Reason
XPNGER. 216
MnaMbn FM Oeb W¢IPpfe Las[Motl By
Rev Reason'. Updated Tag Dean 5312019 2F -OJ 2emba'
Casing Strings
Ca:mg Deaolpnon Do lml ID (m Tupmlcel samepm lnxR set Depin ITVDL.. PAT" O._c40
WETnreaa
CONDUCTOR 16 1506 31.0 109.0 109.0 62.50 H-00 WELDED
Cas, pncrlpnon 00 (nl IOfinl TopmKBl Se10epM IhNaI Sn OeInM1jNp1-. WnLen h_. 6raN Top TM1rctl
SURFACE 9518 836 WS 3.726.8 2.888.8 3600 J.65 BTC
nan ODlinl IDfnl HART Hal sol CounnmKie Set UxtellvUe WHLen11...Onh Top heases
CONDUCTOR;31 o100
PRODUCTION 7 6.28 260 1051.0 6.250.8 26.00 J-55 BTC
'RED CTIO
Tubing Strings
Tubing Des<,lElion String Ma.. ID iln1 TapInK81 SN DepIM1 m.. Set Deptn IIVD I... W111bM1 Grad, TOFConneclion
TUBING 312 2.99 23.8 8,634.1 5,8315 9.30 755 EUEBrd
SAFE"vW.1.96&o
Completion Details et
TOP ol Nominal
Too (HART HIucm D- Com ID hnl23.6
07 HANGER FMC GEN IITOBING HANGER 3.500
1,953.0 1,90 SAFETYVLV OTIS OLP SSW(LOCKEO OUT 11192000) CL TRACK TUBING 2.812
GAS UFT: 2.055.s
PRESSURE
1.0 5, PBR BAKER PER 3.000
0'�
5. PA KER BAKER FHL 3.000
8421.3 5,01 NIPPLE CAMCO D NIPPLE 27W
84333 500 57 CAMCO SHEAR OUT - TTL ELMD@ 8240ON SWS PPROF 992
8/292004
SURFACE: 20.118 A-
Other In Hole (Wrelme retrievable plugs, valves, pumps, fish, etc.)
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Remark:
AOGCC
PTD No. 219-074 Coordinate Check
16 May 2019
INPUT
Geographic, NAD27
KRU 2F-071-1
Latitude: 70 16 23.01800
Longitude: 149 51 25.83000
OUTPUT
State Plane, NAD27
5004 - Alaska 4, U.S. Feet
1/1
NorthinglY: 5949448.184
EastinglX: 517658.318
Convergence: 0 08 03.99448
Scale Factor: 0.999900354
Corpscon v6.0.1, U.S. Army Corps of Engineers
TRANSMITTAL LETTER CHECKLIST
WELL NAME: K�Z( Z -_— 0 71— 1
PTD: Z--Iq—C) %%
Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: ✓e=1 POOL:
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
/B tbZO i07� Co
/
V1
LATERAL
(If last two digits
No. 7 - , API No. 50-09-CSG .
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
(Comnanv 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 8 Pool KUPARUK RIVER, KUPARUK RIV OIL -490100
Well Name: KUPARUK RIV UNIT 2F-071_1 Program DEV Well bore seg
PTD#: 2190740 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type
DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑
Administration
1
Permit. fee attached _ _ _ ..
NA
2
lease number appropriate_____ ____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___ _ _
Yes _
_ _ . Surf. Loc & Top Prod Int Jie in AD10025657: TD lies in ADL0025658.. _
3
tlnique 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 502
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 appropriatek bond in force _ - _ _ _ _ _ _ _ _ _ . _ .... _ _ _
Yes
11
Permit. can be issued without conservation order _ _ ........ . . . . . . .
Yes
Appr Date
12
Permit can be issued without administrative.approval .. _ _ _ _ _ _ _ _ _ ___
Yes
_ _ _ _ _ _ _ _ .........
13
Can permit be approved before 15-day wait-
Yes
SFD 5/16/2019
- - - - - - - - - - - - - - - - - ....... _
14
Well Jocated within area and strata authorized by Injection Order# (put 10# incomments)(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 less than 3 months (For service well only) ..
NA__
17
Nonconven. gas conforms to AS31,05.03% 1.A),¢2.A-D) _ _ _ _ _ _ _ _ _ _ _ _
NA_
18
Conductor string_ provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA_ _
.. _ _ - Conductor set for -KRU.2F-Q7...
Engineering
19
Surface casing_ protects all.knowu USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA .....
Surface casing set for KRU2F-07_
20
CMT. vol. adequate to circulate on conductor 8 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. L B &_permafrost _ _ _ . .. _ _ _ _ _ _ _ _ .
Yes
24
Adequate tankage. or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .
Yes
_ Rig has steel tanks., all waste to approved disposal wells
25
If a.r"rill, has a 10-403 for abandonment been approved ___ _ _ _____ _ _ _ _ _ _ _ _ __
NA
26
Adequate wellbore separation proposed _ _ _ _ _ . . . . . . . ....... . .
Yes
_ _ Anti-collision analysis complete; n0 major risk failures
27
If diverter required, does it meet regulations- _ - - - _ _ _ _ _ _ _ _ _ _ _
NA
Appr Date
28
Drilling fluid_ program schematic 8 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
SOPEs, do they meet regulation _ _ _ _ _ .. _ _ _ _ _ _ _
Yes
30
BOPE.press rating appropriate; test to (put prig in comments)_ _ _ _ _ _ _ _ .....
Yes
_ _ _ MPSP is 3623 psig; will test BOPS. to 40Q0psig
31
Choke manifold complies w/API. RP-53 (May 84) _ _ _
Yes
32
Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ __________ _ _ _ _ _
Yes
33
Is presence. of H2S gas probable. - - - _ ..
Yes ...
_ H2S measures required.
34
Mechanicatconditionofweliswithin AOR verifiied(Forse(vicewall only) ...... ________NA_
.._..___________........_______.__..._________._...
35
Permit can be issued w/o hydrogen sulfide measures .. ...... . . . . . . . . . . .....
No..
_ _ Wells on 2F-Pad are.112S-bearing.. 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,.e coiled-tubing rig, and _managed -pressure drilling technique to control. _ _ _ _ _
SFD 5/16/2019
36
Seabed condition survey (if off-shore) _____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA _
_ _ .. formation pressures and stabilize shale sections with constant BHP of about 11.8 ppg 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
