Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout219-095a
E
Z
a
O
O
N
Oi
O
a
O
J
J
J
J
LL
J
T
�
N
N
a0
c0
t0
N
_U
a
❑
O
❑
❑
�
�
�`+
Z_
Z_
Z_
Z_
I
Z
Z
Z
Z
r
r
r
a
>
r
0
0
0
0~a
z
E
E
NI
NI
NI
2
NI
F
NI
Z
�
�
W
W
W
W
O
�
ip N
�
J
a
N
v
J
J
J
J
7
d
NE
J
J
J
J
J
J
1
¢
N
N
w
LL
N
N
N
N
N
N
O
N
N
Y
p
Y
p
c ai
6
_i
6
d
n
:°
d
ai
ki
ai
d
ti
d
E
E
IL
ll
❑ r
❑
ll
IL
IL
lLL
IL
ll d
N
E v
"c
v
p
'E
v
"c
Yv
o
'c
v«
'c
v
y
'c
v
'c
y
"c
u_
'c
y c
Y
o
C
E
o 0
E
0
0
0
o
rn w0
o
00 >
m
2d
c o
Oo p
o
O
O
o
c O
O pl
in
V u
u
u
u
m¢
uy
uE
q
a
a
a
a
W
05
a o
N rn
a
a
a
a
a M
H
w
w
W
W
N S
W J
W U
W M
W
W
W
W
W n
N S
O
�
Q
�
rn
rn
a
m
m
rn
rn
rn
m
rn
rn
rn
//L�
U
9
a
o
N
0
N
0
N
0
N
0
N
0
N
0
N
0
N
Y�
6
_
2: N
U M
NO
C)
N
M
N
N
N
N
N
N
N
N
N
W
N
K
N
N
N
\
a
m
m
ro
m
0
W
a
c
�
U
Z
O U
�
�
Z
p
p
N
m N
Z
r
r
J
o.
:°
p
pl
Z
a
C
o
0
CaC
c
O
O
O
V
O
N
O
C O
O M
a
d
E
E
n
V =
U
N
C
J
e
z' zo
Q
rc
m
o
J
Z
rn
C
C
v
o u
m
N
7
Q
a
m
❑
Q
a
y
p
\
a
p
Q
C
n
Z
Q
?
a
o
U
p
c
E
J
�
m
Z
o
U
N
N
N
@
y
N
N
N
N
N
a
a s
m M
m
m
m
m
7�
r
E❑
o l
0
o
a
❑
❑
❑
0
0
0
0❑
m
a
m
2wo
m
m
m
S
"a
m
m
76m
m
m
S
chi
❑
❑
❑
o
J
O
❑
❑
O
❑
❑
o
❑
J
voi
>
ZO
0
d d rn
rn
rn
rn
rn
rn
m
m
rn
rn
rn
rn
rn
rn
p�
F
O
� N d
N
N
N
N
N
N
N
N
N
M
M
M
M
M
M
M
M
M
M
M
M
M
M
O
C
G
w G Z
N
Ow¢
_
a
E
m E
Z
C
O
c
LL
O
N
m
O
O
m
«
r
2
J
O
p a9i
U
U
U
U
U
U
U
U
U
U
U
U
O
J
0
c
� o
w
w
w
w
w
w
w
w
w
w
w
J
3
F w
a
E
Z
a
I.f.
O
CL
w
w
w
U
Z
a
J
a�
N
OM
U�
r
J
a
F—
C-
G
V/
a
0
u.
d
3
}
_U
J
N
C
E
U
M
r
T N 'o
`o `o
U U J
N
E
E
0
U
sem,.
0 0
N N
h
ro r
r
0
O
N
U O c
Z c N o
Q o ❑ n
J y N
CL
¢N
E y
U U K
ti
D
I
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT
AND LOG
1a. Well Status: oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑
20AAC 25.105 2(MC 25.110
GINJ ❑ WINJ El . WAG❑ WDSPL ❑ No. of Completions:
1b. Well Class:
Development ❑ Exploratory ❑
Service El ' Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Abend.: 8/5/2019
14. Permit to Drill Number/ Sundry:
219-095 .
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded:
7/19/2019
15. API Number:
50-029-22193-60-00
4a. Location of Well (Governmental Section):
Surface: 394' FNL, 137' FWL, Sec 20, T72N, R10E, UM
Top of Productive Interval:
675' FNL, 2509' FWL, Sec 20, T12N, R10E, UM
Total Depth:
14' FNL, 4364' FWL, Sec 20, T12N, R10E, UM
8. Date TD Reached:
7/21/2019
16. Well Name and Number:
KRU 1R-1261-1 '
9. Ref Elevations: KB:88 •
GL: 45 • BF:
17. Field / Pool(s):
Kuparuk River Field/West Sak Oil Pool
10. Plug Back Depth MD/TVD:
N/A
18. Property Designation:
ADL 25635, A r.3C4i
41b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 539830 y- 5990810 Zone- 4 .
TPI: x- 542206 y- 5990342 Zone- 4
Total Depth: x- 544053 y- 6991214 Zone- 4
11. Total Depth MD/TVD:
7376/3897
19. DNR Approval Number:
LONS 83-134
12. SSSV Depth MD/TVD:
NIA
20. Thickness of Permafrost MD/TVD:
1682/1630
5. Directional or Inclination Survey: Yes ❑� (attached) No ❑
Submit electronic and printed information per 20 AAC 25.050
13. Water Depth, if Offshore:
N/A (ft MSL)
21. Re-drill/Lateral Top Window MD/TVD:
446313417
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
2$. 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 62.58 H-40 43 123 43 123 24 231 sx AS 1
9.625 36 H-40 43 5593 43 4072 12.25 1170 sx PF E, 530 sx Class G
7 26 H40 42 10201 42 3500 8.5 250 sx Class G
Open _ 4463 7375 3417 3897 4.25 Open Hole
Hole
24. Open to production or injection? Yes 0 No ❑
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
Unlined Pilot Hole...... 711912019
COMPLETION
DAT
S s
VERIFIED
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
4.5x3.5x2,876 9747 9570/6523, 9706;/6614,
4431/3397
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes ❑ No 0
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:
NIA
Method of Operation (Flowing, gas lift, etc.):
INJECTOR WELL
Date of Test:
Hours Tested:
Production for
Test Period
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Choke Size:
Gas -Oil Ratio:
Flow Tubing
Press
Casinq Press:
I
Calculated
24 -Hour Ra
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Oil Gravity -API(oorr):
Form 10407 Revised 5/2017 I_a to/a3// gcoNTIN%OE�?O lel GE 2 RBDMSI�w SEP 0 5 2019s oRIG N on(
28. CORE DATA Conventional Corals): Yes ❑ No 21 Sidewall Cores: Yes ❑ No LTJ
If Yes, list formations and intervals cored (MD/rVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS
NAME
MD
TVD Well tested? Yes ❑ No ❑�
Surface If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Permafrost - Base
1682
1630 Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
4463
3417 information, including reports, per 20 AAC 25.071.
Formation @ TPI -West Sak D
West Sak D
6161
3517
West Sak C
6494
3608
West Sak B
6580
3552
West Sak A4
6700
3682
West Sak A3
6799
3712
TO
7375
3897
Formation at total depth:
West Sak A2
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,
naleontolooical report production or well test results.
1 hereby that the foregoing is true and correct to the best of my knowledge.
32. certify
Authorized Name: James Ohlin er Contact Name: Ryon McLaughlin
Authorized Title: Staff CTD Engineer Contact Email: r)/an.mclaughlin0cop.com
Authorized-/�,//5, Contact Phone: 265-6218
Signature: Date:
INSTRUCTIONS
General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Item 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 lb: 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, vdrinite 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 Onl)
i RAM Final DTD Schematic lam
16; _qP Injector
CTD KOP 4W0' MD, 9928
ssN ,51-M9 in. `
PERFS (pWggedl
sed d9699'-es]Y MD
-santl8881'-98U2'MD
A-sentl 9818'-8041'MO
'Ped
Mp155 shoe �
10,W1'MD
Antic Pack cement6 well
aba9a Me West Sak
f..0
T[Btstlon't BosMllew
cv � See..c.ck
¢ment Bn[guess is Pp
"1R-12fi
068-10,WTMD
i2 -71W Slatted Imes 4830'-10,WT MD
w lM sali'.wq 11000'
}92" sola Met M98'-4830' MD
Deployment alww wlseal Eon: 4498' MD
988 155 sMe M 5599'
Top of 2' cement '87W
Ha[BL aB22-91
PERFS (pWggedl
sed d9699'-es]Y MD
-santl8881'-98U2'MD
A-sentl 9818'-8041'MO
'Ped
Mp155 shoe �
10,W1'MD
Antic Pack cement6 well
aba9a Me West Sak
f..0
T[Btstlon't BosMllew
cv � See..c.ck
¢ment Bn[guess is Pp
"1R-12fi
068-10,WTMD
i2 -71W Slatted Imes 4830'-10,WT MD
w lM sali'.wq 11000'
}92" sola Met M98'-4830' MD
Deployment alww wlseal Eon: 4498' MD
__ .... u¢I i Iuuv 1a_9c WELLBORE 1R-26
KUP [NJ WELLNAME 1R-26 WELLBORE 1R-26
Conoco`Phillips
Aualka.
EPE
MWN JDD(Ia)i gam
&wb t8bwa tre.l'. e..sssu�
sIOMIBuma tiw), e.tw�z
ME.,
NIPPLE:
S (Sd LM).
outofine
I back
LTP
mud
KUP SVC WELLNAME 1R-26 WELLBORE 1R -126L1
..__ w....�w T—TO —
CpnocoPhilllp5
SAS .'T
SURFACE. 42"ESS .1�-
Har(S4mNlvx)
EASE 3-
E.4 .
Sltlb(SbtlN L- ERE-��
SYYt fSbNN llw1
VACFER:
6SE:
operations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
Start Time
End Time
our in')
711 7/15/2019
- --
NRJ, test eline (good), PT Upper
2.00 MIR
08:00 10:00
OPRODIVWVHPST
P
P
7/15/2019 7/15/2019
T
Pgood
P
P
1.00 MIF
10:00 11:00
0.0
0.0T
0.0AKO,
0.0T
7/15/2019
7/15/2019
1.70 IF
11:00
12:42
7/1512019
7/15/2019
1.30 MIF
1242
14:00
7/15/2019
7/15/2019
5.00 MIF
1400
19:00
7/15/2019
7/15/2019
1.00 MII
19:00
20:00
7/15/2019
7/15/2019
1.50 MI
20:00
21:30
7/15/2019
7/16/2019
2.50 MI
21:30
00:00
7/16/2019
7/16/2019
5.00 M
00:00
05:00
M�
07:30
09:30
7/16/21
11:30
7/16121
13:30
7/1612
15:45
r7116/2
7/16/2
18:00
09:30
7/16/2
11:30
7/16/2
13:30
7/16/2
15:45
7116/5
16:15
7/16/:
17:00
19:30
Job: DRILLING
End
Complete RD checklist, prep tor reaK
sows to move the rig
PJSM w Peak pusher and operators.
Jack service module and attach sow,
pull away from well row and spot on
pad out of the way.
Jack Sub, attach saws and move
down well row to 1 R-126, spot over
well and set on mats.
PU service module, spot next to sub
and set down
Work RU checklist. MU Scaffolding in
cellar, Service tree valves, well control
choke, and tangos
Nipple up stack
Rig Accept 20:00 "`
Flood up the stack, walk lines, attempt
shell test, leak. Trouble shoot leak,
call out valve crew, grease tree X2.
Determine swab 1 leaking. Dump
SSV and test against the SSV, good
test.
Start BOPE test, 250 psi low 3500 psi
high witness waived by Jeff Jones
AOGCC.
Continued testing BOP'S, 250 psi low,
3,500 psi high fighting the tree valves
ended up calling out the grease crew
again to service the tree.
-- Witness waived by Jeff Jones of the
AOGCC
Tes:back
ting variables, obtain low,
trouing high test, determine
treeto be leaking by, call valve
creout. Finish test, RD testing
equ`.. OPE Test time 10.0 hrs
Inspect pac-off, inial) NRJ test sub
with bleeder, grease crew on location,
service tree valves
Test Cable head and upper NRJ to
3,500 psi, obsere leak at CTC, bleed
off pressure
Remove NRJ/Cable Head, cut CTC o
and trim 12' of coil
r
��
- --
NRJ, test eline (good), PT Upper
OPRODIVWVHPST
P
P
CTOP
PRTS
PULD
OTHR
T
Pgood
P
P
NRJ/Cable Head (good test)
ind
va've and
pacboff (good to t), blow Idown well
control choke
line Flow nd Ok goadL to1500 psi -
PU BHA#1, Window milling BHA, 0.6
W 3.80 " mills. Load into PDLi valve
check IstnB eedtoff weollr Perform no
0'0
0.0
00
0.0
0.0
0.0T
0.0AKO,
0.0T
flow test
19:302u:uu
7/17/2
7/1612019 7/16/21
20:00 21:00
7/17/2
7/16/2019 7/1612
14:03
21:00
22:18
7/16/2019
7/16/2
2218
23:00
7/16/2019
7/16/2
23:00
23:24
7/16/2019
7/17/2
23:24
00:00
7/17/2019
7/17/22
00:00
00:42
717712019
711712
00:42
02:42
7117/2019
7/17/:
0242
10:42
10:42 113:00
7/17/2019
7/17/2
13:0013:18
7/1712019
7/17/2
13:18
14:03
7/17/2019
7117/2
1403
15:33
7117/2019
7/17/2
15:33
16:00
7/17/2019
7/17/2
16:00
17:00
Operations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
our (hr) Phase Op Code Activity Code Time P -T -X
0.50 PROD1 WHPST SFTY - dead welF
1.010 PRODi WHPST IPULD IY p
a
ck offs
Job: DRILLING SIDETRACK
Start Depth
(f1KB) End Depth (WB)
t#1 on 0.0 1 0.0
:onlinue in well on seawater. tdy
)inchpoint @ 4465'
=lush well with sewater
�ompleye seawater flush, displace to
pilling fluid, Close Circ port
Mill window, Initial pinch point 4465.5,
2.61 BPM @ 1935 PSI FS, BHP=1871
Continue Milling, tenth every 6-9 min.
2.69 bpm at 2,012 psi, WHP=37,
BHP=1,859, IA=552, OA=985
Note: Short pump pressure spike
Continue Milling, tenth every 6-9 min.
2.69 bpm at 2,012 psi, WHP=37,
BHP=1,859, IA=552, OA=985
TD First milling run, PUH and ream @
milled TF 0° @ 2.71 bpm 1,824 psi
POOH
At surface practice PUD milling BHA
#1, Mill out @ 2.79 No go
Trouble shoot. Lay down BHA.
M/U new float tube In NRJ. M/U
up tool and put in well
Continue getting tool in well, Mt
injector and surface test - good
Trip in hole, circ port open
0.50 PROD) vvmv� t ' R'� move. Have good comms through tool
to lower subs. Orienter motor going
into overspeed with minimal
amperage. Trouble shoot software.
0.75 PROD1 WHPST TRIP T Unable to get orienter to respond. Trip 4,430.0 52.2
out
Note: Frame 6 down, bring rig off
highline power.
1 0.20 PRODi WHPST -ULD T Surface test tools (good test) tag up I -522 -522
reset counters
22:30
00:00
7/1812019
7/18/2
00:00
00:30
7/18/2019
7/18/2
00:30
01:24
7/18/2019
7/18/2
01:24
02:00
7/18/2019
7/18/'2
02:00
02:30
Operations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
our (hr) Phase Op Code Activity Code Time P -T -X
0.50 PROD1 WHPST SFTY - dead welF
1.010 PRODi WHPST IPULD IY p
a
ck offs
Job: DRILLING SIDETRACK
Start Depth
(f1KB) End Depth (WB)
t#1 on 0.0 1 0.0
:onlinue in well on seawater. tdy
)inchpoint @ 4465'
=lush well with sewater
�ompleye seawater flush, displace to
pilling fluid, Close Circ port
Mill window, Initial pinch point 4465.5,
2.61 BPM @ 1935 PSI FS, BHP=1871
Continue Milling, tenth every 6-9 min.
2.69 bpm at 2,012 psi, WHP=37,
BHP=1,859, IA=552, OA=985
Note: Short pump pressure spike
Continue Milling, tenth every 6-9 min.
2.69 bpm at 2,012 psi, WHP=37,
BHP=1,859, IA=552, OA=985
TD First milling run, PUH and ream @
milled TF 0° @ 2.71 bpm 1,824 psi
POOH
At surface practice PUD milling BHA
#1, Mill out @ 2.79 No go
Trouble shoot. Lay down BHA.
M/U new float tube In NRJ. M/U
up tool and put in well
Continue getting tool in well, Mt
injector and surface test - good
Trip in hole, circ port open
0.50 PROD) vvmv� t ' R'� move. Have good comms through tool
to lower subs. Orienter motor going
into overspeed with minimal
amperage. Trouble shoot software.
0.75 PROD1 WHPST TRIP T Unable to get orienter to respond. Trip 4,430.0 52.2
out
Note: Frame 6 down, bring rig off
highline power.
1 0.20 PRODi WHPST -ULD T Surface test tools (good test) tag up I -522 -522
reset counters
02:30
03:15
7/1812019
7/18/2
03:15
05:15
7/1812019
7/18/:
05:15
07:45
7/18/2019
7/18/:
07:45
07:57
7/18/2019
7/18/:
07:57
09:12
Operations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
our (hr) Phase Op Code Activity Code Time P -T -X
0.50 PROD1 WHPST SFTY - dead welF
1.010 PRODi WHPST IPULD IY p
a
ck offs
Job: DRILLING SIDETRACK
Start Depth
(f1KB) End Depth (WB)
t#1 on 0.0 1 0.0
:onlinue in well on seawater. tdy
)inchpoint @ 4465'
=lush well with sewater
�ompleye seawater flush, displace to
pilling fluid, Close Circ port
Mill window, Initial pinch point 4465.5,
2.61 BPM @ 1935 PSI FS, BHP=1871
Continue Milling, tenth every 6-9 min.
2.69 bpm at 2,012 psi, WHP=37,
BHP=1,859, IA=552, OA=985
Note: Short pump pressure spike
Continue Milling, tenth every 6-9 min.
2.69 bpm at 2,012 psi, WHP=37,
BHP=1,859, IA=552, OA=985
TD First milling run, PUH and ream @
milled TF 0° @ 2.71 bpm 1,824 psi
POOH
At surface practice PUD milling BHA
#1, Mill out @ 2.79 No go
Trouble shoot. Lay down BHA.
M/U new float tube In NRJ. M/U
up tool and put in well
Continue getting tool in well, Mt
injector and surface test - good
Trip in hole, circ port open
0.50 PROD) vvmv� t ' R'� move. Have good comms through tool
to lower subs. Orienter motor going
into overspeed with minimal
amperage. Trouble shoot software.
0.75 PROD1 WHPST TRIP T Unable to get orienter to respond. Trip 4,430.0 52.2
out
Note: Frame 6 down, bring rig off
highline power.
1 0.20 PRODi WHPST -ULD T Surface test tools (good test) tag up I -522 -522
reset counters
09:1209:4'[
711812019
7/1812019
7/18/2
09:42
10:15
7/18/2019
7/18/2
10:15
16:15
711812019
71181:
16:15
18:00
711812019
7/18/:
18:00
18:24
118:24
20:54 21:06
711812019
7/18Y
21:0621:24
r7/19/2
7/18/2019
7/18/:
21:24
21:42
7/18/2019
7/18/:
21:42
22:42
MENEV
03:12
7/19/2
04:12
2
/2019
7/19/2019
2
P
r7/19/2
/2019
7/19/2019
0
07:30
08:15
7/19/2019
7/19/2
08:15
09:15
7/19/2019
7/19/2
09:15
09:33
7/19/2019
7119/22
09:33
12:48
1248 13:06
7119/2019 7/19/2
1306 13_24
Operations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
Job: DRILLING
plus 5.0'
PUW, 28 k, continue IH
Started milling, 2.7 bpm at 2,109 psi,
Diff=507, WHP=44, BHP=1,859,
IA=138, OA=498
Continue milling 2.8 bpn at 2,440 psi,
Diff=585, WHP=46, BHP=1,855,
]A= 150, OA=502
Crew change, on valve check list.
Continue milling 2.8 BPM @ 2440
PSI, , BHP=1855, Call 9 5/8" exit @
4474.3, Time mill with reamer to
4475.3
Mill Rathole to 4493.3, good sand in
rahole TO sample
Back ream window per procedure, As
drilled. 30L, 30R, 180° from as drilled
hrough window
DOOH
At surface. PJSM, Lay dawn BHA #3
Mill out @ 3.76 No Go. Reamer out @
3.78 No Go. Blow down motor
Make up noz le, Stab on injector.
Flush stack and rig surface lines.
Reboot / Service Antech upper NRJ
P/U BHA #4 with 2.2° AKO motor.
Make up to coil and surface test, Open
EDC
RIH BHA #4, circ sub open, Pump min
rate. Test orienter @ 150' - good
Log formation correction of minus
10.51, PUW 35 k
Continue IH, notice survey's were not
correct, PUH slowly to restart
WHP=42, BHP=1,878, IA=O,
D1ff=3971 W4=21, BHP -1,768, IA=3,
OA=96, increase in clay cuttings
across shaker up to 9.7 ppg MW out.
"' Note: Average Dog Leg in the build
section 22.8°
13:24 116:36
7/19/2019 17/19/2
16:36
16:54
7/19/2019
711912
16:54
17:06
7/19/2019
7/19/2
17:06
17:48
17:48
7/19/2
17:54
7119/2
19:42
7/19/2
20:54
102:54
03:36
19:42
8
03:36
7/20/1
04:18
06:00
08:45
7/2012019
712012(
08:45
7/20/20191
08:57
7/20/20191
09:15
7120120192
116:54
13:15
7/20/20192
13:45
7/2012019/22
14:094
Operations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
Job: DRILLING
DIff=610, W4=44, BHP=2,083,
IA=480, OA=652,
Wiper up hole, PUW 40 k
PUW=29.5K
;lean pass up inrougri
'ag up and space out, PJSM, PUD
3HA#4 Build BHA, Bit out 1-12
)lugged nozzles, Avg DLS in build
?3.4
2emove upper NRJ houseing, Clean
and test head up
Continue upper NRJ service
PIU BHA#5 with .8° AKO motor and
HCC Bi Center with Dynamus cuters
and Pressure deploy. Make up to coil
and surface test. Inspect pack offs.
Tag up
;ontinue in well, displace to new muc
,top @ 44ou to close CV. CV not
responding. Troubleshoot. Reboot
computers. CV closed. tool diff @ 460
PSI
RIH, Clean pass through window, Log
in RA @ 4470.5. Continue in well
Orienter not responding. Trouble
shoot. PUH slowly
RBIH, odenter is working in cased
hole
IA=421,
Diff -517,
Time
116:54 11912
1912 19:54
7/20/2019 7/20/2
19:54 22:42
2248
Uperations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
7/20/2019 7/20/2019
0.50 PROD?
22:48 23:18
7/20/2019 7/20/2019
0.40 PRODi
2318 23:42
7/20/2019 7/21/2019
0.30 PRODi
23:42
00:00
7/21/2019
7/21/2019
170 PROD1
00:00
01:42
7/21/2019
7/21/2019
2.00 PROD1
01:42
03:42
7/21/2019
7/21/2019
0.80 PROD1
03:42
04:30
7/21/2019
7/21/2019
1.80 PROD1
04:30
06:18
7/21/2019
7/21/2019
1.00 PRODi
06:18
07:18
7/21/2019
7/21/2019
0.20 PROD1
07:18
07:30
7/21/2019
7/21/2019
1.00 PROD1
07:30
08:30
7/21/2019
7/21/2019
5.25 PROW
08:30
13:45
7/21/2019
7/21/2019
0.50 PROW
13:45
14:15
7/21/2019
7/2112019
0.30
PROD1
1415
14:33
7/21/2019
7121/2019
3.20
PROD?
1433
17:45
7/21/2019
7/21/2019
0.10
PRODi
17:45
17:51
7/21/2019
7/21/2019
0.90
PROD1
17:51
18:45
7/21/2019
7/21/2019
0.40
PRODi
18:45
19:09
7/21/2019
7/21/2019
3.30
PROD1
19:09
22:27
7/21/2019
7/22/2019
1.55
PROD1
22:27
00:00
7/22/2019
7/22/2019
1.10
PROD1
00:00
01:06
Job: DRILLING
Diff=824, WHP=44, BHP=1,999,
IA=470A=712
BHP=2119. Drilling break @ 6385 to
300'/Hr
Lost TROP pressure spike to 1450
then drop. PUH, 200 PSI increase in
free spin. Unable to get differential
pressure or reactive torque. Try
spudding to bottom. Unable o get any
pressure changes from motor
800'
Saw increased cuttings @
has failed. Metal chunks in bit
uSA
(Ugnui) correction of plus 3.5', close
CV, PUW 28 k
Diff=466, WHP=43, BHP=2,059,
IA=14, OA=509
Diff=638, WHP=53, BHP=2,171,
IA=52, OA=694
BHP=2321. New mud @ bit 7146'
-.1— _..__ BHP=2166
7,375.0 4 450.0
DRILL WPRT P Pew=152K, Drilled 968',AVGhole TD, Pull iper 1OLSswab,
6,45' Rotary mode 639'. Sliding /
orienting 329'. AVG Rotary DLS 4.3°
4,450.0 65.0
DRILL WPRT P Continue swab 800 to 1000' with ladditionaper to lfcutti gs
Tag up and set counters
Page 5119 ReportPrinted: 812112019
Uperations Summary (with Timelog Depths)
K19: NABORS CDR3-AC
Time Log
Staq Time
Eed Time Our (hr)
Phase
7/22/2019 7/2212019
1.00 P5_RODI
01:06 02:06
7/22/2019 7122/2019
0.20 PROD1
02:06 02:18
7/22/2019 7/22/2019
0.50 PR0D1
02:18 02:48
7/2212019 7/22/2019
1.20 PRODi
02:48 04:00
7/22/2019 7/2212019
1.30 PROD1
04:00 05:18
7/22/2019 7/22/2019
1.50 PROD1
05:18 06:48
7/2212019 7122/2019
1.75 PROD1
06:48 08:33
7/2212019 7/22/2019
1.30 PROD1
08:33 09:51
7/22/2019 7/22/2019
0.40 PRODi
09:51 10:15
7122/2019 7/22/2019
0.40
PROD1
1015 10:39
712212019
7/22/2019 0.40
PROM
1039
11:03
7/22/2019
7/22/2019 0.30
PROD1
11:03
11:21
7/22/2019
7/22/2019 0.75
PROD?
11.21
12.06
7/22/2019
7/22/2019 1.10
PROD1
12:06
13:12
7/2212019
7/22/2019 0.50
PROM
1312
13:42
7/22/2019
7/22/2019 1.50
PRODt
13:42
15:12
7/22/2019
7/22/2019 1.00
PROD1
15:12
16:12
7/22/2019
7/22/2019 0.75
PROD1
16:12
16:57
7122/2019
7/22/2019 0.30
PROD1
16:57
17:15
7/22/2019
7/22/2019 1.00
PROD1
17:15
18:15
7/22/2019
7/22/2019
0.75
PROM
18:15
19:00
7/22/2019
7/22/2019
1.00
PROD1
1900
20:00
7/22/2019
7122/2019
0.60
PROD1
20:00
20:36
7/22/2019
7/2212019
1.00
PROD1
20:36
21:36
7/2212019
7122/2019
1.00
PROD1
21:36
22:36
7122/2019
7/23/2019
1.40
PROD1
22:36
00:00
1 R-126
Job: DRILLING
window. Clean to 5000'
Pull up hale slowly waiting on sweep,
PUW=40K, Trip out @ 4900'
At surface, PJSM, PUD BHA #6
Inspect AnTech NRJ, Good to go
PD and surface test lateral drilling
aseembly (good -test).
Tag up, reset counters, RIH
Log formation for depth contort, plus
10.0'
Continue down to log, observed RA
marker, stop and correct plus 5.0'
r hole, bring pump up to shear @
4 psi, set down 3.3 k, PUW 27 k,
, 4,880'
test), tag up reset counters
5.5k DHWOB
PUH, bring pump online, flow 2.8 b'
at 2,742 psi, BHA Duff 940-1,500,
WHP=42, obtain parameters, RIH,
past initial tag to 4872', Confer with
town team, continue pushing down
Shut pump aown, run a��u=r=�•
tag at 4872', RBIH, attempt to mill,
seems we are pushing the billet, set
down 2.2 k
2.5',
slowly make all to town team
POOH for second billet, function open
CV above window, continue POOH
Page 6119
ReportPrinted: 812112019
Time
Erb Time19
7123/2019
7/23/201900:30019
DLOG
T
Log RA marker for -2
7123/201901:00019
7/23/2019
0.20 PROD2
V7123/20197/23/2019
7/23/201903:00019
0.70
PROD2 1
04:42
7/23/201903:30019
7123/2019
7/23/201903:48
RBIH, Tag first billet @ 4919. Orient to
7/23/2019
7/23/20197123/2019
0.30 PROD2
03:48
04:30
Operations Summary (with Timelog Depths)
IR -126
: NABORS CDR3-AC
Code
Job: DRILLING
Inspect cleam and service upper INK
PJSM, PD BHA#9 OH Anchor billet.
Make up to coil and surface test tool
window. Correct+3' at RA marker.
Continue in hole. See first billet @
4920 with 1.8K DHWOB. Orient to
345°ROHS. Stand by for confirmation
from town
04:30
04:42
7123/2019
DRILL
DLOG
T
Log RA marker for -2
7/23/2019
7/23/2019
0.20 PROD2
7/23/2019
7123/2019
0.70
PROD2 1
04:42
04:54
7123/2019
T
RBIH, Tag first billet @ 4919. Orient to
7/23/2019
7/23/2019
0.30 PROD2
DRILL
TRIP
7123/2019
345°ROHS. Close CV Bring on
04:54
05:12
14:18
16:06
pumps. See tool shift @ 4100 PSI, Set
7123/2019
0.20
PROD2
16:06
16:18
down5.5K, TOB=4906.6
7/23/2019
7123/2019
1.20 PROD2
DRILL
TRIP
T
POOH
05:12
06:24
7123/2019
0.40
PROD2
T
At surtace, PJSM. PUD BHA #9.
7/23/2019
7/23/2019
2.10 PROD2
DRILL
PULD
PROD2
17:30
06:24
08:30
7/23/2019
7/2312019
T
Pis P and pressure
7/23/2019
7/23/2019
1.50 PROD2
DRILL
PULD
#10 wiith!8° AKOrmotore altor, and
08:30
10:00
HYC bi center. Service upper NRJ.
Replace flow tube. Make up to coil
and surface test
7123/2019
7/23/2019
0.70 PROD2
DRILL
TRIP
T
RIH BHA#10
10:00
10:42
DLOG
T
Lo formation, Correct +l2, Log by RF
7/23/2019
712312019
0.80 PROD2
DRILL
for92' Continue to top of billet
10:42
11:30
MILL
P
Bringon
7/23/2019
7/23/2019
1.10 PROD2
DRILL
ppumps28BPM4@3060
11:30
12:36
1
1
BHP=1910 PSI. Mill V1 Hour TR=30R
7123/2019 7123/2019 0.60 PROD2 C
12:36 13:12
7123/2019
7/23/2019
0.20
PROD2
1312
13:24
7/23/2019
7123/2019
0.70
PROD2 1
13:24
14:06
7123/2019
7123/2019
0.20
PROD2 I
14:06
14:18
7123/2019
7123/2019
1.80
PROD2 I
14:18
16:06
7/23/2019
7123/2019
0.20
PROD2
16:06
16:18
7/23/2019
7/23/2019
0.80
PROD2
16:18
17:06
7123/2019
7123/2019
0.40
PROD2
17:06
17:30
7/23/2019
7/23/2019
0.50
PROD2
17:30
18:00
7/23/2019
7/2312019
2.20
PROD2
18:00
20:12
4950 Wiper trip past billit area, to 4w
PUW=40K. Billit area clean
4950', Drill Ahead, 2.8 BPM @ 3336
PSI FS, BHP=1913, Diff press=1230
5208', Pull up for survey
reconcilliation, PUW=42K
5208', Drill, 2.8 BPM @ 3320 PSI F8
BHP=1967
2100
120:12
12348
2348
02:00
02:00 103:48
7/24/2019 17/24/21
03:48
04:48
7/24/2019
7/24/21
06:24019
7/24/206:54019
7/24/208:00019
P
7/24/208:06019
7/24/2
08:54019
7/24/:
09:24
7/24/2019
71241:
09:24
11:12
11:12
7/24/2
13:12
7/24/2
13:54
7/24/2
14:00
7/24/:
14:30
13:12
14:00
7/24/2
14:30
71241 i
16:36
Operations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
Code I Time P -T -X
Job: DRILLING SIDETRACK
2040 PSI
100' BHA Wiper @ 5857', PUW=46K,
RIW=10K
BOBD, 2.8 BPM @ 2980 PSI FS, BHP
2100 PSI
0.25 BPM Losses @ 6000'
2130 PSI, WHP 54 PSI, Diff 1200 PSI
0.25 BPM Losses
Mud Swap 2.6% Solids Old System,
New Mud at Bit: 6055'
100' BHA Wiper at 6138', PUW=39K,
RIW=10K
BOBD 2.8 BPM @ 2980 PSI FS, BHP
2050 PSI, WHP 55 PSI, Diff 1400 PSI
HA Wiper @ 6206', PUW=47K,
100. �RIW=1OK
Diff ess than free spin tagging bottom,
pull window wiper 200' early.
Wiper trip to window. PUW=47K.
Circulate bottoms up at window. MW
out 2 ppg over MW in. Blow down
micromotion to correct.
RBIH, Tie in to RA Tag, +2' Correction,.
RIW=12K
BOBD 2.8 BPM @ 2570 PSI FS, BHP
2000 PSI, WHP 44 PSI.
No Losses.
1994, Diff=1077
Diff=1069
BHP=2040, Diff=1215, RIW=3.SK,
DHWOB=2.2K. Decision to plug back.
Drop angle 1,005cut ea
Call TD. Pump sweeps,arChase to
swab in preperation for Anchored billet
iinue in hole, clean pass
low
005, Sweeps coming ou
inhole 200' to 700'
Operations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
Start Time
En'Time
712412019
/29
7/2401
240 PROD2
16:36
19:00
10:00
7/2412019
7/24/2019
0.40 PROD2
19:00
19:24
1.00
7/24/2019
7124/2019
1.30 PROD2
19:24
20:42
7/25/2019
7/24/2019
7/24/2019
1.00 PROM
20:42
21.42
7/24/2019
7124/2019
0.20 PROD2
21:42
21:54
7/24/2019
7/2412019
0.60 PROD2
21:54
22:30
7/2412019
7/24/2019
0.20 PROD2
22:30
22:42
7/24/2019
7124/2019
1.00 PROD2
22:42
23:42
7/24/2019
7/25/2019
0.30 PROD2
23:42
00:00
01:
7/25/122
02:24
7125/2
04:18
7/25/2
05:12
71251'2
05:30
07:06
01:12
7/25/2
0224
7/25/2
04:18
7/2512
05:12
7/25/'2
05:30
07:06
os:oo
10:00
7/25/2019
7/25/2019
2.50
PROD2
10:00
12:30
7/25/2019
7125/2019
1.00
PROD2
12:30
13:30
7/25/2019
7/25/2019
2.00
PROD2
13:30
15:30
Job: DRILLING
Lateral Drilling BHA. Pumping MPD
@ 280 PSI.
Electrical test upper NRJ. Good tes
Checkpackoff.
PD BHA#11. Anchored Billet. CV
Open. MPD pumped: 1 BBL.
Fie in to top of Ugnu, +u uoneuion
✓Veight check above window,
PUW=39K. Tie into RA tag, -2'
Correction. RIH to 4902.3
PU to nuetral weight. Orient to 180°
ROHS. Close circulation valve. Walk
up pump rate slowly to 2 BPM. Shear
at 4200 PSI. Set down 6K. Top of
billet at 4890'.
PSI.
Install new boots. Test upper
Good test.
PD BHA#12. Lateral BHA. f,
pumped: 1 BBL.
RIH lateral BHA. Shallow test
acmitator at 500'.
window. Log RA or+ 1.5'
Dry tag TOB @ 4890'. PUH bring on
pumps. Ease down to get on billet
went past 4890.PUH shut down
pumps. Dry tag @ 4892. Try to put a
little weight on it. Sliding down hole
with 500Ibs WOB. Stopped # 4895
with 5K DHWOB. PUH bring pumps
on feather into billet. Never able to get
any differential on motor. PUH. Confer
with town. Get back on billet dry. Push
down to 4900 where it sat down with
7K DHWOB. PUH Run into billit
working DHWOB from 5K to 10K. 5
cycles down. Billit not moving
downhole.
Trip out of well. Call out billet with 10'
pup joint
OH anchor billet and 10' pup below
3.1.
15:30 119100
7/25/2019 - 17/25/21
19:00
19:42
7/25/2019
712512
19:42
21:18
7/25/2019
7/2512
21:18
22:18
7/25/2019
7/2512
22:18
22:30
7/25/2019
712512
22:30
23:12
7125/2019
7/25/:
23:12
23:30
00:00
Mo e
02:00
03:12
7/26/2019
7/26/21
0312
08:36
7/26/201904:12
7/2612
08:36
08:54
7/26/201904:36
7/2612
08:54
10:12
7/26/201904:54
f7/26/2
10:12
11:12
7/26/2019nssn
7/26/22
11:12
12:36
11111111111�4
08:00
08:18
7/26/2019
7126121
08:18
08:36
7/26/2019
7/2612
08:36
08:54
7/26/2019
7/2612
08:54
10:12
7/26/2019
7/26/2
10:12
11:12
7/26/2019
7/26/22
11:12
12:36
7/26/2019
71261:
12:36
15:00
Operations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
Job: DRILLING
V
u,.,. .13.2. Annular pressuret reading correctly. PUDsor mandrel. PU BHA13.3. Anchored billet withReplace flow tube in upper
PUW-36K. Tag top of billet at 4897'.
Work to Orient to 180 ROHS. Pick up
to nuetral weight.
Close circulation valve. Pressure up
to 2400 PSI shear at 2.2 BPM. Set
down 6.7K.
tools. (Clay on top of coil connector.)
Pump MPD @ 280 PSI. Test e -Line.
Good test.
PD, BHA #14 Lateral BHA, 0.7 AKC
MPD oumoed 0.5 BBL
PUH bring on pump. 2.8 BPM @ 2750
PSI FS, BHP=1938. Start milling off
billet 4888.6, 1 Ft/Hr
4889 6, Aluminum at shaker, Go to 2
Ft/Hr
Diff=967, BHP=1933
Having problems with orienter, PUH
above billet. PUW=38K. PUH slowly
while trouble shooting surface gear
Swap out lower NRJ. Bit @ 1-1
PJSM. P/U BHA#15 and pressure
deploy, Make up to coil and surface
test. Tag up and space out
Start Time
tna
7/26/2019
712612
15:00
16:00
7/26/2019
712612
16:00
16:12
712612019
712612
16:12
17:00
7126/2019
712612
17:00
18:42
7/2612019
7/271:
18:42
00:00
7/27/2019
71271:
00:00
01:00
7/2712019
7/27/:
01:00
02:42
103:48
E��:r'
18:00 19:30
7/27/2019 7127/2
19:30 22:00
22:30
23:00
00:00
7/28/2019
7/2812
00:00
01:00
7128/2019
7/2812
01:00
02:24
7128/2019
7/28/2
02:24
03:06
712812019
7/2811
n7 n6
03:24
0330 06 Uub
7/28/2019 7/281:
06:06 06:24
Operations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
Job: DRILLING SI
Continue in well
Stop running in. Antech sorting out
tool issues after shallow agitator test
epair BHAs.
Repair BHA.
YD BHA#16.1 MPD pumped 1.5
3BL. Tool failed surface test. Lower
NRJ flooded.
PUD BHA#16.1 Pumping MPD @
280 PSI.
Determine incorrect NRJ to slickline
adapter has been allowing tools to
flood during pressure deployment.
Rebuild BHA and replace slickline
adapter.
Crew change out. Run valve check
fist.Stan by for Antech BHA. Inspect
DS PDL. Tighten stuffing bow & upper
shieve. Install Anntech Nogo and
sealing adapter in PDL wire line string.
PT DS PDL to 2000 PSI. Perform
DOMS on crown and traveling blocks.
tube. Meg wire. One wire reading
low, but ok for now.
RIH BHA#16. Pressure sensor not
reading correctly. Ramp pump rate
and record pressure.
BPM CV Closed CV Open
0.5 440 410
1.0 480 410
1.5 625 410
Confirm annular pressure sensor
failed.
POOH to swap sensor mandrels.
PUD BHA#16. Pumping MPD @:
PSI.
NRJ. Good test.
above window.
Tool is rotating in mi
mode, Trip in to drill
Operations Summary (with Timelog Depths)
1 R-126
NABORS CDR3-AC
rme
106:24
06:48
08:18
712812019
7/2812
08:18
0836
7/28/2019
7/28/2
08:36
10:30
7128/2019
7/28/2
10:30
12:30
7/28/2019
7/281:
12:30
17:00
117:00
9141
04:36
04:36
08:30
7129/2019
7/29/2019
1.00 PROD2 DI
08:30
09:30
7/29/2019
7/29/2019
2.30 PROD2 D
09:30
11:48
7/29/2019
7/29/2019
1.20 PROD2 D
11.48
13:00
7/29/2019
7129/2019
1.00
PROD2 C
1300
14:00
7/29/2019
7/29/2019
0.20
PROD2 C
1400
14:12
7/29/2019
7/29/2019
040
PROD2 f
14:36
G2
/2019
7/2912019
0.20
PROD2 t
14:36
14:48
7/29/2019
7/2912019
2.00
PROD2
14:48
16:48
7/29/2019
7/29/2019
1.50
PROD2
16:48
18:18
7/29/2019
7/29/2019
1.70
PROD2
18:18
20:00
Job: DRILLING
pass mrougn wnluu-, �..y ,"•
r for no correction
Drill, 2.8 BPM @ 2922 PSI FS
1955, New mud @ bit @ 4949'
out to inspect BHA and increase AKU.
Atsurfce, PJSM, PUD BHA #17, Lay
down tool
Get tool to Antech shop. Disassemble
upper NRJ. couple of wires outside
normal parameters. Position spool,
Disassemble pressure bulkhead for
inspection / testing. Replace bulkhead
feed throughs.
Cracks found on coil reel while
working in bulkhead. Call out welder
to repair. We cracks.
Re -head eLine. #6 wire still failing
MEG test. Continue to troubleshoot.
Continue troubleshooting eLine. Call
out electrician. Bad test. Trim 8' coil.
Retest eLine. Bad Test. Trim another
5'. Bad Test. Trim 10'. Bad test. (23'
total cut) Discuss with town.
Boot eLine. Stab on to stack. Pump
slack backwards. (3000 PSI @ 7
BPM)
[Rigp hydraulic cutter. Found wire 2'
ut 100' CT and retest wire. Wire
ill low meg ohmes. Cut 50' Retest
same. Cut 170'total CT 168'Wiree upCTC, Pull test to 35K. Make
lug and pressure test CTC to
0 PSI
d up Antech upper NRJ and test
motor and rebuild HCC bi center.
Pressure deploy. Make up to coil and
surface test tool. GOOD. Check
window. See RA for no correction
5107', Drill, 2.8 BPM @ 3548 PSI,
BHP=2004, RIW=14.9. Never able to
get more then 400LBS DHWOB, AVG
nl S=17°
3° above dip. Trip for BOPE test.
Lower AKO motor. At 200' plugged off
choke. Heavy aluminum coming back.
Jog inhole to help clear
PJSM, At surface, PUD BHA#17.
Pumping MPD @ 280 PSI.
MU nozzle, stab onto well, flush
stack. Displace coil and stack to fresh
water. Unstab.
Operations Summary (with Timelog Depths)
1R-126
Job: DRILLING SIDETRACK
Rig: NABORS CDR3-AC
Time Log
Stain Dept
StaTime
Entlrs Time
Dur (hr)
Phase
Op Code
Adivtly Code
P
Time P -T -X
PJSM.
Operation
Rig up polish rod lubricator.
(ftKB) End
0. 0
Dept (flKB)
0.0
7/29/2019 7/29/2019
1.80 PROD2
WHDBOP
MPSP
Stop pumping MPD. Lubricate in test
20:00 21:48
plug.
Attempt to bleed off, unable.
Pressure up. Test plug holding from
above. Discuss with town. Proceed.
Rig down polish rod lubricator.
7/29/2019
7129/2019
1.70
PROD2
WHDBOP
PRTS
P
Grease stack and tree. PJSM. Fluid
0.0
0.0
pack stack.
21:48
7/29/2019
23:30
7129/2019
0.10
PROD2
WHDBOP
PRTS
P
Shell test 3500 psi.
0.0
0.0
23:30
23:36
0.40
PROD2
WHDBOP
BOPE
P
Bgh.egin uEWitness
3500
0.0
0.0
7/29/2019
7/30/2019
PSI waived by
23:36
00:00
Brian Bixby with AOGCC.
7/30/2019
3.70
PR0D2
WHDBOP
BOPE
P'
T�Dntue full OPE test w
00
00
713012019
waived0s
3500 PSI high. Witness by
00:00
03:42
Brian Bixby, AOGCC.
7/30/2019
4.30
PROD2
WHDBOP
BOPE
T
Test joint slide slightly while pressuring
0.0
0.0
7/30/2019
up 3-1/2" rams. Reset joint. Joint slid
03:42
08:00
again Q 2100 PSI. Swap out 2 5/8"
pipe rams. Perform shell test. Test 2
5/8" rams. Good test no slippage.
7/30/2019
2.00
PROD2
WHDBOP
BOPE
p-
Test
Bo
0.0
0.0
7/30/2019
unable get good test on 238",
08:00
10:00
swap to 2-5/8" test jnt, no good,
decision made to swap out variable
rams
7/30/2019
3.60
PROD2
WHDBOP
BOPE
T
Pull VBR's, rubber elements in bad
0.0
0.0
7130/2019
shape, determine incorrrect ram
10:00
13:36
blocks, replace w/ corrected ram
blocks
7/30/2019
1.00
PROD2
WHDBOP
BOPE
P
rm Shell test ,
Pontnue
0.0
0.0
BOP testtestjoint
13:36019
13:36
14:36
WHDBOP
SFTY
PY__
LID test MU no ze, stabon, test
0.0
0.0
019
7/30/2019
1.80
PROD2
RV, unstab, break-Offnozzle
14:36
14:36
16:24
" Saftey Stop: Gather all for rig
personell for short Nabors Safety
Week meeting
7/30/2019
7/3012019
1.25
PROD2
WHDBOP
PRTS
_F7__
Pull test plug
0.0
0.0
16:24
17:39
7/30/2019
0.75
PROD2
WHDBOP
CTOP
P
RD equipment and tools for
0.0
0.0
7/30/2019
17.39
18.24
7130!2019
0.25
PROD2
WHDBOP
CTOP
P
cValvelistw
Part.,
0.0
0.0
7/30/2019
change, perform drawdown
18:24
18:39
7!30/2019
0.50
PROD2
WHDBOP
CTOP
P
sting equipment and
.0
7/30/2019
drill ng cchoke
18:39
18:39
19:09
WHDBOP
CTOP
P
MU nozzle, stab circulate 2.8
0.0
0.0
019
7!30/2019
0.70
PROD2
it over
bpm swapping coil aver to drilling Fluid.
19.09
19.51
7/30/2019
1.00
PROD2
DRILL
PULD
P
cart forward inspect spectt AnTechbNRJlide
0.0
0.0
7/30/2019
19:51
20:51
7!30/2019
1.30
PROD2
DRILL
PULD
P
MU and PD drilling assembly
0.0
58.2
7/30/2019
2051
22:09
DRILL
PULD
P
urf acrsest tools (good), tag up reset
Surface
58.2
58.2
7/30/2019
7!30/2019
0.20
PROD2
22:09
22:21
TRIP
P
RIH w/tlrilling assembly BHA#19
58.2
3,930.0
7/30/2019
7/30!2019
PROD2
DRILL
22:21
22:21
DLOG
P
Log formation for tlepth control
3,930.0
3,954.0
713012019
7/3012019
PROD2
DRILL
22:21
22:21
TRIP
P
Continue IH, log the RA marker (+0.5')
3,954.0
4,957.0
7/30/2019
7/30/2019
PROD2
DRILL
2221
22:214,957.0
PROM
DRILL
TRIP
P
Continue IH
5,160.0
7/31/2019
7/31/2019
0.30
1
00:00
00:18
Report Printed: 812112019
Page 13119
Operations Summary (with Timelog Depths)
e fi Yzt
IR-126
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
StaM1 Time
Entl Time
Dur (hQ
Phase
Op Cade
AMvity Code
Time P-T-X
P
Operation
OBD, 2.8 bpm @ 2,425 psi, Diff=920
(ftKB) End
5,160.0
Depth (ftKB)
5,428.0
7/31/2019 7/3112019
1.20
PROD2
DRILL
DRLG
psi,
WHP=43, BHP =1985, IA=O,
00:18 01:30
OA=555
0.20
PROD2
DRILL
WPRT
P
BHA Wiper up hole, PUW 40 k
5,428.0
5,428.0
71319 7131/2019
1201
01:30
01:42
DRLG
P
2.8 bpm @ 2 425 psi, Diff=920
5,428.0
5,430.0
7/31/2019
7131/2019
0.30
PROD2
DRILL
psi, W HP=43, BHP=1985, IA=O,
psi,
01:42
02:00
OA=555
1.00
PROD2
DRILL
DRLG
P
OBD, 2.8 bpm @ 2,425 psi, Diff=920
5 430.0
5,560.0
7/31/2019
7/31/2019
psi, WHP=43, BHP=1985, IA=O,
02:00
03:00
OA=555
*** Note: Man Down Drill with AAR
details in SFTY Meetings/Operational
Checks
DRILL
WPRT
P
Wiper up hole to 4,950', PUW 38 k
5,560.0
4,950.0
7/31/2019
7/31/2019
0.30
PROD2
03:00
03:18
DRILL
WPRT
P
Wiper back in hole, RIW 14 k
4,950.0
5,560.0
7/31/2019
7/31/2019
0.30
PROD2
03:18
03:36
TR—LGP
BOBD, 2.8 bpm @ 2,340 psi, Diff=731
5,560.0
5,966.0
7/31/2019
7/31/2019
2.80
PROD2
DRILL
psi, WHP=46, BHP=1984, IA=O,
03:36
06:24
OA=578
PROD2
DRILL
WPRT
P
Wiper up-hole, PUW = 39K
5,966.0
5,166.0
7/31/2019
7/3112019
0.30
06:24
06:42
DRILL
WPRT
_P__
Wiper in-hole, RIW —=12K
5,166.0
5,966.0
7/31/2019
7131/2019
040
PROD2
06:42
07:06
DRLG
P
5,966.0
6,455.0
7/31/2019
7/31/2019
3.20
PROD2
DRILL
CWT98S= WOBpsii@5K, BHP=
07:06
10:18
3397 psi, 10.8 ppg @ window, stall at
5989', PUW = 43K, difficulty working
to bottom, lower ROP at -20 fph, then
break out, pump sweeps
0.90
PROD2
DRILL
WPRT
P
Viper tootwi d 4 -4K WOB tug at
6,455.0
4,485.0
7/31/2019
7/31/2019
10:18
11:12515'
DRILL
DLOG
P
Log RA for +3' correction
4,485.0
4,567.0
7/31/2019
7/31/2019
0.20
PROD2
11:12
11244,567.0
DRILL
WPRT
P
Wiper in-hole, RIW =77K
6,455.0
7/31/2019
7/31/2019
0.60
PROD2
11:24
12:00
DRILL
DRLG
P
o3Klbp=831p1r1
6,455.0
6,850.0
7/31/2019
7/31/2019
2.30
PROD2
CWT9 3K, NOB
12:00
14:18
psi, pump = 2912 psi, pump sweeps
PROD2
DRILL
WPRT
P
Wiper up-hole, PUW = 50K
6,850.0
6,204.0
7131/2019
7/31/2019
0.30
14:18
14:36
DRILL
WPRT
P
Wiper in-hole, RIW ='8_5K
6,204.0
6,850.
7131/2019
7/31/2019
0.30
PROD20
14:36
14:54
DRILL
DRLG
P
6,850.0
7,255.0
77517131/2019
90
PROD2
DrWT9 65K, WOBpS11@5K, BHP=
1454
16:48
3233 psi, 10.8 ppg @ window, pump =
3008 psi, swap to new mud system #6
(6% KCI), new mud at bit at 7242'
PROD2
DRILL
WPRT
P
Wiper up-hole, PUW=49K
7,255.0
6,455.0
7/31/2019
7/31/2019
0.30
1648
17:06
DRILL
WPRT
P
Wiper back in hole, RIW 8.0 k
6,455.0
7,255.0
7/31/2019
7/31/2019
0.30
PROD2
17:06
17:24
2.20
PR052
DRILL
DRLG
P
BDOBD0018 WHP =536BHP=12,096,
7,255.0
7,655.0
7/31/2019
7/31/2019
17:24
19:36
IA=244, OA=852
1.20
PROD2
DRILL
WPRT
P
Wiper to the window, PUW 42k
7,655.0
4,463.0
7/31/2019
7/3112019
19:36
20:48
*"Note: Mud weight out increased up
to 9.17 ppg, CR 0.9
Report Printed: 812112019
Page 14/19
AAMM aAhL Operations Summary (with Timelog Depths)
1 R-126
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
our Qv)
Phase
op code
Atl HYCede
Time PJTX
operation
(ftKB)
End Depth MKS)
7/31/2019
7/31/2019
0.20
PROM
DRILL
DLOG
P
Log RA marker (+4.0')
4,463.0
4,505.0
20:48
21:00
7/31/2019
7/31/2019
1.25
PROD2
DRILL
WPRT
P
Wiper back in hole, RIW 6.0k
4,505.0
7,655.0
21:00
22:15
7/31/2019
7/31/2019
1.50
PROD2
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,136 psi, Diff --898,
7,655.0
8,055.0
22:15
23:45
WHP=35, BHP=2,020, IA=235,
OA=853
7/3112019
8/1/2019
0.25
PROD2
DRILL
WPRT
P
Wiper up hole PUW 37 k
8,055.0
7,851.0
23:45
00:00
8/112019
0.20
PROD2
DRILL
WPRT
P
Continue wiper up hole
7,851.0
7,255.0
00:12
8/1/2019
0.30
PROD2
DRILL
WPRT
P
Wiper back in hole, RIW 7 k
7,255.0
8,055.0
00:30
r8/1t2019
8/1/2019
2.30
PROD2
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,548 psi, Diff=836,
8,055.0
8,455.02:48
WHP=50, BHP=2,078, IA=254,
OA=856
8/1/2019
0.30
PROD2
DRILL
WPRT
P
Wiper up hole, PUW 40 k
8,455.0
7,655.0
03:06
81112019
8/1/2019
0.28
PROD2
DRILL
WPRT
P
Wiper back in hole, RIW 6 k
7,655.0
8,455.0
03:06
03:22
8/1/2019
8/1/2019
1 M
PROD2
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,643 psi,
8,455.0
8,628.0
03:22
04:22
Diff --1,230, WHP=50, BHP=2,118,
IA=280, OA=872
8/1/2019
8/1/2019
0.20
PROD2
DRILL
WPRT
P
PUH and cycle power to tools, RBIH
8,628.0
8,628.0
04:22
04:34
8/1/2019
8/1/2019
1.00
PROD2
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,643 psi,
8,628.0
8,855.0
04:34
05:34
Diff --1,230, WHP=50, BHP=2,118,
IA=280, OA=872
811/2019
8/1/2019
1.50
PROD2
DRILL
WPRT
P
Wiper to window, PUW =45K
8,855.0
4,458.0
05:34
07:04
8/112019
8/1/2019
0.20
PROM
DRILL
DLOG
P
Log RA for+5'correction
4,458.0
4,550.0
07:04
07:16
8/1/2019
8/1/2019
1.40
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW = 5K
4,550.0
8,855.0
07:16
08:40
8/1/2019
8/1/2019
2.30
PROD2
DRILL
DRLG
P
Drilling, FS = 1000 psi @ 2.8 bpm,
8,855.0
9,270.0
08:40
10.58
CWT = 6.2K, WOB = 0.31K, 10.7 ppg
@ window, pump = 2759 psi, pump
sweeps
81112019
8/1/2019
0.30
PROM
DRILL
WPRT
P
Wiper up -hole, PUW=44K
9,270.0
8,316.0
10:58
11:16
8/1/2019
8/1/2019
0.40
PROM
DRILL
WPRT
P
Wiper in-hole, RIW=3K
8,316.0
9,270.0
11:16
11:40
8/1/2019
8/1/2019
1.80
PROD2
DRILL
DRLG
P
Drilling, FS = -1000 psi @ 2.8 bpm,
9,270.0
9,546.0
11:40
13:28
CWT = -21K, WOB = 0.3K, 11 ppg @
window, pump = 2864 psi, begin
pumping new mud at 9399', new mud
at bit at 9440'
811/2019
8/1/2019
0.90
PROD2
DRILL
DRLG
P
PU to grab new number, PUW = 44K,
9,546.0
9,710.0
13:28
14:22
FS = 1050 psi @ 2.8 bpm, CWT = 3K,
WOB = 0.31K, pump = 2540 psi, pump
sweeps
81112019
8/1/2019
0.30
PROM
DRILL
WPRT
P
Wiper up -hole, PUW =42K
9,710.0
8,889.0
14:22
14:40
8/1/2019
8/1/2019
0.32
PROM
DRILL
WPRT
P
Wiper in-hole, RIW = 1K
8,889.0
9,710.0
14:40
15:00
8/1/2019
8/112019
1.50
PROD2
DRILL
DRLG
P
Drilling, FS = -1000 psi @ 2.8 bpm,
9,710.0
9,994.0
15:00
16:30
CWT = -1.5K, WOB = 0.21K, BHP =
3027, ECD toe = 11.3 ppg, 10.4 ppg
@ window, cutting ratio = .93, PUW =
62K from 9976', pump sweeps as
required, snubbing to -81K
Page 15119 ReportPrinted: 8121/2019
Operations Summary (with Timelog Depths)
8
1 R-126
qW
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Deem
Start Time
End Time
Dur mo
Phase
Op Code
Activity Code
Time P-T-X
P
Operation
Drilling,CWT=-4K, WOB=-.2K,
(WB)
9,994.0
End Depth (ftKB)
10,055.0
8/1/2019
8/1/2019
0.50
PROD2
DRILL
DRLG
pump = 2592 psi, BHP = 2148 psi
16:30
8/1/2019
17:00
8/1/2019
1.90
PROD2
DRILL
WPRT
P
Wiper to the window, PUW 56k
10,055.0
4,480.0
17:00
8/1/2019
18:54
8/1/2019
0.20
PROD2
DRILL
DLOG
P
Log the RA Marker (+3.5')
4,480.0
4,509.0
1854
8/1/2019
19:06
8/1/2019
2.00
PROD2
DRILL
WPRT
P
Wiper back in hole, RIW 15 k
4,509.0
10,055.0
1906
21:06
8/1/2019
2.00
PROD2
DRILL
DRLG
P
BOBD, 2.8 bpm 2,646 psi, Diff=744,
10,055.0
10,286.0
/2019
WHP=54,BHP=2,103, IA=411,
06
23:06
OA=966
/2019
8/2/2019
0.90
PROD2
DRILL
DRLG
P
OBD, 2.8 bpm 2,646 psi, Diff=744,
10,286.0
10,316.0
WHP=54,BHP=2,103, IA=411,
:06
[23
00:00
OA=966, snubbing minus 23 k, Avg.
ROP 33-50 fph
—Note: Start beaded pills 5x5 @
0,301'
8/2/2019
8/2/2019
1.90
PROD2
DRILL
DRLG
P
OBD, 2.8 bpm 2,579 psi, Diff=859,
10,316.0
10,400.0
WHP=48, BHP=2,051, IA=259,
00:00
01:54
OA=550,
"Note: Bled down OA from 953-550
psi
8/2/2019
8/2/2019
0.20
PR0D2
DRILL
WPRT
P
Wiper up hole, PUW 48 k
10,400.0
10,200.0
01:54
8/2/2019
02:06
8/2/2019
0.20
PROD2
DRILL
WPRT
P
Wiper back in hole, RIW
10,200.0
10,400.0
02:06
8/2/2019
02:18
8/2/2019
1.45
PROD2
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,740 psi,
10,400.0
10,490.0
Diff=864,WHP=51, BHP=2,086,
02:18
03:45
IA=209, OA=530, snubbing -20 k, Avg.
ROP 90 fph
8/2/2019
8/2/2019
0.30
PROD2
ffR I LL
WPRT
P
Wiper up hole, PUW 46 k
10,490.0
9,690.0
03:45
8/2/2019
04:03
8/2/2019
0.35
PROD2
DRILL
W PRT
P
Wiper back in hole, RIW -3.0 k
9,690.0
10,490.0
04:03
8/2/2019
04:24
8/2/2019
1.50
PROD2
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,740 psi,
10,490.0
10,520.0
Diff=843,WHP=56, BHP=2,111,
04:24
05:54
IA=221, OA=527
8/2/2019
8/2/2019
0.50
PROD2
DRILL
-[TR-LG
P
Drilling, snubbing up to -25K,
10,520.0
10,524.0
struggliing w/ weight transfer, difficulty
05:54
06:24
building (dropping), pumping beaded
pills in attempt to transfer weight to bit
"• Unable to stop orientor rotation. PU
off bottom, power down system to hold
HS, trouble-shoot, reboot MD software
8/2/2019
8/2/2019
0.60
PROD2
DRILL
WAIT
T
Unable to power up orienter, decision
10,524.0
10,524.0
06:24
07:00
made to POOH to swap to new
AnTech tools, 15 fpm past billet, clean,
15 fpm
8/2/2019
8/2/2019
3.00
PROD2
DRILL
TRIP
T
POOH, PJSM
10,524.0
58.2
07:00
8/2/2019
10:00
8/2/2019
1.80
PROD2
DRILL
PULD
T
PUD BHA #19 bit came out a 1-2 w/
58.2
0.0
two chipped gauge cutters, inspect
10:00
11:48
non-rotating joint, inspect injector
8/2/2019
8/2/2019
0.30
PROD2
DRILL
CTOP
T
Inspect & UT pipe (13' from CTC),
0.0
0.0
gauge in pipe at –13' from CTC,
11:48
12:06
thinnest wall at .200"
Page 16119 Report Printed: 8121/2019
Uperations Summary (with Timelog Depths)
r }dpi
1 R-126
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Statl DepN
End Time
Dur(m)
Phase
Op Code
Activity Code
Operation
(ftKB)
En�Depth(ftKB)
8/2/2019
3.50
PROD2
DRILL
CTOP
Inspect non -rotating joint, only 2 good
0.0
0.0
15:36
meg on wires out of 7, strip back
cable sheathing & recheck wires, good
rl
tests, wire possibly rubbing with
r06
vibration causing sheathing to
deteriorate, re -head a -line, MU NRJ
8/2/2019
2.10PROD2
DRILL
PULD
PJSM, PD BHA #20 Drilling Assembly
0.0
58.2
17:42
(50 hr NOV agitator, 1.0° AKO motor,
RR Hughes bit)
8/2/2019
8/2/2019
0.75
PROD2
DRILL
TRIP
T
_MH w/ BHA#20, slide in cart, check
58.2
3,980.0
1742
18:27
pack -offs, MU to coil, tag up, set
counters
8/2/2019
-97-2/2o 19
0.25
PROD2
DRILL
DLOG
T
Log formation correction (+7.0')
3,980.0
4,020.0
18:27
18:42
"'Note: Obtain Static Bottom Hole
Pressure above window, 4,465'MD,
9.55 ppg, BHA Sensor @ 3,380.73'
8/2/2019
8/2/2019
2.20
PROD2
DRILL
TRIP
T
Continue IH, logging RA marker
4,020.0
10,524.0
18:42
20:54
(+2.5')
8/2/2019
8/3/2019
3.10
PROD2
DRILL
DRLG
P
BOBD, 2.8 bpm at 2,549 psi, Diff=974,
10,524.0
10,677.0
20:54
00:00
WHP=52, BHP=2,112, IA=O, OA=487
8/3/2019
8/3/2019
2.00
PROD2
DRILL
DRLG
P
OBD, 2.8 bpm at 2,478 psi, Diff=669,
10,677.0
10,768.5
00:00
02:00
WHP=47, BHP=2,130, IA=15,
OA=523
8/3/2019
8/3/2019
2.00
PROD2
DRILL
DRLG
P
OBD, 2.75 bpm at 2,650 psi, Diff=620,
10,768.5
10,813.0
02:00
04:00
WHP=46, BHP=2,115, IA=50, OA=541
8/3/2019
8/3/2019
2.90
PROD2
DRILL
DRLG
P
OBD, 2.75 bpm at 2,650 psi, Diff=620,
10,813.0
10,905.0
04:00
06:54
WHP=46, BHP=2,115, IA=50,
OA=541, snubbing -32k CTSW, Avg.
ROP 30-40 fph, drill to TD of 10,905',
pump 10x10 sweeps
8/3/2019
8/3/2019
2.20
PROD2
DRILL
WPRT
P
Wiper to window, PUW = 45K, pumpF4,480.0
4,480.0
06:54
09:06
10x10 sweeps, log RA for +2.5'
correction
8I3I2019
813/2019
2.50
PROD2
DRILL
WPRT
P
Wiper in-hole, pump 10x10 followed
10,905.0
09:06
11:36
by new mud timed to exit bit at TO
Stack weight at 4889' (billet), PUW =
39K, again stack, adjust TF to 145',
clean past billet, stack CWT at
9975' (though no WOB), did not need
to PU to get by
8/3/2019
8/3/2019
3.10
PROD2
DRILL
WPRT
P
Wiper to swab valve, PUW = 44K, pull
10,905.0
58.0
11:36
14:42
to 60K at 9975'
8/3/2019
8/3/2019
0.80
PROD2
DRILL
TRIP
P
Begin RBIH
58.0
3,978.0
14:42
15:30
8/3/2019
8/3/2019
0.10
PROD2
DRILL
FLOG
P
Log formation for +10' correction
3,978.0
4,030.0
15:30
15:36
8/3/2019
8/3/2019
0.10
PROD2
DRILL
TRIP
P
Continue RIH
4,030.0
4457.0
1536
15:42
8/3/2019
8/3/2019
0.30
PROD2
DRILL
DLOG
P
Confirm 9.8 ppg kills well
4,457.0
4,457.0
15:42
16:00
MD = 4457.64, TVD -sensor = 3408',
drop to 1683 psi, builds 1700 psi,
EMW = 9.59 ppg
8/3/2019
8/3/2019
0.50
PROD2
DRILL
DLOG
P
Log RAfor 0' correction (time taken to
4,457.0
4,500.0
16:00
16:30
confirm between AnTech & geology)
8/3/2019
8/3/2019
2.10
PROD2
DRILL
TRIP
P
Continue RIH, confirm TD at 10,907'
4,500.0
10,907.0
1630
18:36
8/3/2019
8/3/2019
1.00
PROD2
DRILL
CIRC
P
Send beaded LRP down coil
10,907.0
10,907.0
1836
19:36
Page 17/19 Report Printed: 8/2112019
Operations Summary (with Timelog Depths)
1R-126
qW
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Time
8/3/2019 8/3/2019
End Time
Dur (hr)
3.30
Phase
PROD2
Op Code
DRILL TRIP
Acliviry Code
P
Time P-T-%
4000',
Operation
Icontn continue POOH displacing well in bead LRP up to
Stan Depth
(MEI)
10,907 0
End DepVN (ftKB)
58.2
19:36 22:54
8/3/2019
8/3/2019
0.50
PROD2
DRILL -5—VV—FF
to
P
9.8 ppg completion fluid.
At surface,checkwell for flow
58.2
582
22:54
813/2019
23:24
8/412019
0.60
PROD2
DRILL
PULD
P
LD drilling assembly on a dead well
582
0.0
23:24
00:00
•"
Note: Inspect coiil, gouges are
within spec, UT and record wall
thickness
8/4/2019
8/4/2019
—Continue
2.00
PROD2
DRILL
PULD
P
LID
dead well, blow ildown motoling r, l Load out
582
0.0
00:00
02:00
tools to shop,
8/4/2019
8/4/2019
020
PROD2
CASING
PUTB
P
Prep RF for Liner OPS
0.0
0.0
02:00
8/4/2019
02:12
8/4/2019
06:00
81412019
11:30
02:12
8!4/2019
06:00
8/4/2019
11:30
8/4/2019
14:00
3.80
5.50
2.50
PROD2
PROD2
PROD2
CASING
CASING
CASING
PUTB
PUTB
PUTB
P
P
P
PU liner completion (201 jts 2-718"), 55
jots in the hole, crew change
blue PU 2-7/8" liner, 150
jots PJSM, the hole
PJSM, discuss issues &contingencies
with liner in OH, continue PU 2-7/8"
liner (201 2-7/8" jnts total), 1509.74' in
0.0
1,650.0
4,456.0
1,650.0
4,456.0
5,973.0
OH
-- 46K up, 26K down
8/4/2019
8/4/2019
1.50
PROD2
CASING
PUTB
P
Swap out lift sub & safety joint XO's to
3-1/2", PU 3-113" blank liner
5,973.0
6,468.0
1/4/2
8/4/2019
15/2
8/4/2019
1.30
PROD2
CASING
PULD
P
PU
BHA#2PJSM 1 Lnerloyment sleeve RunningT Tools,
6,468.0
6,468.0
15:30
8/4/2019
16:48
8/4/2019
18:33
8/4/2019
20:57
815/2019
00:00
8/5/2019
16:48
8/4/2019
18:33
8/4/2019
20:57
8/5/2019
00:00
8/5/2019
01:30
8/512019
1.75
2.40
3.06
1.50
1.75
PROD2
PROD2
PROD2
PROD2
PROD2
CASING
CASING
CASING
CASING
CASING
PULD
RUNL
RUNL
RUNL
RUNL
P
P
P
P
P
od MU
Tl� to
sett NRJ go PUW 43 k
coat in cart
hoe, settiing down d10,3569h open
continue working Mer towards bottom.
stacking out -30 k
bottoontim, PUH to 60 kestackout - 35 k r towards
Contbottoinue working �Iinr m, PUH to 60 kestackorut - 35 k,
6468.0
6,466.0
10,356.0
10,732.7
10,802.0
6,468.0
10,356.0
10,732.7
10,802.0
10 ,907.0
01:30
03:15
8/5/2019
020
PROD2
CASING
TU—NL
P
Bring pump updiff, PUH, PUWok,5remove liner60si
10,907.0
4404.5
8/5/2019
03:15
03:27
8/5/2019
0.75
DEMOB
WHDBOP
DISP
P
length from counters
DJSMce to towell SWLRer l line andS on location,
PT
4,4054
4,405.4
8/5/2019
03:27
04:12
line to 3,500 psi. stand by for rig ops.
8/5/2019
8/5/2019
0.20
DEMOBEWHDBOP—F5—U—LD
P
P
PUH while displacing well
4,405.4
3,950.0
04:12
04:24
8/5/2019
0,20
DEMOBG
P
Log formation for depth check
3,950.0
4,020.0
8/5/2019
04:24
8/5/2019
04:36
8/5/2019
0,75
DEMOBP
P
POOH
4,020.0
2,500.0
04:36
8/5/2019
05:21
8/5/2019
05:21
8/5/2019
05:51
8/5/2019
0,50
0,35
DEMOBP
DEMOBIP
P
P
diesel to LRS, fill coil with 48 bbls of
Continue POOH
2,500.0
2,500.0
2,500.0
30.0
05:51
8/5/2019
06:12
8/5/2019
1.80
DEMOBLD
P
PJSM, PUD BHA#21
30.0
0.0
06:12
08:00
" 210 psi below master
Page 18119 ReportPrinted: 8/21/2019
operations Summary (with Timelog Depths)
rag: NABOBS CDR3-AC
End Time I Our
10:42
10'A2 12:00
1 R-126
Job: DRILLING
stack, boro-scope stack, pressure
down koomey, break down TT hard-
line, lock -out storage reel & injector,
work RD check list
check list
" Ria Released 8/5 @ 12:00 (noon)
ConocoPhillips
ConocoPhillips Alaska Inc_Kuparuk
Kuparuk River Unit
Kuparuk 1R Pad
111-1261-1
50-029-22193-60
Baker Hughes INTEQ
Definitive Survey Report
22 August, 2019
BA ER
UGHES
,CIE<omoaw
ConocoPhillips
Definitive Survey Report
ConocoPhillips
Local Co-nrdimab Rebbnu: W4111R-26
ConowPhillips Alaska
lnc_Kupamk
1R-26 @60.00us0(I R-26)
Company:
River Unit
WD Reference:
1R-26@80.Oourt(1 R-26)
Project: Kupamk
MD Rehrena'.
She, Kupamk IR Pad
North Referenw: True
Well: IR -26
Survey Calalatlon Method: Minimum Curvature
Wa060re: JFA260
uon
EDT 14 Alaska Prodcti
Datafiaze:
'
1R-1261_1
Kupamk Rod' Unit
Nunn Slope Alaska, United Slates
prolact
Mean Sea Leval
US Skk Plane 1927 (Fxed solution)
System Datum:
Using WeY Reference Point
Map System:
NAD 1927(NADCON CONUS)
Using geode4c sale fador
Geo Datum:
Alaska Zane 04
--
Map Zone:
70.23' 9.012 N
Well R-26
5 990,810 31 usX
Latitude:
33.044 W
Well Posebn ♦Wd
0.00 us6
5]9.02881 usX
Long149.40'
H30 usfl
.04V
0 O usX
Eastingd
gadding:
usfl
Ground Level:
Ground
.-_
0 O0 `0WNmectl
Elevation:Pusher,Pusher,bry
uncena
_—_--
Milton, R-1260
--
piP Angle
Field Resell
(nTI I
Ma0nehcs Model Name
Sample Data
Oeclinatlon
1°I
1,)
5]412
16 51
80.09
'I
BGGM201B
81V2019
I
Design 1R -126L1
.
Audit Notes:
ACTUAL
Te On Depth: 4,45000
Version: 10
Phase:
Dlbcnen
��
(%
Depth From(TVD)
RIaR (Varm
Venlcal Section:
(us")
90.00
_.
0.00
0 00
.
49.20
_
Survey Pmgmm
Dark
survey
Sunday
Dab
Stat Was
End
From To
somey(trnikale)
Toal Noma Owodps°n
1126120142F1
team(wnl
I
Gymdme dedicatingnsing Ms
1R-26-GYD-CT-CMS(1 R-26)
GY0.LT-CMS
711612019
712220MO199
]1
50.00 4,45000
nda
OW6G MWD-SkN
7,344.90
1R-1261_1 MM (I R-126Li)
MWD OWSG
COMPASS 500014 SPAT BSH
Pogo 2
0222019 9:52'51AM
COMPASS 500O14 Shcd 8544
.21242019 9'52:51.495 PaIp3
ConocoPhillips
q
CggCpP11l11p5
Definitive Survey Report
CompamA
pMlea:
Slla;
We!
�y68looso
-. Oolpn;
ConomPhilkps Alaska Inc
Kuparvk Riva Unit
KUDervk 142 Pad
142-26
IR12BL1
1R -126L1
Kuparvk
Local OocNlnate Reference:
WD Reference:
MO Reference:
umM1 Reference:
Survey Calculation Method:
S
Database:
Well 1R-26
1R -20@08.00.-00R-26)
1R-26 ® 88.00uan (1R-26)
Trve
Minimum CurvaWre
EDT 14 Alaska Production
�nurny
iMap
MD
(,am
i /,450,6)
44636)
4494.28
4524.75
45526)
455959
4,62972
465997
469969
411977
474952
477970
4,B1f02
4619.60
486953
409953
492952
4,959.79
4,5"0.26
5.01987
5,34931
5,079.11
5,10973
5,138,16
5,18784
5.19684
S n6.M
5.25581
521051
5.300.5
has
19
6134
51.32
5739
61,63
6621
1102
84.09
895"
9094
09.15
0392
80.35
88.6)
8831
87.51
8721
6).64
88.24
8185
8585
85,52
08.87
81.32
8]6)
6),N
51.N
0]40
95.11
85.97
.15
Ab
PI
10156
10145
105,6)
108.65
1122/
112,3]
116.18
12225
129.52
137,15
145.31
154.10
160.11
163.2
11184
179.48
17861
195.95
163.61
15545
150.9
14246
13447
195.6)
11803
11142
102.61
9465
93,5
8045
TVD
loan)
340821
3.41510
3.434.50
34/9,99
3.461.95
3,476,W
3.48134
3,403.03
348292
3.482.90
34806)
3,484,12
3404.94
3.465,69
3.486.17
3400.14
3493.75
3,49110
3492,1/
3,493.77
3.40..09
3,07 44
3.498.46
346014
3,6)1.34
s.503 11
3,504.56
3.506.22
3,57.23
3,536.42
M36S
leap
3,120.31
3,328.70
3346.58
3,36199
3.313.36
3388.60
3,393.34
3,395,03
3,394.92
3.394.90
339540
3.336.12
3,395,94
3,WAS
3,39B.11
140014
3.401.15
3,403,10
3404.4
3.40571
340299
3.409.44
3,/10.46
3,411.74
3.413.34
3415.11
3,41656
3,41022
34103
3./21.32
.1,1149F1N4
(aan)
418.41
AWSB
AW,33
-09391
E .55
519.65
531,87
546.61
564.02
-6cam
-607.01
-63304
262.13
289 B9
-719.M
-74891
-178.05
2V9,W
23075
266,/2
992.57
-911,24
540.13
-95697
914.47
46637
-9952
-Seem
-1000.45
_ 988.14
luaft)
2,363.02
2,37423
2398.41
2423.61
2446,80
2480.35
2,515.47
2,541.00
3,565,81
2587,73
2600.34
2,62154
2633.51
264242
2.610.93
2651.24
2,651.74
2,654.10
266.41
2670]4
268420
2,100,98
2.72.97
274299
2,761.50
2193.78
2,822.21
205.91
286582
_202.70
NofMlnp
hill
5,96),395./0
5,960,3/241
5,993.336.81
5,990 329 31
5,99].32084
5,990,303.91
5990.29149
5,930,211.30
59902&1.02
5,950,239.51
5,99031644
5,9m,16om
5,993.16188
5,990.134.51
5,9m,106,44
5.990,075SO
5,99004 kk
5,993,01555
5,909,905.82
5,908,958.21
5.989,93214
She 907.55
5,909,89477
5,989,866.95
69NOWIW
5,989.038]2
5,989830.16
5989.825.88
5.9139.82524
5,989,82210
Map
Eaannp
MI
542 tLK.92
512216.33
54223060
542,255.18
542.21681
542 32065
542341.83
54?31424
5@,39639
542.420.36
5/243009
542.454.4/
542436.61
542.47560
542/8227
542484.14
542,485.40
542481.52
542.49139
542,5M.87
542,51847
542.53 .09
542555.40
542,577.60
5426)219
542628.53
54265200
542685.78
54270043
542.130.50
D�
1°ndMl
1.81
065
21.96
1780
19.50
2443
2438
26.85
2/.94
2.05
27.95
29.10
21,12
680
28.29
MA3
346
2104
2899
28.34
18.25
2790
26.51
21.11
2.95
23.6)
21 as
2713
21.5
3409
WNuI
nactlan Survey Taa114ama
Inl
2.363.02 GTDCT-0959 (1)
2.37423 MWO OWSG(2)
239041 MWD MSG (2)
2423.61 MWOMSG (2)
2446.60 MWO OWSG(2)
248035 MWD MSG (2)
2,515.47 MWD MSG (2)
2,54180 MWD MSG (2)
2,56501 MvW MSG (2)
2,587.13 MAID MSG (2)
260634 MWDOWSG(2)
2621.54 MND OWSG(2)
2633.51 MWOMSG (2)
2,64242 WdvDOW5G(2)
2,648,93 MD
265124 MMDO SG(2)
2.651.74 MWD MSG (2)
2,54.10 MWD MSG C2)
2,950,41 vvsDO (2)
2.670,74 MD
268420 MMMSG (2)
2100.69 MWDOWSG(2)
2,720.91 MWOMSG (2)
274289 MND OWSG I2)
3.761.50 MOAD MSG (2)
2193)0 MWDOWSG(2)
2,82221 MWO0 MSG (2)
2,050.97 MWD GWSG(2)
2,966592 MNO MSG (2)
2885.70 MD MSG (2)
Amotetion
TIP
KOP
COMPASS 500O14 Shcd 8544
.21242019 9'52:51.495 PaIp3
annotation
DOMPA55 5000 .1.4 Build SS
ConocoPhillips
ConocoPhiiiips
Definitive Survey Report
Project:
Site:
u
Cono9Pblp/lezke lnc_Kpemk
Kuoamk River Unit
Kuparuk 1R Pad
Local Do neReference:
NReference
MD Reference:
n:
Na Referece
-
IR-26 (IR-26)
zCmDany.
1R-26988.006n(1R46)
Tme
Well:
Wellbore:
IR-26
1R-126L1
ey calculation efOotl:
SurvumM
Oatabaze:
Minimum Duna tume
EDT 11 Alaska Protluclion
Denim:
2R-1261.1
SurveY
---
ka
5,331)3
15,33
5,3599
5.3%]0
$moo
i 5,451.08
549068
5,5129
5,54069
5,57901
504,.
SAK,53
5950.55
5.61
571809
5.748.72
5,775.9
5,810.65
5.8'6.28
5098.53
5,959
59M9
i 5955.15
5.1'0.9+
691.25
6,052.31
6.1019
i 6,134.19
6.269.31
6,29.37
6.232]7
6,29.67
L
Inc
87
9228
0293
00.45
88.63
6.40
8059
B6.T1
8989
8887
9.E4
8820
80.74
9084
88.79
9.2]
B9.i]
90.73
90.87
90.81
90.90
9037
9141
90.37
90.6
9.34
90.15
89.9
87.45
BSW
82.9
79.65
Aa1
1°1
7/.09
7!]8
71.63
Saw
8060
6521
94.68
93.18
8161
E0.31
61.75
9.39
6,14
63.48
6150
61.80
62.9
SO 32
8011
9.49
58.90
SLW
57.18
5424
5276
9)1
5362
46.30
409
4370
42.%
(-a
IeeM
3.512.03
351226
3.51310
350.9
3,514.03
3.525.61
3516.47
3.517.13
3r517.T'
3.510.36
3.519.07
3,519.9
3519,95
351985
3518.83
5.529.82
3519.67
3,51931
3518.84
3510.4
5.528.00
3516.6
3,5129
3,53683
3989
3,516.35
3.51858
3.517.98
3529.48
3522.61
3531.9]
ryo"
IusM
3.4239
3.42!26
3,425.18
3,426.9
3426.03
3,41.61
3428.47
3,429.13
3.4.4.77
3430dfi
3,431.07
3.431.80
3,431.96
3.43185
],43163
3.43282
3.431.67
3,431.32
3,43(1.84
3,430.42
3,43000
3.421.83
34299
3.4892
3,428.55
3,420.35
3,42858
3431.98
3,/31.48
3434.61
343897
♦W8
Iuel3
6B 74
ET].36
-956.6]
-959.87
543.9
52].]3
E13.84
49.9
48]6]
47!9
-561.70
448.06
-83426
ffi056
x;,083
.36
-7799
-]809
-779.49
-]10.10
5910
40233
639
835.10
-616,79 583.6
560.9
55005
329.9
♦EFW
Iu2Rl
2,853.0]
2.4°093
3,01033
3,03907
],096.2]
309921
3,1229
3,1%45
3,176.28
319A9
3.84.24
3.29.76
32]020
3,304.4
328 05
3.39.09
330156
3,49.56
3.496
3,484.75
3.51!9
159.12
3,561.09
3.801.64
31,07
3,66%.]0
360272
3]03.11
.3_24.9
MoD
Northing
ISR
5,959.84041
599.04093
5.909859]8
599,8]175
5,909083]5
5,9998919
599,92323
5,989,92].41
.N.W
5,999
5.909,953.62
5,99.9587
5,99,9]8.9
5.989993.9
5,993.9242
5,90 (120,27
5.9590,03862
589.04933
5,990,069.49
5,990,079 42
5,990095.33
5.9o'no4
0.131]0 5,99
59910,165.437
5,99,194.40
5.991
589..222
5,990,250.09
5,90,283.04
5990.39.20
Mao
Eaztln8
Inl
W 76. 80
54278]90
542825.82
54841.65
542.0]3.62
542,99.ffi
542935.61
542,%1.91
542988]0
543.010.4]
54393,9
543,85820
543084.11
543,112.08
511.13020
43 161.7a
313,192.]4
543215.15
54.2 Sa
543.9-939
543,318.9
WS47.23
54335090
54343243
5,114,3J5
543498.23
543535"
&13GIG 535.44
_543554.8
DLS
i°ItoO'1
ou3
11.36
10.08
10.30
4.53
!34
285
4,78
5.23
520
559
2.01
9.B5
2.98
6.08
2.18
3.07
Z]0
Ofi]
2.30
5.]6
351
4.867
]65
1652
104
Zan
20.31
Vertical
Section Survey Tool Name
n
11 _
2953.07 NWDGMSG 12)
2,90093 M MSG
G{2)
3.020.33 M'ND MSG
3,99.07 WDOWSG (2)
G(2)
1.066,17MVVD MSG
3.99.21 80008096{2)
3,127.59 enNo MSG{2)
3,154.45 MND MSG (2)
31]6.29 MWD MSG (2)
3,29949 WDOWSG{2)
3,22424 WD MSG (2)
3,25076 WD MGG (2)
3,270.20 ~MSG RI
3.301.4] 3180008056 R)
3,32SO5
3,$909 WDINOOD GMSG (2)
3,301.9 MND MSG R)
3.409.56 WD 26 WND MSG 121
3,4976 MNDGWSGRI
3,4&.]5 WDGWSG R)
3,5319 80008066 R)
3.564.04 WDMD DWSG I2)
3.60!fi4 80008096(2)
pgeiG MSG (2)
3665.30 MWDMeGR)
3,682.4 MND MSG R)
3,]9,11 NN2D MSG 121
3,791.00 WDOW
Pepe 0
8422019 8:52:51.431
annotation
DOMPA55 5000 .1.4 Build SS
ConoeoPhillips
s
ConoeoPhillips
Definitive Survey Report
Company
LanocoPM1ipps Alaska lnc_Kupenk
Local CooNinate Reference:
WD Reference:
Wall 1R-26
1R -26a N,OousS(I R-26)
Project:
Kupamk River Unit
MD Rehrence:
1R-25®88ADosit(I R-26)
6Re:
Kupamk 1R
Pad
Norte
Tion,Reference'.
Well:
1R-28
Survey Calculation Method:
Minimum uure
WelOen:
1R-12GL1
Database:
EDT 19 Alaska Preelection
Desl9n:
1R -126L1
Survey
MD
(no)
6290.91
8318.83
6,349.79
8.3]9.49
6410.01
1 6,431.32
6.41561
6,504.0]
6.565.42
8.%5.23
6,59545
nusee
6,853.93
6,815.21
661959
6743]6
6773.16
6,101.89
6,832.23
6162.91
i 6,911,14
6,911.14
6,940.79
6,8]0.93
1,0015
` ],030.17
7,055.31
( 7,012.12
718397
] 148.28
7 90.18
Inc
1°I
96.27
]250
6939
ft5.0
65.44
Wait
67.80
66.E
6937
603]
68.33
6690
10.11
]0.32
72.0.3
9224
am
14.67
7251
72.00
72.10
]233
71M
]1.94
]3.0]
and
14.98
]3.28
]346
73.53
72.04
All
t°l
4215
4).84
69.83
42.49
40.43
41.34
3 ].90
34.91
34.69
32.46
3283
32.55
6165
2].52
30.00
14.06
ffi89
2].09
26.00
25.15
25.14
25.3]
an
1272
25.31
21 TO
23.80
33.21
21.82
2176
7330
M
]Man)1141
3,5333]
3.54064
3.517.91
356211
3,579]8
3,58589
3,556
3.611 Be
3.623.95
3.61.34
364549
3,655.58
].fiW.42
3671.60
3,fi8 .
3695.30
370444
3]1315
3TR.22
3.731.54
314U33
3.6W.33
3.]55.14
3.]E9I9
3.7]3.]4
?]818%
3, Plate
3)9].11
6,17.9.38
3,81605
3, 62.]9
WDSS
(ball)
],145.2]
345264
3,463.]1
3,474.16.10
3.486.78
3,497.89
3517.&5
],52186
3535.95
3.546.64
3,55].49
3,588.50
3.51642
3,MD)
3.598.41
3,80].30
3,616.14
3625.15
3.834.22
3,543.54
3.8523)
3,858.33
].85].44
36]fi59
3,685]4
3.693%
3,]0139
3,]09.10
3.706.30
3ran,06
3]34.39
.1114♦EIXi
plan)
EOB.t9
46&18
-465,68
44517
-00533
-38525
-355,59
-331.18
JOB.EB
-MV
-26216
-239.BfiI
.-31962
-189.94
-166.17
-141.89
41644
-00.61
fi4.3t
X69
-2Zee
280
26.39
5595
51.11
1173.42
12694
155.13
ti3
205.11
(nam
3,]4198
3 769A
3778,73
3]95.74
3,831795
3,8450]
3,800.65
6,00679
3,9o0.9B
3.91617
3,93145 3,94544
3,958.94
3,97332
3,9lfi.fil
3,883.26
4,61212
4,0]5.20
4.03].95
4049.51
4,05]49
4.068.02
1,017.13
a.69z93
4,112.26
4,12.50
4,13910
4,116.40
9154.26
pprM/tp
IRI
5,990.]22.10
22
5980.3411
59W3"81
5,990 3B5.58
5,990.423.015.12 5 643 48
5990,44560
5.993.]9986
5990.499.86
5,890521.48
0.545.19 5,93
,12
5,990,591.49
5,990,017.11
SSW.14155
5,990665.55
5,917,689.94
5,993.]1525
5,990.741.15
5.990,14].51
5,90,802.19
5,990.am D6
5,990,834.96
5,913.85143
5817,917
5,segEY+fi2
5,990.9a9' 19
5,980,96].44
5.W10t0.06
599103752
Map
Eastln9
IRI
543 574,08
593.591.E0
543.62e.48
613,fi62.99
643.6]9.50
543.117.93
543.]292
543,]32ot
543.741.04
75221
50.17]609
543790.45
543803.70
543,8161fi
543829.38
543.04210
546,055.114
543,65765
543.OM97
513898.97
543 B98.F
543,90932
643,921
593,9310
541941.17
513.85117
793962]0
543,9]455
513.912.51
DLS
Intact)
1291
1591
5.23
1198
108
152
602
118
2.05
537
124]
611
8.69
4.00
225
158
97]
1So
163
613
0.53
10.32
12.58
797
235
4.28
426
394
Vertical
Section Survey Toni Name
IRI
3.741.95 iaND
3,]59.69 MWDGGWBG (iI
3]96.74 MND MSG (2)
3,815,12
3.11.45 MN90WSG(2)
3.848.0] MNDGWSG (2)
3,819. 65 MAD MSG(2)
3,885.]9 MW90WSG(2)
3,9M.9v MNDGW6G 12
3,916.14 WID MSG (2)
3.WlAS
3.945.44 enNoO 9G 12)
$959.94 pen,lego MS
39]332 MWD MSG I2)
3.�B.6t MND OW6G (2)
3.999.25 MWD MSG (2)
4,01212 MD MSG (2)
4.MS20 M'ND MSG (2)
4,0.1].9.5 MWD MSG(2)
4.MT41 MWO MSG (2)
4,(5740 MVYD MSG (2)
4,[69.02 MND MSG (2)
9080.13 MWD MIG(2)
4,IM.93 MND MSG (2)
911226 MD (2)
912250 MWD MSG (2)
9134.11 MNG MSG (2)
4146.40 MND MSG (2)
4154.26 MWD OWSGI
Annotation
,
i
COMR155Scoot f4 Bu11tl e5H
_
Page 5
fl212019 9:52:51AM
Papa 6
eI12rz01g 9:0:51AM
COMPASS SWC 14 8.0 OW
iig% o
��`'
ConocoPhillips
Definitive Survey Report
ConocoWIMPs
Local Coartllna[e Reference:
Mir 1R-26
CDnomPlulllp Alaska lnc
Kuparuk
1R-26@8600us6(1R-261
Company.
Kuparuk River Unit
WD Reference:
1R-26@ 08.00us8(1R-26)
P,en;
MD Resereace:
Site.
Kupamk I Pad
North Reference'.
True
Well,
iR'26
Survey Calculation Method:
Minimum Curvature
1R
EDT 14 Alaska PreJuceon
Wellbore:
-126L1
Cents..:
Design:
1R-12611_.�--
Survey
Map
Map Vertical
liwhm Survey Tool Name
Annotation
A!
TVD
Mae
+W44
rE4W Northing
Eluding ('DLS
MD
Ina
I7
(toil)
(-to
IMstg
(-am (RI
11
1590 416]10 MO GWSG I2)
Iuilt)
rl
2J2.]J
116]10 5.S9tW5.21
54399530
720214
Rru 2)5]
3033.02
3,]44.02
5.991127,59
544m.0 rz.w 010624 MVD OWSG(2)
22.90
3.046.1
3]69'22
2&9DJ
4184.24
SN.022.45 G]3 0194.69 bM'D OWSG I21
]246]3
BB.99
3,M9.23
294.0]
4,194.80 5,991121W
61 420681 MWD OW5G(2)
1
]3]4.3fi
6].3] 21.69
J.05].23
3.]03.2]
3M..97
4'2[6.61 599115]60
M0 Y
0,21].34 MWD OWSG 131
1 yg99
6633 27,04
3,9H2]
J,]9].29
30.0
4,21130 5,93118].01
544046]0 ]5]
4,22593 PROJECTED to TO
].3465)
E6.It 18.16
3,805.29
022593 5,991314.0]
544053.24 000
],3]5.00
66.01 1&16
3,097.30
3,049.34
X129
Papa 6
eI12rz01g 9:0:51AM
COMPASS SWC 14 8.0 OW
SAER
I UHES
a GE company
Date:
Abby Bell
AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska 99501
i
August 22, 2019
21 9095
31119
Letter of Transmittal
Harvey Finch
Baker Hughes, a GE Company
795 East 94th Avenue
Anchorage, Alaska 99515
Please find enclosed the directional survey data for the following well(s):
1R-126
1R -126L1
1R-126PB1
RECEIVED
AUG 2 3 2019
AOGCC
i
(3) Total print
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Note: Please feel free to send us an email in place of return mail.
Harvey Finch, Baker Hughes, Wellplanner
Harvey.Finch@BakerHughes.com
kft a,
rn
0
rn
� M
N
6mU
L
m
Y
U
I
A
U
� t o
m a A
r T
Y Y CO N
i M N O1
N
CL rL O
IRAI
A
r.
CL
w
r4e
U
(
}\(/
12
(
�•!,_
2|)!@
}\(/
12
\
\§
^
2((
7!§
!!;
CL
w
@
0
t
0�
�
\k)|/k
\\!
.
7
§!!
°!!
\
t5
\
\0
/\
|!!
;
�•!,_
2|)!@
}\(/
12
\
�•!,_
2|)!@
7
�\
}\(/
12
7
�\
a
O
O� M W •n[1 ffP� W N Nq O ImIo� 0 2 A N l0 N P m �2 NIp IP O O�1 10 IA`I T mN
(n q P �vri m 3 W N OI P O O O m N N N N M P O V h i0 N N 1O. m IO
a
m N� N�
P
N
0 M
N N N N
$� P�
Im•1
(NO <
b V
A
E
y,FoBe
N
S88S8
0
8�o8S
i!1
$"dP��'
�8'S"=
m
o�8SS
?�
M
M
M 17 M m
M
M
M M
M 1+1
M NI C) f•1
M
M M M
Ci
M
M m
M M
M M M
33i
5�33003»33
S3
a
0 0
0
0 0 0 0
0
0 0 0
0 0
0 0 0 0
0 0
0 0 0 0
0 0 0 0
0
0 0
y
gg
gg�
gggp��
�ggg�
Y'
g ggg�g
F �
M
Oi Ci Oi Oi
M
CI
✓i
Irl t•'i
IM M
M
Ci IM IBJ
N C
N N O
N
i0 NN
0
PI�
O O1
N
mW
O
O
Or
T
pm p0
Np
O O
�M
(� 10 N
IINI
H
1N1pp
pn tryO
N
C
pN
V
•Y
P
W l0 m$
OMi
OI $ O
-
- -
ry
- - - -
- -
fN•1 0 4<
- - - -
It)
- - r- .-
0
10 f0
W
D
K
ii
m
a
�p
�Ipp
ry
p �p
^ m 0
.
. O m N
N
Oi < N
(O O�
m A
m
o
mW 0
0 m
m$ mN
N
� r
M
•-
y
tt
H
���
J
O
P
0
O
�
m Cml
V 0
MW
N N
W
O�
m
O tm'1
Yi
53
N
N
W
N
C
f
N
d
tV
I.
O
O P N m
m
N
tV N' r
N •D
y0 ry
�Wq gyp.
rp. �'p
y� �Np
tm�
�fW�yl
IO b N m
m 1�
30�
j
P �W
9
P P
y¢
o!
3
@:
m m
m
m B m m$$
8 8
R y C
N N
N
p yN y p
p
[pV yN (V
pp
ppppVV Npp
N
pp ppVV
� N yy
N
N N
r-
�
Imrk p
p
pp
p
p�
O
y
W
hi
u
ppp
m0
9
(pO
m
ry
W
U
O
W
O<
f
'
M
.G
4
n^
pp YI 1p0 IN
m
NW (rV n^
n
r N O r
p'
�p N �Ipp
ry� A
m N
C
Z
G
�
vaw33ti
y
Q
7
S
O
Z-
N N
N
N Itl Ir) IN
VI
N N N
N Yl
h IN N N
N N
N Yj IN N
N N N Vl
IN
� N
U
mE
'ti
c
=
O
>
'E
°
N
v
O
'c
p
y
•Si
U
a
n
,u
ry e m$$
o w '$
n m$
n m `�
v <o
n ry a�
`� 'v m y
19i
m m
IA.I
0w
�
�
z
A
3c
N �
�
�
� � �
N
� � �
r �
'v �
W W •�
w
W
N_
3
J
•2'
Z
N
O
a -
O� M W •n[1 ffP� W N Nq O ImIo� 0 2 A N l0 N P m �2 NIp IP O O�1 10 IA`I T mN
(n q P �vri m 3 W N OI P O O O m N N N N M P O V h i0 N N 1O. m IO
z
0
h
W
m
m N� N�
P
N
0 M
N N N N
$� P�
Im•1
(NO <
b V
A
y,FoBe
N
S88S8
0
8�o8S
i!1
$"dP��'
�8'S"=
m
o�8SS
?�
M
M
M 17 M m
M
M
M M
M 1+1
M NI C) f•1
M
M M M
Ci
M
M m
M M
M M M
Y'
F �
M
Oi Ci Oi Oi
M
CI
✓i
Irl t•'i
IM M
M
Ci IM IBJ
Ci
M M
M M m
O
C
W
�p
�Ipp
ry
p �p
^ m 0
rW
0
0
0
N m mW
m A
m
o
mW 0
0 m
m$ mN
M
W
y
tt
H
�2
o
Yi
53
8 0
o 8
9
Y
y¢
o!
3
@:
m m
m
m B m m$$
8 8
m$
m$ m m$
8 S
m
8
8
m m
•, O
r-
�
Imrk p
p
pp
p
p�
W
U
O
C
4
RM
vaw33ti
y
z
0
h
W
M t7 N N O P gO m 0 0 m 0 (0 0 0 0 0 N r N 4 P [O r
RP N m m mi a e a v'i vP1 vmi .o m
+ r
O m m N V O N N�p N 01 m O O o N O m y O N m �V0) IYN�I yrs y b� � Pp N Omm1 N h 00p Y,
Q y<@ O m� 0 4 p tmh s p Q N N^ N N N N N YI N p P Q N m M iP P M
F v m
tf
d
O
m
W
N V Q N
b�
N
U1 m�
N
O m
O N
m N
N r
1D
P tm0
E
O 01
r
O
O
d
o
j
_
_
y
u1
In
N
N N N N
N
N N
N N
N h
m N
N Yl
IA rn
I`I 10
10
� u1
Q
N N
C
Y�
00000000000000
O
S
m O
P
N N
ImO N
000000000000000000
pp mm
N m (0
�2
�2
n N
P
Ol IP O
�p
t0
�p
P m
of
•�
�
m o
0
0
0 0
0 0 0
0 0
0 0
0 0
0 0
0 0
0 0
0 0
0
0 0
0 0 0
0 0 0
�p �p
�p1�
Ab�pp m O
y ggg
P p
m
P
ggg�g
T
ggg��
�g�gg
C
gggg�
EJ
O
gg��€�
T O1
�g�
m
N
b (O I(ml
b
P
P C
M
M (ggO
N N
N
a
Z
C
f E C rn
gm� $
2
2 2 m
m
�
o
�
�
� m
� m
m^
yd
�'
m
`r9i
P m O N
r
di 3i
N m�
m
10
Q
c r
n
r
m
m m
,.O'
r
r
b
N
ry m
M
y
Y P
1^
N
N
N Y1
N
- —"
`
`
`
- ` -
- `
ry
N
N N
N
N
N N
N
N N
N N N
N N N
d
�
a ✓
W
W
�
y
r
r
d
9
m
�y
ry
p
J
J
m
OO
N
d N
M N m
O T
�
K
S
tV t7
10 IM
�
b V
m M
m j nj
C
O
�k
p
d
lJ d
y
tm0
O
b
eepp
O
N
I� h
N r
y�
1U N
N
N O O
N
N
r
N
0
�p
D N N
N O
U
rc
Z
3 m
M
g
S$ '3i
51 m
m m
S
S '°
'ImR
m N
�
�
N
'pvi h
01
n
`u4 y
N
N O M N
p
A
in O
r 10
N N
A P�
ry
J
t7
N
p
S
SN
� h
m 01
0 0
0
Pp mV
N P
N yN�
�pU�
p
J
F
V
P
d
m 0
+ -
m Fi
m R
N
-4�
m m
1 (
o O`
O
P
mm
m m
q
m
m m
m N 01
OI 101
`
H
E
C
W � a C N
Nyy
O
N
P
p
pN yp
py
P
pp
P V
N C!
P
(J (J
N N
N ry
pN
p N O
p lV
CL
W �
b
N
10 h
Y1 N In
N N
N N
m N
m
N N
N IlP1
N IO
N
b N
i(1 N N
N N h
M t7 N N O P gO m 0 0 m 0 (0 0 0 0 0 N r N 4 P [O r
RP N m m mi a e a v'i vP1 vmi .o m
+ r
O m m N V O N N�p N 01 m O O o N O m y O N m �V0) IYN�I yrs y b� � Pp N Omm1 N h 00p Y,
Q y<@ O m� 0 4 p tmh s p Q N N^ N N N N N YI N p P Q N m M iP P M
F v m
tf
O
m
W
N V Q N
b�
N
U1 m�
N
O m
O N
m N
N r
1D
P tm0
m P N
O 01
r
O
O
o
j
y
u1
In
N
N N N N
N
N N
N N
N h
m N
N Yl
IA rn
I`I 10
10
� u1
Q
N N
C
Y�
��pp
O
O
S
m O
P
N N
ImO N
pp
N N b
pp mm
N m (0
�2
�2
n N
P
Ol IP O
�p
t0
�p
P m
of
•�
�
�
M
U
L
y01
p1
s
p O
m pm
m p
lV ni
� Ih
f
pmaV N
pN
�p �p
�p1�
Ab�pp m O
^
P p
m
P
T
wO.
C
O �
EJ
O
O O P
T O1
m
m
N
b (O I(ml
b
P
P C
M
M (ggO
N N
N
a
Z
C
f E C rn
gm� $
2
2 2 m
m
�
� �
�
�
� m
� m
yd
�'
m
P m O N
r
di 3i
N m�
oo
0 N�
Q
N
q
h r
d
,.O'
Z Yl
b
N b N
N b
IN N
N u1
N N N
N N N
N
N
N Y1
N
N IN N
N N
N YI
N
b
N
--
d
a ✓
W
W
�
y
L
a
K
S
m
a
m
a
Q
C
O
�k
p
d
lJ d
y
tm0
O
b
eepp
O
N
I� h
N r
y�
1U N
N
N O O
N
N
r
N
0
�p
D N N
N O
U
rc
Z
3 m
M
g
S$ '3i
51 m
m m
S
S '°
'ImR
m N
�
�
N
'pvi h
01
n
`u4 y
N
N O M N
p
A
in O
r 10
N N
A P�
ry
m
t7
N
b N0
S
SN
vN^1
lm`Q1 1`R
N
J
F
f
ZO
d
m 0
+ -
m Fi
m R
8i
m `b°
m m m
m m
m
`
M t7 N N O P gO m 0 0 m 0 (0 0 0 0 0 N r N 4 P [O r
RP N m m mi a e a v'i vP1 vmi .o m
+ r
O m m N V O N N�p N 01 m O O o N O m y O N m �V0) IYN�I yrs y b� � Pp N Omm1 N h 00p Y,
Q y<@ O m� 0 4 p tmh s p Q N N^ N N N N N YI N p P Q N m M iP P M
F v m
C
QC
O
m
W
N V Q N
b�
N
U1 m�
N
O m
O N
m N
N r
1D
P tm0
m P N
O 01
r
O
o
j
y
u1
In
N
N N N N
N
N N
N N
N h
m N
N Yl
IA rn
I`I 10
10
� u1
u1 V1 N
N N
Y�
� �
of
M
M of vi n
of
ri ri
of of
M m
M
ci M
M ri
of m
of
1n ci
M M M
M M
M
U
C
yd
�'
m
P m O N
r
pp
N m�
oo
0 N�
O
m m
S
h r
��pp
0 m 0
p �p
01 Q
N
N
N
001
m
lmV V
V
b
N
--
d
a ✓
W
W
�
L
a
K
S
m
a
m
a
2
2
1\
O
m
m N
�
�
01
N
P
N O M N
4
W b
in O
r 10
N N
A P�
m
0 0
t7
n
i0 m tD
N Oi
M
m m
m w
m m
m
m m
m Fi
m R
8i
m `b°
m m m
m m
m
`
m
CL
A
$
.
N
ur
b
b
m m
m 10
�O
m 1U
10. m
m m
l0
m
U
C
f.
a8
v
C
c
0
O
i
n
d
E
o
T 0
0
0
0
0
O O
0 0
0 0
0 0 0
W
p0 p0
pj0
p0
¢
¢
G
> W
d
yy�
qq pp�
N
O
N
mm
n
� m<
mm
N ON
m$
O
N m
�
P
O
N
W
0
O
U
�
3
M1
�pgm' mp
v
tt
tt
t2 E
w
n
m
m$
m
o
v v
o
0
d d N
g
N
N
N N
p
N
p
1
yam' p
� h N
w
N N
N N
ul upl
N
N
ti
NQ
$'
n
d
n n
n
q
.aj
N
N
N
N
N
VI Y1
N
N N
YI V1
N
YI
�
d
v
u
7.5
d
Wp
d
T
CL, d
R
il
yN�.
Q
N
gy�pp.
qq.
dUU
p>>
j
aq
ri N
N
uS
h
N
N N
N N
N
N h ry
n
N
J
0p
`L
W
N
ry
N N N
N N
F
Z N
a
0,
N
N
r
m (pOpH�
6i N
W
pap
p
Z=
r
r
mi
r
m N T
S D
O O
r
N
N
}
pp
V��pp
m
ri
Cj I.j Fj
m m
rl
m m
M
pm
Y
N rn
m
m
Vml_ VM1
N
ri{
N NN
N
Vm] BOO
10 m
N
z�
mmMM�6
m �;
m
m.
m
d
N"
m
N
N$
m
0
CNI r 0
0 P
m
m
C
m$$$
IO
o� m
m m
Omi Crl fp
o m
m
- .-
�o
a
C
a
a
cmi 2 �
�
U
Y
Y
V
N
tp
O Ip
O
V
impp
M
p
l0 N
N Y r
m$
T.
e�
n n
. .
N
r n
r n ..
h
i
n
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
w .aogcc.aloska.gov
Re: Kuparuk River Field, West Sak Oil Pool, KRU 1R -126L1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-095
Surface Location: 394' FNL, 137' FWL, SEC. 20, T12N, RIDE, UM
Bottomhole Location: 168' FNL, 4295' FWL, SEC. 20, T12N, R10E, UM
Dear Mr. Ohlinger:
Enclosed is the approved application for the permit to redrill the above referenced service well.
The permit is for a new wellbore segment of existing well Permit No. 219-094, API No. 50-029-
22193-01-00. Production should continue to be reported as a function of the original API number
stated above.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs
run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment
of this well.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Daniel T. Seamount, Jr.
Commissioner
/d
DATED this 3 day of July, 2019.
H, -DIVED
P.O. Box 100360 Anchorage, AK 99510-0360
iurface:
394' FNL, 137' FWL, Sec 20, T12N, RIDE, UM
STATE OF ALASKA
JUN 27
rota) Depth:
AL.
KA OIL AND GAS CONSERVATION COMM, ,ION
of Well (State Base Plane Coordinates - NAD 27):
20 19
539830 y- 5990810 Zone- 4
PERMIT TO DRILL
sx Class'G'
20 AAC 25.005
Type of Work: r
1b. Proposed Well Class:
Service - WAG ❑ Service - Disp
Exploratory - Gas ❑ ,
❑ Single Zone
❑
ic. Specify
Coalbed Gas ❑ Gas Hydrates ❑
❑ Lateral
Stratigraphic Test ❑
Development - Oil ❑ Service - Winj
❑
Geothermal ❑ Shale Gas ❑
hill ❑ Reentry ❑
Exploratory -Oil ❑
Development -Gas ❑
SingleZone
lanke❑t Q Multiple
Bond - Supply
Well ❑
11. Well Name and Number: i
)perator Name:
SS
Bond No. 5952180
KRU 1 R -1 26L1
ConocoPhillios Alaska, Inc.
„ M;.WPnMrcl.
P.O. Box 100360 Anchorage, AK 99510-0360
iurface:
394' FNL, 137' FWL, Sec 20, T12N, RIDE, UM
fop of Productive Horizon:
874' FNL, 2507' FWL, Sec 20, T12N, R10E, UM
rota) Depth:
168' FNL, 4295' FW L, Sec 20, T12N, RIDE, UM
4b. Location
of Well (State Base Plane Coordinates - NAD 27):
Surface: x-
539830 y- 5990810 Zone- 4
Maximum Hole Angle: 91 degrees
Hole Casing I Weight A Grade
79, PRESENT WELL CONDITION SUMMARY (To be
Total Depth MD (ft): Total De': I TVD (ft): Plugs (measured):
10218' 1 6976' 4320'
9916'-9941'
Fracture planned? Yes❑ No 0
MD: 7319' TVD: 3881' '
2560
10. KB Elevation above MSL (ft): 88'
GL / BF Elevation above MSL (ft): 45'
17. Maximum Potential Pressures in psig (see
1..Mle 1440 Surface:
Kuparuk River Field I
West Salk Oil Pool
13. Approximate Spud Date:
7/15/2019 '
14. Distance to Nearest Property:
12,700'
15. Distance to Nearest Well Ope
to Same Pool: 122', 1R-27
T TVD MD TVD
I
Unlined pilot hole with anchored aluminum
for Redrill and Re -Entry Operations)
10201'ent Volume1
D (ftP'G-5593'
iff,Depth
sx AS 1E,
530 sx Cl250
sx Class'G'
T11*11
or
9241'
3327'-3427', 6582'-6604', 6750'-6760',6770'-6787-
UL
20. Attachments: Property Plat ❑ BOP Sketch Drilling Program nng v. d Por m
Diverter Sketch Seabed Report Ddlling Fluid Program
Verbal Approval: Commission Representative:
I hereby certify that the foregoing is true and the
iated from without prior written approval.
iorized Name: James Ohling
Shallow Hazard
20 AAC 25.050 reqs
Date
Contact Name: Ryan McLaughlin
Contact Email: uahlin(a)COP COM
Contact Phone: 907-265-6218
Date: ���-%' e
zed Signature:
Commission Use Only
API Number: Permit Approval I See cover letter for other
to Drill requirements.
ir:—o95 5o-oZ9-22193"60-00 Date:
BIP
ions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes ❑ NOY Mud log req'd: Yes❑ NOR'
Bhp f"Gu�f t0 ,3 SUO�S-1 Zl�r5 t yo 25 n y Directional sv req'd: Yes No❑
/inry/arpr-,✓l'kl 'I bV S �zS bonermeasur's: Yes E] No[� y q r
J O l S(y Inclination -only svy req'd: Yes E] NOR'
tra-r%a n ce 70 ;?D f}!ii ZS- - Spacing exception req'd: Yes ❑ NoL"J ❑
ost ilial injecti n MIT a 'd: Yes No
07,-11 o 6L fi o l�n"vw !Q Q �isf gip"
!3 eJrar,tr�l f� ablvw ftie kl`cka�f y evor w
a✓! o7`nf a lona f71a parr✓ t lai`tral n, o i �n�
{/A/7dr7Yf yeas P,r?7� :{OR-ACZ S•0f3UCQ)�'S) �Y+ C�v,cl� yr m�,f/f sok w/.�Aow s5 f,ny •ur
WGr15N�tYtthr✓�l✓}nofi5ou f�i4P-17" o wlverr r�Zv�Sjf�l$ w�avr�Yrft�✓`O�"
the ) U fVYY. M 5 / APPROVED BY
Date
7/3//
COMMISSIONER THE COMMISSION
ved by: Submit Form and
This ermit s valid for 24 mon f ��t�e�fpFp � Per 20 AAC 25.005( nna�'"ents in Duplicate
re , /
Form 1�4cji
Revise m ��1� P q R I v L 7/1 r/fq —7jy1�y1!','r�•rll(/� 6
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
June 24, 2019
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 1 R-26
(PTD# 191-092) using the coiled tubing drilling rig, Nabors CDR3-AC.
CTD operations are scheduled to begin on July 15th, 2019. The objective will be to drill two laterals — 1 R -
126L1 will be a pilot hole drilled to the northeast across the West Sak sands to de -risk future rotary projects and
1 R-126 will target the West Sak B -sand.
To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20
AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of
being limited to 500' from the original point.
Attached to this application are the following documents:
- Permit to Drill Application Forms (10-401) for 1 R-126 & 1 R-1261-1
- Detailed Summary of Operations
- Directional Plans for 1 R-126 & 1 R-1261-1
- Current wellbore schematic
- Proposed CTD schematic
If you have any questions or require additional information, please contact me at 907-265-6218.
Sincerely,
Ryan McLaughlin
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Kuparuk CTD Lateral
1 R-126 & 1 R-1261-1
Application for Permit to Drill Document
March 5, 2019
Page 1 of 9
2
1.
Well Name and Classification........................................................................................................
(Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b))..................................................................................................................
2
2.
Location Summa
................
""""'
(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..................................................................
(Requirements of 20 AAC 25.005 (c)(a)).................. ... ...... .......... _..... .. _...... _. ....... _.....
2
5.
Procedure for Conducting Formation Integrity tests...................................................................
(Requirements of 20 AAC 25.005(c)(5))..............................................................................................................................................
3
6.
Casing and Cementing Program....................................................................................................
3
(Regwrements of 20 AAC 25.005(c)(s))..................................................................................................................................................
3
7.
Diverter System Information..........................................................................................................
3
(Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................
3
8.
Drilling Fluids Program..................................................................................................................
_... 3
(Requirements of 20 AAC 25.005(c)(8)) .................. _.............._.........................................................................................................
9.
Abnormally Pressured Formation Information.............................................................................4
a
(Requirements of 20 AAC 25.005(c)(9)1..................................................................................................................................................
4
10.
Seismic Analysis.............................................................................................................................
a
(Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................
11.
Seabed Condition Analysis............................................................................................................4
4
(Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................
4
12.
Evidence of Bonding
............
"""'
(Requirements of 20 AAC 25.005(c)(12))....................................................................................................
.
4
13.
Proposed Drilling Program.............................................................................................................
(Requirements of 20 AAC 25.005(c)(13))..........................................................................................................................
...........4
Summaryof Operations........................................................................................................................................
LinerRunning...................................................................................................................................................................5
5
Drilling Mud and Cuttings..........................................................................................
14.
Disposal of
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................
6
Plans for Intentionally Deviated Wells.......................................................................
15.
Directional
s
(Requirements of 20 AAC 25.050(b))......................................................................................................................................................
16.
Attachments....................................................................................................................................7
Attachment 1: Directional Plans for 1R-126, 1R-1261-1...................................................................................................9
Attachment 2: Current Well Schematic for 1 R-126, 1 R-126L1...................................................................
....................9
Attachment 3: Proposed Well Schematic for 1 R-126, 1 R-1 26L1 .....................................................................................9
March 5, 2019
Page 1 of 9
PTD Application: 1R-126, 1R-1261-1
Well Name and Classification
(Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))
The proposed laterals described in this document are 1 R-126 & 1 R-1 26L1. The laterals will be classified as
"Service - Winj" wells.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
These laterals will target the B sand package in the West Sak reservoir. See attached 10-401 form for surface
and subsurface coordinates of IR -126 & 1R-1261-1.
3. Blowout Prevention Equipment Information
(Requirements of 20 AAC 25.005 (c)(3))
Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC.
BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations.
— Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. The
nearest MDT in the West Sak formation was recorded to be 0.45 psi/ft in 2006. lWe maximum
potential surface pressure in 1 R-126, assuming a gas gradient of 0.1 psi/ft, would be 1098 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. 10
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 nearest formation pressure gradient measurement in the West Sak was 0.45 psi/ft with an MDT in 2006.
Based on this pressure gradient, the downhole pressure at the window is estimated to be 1440 psi. Reservoir
pressure is not anticipated to have changed since no production or injection has occurred in the West Sak
formation in the vicinity of this project
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
Free gas is not anticipated while drilling the 1 R-126 & 1 R -126L1 laterals. If gas is detected in the returns the
contaminated mud can be diverted to a storage tank away from the rig.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c))
The major expected risk of hole problems in the 1 R-126 and 1 R-1261-1 laterals will be lost circulation and
differential sticking. Reduced mud rheology will be used to minimize ECDs and attempt to prevent lost
circulation and differential sticking.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 1 R-126 & 1 R-1261-1 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a
formation integrity test is not required.
June 24, 2019
Page 2 of 9
PTD Application: 1R-126, 1R-1261_1
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
rew comprenan
UVLOIIa
Top
Liner Top
Liner Btm
Liner Top
Liner Btm
Liner Details
Lateral Name
MD
MD
TVDSS
TVDSS
sl
psi
Conductor
16"
t
62.5
H-40
2-7/8", 6.5#, L-80, ST -L slotted liner,
Surface
123'
Surface
t4072'3520
3-1/2", 9.2#, L-80, ST -L solid liner in
1 R-126
4450'
12,000'
3320'
5610'
the build; Shorty deployment sleeve
5593'
10,201'
Surface
Surface
432Tubin
on to
7"
4-1/2"
26.0
12.6
J-55
L-80
-MOD
HYD 503
Surface
Pilot hole — will be unlined with an
1R -126L1
N/A
N/A
N/A
N/A
anchored billet set at 4850' MD
Existing Gasmgruner nuvnuauvr.
Top
Collapse
Category
OD
Weight
Grade
Connection
Top MD
Btm MD
TVD
sl
psi
Conductor
16"
t
62.5
H-40
Welded
Surface
123'
Surface
t4072'3520
670
202Production
Surface
9-5/8"
36.0
J-55
BTC
BTC
Surface
Surface
5593'
10,201'
Surface
Surface
432Tubin
7"
4-1/2"
26.0
12.6
J-55
L-80
-MOD
HYD 503
Surface
4252"
Surface
7500
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a
diverter system is not required.
8. Drilling Fluids Program
(Requirements of 20 AAC 25.005(c)(8))
Diagram of Drilling System
A diagram of the Nabors CDR3-AC mud system is on file with the Commission.
Description of Drilling Fluid System
— Window milling operations: Chloride -based PowerVis mud (8.4 ppg)
— Drilling operations: Chloride -based PowerVis mud (8.4 ppg). This mud weight may not hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with NaCl completion fluid in order to provide
formation over -balance while running completions. If pressures higher than anticipated are
encountered NaBr completion fluids may also be used.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases,
the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke.
BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment
Information'.
In the 1 R-126 & 1 R -1 26L1 laterals we will target a constant BHP to match formation pressure. The constant BHP
target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions
if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be
employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates
or change in depth of circulation will be offset with back pressure adjustments.
June 24, 2019
Page 3 of 9
PTD Application: 1R-126, 1R -126L1
..cng RAM aA4A' T/fll ilcinn MPD
.�, ..�•� --
3 b m
Pressure at me 7K -ILO YIPT
------ -
Pum s OffB-sand
Formation Pressure 8.65
si
1536 siMud
1491
H drostatic 84
si
siAnnular
0
friction i.eECD, 0.035 si/ftsi
siMud
1491 psino
+ ECD Combined
psi
d -111 si
Underbalanced -45 siTar
choke ressure
et BHP at Window 8.65
si
1536 siChoke
Pressure Required toMaintainsi
45 psi
Target BHP
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 1 R-26 was recently worked over and is now equipped with 4-1/2" tubing and 7"
production casing. The CTD sidetrack will utilize one lateral to target the West Sak B -sand to the
south of 1 R-26 and an unlined pilot lateral to the northeast that will de -risk future rotary projects in
the area.
An inner wedge will be set pre -CTD inside the tandem wedge installed during the workover in the
4-1/2" tubing at a planned kickoff point of 4460' MD
CDR3-AC will use the whipstock to mill a window in the 4-1/2", 7", and 9-5/8" casing strings. The
1 R-1 26L1 lateral will be drilled first to the northeast to a TD of 7319' MD. An anchored billet will
be set at a depth of 4850' MD to kick off from and drill the 1 R-126 lateral to a depth of 12,000'
MD. The 1R-126 lateral will be completed with 2-7/8" slotted liner from TD up the end of the build
and 3-1/2" solid liner from the end of the build to inside the parent wellbore.
Pre -CTD Work
1. RU E -Line: Drift, set inner wedge at 4460' MD
2. Prep site for Nabors CDR3-AC rig.
June 24, 2019
Page 4 of 9
PTD ADDlication: 1R-126, 1R-1261-1
Ria Work
1. MIRU Nabors CDR3-AC rig using 2-518" coil tubing. NU 7-1/16" BOPE, test.
2. 1 R -1 26L1 Lateral (West Sak pilot hole - northeast)
a. Mill 3.80" window at 4460' MD
b. Drill 4-1/4" bi-center lateral to TD of 7319' MD.
c. Set anchored aluminum billet at 4850' MD
3. 1R-126 Lateral (West Sak B -sand -south)
a. Kickoff of the aluminum billet at 4850' MD.
b. Drill 4-1/4" bi-center lateral to TD of 12,000' MD.
c. Run 2-7/8" slotted liner and 3-112" solid liner with deployment sleeve from TD up to 4450' MD.
4. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Rig Work
5. Return well to production.
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the
Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the
Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator.
This pressure control equipment listed ensures reservoir pressure is contained during the deployment process.
During BHA deployment, the following steps are observed.
- Initially the swab valve on the tree is closed to isolate reservoir pressure. The lubricator is installed on the
BOP riser with the BHA inside the lubricator.
- Pressure is applied to the lubricator to equalize across the swab valve. The swab valve is opened and the
BHA is lowered in place via slick -line.
- When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir
pressure via the annulus. A closed ball valve and check valve isolate reservoir pressure internal to the
BHA. Slips on the deployment ram prevent the BHA from moving when differential pressure is applied.
The lubricator is removed once pressure is bled off above the deployment ram.
- The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to
the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is
made up to the riser, annular pressure is equalized, and the deployment ram is opened. The BHA and
coiled tubing are now ready to run in the hole.
During BHA undeployment, the steps listed above are observed, only in reverse.
Liner Running
- The 1 R-126 & 1 R-1261-1 laterals will be displaced to an overbalancing fluid prior to running liner. See
"Drilling Fluids" section for more details.
- While running liner, a joint of 2-5/8" non -slotted tubing will be standing by for emergency deployment. A
floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with
this emergency joint on every slotted liner run. The 2-518" rams will provide secondary well control
while running 2-318" liner.
14. Disposal of Drilling Mud and Cuttings
(Requirements of 20 AAC 25.005(c)(14))
No annular injection on this well.
All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal.
June 24, 2019
Page 5 of 9
PTD Application: 1 R-126, 1 R -1 26L1
Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18
or 1 B disposal facilities) or Prudhoe DS4 if a Kuparuk facility is unavailable.
All wastes and waste fluids hauled from the pad must be properly documented and manifested.
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200).
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
- The Applicant is the only affected owner.
- Please see Attachment 1: Directional Plans
- Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
- MWD directional 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
1R-126
14,887'
IR -126L1
12, 700'
- Distance to Nearest Well within Pool
LGatera�l Name Distance Well
1R-1126 110 I IR -29
11111-11261-11 122' 1 R-27
June 24, 2019
Page 6 of 9
PTD Application: 1R-126, 1R -126L1
16. Quarter Mile Injection Review (for injection wells only)
(Requirements of 20 AAC 25.402)
-- --
—
Surface
Surface
Top of D-
Top of D-
Surface
Surface
Casing Set
Casing Set
Well '',
Well
Well
sand Oil
Sand Oil
Casing Set
Casing Set
Pro
API
Across
Across West
Name
Classification
Status
Pool (TVD)_
Depth (MD{_
Depth (TVD)
Pool (MD{_
-
,T
1G -07A
218-051
50-029-20872-01
Producer
producing
3,950
3,395
2,487
2,367
FA.L^oE
FALSE
1R -01B 200-156
50-029-2140402
Producer
LTSI
3,684
3,383
4,381
3,868
TRUE
TRUE
1R-02 185-176
50-029.21405-00
Producer
producing
4.114
3,390
4,814
3,885
TRUE
TRUE
1R-25 191.047
50-029.22153-00
Producer
producing
4,512
3,450
5,571
4,122
TRUE
TRUE
1R-26 191-092
j
50-029.22193-00
Injector
Suspended
4,426
3,399
5,593
4,081
TRUE
TRUE
1R-27 191-102
50-029.22201-00
Producer
LTSI
5,240
3,528
6,547
4,192
TRUE
TRUE
1R-29 191-094
50.029-22195.00
Producer
producing
4,857
3,414
6,042
4,119
TRUE
TRUE
Page 7 of 9
June 24, 2019
PTD Application: 1R-126, 1R -126L1
Page 8 of 9 June 24, 2019
Within
Within
Wer
Surface Casing Cement
Arctic Pack
1/4
1/4 Mile
Mechanical Integrity
Name
Operations Summary
Cement Ops
Mile of
of
W1
r
E
1R-1:
1R -126L1
18-3/4':1300 sx (445 bbl) of AS -III
OA: 41 bbl cmt . ???
NORMAL WELL
12.2 ppg lead .250 sx (41 bbl) of 15.7
Bbl diesel, 116183. 41
MIT -IA to 2500 psi passed 10113116
1G -07A
ppg PF -C tail. Cement to surface,
bbl = 844' in csg
MIT -OA to 1800 psi passed 3111118
TRUE
no reciprocation. FIT = 12.4 ppg
annuli.
EMW 406 psi w19.1 ppg mud).
9-518-:1250 sx (439 bbl) of PF -E
OA: 33 bbl cmt, 55
NORMAL WELL
12.3 ppg lead . 400 sx (68 bbl) of 15.6
bbl diesel, 915185. 33
TIFL passed 719113
1R-018
ppg PF -C tail. Full returns entire
bbl = 1110' in csg
CMIT-IA to 1950 psi passed 5117108
TRUE
TRUE
job, circ 279 sx (98 bbl) cement to
annuli, 55 bbl = 1851'.
MIT -OA to 1800 psi passed 10121118
surface. No reciprocation. FIT =
9-518":1470 sx (515 bbl) of PF -E
OA: 42 bbl cmt, 55.5
NORMAL WELL
12.3 ppg lead . 410 sx (69 bbl) of 15.6
bbl diesel, 9116185. 33
MIT -OA to 1600 psi passed 11119109
1R-02
ppg PF -C tail. Good returns entire
bbl = 1414' in csg
TIFL passed 1112115
TRUE
TRUE
job, circ 145 bbl cement to surface.
annuli, 55.5 bbl =
FIT =12.5 ppg EMW.
1868'.
9-518-:1050 sx (369 bbl) of PF -E
OA: 50 bbl cmt, 60
NORMAL WELL
12.3 ppg lead . 630 sx (132 bbl) of
bbl diesel, 121201915.
TIFL passed 3131116
1R-25
15.6 ppg G tail. Full returns, recip
50 bbl = 1683' in csg
MIT -T to 2500 psi passed 913107
TRUE
TRUE
casing, cement to surface. FIT =
annuli, 60 bbl = 2019'
MIT -IA to 2500 psi passed 8126107
11.5 ppg EMW.
MIT -OA to 1800 psi passed 715109
9-518-:1170 sx (410 bbl) of PF -E
OA: 42 bbl cmt, 58
NORMAL WELL
12.3 ppg lead . 530 sx (108 bbl) of G
bbl diesel, 9123191. 42
MIT -IA to 3000 psi on 3.27.14
1119-26
15.8 ppg tail. Full returns entire job,
bbl = 1414' in csg
MIT -OA to 1800 psi passed 10122118
TRUE
TRUE
circ 23 sx (8 bbl) cement to surface.
annuli, 58 bbl = 1952'.
FIT =12.5 ppg EMW.
9-518-:1390 sx (488 bbl) of PF -E
OA: 42 bbl cmt, 63
NORMAL WELL
12.1 ppg lead . 570 sx (117 bbl) of 15.8
bbl diesel, 1014191. 42
TIFL passed 12129110
1R-27
ppg G tail. Full returns but no
bbl = 1414' in csg
MIT -T to 2500 psi passed 5129116
TRUE
TRUE
cement to surface. Top job with 173
annuli, 63 bbl = 2120'.
MIT -IA to 2500 psi on 11117112
sx 29 bbl of 15.6 ppg PF -C. FIT =
MIT -OA to 1800 psi passed 10110112
9-518':1320 sx (463 bbl) of PF -E
OA: 33.8 bbl cmt, 65
NORMAL WELL
12.1 ppg lead . 560 sx (115 bbl) of 15.8
bbl diesel, 12116191.
TIFL passed 4114118
1R-29
ppg G tail. Full returns whil recip
33.8 bbl = 1138' in csg
MIT -T to 2500 psi passed 5129116
TRUE
TRUE
casing, -100 bbl cement to surface.
annuli, 65 bbl = 2188'.
MIT -IA to 2500 psi on 11117112
FIT = 12.5 ppg EMW.
MIT -OA to 1800 psi passed 10110112
Page 8 of 9 June 24, 2019
PTD Application: 1R-126, 1R -126L1
17. Attachments
Attachment 1: Directional Plans for the 1R-126 & 1R -126L1 laterals
Attachment 2: Current Well Schematic for 1R-26
Attachment 3: Proposed CTD Well Schematic for the 1R-126 & 1R -126L1 laterals
Page 9 of 9
June 24, 2019
Well KRu xx-xx
Quick Test Sub to Otm
Top of 7" Otis
Distances from top o
Excluding quick -test
Top of Annular
C, Annular
Bottom Annular Flanc
Ci Blind/Shears
Ci 2-5/8" Combi s
CL 3.1/8" Combi's
Ci VBR's
CL of Top Sw.
Top of Swab
CL Swab 1
Flow Tee
CL SSV
CL Master
LOS
Ground Lew
Nabors CDR3-AC: 4 -Ram BOP Configuration Date June 26, 2019
2-518" Coiled Tubing and 3-1/8" BHA
Tree Size 4 1/16
Q
��
u
O
C
O
V
Y
K p
a. s'
x.......
c 3
0 3
¢_
z
8
m
m
�- ConocoPhillips BA. �(ER
ConocoPhillips Anticollision Report �j IGHES
BAT
GEcomvanY
Company:
ConocoPhillips Alaska Inc-Kuparuk
Project:
Kuparuk River Unit -2
Reference Site:
Kuparuk 1R Pad
Site Error:
0.00 usft
Reference Well:
1 R-26
Well Error:
0.00 usft
Reference Wellbore
1R-12BLI
Reference Design:
1 R-126L1_wp02 (Draft C)
Reference 1R-1261-1_wp02(Draft C)
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Fiftertype:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method:
MD Interval 100.00usft Error Model:
Depth Range:
Unlimited Scan Method:
Results Limited by:
Maximum center -center distance of 927.58 usft Error Surface:
Levels Evaluated at: 2.79
SI urvey Tool Program
From To
(usft) (usft)
Date 5/29/2019
Survey (Wellbore)
50.00 4,450, 00 1 R-26 - GYD-CT-CMS (1 R-26)
4,450.00 7,319.00 1R-126L1_wp02(Draft C)(IR-1261-1)
Method:
Tool Name
GYD-CT-CMS
MWD
Well 1 R-26
1 R-26 @ 88.00usft (1 R-26)
1 R-26 @ 88.00usft (1 R-26)
True
Minimum Curvature
2.00 sigma
EDT 14 Alaska Production
Offset Datum
ISCWSA
Tray. Cylinder North
Combined Pedal Curve
Added to Error Values
Description
Gyrodata Wnl.casing m/s
MWD - Standard
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well -Wellbore -Design
(usft)
(usft)
(usftl
(usft)
Kuparuk 1 R Pad
1 R-01 - 1 R-01 - 1R-01
43.20
36.80
239.81
239.02
302.765 CC
1 R-01 - 1 R-01 - 1R-01
602.56
600.00
242.01
234.77
33.437 ES
1R -01 -1R -01-1R-01
1,158.71
1,200.00
292.27
277.56
19.877 SF
1 R-01 - IR -01A - 1 R -01A
43.20
36.80
239.81
239.02
302.765 CC
1 R-01 - IR -01A- 1 R -01A
602.56
600.00
242.01
234.77
33.437 ES
1R -01 -1R -01A -1R -01A
1,158.71
1,200.00
292.27
277.56
19.877 SF
1R-01 - IR -0115- 1R -01B
43.20
36.80
239.81
239.02
302.765 CC
1R.01 - IR -01B - 1R -01B
602.56
600.00
242.01
234.77
33.437 ES
1R-01 - IR -0113 - 1R -01B
1,158.71
1,200.00
292.27
277.56
19.877 SF
1 R-01 - 1 R-01 BLt - 1 R-01 311
43.20
36.80
239.81
239.02
302.765 CC
1R -01-1R-01 BL7-1R-01 BL1
602.56
600.00
242.01
234.77
33.437 ES
1R -01-1R-01 BL1-1R-01 BL1
1,158.71
1,200.00
292.27
277.56
19.877 SF
1R -01-1R-01 BL1-01.1R-01 311-01
43.20
36.80
239.81
239.02
302.765 CC
1R -01-1R-01 BL1-01-1R-01 311-01
602.56
600.00
242.01
234.77
33.437 ES
1R -01-1R-01 BL1-01-1R-01 311-01
1,158.71
1,200.00
292.27
277.56
19.877 SF
1R -01-1R-01 311-01 PB1-1R-01 31-1-01 PB1
43.20
36.80
239.81
239.02
302.765 CC
1R -01-1R-01 BL1-01 PB1-1R-01 BLI-01 P81
602.56
600.00
242.01
234.77
33.437 ES
1R -01-1R-01 311-01 PBI -1R-01 BL1-01 PB1
1,158.71
1,200.00
292.27
277.56
19.877 SF
1R -01-1R-01 BL1 PB1-1R-01 BL7 PBI
43.20
36.80
239.81
239.02
302.765 CC
1R -01-1R-01 311 PB1-1R-01 BL1 Pet
602.56
600.00
242.01
234.77
33.437 ES
1R -01-1R-01 BL1 PBI -1R-01 31-1 PB1
1,158.71
1,200.00
292.27
277.56
19.877 SF
1 R-01 - 1 R-101 - 1 R-101_wp02
43.20
36.80
239.81
239.02
302.765 CC
1 R-01 - 1 R-101 - 1 R-101_wp02
602.56
600.00
242.01
235.07
34.894 ES
1 R-01 - 1R-101 - 1R-101_wp02
3,900.10
4,900.00
812.66
749.23
12.814 SF
1 R-02 - 1 R-02 - 1 R-02
1,980.70
2,000.00
143.87
130.57
10.818 CC, ES
1 R-02 - 1 R-02 - 1 R-02
3,330.40
3,400.00
267.25
241.92
10.552 SF
1 R-03 - 1 R-03. 1 R-03
87.37
82.00
120.15
119.75
299.958 CC
1 R-03 - 1 R-03 - 1 R-03
604.15
600.00
121.90
115.25
18.315 ES
1 R-03 - 1 R-03 - 1 R-03
985.68
1,000.00
145.37
133.78
12.548 SF
1 R-03 - 1 R -03A- 1 R -03A
87.37
82.00
120.15
119.75
299.958 CC
1 R-03 - 1 R -03A - 1 R -03A
604.15
600.00
121.90
115.25
18.315 ES
1R -03 -1R -03A -1R -03A
985.68
1,000.00
145.37
133.78
12.548 SF
1R-03-1R-03APB1-1R-03APB1
87.37
82.00
120.15
119.75
299.958 CC
1R-03-1R-03APB1-1R-03APB1
604.15
600.00
121.90
115.25
18.315 ES
1 R-03 - 1 R-03APB 1 - 1 R-03APB 1
985.68
1,000.00
145.37
133.78
12.548 SF
1 R-04 - 1 R-04 - 1 R-04
87.68
82.00
60.16
59.76
149.772 CC
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
512912019 2:53: 11PM Page 2 COMPASS 5000.14 Build 85D
ConocoPhillipsER a
ConocoPhillips Anticollision Report UGHES
a GEcampalry
Company:
ConocoPhillips Alaska lnc_Kupamk
Local Co-ordinate Reference:
Well 1R-26
Project:
Kuparuk River Unit_2
TVD Reference:
1 R-26 Q 88.00usft (1R-26)
Reference Site:
Kuparuk 1 R Pad
MD Reference:
1 R-26 Q 88,00usft (1R-26)
Site Error:
0.00 usft
North Reference:
True
Reference Well:
1R-26
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00 usft
Output errors are at
2.00 sigma
Reference Wellbore
1R -126L1
Database:
EDT 14 Alaska Production
Reference Design:
1R -126L7 wp02 (Draft C)
Offset TVD Reference:
Offset Datum
Summary
Kuparuk I Pad- 1R -01 -1R -01-1R-01
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation
Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
Measured vesical
Kuparuk 1R Pad
ver4cal
Reference
Offset
Azimuth
Offset Wellbore came
Betwean
1 R-04 - 1 R-04 - 1 R-04
605.00
600.00
62.62
55.95
9.391
ES
1 R-04 - 1 R-04 - 1 R-04
802.83
800.00
69,67
60.50
7.595
SF
1 R-04 - 1 R-1 04A CTD Sidetrack - 1 R-1 04A wp03
87.68
82.00
60.16
59.79
160.155
CC
1 R-04 - 1 R-1 04A CTD Sidetrack - 1 R-1 04A wp03
605.00
600.00
62.62
55.97
9.428
ES
1 R-04 - 1 R-1 04A CTD Sidetrack - 1 R -1 04A wp03
802.83
800.00
69.67
60.52
7.616
SF
1 R-24 - 1 R-24 - 1 R-24
86.43
88.00
300.14
299.74
755.742
CC
1 R-24 - 1 R-24 - 1 R-24
300.31
300.00
301.18
298.94
134.868
ES
1R -24 -1R -24-1R-24
3,059.49
3,100.00
816.60
767.46
16.617
SF
1R -26 -1R -126-1R-126 wp02(Draft A)
4,598.15
4,600.00
20.60
-20.68
0.499
STOP Drilling, ES
1R -26 -1R -126-1R-126 wp02(Draft A)
4,914.88
4,900.00
4.75
-10.59
0.310
STOP Drilling, CC, SF
1R -26 -1R -26-1R-26
4,780.00
5,000.00
324.71
320.94
85.971
CC, ES
1R -26 -1R -26-1R-26
6,594.56
6,300.00
919.41
894.38
36.740
SF
1 R-27 - 1 R-27 - 1 R-27
87.84
88.00
30.15
29.75
74.949
CC
1 R-27 - 1 R-27 - 1 R-27
300.00
300.00
30.56
27.62
10.412
ES
1R -27 -1R -27-1R-27
6,394.77
5,500.00
122.40
42.13
1.525
Caution Monitor Closely, SF
1 R-29 - 1 R-29 - 1 R-29
200.15
200.00
60.00
58.75
48.226
CC
1 R-29 - 1 R-29 - 1 R-29
299.92
300.00
60.29
58.58
35.103
ES
1R -29 -1R -29-1R-29
5,260.00
4,900.00
632.62
557.48
8.418
SF
1 R-29 - 1 R -29L7 - 1 R-291-1
200.15
200.00
60.00
58.75
48.226
CC
1 R-29 - 1 R-291.1 - 1 R-291-1
299.92
300.00
60.29
58.58
35.103
ES
1R -29 -1R -291-7-1R-291-1
5,260.00
4,900.00
632.62
557.48
8.418
SF
1 R-29 - t R-2911-01 - 1 R-2911-01
200.15
200.00
60.00
58.75
48.226
CC
1R -29 -1R -29L1 -01-1R-291-1-01
299.92
300.00
60.29
58.58
35.103
ES
1R -29 -1R -29L7 -01 -1R -29L1-01
5,260.00
4,900.00
632.62
557.48
8.418
SF
1 R-29 - 1 R -29L1-02 - 1 R-2911-02
200.15
200.00
60.00
58.75
48.226
CC
1 R-29 - 1 R -29L1-02 - 1 R-2911-02
299.92
300.00
80.29
58.58
35.103
ES
1R-29. 1R -29L1 -02-1R-291-1-02
5,260.00
4,900.00
632.62
557.48
8.419
SF
1 R-29 - 1 R -29L1-03 - 1 R-2911-03
200.15
200.00
60.00
58.75
48.226
CC
1R-29. 1R -29L1 -03-1R-291-1-03
299.92
300.00
60.29
58.58
35.103
ES
1R -29 -1R -29L7 -03 -1R -29L1-03
5,260.00
4,900.00
632.62
557.48
8.419
SF
1R-29-1R-291-1-03PB7-1R-29L1-03PB1
200.15
200.00
60.00
58.75
48.226
CC
1R-29-1R-291-1-03PB1-1R-29L1-03PB7
299.92
300.00
60.29
58.58
35.103
ES
1R-29-1R-291-1-03PB1-1R-29L7-03PB1
5,260.00
4,900.00
632.62
557.48
8.419
SF
Kuparuk UGNU
Plan East Ugnu # 1 - Ugnu #1 - Plan #2
Out of range
Offset Design
Kuparuk I Pad- 1R -01 -1R -01-1R-01
onsetsite Error: 0.00 daft
Survey program'. 100
-GCT -MS
offset WNI Error. apo usft
Reference
Mae,
Semi Malo,Aes
Distance
Measured vesical
Measured
ver4cal
Reference
Offset
Azimuth
Offset Wellbore came
Betwean
Between
Minimum
separation
warning
Depth Depth
Depth
Depth
Iron earth
eN14
♦EIM
centres
Ellipses
SepamSon
Fee.,
(usry lush)
luso)
(usft)
(lass)
lean)
(°)
teary
tern)
(deft)
(eery
Ideal
43.20 4320
36.80
36.80
0.00
0.00
0.29
239.0,]
1.21
239.81
239.02
0.79
302365 CC
10470 104.70
100,00
100.00
0.15
0.20
0.16
23978
1.15
240.09
238.85
1,24
193694
205.45 205.45
200.00
200.00
0.36
1.17
0.14
239.93
0.97
240.39
230.16
2.23
107.687
306.21 30631
300.00
300.00
0.57
2.04
OAS
239.86
0.09
240.53
237.05
3.48
69.076
405.54 405.54
400.00
400.00
0.73
2.92
0.04
239.87
0.77
240.73
236.00
4.73
60.931
504.43 504.41
500.00
500.00
0.93
3.00
-0.37
239.86
0.67
240.99
235.01
5.98
40.313
602.56 602.47
600.00
600.00
1.16
4.67
-1.23
239.83
0,63
242.01
234,77
7.24
33.437 ES
700,77 700.42
700,00
700.00
1.40
5.55
-2.96
239.81
0.56
243.90
23$.39
8.51
20.664
799.58 790.70
000.00
800.00
1.65
6.43
-5.26
239.73
0.53
246.19
236.39
9.79
25.140
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
5292019 2:53:11 PM Page 3 COMPASS 5000.14 Build 85D
�4
(ui/ysn S9) 9ldaQ 1¢3cu3p aniy
u
From:
McLaughlin, Ryan
To:
Boyer, David L (CED)
Subject:
RE: [EXTERNAL]Digital Survey Files
Date:
Monday, July 1, 2019 9:51:31 AM
Hello Dave,
Yes, the two 113 water injectors will be pre -produced for approximately 3 weeks.
Regards,
Ryan McLaughlin
Coiled Tubing Drilling Engineer
ConocoPhlllips Alaska
Office: 907-265-6218 Cell: 907-444-7886
700 G St, ATO 670, Anchorage, AK 99501
From: Boyer, David L (CED) <david.boyer2@alaska.gov>
Sent: Monday, July 1, 2019 9:30 AM
To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com>
Subject: RE: [EXTERNAL] Digital Survey Files
Hi Ryan,
Will the two 1R water injectors be preproduced? If so, for less than 3 months?
Thank you,
Dave Boyer
From: McLaughlin, Ryan <Rv Mc aL.Ighlin(@corloco[hillios com>
Sent: Friday, June 28, 2019 8:35 AM
To: Boyer, David L (CED) <david boyer2@alaska eov>
Subject: RE: [EXTERNAL] Digital Survey Files
Dave,
Digital survey files for the 111-126 and 1R -126L1 laterals are attached.
Regards,
Ryan McLaughlin
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Office: 907-265-6218 Cell: 907-444-7886
700 G St, ATO 670, Anchorage, AK 99501
From: Boyer, David L (CED) <david bover2Qalaska eov>
Sent: Friday, June 28, 2019 8:21 AM
To: McLaughlin, Ryan <Rvan Mci-aughliogQonoco I�lilli sp com>
Subject: [EXTERNAL] Digital Survey Files
Hi Ryan,
Would it be possible to send over the digital survey files for KRU 1R-126 & 1R -126L1 PTD
applications in Excel or ASCII format. We plot the wellpaths in the Geographix program before
issuing the permits.
Thank you,
Dave Boyer
Senior Geologist
AOGCC
TRANSMITTAL LETTER CHECKLIST
WELL NAME: K R Lk� 1R -- ( a S /L 1
PTD:
�4 1 — 000
Development v Service Exploratory _ Stratigraphic Test —Non -Conventional
FIELD: Vx L4 a t- A -R 1 0� POOL: \n%p,5±
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing well Permit
LATERAL
No. 'a 19 — 094- , API No. 50- OZ ZZ 19 3 - 4; 1- OD
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above. Cwt s-FSak'
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50-_-
from records, data and logs acquired for well
name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL-490150
PTD#: 2190950 Company ConocoPhillips Alaska. Inc. Initial Class/Type
Well Name: EQPARUL_W V_d1L1R-Z611 Program SER Well lore seg 0
SER/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑
Administration
1
Permit fee attached _ .
NA
'2
Lease number appropriate. _ . .... . ... . ......... . . . .
Yes
_
3
Ilnique well name and number _ _ _ _ _ _ ....
Yes
_
4
Well located in a. defined. pool _ _ _ _ _ _ _
Yes
_ . . . ........ . .... . . . . . .. . . ... . . . _ _ _
5
Well located proper distance from. drilling unit boundary_ _ _ _ _ _
Yes
_ .. _
6
Well located proper distance from other wells.. _ _ _ _ _ _
Yes
7
Sufficient acreage available in drilling unit _ _ ................. .
Yes
8
If deviated, is wellbore plat. included _ _ _ _ _ .....
Yes
Wellboreplan view & wellbore profile view included.
9
Operator only affected party _ . ............ . . . . . . _ _ . _ _
Yes
-----------
10
Operator has appropriate bond in force _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes
11
Permitcan be issued without conservation order. . . . . . ...... . . . . ..... . .
Yes
Appr Date
12
Permit can be issued without administrative approval _ _ _ _ _ _ _ _ _ _ _ _ _ ____ _ ___
Yes
13
Can permit be approved before 15-day wait _ _ _ _ _ .. _
Yes
.. _ _ .. _ _ .. . .. . . . . . . . .
DLB 7/1/2019
14
Well located within area and strata authorized by Injection Order # (put 10# In comments) (For
Yes
_ _ Area Injection Order No. 2B
15
All wells within 1/4.mile areaof review identified (For service well only) _ __ _ _ _ _ _ _ _ _ _ _
Yes
16
Pre-produced injector; duration of pra-productipn less. than 3 months (For service well only) ..
Yes
17
Nonconven, gas conforms to A831 A5.030Q.1_.A),Q.2.A-D) . . ...............
NA.
18
Conductor string.provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ..............
NA........
Conductor set.for.KRU.1R-26... .
Engineering
19
Surface casing protects all known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _
NA.......
Surface casing set for KRU 1R726.
20
CMT vol adequate to circulate on conductor_& surf_csg _ _ _ _ _ _ _ _ _ _ _
NA. _
... _ Surface casing set and fully.cemented
21
CMT. vol adequate to tie-in long string to surf erg ... __..._._._.
NA__..._
22
CMT will cover all known productive horizons _ _ .... _ _ _ _ _
No..
_ Productive_ interval not lined.
23
Casing designs adequate for C, T, B & permafrost _ _ .... ....... _
Yes
24
Adequate tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ ....
Yes
_ _ Rig has steel tanks; all waste to approved disposal wells
25
if a. re-drill, has. a. 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _
NA
26
Adequate wellbore separation proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes _
_ _ _ Anti-collision analysis complete; no major risk failures
27
If diverter required, does it meet regulations _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA
Appr Date
28
Drilling fluid. program schematic & equip list adequate.. . . . . . . . .... _
Yes
_ Max formation pressure is 1440 psig(8.16 ppg EMW); will drill. w/ 8,4. ppg EMW and. maintain overbai w/ MPD _
VTL 7/2/2019
29
BOPEs, do they meet regulation _ _ ........ ... - .
Yes
30
DOPE press rating appropriate; test to (put psig in comments). . .. . ..... . . ........
Yes
... MPSP is 1098 psig; will test BOPS, to 3500.psig .... ....
31
Choke.manifold complies w/API. RP-53 (May 84)
Yes ..
.... . . ............................... ..
32
Work will occur without operation shutdown. _ _ _ _ _ _ _ _ _ _Yes
...
33
Is presence of 112S gas probable _ _ _ _ _ _ _ _ _
No
34
Mechanical condition of wells within AOR yedfied (For service well only) _ _ _ _ _ _ _ _ .
Yes _
_ _ _ _ _ _ 6 wells identified and verified.
35
Permit can be issued w/o hydrogen sulfide measures ......... . .... . .. . . . ..
Yes
_ _ _ _ _ _ 1R-126_is only the 3rd West Sak well drillyd on 1 R Pad.
Geology
36
....
Data_presented on potential overpressure zones .................... ...
Yes ......
(First 2 West Sak. wells not drilled yet.)
Appr Date
37
Seismic analysis of shallow gas zones
NA..
_ . _ _ _ . _ . _ .
38
Seabed condition survey _(if off-shore) . . . . . .............................
NA.....
39
Contactname/phone for weekly-progress reports [exploratory only]
NA _
Geologic Engineering Public
Commissioner: Date: Commissioner: Date Commissioner Date
�rC�a�ly
