Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout218-134MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Tuesday, October 15, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Adam Earl
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
MT6-09
GMTU MT6-09
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 10/15/2024
MT6-09
50-103-20779-00-00
218-134-0
G
SPT
7875
2181340 1969
2436 2441 2437 2437
80 180 180 180
4YRTST P
Adam Earl
8/11/2024
MIT-IA. OOA - 200/220/220/220
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:GMTU MT6-09
Inspection Date:
Tubing
OA
Packer Depth
895 3310 3260 3245IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitAGE240812140515
BBL Pumped:2.9 BBL Returned:2.9
Tuesday, October 15, 2024 Page 1 of 1
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999
99
9 9
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James B. Regg Digitally signed by James B. Regg
Date: 2024.10.15 15:18:48 -08'00'
TT RR AA NN SS MM II TT TT AA LL
FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 330 W. 7
th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99501
RE: Schlumberger Wireline Backlog – Mooses Tooth
DATE: 12/19/2023
Transmitted:
North Slope, Mooses Tooth Unit
Via hard drive data drop
Moose's Tooth
MT6-08 50-103-20772-00
218048_MT6-08_JetCutter_22Apr2022
218048_MT6-08_Puncher_02Feb2022
MT6-09 50-103-20779-00
218134_MT6-09_Puncher_18Feb2022
218134_MT6-09_SBHP_16Feb2022
218134_MT6-09_Tubing Cut_22Feb2022
MT7-01 50-10-320832-00
221052_MT7-01_Perf_29Oct2022
221052_MT7-01_PPROF_03Feb2023
MT7-02 50-103-20840-00
222026_MT7-02_ChemCut_21Dec2022
222026_MT7-02_Plug&Perf_17Apr2023
MT7-03 50-103-20830-00
221024_MT7-03_GR_12Aug23
221024_MT7-03_MechCutter_31Oct23
221024_MT7-03_RBP_1Nov23
MT7-05 50-103-20833-00
221087_MT7-05_PPROF_20Apr2023
221087_MT7-05_SCMT_25Dec2021
MT7-06 50-103-20831-00
221048_MT7-06_IBC-DSLT_04Oct2022
1of 3
Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
Receipt: Date:
Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
T38419
T38420
T38421
T38422
T38423
T38424
T38425
2/29/2024
MT6-09 50-103-20779-00
218134_MT6-09_Puncher_18Feb2022
218134_MT6-09_SBHP_16Feb2022
218134_MT6-09_Tubing Cut_22Feb2022
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2024.02.29
10:56:14 -09'00'
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
You don't often get email from kate.dodson@conocophillips.com. Learn why this is important
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: GMTU MT6-09 (PTD# 218-134-0) Water Injection Continuation
Date:Thursday, July 7, 2022 1:27:21 PM
Attachments:MIT GMTU MT6-09 06-07-22.xlsx
MIT GMTU MT6-08 & 09 05-20-22.xlsx
AnnComm Surveillance TIO for MT6-09.pdf
From: Dodson, Kate <Kate.Dodson@conocophillips.com>
Sent: Thursday, July 7, 2022 9:25 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Dodson, Kate
<Kate.Dodson@conocophillips.com>; Smith, Travis T <Travis.T.Smith@conocophillips.com>
Subject: RE: GMTU MT6-09 (PTD# 218-134-0) Water Injection Continuation
Hi Chris,
GMTU MT6-09 (PTD# 218-134-0) has completed the 30 day monitor period on MI Injection.
The IA has stabilized and appears to have integrity as shown in the AOGCC witnessed
MIT-IA on 5/20/2002 and 6/7/2022. The paperwork to cancel AA 40.001 will be submitted
as required. See attached for 90 Day TIO Plot and 10-426 forms for completed MITs as
mentioned above. Let me know if you have any questions or disagree with this plan.
Thanks,
Kate Dodson | Senior Well Intervention Engineer
ConocoPhillips Alaska | Wells Engineering
O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com
From: Smith, Travis T
Sent: Thursday, October 7, 2021 4:36 PM
To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: GMTU MT6-09 (PTD# 218-134-0) Water Injection Continuation
Chris—
GMTU MT6-09 (PTD# 218-134-0) was previously found with TxIA communication while on water
injection. The well has been on a diagnostic period after swapping a dummy valve to attempt to
troubleshoot this issue. The TxIA communication appears to be ongoing despite this work.
For the time being we have limited options to preserving adequate flow rate in the MT6 injection
cross country line. The barriers present in this well allow it to operate safely as a water injector
despite the TxIA communication that is seen during water injection. This well most recently passed a
diagnostic MITIA (4-1/2” x 7”) on September 23, 2021. TIO plot trends indicate the OA (7”x9-5/8”)
has integrity as well, although we intend to get a diagnostic MITOA in the near future as well.
Furthermore, TIO trends indicate the OOA (9-5/8” x 13-3/8”) has integrity.
Our intent is to submit a request for Administrative Approval to allow the well to operate in water
injection service only with known TxIA communication. We will submit this justification shortly after
we have performed the diagnostic MITOA on the 7” x 9-5/8” annulus. Our intent is to leave the well
on water injection service during this application process.
Please let me know if you have any questions or disagree with the plan.
Thanks,
Travis Smith
WNS Intervention & Integrity Engineer
907-670-4014
Travis.T.Smith@conocophillips.com
MT6-09 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
MT6-09 2022-05-07 200.0 625 425.0 IA
MT6-09 2022-05-11 850.0 819 -31.0 IA
MT6-09 2022-05-16 840.0 340 -500.0 IA
MT6-09 2022-05-27 988.0 1724 736.0 IA
MT6-09 2022-06-04 2037.0 1492 -545.0 IA
MT6-09 2022-06-05 2063.0 1836 -227.0 IA
MT6-09 2022-06-07 953.0 650 -303.0 OA
MT6-09 2022-06-12 1020.0 375 -645.0 OA
MT6-09 2022-06-15 2410.0 1000 -1410.0 IA
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
LAST TAG:MT6-09 jennalt
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Pulled DFCV, pushed Obsidian Plug to TD. 5/3/2022 MT6-09 famaj
Casing Strings
Casing Description
CONDUCTOR
OD (in)
20
ID (in)
19.12
Top (ftKB)
36.7
Set Depth (ftKB)
115.0
Set Depth (TVD) …
115.0
Wt/Len (lb…
94.00
Grade
H-40
Top Connection
Welded
Casing Description
SURFACE
OD (in)
13 3/8
ID (in)
12.40
Top (ftKB)
36.7
Set Depth (ftKB)
2,146.0
Set Depth (TVD) …
2,030.8
Wt/Len (lb…
68.00
Grade
L-80
Top Connection
TXP
Casing Description
INTERMEDIATE #1
OD (in)
9 5/8
ID (in)
8.84
Top (ftKB)
34.2
Set Depth (ftKB)
10,395.7
Set Depth (TVD) …
7,286.1
Wt/Len (lb…
40.00
Grade
TN-80
Top Connection
TXP
Casing Description
TIEBACK STRING
OD (in)
7
ID (in)
6.28
Top (ftKB)
32.1
Set Depth (ftKB)
9,767.0
Set Depth (TVD) …
6,907.6
Wt/Len (lb…
26.00
Grade
L80
Top Connection
TSHBlue
Casing Description
INTERMEDIATE #2 SDL
LINER
OD (in)
7
ID (in)
6.28
Top (ftKB)
9,754.6
Set Depth (ftKB)
12,026.0
Set Depth (TVD) …
7,897.1
Wt/Len (lb…
26.00
Grade
L-80
Top Connection
Tenaris Blue
Liner Details: excludes liner, pup, joints, casing, sub , shoe , float...
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Item Des Com Nominal ID (in)
9,754.6 6,900.1 52.91 SBE Seal Bore Extension 7.375
9,787.1 6,919.7 52.91 SEAL ASSY Latching Seal assy (5.76' seals in LSS below) 6.170
9,789.9 6,921.4 52.91 SETTING
SLEEVE
HRD-E Liner Setting Sleeve 7.735
9,798.8 6,926.8 52.91 QUICK
CONNECT
HP Liner Quick Connect,w/Bullet Seals 7" 32# Tenaris Blue 6.151
9,804.4 6,930.2 52.91 INT CASING Pup 7" 26# L-80 Liner Tenaris Blue Liner 6.276
11,983.0 7,891.8 82.87 INT CASING 7" 32# L-80 Liner Tenaris Blue Casing joint 6.276
12,019.8 7,896.3 83.29 STABILIZER Reamer Shoe Stabilizer w/ Spline Profile, 7" 32# MYS110
Tenaris Blue
6.080
Casing Description
PRODUCTION LINER
OD (in)
4 1/2
ID (in)
3.96
Top (ftKB)
11,864.2
Set Depth (ftKB)
16,090.3
Set Depth (TVD) …
7,954.8
Wt/Len (lb…
12.60
Grade
L-80
Top Connection
TXP
Liner Details: excludes liner, pup, joints, casing, sub , shoe , float...
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Item Des Com Nominal ID (in)
11,864.2 7,876.6 81.76 PACKER HRDE ZXP 5.75" SBE (16.10') 5.000
11,890.7 7,880.3 82.35 HANGER 4-1/2" x 7" Flex Lock Hgr H521 Box x TXP Pin 3.875
Tubing Strings: string max indicates LONGEST segment of string
Tubing Description
Tubing – Completion Upper
String …
4 1/2
ID (in)
3.96
Top (ftKB)
28.7
Set Depth (ft…
11,875.3
Set Depth (TVD…
7,878.2
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
Hyd563
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Item Des
Nominal ID
(in)
OD
Nominal
(in)Make Model
28.7 28.7 0.00 Hanger 3.958 13.350 FMC TC-EMS
2,018.1 1,924.0 33.00 Nipple - X 3.813 4.500 HES X-Nipple
11,114.1 7,663.2 64.79 Mandrel 3.884 4.500 Camco KBG2
11,223.1 7,707.1 67.58 Nipple - X 3.813 4.500 HES X-Nipple
11,775.3 7,862.3 79.81 Packer 3.880 4.500 SLB SLB Perm PKR
11,832.5 7,871.9 81.06 Nipple - DB, XN, DS, D 3.750 4.500 SLB DB-6 nipple
11,860.0 7,876.0 81.67 No-Go Locator 3.930 5.000 Baker No-Go
11,861.0 7,876.1 81.69 Seal Assembly 3.930 5.000 Baker Bullet
Mandrel Inserts : excludes pulled inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 11,114.1 7,663.2 64.79 Camco 1 GAS LIFT DMY BK 0.000 0.0 5/2/2022
HORIZONTAL, MT6-09, 5/4/2022 7:43:47 PM
Vertical schematic (actual)
PRODUCTION LINER ;
11,864.2-16,090.3
INTERMEDIATE #2 SDL LINER;
9,754.6-12,026.0
Seal Assembly; 11,861.0
No-Go Locator; 11,860.0
Pup Joint; 11,844.4
Nipple - DB, XN, DS, D;
11,832.5
Packer; 11,775.3
Nipple - X; 11,223.1
Mandrel; 11,114.1
INTERMEDIATE #1; 34.2-
10,395.7
TIEBACK STRING; 32.1-9,767.0
SURFACE; 36.7-2,146.0
Nipple - X; 2,018.1
CONDUCTOR; 36.7-115.0
Pup Joint; 30.9
Hanger; 28.7
WNS INJ
KB-Grd (ft)
36.64
RR Date
12/22/201
8
Other Elev…
MT6-09
...
TD
Act Btm (ftKB)
16,296.0
Well Attributes
Field Name
LOOKOUT
Wellbore API/UWI
501032077900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
92.48
MD (ftKB)
15,327.65
WELLNAME WELLBOREMT6-09
Annotation
LAST WO:
End Date
4/17/2022
H2S (ppm) DateComment
SSSV: X NIPPLE
HORIZONTAL, MT6-09, 5/4/2022 7:43:48 PM
Vertical schematic (actual)
PRODUCTION LINER ;
11,864.2-16,090.3
INTERMEDIATE #2 SDL LINER;
9,754.6-12,026.0
Seal Assembly; 11,861.0
No-Go Locator; 11,860.0
Pup Joint; 11,844.4
Nipple - DB, XN, DS, D;
11,832.5
Packer; 11,775.3
Nipple - X; 11,223.1
Mandrel; 11,114.1
INTERMEDIATE #1; 34.2-
10,395.7
TIEBACK STRING; 32.1-9,767.0
SURFACE; 36.7-2,146.0
Nipple - X; 2,018.1
CONDUCTOR; 36.7-115.0
Pup Joint; 30.9
Hanger; 28.7
WNS INJ MT6-09
...
WELLNAME WELLBOREMT6-09
Comment
Set 4.5" MCX Inj valve (SN: 42…
Submit to:
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 2180480 Type Inj W Tubing 1052 1060 1053 1051 Type Test P
Packer TVD 7938 BBL Pump 2.9 IA 480 2200 2160 2150 Interval I
Test psi 1985 BBL Return 2.4 OA 228 318 316 315 Result P
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 2181340 Type Inj W Tubing 964 967 965 965 Type Test P
Packer TVD 7862 BBL Pump 3.6 IA 810 3300 3240 3240 Interval I
Test psi 3000 BBL Return 2.5 OA 297 665 653 647 Result P
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
ConocoPhillips Alaska Inc,
Alpine / GMTU / MT6 PAD
Brian Bixby
Hembree / Hills
05/20/22
Notes:Initial MITIA post RWO per Sundry # 321-634
Notes:
MT6-08
MT6-09
Notes:Initial MITIA post RWO per Sundry # 321-633 and MITIA to MAIP per AIO 40.001
Notes:
Notes:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Form 10-426 (Revised 01/2017)MIT GMTU MT6-08 09 05-20-22 (002)
Submit to:
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 2181340 Type Inj G Tubing 3327 3339 3342 3346 Type Test P
Packer TVD 7862 BBL Pump 2.6 IA 1520 4000 3980 3980 Interval V
Test psi 3000 BBL Return 2.7 OA 630 900 900 900 Result P
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Notes:MITIA to MAIP per AIO 40.001 OOA 100 110 110 110
Notes:
MT6-09
Notes:
Notes:
Notes:
ConocoPhillips Alaska Inc,
Alpine / GMTU / MT6 PAD
Bob Noble
Miller / Weimer
06/07/22
Form 10-426 (Revised 01/2017)MIT GMTU MT6-09 06-07-22 (002)
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, July 29, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Bob Noble
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
MT6-09
GMTU MT6-09
Jim Regg
InspectorSrc:
MT6-09 G
SPT
7875
2181340 3000
3327 3339 3342 3342
630 900 900 900
Required by Variance Pass
MIT-IA to max injection pressure per AIO 40.001. OOA - 100/110/110/110
30 MinPretestInitial15 Min
Type Test
Notes:
Interval P/F
Well Type Inj TVD
PTD Test psi
Tubing
OA
Packer Depth
1520 4000 3980 3980IA
45 Min 60 Min
50-103-20779-00-00
218-134-0
Bob Noble
6/7/2022
Well Name
Permit Number:
API Well Number Inspector Name:GMTU MT6-09
Inspection Date:Insp Num:
Rel Insp Num:
mitRCN220612154003
MITOP000009238
BBL Pumped:2.6 BBL Returned:2.7
Friday, July 29, 2022 Page 1 of 1
5(9,6('
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9
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9
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AIO 40.001.
James B. Regg Digitally signed by James B. Regg
Date: 2022.07.29 15:53:13 -08'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Wednesday, July 20, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Bob Noble
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
MT6-09
GMTU MT6-09
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 07/20/2022
MT6-09
50-103-20779-00-00
218-134-0
G
SPT
7875
2181340 4000
3327 3339 3342 3342
630 900 900 900
REQVAR P
Bob Noble
6/7/2022
MIT-IA to max injection pressure per AIO 40.001. OOA - 100/110/110/110
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:GMTU MT6-09
Inspection Date:
Tubing
OA
Packer Depth
1520 4000 3980 3980IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitRCN220612154003
BBL Pumped:2.6 BBL Returned:2.7
Wednesday, July 20, 2022 Page 1 of 1
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Tuesday, June 14, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Brian Bixby
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
MT6-09
GMTU MT6-09
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 06/14/2022
MT6-09
50-103-20779-00-00
218-134-0
W
SPT
7875
2181340 3000
964 967 965 965
297 665 653 647
INITAL P
Brian Bixby
5/20/2022
Initial MITIA Post RWO as per SUNDRY 321-633. Tetsed to MAIP as per AIO 40.001.
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:GMTU MT6-09
Inspection Date:
Tubing
OA
Packer Depth
810 3300 3240 3240IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitBDB220521164453
BBL Pumped:3.6 BBL Returned:2.5
Tuesday, June 14, 2022 Page 1 of 1
9
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MITIA Post RWO SUNDRY 321-633.AIO 40.001.
James B. Regg Digitally signed by James B. Regg
Date: 2022.06.14 16:31:59 -08'00'
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: GMTU MT6-09 (PTD# 218-134-0) Workover Complete
Date:Thursday, May 5, 2022 12:16:00 PM
From: Smith, Travis T <Travis.T.Smith@conocophillips.com>
Sent: Wednesday, May 4, 2022 3:32 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: GMTU MT6-09 (PTD# 218-134-0) Workover Complete
Hello Chris—
GMTU injector well MT6-09 (PTD# 218-134-0) recently completed a workover to address TxIA
communication. The well had previously been operating under Administrative Approval 40.001 to
allow water-only injection with known TxIA communication.
The well will return to water injection service soon and once stabilized perform an AOGCC-witnessed
MITIA. Of course, the AOGCC will receive a 10-404 Sundry for this workover as well.
I am writing to let you know our intent is to wait until the well has been placed on its first MI
injection cycle, and completed a 30-day monitoring period of gas injection, to send a cancellation
notification of AA 40.001. At that time we will notify you we intend to treat the well as a normal
WAG injector and cancel AA 40.001.
Please let me know if you have any questions or disagree with the plan.
Thanks,
Travis Smith
WNS Intervention & Integrity Engineer
907-670-4014
Travis.T.Smith@conocophillips.com
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Doyon Camp 5
To:DOA AOGCC Prudhoe Bay;Regg, James B (OGC);Brooks, Phoebe L (OGC);
"BLM_AK_AKSO_EnergySection_Notifications@blm.gov";"Drilling Supervisor, Doyon 25"
Cc:Samuel Dye;Bill Walter;"Greg.S.Hobbs@conocophillips.com";WSC Rig Advisor
Subject:Rig 25 BOP test 4/14/22
Date:Friday, April 15, 2022 6:29:57 AM
Attachments:D25 4-14-22 Chart 2.pdf
D25 4-14-22 Chart 1.pdf
Doyon 25 04-14-22.xlsx
MT6-09 Test sequence 4-14-22.docx
Some people who received this message don't often get email from dc5@doyondrilling.com. Learn
why this is important
Everett Potter
Rig 25 Toolpusher
rig25@doyondrilling.com
907-670-4971
*07807
37'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSub m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Owner/Contractor: Rig No.:25 DATE: 4/14/22
Rig Rep.: Rig Phone: 670-4971
Operator: Op. Phone:670-4970
Rep.: E-Mail
Well Name:PTD #22181340 Sundry #321-633
Operation: Drilling: Workover: X Explor.:
Test: Initial: X Weekly: Bi-Weekly: Other:
Rams:250/4200 Annular:250/2500 Valves:250/4200 MASP:4125
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result Test Result Quantity Test Result
Location Gen.P Well Sign P Upper Kelly 1P
Housekeeping P Rig P Lower Kelly 1P
PTD On Location P Hazard Sec.P Ball Type 2P
Standing Order Posted P Misc.NA Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8"x5000psi P Pit Level Indicators PP
#1 Rams 1 2 7/8 x5 1/2 VBR P Flow Indicator PP
#2 Rams 1 Blind/Shear P Meth Gas Detector PP
#3 Rams 1 2 7/8 x5 1/2 VBR P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NA Quantity Test Result
Choke Ln. Valves 1 3-1/8 x5000psi P Inside Reel valves 0NA
HCR Valves 2 3-1/8 x5000psi P
Kill Line Valves 2 3-1/8 x5000psi P
Check Valve 0NAACCUMULATOR SYSTEM:
BOP Misc 1 see remarks FP Time/Pressure Test Result
System Pressure (psi)3000 P
CHOKE MANIFOLD:Pressure After Closure (psi)1500 P
Quantity Test Result 200 psi Attained (sec)12 P
No. Valves 15 P Full Pressure Attained (sec)86 P
Manual Chokes 1P Blind Switch Covers: All stations Yes
Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 6 @ 2020 P
CH Misc 0NA ACC Misc 0NA
Test Results
Number of Failures:1 Test Time:8.5 Hours
Repair or replacement of equipment will be made within days.
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 4/12/22 07:05
Waived By
Test Start Date/Time:4/14/2022 3:30
(date) (time)Witness
Test Finish Date/Time:4/14/2022 12:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Adam Earl
Doyon
Test Annular to 250/3500psi w/4" & 4.5" Test Joint, Ram #1 & #3 w/4" & 4.5" test joint to 250/4200 psi f/ 5/10 min.Test
Ram #2 to 250/4200 psi f/ 5/10 min. Test 2 4" FOSV and 1 4" Dart valve. Function primary & remote BOPE control
stations. Test LEL and H2S alarms. Ann close time 25 secs, ram close time 13 sec, HCR close time 2 sec. BLM waived
witness. Choke line ring gasket FP.
E.Potter / C. Bali
CPAI
B. Book / P.Angelle
GMTU MT6-09
Test Pressure (psi):
rig25@doyondrilling.com
Form 10-424 (Revised 02/2022) 2022-0414_BOP_Doyon25_GMTU_MT6-09
999
9
9
9999
9
9
- 5HJJ
y
Ann close time 25 secs, ram close time 13 sec, HCR close time 2 sec.
Choke line ring gasket FP.
FP
4/14/22
'R\RQ%23(7HVW
*07807 37'
-5HJJ
%PZPO#01&5FTU
(.56.5 15%
- 5HJJ
4/14/22
MT6-09
Gareth Stanley
Doyon Rig 25
CPAI
BOPE Test
4” Test jt
1. Annular Preventer
2. Upper Pipe Rams 2 7/8” x 5 ½” Valves: 13,14,15, kill, 4” dart- 3500 PSI
3. Valves, 2,10,12,HCR kill, FOSV #1- 4200 psi
4. Valves 9,6,11, FOSV#2, Manual kill
5. Retested- questionable duration of flat line on test
6. Retested- questionable duration of flat line on test
7. Lower pipe rams
8. Blinds, upper IBOP , Valves 5,7,8
9. Valves 3, lower IBOP
10. Valve- 4
11. Super and manual chokes
4 ½” test joint
12. Annular 3500 psi
13. Upper rams, HCR choke
14. Manual choke
15. Lower rams
9
9
4/14/22
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Regg, James B (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: Doyon 25 RWO Service
Date:Friday, April 8, 2022 12:11:19 PM
GMTU MT6-09 (PTD 2181340)
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
From: Regg, James B (OGC)
Sent: Friday, April 8, 2022 12:01 PM
To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Loepp, Victoria T (OGC)
<victoria.loepp@alaska.gov>
Subject: RE: Doyon 25 RWO Service
I concur.
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Sent: Friday, April 8, 2022 11:50 AM
To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Regg, James B (OGC)
<jim.regg@alaska.gov>
Subject: Doyon 25 RWO Service
Victoria and Jim,
With rig schedule changes around rig 142 efforts at CD1, Doyon 25 is going to MT6 to complete two
rig workovers (see attached schedule).
I just wanted to confirm that the rig will be on two-week BOP testing intervals in RWO services as it
participates in the between well maintenance program (BWM) on its blow out preventer (BOP)
equipment.
The plan would be that the rig would complete its BWM prior to the first MT6 RWO, complete the
two workovers with a two-week BOP testing interval, then complete a BWM on the return to rotary
service at MT7.
I am requesting your concurrence that this complies the Docket for Between Well Maintenance that
the rig operates under.
Thank-you!
Greg
Greg Hobbs, P.E.
Regulatory Engineer | Wells Team
ConocoPhillips Alaska Inc.
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By Samantha Carlisle at 4:08 pm, Dec 21, 2021
Travis T. Smith
Digitally signed by Travis T.
Smith
Date: 2021.12.21 15:48:15
-09'00'
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Digitally signed by
Jeremy Price
Date: 2022.01.11
15:42:12 -09'00'
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1
Guhl, Meredith D (CED)
From:Wallace, Chris D (CED)
Sent:Tuesday, October 19, 2021 9:07 AM
To:AOGCC Records (CED sponsored)
Subject:FW: GMTU MT6-09 (PTD# 218-134-0) Water Injection Continuation
From: Smith, Travis T <Travis.T.Smith@conocophillips.com>
Sent: Thursday, October 7, 2021 4:36 PM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: GMTU MT6‐09 (PTD# 218‐134‐0) Water Injection Continuation
Chris—
GMTU MT6‐09 (PTD# 218‐134‐0) was previously found with TxIA communication while on water injection. The well has
been on a diagnostic period after swapping a dummy valve to attempt to troubleshoot this issue. The TxIA
communication appears to be ongoing despite this work.
For the time being we have limited options to preserving adequate flow rate in the MT6 injection cross country line. The
barriers present in this well allow it to operate safely as a water injector despite the TxIA communication that is seen
during water injection. This well most recently passed a diagnostic MITIA (4‐1/2” x 7”) on September 23, 2021. TIO plot
trends indicate the OA (7”x9‐5/8”) has integrity as well, although we intend to get a diagnostic MITOA in the near future
as well. Furthermore, TIO trends indicate the OOA (9‐5/8” x 13‐3/8”) has integrity.
Our intent is to submit a request for Administrative Approval to allow the well to operate in water injection service only
with known TxIA communication. We will submit this justification shortly after we have performed the diagnostic
MITOA on the 7” x 9‐5/8” annulus. Our intent is to leave the well on water injection service during this application
process.
Please let me know if you have any questions or disagree with the plan.
Thanks,
Travis Smith
WNS Intervention & Integrity Engineer
907‐670‐4014
Travis.T.Smith@conocophillips.com
C:\Users\aebell\Desktop\September 2021 Data Drop\CPA Data Drop 09142021\2021-09-08_14483_GMTU_MT6-09_LeakPointSurvey_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket #Field Well #API #Log Description Log Date
14483 GMTU MT6-09 50-103-20779-00 LeakPoint Survey 08-Sep-21
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile FTP
______________________________ ______________________________________
Print Name Signature
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM
37'
(6HW
Abby Bell ______________________________________________
Signatuuuuruuuuuuuuuuuuuuuuue
By Abby Bell at 11:23 am, Sep 14, 2021
From:Wallace, Chris D (CED)
To:AOGCC Records (CED sponsored)
Subject:FW: GMTU MT6-09 (PTD# 218-134-0) IA pressurization
Date:Thursday, September 9, 2021 8:10:52 AM
From: Smith, Travis T <Travis.T.Smith@conocophillips.com>
Sent: Thursday, September 9, 2021 8:01 AM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: GMTU MT6-09 (PTD# 218-134-0) IA pressurization
Chris—
An update on GMTU injection well MT6-09 (PTD# 218-134-0). An acoustic/temperature leak detect
log was performed yesterday and the data is still being processed. We expedited logging on this
emerging problem for efficiency but we have not yet performed our more typical troubleshooting
operations.
Additionally, as we discussed on the phone, this is currently our only online water injector at MT6
drillsite. We propose placing MT6-09 on a 30-day monitoring period of continued water injection.
During this time we will perform diagnostics including MITIA and wellhead testing as well as slickline
work to troubleshoot the dummy valve in the GLM.
Let me know if you have any questions or disagree with the plan.
Travis
From: Smith, Travis T
Sent: Tuesday, September 7, 2021 4:21 PM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: GMTU MT6-09 (PTD# 218-134-0) IA pressurization
Chris—
GMTU injection well MT6-09 (PTD# 218-134-0) exhibited IA pressurization over the weekend.
Currently wireline and leak detect logging personnel and equipment are at Alpine for a different job.
In order to troubleshoot MT6-09 most efficiently, we propose leaving the well on stabilized injection
so that we can log it as soon as possible. A well schematic and 90-day TIO are attached.
Let me know if you have any questions or disagree with the plan.
Travis Smith
Annular Communication Surveillance
9-Jun-2021Well Name:MT6-09
Start Date:9-Jun-2021
7-Sep-2021Days:90
End Date:7-Sep-2021
50
60
70
80
90
100
110
120
130
140
150
0
500
1000
1500
2000
2500
3000
9-Jun-2112-Jun-2115-Jun-2118-Jun-2121-Jun-2124-Jun-2127-Jun-2130-Jun-213-Jul-216-Jul-219-Jul-2112-Jul-2115-Jul-2118-Jul-2121-Jul-2124-Jul-2127-Jul-2130-Jul-212-Aug-215-Aug-218-Aug-2111-Aug-2114-Aug-2117-Aug-2120-Aug-2123-Aug-2126-Aug-2129-Aug-211-Sep-214-Sep-217-Sep-21Temperature (degF)Pressure (PSI)Pressure Summary
WHP IAP OAP WHT
0
2000
4000
6000
8000
10000
12000
9-Jun-2112-Jun-2115-Jun-2118-Jun-2121-Jun-2124-Jun-2127-Jun-2130-Jun-213-Jul-216-Jul-219-Jul-2112-Jul-2115-Jul-2118-Jul-2121-Jul-2124-Jul-2127-Jul-2130-Jul-212-Aug-215-Aug-218-Aug-2111-Aug-2114-Aug-2117-Aug-2120-Aug-2123-Aug-2126-Aug-2129-Aug-211-Sep-214-Sep-217-Sep-21Injection Rate (BPD or MSCFD)Injection Rate Summary
DGI MGI PWI SWI BLPD
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
LAST TAG: MT6-09 jennalt
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Pull Injcetion Valve for Ice plug Removal 8/21/2021 MT6-09 claytg
Casing Strings
Casing Description
CONDUCTOR
OD (in)
20
ID (in)
19.12
Top (ftKB)
36.7
Set Depth (ftKB)
115.0
Set Depth (TVD) …
115.0
Wt/Len (l…
94.00
Grade
H-40
Top Thread
Welded
Casing Description
SURFACE
OD (in)
13 3/8
ID (in)
12.40
Top (ftKB)
36.7
Set Depth (ftKB)
2,146.0
Set Depth (TVD) …
2,030.8
Wt/Len (l…
68.00
Grade
L-80
Top Thread
TXP
Casing Description
INTERMEDIATE #1
OD (in)
9 5/8
ID (in)
8.84
Top (ftKB)
34.2
Set Depth (ftKB)
10,395.7
Set Depth (TVD) …
7,286.1
Wt/Len (l…
40.00
Grade
TN-80
Top Thread
TXP
Casing Description
TIEBACK STRING
OD (in)
7
ID (in)
6.28
Top (ftKB)
32.1
Set Depth (ftKB)
9,767.0
Set Depth (TVD) …
6,907.6
Wt/Len (l…
26.00
Grade
L80
Top Thread
TSHBlue
Casing Description
INTERMEDIATE #2 SDL
LINER
OD (in)
7
ID (in)
6.28
Top (ftKB)
9,754.6
Set Depth (ftKB)
12,026.0
Set Depth (TVD) …
7,897.1
Wt/Len (l…
26.00
Grade
L-80
Top Thread
Tenaris Blue
Liner Details
Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com
Nominal ID
(in)
9,754.6 6,900.1 52.91 SBE Seal Bore Extension 7.375
9,787.1 6,919.7 52.91 SEAL ASSY Latching Seal assy (5.76' seals in LSS below) 6.170
9,789.9 6,921.4 52.91 SETTING
SLEEVE
HRD-E Liner Setting Sleeve 7.735
9,798.8 6,926.8 52.91 QUICK
CONNECT
HP Liner Quick Connect,w/Bullet Seals 7" 32#
Tenaris Blue
6.151
9,804.4 6,930.2 52.91 INT CASING Pup 7" 26# L-80 Liner Tenaris Blue Liner 6.276
11,983.0 7,891.8 82.87 INT CASING 7" 32# L-80 Liner Tenaris Blue Casing joint 6.276
12,019.8 7,896.3 83.29 STABILIZER Reamer Shoe Stabilizer w/ Spline Profile, 7" 32#
MYS110 Tenaris Blue
6.080
Casing Description
PRODUCTION LINER
OD (in)
4 1/2
ID (in)
3.96
Top (ftKB)
11,864.2
Set Depth (ftKB)
16,090.3
Set Depth (TVD) …
7,954.8
Wt/Len (l…
12.60
Grade
L-80
Top Thread
TXP
Liner Details
Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com
Nominal ID
(in)
11,864.2 7,876.6 81.76 PACKER HRDE ZXP 5.75" SBE (16.10') 5.000
11,890.7 7,880.3 82.35 HANGER 4-1/2" x 7" Flex Lock Hgr H521 Box x TXP Pin 3.875
Tubing Strings
Tubing Description
Tubing – Production
String Ma…
4 1/2
ID (in)
3.96
Top (ftKB)
28.6
Set Depth (ft…
11,874.7
Set Depth (TVD) (…
7,878.1
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
Tblue
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
28.6 28.6 0.00 HANGER FMC 4-1/2" Tubing Hanger 563 3.958
2,014.8 1,921.2 32.98 NIPPLE NIPPLE,LANDING,4 1/2",X,3.813", TSH Blue 3.813
11,405.9 7,770.9 71.56 NIPPLE NIPPLE,LANDING,4 1/2", 3.813" XN, TSH Blue with RHC Plug
Body Installed @ 72° @11,427'
3.750
11,859.4 7,875.9 81.65 NO-GO
LOCATOR
Locator No-Go 5.75" OD 3.930
11,860.4 7,876.0 81.67 SEAL ASSY Seal Assembly 3.930
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 11,227.5 7,708.8 67.68 Camco KBG-2 GAS LIFT OPEN 12/19/2018
Notes: General & Safety
End Date Annotation
1/14/2018 NOTE: View Schematic w/ Alaska Schematic 10.0
MT6-09, 8/22/2021 5:28:14 AM
Vertical schematic (actual)
PRODUCTION LINER ;
11,864.2-16,090.3
INTERMEDIATE #2 SDL LINER;
9,754.6-12,026.0
SEAL ASSY; 11,860.3
NO-GO LOCATOR; 11,859.4
NIPPLE; 11,405.9
GAS LIFT ; 11,227.5
INTERMEDIATE #1; 34.2-
10,395.7
TIEBACK STRING; 32.1-9,767.0
SURFACE; 36.7-2,146.0
NIPPLE; 2,014.8
CONDUCTOR; 36.7-115.0
HANGER; 28.6
WNS INJ
KB-Grd (ft)
36.64
Rig Release Date
12/22/2018
MT6-09
...
TD
Act Btm (ftKB)
16,296.0
Well Attributes
Field Name
LOOKOUT
Wellbore API/UWI
501032077900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
92.48
MD (ftKB)
15,327.65
WELLNAME WELLBOREMT6-09
Annotation
LAST WO:
End DateH2S (ppm) DateComment
SSSV: NIPPLE
MT6-09, 8/22/2021 5:28:14 AM
Vertical schematic (actual)
PRODUCTION LINER ;
11,864.2-16,090.3
INTERMEDIATE #2 SDL LINER;
9,754.6-12,026.0
SEAL ASSY; 11,860.3
NO-GO LOCATOR; 11,859.4
NIPPLE; 11,405.9
GAS LIFT ; 11,227.5
INTERMEDIATE #1; 34.2-
10,395.7
TIEBACK STRING; 32.1-9,767.0
SURFACE; 36.7-2,146.0
NIPPLE; 2,014.8
CONDUCTOR; 36.7-115.0
HANGER; 28.6
WNS INJ MT6-09
...
WELLNAME WELLBOREMT6-09
Comment
Set 4.5" MCX Inj valve (SN: 42…
To: Jim Regg �9 „Z Z 123, Z0'2u
P.I. Supervisor ��`"'�
FROM: Lou Laubenstein
Petroleum Iaspeetor
NON -CONFIDENTIAL
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Friday, July 10, 2020
SUBJECT: Mechanical Integrity Tests
ConocoPhOlips Alaska, Inc,
MT6-09
GMTU MT6-09
Sre: Inspector
Reviewed By:
P.I. Supry
Comm
Well Name GMTU MT6-09
API Well Number 50.103.20779-00-00
Inspector Name: Lou Laubenstein
Permit Number: 218434-0 Inspection Date: 6@3/2020 -
Insp Num: mitLOL200708112201
Rel Insp Num:
Packer Depth Pretest Initial
15 Min 30 Min 45 Min 60 Min
Well
MT6-09 "Type
Inj
G'
TVD
7875
Tubing
2998
2998
2998 -
2998 "
PTD
2181340 '
Type Test
SPT
Test psi
1969
IA
1830
.2400
2400 -
2400 '
BBL Pumped: 0 B
.6 ' BL Returned:
0.6 -
OA
650 -
700
700 '
700
Interval 4YRTST
P/F P
-
Notes: OOA 10011001100/100
Friday, July 10, 2020 Page 1 of I
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
May 10, 2020
Commissioner Jesse Chmielowski
Alaska Oil & Gas Commission
333 West 7`h Avenue, Suite 100
Anchorage, AK 99501
Commissioner Jesse Chmielowski:
RECEIVED
Mpl,'Y 13 2020
AOCCC
Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these
wells was found to have a void in the conductor. These voids were filled with cement/sand if
needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As
per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that
the treatments took place and meets the requirements of form 10-404, Report of Sundry
Operations.
The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant
was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet presents the well
name, top of cement depth prior to filling, and volumes used on each conductor.
Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions.
Sincerel !,
�
Roger Winter
ConocoPhillips Well Integrity Field Supervisor
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off
Report of Sundry Operations (10-404)
Alpine Field
Date 5/10/2020 CD2, 3, 4 & MT6
Well Name
API #
PTD #
Initial top of
cement
Vol. of cement
pumped
Final top of
cement
Cement/Sand
top off date
Corrosion
inhibitor
Corrosion
inhibitor/
sealant date
ft
bbls
ft
gal
CD2 -02
*501032051300
2051090
30"
14
gals
9"
4/24/2020
1.5
4/25/2020
CD2 -73
*501032059000
2081960
11"
1
gal
6"
4/24/2020
0.5
4/2512020
CD2 -468
*501032058700
2081800
11"
1
gal
7"
4/24/2020
0.8
4/25/2020
CD3 -111A
*501032052601
2170040
14"
4 gals
V.
4/21/2020
1.3
4/22/2020
CD3 -198
*501032063700
2110240
10"
10"
3
4/22!2020
CD4 -215
*501032053900
2061570
40"
28
gals
9"
4/23/2020
1.4
4/23/2020
CD4 -291
*501032067200
2131100
2r
80
gals
6"
4/23/2020
0.5
4/23/2020
CD4 -321
*501032053600
2061420
18.5'
4 gals
6"
4/23/2020
0.5
4/23/2020
MT6-02
*501032079200
2181600
30"
14
gals
8"
4/23/2020
1
4/24/2020
MT6-03
*501032077000
2180160
49"
32
gals
10"
4/23/2020
1.7
4/24/2020
MT6-04
*501032077500
2181080
24"
17
gals
8"
4/23/2020
1
4/24/2020
MT6-05
*501032077100
2180450
30"
10
gals
7"
4/23/2020
1.3
4/24/2020
MT6-06
*501032077300
2180930
25'
7 gals
8"
4/23/2020
1
4/24/2020
MT6-08
*501032077200
2180480
12"
2.5
gals
7"
4/23/2020
1
4/24/2020
MT6-09
*501032077900
2181340
34"
15
gals
9"
4/23/2020
1.5
4/24/2020
DATA SUBMITTAL COMPLIANCE REPORT
4/15/2019
Permit to Drill
2181340
Well Name/No. GMTU MT6-09
Operator CONOCOPHILLIPS ALASKA, INC.
API No. 50-103-20779-00-00
MD 16296
TVD
7972 Completion Date 12/21/2018
Completion Status WAGIN Current Status WAGIN
UIC Yes
C
30442 Digital Data
REQUIRED INFORMATION
Mud Log No Z Samples No ✓ Directional Survey Yes Z
DATA INFORMATION
List of Logs Obtained: GR/RES/NEU/DEN/TOC (from Master Well Data/Logs)
Well Log Information:
Log/ Electr
Data Digital Dataset Log Log Run Interval OH/
Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments
ED C 30212 Digital Data 11830 9582 1/8/2019 Electronic Data Set Filename: MT6-
ED C 30212 Digital Data
ED C 30212 Digital Data
Log
C
30212 Log Header Scans 0 0
ED
C
30442 Digital Data
ED
C
30442 Digital Data
ED
C
30442 Digital Data
ED
C
30442 Digital Data
Log
C
30442 Log Header Scans 0 0
ED
C
30533 Digital Data 34 16296
ED C 30533 Digital Data 80 16296
ED C 30533 Digital Data
ED C 30533 Digital Data
ED C 30533 Digital Data
AOGCC Page 1 of 3 Monday, April 15, 2019
09_SCMT_ 17DEC2018_PASSUP30FPM_PSP_0
09PUC.las
1/8/2019
Electronic File: MT6-
09 SCMT_ 17DEC2018_PASSUP30FPM_PSP_0
09PUC.DLIS
1/8/2019
Electronic File: MT6-09 SCMT 17DEC2018
FIELD PRINT.PDF
2181340 GMTU MT6-09 LOG HEADERS
3/13/2019
Electronic File: MT6-09 EOW - NAD27.pdf
3/13/2019
Electronic File: MT6-09 EOW - NAD27.txt
3/13/2019
Electronic File: MT6-09 EOW - NAD83.pdf
3/13/2019
Electronic File: MT6-09 EOW - NAD83.txt
2181340 GMTU MT6-09 LOG HEADERS
4/2/2019
Electronic Data Set, Filename: MT6-09 Ddlling
Mechanics Depth Data.las
4/2/2019
Electronic Data Set, Filename: MT6-09 LTK
Memory Drilling Data.las
4/2/2019
Electronic File: MT6-09 Drilling Mechanics Depth
Log.cgm
4/2/2019
Electronic File: MT6-09 LTK 2MD Memory
Drilling Log.cgm
4/2/2019
Electronic File: MT6-09 LTK 51VID Memory
Drilling Log.cgm
AOGCC Page 1 of 3 Monday, April 15, 2019
DATA SUBMITTAL COMPLIANCE REPORT
4/15/2019
Permit to Drill 2181340 Well Name/No. GMTV MT6-09
MD 16296
tD U
TVD 7972
30533 Digital Data
Completion Date 12/21/2018
ED
C
30533 Digital Data
ED
C
30533 Digital Data
ED
C
30533 Digital Data
ED
C
30533 Digital Data
ED
C
30533 Digital Data
ED
C
30533 Digital Data
ED
C
30533 Digital Data
ED
C
30533 Digital Data
ED
C
30533 Digital Data
ED
C
30533 Digital Data
Log
C
30533 Log Header Scans
Well Cores/Samples Information
Name
INFORMATION RECEIVED
Completion Report OY
Production Test Information Y U
Geologic Markers/Tops O
COMPLIANCE HISTORY
Completion Date: 12/21/2018
Interval
Start Stop
Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20779.00-00
Completion Status WAGIN Current Status WAGIN UIC Yes
4/2/2019
Electronic File: MT6-09 LTK 51VID Memory
Drilling Log.cgm.meta
4/2/2019
Electronic File: MT6-09 LTK 5TVD Memory
Drilling Log.cgm
4/2/2019
Electronic File: MT6-09 LTK Memory Drilling
Data.dls
4/2/2019
Electronic File: MT6-09 Drilling Mechanics Depth
Log.pdf
4/2/2019
Electronic File: MT6-09 LTK 21VID Memory
Drilling Log.pdf
4/2/2019
Electronic File: MT6-09 LTK 51VID Memory
Drilling Log.pdf
4/2/2019
Electronic Fite: MT6-09 LTK 5TVD Memory
Drilling Log.pdf
4/2/2019
Electronic File: MT6-09 EOW - NAD27.pdf
4/2/2019
Electronic File: MT6-09 EOW - NAD27.txt
4/2/2019
Electronic File: MT6-09 EOW - NAD83.pdf
4/2/2019
Electronic File: MT6-09 EOW - NAD83.txt
0 0
2181340 GMTU MT6-09 LOG HEADERS
Sample
Set
Sent Received Number Comments
Directional / Inclination Data D Mud Logs, Image Files, Digital Data Y /S Core Chips Y A
Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files (% Core Photographs Y A
Daily Operations Summary (D Cuttings Samples Y/& Laboratory Analyses Y N
AOGCC Page 2 of 3 Monday, April 15, 2019
DATA SUBMITTAL COMPLIANCE REPORT
4/15/2019
Permit to Drill 2181340 Well Name/No. GMTU MT6.09 Operator CONOCOPHILLIPS ALASKA, INC.
MD 16296 TVD 7972 Completion Date 12/21/2018 Completion Status WAGIN Current Status WAGIN
Release Date: 11/7/2018
Description Date Comments
Comments:
Compliance Reviewed By:
Date:
API No. 50-103-20779-00-00
UIC Yes
AOGCC Page 3 of 3 Monday, April 15, 2019
I
BAUGHER 0 PRINT DISTRIBUTION LIST
ES
a GE company
COMPANY ConocoPhillips Alaska, Inc.
WELL NAME MT6-09
FIELD
Greater Mosses Tooth Unit
COUNTY
ALPINE
CD/DVD
BHI DISTRICT
Alaska
PRELIM
AUTHORIZED BY
Paul Canizares
EMAIL
Paul. Canizares(a)bhoe.com
STATUS Final Replacement:
COMPANY
ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX)
PERSON ATTENTION
V
t ConocoPhillips Alaska, Inc
Ricky Elgarico. ATO 3-380
700'G' Street.
Anchorage, Alaska 99501
No
21 01 34
30533
;e sign and return a of this transmittal form to:
3coPhillips Alaska, Inc.
j Elgarico. Richard.E.Elgarico@conocophillips.com
3-380.
'G' Street. Anchorage, AK 99501
LOG TYPE GR-RES-DEN-NEU
LOG DATE December 16, 2018
TODAYS DATE April 2, 2019
Revision
Details:
Rev. Requested by: ---
FIELDI
FINALI
CD/DVD
FINAL
0Q
PRELIM
LOGS
(las, dlis, PDF, META,
SURVEY
REPORT
LOGS
CGM, Final Surveys)
Anchorage, Alaska. 99519-6860
# OF PRINTS
# OF COPIES
I#OFCOPIES
# OF COPIES
is is lu
0 1 0
2
Alpine Wells Supervisor, NSK-33
0
0Q
atm
0
0%
P.O. Box 196860
Anchorage, Alaska. 99519-6860
APR 0 2 2019
3 ASRC, Attn: Teresa Imm
I
0 I
0 I
0 0
0
3900'C' Street, Suite 801
Anchorage, Alaska 99503-5963
4 Wayne Svejnoha
0
F 0-1
0 0
0
BLM State Office
222 W. 7th Ave., Suite#13
Anchorage, Alaska 99513-7504
5 AOGCC ATTN: Natural Resources Tech
0
1
1 0
0
333 W. 7th Ave., Suite 100
Anchoraee. Alaska 99501-3539
[MT6-091 is located in a federal oil and gas unit. Only with respect to the [MT6-091 Well Data, CPAI hereby waives its right
to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a
waiver of indefinite confidentiality on any other wells.
Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well
data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM)
and/or Arctic Slope Regional Corporation (ASRC).
TOTALS FOR THIS PAGE: 0 1 1 0 0
BA ER Date:
i-�UGHE$ March 8, 2019
AT
GE company
Abby Bell
AOGCC
333 West 7`" Ave, Suite 100
Anchorage, Alaska 99501
21 81 34
30 44 2
Letter of Transmittal
Michael Soper
Baker Hughes, a GE Company
795 East 94`" Avenue
Anchorage, Alaska 99515
Please find enclosed the directional survey data for the following well(s):
MT6-09
RECEIVED
MAR 13 2019
AOCCC
(1) Total print
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Note: Please feel free to send us an email in place of return mail.
Michael Soper, Baker Hughes, Applications Engineer
Michael.SoperCo)BakerHughes.com
21 81 34
3041:2
ConocoPhillips
ConocoPhill ips(Alaska) Inc. MNS
Western North Slope
GMT1 Lookout Pad
MT6-09
50-103-20779-00
Baker Hughes INTEQ BAT(ER
GE<ompany
UGHES
a
Definitive Survey Report
19 December, 2018
12/19/2018 5: 12: 43PM Page 2 COMPASS 5000 14 Build 85D
ConocoPhillips
R
' "G"
ConocoPhilli p s
Definitive Survey Report
Company:
ConocoPhillips(Alaska) Inc. -WNS
Local Coordinate Reference:
Well MT6-09
`
Project:
Western North Slope
TVD Reference:
ACTUAL MT6-09 @ 88.94usft (Doyonl9)
Site:
GMT1 Lookout Pad
MD Reference:
ACTUAL MT6-09 @ 88.94usft (Doyonl9)
Well:
MT6-09
North Reference:
True
Wellbore:
MT6-09
Survey Calculation Method:
Minimum Curvature
Design:
A2-wp01
Database:
EDT 14 Alaska Production
Project
Western North Slope, North Slope Alaska, United States
Map System:
US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum:
NAD 1927 (NADCON CONUS)
Using Well Reference
Point
Map Zone:
Alaska Zone 04
Using geodetic scale factor
Well
MT6-09
Well Position
+N/ -S 0.00 usft
Northing: 5,945,516 47usft
Latitude:
70° 15'22.677 N
+E/ -W 0.00 usft
Easting: 316,984.85usft
Longitude:
151° 28'45 096 W
Position Uncertainly
0.00 usft
Wellhead Elevation: 0.00usft
Ground Level:
37.20 usft
Wellbore
MT6-09
Magnetics
Model Name Sample Date
Declination
Dip Angle
Field Strength
(°I
V)
(nT)
BGGM2018 11/19/2018
1630
80.69
57,387
DesignMT6-09
--.,•„-,�,.°�--r..�....-.,--**....-,:
_.-,.....
,--,-,.....A...-P—,,,�.......°,.—..-..--.,._._._.. .,
Audit Notes:
Version:
1.0 Phase: ACTUAL
Tie On Depth: 36.64
Vertical Section:
Depth From (TVD)
+Nl-S
+EI -W Direction
+�
(usft)
(usft)
'(usft) l°1
3664
0.00
0.00 312.64
12/19/2018 5: 12: 43PM Page 2 COMPASS 5000 14 Build 85D
ConocoPhillips eA ER
ConocoPhillips Definitive Survey Report
Company:
Company:
ConocoPhillips(Alaska) Inc. -WNS
Local Coordinate Reference:
Well MT6-09
Project:
Western North Slope
ND Reference:
ACTUAL MT6-09 @ 88.94usft (Doyon19)
Site:
GMT1 Lookout Pad
MD Reference:
ACTUAL MT6-09 @ 88.94usft (Doyon19)
Well:
MT6-09
North Reference:
True
Wellbore:
MT6-09
Survey Calculation Method:
Minimum Curvature
Design:
A2-wp01
Database:
EDT 14 Alaska Production
Survey Program
Inc
Date
-
N
i•yY
From
To
Map
DLS
VerticalDSS
(usft)
(usft)
Survey (Wellbore)
Tool Name
Description
73.14
1,009.87
1. Gyrodata GyroSS 16" (MT6-09)
GYD-CT-DMS
Gyrodata cont.drillpipe m/s
1,052.98
2,090.28
2. BHGE MWD+IFR+MSA 16"(MT6-09)
MWD+IFR-AK-CAZ-SC
MWD+IFRAKCAZSCC
2,175.41
10,364.48
3. BHGE MWDATK+IFR+MSA 121/4"(M
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
10,500.71
12,080.58
4. BHGE MWD+IFR+MSA 6 3/4" (MT6-0
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
12,182.47
16,184.28
S. BHGE MWD+IFR+MSA 4-1/8"(MT6-0
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
Survey
UNDEFINED
73.14
0,46
165.82
Survey
Start Date
11/21/2018
11/21/2018
11/21/2018
12/3/2018
12/17/2018
MD
Inc
Azi
ND
N
+N/ -S
+E/ -W
Map
Map
DLS
VerticalDSS
(usft)
(°)
(°)
(usN)
(usft)
(usft)
(usft)
Northing
East,.ng
(°1100•)
Section
Survey Tool Name
(N)
(ft)
(ft)
3664
0.00
0.00
36.64
-52.30
0.00
0.00
5,945,51647
316.984.85
0.00
0.00
UNDEFINED
73.14
0,46
165.82
73.14
-15.80
-0.14
0.04
5,945,516.33
316,984.88
126
-0.12
GYD-CT-DMS(1)
i 165.85
I
0.70
163.59
165.84
76.90
-1.05
0.29
5,945,515.42
316.985.11
0.26
-0.92
GYD-CT-DMS(1)
257.12
0.78
174.81
257.11
168.17
-2.20
0.50
5,945,514.26
316,985.30
0.18
-7.86
GYD-CT-DMS (1)
_) 350.34
0.80
211.82
350.32
261.38
-3.38
022
5,945,513.08
316,984.98
0.54
-2.45
GYD-CT-DMS(1)
444.54
2.65
274.05
444.48
355.54
-3.79
-2.30
5,945,512.74
316,98246
2.53
-0.87
GYD-CT-DMS(1)
539.07
1
4.89
282.11
538.80
449.86
-2.79
-8.42
5,945,513.89
316.976 36
2.43
4.31
GYD-CT-DMS (1)
633.69
6.45
289.26
632.95
544.01
-0.19
-17.39
5,945,516.70
31696747
1.61
12.66
GYD-CT-DMS(1)
727.03
8.84
289.51
725.46
636.52
3.93
-29.10
5,945,521.11
316,955.86
2.56
24.07
GYD-CT-DMS(1)
821.52
1047
290.98
818.61
729.67
9.43
-43.96 __
5,945,526.97
316941.14
1.74
38.73
GYD-CT-DMS(1)
915.95
11.55
292.93
911.30
822.36
16.19
-60.68
5,945,534.13
316924.59
1.21
55.60
GYD-CT-DMS (1)
1,009.87
12.51
293.26
1,003.15
914.21
23.87
-78.68
5,945,542.25
316,906.78
1.02
74.05
GYD-CT-DMS(1)
1,052.98
13.53
295.72
1,045.15
956.21
27.90
-87.51
5,945,546.49
316,898.05
2.69
83.28
MWD+IFR-AK-CAZ-SC(2)
1,146.49
15.59
296.41
1,135.66
1,046.72
38.24
-108.62
5,945,557.34
316,877.19
2.21
105.81
MWD-IFR-AK-CAZ-SC (2)
1,241.75
18.04
294.65
1,226.84
1,137.90
50.09
-133.50
5,945,569.79
316,852.62
263
132.13
MWD+IFR-AK-CAZ-SC(2)
1,336.57
19.69
293.72
1,316.56
1,227.62
62.64
-161.47
5,945,583.01
316,824.96
1.77
161.21
MWD+IFR-AK-CAZ-SC(2)
1,430.45
21.20
292.77
1,404.52
1,315.58
75.57
-191.60
5,945,596.67
316795.15
1.65
192.14
MWD+IFR-AK-CAZ-SC(2)
1,523.73
23.31
290.78
1,490.85
1,401.91
8865
-224.41
5.945,610 54
316,76267
2.40
225.13
MWD+IFR-AK-CAZ-SC(2)
1,618.89
25.59
29046
1,577.47
1,488.53
102.51
-261.28
5.945,625 30
316,726.16
2.40
261.64
MWD+IFR-AK-CAZ-SC(2)
Survey
End Date
11/21/2018
11/21/2018
11/26/2018
12/17/2018
Annotation
12/19/2018 5+12:43PM Page 3 COMPASS 5000.14 Build 851)
ConocoPhillips ER
ConocoPhilli s D"f{`UGHES
p Definitive Survey Report
Company:
ConocoPhillips(Alaska) Inc. -WNS
- Local Co-ordinate Reference:
Project:
Western North Slope
TVD Reference:
Site:
GMT1 Lookout Pad
MD Reference:
Well:
MT6-09
North Reference:
Wellbore:
MT6-09
Survey Calculation Method:
Design:
A2-wp01
Database:
Survey
MD
Inc
Azi
TVD
TVDSS
+N1-S+E/-W
Map
(usft)
(°)
(°)
(usH
(usH)
(usN)
(usH)
Northing
(ft)
1,712.63
27.94
292.41
1,661.17
1,572.23
117.96
-300.55
5,945,641.70
1,807.16
29.92
293.03
1,743.90
1,654.96
135.63
-342.73 -
5,945,660.38
1,901.11
30.90
292.57
1,824.92
1,735.98
154.06
-386.57
5,945,679.87
1,995.30
32.85
291.84
1,904.90
1,815.96
172.84
-432.62
5,945,699.77
2,090.28
33.47
292.13
1,98441
1,895.47
192.29
480.79
5,945,720.38
2,175.41
33.84
292.02
2,055.27
1,966.33
210.02
-524.51
5,945,739.17
2,270.07
34.98
292.33
2,133.37
2,044.43
23022
-574.05
5,945,760.55
2,364.05
36.90
292.95
2,209.46
2,120.52
251.45
-624.95
5,945,783.02
2,45943
38.39
293.87
2,284.98
2,196.04
274.61
-678.40
5,945,80746
2,552.76
40.13
293.54
2,357.24
2,268.30
298.35
-732.48
5,945,832.51
2,647.43
41.60
293.69
2,428.83
2,339.89
323.16
-789.23
5,945,858.69
2,742.32
42.90
292.70
2,499.07
2,410.13
348.28
-847.88
5,945,885.23
2,836.00
43.07
292.05
2,567.60
2,478.66
372.59
-906,94
5,945,910.97
2,930.07
43.25
292.28
2,636.22
2,547.28
396.87
-966,53
5,945.936.69
3,024.24
4320
291.85
2,704.84
2,615.90
421.10
-1,026.30
5,945,962.36
3,118.42
43.44
292.22
2,773.36
2,684.42
445.34
-1,086.20
5,945,988.05
3,213.17
43.29
292.21
2,842.24
2,753.30
469.94
-1,146.43
5,946,014.10
3,307.34
43.30
291.89
2,910.78
2,821.84
494.18
-1,206.28
5,946,039.79
3,401.47
4343
291.85
2,979.21
2,890.27
518.26
-1,266.26
5,946065.31
3,495.73
4325
291.63
3,047.77
2,958.83
54222
-1,326.35
5,946,090.73
3,590.03
43.48
291.93
3,116.32
3,027.38
566.25
-1,386.48
5,946,11620
3,68348
43.26
291.97
3,184.25
3,095.31
590.23
-1,446.00
5,946,141.63
3,778.00
43.33
292.49
3,253.05
3,164,11
614.76
-1,506.00
5,946,167.60
3,871.75
43.20
291.86
3,321.32
3,232.38
639.01
-1,565.50
5,946,193.29
3,966.08
43.20
291.79
3,390.08
3,301.14
663.01
-1,625.45
5,946,218.74
4,060.42
45.23
292.25
3,457.69
3,366.75
68]68
-1.686.43
5,946,244.88
4,154.85
47.92
293.00
3,522.60
3,433.66
714.07
-1,749.73
5,946,272.80
4,249.02
49.63
293.33
3,584.66
3,495.72
741.94
-1,814.84
5,946,302.24
4,342.79
53.04
294.30
3,643.23
3,554.29
771.51
-1,881.80
5,946,333.43
4,437.63
53.07
294.82
3,700.24
3,611.30
803.01
-1,950.74
5,946,366.60
4,531.95
53.10
294.65
3,756.89
3,667.95
834.57
-2,019.24
5,946,399.80
WellMT6-09
ACTUAL MT6-09 @ 88.94usft (Doyon19)
ACTUAL MTS -09 @ 88.94usft (Doyon19)
True
Minimum Curvature
EDT 14 Alaska Production
Map
Easting 1 DLS
(ft) (°1100')
316,687.27 2.68
316,645.54 2.12
316.602.16 1.07
316.556 59 2.11
316,508.90 067
316,465.63 0.44
316,416.60 1.22
316,366.23 2.08
316,313.36 1.67
316,259.88 1.88
316,203.75 1.56
316,145.74 1.54
316087.29 0.51
316028.31 0.25
315,969.15 0.32
315,909.86 0.37
315,850.25 0.16
315,791.01 0.23
315,731.63 0.14
315,672.14 0.25
315,612.62 0.33
315,553.70 0.24
315,494.32 0.38
315,435.43 0.48
315,376 09 0.05
315,315.73 2.18
315,253.10 2.91
315,188.69 1.83
315,122.46 3.73
315,054.31 0.44
314,986,61 0.15
Vertical
Section Survey Tool Name
(ft)
301.00 MWD+IFR-AK-CAZ-SC (2)
343.99 MWD+IFR-AK-CAZ-SC (2)
388.72 MWD+IFR-AK-CAZ-SC(2)
435.33 MWD+IFR-AK-CAZ-SC(2)
483.94 MIND+IFR-AK-CAZ-SC(2)
528.11 MWD+IFR-AK-CAZ-SC(3)
578.23 MWD+IFR-AK-CAZ-SC(3)
630.06 MWD+IFR-AK-CAZ-SC(3)
685.07 MWD+IFR-AK-CAZSC(3)
740.93 MWD+IFR-AK-CAZ-SC(3)
799.49 MWD+IFR-AK-CAZ-SC(3)
859.64 MWD+IFR-AK-CAZ-SC(3)
919.56 MWD+IFR-AK-CAZ-SC(3)
979.84 MWD+IFR-AK-CAZ-SC(3)
1,040.22 MWD+IFR-AK-CAZ-SC (3)
1,100.70 MWD+IFR-AK-CAZ-SC (3)
1,161.67 MWD+IFR-AK-CAZ-SC(3)
1,222.12 MWD+IFR-AK-CAZ-SC(3)
1,282.56 MWD+IFR-AK-CAZ-SC(3)
1,342.99 MWD+IFR-AK-CAZ-SC(3)
1,403.50 MWD+IFR-AK-CAZ-SC (3)
1,463.53 MWD+IFR-AK-CAZ-SC (3)
1,524.28 MWD+IFR-AK-CAZ-SC(3)
1,584.48 MWD+IFR-AK-CAZ-SC(3)
1,644.84 MWD+IFR-AK-CAZ-SC(3)
1,706.41 MWD+IFR-AK-CAZ-SC(3)
1,770.85 MWD+IFR-AK-CAZ-SC(3)
1,837.62 MWD+IFR-AK-CAZ-SC(3)
1,90691 MWD+IFR-AK-CAZ-SC(3)
1,97897 MWD+IFR-AK-CAZ-SC (3)
2,050.73 MWD+IFR-AK-CAZ-SC(3)
a
Annotation .j
13-3/8"x 16"
12119/2018 5:12:43PM Page 4 COMPASS 5000.14 Build 85D
ConocoPhillips
Company:
ConocoPhillips(Alaska) Inc. -WNS
Project:
Western North Slope
Site:
GMTi Lookout Pad
Well:
MT6-09
Weflbore:
MT6-09
Design:
A2-wp01
Survey
MD
(usft)
4,625.98
4,720.46
4,814.31
4,911.46
5,008.06
5,102.28
5,195.57
5,288.19
5,383.00
5,477.55
5,571.85
5,666.21
5,759.95
5,853.96
5,946.63
6,041.09
6,135.10
6,229.48
6,324.10
6,418.82
6,512.09
6,606.02
6,701.14
6,793.82
6,886.01
6,981.79
7,076.02
7,170.05
7,264.18
7,356.02
7,450.82
Inc
53.05
53.05
53.15
53.14
53.11
53.14
53.08
52.95
52.85
52.94
52.84
53.00
52.79
52.98
53.11
53.12
53.10
53.14
53.11
53.07
53.07
53.08
52.99
52.98
53.06
53.11
53.11
53.15
53.22
52.99
52.99
ConocoPhillips
TVD
UGHFS 0
Definitive Survey Report
+El -W
Map
Local Co-ordinate Reference:
WellMT6-09
,
TVD Reference:
ACTUAL MT6-09 @ 88.94usft (Doyon19)
(usft)
MD Reference:
ACTUAL MT6-09 @ 88.94usft (Dayon19)
(usft)
North Reference:
True
("Dt-S
Survey Calculation Method:
Minimum Curvature
Database:
EDT 14 Alaska Production
Azi
TVD
TVDSS
+Nl-S
+El -W
Map
Map
DLS
Vertical
V)
(usft)
(usft)
(usft)
(usft)
Northing
Easting
("Dt-S
Section
Survey Tool Name
(ft)
(ft)
(ft)
295.08
3,813.38
3,724.44
866.17
-2,087.44
5,946,433.06
314,919.20
0.37
2,122.31
MWD+IFR-AK-CAZ-SC(3)
295.01
3,870.17
3,781.23
898.14
-2,155.84
5,946,466.67
314,851.60
0.06
2,194.28
MWD+IFR.AK-CAZ-SC(3)
294.49
3,926.52
3,837.58
929.56
-2,224.00
5,946,499.73
314,784.23
0.46
2265.70
MWD+IFR-AK-CAZ-SC (3)
294.50
3,984.79
3,895.85
961.79
-2,294.74
5,946,533.67
314,714.30
0.01
2,339.57
MWD+IFR-AK-CA7-SC (3)
294.97
4,042.76
3,953.82
994.12
-2,364.92
5,946,567.70
314,644.93
0.39
2,413.10
MWD+IFR-AK-CAZ-SC (3)
294.79
4,099.30
4,010.36
1,025.83
-2,433.30
5,946,601.06
314.577.35
0.16
2,484.88
MWD+IFR-AK-CAZ.SC(3)
294.70
4,155.30
4,066.36
1,057.06
-2,501.06
5,946,633.92
314,510.37
0.10
2,555.88
MWD+IFR.AK-CAZ-SC(3)
294.63
4,211.02
4,122.08
1,087.94
-2,568.29
5,946,666.42
314,443.81
0.15
2,626.26
MWD+IFR-AK.CAZ-SC(3)
295.02
4,268.21
4,179.27
1,119.69
-2.636.93
5.946.699.83
314,376.07
0.34
2,698.25
MWD+IFR-AK-CAZ-SC(3)
295.29
4,325.25
4,236.31
1,151.74
-2,705.18
5,946,733.53
314,308.62
0.25
2,770.17
MWD+IFR-AK-CAZ-SC(3)
295.66
4,382.14
4,293.20
1,184.08
-2,773.07
5,946,767.51
314,241.54
0.33
2,842.02
MWD+11FR-AK.CAZ-SC (3)
295.46
4,439.04
4,350.10
1,216.56
-2,840.98
5,946,801.63
314,174.44
0.24
2,913.98
MWD+IFR-AK-CAZ-SC (3)
295.39
4,495.59
4,406.65
1,248.66
-2,908.50
5,946,835.35
314,107.72
0.23
2,985.40
MWD+IFR-AK-CAZ.SC(3)
296.44
4,552.32
4,463.38
1,281.42
-2,975.93
5,946,869.74
314,041.12
0.91
3,057.19
MWD+IFR.AK-CAZ-SC(3)
296.09
4.608.03
4,519.09
1,314.19
.3,042.34
5,946,904.11
313,975.53
0.33
3,128.24
MWD+IFR-AK-CAZ.SC(3)
295.39
4,664.72
4,575.78
1,347.01
-3,110.39
5,946,938.57
313,908.30
0.59
3,200.53
MWD+IFR.AK-CAZ-SC(3)
295.22
4,721.16
4,632.22
1,379.14
-3,178.37
5,946,972.35
313,841.13
0.15
3,272.30
MWD+IFR-AK-CAZ-SC (3)
294fi3
4,777.80
4,688.86
1,410.96
-3,246.83
5,947,005.81
313,773.46
0.50
3,344.21
MWD+IFR-AK-CAZ-SC(3)
293.68
4,834.58
4,745.64
1,441.93
-3,315.89
5,947,038.45
313.705.18
0.80
3,416.00
MWD+IFR-AK-CAZ.SC(3)
294.11
4,891.46
4,802.52
1,472.61
-3,385.13
5,947,070.80
313,636.70
0.37
3,487.72
MWD+IFR-AK-CAZ.SC(3)
293.11
4,947.50
4,858.56
1,502.47
.3,453.45
5,947,102.31
313,569.14
0.66
3,558.20
MWD+IFR-AK-CAZ-SC(3)
292.92
5,003.94
4,915.00
1,531.83
-3,522.56
5,947,133.34
313,500.77
0.16
3,628.93
MWD+IFR-AK-CAZ.SC(3)
292.41
5,061.13
4,972.19
1,561.11
-3,592.69
5,947,164.32
313.431.37
0.44
3,700.35
MWD+IFR-AK-CAZ-SC(3)
292.76
5,116.93
5,027.99
1,589.53
.3,661.02
5,947,194.39
313,363.76
0.30
3,769.87
MWD+IFR-AK-CAZ-SC(3)
294.11
5,173.59
5,084.65
1,619.46
-3,730.05
5,947,225.98
313,295.48
1.15
3,840.92
MWD+IFR-AK-CAZSC 13)
295.38
5,229.92
5,140.98
1,650.84
-3,798.15
5,947,259.01
313,228.17
1.08
3,912.27
MWD+IFR-AK-CAZ-SC(3)
295.97
5,286.48
5,197.54
1,683.50
-3,866.07
5,947,293.30
313,161.07
0.50
3.984.36
MWD+IFR.AK-CAZ-SC(3)
297.63
5,342.90
5,253.96
1,717.41
.3,933.21
5,947,328.83
313,094.77
1.41
4,056.72
MWD+IFR-AK-CAZ-SC(3)
295.90
5,399.31
5,310.37
1,751.34
-4,000.49
5,947,364.39
313,028.34
1.47
4,129.20
MWD+IFR-AK-CAZ-SC(3)
295.95
5,454.45
5,365.51
1783.45
-4066.55
5,947,398.09
312,963.09
0.25
4,199.54
MWD+IFR.AK-CAZ-SC(3)
295,91
5,511.51
5,422.57
1,816,56
-4,134.63
5,947,432.84
312,895.84
0.03
4,27205
MWD+IFR-AK-CAZ-SC(3)
Annotation
121192018 5:12:43PM Page 5 COMPASS 5000.14 Build 85D
ConocoPhillips a ER
ConocoPhillips Definitive Survey Report
urEs
Company:
Conoco Phillips(Alaska) Inc. -WNS
Local Coordinate Reference:
Well MT6-09
Project:
Western North Slope
ND Reference:
ACTUAL
MT6-09 Q
88.94usft (Doyonl9)
Site:
GMT1 Lookout Pad
MD Reference:
ACTUAL MT6-09 @
88.94usft (Doyonl9)
Well:
MT6-09
North Reference:
True
Wellbore:
MT6-09
Survey Calculation Method:
Minimum
Curvature
Design:
A2-wp01
Database:
EDT 14
Alaska Production
Survey
I
MD
Inc
Azi
ND
NDSS
+N! -S
+E/ -W
Map
Map
DLS
Vertical
(usft)
0
(0)
(usft)
(usft)
(usft)
(usft)
Northing
Easting
(°1100')
Section
Survey Too[ Name
Annotation
(ft)
(ft)
(ft)
-.
7,545.33
52.93
295.72
5,568.44
5,479.50
1,849.41
-4,202.54
5.947,467.33
312,828'75
0.17
4,344.26
MW0+1FR-AK-CAZ-SC (3)
7,637.53
52.99
295.60
5,623.98
5,535.04
1,881.28
-4,268.87
5,947,500.80
312,763.21
0.12
4,41464
MWD+IFR-AK-CAZ-SC(3)
7,732.53
52.81
296.50
5,681.29
5,592.35
1,914.55
4,336.95
5,947,535.71
312,695.97
0.78
4,487.26
MWD+iFR-AK-CAZ-SC (3)
7,827.25
52.92
295.61
5,738.47
5,649.53
1,947.72
-4,404.78
5,947,570.51
312.628.96
0.76
4,559.63
MWD+IFR-AK-CAZ-SC (3)
(i 7,921.01
I
53.01
295.14
5,794.94
5,706.00
1,979.79
-4,472.41
5,947,604.22
312,562.14
0.41
4,631.10
MWD+IFR-AK-CAZ-SC(3)
8,014.97
53.00
294.60
5,851.48
5.762.54
2,011.35
-0,540.49
5,947,637.42
312.494.85
0.46
4,702.57
MWD+IFR-AK-CAZ-SC(3)
8,109.81
52.91
294.81
5,908.62
5,819.68
2,042.99
.4,60926
5,947,670.72
312,426.87
0.20
4,774.58
MWD+IFR-AK-CAZ.SC(3)
j 8,204.21
52.84
295.04
5,965.59
5,876.65
2,074.71
-4,677.52
5,947,704.09
312,359.41
0.21
4,846.28
MWD+IFR-AK-CAZ-SC(3)
I 8,298.34
52.89
294.27
6,022.42
5,933.48
2,106.01
-4,745.72 _
5,947,737.04
372,292.D0
0.65
4,917.68
MWD+IFR-AK-CAZ-SC (3)
i
8,392.33
52.88
294.18
6,079.14
5,990.20
2,136.77
.4,814.07
5,947,76944
312,224.42
0.08
4,988.77
MWD+IFR-AK-CAZ-SC(3)
8,486.08
53.16
293.98
6,135.53
6,046.59
2,167.32
4,882.44
5,947,801.65
312,156.81
0.34
5,059.77
MWD+IFR-AK-CAZ-SC (3)
8,580.68
52.88
295.23
6,192.44
6,103.50
2,198.78
-4,951.15
5,947,834.77
312,088.89
1.10
5,131.62
MWD+IFR-AK-CAZ.SC(3)
y
8,673.80
52.96
295.72
6,248.58
6,159.64
2,230.74
-5,018.22
5,947,868.34
312,022.63
0.43
5202.60
MWD+IFR-AK-CAZ.SC(3)
8,768.42
52.92
295.34
6,30560
6,216.66
2,263.28
.5,086.35
5,947,902.52
311,955.31
0.32
5,274.77
MWD+IFR-AK-CAZ.SC(3)
i
8,863.59
52.96
295.07
6,362.96
6,274.02
2.295.62
-5,155.07
5,947,936.53
311.887.40
0.23
5,347.22
MWD+IFR-AK-CAZ-SC(3)
8,956.73
52.95
294.66
6,419.07
6,330.13
2,326.88
-5,222.52
5,947,969.41
311,820.74
0.35
5,418.02
MWD+IFR-AK-CAZ-SC(3)
1
9,050.72
52.90
294.28
6,475.73
6,386.79
2,357.94
.5,290.77
5,948,002.12
311,753.26
0.33
5,489.27
MWD+IFR-AK-CAZ-SC(3)
9,144.05
52.91
293.91
6,532.02
6,443.08
2,388.34
.5,358.73
5,948,034.15
311,686.07
0.32
5,559.84
MWD+IFR-AK-CAZ-SC (3)
i
( 9238.79
52.86
294.52
6,589.19
6,500.25
2,419.32
-5,427,63
5,948,066.80
311,617.94
0.52
5,631.52
MWD+IFR-AK-CAZSC (3)
9,334.18
52.95
294.61
6,646.73
6,557.79
2,450.95
-5,496.83
5,948,100.10
311,549.54
0.12
5,703.85
MWD+IFR-AK-CAZ-SC(3)
i 9,428.60
52.95
294.41
6,703.62
6,614.68
2,482.22
-5,565.39
5,948,133.02
311,481.75
0.17
5,775.47
MWD+IFR-AK-CAZ.SC(3)
9,523.24
52.96
294.36
6,760.63
6,671.69
2,513.40
-5,634.19
5,948,165.87
311,413.74
0.04
5,847.20
MWD+IFR.AK-CAZ-SC(3)
{
9,618.09
52.92
294.21
6,817.79
6,728.85
2,544.53
-5,703.19
5,948,198.66
311,345.52
0.13
5,919.04
MWD+IFR-AK-CAZ-SC (3)
i
9,712.06
52.91
294.77
6,874.46
6,785.52
2.575,61
-5,771.40
5,948,231.38
311,278.08
0.48
5,990.28
MWD+IFR.AK-CAZ-Sc(3)
1
(i 9,805.89
52.91
295.17
6,931.04
6,842.10
2,607.20
-5,839.26
5,948,264.62
311,211. D3
0.34
6,061.59
MWD+IFR-AK-CAZ-SC (3)
} 9,900.95
q
53.00
295.73
6,988.31
6,899.37
2,639.81
-5,907.77
5,948,298.87
311,143.33
0.48
6,134.08
MWD+IFR- AK-CAZ-SC (3)
t
i
3 9,994.83
53.03
296.03
7,044.79
6,955.86
2,672.54
-5,975.24
5,948,333.23
311,076.68
0.26
6,205.88
MWD+IFR-AK-CAZ-SC (3)
10,089.11
52.96
296.16
7,101.54
7,012.60
2,705.66
-6,042.85
5,948,367.98
311,009.90
0.13
6,278.05
MWD+IFR-AK-CAZ-SC(3)
10,181.66
52.91
296.45
7,157.32
7,068.38
2,738.38
-6109.05
5,948,402.31
310,94451
0.26
6,348.92
MWD+IFR-AK-CAZ.SC(3)
j 10274.74
53.09
296.30
7,213.33
7,124.39
2,771.41
8175.65
5,948,436.94
310,878.74
0.23
6,420.28
MWD+IFR-AK-CAZ.SC(3)
1036448
52.9]
296.64
7.267.30
],1]8.36
2,803.37
6239.83
5948,47044
310,815.36
0.33
6.489.15
MWD+IFR-AK-CAZ-SC (3)
i
9-518"x12-1/4"
12119/2018 5:12:43PM
Page 6
COMPASS 5000,14 Build 85D
Conocoftillips
BA Efl�°�
ConocoPhilli p s
Definitive Survey Report
Company:
ConocoPhillips(Alaska)
Inc. -WNS
Local Co-ordinate Reference:
Well MT6-09
Project:
Western North Slope
TVD Reference:
ACTUAL MT6-09 @
88.94usft (Doyonl9)
Site:
GMT1 Lookout Pad
MD Reference:
ACTUAL MT6-09 @
88.94usft (Doyonl9)
Well:
MT6-09
North Reference:
True
Wellbore:
MT6-09
Survey Calculation Method:
Minimum Curvature
Design:
A2-wp01
Database:
EDT 14
Alaska Production
Survey
�
MD
Inc
Azi
TVD
TVDSS
+N/ -S
+E/ -W
Map
Map I
DLS
Vertical
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
Northing
Northing
Easting I
(°1100')
Section
Section
Surve Tool Name
y
Annotation {
(ttl
- -`
10,500.71
53.33
298.43
7,349.01
7,260.07
2,853.76
-6,336.49
5,948,523.17
310.719.96
1.08
6,594.38
MWD+IFR-AK-CAZ-SC(4)
i 10,595.17
55.30
303.21
7,404.13
7,315.19
2,893.08
-6,402.32
5,948,564.07
310,655.10
4.61
6.669.45
MWD+IFR-AK-CAZ-SC(4)
10,688.63
57.07
304.84
7,456.14
7,367.20
2,936.54
-6,466.67
5,948,609.08
310,591.84
2.38
6,746.22
MWD+IFR-AK-CAZ-SC(4)
M 10,782.62
58.82
306.33
7,506.02
7,417.08
2,982.90
-6,531.44
5,948,656.99
310,528.22
2.30
6,825.27
MWD+IFR-AK-CAZ-SC(4)
10,877.06
60.48
309.73
7,553.75
7,464.81
3,033.11
-6,595.61
5,948,708.75
310,465.29
3.57
6,906.46
MWD+IFR-AK-CAZ-SC(4)
10,971.73
62.23
310.34
7,599.13
7,510.19
3,086.55
-6,65921
5,948,763.72
310,403.01
1.93
6,989.48
MWD+IFR-AK-CAZ-SC(4)
11,066.23
63.38
309.38
7,642.32
7,553.38
3,140.42
-6,723.73
5,948,819.13
310,339.82
1.52
7,073.43
MWD+IFR-AK-CAZ-SC(4)
11,160.37
66.15
313.16
7,682.46
7,593.52
3,196.59
-6,787.69
5,948,876.84
310,277.25
4.67
7,158.53
MWD+IFR-AK-CAZSC (4)
11,255.35
68.31
314.40
7,719.22
7,630.28
3,257.19
-6,850.92
5,948,938.95
310,215.52
2.57
7,246.09
MWD+IFR-AK-CAZ-SC(4)
E9
11,350.02
70.30
316.72
7,752.68
7,663.74
3,320.42
-6,912.91
5,949,003.66
310,15509
3.11
7,334.52
MWD+IFR-AK-CAZ-SC(4)
11,444.37
72.42
321.39
7,782.85
7,893.91
3,387.94
-6,971.45
5,949,072.58
310,098.20
5.20
7,423.32
MWD+IFR-AK-CAZ-SC(4)
11,539.12
74.43
322.93
7,809.88
7,720.94
3,459.65
-7,027.15
5,949,145.62
310,044.26
2.63
7,512.88
MWD+IFR-AK-CAZ-SC(4)
7
i
11,633.57
76.65
326.52
7,833.47
7,744.53
3,534.31
-7,079.95 _
5,949,221.53
309,993.30
4.37
7,602.28
MWD+IFR-AK-CAZ-SC (4)
j
11,727.87
78.78
326.93
7,853.53
7,764.59
3,611.34
-7,130.50
5,949299.76
309,944.64
2.30
7,691.65
MWD+IFR-AK-CAZ-SC(4)
11,820.52
80.79
328.95
7,869.97
7,781.03
3,68861
-7,176.89
5,949,378.18
309,898.15
3.05
7,779.59
MWD+IFR-AK-CAZ-SC(4)
Y
d
11,913.87
82.86
329.94
7,883.24
7,794.30
3,768.17
-7,225.85
5,949,458.86
309,853.13
2.45
7,868.04
MWD+IFR-AK-CAZ-SC(4)
I
12,006.53
82.88
330.74
7,894.74
7,805.80
3,848.07
-7,271.35
5,949,539.83
309,809.59
0.86
7,955.63
MWD+IFR-AK-CAZ-SC (4)
i
12,080.58
85.17
331.77
7,902.45
7,813.51
3,912.64
-7,306.77
5,949,605.24
309,775.76
3.39
8,025.41
MWD+IFR-AK-CAZ-SC(4)
6"X6-3/4"
12,182.47
87.97
331.16
7,908.54
7,819.60
4,001.98
-7,355.35
5,949,695.73
309,729.36
2.81
8,121.67
MWD+IFR-AK-CAZ-SC(5)
12,281.02
86.94
331.98
7,912.92
7,823.98
4,088.56
-7,402.22
5,949,783.41
309,684.61
1.34
8,214.60
MWD+IFR-AK-CA7-SC(5)
f
12,377.42
86.88
333.12
7,918.12
7,829.18
4,173.98
-7,446.59
5,949,869.88
309,642.33
1.18
8,305.30
MWD+IFR-AK-CAZ-SC(5)
li
12,471.16
86.92
334.84
7,923.19
7,834.25
4,258.09
-7,487.65
5,948,954.96
309,603.33
1.83
8,392.48
MWD+IFR-AK-CAZ-SC (5)
I
12,566.42
87.01
335.28
7,928.23
7,839.29
4,344.34
-7,527.76
5,950,042.16
309,565.33
0.47
8,480.42
MWD+IFR-AK-CAZ-SC(5)
12,662.80
88.11
335.00
7,932.33
7,843.39
4,431.71
-7,568.24
5,950,130.48
309,526.98
1.78
8,569.38
MWD+IFR-AK-CAZ-SC(5)
12,756.78
89.25
333.04
7,934.50
7,845.56
4,516.17
-7,609.40
5,950,215.91
309,487.99
2.41
8,656.87
MWD+IFR-AK-CAZ-SC(5)
12,852.81
88.47
332.21
7,936.41
7,847.47
4.60143
-7,653.55
5,950,302.21
309,445.84
1.19
8,747.09
MWD+IFR-AK-CAZ-SC(5)
12,948.24
87.71
331.40
7,939.59
7,850.65
4,685+48
-7,698.61
5,950,387.33
309,402.83
1.16
8,837.18
MWD+IFR-AK-CAZ-SC(5)
i 13,042.44
87.68
332.41
7,943.38
7,854.44
4,768.52
-7,742.93
5,950,471.41
309,360.54
1.07
8,926.03
MWD+IFR-AK-CAZ-SC(5)
13,138.63
87.65
332.16
7,947.30
7,858.36
4,653.60
-7,787.63
5,950,557.55
309,317.92
0.26
9,076.55
MWD+IFR-AK-CAZ-SC (5)
1 13.233.31
89.23
333.60
7,949.87
7,860.93
4,937.83
.7 830,77
5,950,642.80
309,276.84
2.26
9,105.35
MWD+IFR-AK-CAZ-SC(5)
13329.10
91.75
334.06
7.949.06
7,860.12
5,023.79
-7,873.02
5,950,729.76
309,236.71
2.67
9,194.65
MWD+IFR-AK-CAZ-SC(5)
12/19/2018 5.12:43PM
Page 7
COMPASS 5000.14 Build 850
ConocoPhillips
WNF-S
ConocoPhillips Definitive Survey Report
Survey
MD
Inc
Azi
ND
Company:
ConocoPhillips(Alaska) Inc. -W NS
Local Co-ordinate Reference:
....
Well MT6-09
Project:
Western North Slope
ND Reference:
ACTUAL MT6-09 @ 88.94usft (Doyonl9)
Site:
GMT1 Lookout Pad
MD Reference:
ACTUAL MT6-09 @ 88.94usft (Doyon19)
Well:
MT6-09
North Reference:
Tme y
Wellbore:
MT6-09
Survey Calculation Method:
Minimum Curvature 1
Design:
A2-wp01
Database:
EDT 14 Alaska Production _1
Survey
MD
Inc
Azi
ND
N
+N/ -S
+E/-WDLS'
Map
Map
VerticalD55
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
Northing
Ea( ting
(°1100')
Section
Survey Tool Name
Annotation
13,424.44
91.92
334.43
7,946.00
7,857.06
5,109.62
-7,914.42
5,950,816.56
309,19740
043
9,283.24
MWD+IFR-AK-CAZ-SC(5)
4 13,519.22
!i
91.15
334.76
7,94346
7,854.52
5,195.20
-7,955.07
5,950,903.10
309,15885
0.88
9,371.12
MWD+IFR-AK-CAZ-SC(5)
i
13,614.55
91.25
334.79
7,941.47
7,852.53
5,281.42
-7,995.69
5,950,990.28
309,120.34
0.11
9,459.40
MWD+IFR-AK-CAZ-SC(5)
{ 13,710.07
91.18
334.43
7,939.44
7,850.50
5,367.70
-8.036.63
5,951,077.51
309,081.50
0.38
9,547.97
MWD+IFR-AK-CAZ.SC(5)
13,805.17
91.18
333.94
7,93248
7,848.54
5,453.29
-8,078.04
5,951,164.08
309,042.19
0.52
9,636.40
MWD+IFR.AK-CAZ-SC(5)
i
33f 13.900.27
91.25
333.85
7,935.47
7,846.53
5,53867
-8,119.87
5,951,250.45
309,002.45
0,12
9,725.01
MWD+IFR-AK-CAZ.SC(5)
E(
13,995.65
9047
333.98
7,934.03
7,845.09
5,624.32
-8,161.81
5,951,337.09
308,96261
0.83
9,813.88
MWD+IFR-AK-CAZ-SC(5)
14,089.95
90.45
334.05
7,933.28
7,844.34
5,709.09
-8,203.12
5,951,422.83
308,923.37
0.08
9,901.69
MWD+IFR-AK-CAZ-SC(5)
14,185.32
90.48
334.82
7,932.50
7,843.56
5,795.12
.8,244.28
5,951,509.82
308,884.32
0.81
9,990.24
MWD+IFR-AK-CAZ-SC
(5)
p
` 14,280.76
90.11
334.74
7,932.01
7,843.07
5,881.46
-8,284.94
5,951,597.12
308,845.76
040
10,078.64
MWD+IFR-AK-CA7-SC(5)
!1
( 14,375.34
89.09
335.38
7,932.67
7,843.73
5,967.21
-8,324.82
5,951,683.82
308,807.98
1.27
10.166.07
MWD+IFR-AK-CAZ-SC(5)
14,469.69
87.92
334.29
7,935.13
7,946.19
6,052.58
-8,364.93
5,951,770.13
308,769.97
169
10,253.40
MWD+IFR-AK-CAZ.SC(5)
14,566.06
87.15
334.00
7,939.28
7,850.34
6,139.22
-8,406.91
5,951,857.76
308,730.10
0.85
10,342.98
MWD+IFR-AK-CAZ.SC(5)
14,661.64
87.50
334.34
7,943.74
7,854.80
6,225.16
-8,448.51
5,951,944.67
308,690.60
0.51
10,431.79
MWD+IFR-AK-CAZ-SC(5)
14,757.17
87.16
335.59
7,948.19
7,859.25
6,311.62
-8,488.89
5,952,032.08
308,652.34
1.35
10,520.06
MWD+IFR-AK-CAZ-SC(5)
14,853.03
89.91
334.98
7,950.64
7,861.70
6,398.66
.8,528.96
5,952,120.07
308,61440
2.94
10,608.49
MWD+IFR-AK-CAZ-SC(5)
14,947.92
91.06
334.12
7,949.84
7,860.90
6,484.33
-8,569.73 -
5,952,206.70
308,575.73
1.51
10,696.52
MWD+IFR-AK-CAZ-SC
(5)
`
15,043.00
91.09
333.78
7,948.05
7,859.11
6,569.74
-8,611.48
5,952,293.09
308.536.07
0.36
10,785.09
MWD+IFR-AK-CAZ-SC(5)
15,137.64
91.15
335.02
7,946.20
7,857.26
6,655.07
-8,652.36
5,952,379.39
308,497.27
1.31
10,872.97
MWD+IFR-AK-CAZ.SC(5)
15,232.51
91.09
334.60
7,944.35
7,855.41
6,740.90
-8,692.73
5,952,466.17
308,459.00
045
10,960.80
MWD+IFR-AK-CAZ.SC(5)
15,327.65
92.48
334.24
7,941.39
7,852.45
6,826.67
.8,733.79
5,952,552.91
308,420.04
1.51
11,049.11
MWD+IFR-AK-CAZ.SC(5)
15,422.67
90.56
334.73
7,938.87
7,849.93
6,912.39
-8,774.70
5.952,639.59
308,381.23
2.09
11,137.27
MWD+IFR-AK-CAZ-SC(5)
15,518.20
88.93
334.13
7,939.29
7,850.35
6,998.56
-8,815.93
5,952,726.73
308,342.10
1.82
11,225.97
MWD+IFR-AK-CAZ-SC(5)
15,613.08
B9.22
334.89
7,940.82
7,851.88
7,084.19
.8,856,76
5,952,813.32
308,303.37
0.86
11,314.01
MWD+IFR-AK-CAZ-SC(5)
15,708.96
88.94
333.23
7,942.36
7,853.42
7,170.40
-8,898.69
5,952,900.52
308,263.55
1.76
11,403.25
MWD+IFR-AK-CAZ-SC
(5)
15,803.91
89.10
334.21
7,943.99
7,855.05
7,255.52
.8,940.73
5.952.986.63
308,223.60
1.05
11,491.83
MWD+IFR-AK-CAZ-SC
(5)
15,899.03
88.01
333.24
7.946.38
7,857.44
7,340.79
-8,982.82
5,953,072.89
308,18359
1.53
11,580.55
MWD+IFR-AK-CAZ-SC(5)
15,993.66
87.99
334.07
7,949.69
7,860.75
7,425.53
-9,024.79
5,953,158.62
308,14370
0.88
11,668.84
MWD+IFR-AK-CAZ.SC(5)
16,089.03
85.95
333.80
7,954.73
7,865.79
7,511.08
-9.066.63
5,953,245.16
308,103.95
2.16
11,757.56
MWD+IFR-AK-CAZ.SC(5)
16,184.28
85.03
333.45
7,962.22
7,873.28
7,596.15
-9,108.82
5,953,331.22
308,063.85
1.03
11,846.22
MWD+IFR-AK-CAZ-SC(5)
16,296.00
85.03
333.45
7,971.90
7,882.96
7,695.71
-9,158.56
5.953.431.96
308,016.53
0.00
11,950.26
PROJECTED to TD
4-1/8"x6"
12/192018 5: 12
43P
Page 8
COMPASS 5000.14 Build 85D
Pro 2te-13f
Loepp, Victoria T (DOA)
From: Cookson, John <John.Cookson@conocophiIli ps.com>
Sent: Thursday, March 7, 2019 11:03 AM
To: Loepp, Victoria T (DOA)
Cc: Haggerty -Sherrod, Ann (Northland Staffing Services)
Subject: RE: [EXTERNAL]RE: GMT Well MT6-09(PTD 218-134) (API 80-103-20779-00-00) Change
from WI to WAG
Follow Up Flag: Follow up
Flag Status: Flagged
That's great Victoria, Thanks!
From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Sent: Thursday, March 07, 2019 11:01 AM
To: Cookson, John<John.Cookson @conocophiIIips.com>
Cc: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann. Hagge rty-Sherrod@contractor.conocophi Ilips.com>
Subject: [EXTERNAL]RE: GMT Well MT6-09(PTD 218-134) (API 80-103-20779-00-00) Change from WI to WAG
John,
Our files have been modified to reflect WAG status on the 10-401 and 10-407 as well as in our database. You may adjust
the status to WAG in your files.
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria.LoeooCa)alaskagov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state of federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Victoria Loepp at (907)793-1247 or Victoria Loepp@alaska gov
From: Cookson, John <John Cookson@conocophillips com>
Sent: Wednesday, March 6, 2019 4:44 PM
To: Loepp, Victoria T (DOA) <victoria.loeop@alaska eov>
Cc: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann. Haggerty-Sherrod@contractorconocophillios com>
Subject: GMT Well MT6-09 (API 80-103-20779-00-00) Incorrectly Permitted
Hi Victoria, this is a follow-up on our call today. This well's 10-401 and 10-407 both have the WIND box checked instead
of the WAG box. This was simply a mistake as all of the MT6 injection wells have always been planned as WAG
MEMORANDUM
TO: Jim Regg
P.I. Supervisor
FROM: Austin McLeod
Petroleum Inspector
K)
�l
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Wednesday, January 23, 2019
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA, INC.
6-09
GMTU MT6-09
Ste: Inspector
Reviewed By:
P.I. Supry 1^
Comm
Well Name GMTU MT6-09 I API Well Number 50-103-20779-00-00 Inspector Name: Austin McLeod
Permit Number: 218.134-0 Inspection Date: 1/16/2019
IUsp Num: mitSAM190117183332
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 6-09 TypelnJ w TVD 7875 Tubing �2ni »02 2w ,202-
PTD 2181340 Type Test SPT Test psi 1969 IA 140 3000 2980 2980 -
BBL Pumped: z.� BBL Returned. ' OA al 99 ' 98
---
IR
Interval I INITAL
Notes: initial Test. OOA- 103/105/104/103
Wednesday, January 23, 2019 Page 1 of I
I STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COML.sSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG' J
1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑
1b. Well Class.
20AAC 25.105 20MC 25.110
Development L]Explorat ry❑
-//,�31q-(/c�
GINJ ElWINJ L9} WAG(y t" WDS/PL ❑ No. of Completions:
Service ❑� Stratigraphic Test ❑
2. Operator Name:
6. Date Comp., Susp.,,or
14. Permit to Drill Number / Sundry:
ConocoPhillips Alaska, Inc.
Abend.: 12/212018 1&
218-134
3. Address:
7. Date Spudded:
15. API Number:
P.O. Box 100360 Anchorage, AK 99510-0360
11/19/2018
50-103-20779-00.00
4a. Location of Well (Governmental Section):
8. Date TO Reached:
16. Well Name and Number:
Surface: 290' FNL, SWEC, Sec 6, TION, RX, UM
r
12115/2018
MT6.09
Top of Productive Interval: 3% +5' FE L a F -� ZqI'f 119
9. Ref Elevations: KB:88.9
17. Field / Pool(s):
1733' FNL, 217' FEL, Sec 35, T11 N, R2E, UM
GL: 37.2 • OF:
Greater Mooses Tooth LIMULookout Oil
Total Depth:
10. Plug Back Depth MD/TVD:
18. Property Designation
r
3160' FNL, 2109' FEL, Sec 26, T11, R2E, UM
N/A
AA081798 AAO818, AA092346
41b. Location of Well (State Base Plane Coordinates, NAD 27):
11. Total Depth MD1fVD:
19. DNR Approval Number:
Surface: x- 316965 - y- 5945516 Zone- 4
1629617972
932533000, 932553000, 340760000
TPI: x- 309813 y- 5949532 Zone- 4
12. SSSV Depth MD/TVD:
20. Thickness of Permafrost MD/TVD:
Total Depth: x- 308016 y- 5953432 - Zone- 4
N/A
1 1203/1189 1
5. Directional or Inclination Survey: Yes El (attached) No ❑
13. Water Depth, if Offshore:
21. Re-drilVLateral Top Window MDrf VD:
Submit electronic and printed information per 20 AAC 25.050
NIA (ft MSL)
I N/A
22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days
of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential,
gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and
perforation record. Acronyms may be used. Attach a separate page if necessary
GR/Res/Neu/DenrTOC
23. CASING, LINER AND CEMENTING RECORD
CASING
WT. PER
GRADE
SETTING DEPTH MD
SETTING DEPTH ND
AMOUNT
FT.
HOLE SIZE
CEMENTING RECORD
PULLED
TOP
BOTTOM
TOP
BOTTOM
20
94
H-40
37
115
37
115
42
10 yds
13318
68
L-80
37
2146
37
2031
16
950 sx 11.Oppg Class B,
331 sx 15.8ppg Class G
95/8
40
L-80
34
10396
34
7286
121/4
89 sx 12.2ppg Class G,
204 sx 15.8ppg Class G
7
26
L-80
9755
12026
6900
7897
6x8 3/4
287 sx 15.8ppg Class G
4 12
12.6
L-80
11864
16090
7877
7955
6
Uncemented Liner
24. Open to production or injection? Yes ❑� No ❑
25. TUBING RECORD
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
Size and Number; Date Perfd):
4 112 16090 11864/7877
PERF PUPS @:
12102.12107 MD and 7904-7905 TVD... 12/17/2018
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
12386-12391 MD and 7919-7919 TVD... 12/17/2018
Was hydraulic fracturing used during completion? Yes ❑ No ❑r
12670-12675 MD and 7933-7933 TVD... 12/17/2018
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
12952-12957 MD and 7940-7940 TVD... 12/17/2018
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
13239-13244 MD and 7950-7950 TVD... 12/17/2018
13365-13370 MD and 7948-7948 TVD... 12/17/2018
13612-13617 MD and 7941-7941 TVD... 12/17/2018
13859-13864 MD and 7936-7936 TVD... 12/17/2018 COMPLETION
14104-14109 MD and 7933-7933 TVD... 12/17/2018 DATE
14348-14353 MD and 7932-7932 TVD... 12/17/2018_ 121 Z I �) A
14668-14673 MD and 7944-7944 TVD... 12/17/2018 VERIFIED
14996-15000 MD and 7949-7949 TVD...12/17/2018
,t
15275-15279 MD and 7943-7943 TVD... 12/17/2018x-
15511-15516 MD and 7939-7939 TVD... 12/17/2018
15795-15800 MD and 7944-7944 TVD... 12/17/2018
27. PRODUCTION TEST
Date First Production:
Method of Operation (Flowing, gas lift, etc.):
N/A
INJECTION ONLY - NOT PRE -PRODUCED
Date of Test:
Hours Tested:
Production for
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Choke Size:
Gas -Oil Ratio:
Test Period
Flow Tubing
Casinq Press:
Calculated
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Oil Gravity - API (torr):
Press.
24 -Hour Rate
Form0-407 RevJ'sed 5/2017 `jrG Z 8 CONTINUED ON PAGE 2 , N', o Sub it ORI INIAL
28. CORE DATA Conventional Corals): Yes ❑ No 21 Sidewall Cores: Yes ❑ No ❑�
If Yes, list formations and intervals cored (MD/ VD, From 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 21
If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Surface
Permafrost - Base
1203
1189
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
11998
7894
information, including reports, per 20 AAC 25.071.
Formation @ TPI -Alpine C
C-30
2206
2081
C-10
2673
2448
K-3
3903
3344
K-2
4293
3613
ALBIAN 96
5186
4149
HRZ
10304
7231
LCU
10635
7427
Formation at total depth,
Alpine —G
31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontolooical report. production or well test results. per 20 AAC 25 070,
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: Chip Alvord Contact Name: Werfeng Dai
Authorized Title: Alaska Drilling Manager Contact Email: weifenq.daiQC0D.G0rA
Authorized / Contact Phone: 263-4324
1' Z &P 16
Signature: {.. Date: 11
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 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Form 10-407 Revised 5/2017 Submit ORIGINAL Only
MT6-09, Injector Completion Schematic Draft
,@�
TOC at least 500MD
above .Alpine C
0
0
4-',4" 12.6# L-80 TXP
With Pert Pups
TopAlpineC • `'�� 0 0 0 0
12, 044' M D 7 7, 692 -TVD
7" 26 ppf L80 T -Blue Liner
0 0 0 0 0�j
6" Hole, TD at 1
at 17,821' MD / 7,906' TVD
August 23, 2018 -AK
20' 79 ppf H-40Insulated
IL Conductor Tubings Liner Completion
80 feel, cemented to surface
1) 4-%" Landing Nipple (3.813' X)
3) 4-'/,'x 1'GLM
O
4)4-!/' Landing Nipple (3.725- DB No Go)
set at 74 deg
5) Liner Top Packers Hanger
13.318"6B ppf L-80TXP (Surf wlTie Back sleeve
to-110(Y)1BTCM to TO
Surface Casing 6)4'/:`TXP Blank Pipe
@ 2.159 MD 11,954 TVD
cemented to surface 7) 4 W TXP Liner with Perf Pups
4.12" 12.6 ppf L.80 Tenads Blue
to 8.677 1.10
9 518" 40 ppf L-80 TXP Ito 5636 md)
9 518" 40 ppf TN -80 HS TXP (to TD)
@ 10.365' MD 17.178 TVC)
,@�
TOC at least 500MD
above .Alpine C
0
0
4-',4" 12.6# L-80 TXP
With Pert Pups
TopAlpineC • `'�� 0 0 0 0
12, 044' M D 7 7, 692 -TVD
7" 26 ppf L80 T -Blue Liner
0 0 0 0 0�j
6" Hole, TD at 1
at 17,821' MD / 7,906' TVD
August 23, 2018 -AK
WNS IPr 1 WELLNAME MT6-09 WELLBORE MT6-09
Well Attribute Max Angle 1 TD
\.VI1V4.Y# E#aL1L'/'7
Wellbore Bbms
ncll°I MOlgr.
ACIBtm INKaI
AlaskalrlG
Iws5003277900
LOOKOUT
LOOKOUT
5010320D90p INJ
248 15,32].65
16,2960
Comment N23(spm)
AnnoMlion End Date K84. bit
RipReleaseon-
SSSV NIPPLE
laser
LAST WO. 3664
12122/2018
MTeos, lm]slg lass.. AAi
Last Tag
Vsses' Mlmlc(cOWI
Annotation
dinginess) En. Dain WepDare
IasIMW By
LAST TAG.
MT6-09
jennalt
HARDER; W6
Last Rev Reason
Annotation
Entl Dale Wellbore
LdsIMW By
REV REASON: Pull BIR, RHO, Install
DV, A-1
1wasti18 jsylw
jennalt
Casing Strings
Casing oxaiplton .0 (in)
(in) Top YKel
ser ninon (Win set sled,(TVIa. call IL..Grwe Top Tnreaa
......................
_...
CONDUCTOR 20
I'D
1912 36.7
115.0 115.0 9400 H40
Welded
Caa11p 0eactlplbn OD(n)
IO lint Top'"
set Wrap eel Deas, IN01... Wlll.en lL.. Orale Tap TM1rmtl
SURFACE 13318
12.40 36.7
2,146.0 2,030.8 68.00 LA0
TXP
Caz11p Description OOlinl
ID lin) TOPIIIRaI
set DeW, I'7% Ser DeWn l]v01... WIILen IL.. G. Top TM1mE
INTERMEDIATE #1 9518
8.84 34.2
10,3957 ],286.1 4000 TN -80 TXP
Cases Description OD lint
)Olin) Top IRRBI
eel Depth o l Set Detroit INDn... vel a.. Greek, TaPTM1ne4
TIEBACK STRING 7
6.28 32.1
9,767.0 6,9076 2600 L80
TSHBIue
Gazing Description OD lint
JID (in) Ter (me)
Set Depth goal Sobel IIVD)vNLen IL. Gregg Tap Th.
INTERMEDIATE#2 SDL 7
628 9,754.6
12,026.0 7,897.1 26.00 L-80
Terris Blue
LINER
Liner Details
CONDUCTOR: se.] -1110
Top(Me) Top IlpeKe)
Top Incl I-) Irish wa
Com
rvomm.HD
(in)
9,754.8 6,900.1
52.91 SBE
Seal Bare Extension
7.375
NPKE,;Due
9787.1 6,9197
5291 SEAL ASSY
FeWhing Seal easy (5.76- seals in LES below)
6.170
---77W-9 6,9210
5291
HRD-E Liner Sexing Sleeve
7.735
SLEEVE
7 6,926.8
52.91 TU17K
HP Liner Quick ronneCtWJBHIlet Seals 7 32#
6.151
RURFue, ss]-zlmo
CONNECT
TenHds Blue
A 6,930.2
5291 INT CASING
Pup T' 26W L-80 Liner Terris Blue Liner
6276
11, 7,891.6
8287 INT CASING
7"32#L o Liner Terris Blue Casing joint
6.276
12, 1 7,896.3
83.29 STABILIZER
eamer Ace tabllizer nil Spline Pro le 7 32#-
6.080
MYS110 Total Blue
Casing Description OD lin)
I011n) Tan ItIKBI
9N OepIM1 (XKB) Shc Depin (rvm... WVLm g... Onaa Top Th.
ne.isa1RING. a2.1e.7ezD
PRODUCTION LINER 4112
3.96 11,864.2
16,090.3 7,954.8 12.611 L-80
TXP
Liner Details
Nome."Top
IRK!) ToplrvD)IBKeI
Tovtncl l'1 IMm Des
Lem
lion
11,864.2 7,876.
HIDPACKER
HRDEZXP SJS"BBE(16.1 ')
5.000
11,890.7 7.880.3
8235 HANGER
4-112"x7"Flex Lock Hgr H5218DxxTXP Pin
3.8]5
Tubing Strings
Tubing Descnplion 54inp Ma..
lDlin)
Top InNB)
sN Cep In..
5N 0epM TV -)I...
(Fir,
ones,
Top Canneclion
PRODUCTION 41/2
3.96
28.6
11,874.7
7.878.1
12 fi0
LA0
Tblue
TUBING
NTERME.41Eg1:30.1
Completion Details
ohs i
toptTop Incl
Nominal
Top(Inoun PI
Item des
Com
to an)
28.6 286 000
286 2
HANGER FMC 4-12'
Tubing Hanger 563
3 95
Due uFT: 1".a
2,0148 1,9212 32.98
NIPPLE NIPPLE,
LANDING, 412",X,3813".TSH Blue
3.813
11,405.9 7,7709 71.56 NIPPLE NIPPLE ITANDING 41 ", 3.913XN, TSH Blue veto PRO Plot, 3.750
ulpxE, 11,405.#
Body Installed @ 72° @11,427'
11,8594 7.875.9 81.65 N Locator No -GO 53S OD
3.930
LOCATOR
ll $ LOCATOR: 11 ,851P 4
-71'W4 7,876.0 8187
SEALASSY Seal Assembly
3.930
REAL ASSY; IiM3
Marginal Inserts
at
.9
N Topill
Top OV01valve
dii
Make
Model
OD (in)
Rery
Type
IBR,
Type
ponslxe
.s
TRO Run
IOseeR
Run D.b
Cmm
t 1,21.5
7706.8
CaM10
KBD
-it
GADUI-1
OPEN
12/192018
IN]ERMFDtOT%n RO
Notes: General & Safely
End D.
Annatxion
A]SY6RO2&0
Zons.
1114/2018NOTE.
View Schematic wl Alaska Schematic 10.0
PRODUCTION LINER: x.!81.2
-Weens
`
Operations Summary (with Timelog Depths)
LL MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
s tart Time
End Time
our (he)
Phase
Op Cotle
Adniry Cotle
Time P-T-X
Operation
Start Depth
(rt De
End Depth (flK8)
11/19/2018
11/19/2018
1.00
MIRU
MOVE
MOB
P
Prep rig for move, secure drain lines,
0.0
0.0
00:00
01:00
mobilize surface riser sections to rig
floor. Move pipe shed away.
11/19/2018
11/19/2018
1.00
MIRU
MOVE
MOB
P
Blow down Sub water, steam,
0.0
0.0
01:00
02:00
disconnect electrical/ service lines.
11/19/2018
11/19/2018
1.00
MIRU
MOVE
MOB
P
Move pits I motor complexes off MT6-
0.0
0.0
02:00
03:00
04.
11/19/2018
11/19/2018
3.00
MIRU
MOVE
MOB
P
Skid dg floor into move position, raise
0.0
0.0
03:00
06:00
windwalls and stompers. Back sub off
MT6-04. Spot wellhead and MPD
equipment on MT6-09.
Clean up around MT6-04.
11/19/2018
11/19/2018
2.00
MIRU
MOVE
MOB
P
Spot and shim sub over MT6-09.
0.0
0.0
06:00
08:00
Lower stompers and windwalls. Skid
dg floor into move position.
11/19/2018
11/19/2018
2.50
MIRU
MOVE
MOB
P
Spot and shim pits and motor
0.0
0.0
08:00
10:30
complexes.
11/19/2018
11/1912018
1.50
MIRU
MOVE
MOB
P
Rig up steam / electrical service lines.
0.0
0.0
10:30
12:00
Spot ball mill and pipeshed
complexes.
11/19/2018
11/19/2018
2.50
MIRU
MOVE
RURD
P
Rig up drain lines, mud lines to cellar
0.0
0.0
12:00
14:30
under rig floor. Prep pumps and pits
for drilling. Obtain RKS's. Function test
draworks and top drive. Complete rig
acceptance checklist.
Rig accepted @ 13:00 hrs, Rig on
high line power @ 14:10 hrs.
11/19/2018
11/19/2018
0.50
MIRU
MOVE
RURD
P
PJSM, Rig up surface riser.
0.0
0.0
14:30
15:00
11/19/2018
11/19/2018
2.00
MIRU
MOVE
RURD
P
N/U surface riser and flowline,
0.0
0.0
15:00
17:00
bleeder, holefill. SIMOPS- Take on
mud into rig pits.
11/19/2018
11/19/2018
0.25
MIRU
MOVE
BHAH
P
PJSM on M/U BHA#1
0.0
0.0
17:00
17:15
11/19/2018
11/19/2018
1.75
MIRU
MOVE
BHAH
P
P/U BHA#1 as per DD/MWD to 89',
0.0
89.0
17:15
19:00
tagged up on fill.
11/19/2018
11/19/2018
0.50
MIRU
MOVE
SFTY
P
Pre-Spud meeting with all parties.
89.0
89.0
19:00
19:30
11/19/2018
11/19/2018
0.25
MIRU
MOVE
CIRC
P
Fill conductor@ 5 bpm, check for
89.0
89.0
19:30
19:45
leaks, good.
11/19/2018
11/19/2018
0.25
MIRU
MOVE
SEQP
P
Pressure test mud line to 4000 psi,
89.0
89.0
19:45
20:00
good.
11/19/2018
11119/2018
0.75
MIRU
MOVE
DRLG
P
Clean out conductor to 115' MD @
89.0
115.0
20:00
20:45
525 gpm, 520 psi, 40 rpm. 2.5k Tq.
11/19/2018
11/19/2018
1.00
SURFAC
DRILL
DDRL
P
Drill from 115' MD to 183' MD, 525
115.0
183.0
20:45
21:45
gpm, 550 psi, 40 rpm, 3k Tq.
11/19/2018
11/19/2018
0.50
SURFAC
DRILL
BKRM
P
POOH from 183' MD to 68' MD.
183.0
68.0
21:45
22:15
Backreaming @ 525 gpm, 530 psi, 40
rpm. Confirmed scribe @ 68' MD.
11/19/2018 11111912018
0.75
SURFAC
DRILL
PULD
P
Set HWDP back, P/U and RIH
68.0
183.0
22:15
23:00
w/NMDC from 90' MD to 183' MD.
11/19/2018
11/20/2018
1.00
SURFAC
DRILL
DDRL
P
Drilling from 183' MD to 325' MD, 525
183.0
325.0
23:00
00:00
gpm, 550 psi, 40 rpm, 3k Tq. ADT=1.3
hrs, ART=1.3 hrs, TVD=325'
11/20/2018
11/20/2018
12.00
SURFAC
DRILL
DDRL
P
Drill ahead f/325'to 1,305' MD / 1,288'
325.0
1,305.0
00:00
12:00
TVD, ADT 9.1 Him. 700 gpm, 1490 psi,
PU wt 100 k, SIO wt 100 k, ROT wt
100 k, 70 rpm, Trq On/Off 4/1.8 k
ft/lbs, pumping nut plug/drill zone
sweeps to aid in hole cleaning.
Page 1123 ReportPrinted: 1212612018
Operations Summary (with Timelog uepths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Coda
Time P-T-X
O eration
p
(We)
End Depth (flKB)
11/20/2018
11/20/2018
11.00
SURFAC
DRILL
DDRL
P
Drill ahead f/1,305'to TO of 2,154'
1,305.0
2,154.0
12:00
23:00
MD / 2,037' TVD, ADT 8.2 Hrs, 859
gpm, 2590 psi, PU wt 117 k, SIO wt
112 k, ROT wt 115 k, 60 rpm, Trq
On/Off 5/2 k Nibs, pumping nut
plug/drill zone sweeps to aid in hole
cleaning.
11/20/2018
11/21/2018
1.00
SURFAC
CASING
CIRC
P
Pump sweep & circulate clean w/860
2,154.0
2,061.0
23:00
00:00
gpm, 2380 psi, 30 rpm, 2.5 k trq. Rack
back 1 stand f/2,154'to 2,061'
11/21/2018
11121/2018
2.00
SURFAC
CASING
CIRC
P
Pump sweeps & circulate clean for 5
2,061.0
1,7T8-0-
00:00
02:00
B/U total w/860 gpm, 2450 psi, 40
rpm, 2.5 k trq. Rack back 1 stand each
f/2,061'to 1,778'
11/21/2018
11/21/2018
0.25
SURFAC
CASING
OWFF
P
FIC (static) BID top drive
1,778.0
1,778.0
02:00
02:15
11/21/2018
11/21/2018
1.00
SURFAC
CASING
TRIP
P
POOH f/1,778'to 1,158'. Not able to
1,778.0
1,158.0
02:15
03:15
POOH thru base of permafrost. Not
able to slack off.
11/21/2018
11/21/2018
0.25
SURFAC
CASING
REAM
T
Ream in hole from 1,158'to 1,212'
1,158.0
1,308.0
03:15
03:30
w/400 gpm, 30 rpm. RIH on elevators
f/1,212'to 1,308'
11/21/2018
11/21/2018
0.50
SURFAC
CASING
BKRM
T
BROOH f/1,308'to 1,212'w/700 gpm,
1,308.0
1,212.0
03:30
04:00
1600 psi, 40 rpm, 1.5 k trq. Hole
unloaded significant amount of
cuttings.
11/21/2018
11/21/2018
0.25
SURFAC
CASING
TRIP
T
POOH f/1,212'to 1,117'. Drop Gyro
1,212.0
1,117.0
04:00
04:15
tool. B/D top drive.
11/21/2018
11/21/2018
2.25
SURFAC
CASING
TRIP
P
POCH f/1,117'to 90'. Rack back
1,117.0
90.0
04:15
06:30
HWDP, Jars & NMFC. Retrieve Gyro
tool.
11/21/2018
11/21/2018
0.50
SURFAC
CASING
CIRC
P
Pump nut pulg sweep to aid in
90.0
90.0
06:30
07:00
cleaning up BHA w/550 gpm. 780 psi,
40 rpm, 1 k trq
11/21/2018
11/21/2018
1.75
SURFAC
CASING
SHAH
P
LID BHA as per Baker reps
90.0
0.0
07:00
08:45
11/21/2018
11/2112018
1.00
SURFAC
CASING
SHAH
P
Clean& clear floor of BHA tools&
0.0
0.0
08:45
09:45
equipment.
11/21/2018
11/21/2018
2.75
SURFAC
CASING
RURD
P
R/U to run casing. R/U Volant, bale
0.0
0.0
09:45
12:30
extensions, slips & elevators.
11/21/2018
11/21/2018
2.00
SURFAC
CASING
PUTS
P
PJSM on casing. M/U shoe track &
0.0
161.0
12:30
14:30
check floats (good).
11/21/2018
11/21/2018
3.50
SURFAC
CASING
PUTB
T
Had to swap jts 5,6, & 7 & collar of jt
161.0
161.0
14:30
18:00
#4 due to BTC casing cross threading
11/21/2018
11/21/2018
4.50
SURFAC
CASING
PUTB
P
RIH 13-3/8" 68# L-80 BTC/TXP casing
161.0
1,261.0
18:00
22:30
f/161'to 1,261' Washed down @ 3
bpm f/1,100'to 1,261'
11/21/2018
11/21/2018
0.50
SURFAC
CASING
CIRC
P
Circ B/U & Gond mud. Stage flow rate
1,261.0
1,261.0
22:30
23:00
up to 5 bpm, 130 psi. Reciprocate
pipe.
11/21/2018
11/22/2018
1.00
SURFAC
CASING
PUTS
P
Cont. RIH 13-3/8" 68# L-80 TXP
1,261.0
1,540.0
23:00
00:00
casing f/1,261' to 1,540'. SIO wt 105 k
11/22/2018
11/22/2018
2.00
SURFAC
CASING
PUTB
P
Cont. RIH 13-3/8" 68# L-80 TXP
1,540.0
2,067.0
00:00
02:00
1
1
casing (/1,540' to 2,067' SIO wt 130 k
11/22/2018
11/22/2018
1.00
SURFAC
CASING
HOSO
P
M/U hanger & landing jt. Wash down
2,067.0
2,146.0
02:00
03:00
w/3 bpm @ 200 psi & land on hanger
@ 2,146'. P/U wt 157 k, SIC, wt 132 it.
11/22/2018
11/22/2018
1.50
SURFAC
CEMENT
CIRC
P
Circ& cond mud for cement job.
2,146.0
2,146.0
03:00
04:30
Stage flow rate up to 8 bpm @ 220
psi. Reciprocate pipe 10'
11/22/2018
11/22/2018
0.50
SURFAC
CEMENT
RURD
P
BID top drive. R/U cement lines.
2,146.0
2,146.0
04:30
05:00
Page 2/23 Report Printed: 12/26/2018
Operations Summary (with Timelog Depths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Start Time
End Time
our (hr)
Phase
Op Cotle
AgWity Cale
Time P -T -X
Operation
Start Depth
(ftKB)
End Depth (aKB)
11/22/2018
11/22/2018
2.50
SURFAC
CEMENT
CIRC
P
Circ & cond mud for cement job w/8
2,146.0
2,146.0
05:00
07:30
bpm @ 400 psi. Reciprocate pipe 10'.
SIMOPS - PJSM on cementing.
11/22/2018
11/22/2018
3.75
SURFAC
CEMENT
CMNT
P
Dowell pump 3 bbls H2O & PT to
2,146.0
2,146.0
07:30
11:15
3500 psi (good). Dowell pump 100.2
bbls 10.3 ppg mud push at 4 bpm.
Shut down & drop bottom plug. Dowell
pump 330 bbls 11.0 ppg 1.95 ft3/sx
yield LiteCRETE lead cement and
68.3 bbls 15.8 ppg 1.16 ft3/sx yield tail
cement @ 4 - 5 bpm. Drop top plug.
Dowell pump 20 bbls H2O. Rig
displace with 289 bbls 12,893 stks 10
ppg DrillPlex with 8 bpm 1850 psi.
Reduce pumps to 3 bpm / 550 psi. last
10 bbls. Bump plug, pressure 500 psi
over to 1100 psi for 5 min. Check
floats. FIC good. CIP @ 11:15 Hrs.
Calculate 154 bbls good cement to
surface. Full returns during cement
job.
11/22/2018
11/22/2018
2.00
SURFAC
CEMENT
RURD
P
Flush riser w/black water. RID Volant
0.0
0.0
11:15
13:15
& casing running tools & equipment.
UD landing jt.
11/22/2018
11/22/2018
1.50
SURFAC
CEMENT
RURD
P
R/D surface riser assy. N/D speed lock
0.0
0.0
13:15
14:45
head adaptor. SIMOPS - clean pits.
11/22/2018
11/22/2018
0.75
SURFAC
WHDBOP
NUND
P
N/U well head & test to 1000 psi for 10
0.0
0.0
14:45
15:30
min (good). SIMOPS - clean pits.
11/22/2018
11/22/2018
2.25
SURFAC
WHDBOP
NUND
P
N/U BOPE & N/U choke/kill lines.
0.0
0.0
15:30
17:45
SIMOPS - clean pits.
11/22/2018
11/22/2018
2.75
SURFAC
WHDBOP
MPDA
P
N/U RCD clamps & orbit valve. N/U
0.0
0.0
17:45
20:30
flow line & flow box. Install annulus
valves. Obtain RKB's. Install trip
nipple. Install KatchKan.
11/22/2018
11/22/2018
1.50
SURFAC
WHDBOP
MPDA
P
R/U test equipment. Test MPD
0.0
0.0
20:30
22:00
equipment 250/1500 psi. RID testing
equipment & in stall trip nipple.
SIMOPS - M/U choke & flare lines.
11/22/2018
11/22/2018
0.50
SURFAC
WHDBOP
RURD
P
Install test jt & R/U to test BOPE
0.0
0.0
22:00
22:30
11/22/2018
11/23/2018
1.50
SURFAC
WHDBOP
BOPE
P
Test BOPE w/5" lest jt. Annular 250
0.0
0.0
22:30
00:00
psi 5 min 12500 psi 10 min. Test 3-
1/2" X 6 VBR's, choke valves 1 - 14,
Man IBOR HCR kill & dart valve 250
psi 5 min 13500 psi 10 min.
11/23/2018
11/23/2018
4.50
SURFAC
WHDBOP
BOPE
P
Test BOPE w/5 test joint. Annular 250
0.0
0.0
00:00
04:30
psi for 5 min 12500 psi for 10 min,
Remaining test 250 psi for 5 min /
3500 psi for 10 min. 4" Demco, Choke
valves 1 - 14; IBOP's, Choke needle
valve, Upper/lower 3-1/2" X 6" VBR's
& blind rams, 5" Darf/FOSV, HCR /
Man choke/kill, Accumulator test,
Initial 3,050 psi, final 1,490 psi, 1st
200 psi recharge = 31 sec's, full
recharge = 161 seconds. Nitrogen
Bottles x4 = 2,050 psi. Gas alarms
and PVT alarms tested. Draw down on
chokes U1100 psi. AOGCC Brian
Bixby & BLM Mutasim Elganzoory
waived witness.
11/23/2018
11/23/2018
1.00
SURFAC
WHDBOP
RURD
P
R/D testing equipment. B/D lines. Pull
0.0
0.0
04:30
05:30
test plug & set 12.375" ID wear ring.
11/23/2018
11/23/2018
3.50
SURFAC
CEMENT
BHAH
P
PJSM. M/U 12-1/4" BHA#2 as per
0.0
157.0
05:30
09:00
Bakerreps
Page 3123 Report Printed: 1 212 612 01 8
Operations Summary (with Timelog Depths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
St rt DO
State rime
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
( B)
Ertl Depth (ftKB
11/2312018
11/23/2018
2.50
SURFAC
CEMENT
TRIP
P
RIH fl157'to 1,933'
157.0
1,933.0
09:00
11:30
11123/2018
11/23/2018
0.50
SURFAC
CEMENT
DHEO
P
Shallow hole test MWD tools.
1,933.0
1,933.0
11:30
12:00
11/23/2018
11/23/2018
1.50
SURFAC
CEMENT
SLPC
P
Slip & cut drill line. Service rig.
1,933.0
1,933.0
12:00
13:30
11/23/2018
11/23/2018
1.50
SURFAC
CEMENT
PRTS
P
R/U testing equip. Test casing to 2500
1,933.0
1,933.0
13:30
15:00
psi & chart for 30 min. Rtd testing
equip.
11/23/2018
11/23/2018
5.00
SURFAC
CEMENT
DRLG
P
Drill out cement & shoe track to 2,154'
1,933.0
2,154.0
15:00
20:00
w/450 - 600 gpm, 500 - 800 psi, 40 -
80 rpm, 2 - 5 k trq. Displace to new
10.5 ppg LSND on the fly.
11/23/2018
11/23/2018
0.25
SURFAC
CEMENT
DDRL
P
Drill 20' new formation f/2,154'to
2,154.0
2,174.0
20:00
20:15
2,174' MD / 2,054' TVD w/600 gpm,
830 psi, 80 rpm„ 5 - 6 k trq.
11/23/2018
11/23/2018
0.25
SURFAC
CEMENT
BKRM
P
BROOH f/2,174'to 2,120'& circ hole
2,174.0
2,120.0
20:15
20:30
clean w/600 gpm, 800 psi, 80 rpm„ 5 -
6 k trq.
11/23/2018
11/23/2018
0.75
SURFAC
CEMENT
FIT
P
R/U testing equip. Attempt FIT to 18.0
2,120.0
2,120.0
20:30
21:15
ppg. LOT to 15.6 ppg 1540 psi. RID
testing equip.
11/23/2018
11/23/2018
0.25
INTRMI
DRILL
REAM
P
W&R f/2,120'to 2,174'w/800 gpm,
2,120.0
2,174.0
21:15
21:30
1
1350 psi, 80 rpm, 3 k trq
11/23/2018
11/24/2018
2.50
INTRMI
DRILL
DDRL
P
Drill ahead f/2,174'to 2,404' MD /
2,174.0
2,404.0
21:30
00:00
2,242' TVD, ADT 1.8 Hrs, ECD 11.11
ppg, 850 gpm, 1640 psi, P/U wt 127 k,
S/O wt 122 k, ROT w! 125 k, 150 rpm,
Trq On/Off 5/3 k ftllbs
11/24/2018
11/24/2018
12.00
INTRMI
DRILL
DDRL
P
Drill ahead f2,404'to 3,951'MD 1
2,404.0
3,951.0
00:00
12:00
3,379' TVD, ADT 9.2 Hrs, ECD 11.30
ppg, 920 gpm, 2200 psi, P/U wt 133 k,
S/O wt 125 k, ROT wt 131 k, 180 rpm,
Trq On/Off 7/3 k fttlbs
11/24/2016
11/24/2018
7.25
INTRMI
DRILL
DDRL
P
Drill ahead f/3,951'to 4,949' MD /
3,951.0
4,949.0
12:00
19:15
4,007' TVD, ADT 6 Hrs, ECD 11.33
ppg, 920 gpm, 2650 psi, PIU wt 138 k.
S/O wt 128 k, ROT wt 135 k, 180 rpm,
Trq OnlOff 8.5/3 k ft/lbs
11124/2018
11/24/2018
1.00
INTRMI
DRILL
CIRC
P
BROOH 2jts while circulating B/U
4,949.0
4,949.0
19:15
20:15
f/4,949' to 4,885'w/925 gpm, 2650 psi,
100 rpm. Install 10-5/8" ghost reamer.
(Above 1st single on stand # 46)
Ream back in hole to resume drilling
ahead.
11124/2018
11/25/2018
3.75
INTRMI
DRILL
DDRL
P
Drill ahead f/4,949'to 5.424' MD /
4.949.0
5,424.0
20:15
00:00
4,293' TVD, ADT 2.9 His, ECD 11.37
ppg, 925 gpm, 2700 psi, P/U wt 160 k,
S/O wt 140 k, ROT wt 145 k, 180 rpm,
Trq On/Off 10/5 k f albs
11/25/2018
11/25/2018
12.00
INTRMI
DRILL
DDRL
P
Drill ahead f/5,424'to 6,964' MD /
5.424.0
6,964.0
00:00
12:00
5,219' TVD, ADT 9.2 Hrs, ECD 11.4
ppg, 925 gpm, 2882 psi, P/U wt 185 k,
SID wt 151 k, ROT wt 165 k, 180 rpm.
Trq On/Off 13/5.5 k ft/lbs
11/25/2018
11/26/2018
12.00
INTRMI
DRILL
DDRL
P
Drill ahead f/6,964'to 8,540' MD /
6,964.0
8,540.0
12:00
00:00
6,168' TVD, ADT 9.5 Hrs, ECD 11.47
ppg, 925 gpm, 2780 psi, P/U wt 215 k,
S/O wt 155 k, ROT wt 185 k, 180 rpm,
Trq On/Off 16/9 k ft/lbs
Page 4/23 Report Printed: 12/26/2018
Operations Summary (with Timelog Depths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Our(hr)
Phase
Op Code
Acbmly Code
Time P -T -X
Operation
(ftKB)
Pstl Depth (itKa)
11/26/2018
11/26/2018
6.00
INTRMI
DRILL
DDRL
P
Drill ahead f/8,540'to 9,373' MD / 6.'
8,540.0
9,373.0
00:00
06:00
TVD, ADT 4.5 Hrs, ECD 11.47 ppg,
925 gpm, 2800 psi, P/U wt 230 k, SIO
wt 158 k, ROT wt 188 It, 180 rpm, Trq
On/Off 19/9.5 k ft/lbs
11/26/2018
11/26/2018
1.00
INTRMI
DRILL
BKRM
P
BROOH f/9,373'to 9,277'w/925 gpm,
9,373.0
9,277.0
06:00
07:00
2860 psi, 180 rpm, 10 k trq
11/26/2018
11/26/2018
0.25
INTRMI
DRILL
OWFF
P
FIC (static) - B/D top drive.
9,277.0
9,277.0
07:00
07:15
11/26/2018
11/26/2018
0.50
INTRMI
DRILL
MPDA
P
PJSM. Pull trip nipple & install RCD
9,277.0
9,277.0
07:15
07:45
1
bearing.
11/26/2018
11/26/2018
0.50
INTRM1
DRILL
REAM
P
W&R f/9,277'to 9,373'& break in
9,277.0
9,373.0
07:45
08:15
RCD bearing.
11/26/2018
11/26/2018
3.75
INTRMI
DRILL
DDRL
P
Drill ahead f/9,373'to 9,844' MD /
9,373.0
9,844.0
08:15
12:00
6,954' TVD, ADT 2.7 Hrs, ECD 11.50
ppg, 925 gpm, 2970 psi, P/U wt 244 k,
S10 wt 160 k, ROT wt 190 k, 180 rpm,
Trq On/Off 21.5/10.5 it ff/Ibs. Holding
back pressure on connections.
11/26/2018
11/26/2018
4.75
INTRMI
DRILL
DDRL
P
Drill ahead f/9,844'to 10,405' MD /
9,844.0
10,405.0
12:00
16:45
7,292' TVD, ADT 3.1 Hrs, ECD 11.41
ppg, 925 gpm, 3230 psi, P/U wt 255 k,
S/0 wt 170 k, ROT wt 205 k, 180 rpm,
Trq On/Off 21/16 k Nlbs. Holding back
pressure on connections.
11/26/2018
11/26/2018
6.00
INTRMI
CASING
CIRC
P
Circ & cond mud for B/U w/925 - 944
10,405.0
10,129.0
16:45
22:45
gpm, 2900 - 3200 psi, 180 - 100 rpm.
Rack back 1 stand every 2 B/U
fit 0,405'to 10,129'
11/26/2018
11/26/2018
0.50
INTRMI
CASING
OWFF
P
FIG(static)- SIMOPS - Line up MPD
10,129.0
10,129.0
22:45
23:15
to StripOOH
11/26/2018
11/27/2018
0.75
INTRM1
CASING
SMPD
P
StripOOH f/10,129'to 9,846' as per
10.129.0
9,846.0
23:15
00:00
MPD schedule.
11/27/2018
11/27/2018
2.25
INTRMI
CASING
SMPD
P
StripOOH f/9,846'to 7,790' as per
9,846.0
7,790.0
00:00
02:15
MPD schedule. Various tight spots w/
30 k over pull. Not able to make
forward progress past 7,790'. Work
thru several times with minimal
success. Decision made to back ream.
11/27/2018
11/27/2018
0.50
INTRMI
CASING
TRIP
P
RIH f/7,790'to 8,080'. PJSM on
7,790.0
8,080.0
02:15
02:45
installing trip nipple.
11/27/2018
11/27/2018
0.50
INTRMI
CASING
MPDA
P
F/C (static). Pull RCD & install trip
7,790.0
8,080.0
02:45
03:15
nipple.
11/27/2018
11/27/2018
8.75
INTRMI
CASING
BKRM
P
BROOH f/8,080'to 5,238'w/925 gpm,
8.080.0
5,238.0
03:15
12:00
2820 - 2500 psi, 120 rpm, 11.5 - 9 k
trq. Hole un -loading significant amount
of cuttings & caving's periodically.
11/27/2018
11/28/2018
12.00
INTRM1
CASING
BKRM
P
BROOH f/5,238'to 1,275'w/925 gpm,
5,238.0
1,275.0
12:00
00:00
2500 - 1800 psi, 120 - 140 rpm, 10 - 4
k trq. Hole attempting to pack off
through out with significant amount of
cuttings/cavings on shakers. The hole
un -loaded softball & football size clay
balls & caving's at 2600'. Performed
275 bbl dilution @ 4,000'. Pumped
sweeps to aid in hole cleaning.
11/28/2018
11/28/2018
1.50
INTRMI
CASING
BKRM
P
BROOH f/1,275'to 616'w/920 gpm,
1,275.0
616.0
00:00
01:30
1620 psi, 140 rpm, 1.5 k trq. Hole
continued un -loading softball size clay
balls & caving's.
11/28/2018
11/28/2018
2.25
INTRMI
CASING
CIRC
P
Pump high vis nut plug weighted
616.0
585.0
01:30
03:45
sweep & circ & cond to 10.5 ppg in/out
w/920 gpm, 1570 psi, 30 rpm.
Reciprocate pipe to 585'
Page 5123 Report Printed: 1 212 6/2 01 8
Operations Summary (with Timelog Depths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
StartTime
End T,me
our (hr)
Phae
O Code
AOvl Code
Time P -T-%
Operation on
Start Depth
(n Ke)
Entl Depth (ftKB)
11/28/2018
11/28/2018
0.25
INTRMI
CASING
OWFF
P
FIC (static) SIMOPS - B/D top drive &
585.0
585.0
03:45
04:00
PJSM on BHA
11/28/2018
11/28/2018
0.75
INTRMI
CASING
TRIP
P
POOH f/585 to 157'. Rack back
585.0
157.0
04:00
04:45
HWDP & Jars
11/28/2018
11/28/2018
1.25
INTRMI
CASING
SHAH
P
LID BHA as per Baker reps f/157'
157.0
0.0
04:45
06:00
11/28/2018
11/28/2018
1.25
INTRMI
CASING
WWWH
P
Pull wear ring. M/U Johnny Wacker&
0.0
0.0
06:00
07:15
1
1
flush stack 2X
11/28/2018
11/28/2018
2.25
INTRMI
CASING
BOPE
P
PJSM-Change out upper pipe rams to
0.0
0.0
07:15
09:30
9 5/8". Set test plug & R/U to test
ROPE. SIMOPS - Clean & clear floor.
Mobilize casing running tools to rig
floor.
11/28/2018
11/28/2018
1.50
INTRM1
CASING
BOPE
P
Test annular preventer to 250 for 5
0.0
0.0
09:30
11:00
min / 12500 psi for 10 min. Test upper
pipe rams to 250 for 5 min 113500 psi
for 10 min.
11/28/2018
11/28/2018
0.50
INTRMI
CASING
BOPE
P
RID testing equipment. Set 13.125"
0.0
0.0
11:00
11:30
1
1
wear ring.
11/28/2018
11/28/2018
2.00
INTRMI
CASINGRURD
P
Dummy run hanger. R/U to run casing.
0.0
0.0
11:30
13:30
R/U Volant, spider's & elevators.
11/28/2018
11/29/2018
10.50
INTRMI
CASING
PUTB
P
PJSM on running casing. M/U 9-5/8"
0.0
6,030.0
13:30
00:00
40# TN -80 TXP shoe track to 160'.
Check floats (good). RIH 9-5/8" 40#
TN -80 TXP casing f/160' to 6.030'
11/2912018
11/29/2018
6.50
INTRMI
CASING
PUTS
P
RIH 9-518" 40# TN -80 TXP casing
6,030.0
9,043.0
00:00
06:30
f/6,030' to 9,043'. S/O wt starting to
diminish w/25 k drag. P/U wt 335 k /
SIC, wt 205 k
11/29/2018
11/29/2018
1.25
INTRMI
CASING
CIRC
P
Break circ & stage pumps up to 4.5
9,043.0
9.076.0
06:30
07:45
bpm 1520 psi. Circ & cond mud f/
9,043'to 9,076'
11/29/2018
11/29/2018
5.75
INTRMI
CASING
PUTS
P
Cont. RIH 9-5/8" 40# TN -80 TXP
9,076.0
10,358.0
07:45
13:30
casing while washing down w/3 bpm /
600 psi f/9,076' to 10,358'
11/29/2018
11/29/2018
0.50
INTRMI
CASING
HOSO
P
M/U hanger& landing jt. Wash down
10,358.0
10,395.0
13:30
14:00
w/3 bpm 1600 psi & land on hanger
10,395'(S/0 wt 200 k, not able to
work pipe up)
11/29/2018
11/29/2018
3.25
INTRMI
CEMENT
CIRC
P
Break circ & stage pumps up to 8
10,395.0
10,395.0
14:00
17:15
bpm 1580 psi. Circ & cond mud for
cementjob.
11/29/2018
11/29/2018
0.50
INTRMI
CEMENT
RURD
P
Shut down, FIC static. Blow down top
10,395.0
10,395.0
17:15
17:45
drive, Rig up cement hose and 1502
equipment to cement line. Break circ
w/8 bpm / 840 psi.
11/29/2018
11/29/2018
4.25
INTRMI
CEMENT
CMNT
P
Dowell pump 1.2 bbls H2O & PT to
10,395.0
10,395.0
17:45
22:00
4000 psi (good). Dowell pump 60 bbls
11.5 ppg mud push at 4 bpm. Shut
down & drop bottom plug. Dowell
pump 36.2 bbls 12.2 ppg 2.3 fl3/sx
yield Class G lead cement and 42.4
bbls 15.8 ppg 1.16 R3/sx yield tail
cement @ 4 bpm. Drop 2 top plugs.
Dowell pump 20 bbls H2O. Rig
displace with 762 bbls (7,640 stks Q
95%) 10.5 ppg LSND with 8 bpm / 500
- 850 psi. Reduce pumps to 3 bpm /
570 psi. last 10 bbls. Bump plug,
pressure 500 psi over to 1100 psi for 5
min. Check floats. F/C good. CIP @
21:50 Hrs. Full returns during cement
job.
Page 6123 Report Printed: 12/26/2018
Operations Summary (with Timelog bepths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Start Time
EM Time
Dur(hr)
Phase
OpCMe
Activity COCe
Time P-T-X
Operation
start Depth
(flKB)
EM Depth(fiKB)
11/29/2018
11/29/2018
1.25
INTRMI
CEMENT
OWFF
P
Monitor well. Static. SIMOPS - RID
0.0
0.0
22:00
23:15
Volant & LID landing jt.
11/29/2018
11/30/2018
0.75
INTRMI
CEMENT
RURD
P
Drain stack & R/U to flush stack
0.0
0.0
23:15
00:00
11/30/2018
11/30/2018
1.00
INTRMI
CEMENT
WWWH
P
M/U Johnny Wacker &flush stack.
0.0
0.0
00:00
01:00
11/30/2018
11/30/2018
0.75
INTRMI
CEMENT
WWSP
P
FMC Pull thin wall wear ring. Set 9-
0.0
0.0
01:00
01:45
5/8" packoff and test to 5000 psi for 10
minutes, CPAI witnessed (good)
11/30/2018
11/30/2018
4.25
INTRMI
CEMENT
NUND
P
PJSM on N/D BOPE. De-energize
0.0
0.0
01:45
06:00
Koomy. Remove mouse hole. Break
choke connection. Pull trip nipple &
N/D flow line, flow box, hole fill &
bleeder lines. Install 7" spool & test
void to 5000 psi (good). NIL BOPE on
7" spool.
11/30/2018
11/30/2018
2.50
INTRMI
CEMENT
MPDA
P
R/U MPD package. M/U flow box &
0.0
0.0
06.00
08:30
NIL hole fill bleeder lines. M/U choke
Pines. Install trip nipple.
11/30/2018
11/30/2018
3.75
INTRMI
WHDBOP
RURD
P
C/O upper rams to 4-1/2" X 7" VBR's.
0.0
0.0
08:30
12:15
Obtain RKB's. Grease choke manifold.
Install mouse hole. Set test plug. Fill
stack w/H20. Purge air from system.
R/U to test BOPE.
11/30/2018
11/30/2018
7.00
INTRMI
WHDBOP
BOPE
P
Test BOPE w/4", 5", & 7" test joints.
0.0
0.0
12:15
19:15
Annular 250 psi for 5 min 12500 psi
for 10 min, Remaining test 250 psi for
5 min 13500 psi for 10 min. 4" Demco,
Choke valves 1 - 14; IBOP's, Choke
needle valve, Upper 4-1/2" X 7"
VBR's, Lower 3-1/2" X 6" VBR's &
blind rams, 5" Dart/FOSV, HCR / Man
choke/kill, Accumulator test, Initial
3,000 psi, final 1,450 psi, 1 at 200 psi
recharge = 37 sec's, full recharge =
160 seconds. Nitrogen Bottles x4 =
2,100 psi. Gas alarms and PVT
alarms tested. Draw down on chokes
U1100 psi. AOGCC Guy Cook waived
witness of test.
11/30/2018
11/30/2018
2.25
INTRMI
WHDBOP
RURD
P
RID testing equipment. B/D lines.
0.0
0.0
19:15
21:30
Install 8.8125" wear ring. SIMOPS -
R/U lines on BPA. Stage BHA tools &
equipment.
11/30/2018
11/30/2018
1.00
INTRMI
CEMENT
SFTY
T
Clean up centrifugal room & pump
0.0
0.0
21:30
22:30
room from spill. ACS inspect mat
boards.
11/30/2018
11/30/2018
0.50
INTRMI
CEMENT
BHAH
P
M/U 8-3/4" clean out/kick off BHA as
0.0
399.0
22:30
23:00
per Baker reps.
11/30/2018
12/1/2018
1.00
INTRMI
CEMENT
TRIP
P
RIH f/399'to 1,814'
399.0
1,814.0
23:00
00:00
12/1/2018
12/1/2018
5.00
INTRMI
CEMENT
TRIP
P
RIH V1,814'to 10,000'
1,814.0
10,000.0
00:00
05:00
12/1/2018
12/1/2018
0.50
INTRMI
CEMENT
CIRC
P
Circ & cond w/350 gpm, 890 psi
10,000.0
10,090.0
05:00
05:30
f/10,000' to 10,090'
12/1/2018
12/1/2018
2.00
INTRMI
CEMENT
PRTS
P
B/D top drive. R/U to test casing to
10,090.0
10,090.0
05:30
07:30
3500 psi & chart for 30 min (good),
RIO testing equipment.
12/1/2018
12/1/2018
1.00
INTRMI
CEMENT
SLPC
P
Slip &cut drill line.
10,090.0
10,090.0
07:30
08:30
12/1/2018
12/1/2018
1.00
INTRM1
CEMENT
COCF
P
W&R f/10,090'& tag TOC @ 10,312'
10,090.0
10,312.0
08:30
09:30
I
w/400 gpm, 1190 psi.
Page 7123 ReportPrinted: 1212612018
Operations Summary (with Timelog Uepths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
seen Depth
Start Time
End Time
Dur m
( )
Phase
Op Code
Activity Code
Time P -T -X
Operaton
(fd(B)
End Depth (RKB)
12/1/2018
12/1/2018
2.50
INTRMI
CEMENT
DRLG
P
Drill shoe track & rat hole to 10,405'
10,312.0
10,405.0
09:30
12:00
w/550 gpm, 1760 psi, 40 rpm, 18 k trq.
Hole attempting to pack off while
working thru shoe.
12/1/2018
12/1/2018
0.50
INTRMI
CEMENT
REAM
P
W&R & clean up shoe w/500 gpm.
10.405.0
10,370.0
12:00
12:30
1550 psi, 60 rpm, 14 k lrq
12/1/2018
12/1/2018
1.00
INTRMI
CEMENT
DISP
P
Displace to new 10.8 ppg -SND w/500
10,370.0
10,370.0
12:30
13:30
1
1
gpm, 1600 - 1500 psi, 60 rpm, 13 k trq
12/1/2018
12/1/2018
0.50
INTRMI
CEMENT
CIRC
P
SPR's. Wash down f/10,370'to
10,370.0
10,405.0
13:30
14:00
10,405'w/500 gpm, 1500 psi, 60 rpm,
13ktrq
12/1/2018
12/1/2018
1.00
INTRMI
CEMENT
DDRL
P
Drill ahead f/10,405'to 10,425' MD /
10,405.0
10,425.0
14:00
15:00
7,303' TVD, ADT =.6 Hrs, 500 gpm,
1500 psi, PU wt 268 k, SO wt 148 k,
ROT wt 184 k, 60 rpm, Tr On/Off 14/
13 k ft/lbs
12/1/2018
12/1/2018
1.00
INTRMI
CEMENT
CIRC
P
Circ & cond mud for FIT & rack back 1
10,425.0
10,370.0
15:00
16:00
stand f/10,425'to 10,370' w/500 gpm,
1550 psi, 60 rpm, 13 k trq
12/1/2018
12/1/2018
0.25
INTRMI
CEMENT
OWFF
P
F/C (static)
10,370.0
10,370.0
16:00
16:15
12/1/2018
12/1/2018
1.00
INTRMI
CEMENT
FIT
P
R/U testing equipment. FIT to 14.0
10,370.0
10,370.0
16:15
17:15
ppg @ 1220 psi. R/D testing
equipment.
12/1/2018
12/1/2018
0.75
INTRM2
DRILL
MPDA
P
Pull trip nipple & install RCD bearing.
10,370.0
10,370.0
17:15
18:00
SPR's
12/1/2018
12/1/2018
0.25
INTRM2
DRILL
REAM
P
W&R f/10,370'to 10,425' w/500 gpm,
10,370.0
10,425.0
18:00
18:15
1500 psi, 60 rpm, 13 k trq
12/1/2018
12/1/2018
2.00
INTRM2
DRILL
DDRL
P
Drill ahead SDL rat hole f/10,425' to
10,425.0
10,485.0
18:15
20:15
10,485' MD / 7,339' ND, ADT = 1.6
Hrs, 500 gpm, 1500 psi, PU wt 250 k,
SO wt 150 k, ROT wt 190 k, 60 rpm,
Trq On/Off 14/ 13 k fUlbs
12/1/2018
12/1/2018
1.75
INTRM2
CSGDRL
BKRM
P
W&R & clean up rat hole 2X w/500 -
10,485.0
10.373.0
20:15
22:00
600 gpm, 1550 - 2440 psi, 60 rpm,
12.5 k trq. Work stand out of hole
f/10,485'to inside casing shoe @
10,373'.
12/1/2018
12/1/2018
1.50
INTRM2
CSGDRL
CIRC
P
Circ &cond f/l 0.373'to 10,278'w/600
10,373.0
10,278.0
22:00
23:30
gpm, 2440 psi, 60 rpm, 12 k trq.
12/1/2018
12/2/2018
0.50
INTRM2
CSGDRL
OWFF
P
F/C (static) SIMOPS - B/D top drive &
10,278.0
10,278.0
23:30
00:00
line up MPD to StripOOH.
12/2/2018
12/2/2018
1.25
INTRM2
CSGDRL
SMPD
P
StripOOH f/10,278' to 9,338' as per
10,278.0
9,338.0
00:00
01:15
MPD schedule.
12/2/2018
12/2/2018
0.25
INTRM2
CSGDRL
CIRC
P
Pump dry job
9,338.0
9,338.0
01:15
01:30
12/2/2018
12/2/2018
3.50
INTRM2
CSGDRL
SMPD
P
StripOOH (/9,338'to 5,106' as per
9,338.0
5,106.0
01:30
05:00
MPD schedule.
12/2/2018
12/2/2018
1.25
INTRM2
CSGDRL
CIRC
P
Circ & cond mud w/415 gpm, 980 psi.
5,106.0
5,106.0
05:00
06:15
10.8 ppg In/Out
12/2/2018
12/2/2018
2.50
INTRM2
CSGDRL
SMPD
P
StripOOH f/5,106'to 1,056' as per
5,106.0
1,056.0
06:15
08:45
MPD schedule.
12/2/2018
12/2/2018
0.25
INTRM2
CSGDRL
OWFF
P
F/C (static) SIMOPS - PJSM on
1,056.0
1,056.0
08:45
09:00
installing trip nipple.
12/2/2018
12/2/2018
0.50
INTRM2
CSGDRL
MPDA
P
Pull RCD & install trip nipple.
1,056.0
1,056.0
09:00
09:30
12/2/2018
12/2/2018
0.75
INTRM2
CSGDRL
TRIP
P
POOH f/1,05610 217' (Rack back
1,056.0
217.0
09:30
10:15
HWDP & jars)
12/2/2018
12/2/2018
0.25
INTRM2
CSGDRL
OWFF
P
F/C (static) SIMOPS - PJSM on BHA
217.0
217.0
10:15
10:30
12/2/2018
12/2/2018
1.00
INTRM2
CSGDRL
SHAH
P
UD BHA as per Baker reps.
217.0
0.0
10:30
11:30
Page 8123 ReportPrinted: 12/2612018
operations Summary (with Timelog Depths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Stert Time
EM Time
our (hr)
Phase
Op Calle
Activity GO
Time P -T -X
Operation
Steil Deprh
(ftKB)
End Depth (flKB)
12/2/2018
12/2/2018
1.25
INTRM2
CSGDRL
BHAH
P
Clean & clear floor of BHA tools &
0.0
0.0
11:30
12:45
equipment. P/U flow diverter & M/U to
stab & float sub. Prep BHA for SOL.
12/2/2018
12/2/2018
3.50
INTRM2
CSGDRL
BHAH
P
M/U 6" X 8-3/4" SDL inner string BHA
0.0
0.0
12:45
16:15
as per Baker reps & rack back in
derrick.
12/2/2018
12/2/2018
1.50
INTRM2
CSGDRL
RURD
P
R/U to run liner. R/U double stack
0.0
0.0
16:15
17:45
1
1
tongs, torque turn, slips & elevators.
12/2/2018
4.00
INTRM2
CSGDRL
PUTB
P
PJSM. M/U 7" 32# L-80 Tanana Blue
0.0
2,223.0
17:45
1121212018
21:45
liner to 2223'. (C/O collar on jt #7 &
swapped out jt #8) PU wt 105 k / SO
wl 100 k
12/2/2018
12/2/2018
1.00
INTRM2
CSGDRL
RURD
P
R/D liner running equipment. & torque
0.0
0.0
21:45
22:45
turn. R/U false table. M/U 4" handling
equipment. UD running tool.
12/2/2018
12/3/2018
1.25
INTRM2
CSGDRL
BHAH
P
M/U Baker rotary steerable inner
0.0
82.0
22:45
00:00
string BHA to 82'. (Load sources)
12/3/2018
12/3/2018
0.50
INTRM2
CSGDRL
BHAH
P
Cont. M/U Baker rotary steerable inner
82.0
181.0
00:00
00:30
1
1
1 string BHA f/82'to 181'.
12/3/2018
12/3/2018
0.25
INTRM2
CSGDRL
SFTY
P
RIH 1 stand of drill pipe f/181' to 275'
181.0
275.0
00:30
00:45
& perform SDL kick drill with both
drilling crews.
12/3/2018
12/3/2018
1.25
INTRM2
CSGDRL
TRIP
P
RIH w/4" DP inner string to 2,321'
275.0
2,321.0
00:45
02:00
12/3/2018
12/3/2018
0.75
INTRM2
CSGDRL
HOSO
P
M/U single stand of 4" DP & No go out
2,321.0
2.321.0
02:00
02:45
on depth w/10 k WOB. Pull out of hole
& rack back same. M/U space out
pups. SIMOPS - C/O handling
equipment.
12/3/2018
12/3/2018
0.75
INTRM2
CSGDRL
BHAH
P
M/U HRDE liner running tools, Baker
2,321.0
2,344.0
02:45
03:30
flow diverter & stabilizer. SIMOPS -
R/D false table & work platform.
12/3/2018
12/3/2018
0.50
INTRM2
CSGDRL
TRIP
P
RIH SDL w/5" DP f/2,344'to 2,805'
2,344.0
2,805.0
03:30
0400
12/3/2018
12/3/2018
0.50
INTRM2
CSGDRL
DHEQ
P
Shallow hole lest SDL directional:
2,805.0
2,805.0
04:00
04:30
assy w/230 gpm, 1310 psi (good).
SIMOPS - clean & clear floor & UD
excess tools & equipment.
12/3/2018
12/3/2018
7.25
INTRM2
CSGDRL
TRIP
P
RIH SDL w/5" DP f/2.805'to 10, 152'
2,805.0
10,152.0
04:30
11:45
12/3/2018
12/3/2018
0.75
INTRM2
CSGDRL
MPDA
P
PJSM. Pull trip nipple & install RCD.
10,152.0
10,152.0
11:45
12:30
Break in bearing & SPR's.
12/3/2018
12/3/2018
1.75
INTRM2
CSGDRL
WASH
P
Wash down f/10,152'to TO of 10,485'
10,152.0
10,485.0
12:30
14:15
w/200 - 220 gpm, 1340 - 1450 psi.
Star cutting mud wt f/10.8 ppg to 10.5
Ppg
12/3/2018
12/4/2018
9.75
INTRM2
CSGDRL
DCSG
P
Drill ahead w/SDLV10,485'to 10,740'
10,485.0
10.740.0
14:15
00:00
MD / 7,484' TVD, ADT 8.6 Hrs, ECD
1.675 ppg, 600 gpm, 2730 psi, PU wt
265 k, SO wt 175 k, ROT wt 210 k, 40
rpm, Trq On/Off 16/12.5 k f/lbs. MPD
trapping 11.5 ppg Mud wt equiv.
12/4/2018
12/4/2018
1.25
INTRM2
CSGDRL
DCSG
P
Directional drill with SDL from 10,740'
10,740.0
10,785.0
00:00
01:15
MD to 10,785' MD, holding 11.5 ppg
EMW with MPD.
12/4/2018
12/4/2018
0.75
INTRM2
CSGDRL
RGRP
T
Change out swab and liner on pump
10,785.0
10.785.0
01:15
02:00
#1.
PIU off bottom, circulate and condition
with pump #2, rotate and reciprocate.
445 gpm, 1560 psi holding 11.5 ppg
EMW with MPD. ROT=216k. 14k Tq.
Page 9/23 Report Printed: 12I26I2016
operations Summary (with Timi Uepths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Sart lime
End Time
our (i
Phase
Op Gme
Acevsy Code
Time P -T -X
operatum
Stan Depth
(fd(8)
End Dei (W)
12/4/2018
12/4/2018
10.00
INTRM2
CSGDRL
DCSG
P
Continue directional drill with SDL
10,785.0
11,143.0
02:00
12:00
from 10,785' MD to 11,143' MD, 7,676'
TVD, holding 11.5 ppg EMW with
MPD.
ADT=10.2 hrs, P/U=244k, S/0=182k,
ROT=215k, Tq on/off=14.3k/12.9k
12/4/2018
12/5/2018
12.00
INTRM2
CSGDRL
DCSG
P
Continue directional drill with SDL
11.143.0
11.480.0
12:00
00:00
from 11.143' MD to 11,480' MD, 7,793'
TVD, holding 11.5 ppg EMW with
MPD.
ADT=11.0 hrs, P/U=244k, S/0=182k,
ROT=220k, Tq on/off=15k/13k
12/5/2018
12/5/2018
12.00
INTRM2
CSGDRL
DCSG
P
Continue directional drill with SDL
11,480.0
11,850.0
00:00
12:00
from 11,480' MD to 11,850' MD, 7,874'
TVD, holding 11.5 ppg EMW with
MPD. 5-10k WOB, 600 gpm @ 2800
psi diverter open, TRPM -4200. ML
gas average 200 units,
ADT=11.1 hrs, P/U=265k, S/0=184k,
ROT=200k, Tq on/off--,15.2k/13.8k
12/5/2018
12/6/2018
12.00
INTRM2
CSGDRL
DCSG
P
Continue directional drill with SDL
11,850.0
12,106.0
12:00
00:00
from 11,850' MD to 12,106' MD, 7,904'
TVD, holding 11.5 ppg EMW with
MPD. Closed Under reamer @
12,092', drilled down to 12,106'
observed static reamer land on ledge
@ 12,105.7' bit depth, 12,025' MD
shoe depth. 5-10k WOB, 600 gpm @
2700 psi diverter open, TRPM -4400.
ML gas increased to 1700 units in C
sand.
ADT=11.3 hrs, ROT=220k, Tq
on/off=16k/14k
12/6/2018
12/6/2018
0.50
INTRM2
CEMENT
CIRC
P
Circulate 3 liner annulus volumes
12,106.0
12,106.0
00:00
00:30
while rotating 40 rpm It 35 bbl) at TD
12,106'. 600 gpm, 2760 psi. Cycle
pumps for final survey (holding 11.5
ppg with MPD), rotate to open flow
diverter then stop rotary.
12/6/2018
12/6/2018
2.25
INTRM2
CEMENT
CIRC
P
Continue to circulate and condition,
12.106.0
12,106.0
00:30
02:45
CBU x 3 @ 600 gpm, 2680 psi.
SIMOPS- PJSM and lay down 5"
HWDP, Jars and DP from derrick.
12/6/2018
12/6/2018
3.50
INTRM2
CEMENT
CIRC
P
Weight up from 10.3 ppg to 10.8 ppg
12,106.0
12,106.0
02:45
06:15
in 2 circulations with spike fluid. 10.3
ppg-10.5+, then 10.5+ to 10.8 ppg.
Initial circulating @ 600 gpm, holding
50 psi for 11.5 ppg EMW, final 360
gpm, 1280 psi @ 11.6 ppg EMW.
Diverter open.
12/6/2018
12/6/2018
0.25
INTRM2
CEMENT
OTHR
P
Shut down, break out tool joint and
12,106.0
12.106.0
06:15
06:30
drop 1.75" Bronze release ball per
BOT rep.
12/6/2018
12/6/2018
0.50
INTRM2
CEMENT
CIRC
P
Slack off 20k to 225, pump down 1.75"
12,106.0
12,106.0
06:30
07:00
release ball to seat @ 2 bpm, 580 psi.
Ball on seal @ 487 strokes. Slack off
to 1951k. Pressure up to 3640 psi to
blow out ball seat. Continue pump 1
bpm 375 psi. PIU and verify release @
2351k per BOT.
12/6/2018
12/6/2018
0.50
INTRM2
CEMENT
PMPO
P
Pump out slowly from 12.106' MD to
12,106.0
11,940.0
07:00
07:30
11,940' MD @ 200 gpm, 1250 psi @
P/U 235k. Displacing out old mud from
inside IinenTotal pumped 105 bbl.
Page 10123 ReportPrinted: 12126/2018
operations Summary (with Timelog uepths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Start Tene
End Time
our (hr)
Phase
op CMG
Activity Code
Time P-T-X
Opmbon
Sled Depth
(KKB)
End Depth (PoCB)
12/6/2018
12/6/2018
0.50
INTRM2
CEMENT
OWFF
P
Flow check well static, Blow down top
11,940.0
11,940.0
07:30
08:00
drive and PJSM to strip out of hole.
Line up MPD.
12/6/2018
12/6/2018
4.00
INTRM2
CEMENT
SMPD
P
Strip out of hole with MPD per
11,940.0
8,930.0
08:00
12:00
schedule from 11,940' MD to 8,930'
MD, maintaining 11.1 ppg with 123 psi
in slips, 315-350 psi pulling.
12/6/2018
12/6/2018
4.00
INTRM2
CEMENT
SMPD
P
Continue stripping out of hole with
8,930.0
2,532.0
12:00
16:00
MPD from 8,930' MD to 2,532' MD
holding 310 psi AP pulling and 90 psi
in slips.
12/6/2018
12/6/2018
0.25
INTRM2
CEMENT
OWFF
P
Observe well for flow @ 2,532' MD.
2,532.0
2,532.0
16:00
16:15
Prep to pull RCD.
12/6/2018
12/6/2018
0.75
INTRM2
CEMENT
MPDA
P
Pull MPD bearing and install trip
2,532.0
2,532.0
16:15
17:00
nipple.
Function test annular, upper and lower
rams. (weekly)
12/6/2018
12/6/2018
0.25
INTRM2
CEMENT
TRIP
P
POOH from 2,532' MD to 2,343' MD.
2,532.0
2,343.0
17:00
17:15
PIU=105k. S/0=105k.
12/6/2018
12/6/2018
0.50
INTRM2
CEMENT
BHAH
P
Lay down flow diverter assembly,
2,343.0
2,299.0
17:15
17:45
1
1
1 stabilizer and liner running tool.
12/6/2018
12/6/2018
0.50
INTRM2
CEMENT
RURD
P
Change out from 5" handling
2,299.0
2,299.0
17:45
18:15
equipment to 4" handling equipment.
12/6/2018
12/6/2018
1.25
INTRM2
CEMENT
TRIP
P
POOH from 2,299' MD to 180' MD.
2,299.0
180.0
18:15
19:30
Calc Fill=98.5 bbl, Actual F111=129 bbl.
12/6/2018
12/6/2018
0.50
INTRM2
CEMENT
OWFF
P
Monitor well for flow, static slight drop.
180.0
180.0
19:30
20:00
SIMOPS- Clean and clear rig floor,
prep for BHA.
12/6/2018
12/6/2018
1.00
INTRM2
CEMENT
BHAH
P
Lay down BHA #4 per DD/MWD from
180.0
116.0
20:00
21:00
180' MD to 116' MD.
12/6/2018
12/6/2018
0.25
INTRM2
CEMENT
BHAH
P
Unload and secure sources from
116.0
116.0
21:00
21:15
MWD.
12/6/2018
12/6/2018
1.25
INTRM2
CEMENT
SHAH
P
Continue UD BHA from 116' MD per
116.0
0.0
21:15
22:30
DD/MWD reps. Note; Nozzle missing
from bit, otherwise BHA looked very
good.
Break bit from backup steering head.
Function tested blind rams.
12/6/2018
12/7/2018
1.50
INTRM2
CEMENT
BHAH
P
Clean and clear rig floor from BHA #41.
0.0
0.0
22:30
00:00
P/U tools and equipment for cement
retainer/ liner hanger and packer run.
12/7/2018
12/7/2018
0.25
INTRM2
CEMENT
RURD
P
P/U and stage tools for K11 cement
0.0
0.0
00:00
00:15
retainer and SLZXP liner hanger
packer assy, latching seal assy.PJSM
with BOT on M/U inner string.
1217/2018
12/7/2018
2.00
INTRM2
CEMENT
TRIP
P
Make up K-1 Cement retainer as per
0.0
2,155.0
00:15
02:15
BOT rep with 9.73' pup joint. Continue
RIH with 22 stands DP and 2 singles
4" DP to 2,155' MD
12/7/2018
12/7/2018
1.00
INTRM2
CEMENT
PUTB
P
Rig up double stack tongs, change to
2,155.0
2,243.0
02:15
03:15
5" handling equipment. P/U SLZXP,
make up 10.62' pup on bottom. Make
up latching seal assy to packer, make
up to inner string. M/U 5" space out
pups to 2,243' MD.
12/7/2018
12/7/2018
0.50
INTRM2
CEMENT
CIRC
P
RIH 1 stand, M/U to top drive and
2,243.0
2,335.0
03:15
03:45
establish circulation, pump string
volume to confirm flow path. 1
bpm=110 psi, 2 bpm=120psi, 3
bpm=150 psi. P/U and S/0= 90k. Blow
down top drive.
Page 11123 Report Printed: 12126/2018
uperations Summary (with Timelog Depths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
sled Dept
start Time
End Time
Our to
Phase
Op Code
Activity Code
Time P -T -X
Op.nuon
(ftKB)
End Dept(fiKB)
12/7/2018
12/7/2018
5.25
INTRM2
CEMENT
TRIP
P
RIH with assembly from 2,335' MD to
2,335.0
9,676.0
03:45
09:00
9,676' MD on 5" DP/ P/U=210k,
S/0=115k.
12/7/2018
12/7/2018
1.00
INTRM2
CEMENT
CIRC
P
Make up to top drive, establish
9,676.0
9,865.0
09:00
10:00
circulation and wash through TOL @
9,790' MD with retainer. ICP 1 bpm @
250 psi, FCP 3 bpm @ 360 psi.
Observed no loss of S/O weight going
into TOL. Blow down top drive.
12/7/2018
12/7/2018
2.00
INTRM2
CEMENT
TRIP
P
Continue RIH from 9,865' MD to
9,865.0
11,844.0
10:00
12:00
11,844' MD. Calculated
Displacement=93,88 bbl, Actual
Disp=90.5 bbl.
12/7/2018
12/7/2018
0.50
INTRM2
CEMENT
CIRC
P
Break circulation, stage up to 2.5 bpm.
11,844.0
11,844.0
12:00
12:30
1 bpm=400 psi, 2 bpm=480 psi, 2.5
bpm=520 psi.
12/7/2018
12/7/2018
0.50
INTRM2
CEMENT
WASH
P
Wash down from 11,844' MD to
11,844.0
11,964.0
12:30
13:00
11,964' MD @ 1 bpm, 400 psi.
12/7/2018
12/7/2018
1.00
INTRM2
CEMENT
RURD
P
Blow down top drive, PIU and M/U
11,964.0
11,964.0
13:00
14:00
1
1
cement swivel.
12/7/2018
12/7/2018
0.25
INTRM2
CEMENT
WASH
P
Line up to cement head, establish
11,964.0
11,964.0
14:00
14:15
circulation and wash down to 11,972'
MD @ 1 bpm, 420 psi. Observe
pressure increase as seals enter liner
top.
12/7/2018
12/7/2018
1.00
INTRM2
CEMENT
HOSO
P
Slack off from 11,972' MD to 11,978'
11.964.0
11,978.0
14:15
15:15
MD, latch in seal assembly. P/U to
confirm latched in with 270k up. 170k
Down. Stage up pump to 2 bpm 510
psi.
1217/2018
12/7/2018
0.75
INTRM2
CEMENT
CIRC
P
Blow down top drive, drop 1.75" ball
11,978.0
11,978.0
15:15
16:00
pump down @ 2 bpm. 500 psi. Ball on
seat @ 480 stks. Pressure up to 4100
psi, bleed down to 550 in 4 minutes for
DOBS to open.
12/7/2018
12/7/2018
0.50
INTRM2
CEMENT
MPSP
P
P/U to 11,968' MD and set K-1 cement
11,978.0
11,968.0
16:00
16:30
retainer with RH rotation per Baker
rep. Un -sting from retainer. P/U=235k,
S/0=165k.
1217/2018
12/7/2018
0.25
INTRM2
CEMENT
OWFF
P
Observe well for flow, static.
11,968.0
11,968.0
16:30
16:45
1217/2018
12/7/2018
1.00
INTRM2
CEMENT
CIRC
P
P/U to 11,959' MD and CBU @ 8 bpm,
11,968.0
11,959.0
16:45
17:45
1270 psi.
12/7/2018
12/712018
1.75
INTRM2
CEMENT
CIRC
P
Sting into cement retainer and set
11,959.0
11,970.0
17:45
19:30
down 25k to 11,970' MD. Stage up
from .5 bpm=290 psi, 1 bpm=330 psi,
1.5 bpm=400 psi, 2 bpm=450 psi, 2.5
bpm=550 psi, observe some packing
off pressuring up to 625 psi. Reduce
rate to 2 bpm, 580-660, reduce to 1.5
@ 500 psi.
SIMOPS- PJSM on cement job.
Page 12123 Report Printed: 12/2612018
kiperations Summary (with Timelog L epths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Sten Three
End Time
Dur (hr)
Phase
Op Code
Activity code
Time P -T -X
Operation
Stan Depth
(fiKB)
End Depth(ftKB)
12/7/2018
12/8/2018
4.50
INTRM2
CEMENT
CMNT
P
Flood lines with water, pressure test
11,970.0
11,970.0
19:30
00:00
lines to 4000 psi. SLB pump 30 bbl
12.5 ppg Mud Push @ 2 bpm, 644 psi,
swap to 59.5 bbl 15.8 ppg G Cement
@ 1.9 bpm initial 675 psi, climbing to
1200 psi packing off and erratic.
Reduce rate to 1 bpm, 925 psi,
smoothed out, FCP 445 psi @ 1 bpm.
Chase with 20 bbl water @ 1 bpm,
400-550 psi. Swap to rig to displace @
1 bpm, initial, up to 840 psi observing
losses @ 30%. Reduce rate to .5-.7
bpm, 980-1300 psi, 50% losses.
Cement rounding shoe @ 00:00 hrs,
119 bbl away.
12/8/2018
12/8/2018
1.25
INTRM2
CEMENT
CMNT
P
Continue displacing cement with 10.8
11,970.0
11,970.0
00:00
01:15
ppg LSND @ .7 bpm, 1280 psi. 165.8
bbl total displacement. 50% returns.
12/8/2018
12/8/2018
0.50
INTRM2
CEMENT
CIRC
P
Unsting out of cement retainer while
11,970.0
11,934.0
01:15
01:45
pumping, increase rale to 280 gpm to
clear string of excess cement. Pump
100 bbl to dear top of liner. PIU 20' to
expose rotating dog sub. P/U=240k,
S/0=170k. Set 52k down to set liner
hanger/ packer assy, observe shear,
PIU, rotate 15 rpm and repeat to
confirm as per BOT Rep.
12/8/2018
12/8/2018
0.25
INTRM2
CEMENT
RURD
P
Shut down, dg down cement swivel,
11,934.0
11,934.0
01:45
02:00
lay down single to shed and 7.66' pup
joint. Blow down cement line. M/U to
top drive.
12/8/2018
12/8/2018
2.50
INTRM2
CEMENT
CIRC
P
Circulate and condition mud system @
11,934.0
11,934.0
02:00
04:30
700 gpm, 3170 psi. Pump 2 sweeps of
treated water to clean pipe and treat
cement contamination. Observe high
ph at bottoms up from liner top,
followed by the 5 bbl excess cement
left in pipe. Circulate until even 10.7
ppg in/out, 2 full circulations. ICP3170
psi, FCP=2960 psi @ 7000 gpm.
12/8/2018
12/8/2018
0.25
INTRM2
CEMENT
OWFF
P
Blow down top drive, OWFF. Slighly
11,934.0
11,934.0
04:30
04:45
out of balance, trickling at flowline,
115
falling in pipe. Flowline went static in
minutes.
12/8/2018
12/8/2018
2.25
INTRM2
CEMENT
TRIP
P
POOH on elevators from 11,934' MD
11,934.0
10,052.0
04:45
07:00
to 10,052' MD.
12/8/2018
12/8/2018
0.50
INTRM2
CEMENT
OWFF
T
Observe hole fill not correct. Stop and
10,052.0
10,052.0
07:00
07:30
OWFF, fluid still out of balance falling
down drill pipe.
12/8/2018
12/8/2018
0.50
INTRM2
CEMENT
TRIP
P
Continue POOH from 10,052' MD to
10,052.0
9,864.0
07:30
08:00
9,864' MD.
12/8/2018
12/8/2018
1.00
INTRM2
CEMENT
PMPO
P
Wash across TOL from 9,864' MD to
9,864.0
9,675.0
08:00
09:00
9,675' MD pumping out @ 600 gpm,
1940 psi. CBU x 1 while pumping out,
no obstructions. P/U=200k, 10.7 ppg
in/out.
12/8/2018
12/8/2018
0.25
INTRM2
CEMENT
OWFF
P
OWFF, static.
9,675.0
9,675.0
09:00
09:15
12/8/2018
12/8/2018
0.25
INTRM2
CEMENT
CIRC
P
Pump 20 bbl 12.9 ppg dry job.
9,675.0
9,675.0
09:15
09:30
Displace with 8 bbl 10.7 ppg @ 126
gpm, 270 psi.
12/8/2018
12/8/2018
0.25
INTRM2
CEMENT
RURD
P
PJSM on POOH and laying down 5"
9,675.0
9,675.0
09:30
09:45
DP. Prep pipe shed and tools for
laying down.
Page 13123 Report Printed: 12/2612018
operations Summary (with Timelog L epths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Stan Depth
Stan Time
EM Time
our (hr)
Phase
Op cod.
Achvay Code
Time P-T-X
Operation
(RKe)
End Depth(Ilxa)
12/8/2018
12/8/2018
2.25
INTRM2
CEMENT
PULD
P
POOH with liner running tools and
9.675.0
8,316.0
09:45
12:00
cement slinger, laying down 5" DP
from 9,675' MD to 8,316' MD.
12/8/2018
12/8/2018
0.25
INTRM2
CEMENT
OWFF
P
OWFF, slight flow at flowline, dry job
8.316.0
8,316.0
12:00
12:15
still falling slowly.
12/8/2018
12/8/2018
5.25
INTRM2
CEMENT
PULD
P
Continue POOH with liner running
8.316.0
2,243.0
12:15
17:30
tools and cement slinger, laying down
5" DP from 8,316' MD to 2,243' MD.
12/8/2018
12/8/2018
0.75
INTRM2
CEMENT
BHAH
P
Lay down Baker liner running tool to
2,243.0
2.159.0
17:30
18:15
2,159' MD. Observe dog sub sheared.
Change out to 4" running tools.
12/8/2018
12/8/2018
1.25
INTRM2
CEMENT
TRIP
P
POOH from 2,159' MD, racking back
2,159.0
0.0
18:15
19:30
4" DP.
12/8/2018
12/8/2018
0.25
INTRM2
CEMENT
BHAH
P
Lay down cement retainer running tool
0.0
0.0
1930
1945
and stinger, lay down 7' pup.
12/8/2018
12/8/2018
0.75
INTRM2
CEMENT
PRTS
P
Rig up and test liner top packer and
0.0
0.0
19:45
20:30
retainer to 1000 psi for 10 minutes
charted, good test. Close blind rams
and test via HCR kill.
12/8/2018
12/8/2018
0.50
INTRM2
CEMENT
RURD
P
Drain stack and FMC pull 8.812" ID
0.0
0.0
20:30
21:00
wear ring.
12/8/2018
12/8/2018
2.00
INTRM2
CEMENT
RURD
P
Mobilize 7" casing handling equipment
0.0
0.0
21:00
23:00
to rig floor, R/U to run tie-back. M/U
Volant CRT and torque turn
equipment.
12/8/2018
12/8/2018
0.25
INTRM2
CEMENT
SFTY
P
PJSM on running 7" tie-back casing
0.0
0.0
23:00
23:15
string. Discuss exclusion zones, lifting
operations, line of fire, new hands on
rig floor.
12/8/2018
12/9/2018
0.75
INTRM2
CEMENT
PUTS
P
Make up seal assembly and 7" TSH
0.0
67.0
23:15
00:00
Blue tie-back to 67' MD.
12/9/2018
12/9/2018
3.25
INTRM2
CEMENT
PUTS
P
Continue P/U and RIH with 7" 26# L-
67.0
1,466.0
00:00
03:15
80 TSH Blue tie-back casing from 67'
to 1,466' MD, Joint #35. Torque
turning with double stack tongs and
running with Volant. S/0=93k.
12/9/2018
12/9/2018
0.50
INTRM2
CEMENT
PUTS
T
Swap out joint#36 for joint#262, and
1,466.0
1,466.0
03:15
03:45
collar on jt #35 due bad Torque tum
make up curve. (Thread damage)
12/9/2018
12/9/2018
8.25
INTRM2
CEMENT
PUTS
P
Continue P/U and RIH with 7" 26# L-
1,466.0
4,493.0
03:45
12:00
80 TSH Blue tie-back casing from
1,466'to 4,493' MD. Torque turning
with double slack tongs and running
with Volant. S/0=125k.
12/9/2018
12/9/2018
2.50
INTRM2
CEMENT
PUTS
P
Continue P/U and RIH with 7" 26# L-
4,493.0
5,765.0
12:00
14:30
80 TSH Blue tie-back casing from
4,493' to 5,765' MD. Torque turning
with double stack tongs and running
with Volant. S/0=135k.
12/9/2018
12/9/2018
0.50
INTRM2
CEMENT
PUTS
T
Change out collar on it #140 due bad
5,765.0
5,765.0
14:30
15:00
Torque tum make up curve. (Galled
threads)
12/9/2018
12/9/2018
2.25
INTRM2
CEMENT
PUTS
P
Continue RIH with 7" Tie Back from
5,765.0
6,876.0
15:00
17:15
5,765' MD to 6,876' MD
12/9/2018
12/9/2018
0.25
INTRM2
CEMENT
PUTS
T
Swap out joint#168 for joint#258, and
6,876.0
6,876.0
17:15
17:30
collar on jt #167 due bad Torque turn
make up curve. (Thread damage)
12/9/2018
12/9/2018
2.25
INTRM2
CEMENT
PUTS
P
Continue RIH with 7" Tie Back from
6,876.0
7,946.0
17:30
19:45 1
1
1
1
16,876'MD
to 7,946' MD
12/9/2018
12/912018
0.25
INTRM2
CEMENT
PUTB
T
Swap out joint#194 for joint#247, and
7,946.0
7,946.0
19:45
20:00
1
I
collar on jt #193 due bad Torque turn
make up curve. (Thread damage)
Page 14123 ReportPrinted: 12/2612018
operations Summary (with Timelog uepths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time Pd
Operation
start Depm-X
(111<6)
End Depth(flKB)
12/9/2018
12/9/2018
0.50
INTRM2
CEMENT
PUTB
P
Continue RIH with 7" Tie Back from
7,946.0
8,194.0
20:00
20:30
7,946' MD to 8,194' MD
12/9/2018
12/9/2018
0.25
INTRM2
CEMENT
PUTB
T
Change out collar on jt #199 due bad
8,194.0
8.194.0
20:30
20:45
Torque turn make up curve. (Galled
threads)
12/9/2018
12/9/2018
2.75
INTRM2
CEMENT
PUTS
P
Continue RIH with 7" Tie Back from
8,194.0
9,548.0
20:45
23:30
8,194' MD to 9,548' MD
12/9/2018
12/9/2018
0.25
INTRM2
CEMENT
PUTS
T
Bad make up on #233. Threads
9,548.0
9,548.0
23:30
23:45
appear OK. Clean box and pin on joint
#2321#233, re -apply dope and M/U
OK
12/9/2018
12/10/2018
0.25
INTRM2
CEMENT
PUTS
P
Continue RIH with 7" Tie Back from
9,548.0
9,631.0
23:45
00:00
9,548' MD to 9,631' MD
12/10/2018
12/10/2018
0.25
INTRM2
CEMENT
PUTS
P
Continue RIH with 7" Tie Back from
9,631.0
9.653.0
00:00
00:15
9,631' MD to 9,653' MD
12/10/2018
12/10/2018
1.25
INTRM2
CEMENT
HOSO
P
Establish circulation on joint #238 with
9,653.0
9,774.0
00:15
01:30
Volant CRT @ 1 bpm, 290 psi. Wash
down to locate TOL. Locate seals @
9,763' via pressure increase. Shut
down and bleed off, slack off to no-go
@ 9,783'. (TOL=9,754' corrected.)
12/10/2018
0.50
INTRM2
CEMENT
PRTS
P
Rig up and pressure test seal
9,774.0
9,774.0
01:30
112/10/2018
02:00
assembly via annulus to 1000 psi for
10 minutes, with bleeder open on
casing side. Good.
12/10/2018
12/10/2018
1.00
INTRM2
CEMENT
HOSO
P
Lay down casing joints #238, #237
9,774.0
9,774.0
02:00
03:00
and #236. Rig down Volant CRT, blow
down top drive. Calculate spaceout
and prep pups.
12/10/2018
12/1012018
1.75
INTRM2
CEMENT
HOSO
P
Make up XO from TSH Blue to H563,
9,774.0
9,747.0
03:00
04:45
M/U 19.86' and 9.86' space out pups.
M/U hanger and landing joint with
pumping equipment made up to lop.
Pump down casing string @ 1 bpm
again to verify spaceout, locate TOL
@ 21' in on landing joint. PIU to
breakover +10' to clear seals. Drain
stack and slack off 6'to place hanger
just below annular preventer. Close
annular to reverse in. P/U=234k,
S/0=175k.
12/10/2018
12/10/2018
1.75
INTRM2
CEMENT
CRIH
P
PJSM, line up and reverse in 20 bbl Hi
9,747.0
9,766.0
04:45
06:30
Vis 9.5 ppg spacer, 247 bbl corrosion
inhibited seawater into 9.625" x 7"
annulus.
12/10/2018
12/10/2018
1.00
INTRM2
CEMENT
FRZP
P
Line up Ball mill and PT lines to 2500
9,766.0
9,766.0
06:30
07:30
psi. 42 bbl diesel pumped by Ball Mill
into 9.625" x 7" annulus @ 2.5 bpm,
1060 psi.
12/10/2018
12/10/2018
0.25
INTRM2
CEMENT
HOSO
P
Shut down, strip in landing joint until
9,766.0
9,766.0
07:30
07:45
seals entered TOL, Bleed pressure to
0, open annular and continue slacking
off until landed @ 9,766' seal assy
depth, spaced 7.13' off fully located.
12/10/2018
12/1012018
1.00
INTRM2
CEMENT
RURD
P
Rig down reverse circulating
9,766.0
0.0
07:45
08:45
equipment, back out and lay down
landing joint.
12/10/2018
12/10/2018
1.25
INTRM2
CEMENT
WWSP
P
Make up packoff running tool, Install
0.0
0.0
08:45
10:00
13"x7" Packoff. RILDS. Pressure test
void to 250/5000 psi, good.
Page 15123 Report Printed: 12/2612018
uperations Summary (with Timelog L/epths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
StsdMme
End More
(hr)
Phase
o code
Activity Ycode
TimP-T-X
Operation
Start Depth
KB)
End Depth (ftKa)
12/10/2018
12/1012018
1.00
INTRM2
CEMENT
PRTS
P
Pressure test 9-5/8" x 7" annulus to
0.0
0.0
10:00
11:00
2500 psi for 30 minutes charted, good.
Used Ball Mill pump and diesel for
test. Bleed annulus to 0 psi, close in
valves. Clear lines of diesel. Install PT
sensor / gauge on annulus @ wing
valve.
12/10/2018
12/10/2018
1.00
INTRM2
CEMENT
RURD
P
Lay down 7" CRT and equipment,
0.0
0.0
11:00
12:00
clean and clear dg floor. P/U BHA
components for BHA#5.
12/10/2018
12/10/2018
0.50
INTRM2
CEMENT
BHAH
P
Continue PIU BHA tools and
0.0
0.0
12:00
12:30
equipment via Beaverslide.
12/10/2018
12110/2018
0.25
INTRM2
CEMENT
SFTY
P
PJSM on changing out upper pipe
0.0
0.0
12:30
12:45
rams and changing saver sub to
XT39.
12/10/2018
12/10/2018
3.75
INTRM2
CEMENT
BOPE
P
Change out upper rams from 4%" x 7"
0.0
0.0
12:45
16:30
VBR to 31/2' x 6" VBR.
SIMOPS- Change out saver sub on
top drive from NC50 to XT39.
12/10/2018
12/10/2018
1.25
INTRM2
CEMENT
BOPE
P
Rig up and test upper rams to
0.0
0.0
16:30
17:45
250/3500 for 5/10 minutes with 4" test
joint.
12/10/2018
12/10/2018
0.25
INTRM2
CEMENT
BOPE
P
Pull test plug, R/D test equipment.
0.0
0.0
17:45
18:00
12/10/2018
12/10/2018
0.75
INTRM2
CEMENT
RURD
P
Install 6.125" ID wear bushing, RILDS.
0.0
0.0
18:00
18:45
L/D test joint.
12/10/2018
12/10/2018
0.25
INTRM2
CEMENT
SFTY
P
PJSM on PIU Cleanout BHA #5.
0.0
0.0
18:45
19:00
12/10/2018
12/10/2018
1.00
INTRM2
CEMENT
BHAH
P
PIU and RIH with BHA #5 to 242' MD
0.0
242.0
19:00
20:00
12/10/2018
12/11/2018
4.00
INTRM2
CEMENT
PULD
P
RIH with BHA *5, picking up 4" DP
242.0
3,091.0
20:00
00:00
from pipe shed to 3,091' MD.
12/11/2018
12/11/2018
1.25
INTRM2
CEMENT
PULD
P
Run in hole with cleanout assembly
3,091.0
4,228.0
00:00
01:15
BHA#5, picking up 4" DP from shed
from 3,091' MD to 4,228' MD.
12/11/2018
12/11/2018
1.25
INTRM2
CEMENT
TRIP
P
Continue RIH with BHA#5 wioth 4"
4,228.0
6,510.0
01:15
02:30
DP out of derrick from 4,228' MD to
6,510' MD.
12/11/2018
12/11/2018
6.25
INTRM2
CEMENT
PULD
P
Resume singling in from pipe shed
6,510.0
11,840.0
02:30
08:45
with 4" 14# and 15.7# drill pipe from
6,510' MD to 11,840' MD, filling every
20 stands.
12/11/2018
12/11/2018
1.75
INTRM2
CEMENT
SLPC
P
PJSM, Cul and slip drilling line (90').
11.840.0
11,840.0
08:45
10:30
SIMOPS- circulate and condition @ 2
bpm, 870-630 psi, reducing mud
weight from 10.7 ppg to 10.5 ppg.
Service and calibrate top drive,
draworks and blocks.
12/11/2018
12/11/2018
0.75
INTRM2
CEMENT
RURD
P
Rig up for casing test, dg up surface
11,840.0
11,840.0
10:30
11:15
lines and establish circulation via kill
line. Observe 4" Demco valve leaking
on standpipe at low pressuure.
Decision to repair prior to test.
12/11/2018
12111/2018
0.75
INTRM2
CEMENT
RGRP
T
Rebuild and pressure test 4" Demco
11,840.0
11,840.0
11:15
12:00
valve on stand pipe prior to test.
12/11/2018
12/11/2018
0.75
INTRM2
CEMENT
PRTS
P
Test 7" casing string to 3500 psi for 30
11,840.0
11,840.0
12:00
12:45
minutes charted, good.
12/11/2018
12/11/2018
0.75
INTRM2
CEMENT
RURD
P
Rig down test equipment, blow down
11,840.0
11,840.0
12:45
13:30
kill line.
12/11/2018
12/11/2018
1.50
INTRM2
CEMENT
COCF
P
Wash and ream down from 11,840'
11,840.0
11,964.0
13:30
15:00
MD to 11,964' MD tag up on cement /
cement retainer. 200 gpm, 1250 psi,
40 rpm, 4-5k.
Page 16123 Report Printed: 1212612018
uperations Summary (with Timelog depths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Sort Time
End Time
our (M
Phase
Op Code
Actift Code
Time Pd -x
Operation
5i(ftKB)
End OeVt6 (ftKa)
12/11/2018
12/11/2018
4.00
INTRM2
CEMENT
DRLG
P
Drill cement retainer@ 11,964' MD
11,964.0
12,106.0
15:00
19:00
and shoe track to 12,026', then rathole
to 12,106' MD @ 200 gpm, 1150 psi,
40-60 rpm, 4-6.5k Tq.
12/11/2018
12/11/2018
2.50
INTRM2
CEMENT
DDRL
P
Drill formation from 12,106' MD to
12,106.0
12,126.0
19:00
21:30
12,126' MD, 7,905' TVD. ADT=1.7 hrs,
12/11/2018
12/11/2018
1.00
INTRM2
CEMENT
CIRC
P
Circulate bottoms up @ 290 gpm,
12,126.0
12,126.0
21:30
22:30
1
1
1760 psi, 50 rpm. 1760 psi.
12/11/2018
12/11/2018
0.75
INTRM2
CEMENT
PMPO
P
POOH with pump from 12,126' MD to
12,126.0
11,999.0
22:30
23:15
11,999' MD @ 200 gpm, no rotation.
Work into shoe @ .5 bpm
12/11/2018
12/11/2018
0.25
INTRM2
CEMENT
RURD
P
Blow down top drive, Rig up for FIT.
11,999.0
11,999.0
23:15
23:30
12/11/2018
12/12/2018
0.50
INTRM2
CEMENT
FIT
P
Perform LOT to 11.9 ppg EMW,
11,999.0
11,999.0
23:30
00:00
pressure up to 870 psi max, observe
leakoff @ 700 psi. Total 1.8 bbl
pumped, 1.5 bbl bled back.
12/12/2018
12/12/2018
0.25
PROD1
DRILL
RURD
P
Rig down from LOT, prep rig floor for
11,999.0
11,999.0
00:00
00:15
1
1
POOH.
12/12/2018
12/12/2018
1.25
PRODi
DRILL
OWFF
T
Monitor for flow, observe slight flow at
11,999.0
11,999.0
00:15
01:30
flowline. Monitor with vis cup for 1
hour, continual trickle but decreasing
from 24 sec/ vis cup to 60 see/ vis cup
then steady readings at 60.
12/12/2018
12/12/2018
1.00
PROD1
DRILL
CIRC
T
M/U top drive and CBU, observe 1760
11,999.0
11,999.0
01:30
02:30
units gas at bottoms up. Continue full
circulation until gas decreased to
<100..
12/12/2018
12/12/2018
0.75
PROD1
DRILL
OWFF
T
OWFF again, flowing slightly out pipe
11,999.0
11,999.0
02:30
03:15
and flowline. Installed FOSV on pipe
and closed rams, monitor for pressure
build. Observe increase of 3 psi in 15
minutes. Bleed, open FOSV and rams.
Back to vis cup.
12/12/2018
12/12/2018
2.00
PRODt
DRILL
OWFF
T
Monitor with vis cup @ rotating head,
11,999.0
11,999.0
03:15
05:15
60 sec/qt reduced to 112 sec/qt.
Rotate string 5 rpm to break gels.
12/12/2018
12/12/2018
1.50
PROD1
DRILL
CIRC
T
M/U top drive and CBU, 200 gpm,
11,999.0
11,934.0
05:15
06:45
1060 psi, 20 rpm, 5.6k Tq, 165k ROT
wt.. Observe 372 units gas at bottoms
up. Continue full circulation until gas
decreased. Rack back stand to
11,934' MD..
12/12/2018
12/12/2018
1.75
PROD1
DRILL
OWFF
T
Monitor with vis cup @ rotating head,
11,934.0
11,934.0
06:45
0830
31 sec/qt reduced to 113 sec/gt.
Rotate string 5 rpm to break gels.
Decision made to install RCD to strip
out.
12/12/2018
12/122018
0.50
PRODi
DRILL
MPDA
P
PJSM, Pull trip nipple and install MPD.
11,934.0
11,934.0
08:30
09:00
Line up to strip out.
12/122018
12/12/2018
0.50
PROD1
DRILL
OWFF
P
OWFF, good.
11,934.0
11,934.0
09:00
09:30
12/12/2018
12/12/2018
2.50
PROD1
DRILL
SMPD
P
Strip out with MPD from 11,934' MD to
11,934.0
9,648.0
09:30
12:00
9,743' MD per schedule holding
50/100 psi in/out of slips. P/U=200k.
12/12/2018
12/12/2018
0.25
PROD1
DRILL
SMPD
P
Continue SOOH with MPD from 9,743'
9,648.0
9,648.0
12:00
12:15
MD to 9,648' MD holding 50/100 psi
infout of slips.
12/12/2018
12/12/2018
0.25
PROD1
DRILL
OWFF
P
OWFF at liner top, static.
9,648.0
9,648.0
12:15
12:30
1
12/12/2018
12/12/2018
0.25
PROD1
DRILL
CIRC
P
Pump 30 bbl 12.2 ppg slug, 160 gpm,
9,648.0
9,648.0
12:30
12:45
660 psi.
Page 17123 Report Printed: 12126/2018
Uperations Summary (with Timelog Uepths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
start Depth
startTime
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(ftKB)
End Depth(ftKB)
12/12/2018
12/12/2018
3.75
PROW
DRILL
SMPD
P
Blow down top drive and SOOH with
9,648.0
2,044.0
12:45
16:30
MPD from 9,648' MD to 2,044' MD per
schedule holding 50/100 in/out of
slips.
12/12/2018
12/12/2018
0.25
PRODt
DRILL
OWFF
P
Monitor well for flow, static
2,044.0
2,044.0
16:30
16:45
12/12/2018
12/12/2018
0.50
PROD1
DRILL
MPDA
P
Pull RCD, install trip nipple
2,044.0
2,044.0
16:45
17:15
12/12/2018
12/12/2018
1.25
PROD1
DRILL
TRIP
P
POOH on elevators from 2,044' MD to
2,044.0
60.0
17:15
18:30
60' MD, racking back HWDP and Jars.
12/12/2018
12/12/2018
1.25
PROW
DRILL
BHAH
P
Lay down BHAfrom 60' MD. Clean
60.0
-T-0-
18:30
19:45
magnets, weight 37 lbs metal from
magnets.
12/12/2018
12/12/2018
0.50
PROD1
DRILL
SHAH
P
Clean and clear rig floor, Lay down
0.0
0.0
19:45
20:15
RCD element.
12/12/2018
12/12/2018
0.75
PROD1
DRILL
RURD
P
Flush stack @ 10 bpm, 40 rpm. Blow
0.0
0.0
20:15
21:00
down top drive.
12/12/2018
12/12/2018
0.75
PROD1
WHDBOP
RURD
P
R/U and pull 6.125" wear ring.
0.0
0.0
21:00
21:45
12/12/2018
12/12/2018
1.25
PROD1
WHDBOP
RURD
P
Drain stack and set test plug. R/U to
0.0
0.0
21:45
23:00
test BOPE. Fill stack and manifold
with water, purge air from system.
12/12/2018
12/13/2018
1.00
PROD1
WHOBOP
BOPE
P
Test BOPE with 4" TJ. AOGCC Brian
0.0
0.0
23:00
00:00
Bixby witnessed. BLM Mutasim
Elganzoory waived. Test annular
250/2500 psi 5/10 min, Test upper 3%f
x6" VBR's, Valves 1, 12,13,14, Auto
IBOP and 4" Demco to 250/3500 psi
charted.
12/13/2018
12113/2018
4.00
PROD1
WHDBOP
BOPE
P
Continue testing BOPE with 4" TJ.
0.0
0.0
00:00
04:00
Test UPR, Manual and Auto IBOP,
HCR choke and kill, CV
9,11,5,8,10,4,6,7,2, XT39 FOSV, XT39
Dart, Lower VBR's.
Tested PVT, gas and flow alarms
12/13/2018
12/13/2018
0.50
PROD1
WHDBOP
BOPE
P
Perform accumulator test, System
0.0
0.0
04:00
04:30
pressure=2950 psi, Pressure after
fuctioning=1400 psi, 200 psi
attained=36 sec, Full system
recovery=175 sec. 4 bottle Nitrogen
average 2050 psi.
12/13/2018
12/13/2018
1.00
PROD1
WHDBOP
BOPE
P
Change to 411? test joint test upper
0.0
0.0
04:30
05:30
and lower VBR's to 250/3500 psi for
5/10 min. Annular to 250/2500 psi.
Test manual and super auto choke to
1100 psi.
12/13/2018
12/13/2018
0.75
PROD1
WHDBOP
RURD
P
Blow down choke and kill, choke
0.0
0.0
05:30
06:15
manifold. Rig down test equipment.
SIMOPS- PIU RCD bearing and prep
BHA tools and equipment.
12/13/2018
12/13/2018
0.50
PROD1
WHDBOP
RURD
P
Pull test plug and install 6.125" wear
0.0
0.0
06:15
06:45
1
1
ring.
12/13/2018
12/13/2018
3.25
PROD1
DRILL
BHAH
P
PJSM. M/U BHA #6 to 333' MD per
0.0
333.0
06:45
10:00
Baker DD/MWD
12/13/2018
12/13/2018
0.75
PROD1
DRILL
TRIP
P
Trip in hole with BHA #6 to 2,230' MD
333.0
2,230.0
10:00
10:45
from derrick.
12/13/2018
12/13/2018
0.50
PROD1
DRILL
DHEQ
P
Shallow test MWD @ 225 gpm, 920
2,230.0
2,230.0
10:45
11:15
psi. Good.
12/13/2018
12/13/2018
0.75
PROD1
DRILL
TRIP
P
Continue RIH from 2,230' MD to
2,230.0
3,179.0
11:15
12:00
3,179' MD. S10=96k
12/13/2018
12/13/2018
5.00
PRODt
DRILL
TRIP
P
Continue RIH from 3,179' MD to
3.179.0
11,930.0
12:00
17:00
11,930' MD. P/U=197k, S/0=138k.
Page 18123 ReportPrinted: 12/26/2018
operations Summary (with Timelog uepths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Stan Time
EnO Time
Our(hrt
Phase
Op Code
Activity Code
Time P-T-X
Operation
Start Depth
(ftKe)
End Depth(ftKe)
12/13/2018
12/13/2018
0.50
PROD1
DRILL
OWFF
P
Monitor for flow, static.
11,930.0
11,930.0
17:00
17:30
12/13/2018
12/13/2018
0.50
PROD1
DRILL
MPDA
P
Pull trip nipple and install MPD
11,930.0
11,930.0
17:30
18:00
element
12/13/2018
12/13/2018
0.75
PRODI
DRILL
CIRC
P
Circulate bottoms up @ 200 gpm,
11,930.0
11,930.0
18:00
18:45
1700 psi. No gas observed.
12/13/2018
12/13/2018
1.50
PROD1
DRILL
REAM
P
Wash and ream down 200 gpm, 1590
11,930.0
12,121.0
18:45
20:15
1
1
1 psi. 40 rpm, 4-5k Tq.
12/13/2018
12/13/2018
1.75
PRODI
DRILL
DISP
P
Displace from 10.2 ppg LSND to 8.8
12,121.0
12,121.0
20:15
22:00
ppg Flo Pro, holding 10.2 on well with
MPD during displacement.
12/13/2018
12/13/2018
0.25
PRODI
DRILL
PMPO
P
Pump out from 12,121'MD to 12,025'
12,121.0
12,025.0
22:00
22:15
MD @ 200 gpm, 1500 psi, 60 rpm, 5k,
racking back 1 stand. Ramp down
pump, holding 575 psi initial with MPD
chokes.
12/13/2018
12/13/2018
0.25
PROD1
DRILL
OWFF
P
Perform MPD drawdown, Initial
12,025.0
12,025.0
22:15
22:30
pressure bled to 500 psi to start. Step
1 reduced to 142 psi, step 2=61 psi,
step 3=35 psi, step 4=25 psi. Abort
test for flow check.
12/13/2018
12/13/2018
0.25
PROD1
DRILL
OWFF
P
Flow check well at rotating head with
12,025.0
12,025.0
22-.30
22:45
Vis cup. initial 19 seconds to fill cup,
reduced to 60 second in 5 minutes.
Shut in.
12/13/2018
12/13/2018
0.75
PRODI
DRILL
REAM
P
Wash down from 12,025' MD to
12,025.0
12,126.0
22:45
23:30
12,126' MD @ 200 gpm, 1120 psi, 60
rpm, 4.5k Tq.
12/13/2018
12/14/2018
0.50
PROD?
DRILL
DDRL
P
Directional drill from 12,126' MD to
12,126.0
12,150.0
23:30
00:00
12,150' MD, 7,906' TVD @ 220 gpm,
1180 psi, 120 rpm, 7k Tq. ADT=.3 hrs
12/14/2018
12/14/2018
11.50
PRODI
DRILL
DDRL
P
Directional drill from 12,150' MD to
12,150.0
13,263.0
00:00
11:30
13,263' MD, 7,950' TVD @ 230 gpm,
1180 psi, 140 rpm, 7.6k ftlbs T( ADT=
9.3 hrs
12/14/2018
12/14/2018
1.00
PROD1
DRILL
CIRC
P
Circulate bottoms up 230gpm 1720psi
13,263.0
13,263.0
11:30
12:30
80rpm 4k ftlbs tq to evaluate samples.
12/14/2018
12/15/2018
11.50
PROD1
DRILL
DDRL
P
Directional drill from 13,263' MD to
13,263.0
14,430.0
12:30
00:00
14,430' MD, 7,964' TVD @ 230 gpm,
1930 psi, 140 rpm, 7.5k ftlbs Tq.
P/U=187k, S/0=137k, ROT=161 k.
ADT= 9.5 hrs
12/15/2018
12/15/2018
12.00
PROD1
DRILL
DDRL
P
Directional drill from 14,430' MD to
14,430.0
15780.0
00:00
12:00
15,780' MD, 7,943' TVD @ 230 gpm,
2510 psi, 140 rpm, 9.5k ftlbs Tq.
P/U=190k. S/0=130k, ROT=155k.
ADT= 9.0 hrs
Swapped mud returns to MGS @
14,500' MD due entrained gas.
12/15/2018
12/15/2018
5.25
PROD1
DRILL
DDRL
P
Directional drill from 15,780' MD to
15,780.0
16,296.0
12:00
17:15
16,296' MD, 7,971' TVD @ 230 gpm,
2450 psi, 140 rpm, 9k ftlbs Tq.
PIU=187k, S/0=130k, ROT=150k.
ADT= 4.5 hrs
12/15/2018
12/15/2018
1.50
PRODi
CASING
BKRM
P
BROOH from 16,296' MD to 16,023'
16,296.0
16,023.0
17:15
18:45
MD @ 230 gpm, 2360 psi, 140 rpm,
9k. Holding 150 psi back pressure on
connections.
12/15/2018
12/15/2018
2.25
PROD1
CASING
CIRC
P
Circulate 2 bottoms up @ 230 gpm,
16,023.0
15,928.0
18:45
21:00
2060 psi, 140 rpm, 71k. Rack back
stantl to 15,928'.
Page 19/23 ReportPrinted: 1212612018
operations Summary (with Timelog L,epths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Start Depth
SfeM1Time
End Time
our (hr)
Phase
Op Code
Actevily Code
Time P -T -X
Opem4on
(WS)
End Depth(ftKB)
12/15/2018
12/15/2018
0.25
PROD?
CASING
OWFF
P
Perform MPD fingerprint, no pressure
15.928.0
15,928.0
21:00
21:15
build after 3 cycles, 9 psi steady shut it
after minutes.
SIMOPS- Swap mud returns from
MGS to Flowline,
12/15/2018
12/15/2018
2.25
PROD1
CASING
DISP
P
Displace well to 9.2 ppg Vis Brine with
15,928.0
15,928.0
21:15
23:30
2% Lube 776 with 30 bbl spacer,
followed by 550 bbl 9.2 Vis brine @
240 gpm, 100 rpm, 6.5k Tq.
FCP=1420
12/15/2018
12/16/2018
0.50
PROD1
CASING
OWFF
P
Monitor well for Flow, static in 12
15,928.0
15,928.0
23:30
00:00
minutes.
SIMOPS- Blow down lop drive and
line up to SOON. Swap to rig
gaswatch from mudlogger gas sensor.
12/16/2018
12/16/2018
3.25
PROD1
CASING
SMPD
P
Strip out of hole N 15928'to 13220'.
15.928.0
13,263.0
00:00
03:15
Holding 80psi backpressure on/off
slips. Observe 30k overpull at 13220'
Run back in to 13263'. Attempt to work
through 3 times. No success, up/200k
down 130k
12/16/2018
12/16/2018
1.25
PROD1
CASING
CIRC
T
Circulate bottoms up 230gpm.
13,263.0
13,168.0
03:15
04:30
1200psi. 140rpm. 5-6k ftlbs tq. 152k
rot wt. Rotate/Reciprocate f/ 13263'
U13168'.
12/16/2018
12/16/2018
1.25
PROD1
CASING
SMPD
P
Strip out of hole f/ 13168' 1/ 11930'.
13,168.0
11,930.0
04:30
05:45
Holding 80psi backpressure on/off
slips. up wt 192k. (Insert 2.1" hollow
drift @ 12311'). ( Shoe @ 12026')
12/16/2018
12/16/2018
1.00
PROD1
CASING
CIRC
P
Circulate bottoms up. 240gpm.
11,930.0
11,835.0
05:45
06:45
1
1
1200psi. 80rpm. 3.5k ftlbs tq.
12/16/2018
12/16/2018
0.50
PROD1
CASING
OWFF
P
Flow check. Static.
11,835.0
11,835.0
06:45
07:15
12/16/2018
12/16/2018
1.75
PROD1
CASING
SMPD
P
Strip out of hole f/ 11 930' t/ 9739'.
11,835.0
9,739.0
07:15
09:00
Holding 80psi backpressure on/off
slips. 192k up/130k down.
12/16/2018
12/16/2018
0.25
PROW
CASING
OWFF
P
Flow check. Static
9,739.0
9,739.0
09:00
09:15
12/16/2018
12/16/2018
0.50
PROD1
CASING
CIRC
P
Pump 29bbls loppg slug.
9,739.0
9,739.0
09:15
09:45
12/162018
12/16/2018
2.25
PROD1
CASING
SMPD
P
Strip out of hole f/ 9739't/ 4319'.
9.739.0
4,319.0
09:45
12:00
Holding 50/80psi backpressure on/off
slips. 113k up/105k down.
12/16/2018
12/16/2018
0.25
PROD1
CASING
OWFF
P
Flow check. Static. (Held PJSM for
4,319.0
4,319.0
12:00
12:15
pulling RCD bearing and installing trip
nipple).
12/16/2018
12/16/2018
0.75
PROD1
CASING
MPDA
P
Pull Rod bearing assembly. Install trip
4,319.0
4,319.0
12:15
13:00
nipple.
12/16/2018
12/16/2018
1.50
PROD?
CASING
TRIP
P
Pull out of hole f/4319'tl 333'.
4,319.0
333.0
13:00
14:30
12/16/2018
12/16/2018
0.25
PROW
CASING
OWFF
P
Flow check. Static. (PJSM for I/d bha).
333.0
333.0
14:30
14:45
12/16/2018
12/16/2018
2.75
PROD1
CASING
BHAH
P
LID BHA. Clean and clear rig Floor.
333.0
0.0
14:45
17:30
12/16/2018
12/16/2018
1.50
COMPZN
CASING
RURD
P
PJSM. RU to run 4 1/2" liner.
0.0
0.0
17:30
19:00
12/16/2018
12/17/2018
5.00
COMPZN
CASING
PUTB
P
RIH w/ 4 /12" 12,6# L80TXP liner to
0.0
3,784.0
19:00
00:00
3784'. MU TO 7k ft/lbs.
12/17/2018
12/17/2018
0.50
COMPZN
CASING
PUTB
P
RIH w/ 4 /12" 12,6# L80TXP liner f/
3.784.0
4,188.0
00:00
0030
3784' to 4188'. MU TO 7k ft/lbs.
Page 20123 Report Printed: 1212612018
operations Summary (with Timelog uepths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Stan Tlme
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time RDX
Operation
startoopm
(MKa)
End Depth (WB)
12/17/2018
12/17/2018
2.00
COMPZN
CASING
OTHR
P
MU and RIH w/ 5" x 7" flex lock
4,188.0
4,339.0
00:30
02:30
hanger/5" x 7" HRDE ZXP packer. MU
to stand of 4" DP. Break circulation.
3bpm. 90psi. up98k/down 95k.
12/17/2018
12/17/2018
5.50
COMPZN
CASING
RUNL
P
RIH w/ 4.5" liner on DP to 11945'.
4,339.0
11,940.0
02:30
08:00
break circulation every 20stds.
Take weights before going in to OH.
up175k/down140k/Rot155k. TQ
1 Orpm 41k ff/Ibs/20rpm 4k ft/lbs
12/17/2018
12/17/2018
3.75
COMPZN
CASING
RUNL
P
RIH w/ 4.5" liner on DP f/ 11940'to
11,940.0
16,035.0
08:00
11:45
16035'. Set down 15k @ 13558'.
Wash down at 2.5bpm 200psi f/
13558' to 13653'.
12/17/2018
12/17/2018
0.25
COMPZN
CASING
RUNL
P
Set liner shoe on depth @ 16090'.
16,035.0
16,090.0
11:45
12:00
up2001k/down140k. break circulation
12/17/2018
12/17/2018
1.00
COMPZN
CASING
CIRC
P
Circulate bottoms up at 4bpm 510psi.
16,090.0
16,090.0
12:00
13:00
12/17/2018
12/17/2018
1.75
COMPZN
CASING
PACK
P
Drop 1.625" ball and pump down at
16.090.0
11,948.0
13:00
14:45
3bpm 300psi. Ball on seat after 90bbls
pumped. Hold 650psi 1minute.
Pressure up to 2300psi to set hanger.
SO 401k to confirm hanger set.
Pressure up to 4000psi to release
running tool. PU 4'to expose dogs.
Set packer by rotating and setting 401k
down. PU to neutral weight 1501k.
Top of liner @ 11863.91'
12/17/2018
12/17/2018
0.50
COMPZN
CASING
PRTS
P
Test packer to 3300psi for 10 minutes.
11,948.0
11,948.0
14:45
15:15
good test charted.
12/17/2018
12/17/2018
0.25
COMPZN
WELLPR
TRIP
P
POOH f/ 11948'to 11830'
11,948.0
11,830.0
15:15
15:30
12/17/2018
12/17/2018
1.00
COMPZN
WELLPR
CIRC
P
Circulate bottoms up at 5bpm 490psi.
11,830.0
11,830.0
15:30
16:30
12/17/2018
12/17/2018
0.25
COMPZN
WELLPR
OWFF
P
Flow check. Static
11,830.0
11,830.0
16:30
16:45
12/17/2018
12/17/2018
0.25
COMPZN
WELLPR
TRIP
P
POOH f/ 11830'to 11798'
11,830.0
11,798.0
16:45
1700
12/17/2018
12/17/2018
0.25
COMPZN
WELLPR
CIRC
P
Pump 23bbl 10+ ppg slug.
11,798.0
11,798.0
17:00
17:15
12/17/2018
12/17/2018
2.25
COMPZN
WELLPR
QEVL
P
POOH from 11798'to 9607' at
11,798.0
9,607.0
17:15
19:30
18000/hr logging w/ SCMT tool.
12/1712018
12/17/2018
1.50
COMPZN
WELLPR
SI -PC
P
PJSM. Slip/cut 60'tldll line
9,607.0
9,607.0
19:30
21:00
12/17/2018
12/17/2018
0.25
COMPZN
WELLPR
SVRG
P
Service rig
9,607.0
9,607.0
21:00
21:15
12/17/2018
12/18/2018
2.75
COMPZN
WELLPR
PULD
P
PJSM. POOH UD 4" DP f/ 9607' to
9,607.0
16,090.0
21:15
00:00
6848'
12/18/2018
12/18/2018
5.50
COMPZN
WELLPR
PULD
P
Continue UD 4" DP f/ 6848' to 105'.
6,848.0
105.0
00:00 j
05:30
(26jts culled for wear).
12/18/2018
12/18/2018
1.00
COMPZN
WELLPR
BHAH
P
PJSM. UD bumper sub/running tool/
105.0
0.0
05:30
06:30
SCMT tools.
12/18/2018
12/18/2018
0.50
COMPZN
WELLPR
BHAH
P
Clean/clear rig floor.
0.0
0.0
06:30
07:00
12/18/2018
12/18/2018
0.75
COMPZN
RPCOMP
W W WH
P
MU jet sub. Jet BOP. Retrieve wear
0.0
0.0
07:00
07:45
bushing.
12/18/2018
12/18/2018
1.00
COMPZN
RPCOMP
RURD
P
RU tubing handling equipment.
0.0
0.0
07:45
08:45
12/18/2018
12/18/2018
3.25
COMPZN
RPCOMP
PUTB
P
PJSM. RIH w/ 4.5" TSH blue
0.0
1,338.0
08:45
12:00
completion string to 1338'
12/18/2018
12/19/2018
12.00
COMPZN
RPCOMP
PUTB
P
Cont. to RIH w/ 4.5" TSH blue
1,338.0
11,348.0
12:00
00:00
1
I
completion string f/1338' to 11,348'
Page 21/23 Report Printed: 1 212 612 01 8
operations Summary (with Timelog Uepths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
sWtl Time
End Time
Dur(hr)
Phase
Op Code
Activity Code
Time P -T -x
Operation
SWA Depth
(flKB)
End Depth(ftKS)
12/19/2018
12/19/2018
1.00
COMPZN
RPCOMP
PUTB
P
Cont. to RIH w/ 4.5" TSH blue
11,348.0
11.788.0
00:00
01:00
completion string f/11.348'to 11,788'
12/19/2018
12/19/2018
1.75
COMPZN
RPCOMP
HOBO
P
M/U 2 extra its & head pin to locate
11,788.0
11,841.0
01:00
02:45
seals & no-go out. Locate top of liner
11,864'w/ 1 bpm, observe pressure
increase. S/O to fully locate on no-go.
POOH w/extra its & M/U space out
pups.
12/19/2018
12/19/2018
1.00
COMPZN
RPCOMP
THGR
P
M/U tubing hanger, landing it A& head
11,841.0
11,841.0
02:45
03:45
pin. Wash down w/1 bpm & locate top
of liner. Observe pressure increase.
Pull hanger to rig floor & prep for
displacement.
12/19/2018
12/19/2018
1.50
COMPZN
RPCOMP
CRIH
P
PJSM. Pump 20 bbl;s spacer
11,841.0
11,841.0
03:45
05:15
Displace well with 100 bbl 9.2 ppg
Gear brine, followed by 153 bbl
corrosion inhibited brine, displace with
174 bbls 9.2 ppg clear brine.
12/19/2018
12/19/2018
0.50
COMPZN
RPCOMP
OWFF
P
F/C (static)
11,841.0
11,841.0
05:15
05:45
12/19/2018
12/19/2018
0.50
COMPZN
RPCOMP
THGR
P
Land tubing on hanger @
11,841.0
11,874.0
05:45
06:15
11.874' (3.88' from fully located)
12/19/2018
12/19/2018
1.50
COMPZN
RPCOMP
THGR
P
R/U to test. Pressure test hanger
11,874.0
11,874.0
06:15
07:45
seals to 250 psi 5min & 5000 psi for
10 minutes
12/19/2018
12/19/2018
1.75
COMPZN
RPCOMP
PRTS
P
Drop ball and rod. Pressure test
11,874.0
11,874.0
07:45
09:30
surface lines to 4300 psi (good). Test
tubing string to 4200 psi & observe
pressure increase on IA. Appears fluid
is leaking past SOV in GLM. Discuss
options with town. Pressure up on IA
to 1000 psi & got returns thru tubing &
confirming fluid leaking thru GLM.
Decision made to R/U slick line & set
dummy valve.
12/19/2018
12/19/2018
1.00
COMPZN
RPCOMP
RURD
T
R/D landing jt A. Clean & clear floor.
11,874.0
11,874.0
09:30
10:30
Mobilize slick line to location.
12/19/2018
12/19/2018
2.50
COMPZN
RPCOMP
WAIT
T
Wait on slick line. SIMOPS - clean rig
11,874.0
11,874.0
10:30
13:00
& prep for rig move.
12/19/2018
12/19/2018
9.25
COMPZN
RPCOMP
SLKL
T
R/U slick line. RIH w/OMK retrieval
11,874.0
11,874.0
13:00
22:15
tool to pull SOV. Un -successful. Make
second attempt to pull SOV. Un-
successful. Appears to be junk in hole.
RIH w/bailer & recover significant
amounts of dark grey heavy pasty
substance. Make second bailer run &
recover same. M/U retrieval tool & RIH
& retrieve SOV. (Success)
12/19/2018
12/20/2018
1.75
COMPZN
RPCOMP
SLKL
T
RIH w/ dummy valve & set. Pressure
11,874.0
11,874.0
22:15
00:00
up on IA to 200 psi & confirm set
(good)
12/20/2018
12/20/2018
1.00
COMPZN
RPCOMP
SLKL
T
POOH w/slick line dummy valve
11,874.0
11,874.0
00:00
01:00
setting tool.
12/20/2018
12/20/2018
2.00
COMPZN
RPCOMP
PRTS
T
R/U testing equipment. Pressure test
11,874.0
11,874.0
01:00
03:00
tubing string to 4200 psi for 30
minutes charted. Bleed tubing down to
2000 psi. Test 7" x 4%" IA to 3300 psi
for 30 minutes charted. Bleed off
everything to 0 psi. R/D testing
equipment.
12/20/2018
12/20/2018
7.00
COMPZN
RPCOMP
SLKL
T
Slick Line attempt to pull dummy
11,874.0
11,874.0
03:00
10:00
valve. No success. RIH within
bailer run
and recover more sludge. RIH and pull
dummy valve. R/D slick line.
Page 22/23 Report Printed: 1 212 612 01 8
operations Summary (with Timelog Lrepths)
MT6-09
Rig: DOYON 19 Job: DRILLING ORIGINAL
Time Log
Sten Time
Ertl Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
Start Depth
(RKS)
End Depth(flKB)
12/20/2018
12/20/2018
2.00
COMPZN
WHDBOP
MPSP
P
FMC install HP BPV M/U landing jt B.
0.0
0.0
10:00
12:00
Pressure test BPV in direction of flow
to 2500 psi. UD landing it B. SIMOPS
- B/D mud lines, choke & kill lines.
12/20/2018
12/20/2018
2.50
COMPZN
WHDBOP
MPDA
P
PJSM. N/D flow box, & MPD
0.0
0.0
1200
14:30
equipment.
12/20/2018
12/20/2018
3.50
COMPZN
WHDBOP
NUND
P
N/D BOPE. Break ram doors for
0.0
0.0
14:30
18:00
BWM. Remove choke & kill lines.
SIMOPS - CIO saver sub
12/20/2018
12/20/2018
0.50
COMPZN
WHDBOP
NUND
P
Install Smooth Bore Metal Seal, install
0.0
0.0
18:00
18:30
plug off tool in HP-BPV profile per
FMC.
12/20/2018
12/2012018
1.50
COMPZN
WHDBOP
NUND
P
N/U tree adapter flange, test to 5000
0.0
0.0
18:30
20:00
psi CPAI witnessed. Fill tree with
diesel.
12/20/2018
12/20/2018
2.25
COMPZN
WHDBOP
PRTS
P
Fill tree w/diesel & R/U to test. Test
0.0
0.0
20:00
22:15
tree to 250 psi low, 5000 psi hi for 10
minutes each charted.
12/20/2018
12/20/2018
0.75
COMPZN
WHDBOP
MPSP
P
FMC remove HP-BPV. SIMOPS- R/U
0.0
0.0
22:15
23:00
1
1 circulating lines to freeze protect.
12/20/2018
12/21/2018
1.00
COMPZN
WHDBOP
FRZP
P
PJSM. Flood lines w/diesel. PT &
0.0
0.0
23:00
00:00
check for leaks. Swap out hoses in
cellar. Pressure test lines to 2500 psi
I(good)
12/21/2018
12/21/2018
2.00
COMPZN
WHDBOP
FRZP
P
Ball Mill pump 47 bbls diesel for freeze
0.0
0.0
00:00
02:00
protect. Shut in & let U-tube for 1 Hr.
SIMOPS - Prep cellar for move & prep
Ito
secure well.
12/21/2018
12/21/2018
2.25
COMPZN
WHDBOP
MPSP
P
Rig up FMC lubricator, test to 1000
0.0
0.0
02:00
04:15
psi. Install HP-BPV & test to 2500 psi
(good). Final Tubing = 100 psi, IA=
100 psi, & OA= 80 psi. Well Secure at
4:15 Hrs
12/21/2018
12/21/2018
0.75
COMPZN
WHDBOP
RURD
P
RID & B/D lines & clean well head &
0.0
0.0
04:15
05:00
1
tree.
12/21/2018
12/21/2018
1.00
DEMOB
MOVE
RURD
P
UD misc tools & equipment from rig
0.0
0.0
05:00
06:00
1
floor. Install mouse hole.
12/21/2018
12/21/2018
8.50
DEMOB
MOVE
PULD
P
UD 68 stands of 4" & 22 stands of 5"
0.0
0.0
06:00
14:30
DP via mouse hole.
12/21/2018
12/21/2018
1.50
DEMOB
MOVE
CLEN
P
Clean drip pan & pipe racks
0.0
0.0
14:30
16:00
12/21/2018
12/21/2018
4.00
DEMOB
MOVE
RURD
P
Stage BHA tools & equipment. Prep
0.0
0.0
16:00
20:00
for move. Pull mouse hole. Secure
derrick climber. B/D steam.
12/21/2018
12/22/2018
4.00
DEMOB
MOVE
RURD
P
Prep for rig move, blow down water to
0.0
0.0
20:00
00:00
sub, disconnect service lines in
mezzanine and pits. Back away pits &
motors complex & inspect mat boards
& herculite from previous spill. Skid rig
floor. Raise stompers & prep to move
sub away from well. Rig release @
00:00 hrs 12/22/18
Page 23123 ReportPrinted: 12/2612018
ConocoPhillips
ConocoPhillips(Alaska) Inc. -WNS
Western North Slope
GMT1 Lookout Pad
MT6-09
60-103-20779-00
Baker Hughes INTEQ
Definitive Survey Report
19 December, 2018
BAT
UGHES
GEta ,,
Compny.
C000mPhl9ips(Alaska) Inc -V S
FB gy
ircHEs
Pm)ea.
Make. North Slope
Site:
GMTt Lookout Pad
Well:
MT6419
Wellbore:
MT"9
oeal9n:
A21kp01
Profen
Wesurn North Slope, Noah Slope Alaska, United States
Map System:
US State Plane 1927 (Exact solution) System Datum:
Geo Uatum:
NAD 1927(NADCON CONUS)
Map Zone:
Alaska Zone 04
Punh
Well
MT"9
Well Position
AWS 0.00 unit
Northing:
316,984.85us0
.Em 0.00.sit
Eaating:
Position Uncertainty 0A0 ueit
Wellhead EI
WMlbom
MTe-09_
pip Angle
MagnMloa
activists.. Sample Data
(1
I-1)
BGGM2018 11/19/2018
80.69
Design MT6d9
Audit Notes:
Version: 1.0 Phase: ACTUAL
Writing U000: Depth Fresh (M)
(deft)36,64
deft)
36 64
ConocoPhillips
Survey
Oambin
FB gy
ircHEs
Definitive Survey Reportr
Local Coordinate Reference:
WEA MT&09
TVD Reference:
ACTUAL MT&09®88.94usft(Doyonl9)
MO Reference'.
ACTUAL MT"9 ® III (Doyonl9)
North Reference:
Thus
Calculation Memod:
Minimum Curvature
e'.
EDT 14 Alaska Production
Mean Sea Level
Using Vnell Referee
Punh
Using geodetic scale factor
5,945,516.47usft
` Latitude:
70° 15'22S77 N
316,984.85us0
Longitude:
151° 20' 45.0% W
.kation: 0.00usft
Ground Level:
37.20 out
Dec0wtlon
pip Angle
Field 5lmngda
(1)
(1
I-1)
16,30
80.69
57,387
Te On Depth: 36.64
•kAS eFJ4N Dinotl..
(daft) (oan) P)
0.00 0.00 312.64
12/19/1010 5'12:43PM Page 2 COMPASS 500014 B.W SSD
ConocoPhillips ER A
ConocoPhilli
ps Definitive Survey Report
Company:
ConocoPhilips(Alaska) Inc. -MS
Local OOnadnats Reference:
Well MT6-09
Project:
Weslam North Slope
TVD Reference;
ACTUAL MT6419@ 80.94usB(Doyonl9)
K8abtlon
MD
So,
GMTi Lookout Ped
MD Reference:
ACTUAL MT84)9@ 88.94s8(Doyonl9)
+WS
+Ely2
Well'.
MT649
North Reference:
Tme
(own
(n
Wellbore:
MTB -09
Survey Calculation Method:
Minimum Curvature
(usm
m)
Design:
A2- 01
D.base:
EDT 14 Alaska Production
000
000
Survey Program
Data
0.00
000
5,90.5,516.47
31fi HBG.65
From
To
M14
0.80
Survay
Survey
(.an)
(-am Survay [W.Mare)
Tool Nam
DesoNptlon
son" Dain
End Data
73.14
1,009.87 1. Gymdzla Gy.SS 16" (MT6-09)
GYD-CT-DMS
Gymdsta wnt.dhll ipa Ms
111212018
1112112018
1,052.98
2.M.28 2. BHGE MWD+IFR+MSA IW(MTB59)
MWD+IFR-AK-CAZSC
MWD+IFR AK CAZ SCC
11442018
111212010
2,175.41
10,364.48 3. BHGE MM ATKAFR+MSA 12114"(M
MWO+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
11212018
11262018
10,500.71
12,08D.58 4. BHGE MMAFR+MSA 6 We(MT64)
MMAFRAK-0A C
MWDAFRAKCAZSCC
1L3IZo18
VRLM
12,182.47
16,184.20 5. BHGE MWONFR+MSA 419"(MT64
MWD+IFR-AK-CAZSC
MWD+IFR AK CAZ SCC
ID1712BIR
12/1712018
Survey
iNI81t018 4'12:0.9fMy Page 3 COMAISS 5000.14 Build SSD
Map
Map
K8abtlon
MD
Ine
AN
TVD
T11D99
+WS
+Ely2
Nonong
Est 9
DLE
Survay Tool Nam AnflDtetion
(own
(n
(•)
(u -m
(-am
(ualt)
(usm
m)
Im
(.11w)
m)
35.60
000
000
W.08
5230
0.00
000
5,90.5,516.47
31fi HBG.65
0.00
0.00 UNDEFINED
M14
0.80
105.82
73,14
-1500
414
004
5,944516.33
316998,89
126
4.12 GYD-0T-0M9(1)
165,05
0.70
183.59
165.84
76.90
-1.05
on
5945.51542
316,985M
a'.
4.92 G T-OMS(1)
25TI2
0.78
17421
257.11
197.9
-2.20
050
5,94551426
316,995,30
0.18
d.66 GYDCT-0445(1)
VRLM
000
211.82
3W.32
26139
a.M
0.22
5,945,513.08
316,98450
0.54
245 GYD-CT-DM6(1)
444.54
2.85
274.05
4.4B
35554
A79
-230
5,945,512.74
316,80245
253
-0087 GYMT-DM611)
539.47
989
282.11
53430
445,88
-2.79
43,42
5,945,513.89
316,97539
243
4.31 GYMT-OM6(1)
633.69
6A5
289.28
63 0
54401
5.19
-1]R
6945.51670
316,997.47
1.81
1266 GYDCT-0445(4)
727.03
a'"
259.51
725.45
630.52
393
-29.10
5,945521.11
316,95586
2.56
24.07 GY0. T-0MS(1)
02152
10.47
200M
MAI
79.57
P.
-0356
5,945526.97
316.841.14
1.74
38.73 GYDZT-DMS(1)
91595
11.55
92.93
911.30
8M.36
1616
-Bow
5,945,534.13
316,82469
1.21
55.60 GYD-CT-DMS(1)
1.00957
12.51
939
I.M.15
91421
2387
-78.58
5945542.25
31600.70
1.02
74.05 GYMT-0M6(1)
1,06298
13.53
M.72
104515
958,21
27.90
87.51
5.945.546.49
316898.05
269
83,9 MMD+IFR-M-CAZSC(2)
1, 146A9
15.59
29641
1,1man
1045.72
38.24
-108.62
580.5,y/.34
316,877.19
221
105.81 MbD+IFR-AK-CAZSC(2)
1,241.75
1904
294.65
1,29,N
1.137.90
50.09
-IMM
5045,569.78
315852.62
2.63
132.13 MWDHFR-P AZ -SC 121
1,33857
19.69
293,72
1,315.58
127.62
62.fie
-16147
5,94558301
316,824.96
1.77
161.21 MWDHFRJ-CAZSC(2)
1,430.45
21.9
9277
1,404.52
1,315.58
7557
49160
5,94559&57
316,79545
165
19214 MWO+1FR-AK-CAZSC(2)
1,U&M
23,31
9078
1490.85
1,401.91
8&65
-22441
5.945,610.54
316.762.67
2.40
22513 MWDNFRAKCPZSC(2)
1.618.89
25,59
260.97
1577.47
1,48853
102.51
46128
5,845,625.30
316,TM.15
240
26164 M IFRAKCAZSC(2)
iNI81t018 4'12:0.9fMy Page 3 COMAISS 5000.14 Build SSD
�. ConoeoPhillips
ConocoPhillips Definitive Survey Report
Co.,.,
ConcoPbBhps(Aleska) I., -MS
Local Coordinate Reference:
Mh MT"9
Project:
Mhslem NOM Slope
TVD Reference:
ACTUAL 0276-09®88.Musn(Doyanl9)
Sde:
GMT1 lookout Pad
MD Reference:
ACTUAL MT649@ 08.94usn(Doyonl9)
Well:
MT649
North Reference:
Tme
We0bom:
02]6419
survey Calculation Method:
Minimum Co.tum
Design:
A2-Wp01
Database:
EDT 14 Alaska Production
Survey
Annotation
13418" x 16"
lsqI s
lWf9 18 S143PM Page 4 COMFASS 5000.14 9uM BSD
WP
Map
Vertical
MD
luck)
Inc
19
pL
Typ
1VDee
♦WS
4E1W4
Noohing
Easling
DLS
Section Survey Tool Name
1°I
hurry
IMat1)
(,am
luanj
IN
/R)
I°floal
Int
1]1263
2794
29241
1,99717
1,5.223
117.95
-30055
5945,641.)0
31668727
260
301.00 MWDNFRJJ AZSC RI
1801.16
29.92
293.03
1,743,50
1 054.96
13563
.142.13
5,945.660,38
316.645.54
212
34]99 Mr4➢+IFR-M-CAZSC(2)
1,901.11
3090
M251
1B2F.02
1,135.90
154.06
398,51
5,945619.01
316,602.16
1,07
MS,n NIAD+1FR-A"AZS0(2)
1,99530
32.85
291.84
1.90490
181596
IMM
4.,62
5945,899.71
316.556.59
2.11
435.33 MND+1FRAkL -SC (2)
2,09028
MA7
2SZ13
1,984.41
1,895.47
19229
4.79
5,945.nD38
316,50090
Obi
483.94 MWD+IFR-AK-CAZSC(21
2,11541
3384
29ZM
2.45527
1,25633
21002
524,51
5,945,139.17
316,46563
0.
UBAI MWDNFR✓J(LAZSC(3)
2,2ID.07
MM
29233
2133,31
2,044.43
23022
514.05
5,945 M%
316.416.60
122
57823 WiV IFR-AK-CAZSC(3)
2304.05
W..
02.95
2,2011.46
2,1211.52
25145
52495
5,945,183,02
318.95821
208
63008 M°ND+IFRAKLAL (3)
2.459.43
3838
293.81
2.204.98
219804
21461
51840
5.945807.
318,31335
1.67
68507 MADNFRAK-0AZSC(3)
2.55210
40.13
293.54
235724
226830
24835
-13240
5,945832.51
316,25908
1.88
14093 MWD+IFR-P AZSC(3)
2.64743
41.60
28359
2.AMM
2,33889
3.446
48823
5,945.858.68
316 75
158
799A9 MWD+IFR✓J(-0AZSC(3)
2,142,32
429D
20210
2499.07
2,410.13
34828
.44780
594588923
316,14514
1,54
0 S4 IMD+IFR- -CAZSC(3)
2,836.00
4307
29205
2,557.60
2,478M
3.59
936.94
5945,91097
316,08729
051
91956 MMW+IFR-AK-CA (3)
293002
4325
.4228
2,63682
254128
39547
569.53
5.945836119
316.02831
025
91984 MWD+IFRAK{AZSC(a)
3.02402
43,211
291.85
2,104.84
2815.90
421ID
-102830
5,945952.36
315.56945
032
104022 MWDNFRAWCALSC(31
3,11842
43.44
292]1
217336
2084.42
44534
-1,08620
5,945,958.05
315,960245
0.37
1,10070 MWDHFR-P AZSC(3)
3,213.17
4329
29221
2,84224
2,753.30
46994
-160643
5940D1440
315,85025
0.16
1,161S7 MWDAFRAK AZ-SC(3)
3307M
433D
29189
2910.70
2,02184
49418
-1,20528
Sam D39 T9
315.79101
023
1,222.12 M IFRAK-CAZSC(3)
3,40141
43.43
291.85
2.97921
2,8X27
imm
-129+26
5,940p8531
315,13153
0.14
128256 MWD+1FRAK- 4C (J)
3,495]3
4325
2910
3,00.]7
2,95883
54?.
-1,32635
5,945,0. 73
315,812.14
025
1,%299 MWONFRAK-CAZSC(3)
3,59083
4348
29193
341632
3,02130
Sf6625
-1,3%.A0
5.946.11620
31561262
033
1,40350 14WDNFR-M-CAZSC(3)
3,683.48
41.
29197
3,184.02
3,09531
5X23
-1,446.00
5,946.14153
315,553.10
024
1,46353 MWDNFR-N M-0 C(3)
3,718.03
4333
29249
3,253.W
3.16411
614.76
4,505.00
5,946,18200
31549432
030
1,52428 MAD+IFRAK-CALSC(3)
3,011]5
4320
29186
332132
3,M38
63901
-1.3.50
5.945 ,19329
315.435.43
A.
1,58440 MWDNFRAK-0AZSC(3)
3,956.86
43.20
29179
3,3X00
3,301.14
66301
-1625.45
5.94621074
315310.09
005
164484 MWID+1FRAK4A C(3)
4.600.42
4524
2M25
3,49759
3,36875
681.68
-1,68643
5,916,244.00
315,31573
248
1,106.41 MWD.IFR-AK-0A C(31
4154.85
4702
293W
3.5MM
3,433.60
71/07
-114973
5,9462.80
31525310
2.91
1,11085 M +JFR-41(-CAZSC(3)
4,249.02
4863
293,33
3,584.(36
3,495.
741.94
-1814.84
5,94630224
315,1M.69
183
1,83782 MIFR- -CAZSC(3)
4,242.79
5304
29430
3,843.1
385429
771.51
-1,88180
5,945,33341
315,122.46
3,73
1,90691 MAD+IFRAK-CAZSC(3)
4,431.63
53.07
2 M
3700.24
3.01130
80301
-1,960,74
519451305.60
315.05431
044
1978,97 MND+IFRAK-C7 (3)
4.531.95
53,10
294,65
3.75609
368295
034.57
-201924
594639980
314,9M.61
0.15
205073 "D -IFR -AK -0 C(3)
Annotation
13418" x 16"
lsqI s
lWf9 18 S143PM Page 4 COMFASS 5000.14 9uM BSD
Conoco�hillip5
ConocoPhillips
Definitive Survey Report
Company: ConocoPhillips(Alaska) Inc.-WNS
Local Coordinate Reference:
WbII MTm9
Prefect: Westem NoM Slope
TVD Reference:
ACTUAL MTe-g@ 88.94usg(Doyonl9)
She: CMT1 Lookout Pad
MD Reference:
ACTUAL MT"9@ 88.94usn(DWonl9)
Well: MT6.09
North Reference:
Tve
Wellbpte: MT659
survey Calculation Method:
Minimum Curvature
Design: A2- 01
Database:
EDT 14 Alaska Production
Survey
Annotabon
1
1]192018 S 1240773 Pege 5 COMPASS 5000.14 Build 050
Map
Map
Vertkal
MD
Inc
Aal
TVD
NDSB
aW4
aV4V
NO
FaMlnp
DLS
Section Survey Tool Name
deft)P)
M
luefry
IMalll
laan(
Igpm
(111
Inl
(-glow)
nl
4,635.98
5305
2%.OB
3.813.30
3,II444
655.17.3,p8ZI4
5,916,13306
314.14, 919.20
037
2,1Y2.31 MWOgFR-AK-CA2SC(3)
4,=076
5305
295.01
3,870.17
3,]81.23
896.14
-2155.84
5,946,466.67
314,65100
0.08
2,194.28 MhNaIFRJJ AZSC(3)
4.014,31
53.15
294.49
3,926.52
3.837.58
9X.56
-2.22400
5,946.499.]3
314,784.23
045
236510 MDaIFR-MH X25[(3)
4.911.46
53.14
2MiM
3,984,79
3,895.85
961,79
-229474
5,94&533.6]
314,71430
001
2339.57 MNDaIFR--CAZSC(3)
5,008,06
53.11
291.97
404276
3,95302
99412
-{364.82
5.946 sun
314,64493
0.39
241310 MWD+IFR-A AecSC(3)
5,103.38
53,14
R 79
4099.30
4,01036
1X25.83
-2,433,30
5,8456oim
314,97.35
0.16
3,494.98 MWDNFRAK AZSC(3)
5,19557
530,
29110
4,155.30
4,065,36
1057,06
-0,501.06
5,84663392
314,510.37
0,10
2,555.80 ~+IFRAKCALSL(3)
5,280.19
5295
29463
4,211.2
4,12208
4087,94
-2,566.29
5,946.668.42
314,443.91
0,15
2,62&5 M IFR -N ALSC(3)
S.M3.00
5285
296,02
4.268.21
4,1]92]
1,119.69
-2,638.93
5948,699.83
314,3M.07
034
2.090.25 M -IFR-M( AZSC(3)
5.477,55
5294
295.29
4,325.25
4,236.31
1,151.74
-2706.10
5,945.733.53
314]0652
025
2,7]01] MNDaIFR-MI AZSO(3)
5,57185
$2.81
295.66
4,382,14
4,29320
1,181.0
-2773,07
5,946767.51
314.241.54
0.33
ZMZ02 MNDAFR-AK-CAZSC(3)
5,656.21
5300
295.46
4438.04
4,35010
1.21&56
-284098
5,840,001.63
314.174.44
0.24
291380 MWD+IFR- -CAZSC (3)
5,739.85
52.79
29539
4,495.59
4,406.66
1,24106
-2908.50
5,94x',03535
314,10)]2
033
2,995.40 MWD+IFR-AKCPZSC(3)
5,85398
5288
2 44
4,55232
4,463.38
1]01.42
-2975.93
5,94686974
314041.12
0.91
3.057.19 MWD+IFRAK-CPLSC(3)
5.948A3
53.11
290.09
4,80&03
4.519.09
1,314.19
-3,04234
5,946.90.11
313975.53
033
3,126.24 MWD+IFR-A AZ5CSI
604109
W2
295.39
4,WK.n
4,575.78
1,347.01
y110M
5,946,938.9
313.908.30
059
3,200.53 MJUD+IfR-N(-0X254(3)
6.13587
53,10
295.22
4,721.16
4,632.22
1,379.14
-3,1]63]
5,946.973.35
313.841.13
0.15
3,27230 ~.IFR -M( AZSC(3)
6.Zh,Q
5314
294.63
4777,80
4.88,86
1.410.96
5,24683
5,94],005.91
313.77348
0.50
3,344,21 MWD+IFR--CAZ-oC(3)
8,32410
53.11
29368
4,831.58
4145.64
144193
-33315.89
5,94]X3&45
313.705,18
0.80
3.416.00 MWO+IFRAKCA (3)
641002
53.07
294.11
4,89146
4,802.52
14R61
4385.13
5,947070,00
313,63670
037
3.487.72 MWOHFRAKLAZSC(31
6,512.06
53,07
29341
4,947.60
4,058.511
1,503.47
y45345
5847,10231
313569.14
086
3,566.20 MWUHFRAK-0AZSL(3)
61.46X2
53.87
M92
5,00394
4,915.01)
1,531.83
-3=56
5,947.13334
313,5001]
DA6
3,662X.93 MWD -IFR- AZSC(3)
6,701.14
5289
M41
5,061.13
4,072,19
1$61.11
.1,593X9
5,947,164.32
313431.37
044
3,70035 MJr➢aIFR-AK AZSC(3)
6.79382
5298
292.78
5,116.93
5,07,99
1.589.53
-3,661.02
5947,194.39
313.38373
0.30
3.]698] MWDNFR-AK{AZSC(3)
6,668X1
53.05
294.11
5.173.59
5,081X5
1,61946
-373005
5,947 M.98
313,ID5,ai
1.15
3M0.92 MWD+IFR-AI(-CAZSC(3)
6,98179
53.11
29538
5.20.92
5.14096
1650.84
J79&15
5.917259,01
313,22&17
1.08
3.91237 MM+1FRAK-CAZSC(3)
7,076602
53.11
295.97
5,2864a
5.19754
1,6&5.50
5,6636.07
5.73729330
313,161.07
0.50
3,49436 MMAFRAK-CAZSC(3)
7.1]0X5
5315
297.63
5,34200
5,253.95
1,]1].41
-3.93321
5847.32$03
313,011
101
4066]2 MWD+IFRAKCAZSC(3)
7,264.18
53.22
29590
0,39931
531037
1751.%
4.000,49
5,1736439
313028.14
147
4,129.20 Wac.IFRAKCA2SC(3)
7358.02
0299
29595
5473.45
5,3[3,51
178345
-4,066.55
5,947,398.09
312,963,011
025
4 1995 MNDaIFRVWLAZSL(3)
7,450.82
52.99
Asel
SSttM
54M57
1,81656
-4,13463
5,9474M.M
312895.
003
4,272.05 M +IFR-M-CAZSC(3)
Annotabon
1
1]192018 S 1240773 Pege 5 COMPASS 5000.14 Build 050
ConocoPhillips
ConocoPhillips
De(nitive Survey Report
Company: ConocoPhillips(Maska) Inc. -WAS
Local Co-andimm, Relertnce:
Wall MTB -D9
Pmfem: Westem North Slope
TVD Relarence:
ACTUAL 7676419 @ 88.94us0 (D,mn19)
She: GI Lookout Pad
MD Relennce:
ACTUAL MT689 a 88.94ush(DWonl9)
Well: MT6419
Nohh Rehlence:
Tme
Wellame: MT689
Survey Calculation MCMod:
Minimum Curvature
Design: A2-wygi
DalaEase:
EDT 14 Alaska Pmtluction
Survey
12/198016 5:1242PA4 Pape 6
%I�ueRCNFs O
Annotation
9518" x 12-114"
COMPASS 505014900d 860
Map
MP
wMul
MD
f (llah)
Inc
19
AcL
(°)
TVD
TVD65
+Nis
eEJN
NolNlnp
Ease.,
DL9
6egbn 6urvcy Tool Name
lusfq
(ush)
(ush)
luso)
Ilry
(°11007
fol
],50533
$2.93
395.]2
556644
5,479.50
1,04941
i,2D2,54
5,81
31212. 828.]5
0.17
0,31426 MWp+IFR-N(-0.4250/3)
].63]53
52.50
295.60
5,623 Be
5,535.04
1,801.20
4,260,07
5,947.50080
31276321
012
0,414.64 MWDHFR-AK-00250(3)
],]3253
5201
296.50
5.68128
5.59235
1,91455
4,33695
5,94]535.]1
312,695.97
0.]6
440].26 MWD+IFR-AK-0AZSC(3)
],82]35
52.0
295.61
5]38.4]
5,60953
194].72
-040470
5.94],5]051
312,620.97
0.76
4.559.63 M'00.10FR-AKLA25C(3)
7.921.01
53.01
M..14
5,Aa.90
5, man.
1,9]9.]8
4.4]2.41
5.90.604.21
312,56214
041
4,831.10 MM➢NFR--CA25C(31
j 0,01497
5300
28460
5051L8
5,]6250
2011.35
4,540.49
584],63],42
312494.85
046
4,71257 MDNFR-AK-CAMC(3)
8Mail
52,91
2150.81
5,90662
5,819.68
2,00299
4.60,8
5,94].11M]
312,426.87
0.20
0,]]450 MWDNFR-AM-CA2SC(3)
820431
52.84
295.04
5,955.59
5.8]0.65
207/71
46]].52
5,947 704.09
312,358.41
021
4.M,28 MWD+1FRJJ(CAZSC(3)
8,29876
5209
2449
6.MA2
5,833.48
2,10.01
4,]45.]2
5,80.737.04
312892.00
065
4.917.86 MWD+1FRAKCPLSC(3)
8,392.33
52.0
294.18
6079.14
5,99330
2135]]
-0014.07
590.789.44
312,22142
aloe
4,980]] MND+IFR-PM-CAZSC(3)
8,486.08
WA6
35098
6,13553
6,006.59
2167.32
4,02.40
5,90,0165
312,15681
034
5.059.77 MJN+IFR-N4CAL6C(3)
650060
5288
29523
8.19244
610350
2,198.78
4,851.15
590,81177
312.08689
110
5.13162 MND+1FR-M-CAZSC(3)
667350
52.0
295]2
634658
6,159.64
2.Z0.74
5,010.22
5,847,00.34
312.V12.0
0A3
5.M60 MWD+WR-AK-0AZ4iC 13)
876042
52.92
295,341
6.305,0
6216.66
2,26320
5,00635
5,847 90252
311855,31
0.32
5,274.77 MWDgFR-N4LAZS0(3)
0.0359
62.96
29307
6,]61.85
6.274.02
2,28562
6,155.07
5,947,936.53
311,111
023
5,34722 MVW+1FRAK AZSC(3)
8,956.73
520
N4M
6.419.07
6,33].13
2,3M.80
4,M.52
5,94290.41
311,820.]4
035
5.418.02 MND+IFRJRCAZSC(3)
9,068
52.80
20420
6,05.73
630,]9
2357.94
-5,290.]]
5,81402.12
31175336
0.33
540937 MND+1FR-M( AZSC(3)
8.144.05
5281
283.81
6,53202
6.443.0
2,30.34
5,358]3
5,906034.15
311.60.07
032
5,559.04 MWDNFR-AK-CAZSC(3)
9230}8
52.0
29452
658919
6500.8
2,419.32
5427.0
5,940,00.0
311.61].91
052
5,0152 MWDNFRAK-0AZSC(3)
9.334.10
52.95
294.61
6,605.73
6.557.79
2,45095
5.49i
5.940,10010
311$49,54
012
5.703.05 ~+IFR-AWCAZSC(3)
9.4240
52.85
84.41
6,703.62
4614.60
2,48222
6,5653.
5,948.133.02
317.401.]5
0.9
5,]75.4] Nei (3)
952324
52.50
294.36
6.70.63
07169
2,51340
5,00.18
5,9@1.16587
311,413,74
.04
5,842211 MND+IFR- -CAZSC(3)
8,618.00
5292
28421
6,017.79
6,]28,0
2500.53
-5,M.19
em.190.0
311,345.52
0.13
5,81904 MND+IFR-N(-CAL (3)
97120
5291
294.]]
6874.48
6,78552
257561
5,]]1.40
5944231.38
311.278.0
0.0
5,99028 MWD+1FR--CAZ4iC(3)
9.0588
52.91
285.17
0,01,01
6,84210
3,0720
$039.26
5,840.264.62
311,211.0
0.34
6,06158 MWDHFRAKLPZSC(3)
9,930.85
53.00
295.73
6,918 1
6.899.37
2,63901
5.9077]
5,908398.87
311143.33
048
6.134.00 M O+IFRAKZAZSC(31
90483
53.0
2%.03
7,044]9
6,955.85
2,6.254
5,975.24
5,90633323
311.11MM
026
6,21586 MWO+IFR-AK-CAZSC(3)
1009.11
5250
XE16
7,10154
7,01260
2]05.0
4S04285
5,818357.98
311009.90
013
6,27605 MWD+IFR-M{AZSC(3)
10,181.66
5291
29645
7,15732
7,00,30
27311.38
8,109.05
5910.402,31
310.944.51
026
6,%092 MND+IFR-N(-CAZSC(3)
102]4.74
53.09
20.30
2213.33
7,12439
2]]101
5,175.65
5,948.436,84
310,8]0.]4
0.23
6,42020 MWDHFRAK-CA!SC(3)
10,364.40
5297
29 1
72 7..30
71636
2.8ni
-6 239+M
5.948.00.44
31001536
033
6,589.15 MWD+tFRAK- AZSC(3)
12/198016 5:1242PA4 Pape 6
%I�ueRCNFs O
Annotation
9518" x 12-114"
COMPASS 505014900d 860
Surely
ConocoPhillips
corloc blimps
Definitive Survey Report
Map
j Company. COOo00Phl1liptAlaeke) Inc. -AWS
Local CogMlnate Reference:
Mil MT"9
j Prepat Wastem North Slope
ND Reference:
ACTUAL MT609 C 88.94usX(Doyanl9)
i ams: GMTI Laokout Ped
MO Refinence:
ACTUAL MT6A9 a 88.94us11(Doyoal9)
:Wag: MT6.09
North Reference:
True
WaIlamaC MTM9
Survey Calculation Method:
Minimum CuneWm
� Diew: A ,Aw1
Database:
EDT 14 Alaska Production
Surely
Annotation
6- x 6814'
IVIWO16 5:12:43PBf Page 2 COMPASS 5900 14 B" 659
Map
Vertical
MD
(ac nl
NIC
(1)
RL
C)
TVD
lush)
ND55
(uaR)
-NIS
(usn)
rE/yy
lush)
NpnMng
Eating
OLS
01w)
Seclpn SYnOy Teal WTe
INI
(N)
(M
10,500.21
5333
2934]
7 34901
)260.0]
2.85376
A336A9
5,946523.17
310.719.96
108
559436 MWDrffRAK-CAZSC(4)
10,59512
SE.
30321
7494.13
2315.19
269308
440232
5.948 564,07
310.65510
461
650945 MW0+1FR-AK-CAZSC(4)
10,688.63
52.07
304.84
2.456.14
2,36220
2935.54
-6,456,67
5,948.609.08
310591.84
2.38
6.74622 MM+1FR-AKLPZSC(4)
11D.M.62
58.82
305.33
2508.02
].41].00
2,982.90
1,531.44
5.946,1355.99
310528.22
230
662522 MWDNFR-AX AZSC(4)
10.822.06
WAB
309.23
7.553.25
1464.81
3033.11
-6,595.61
6946.]08]5
310,408.29
3.52
6,905.46 MWDHFR--CAZSC(4)
10.9]1.]3
6223
310.34
2,599.13
2,510.19
3,OM.55
b,659.21
5946,76312
310,40301
1A3
6,90946 MNDHFR-AO AZSC(4)
11,93823
6338
309.39
7,64232
7553.36
3.140.42
SM.73
5948,81.13
310,33982
1.52
2023.43 MrVDHFR-PK-CAZSC(4)
11160.32
66,15
313.16
2,68246
2,58.52
3,1w59
8,28250
5,940,82684
310,222.25
4.67
2,158,53 MWDrIFR-AK-CAZ4iC(4)
11,265.36
68,31
314.40
2.219.22
2630.26
3.26219
8.850.92
5940,930.95
310.215,52
257
224&09 khNT1r1FR-AK-0AZSC(4)
11,350.02
7030
31&22
2752.60
2,66314
3.32042
8.91291
5,949003.66
310.I55.W
3.11
2,334.52 MMNFR-AK-CAZSC(4)
11,444.32
242
31,m
2)82.85
7.693.91
3,382.94
.1,921 46
5,919,02256
310 MkW
5.20
7,42332 MNDHFRAKCAZ-SC(4)
11,539.12
74.43
322.93
7.M. l
2,80.94
3,459.35
4,.2.15
5,949.14562
310,041.28
2.0
7,512.80 MWDHFR--CAZSC(4)
11,633.52
78.65
326.52
],833.4]
2,]44.53
3,531.31
4,079.95
5,91822151
309,993.30
437
7,650.28 MNDHFR-AfcCAZSC(4)
11,22202
78.78
31.93
7,853.63
2.769.59
361134
4,133.66
5949,250.]
309944.64
ZW
2,691.05 MADHFRJ -CA 4ic(4)
11,82052
9070
328.95
2.06997
228103
366&61
-7178.89
5,949,320.10
3@1,898.15
305
7,89.59 MA➢rIFRAWCAZSC(4)
11913.87
6235
3594
7.88334
2,294.30
3,26812
-222565
5,949,4M.M
3W,M3.13
245
2,658,04 M IFRAK-CAZSC(4)
12,00.9.53
8235
33014
2,69414
2,BOW
3,84002
-2,271.35
5.949 ,539.63
350,359.59
a..
2,955.63 MW"FR-AB-0AZSC(4)
12,00.58
85.17
331.8
2,9.45
2,81351
3.912.64
-2,3136.22
5,84.60524
30917516
3.39
802541 MV/OrIFRAKAAZ-SC(4)
12162.4]
87.97
331.16
2,919.54
2,919.60
4,001.98
-2,355.35
5,949.69513
30 M,W
2.81
8,121.62 lWD+lFRJ -CAZ-Sc'5)
13,201.
M.90
331.98
2.91292
2,823.90
4,099.55
4.402.22
5,949.]8341
3W 684.61
1..
9.250.90 MWDHFRARCAZSC(5)
1237742
B6.M
333.12
2.919.12
7.829.18
4,17398
-],446.59
6949M9.M
309.64233
1.18
8305,39 MNDNFRA-CAZSC(5)
12,42116
8692
331.61
292319
7,634.25
4,258.50
.2,49265
5949,951.35
30960333
1.81
8,392.48 M +IFRA-CAZSC(5)
1235&42
8235
335.28
7,93823
2,639.29
4,341.34
-2,52276
6,95,04216
30.555.33
042
8,480A2 MNDrIFRAK-CAZ-SC(6)
12,35260
80.11
335.00
Zan.
7643.39
4,43111
-756.24
5,950,13048
3W,626.99
1.18
8,55938 M IFR-AK-CA21C(5)
12,25520
99.25
33301
2,934.50
2,845.56
4,516.12
-7,60940
5,00215.91
309,45268
241
6.655.87 MWD+lFRAK-CA C(5)
12,85281
0942
33221
29%.41
2842A7
4,501.43
-7.653.55
5.950,30231
W9445.84
119
6.74709 MWD+IFR-AK-CZSC(5)
12949.24
07.21
331,40
2,933,59
7,850.65
4,685.48
-7,60.61
5,9$0,39733
30402.35
116
8,837.15 MWDAFR--CAZSC(5)
13,042.44
87.0
332.41
TM M
7,854.44
410.52
4,742.93
5950.421,41
309,360.54
107
8,926.03 MNDHFR-PK[:A2SC(5)
13,13863
82.65
332.16
7,94733
7,8&1.36
4,953.60
-7,287.63
5,95055].35
309.31292
028
9,01655 MNDr1FRAKCAZSC(5)
13,23331
a923
333.60
7,94907
283.93
4,93783
-2,033.]]
5950.64235
30927684
Z.
9.105.35 MADr(FR--CAZSC(5)
13.329.10
91.25
334.0
2,949.0
2835.12
5.0. 7a
-7,07302
5,950 729,76
30236.71
262
9.19465 MND+1FR-AK-CAZ£C(5)
Annotation
6- x 6814'
IVIWO16 5:12:43PBf Page 2 COMPASS 5900 14 B" 659
ConocoPhilli PS
ConocoPhillips
Definitive Survey Report
aR 0
Corn,ft • ConocoPhiNps(Alaska) Inc.-WNS
local Coordinate Reference:
Well MT6-09
Pokper y4BMem North Slope
TVD Reference:
ACTUAL MT6-09®89.9dustl(DWonl9)
Sib: GMT1I Lookout Pad
MD Rehrence:
ACTUAL MT6-09 @ 88.94uaB (Doyanl9)
Well: MTG09
Nadh Reference:
True
Walft: MT6-09
Survey Calculation Method:
Minimum Curvature
Design: A2 -w,01
Dahla ts:
EDT 14 Alaska Produclion
Sorwy
Map
Map
AND
has
Art
TVD
MSS
.974
♦am
045
IuaM
1°1
17
(oral
(wnl
(dam
loan)
Northing
N
Eastern,
Session guTnol xame
y
Annotation
(B)
Ihl
(°1197)
(11)
13.42444
ei.m
334.43
7,94624
],85].08
5,10962
-791442
595081656
309,19]40
0.43
9,28324 MWD+IFR-N(1AZ1C (5)
13.51922
91.15
334.75
7.943.46
7,064,52
uleem
-],955.0]
5,950,903.10
397,15985
0,66
9,371.12 MWD+IFRJJ(LALBC(5)
13.614.55
9135
334.79
],941.4]
7,65253
5.281.42
-0,99569
5,950.99026
309,12034
0,11
9,459.40 MWD+IFRAK-CAZ£C(5)
13.]10.0]
91.10
324,41
7,939.44
7,850.50
5,36].]0
4.035.03
5951 0]]51
309,081.50
0.38
9,547,97 MWD+IFR-AK-CAZSC(5)
13,005,17
91AB
331.
7,MT4a
],848.54
545329
-0,07804
5,9511...
ZX9,042.19
052
9,63640 MOpHFRAKSAZSC(5)
1390027
91.25
333.85
7AMA7
7,840.53
5,53967
811987
5.951.250.45
319,. 411
0.12
9;2501 MM+IFR-AKCAZSC(6)
13,98565
90,47
333.98
7934.03
7,045,09
5.67532-6,161.81
,161.01
5,951.33].09
30$961
(6
0.83
JJ4
9,813.88 MM+IFRCAZ3C(5)
14099.95
80.45
33405
7,933.20
7,944,34
5.70309
4,203.12
5,951,422.93
308.92337
097
9,901.03 MWD+IFRAK-CAZEC(5)
14.18532
90..
3.482
793250
7.3.56
5,795.12
$244.28
5,951,609.82
308,884.32
001
9,9W.24 MWD+IFR-AK{AZ4tD(5)
14,280.76
90.11
33414
7,932.01
],8,43.0]
5,801.6
5,28W.
5,951597.12
309.645]6
040
10.070. MNDAFR--CAZSC(5)
14,3]5.34
69.09
335.38
7,932.67
7,84313
5,967.21
5.324.82
5,951.6&182
309,007.98
127
10,16607 MN➢+IFRAK-CAZSC(5)
144lR.W
am
33439
7,935.13
7.846.19
6052,58
-6.36493
5,95117013
3[8,769.9]
1.69
10,253.40 MWD+IFR-AWCQSC(5)
14.56&W
87.15
339.97
793828
705034
Sinn
4,406,81
5,951.857.76
308,]3010
0,65
10.342.99 MWD+IFRAK-0AZ4C(5)
14.(61.
0750
3M.M
7,943.14
],654.00
6.22516
4.44951
5,951,924.8]
308.690.60
0.51
10A3V9 MWD+IFR-AK-CAZ£D(5)
14]57.17
87.16
33559
],948]9
7,859.25
6.311.62
448989
5a52 mm
308.652.75
1.35
10,520.45 MND+IFR-A.CAZSC(5)
14,05301
89.91
MAN
7,160..
7,86110
3,39666
5.(66.56
5.952 ,1.4.0]
309,814.40
2.94
10.60949 MJrD+lFRAK-CAZSC(5)
14,947.92
91.06
375.12
],949.64
7897.90
fi464.33
5,56973
5,952,286]0
=,5]5.]3
1,51
10976.52 MND+1FRAKL -SC (6)
15 (141110
91.09
333.78
],948.95
7059.11
6,56914
4,61448
5,952.29309
300,53607
0.36
10,]85.03 MWDHFR- CAZ4C(5)
15,137..
81.15
335.@
7,945.20
],05726
8655 07
5652.35
5,952.379.39
308,49].2]
1.31
10,8.2.9] MWD+IFR-AH-0AZSC(5)
15 51
91.03
3M.E0
7,944.35
7,655.41
6.740.90
4692.73
5,952,45.17
308.459.97
0.5
10.950.80 MWD+IFR. AL C(5)
15.327,65
92.48
334.N
7.941.39
T8534S
6,62667
4,733.]9
5,95252.81
306420.04
net
11.0,19.11 MNDOFRAK-0A24tO(5)
15,422.67
905
334.73
7,936,67
7.049.93
691239
5.77470
595263959
343,39123
2.09
11.13727 MNDNFRAKCAZSC(5)
15518.20
00.83
334.13
7.939.24
7,85035
6,99956
-6,61593
5.952,]2(K]3
308,34210
1,92
1I.M5.97 MWD+IFRA(C7S4C(5)
15.61308
iie2
375.69
797.
7,851.86
T0.,19
4856.76
5,9(6,813.32
308,30337
0.86
11.314.01 MND+IFR-AK( AZ4C(5)
15,700.80
Be..
33323
7,94336
785342
7,170.0
4888.69
5,M2,9W.52
300263.55
176
11,403.25 MWD+IFRAKCAZSC(5)
15.803.91
89.10
33421
7.9,13.99
]955.05
T25.52
494013
5,952,95,63
308.223.W
1.05
11,49103 MND+WRAK-CAZSC(5)
15,(6903
68.01
33324
7.946.38
],85].44
7,34079
4982.82
5,953972.69
309,183.59
1.53
11,58055 MWpHFRAKCAZSC(6)
15M3,w
87.99
334.07
7,949.69
7697.75
7,42553
5,@479
5.953,156.Q
306143.70
088
11%0.. MNWIFRAKCAZSC(5)
1600997
85.95
333.00
7ae.n
7,8529
7,511.08
-9,09763
5,953.245,16
303,12495
216
11157.5 MW3+IFR-AKLAZSC IS)
16,184.20
95M
333.5
786222
],8]320
7,595.15
-9,10.92
5,95.4331,22
3W(H385
103
fl,84g.22 MWD+IFR.AKCAZ4C (5)
1629697
6503
333.45
7971.0
780296
7,695.]1
9,158.%
5953,431.96
308,016.53
000
11950.26 PROJECTED to TO
4-110"x6-
12/18/!010 5: 12 43P
Pegs 0
COMPASS 5000.14 BUM 050
Cement Detail Report
MT6-09
String: Conductor Cement
Job: DRILLING ORIGINAL, 11/19/201800:00
Cement Details
Description
Conductor Cement
Cementing Start Date
2/17/2018 14:00
Cementing End Date
2/17/2018 16:00
Wellbore Name
MT6-09
Comment
Cement Stages
Stage # 1
Description
Conductor Cement
I
Objective Top Depth (ftKB)
Cement Conductor 36.7
Bottom Depth (ftKB)
115.0
Full Return?
No
Vol Cement...
I
Top Plug?
No
I Btm Plug?
No
O Pump Init (bbl/m...
O Pump Final (bbl/...
O Pump Avg (bbl/...
P Pump Final (psi)
P Plug Bump (psi)
Recip?
No
Stroke (ft)
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB)
Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Elm (ftKB)
Amount (sacks)
Class
Volume Pumped (bbl)
Yield (ft/sack)
Mix H2O Ratio (gallsa...
Free Water I%)
Density (Ib/gal)
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr 1 (psi)
Additives
Additive
Type
Concentration
Cone Unit label
Page 1/1
ReportPrinted: 1/17/2019
Cement Detail Report
MT6-09
String: Surface Casing
Job: DRILLING ORIGINAL, 11/19/201800:00
Cement Details
Description
Cementing Start Date
cememing End Date
Wellbore Name
Surface Casing Cement
11/22/2018 07:30
11/22/2018 1115
MT6-09
Comment
Dowell pump 3 bbls H2O & PT to 3500 psi (good). Dowell pump 100.2 bbls 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 330 bbis
11.0 ppg 1.95 ft3lsx yield LiteCRETE lead cement and 68.3 bbls 15.8 ppg 1.16113/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbls H2O.
Rig displace with 289 We / 2,893 stks 10 ppg DriIlPlex with 8 bpm 1850 psi. Reduce pumps to 3 bpm 1550 psi. last 10 Wis. Bump plug, pressure 500 psi over
to 1100 psi for 5 min. Check floats. F/C good. CIP ® 11:15 Hrs. Calculate 154 bbls good cement to surface. Full returns during cement job.
Cement Stages
Stage # 1
Description
ObjectiveTop
Depth (ftKB)
Bottom Depth (ftKB)
Full ReWrn?
Vol Cement...
Top Plug?
Btm Plug?
Surface Casing Cement
Cement Surface Casing
36.6
2,146.0
Yes 1154.0
1 Yes
O Pump Init (bbl/m...
O Pump Final (bbll...
O Pump Avg (bbl/...
P Pump Final (psi)
P Plug Bump (psi)
Recip?
Stroke (ft)
Rotated?
Pipe RPM (rpm)
8 3
6
550.0
1,100.0
No
No
I
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB) Drill
Out Diameter (in)
Comment
Dowell pump 3 bbls H2O & PT to 3500 psi (good). Dowell pump 100.2 bbls 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 330 bbls
11.0 ppg 1.95 ft3/sx yield LiteCRETE lead cement and 68.3 We 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbls H2O.
Rig displace with 289 bbls 12,893 stks 10 ppg DriIlPlex with 8 bpm / 850 psi. Reduce pumps to 3 bpm / 550 psi. last 10 bbls. Bump plug, pressure 500 psi over
to 1100 psi for 5 min. Check floats. F/C good. CIP (d1 11:15 Hm. Calculate 154 bbls good cement to surface. Full returns during cement job.
Cement Fluids & Additives
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Bbn (ftKB)
Amount (sacks)
Class
Volume Pumped (bbl)
Surface Cement
36.6
1,646.0
950
B
330.0
Yield (ft /sack)
Mix H2O Ratio (gal/sa...
Free Water (%)
Density (Ib/gal)
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr 1 (psi)
1.95
7.08
1
1 1
1
5.20
Additives
Additive
Type
Concentration
Conc Unit label
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Btm (ftKB)
Amount (sacks)
Class
Volume Pumped (bbl)
Tail Cement
I 1,646.0
2,146.0
331
G
68.3
Yield (ft/sack)
Mix H2O Ratio (gal/sa...
Free Water (76)
Density (Iblgal)
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr 1 (psi)
1.16
5. 1
15.80
5.20
Additives
Additive
Type
Concentration
Conc Unit label
Page 1/1 ReportPrinted: 1117/20191
Cement Detail Report
MT6-09
String: Intermediate Casing Cement
Job: DRILLING ORIGINAL, 11/19/201800:00
Cement Details
Description
Cementing Start Date
Cementing End Date
Wellbore Name
Intermediate Casing Cement
11/29/2018 18:30
11/29/2018 21:50
MT6-09
Comment
Dowell pump 1.2 bbis H2O & PT to 4000 psi (good). Dowell pump 60 We 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 36.2 bbls
12.2 ppg 2.3 ft3/sx yield Class G lead cement and 42.4 bbis 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 bpm. Drop 2 top plugs. Dowell pump 20 bbis H2O. Rig
displace with 762 bbis (7,640 stks @ 95%) 10.5 ppg LSND with 8 bpm / 500 - 850 psi. Reduce pumps to 3 bpm 1570 psi. last 10 bbis. Bump plug, pressure 500
psi over to 1100 psi for 5 min. Check floats. F/C good. CIP @ 21:50 Hrs. Full returns during cement job.
Cement Stages
Stage # 1
Description
Objective Top Depth (ftKB)
Bottom Depth (ftKB)
Full Return?
Vol Cement...
Top Plug?
Btm Plug?
Intermediate Casing
1 000'of cement above 9,395.0
10,395.7
Yes
Yes
Yes
Cement
shoe
Q Pump Ink (bbl/m...
Q Pump Final (bbU...
Q Pump Avg (bbl/...P
Pump Final (psi)
P Plug Bump (psi)
Recip?
Stroke (ft)
Rotated?
Pipe RPM (rpm) -
8 3
6
570.0
1,100.0
No
No
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB) Drill
Out Diameter (in)
Comment
Dowell pump 1.2 bbis H2O & PT to 4000 psi (good). Dowell pump 60 bbis 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 36.2 bbis
12.2 ppg 2.3 ft3/sx yield Class G lead cement and 42.4 bbis 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 bpm. Drop 2 top plugs. Dowell pump 20 bbls H2O. Rig
displace with 762 bbis (7,640 stks @ 95%) 10.5 ppg LSND with 8 bpm / 500 - 850 psi. Reduce pumps to 3 bpm / 570 psi. last 10 bbis. Bump plug, pressure 500
psi over to 1100 psi for 5 min. Check floats. F/C good. CIP @ 21:50 Hrs. Full returns during cementjob.
Cement Fluids & Additives
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Bon (nKB)
Amount (sacks)
Class
Volume Pumped (bbl)
Lead Cement
9,395.0
9,895.0
89
G
36.2
Yield (ft%sack)
Mix H2O Ratio (gallea...
Free Water (%)
Density (Ib/gal)
Plastic Viscosity (CP)
Thickening Time (hr)
CmprStr 1 (psi)
2.30
13.16
12.20
6.50
Additives
Additive
Type
Concentration
Conic Unit label
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Bbn (ftKB)
Amount (sacks)
Clasa
Volume Pumped (bbl)
Tail Cement
9,895.0
10,395.7
204
G
42.4
Yield (ft /sack)
Mix H2O Ratio (gallsa...
Free Water (%)
Density (Hugal)
Plastic Viscosity (CP)
Thickening Time (hr)
CmprStr 1 (psi)
1.16
5.07
1
1
1
4.50
Additives
Additive
Type
Concentration
Conc Unit label
Page 111 ReportPrinted: 1/17/2019
Cement Detail Report
MT6-09
String: Liner
Job: DRILLING ORIGINAL, 111191201800:00
Cement Details
Description
Cementing Start Date
lCamenting End Date
Wellbore Name
Liner Cement
12/7/2018 20:00
12/8/2018 01:15
MT6-09
Comment
Flood lines with water, pressure test lines to 4000 psi. SLB pump 30 bbl 12.5 ppg Mud Push @ 2 bpm, 644 psi, swap to 59.5 bbl 15.8 ppg G Cement @ 1.9 bpm
initial 675 psi, climbing to 1200 psi packing off and erratic. Reduce rate to 1 bpm, 925 psi, smoothed out, FCP 445 psi @ 1 bpm. Chase with 20 bbl water @ 1
bpm, 400-550 psi. Swap to rig to displace @ 1 bpm, initial, up to 840 psi observing losses @ 30%. Reduce rate to .5-.7 bpm, 980-1300 psi, 50% losses. Cement
rounding shoe @ 00:00 hrs, 119 bbl away. CIP @ 01:13 his 12/8/18. 32 bbl of 59.5 lost while cement in open hole, 54% loss.
Cement Stages
Stage # 1
Description
Objective Top Depth (ftKB)
Bottom Depth (ftKB)
Full Return?
Vol Cement...
Top Plug?
Bum Plug?
Liner Cement
Cement liner 10,525.0
12,026.0
INC I
INO
No
Q Pump Init (bbUm...
O Pump Final (bbl/...
O Pump Avg (bbl/...
P Pump Final (psi)
P Plug Bump (psi)
Recip?
Stroke (ft)
Rotated?
Pipe RPM (rpm)
2
1
1
1,277.0
No
I
No
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB) Drill
Out Diameter (in)
Comment
Flood lines with water, pressure test lines to 4000 psi. SLB pump 30 bbl 12.5 ppg Mud Push @ 2 bpm, 644 psi, swap to 59.5 bbl 15.8 ppg G Cement @ 1.9 bpm
initial 675 psi, climbing to 1200 psi packing off and erratic. Reduce rate to 1 bpm, 925 psi, smoothed out, FCP 445 psi @ 1 bpm. Chase with 20 bbl water @ 1
bpm, 400-550 psi. Swap to dg to displace @ 1 bpm, initial, up to 840 psi observing losses @ 30%. Reduce rate to .5-.7 bpm, 980-1300 psi, 50% losses. Cement
rounding shoe @ 00:00 hrs, 119 bbl away. CIP @ 01:13 his 12/8/18.32 bbl of 59.5 lost while cement in open hole, 54% loss.
Cement Fluids & Additives
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Bim (ftKB)
Amount (sacks)
Class
Volume Pumped (bbl)
Tail Cement
10,525.0
12,026.0
287
G
59.5
Yield (fN/sack)Mix
H2O Ratio (gal/sa...
Free Water (%)
Density (lWgal)
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr 7 (psi)
1.16
5.13
15.80
5.50
Additives
Additive
Type
Concentration
Conc Unit label
Page 1/1 ReportPrinted: 1/17/20191
Originated:
Schlumberger
PTS- PRINT CENTER
6411 A Street
Anchorage, AK 99518
(907)273-1700 main (907)273-4760fax
Delivered to:
AOGCC
ATTN: Natural Resources Technician II
Alaska Oil & Gas Conservation Commision
333 W. 7th Ave, Suite 100
.�� Anchorage, AK 99501
218134
30212
SERVICE ORDER SERVICE Color
WELL NAME API # # FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED Prints CD's
uttal Re -pt \ A Transmittal Receipt signature confines that a package (box,
/ I I envelope, etc.) has been received and the contents of the
X V Y package have been verified to match the media noted above. The
We Sign ture Date specific content of the CDs and/or hardcopy prints may or may
not have been verified for correctness or quality level at this
return via courier or sign/scan and email a copy t chlumberger and CPAI. point.
?TSPrintCenter0slb.com Tom.Osterkamo@conocoohillips.com ISLB Auditor- ,3
Schwartz, Guy L (DOA)
From:
Schwartz, Guy L (DOA)
Sent:
Friday, December 28, 2018 10:47 AM
To:
Dai, Weifeng (Weifeng.Dai@conocophillips.com); Cookson, John
(John.Cookson@conocophillips.com)
Cc:
Loepp, Victoria T (DOA)
Subject:
MT6-09 Injection well (PTD 218-134)
John,
I reviewed the 7" liner SCMT log and other cementing data you forwarded to Victoria. CBL looks good and meets our
regulations for isolation of the Alpine sands. You have approval to proceed with water injection in accordance with AIO
40. Note that a witnessed MIT -IA is required once well has stabilized injection.
Regards,
Guy Schwartz
Sr. Petroleum Engineer
AOGCC
907-301-4533 cell
907-793-1226 office
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartz@alaska.aov(.
Cement Detail Report
MTG-09
Job: DRILLING
3115
String: Liner Cement
IAL, 1111912018 00:00
$chlumbepp ConocoAmgm Cement_
m6-09
3 Cement Bond Quality Lg Summar
Manes 9610ft-11817
Figure > Cement Evaluation Summary Log
kmmm@r 4 20December 2018
-32768.00(
f�
| [ }
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. ! !
^
A«.J
/
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Figure > Cement Evaluation Summary Log
kmmm@r 4 20December 2018
Schlumberger Cementing )oi Report CernCAT v1.7
Well MT6-09
Client Conoco Phillips
Field Alpine
SIR No. 2801042
Engineer Kyle Christensen
Sob Type Liner
Country United States
Sob Date 12-06-2018
Time
�rw.a
Pressure
Density
—Rate
-WHP
Messages
18:39:44
?
anve Location
18:55:00
1
Water PH 7
19:10:00
19:25:00
Blow air bad,
line up down Me well
Start water ahead
Returns at Surtace
ow stall
19:40:00
verily 1. trips
verify high tips
good high test
stag mining MP
Mud push to weight
verified by mudsrale
19:55:00
Reset Total, Vol - 29.97 bbl
P
end mud push
20:10:00
cement wet
Cement weight
verified by by e
Start Cement ne Slung
Slur
20:25:00
20:40:00
20:55:00
End Cement Slung
21:10:00
Reset Total, Vol = 59.51 bet
swap to water
21:25:00
End Water
swap to rig
Reset Total, Vol = 20.00 bbi
21:40:00
21:55:00
22:09:00
End Job
hh:mm:ss
om moo ww moo woo
o w.o xo.o xs.o xza xsa
e.w xu ,.0 4o ea w.o
1. woo woo ww woo
PSI
LB/G
B/M
PSI
12/07/2018 22:25:38
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
4. Cement Quality Evaluation Summary
Depths
Comments
Top
Bottom
Interval
(ft)
(ft)
(ft)
Bond Quality
CBL amplitude is high reading close to free pipe amplitude and strong casing
9610
10332
722
Poor
arrivals in VOL suggesting poor bond quality. TT is observed to be consistent
across the interval, TT change across 9773ft-9813ft is due to presence of sea
assembly and other completion elements.
CBL amplitude is high to medium with strong to moderate casing arrivals and
10332
10471
139
Poorto
Moderate
weak formation arrivals in VOL suggesting poor to moderate bond quality. T
is observed to be consistent across the interval.
CBL amplitude is medium with moderate casing and formation arrivals in VOL
10471
10676
405
Moderate
suggesting moderate bond quality. TT is observed to be consistent across the
interval.
CBL amplitude is low with attenuated casing arrivals and strong formatio
10876
11001
125
Good
arrivals on VOL. This suggests that bond quality is good. TT is observed to be
consistent across the interval.
CBL amplitude is low to medium with moderate to weak casing arrivals and
11001
11065
64
Moderate to
Good
strong formation arrivals on VOL suggesting moderate to good bond quality. TT
is observed to be consistent across the interval.
CBL amplitude is low with attenuated casing arrivals and strong formatio
11065
11201
136
Good
arrivals on VOL. This suggests that bond quality is good. TT is observed to b
consistent across the interval.
CBL amplitude is low to medium with moderate to weak casing arrivals and
11201
11277
76
Moderate to
Goad
strong formation arrivals on VOL suggesting moderate to good bond quality. TT
is observed to be consistent across the interval.
CBL amplitude is low with attenuated casing arrivals and strong formatio
11277
11573
296
Good
arrivals on VOL. This suggests that bond quality is good. TT is observed to b
consistent across the interval.
CBL amplitude is low to medium with moderate to weak casing arrivals and
11573
11817
244
Moderate to
Good
strongformation arrivals on VDI -suggesting moderateto good bond quality. TT
is observed to be consistent across the interval.
Table -1: CBL-VDL Cement Quality Evaluation Summary
Schlumberger 5 20 December 2018
Application ror Permit to Drill, Well GMTU MT6-09
Saved: 8 -Dec -18
GMTU MT6-09
GMTU MT6-09 APD
Page 1 of 28
Printed: 8 -Dec -18
Loepp, Victoria T (DOA)
From: Dai, Weifeng<Weifeng.Dai@conocophillips.com>
Sent: Thursday, December 20, 2018 1:34 PM
To: Loepp, Victoria T (DOA)
Subject: MT6-09 SCMT (PTD #218-134)
Attachments: CPAI_MT6-09_SCMT_17-DEC-2018_Processed_CementEvaluation_Report.pdf
Follow Up Flag: Follow up
Flag Status: Flagged
Victoria,
Please see the attached SCMT file for MT6-09 7" liner cement job. The TOC interpretation from SLB is included in the file.
All in all, very good bond log despite partial return losses during the cement job.
I will include other relevant information for the well in a separate note due to the size of the attachment. Let me know if
you have any questions.
Regards
Weifeng Dai
Western North Slope Drilling Engineer
ConocoPhillips Alaska
Office: (907)-263-4324
Cell Phone: (907)-342-9508
From: Matt Roorda <MRoorda@slb.com>
Sent: Thursday, December 20, 2018 12:02 PM
To: Dai, Weifeng <Weifeng.Dai@conocophillips.com>; Jason Burt <1Burt2@slb.com>
Cc: Jenna Moore <JHouston2@slb.com>
Subject: RE: [EXTERNAL]Re: [Ext] MT6-09 SCMT
Weifeng
Attached is the processed report.
Let me know if you need anything else.
Thanks
Matt
Software Integrated Solutions
Data Services
Cement Evaluation
Company:
ConocoPhillips Alaska, Inc.
Field:
Greater Mooses Tooth
Well Name:
MT6-09
Log Date:
17 -Dec -2018
Service:
CBL-VDL
Run Number:
1
Analyst:
Nitesh Kumar
Reviewed by:
Apoorva Kumar
pW cuAM'.pc�cG wd wwta mss wM pcMu�dtlr rmycmw vww�.
Cgryci/(®Shcmbrpv Ail Nrghb nwwd 1xOGa0RC
Schlumberger
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
1. Schlumberger Legal Disclaimer.........................................................................................2
2. Executive Summary ..........................................................................................................3
Recorded data and comments......................................................................................................3
Schlumberger 1 20 December 2018
Objectives.....................................................................................................................................3
Conclusion....................................................................................................................................3
3.
Cement Bond Quality Log Summary ..................................................................................4
Main Pass: 961 Oft — 1181 7ft ...........................................................................................................4
4.
Cement Quality Evaluation Summary ...............................................................................5
S.
Observations...................................................................................................................6
6.
Theory of Operation.........................................................................................................9
7.
Log Quality Control........................................................................................................10
Transit Time (TT), CBL Amplitude (CBL) & Variable Density Log(VDL)........................................10
8.
Contextual Information..................................................................................................11
FieldLog Header.........................................................................................................................11
WellSketch.................................................................................................................................12
ToolSketch.................................................................................................................................13
9.
Appendix.......................................................................................................................14
Schlumberger 1 20 December 2018
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
1. Schlumberger Legal Disclaimer
ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR
RECOMMENDATION FURNISHED WITH THE SERVICES OR OTHERWISE COMMUNICATED BY
SCHLUMBERGER TO CUSTOMER AT ANY TIME IN CONNECTION WITH THE SERVICES ARE
OPINIONS BASED ON INFERENCES FROM MEASUREMENTS, EMPIRICAL RELATIONSHIPS
AND/OR ASSUMPTIONS, WHICH INFERENCES, EMPIRICAL RELATIONSHIPS AND/OR
ASSUMPTIONS ARE NOT INFALLIBLE, AND WITH RESPECT TO WHICH PROFESSIONALS IN THE
INDUSTRY MAY DIFFER. ACCORDINGLY, SCHLUMBERGER CANNOT AND DOES NOT WARRANT
THE ACCURACY, CORRECTNESS OR COMPLETENESS OF ANY SUCH INTERPRETATION,
RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES OR RECOMMENDATION. CUSTOMER
ACKNOWLEDGES THAT IT IS ACCEPTING THE SERVICES 'AS IS", THAT SCHLUMBERGER MAKES
NO REPRESENTATION OR WARRANTY, EXPRESS OR IMPLIED, OF ANY KIND OR DESCRIPTION IN
RESPECT THERETO. SPECIFICALLY, CUSTOMER ACKNOWLEDGES THAT SCHLUMBERGER DOES
NOT WARRANT THAT ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS,
ESTIMATES, OR RECOMMENDATION IS FIT FOR A PARTICULAR PURPOSE, INCLUDING BUT NOT
LIMITED TO COMPLIANCE WITH ANY GOVERNMENT REQUEST OR REGULATORY REQUIREMENT.
CUSTOMER FURTHER ACKNOWLEDGES THAT SUCH SERVICES ARE DELIVERED WITH THE
EXPLICIT UNDERSTANDING AND AGREEMENT THAT ANY ACTION TAKEN BASED ON THE
SERVICES RECEIVED SHALL BE AT ITS OWN RISK AND RESPONSIBILITY AND NO CLAIM SHALL
BE MADE AGAINST SCHLUMBERGER AS A CONSEQUENCE THEREOF.
Schlumberger 2 20 December 2018
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
2. Executive Summary
Recorded data and comments
A Slim Cement Mapping Tool (SCMT) log was recorded in MT6-09 well on 17 -Dec -2018.
The logging interval, which extends from 9610ft to 11817ft, is completed with 7" tie -back string, weight 26
ppf, nominal ID of 6.276" and nominal theoretical wall thickness of 0.362" from 32.1ft to 9767ft and 7"
intermediate liner, weight 26 ppf, nominal ID of 6.276" and nominal theoretical wall thickness of 0.362" from
9754.6ft to 12026ft as per completion diagram. The data quality is generally good over the entire logged
interval.
At the time of logging, the borehole fluid was brine of density -9.2 ppg.
Objectives
The objective of the logging is to evaluate cement behind the 7" liner.
Conclusion
Across the logging interval, TT (transit time) is consistent throughout, spikes were observed across the
intervals having completion elements.
TOC was observed at—10332ft in the logging interval.
Good bond quality is observed in the interval 10876ft- 11001ft, 11065ft — 11201ft and 11277ft — 11573ft.
Moderate to Good bond quality is observed in the interval 11001ft-11065ft, 11201ft-11277ft and 11573ft —
11817ft. Moderate bond quality is observed in the interval 10471ft-10876ft. Poor to moderate bond quality
is observed in the interval 10332ft — 10471ft; while poor bond quality is observed in the interval 9610ft —
10332ft.
Schlumberger 3 20 December 2018
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� � '.
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Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
4. Cement Quality Evaluation Summary
Depths
Comments
Top
Bottom
Interval
Bond Quality
(ft)
(ft)
(ft)
CBL amplitude is high reading close to free pipe amplitude and strong casing
arrivals in VOL suggesting poor bond quality. TT is observed to be consisten
9610
10332
722
Poor
across the interval, TT change across 9773ft-9813ft is due to presence of sea
assembly and other completion elements.
CBL amplitude is high to medium with strong to moderate casing arrivals and
10332
10471
139
Poorto
weak formation arrivals in VOL suggesting poor to moderate bond quality. T
Moderate
is observed to be consistent across the interval.
CBL amplitude is medium with moderate casing and formation arrivals in VOL
10471
10876
405
Moderate
suggesting moderate bond quality. TT is observed to be consistent across the
interval.
CBL amplitude is low with attenuated casing arrivals and strong formatio
10876
11001
125
Good
arrivals on VOL. This suggests that bond quality is good. TT is observed to be
consistent across the interval.
CBL amplitude is low to medium with moderate to weak casing arrivals and
11001
11065
Moderate to
strong formation arrivals on VOL suggesting moderate to good bond quality. T
Good
is observed to be consistent across the interval.
CBL amplitude is low with attenuated casing arrivals and strong formatio
11065
11201
136
Good
arrivals on VOL. This suggests that bond quality is good. TT is observed to b
consistent across the interval.
CBL amplitude is low to medium with moderate to weak casing arrivals and
11201
11277
76
Moderate to
strong formation arrivals on VOL suggesting moderate to good bond quality. T
Good
s observed to be consistent across the interval.
CBL amplitude is low with attenuated casing arrivals and strong formatio
11277
11573
296
Good
arrivals on VOL. This suggests that bond quality is good. TT is observed to be
consistent across the interval.
CBL amplitude is low to medium with moderate to weak casing arrivals and
11573
11817
244
Moderate to
strong formation arrivals on VOL suggesting moderate to good bond quality. T
Good
is observed to be consistent across the interval.
Table -1: CBL-VDL Cement Quality Evaluation Summary
Schlumberger 5 20 December 2018
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
5. Observations
Figure 2 below show the log section from - 961 Oft -10471 ft.
In the interva1961 Oft-10332ft, CBL amplitude is high reading close to free pipe amplitude and strong casing
arrivals in VOL suggests poor bond quality. TT is observed to be consistent across the interval, TT change
across 9773ft-9813ft is due to presence of seal assembly and other completion elements.
In the interval 10332ft - 10471ft, CBL amplitude is high to medium with strong to moderate casing arrivals
and weak formation arrivals in VDL suggesting poor to moderate bond quality. TT is observed to be
consistent across the interval.
TOC was observed at-10332ft in the logging interval
MD(ft)
I Bond Quality
Well schematic
99000 Transit Time variation
due to presence of
completion elements
Consistent
Transit Time
to
GOBO
Strong casing
arrival
Figure 2- Cement Bond duality in the interval9610ft - 16471ft I Strong to Moderate
casing arrival and weak
formation arrivals
Schlumberger 6 20 December 2018
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MTB -09
Figure 3 below show the log section from - 10471ft - 11065ft. Transit Time (TT) is observed to be mostly
consistent across this section.
In the interval 10471ft- 10876ft, CBL amplitude is medium with moderate casing and formation arrivals in
VDL suggesting moderate bond quality. TT is observed to be consistent across the interval.
In the interval 10876ft- 1 1001ft, CBL amplitude is low with attenuated casing arrivals and strong formation
arrivals on VDL. This suggests that bond quality is good. TT is observed to be consistent across the interval.
In the interval 11001ft-11O65ft, CBL amplitude is low to medium with moderate to weak casing arrivals and
strong formation arrivals on VDL suggesting moderate to good bond quality. TT is observed to be consistent
across the interval.
(ft)MD I Bond Quality
schematic
Consistent Transit Time
Moderate
to
Figure 3- Cement Bond Quality in the interval 10471ft-11065ft
GOBO
Moderate to Weak casing Weak casing
arrival and strong arrival and strong
formation arrivals formation arrivals
Schlumberger 7 20 December 2018
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
Figure 4 below show the log section from - 11065ft - 11817% Transit Time (TT) in this section is generally
consistent.
In the interval 11065ft-11201ft and 11277ft-11573ft, CBL amplitude is low with attenuated casing arrivals
and strong formation arrivals on VOL. This suggests that bond quality is good. TT is observed to be consistent
across the interval.
In the interval 11201ft-11277ft and 11573ft-11817ft, CBL amplitude is lowto medium with moderate to weak
casing arrivals and strong formation arrivals on VOL suggesting moderate to good bond quality. TT is
observed to be consistent across the interval.
Schlumberger 8 20 December 2018
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
6. Theory of Operation
Sonic logging is a measurement of the sound energy that travels across media allow the evaluation of various formation
characteristics.
Sonic waves emitted by the transmitter of the sonic tool travel in different paths on their wayto the receivers. Sound
travels the fastestthrough solid materials. The first arrival is usually the result of a sonic wave traveling outward from
the transmitter through the borehole fluid, then up the casing and out into the borehole and back to the receiver. The
next arrivals will usually be the result of sound traveling through the formation rock and back out to the receiver. In
this case, the first arrival will have an amplitude indicative of the losses obtained while traveling through the formation
rock, casing, and borehole fluid.
The amount of fluid or gas behind the pipe plays a role in whether or not any formation arrivals will be seen at all in the
detection gate allowed. In fast formations, sound travels faster through the formation than it does through the casing
wall. The travel time and the amplitude of the sound energy reflected by the casing are measured in cement bond
logging (CBL).
Schlumberger 9 20 December 2018
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
7. Log Quality Control
Transit Time (TT), CBL Amplitude (CBL) & Variable Density Log (VDL)
The 3ft receiver average TT shows consistent and close to expected value; TT change is observed across
9773ft-9813ft which is due to presence of seal assembly and other completion elements.
VDL also shows good contrasts in cemented section, casing arrivals are visible, indicating good data quality.
Figure 5- LQC Log
Schlumberger 10 20 December 2018
;
.:•'
� ,
t�
rt
ri
t t t t
}} y
t
1
III
1
f
1
!
k� y
1
1
rC ryJ�
i k.t
1
1
'l
��'3�ir•`t
E
I
3�
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i}tr�z
-
i
Figure 5- LQC Log
Schlumberger 10 20 December 2018
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
8. Contextual Information
Field Log Header
Schlumberger 11 20 December 2018
Memory Cement Evaluation Log
Memory GR/CCL/CBL/VDL
o LL m
17 -Dec -2018
v y
290' FNL & 3245' FEL
Elev.: K.B. 88.94 ft
N
g L
At surface
G.L.
o
o a
Z
0
D.F.
FZ LL o g
r
L0 c
U
Permanent Datum: MSL
Elev.: 0.00 ft
z 0 ��" Z. 0
Log Measured From: RKB
88.94 ft above Perm. Datum
t
Drilling Measured From: RKB
M o m
o6 'd o
API Serial No.
Section
Township
Range
o
M u. 3 0
50-103-20779-00
6
10N
3E
Logging Date
17 -Dec -2018
Run Number
1
Depth Driller
16295.7 ft
Schlumberger Depth
TO not tagged
_
Bottom Log Interval
11806 ft -
Top Log Interval
9600 ft
.
Casing Fluid Type
Brine
Salinity
Density
9.2lbm/ al
Fluid Level
BIT/CASING/TUBING
STRING
Bit Size
From
To
Casing/Tubing Size
7.000 in
Weight
26 Ibm/ft
Grade
L-80
From
9754.56 ft
To
12026 ft
Maximum Recorded
Temperatures
Logger On BottomTime
17 -Dec -2018 16:40
Unit Number
Location Alpine
Recorded By
S. Kitanovski
Witnessed By
R. Reinhardt/ R. Bjorhus
Schlumberger 11 20 December 2018
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
Well Sketch
Schlumberger 12 20 December 2018
WNS SVC
WELLNAME MT6-09
WELLBORE
MT6-09
Conoc';
nll AM]iEuw.
Ma. An9N8MO
TO
7Hfip$
Nnaka,lnc.
LOOKOIR
aw
SVC
tl.4 .®
'isP
w'
16.iBB.0
nmmr
•
M✓�nr Oa
mT—
Wsln SM
"tl1n
>r r.
n
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♦w. wm R.w
rr
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a
M=
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i
Tebua'F 6mp�
t'-
'yt
li.
miNn•�rMuinuwnlmt.l
rrmmua�m rt sd
F7.
R
L
�
�
ERrnvm
�Y
wna�a cn•a nna
CmnO
rnlernnprern
rn.wT4.wa.
90
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Min
Z:
Schlumberger 12 20 December 2018
Schlumberger
Tool Sketch
ConocoPhillips Alaska, Inc.
MT6-09
DOWNHOLE EQUIPMENT
AH -SUCKER ROD
KNUCKLE
34.3
AH -SUCKER ROD KNUCKLE IILII'
PSRP
32.1
PRMC32 1710
PSRP-A 3836
PBMS-A
10k Sapphire_Mano
RT6 Thermometer
GR
CCL
GR _
28.4
PBMS
Well
25.3
_Temp
Manometer �_
25.2
CCL —24.6
PBMS U_
23.9
SCMT-CB
23.9
SCMC-CA 8290
SECH-CA
CMIR-AG
SCMS-CB 8155
SCMX-CA 8127
AH -278
TTG -C
OT _
14.8
CBL5 DTSC _
13.3
CRL3 _
12.3
MAP _
11.8
AUX —
10.8
AH -Bullnose
Tension SCM I
0
0.5
TOOLZERO
MAXIMUM STRING DIAMETER 1.69 1N
MEASUREMENTS RELATIVE TO TOOL
ZERO
ALL LENGTHS IN FEET
Cement Evaluation
Schlumberger 13 20 December 2018
Schlumberger ConocoPhillips Alaska, Inc.
MT6-09
9. Appendix
Cement Bond logging Tools
APPLICATIONS
Cement bond tools measure the bond between
• Evaluation of cement quality
the casing and the cement placed in the annulus
• Determination of zone
between the casing and the wellbore. The measure -
isolation
mem is made by using acoustic sonic and ultrasonic
tools. In the case of sonic tools, the measurement
• Location of cement top
is usually displayed on a cement bond log (CBL)
in millivolt units, decibel attenuation, or both.
Reduction of the reading in millivolts or increase
of the decibel attenuation is an indication of better -
quality bonding of the cement behind the casing
to the casing wall. Factors that affect the quality
of the cement bonding are
• cement job design and execution as well
as effective mud removal
• compressive strength of the cement in place
• temperature and pressure changes applied
to the casing after cementing
• epoxy resin applied to the outer wall
of the casing.
SUM ARRAY SONIC TOOL
The Slim Array Sonic Tool (SSLT) is a digital
sonic tool that provides conventional openhole
sonic measurements, standard CBL amplitude
and Variable Density' log (VOL), and attenuation
measurements, which are less affected by borehole
environmental conditions, The SSLT can also make
a short -spacing (1 -ft 10.30-m1) COL measurements
for cement evaluation in fast formations. The two
transmitters and six receivers of the SSLT sonde
have transmitter—receiver spacings of 1, 3, 3.5, 4,
4.5, and 5 I [0.30, 0.91, 1.07,122,11.37, and 1.52 m]
to compute the following:
• standard 3 -ft CBL and 5 -ft VOL measurements
• borehole -compensated (BHC) attenuation
from the 3.5- and 4.5 -ft spacing receivers
• near-pseudoattenuadon from the 3 -ft
spacing receivers
• short -spacing attenuation from the l -ft spacing
receiver for cement bond measurement in fast for-
mations that may affect the standard 3 -ft spacing.
Cement Evaluation
Schlumberger
IJI
k
11
�I I
'urtI osLT
11 Memory Slim
SSIT BSLT CBLTeol
SCMT
HSLT
Schlumberger 14 20 December 2018
Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation
MT6-09
Cement Bond Logging Tools
SUMIITREME SONIC
CEMENT BOND LOG FROM
to evaluate the casing below. In new wells the SCMT is an
LOGGING TOOL
HOSTILE ENVIRONMENT
excellent tool for evaluating casing that is 7% in [19.36 cm] or less.
The Slim%treme' Sonic Lagging
SONIC LOGGING TOOL
The SCMT features a single transmitter, two receivers spaced at
Tool (QSLT) provides the same
The Hostile Environment Sonic
3 and 5ftfrom the transmitter, and eight segmented receivers 2 I
measurements as the SSLT of the
Logging Tool (HSLT) provides
[0.61 ml from the transmitter. The output of the near 13 -ft) receiver
cement bond amplitude, attenua-
the same measurements of the
is used for CBL and transit -time measurement. The output of the far
tion, and Variable Density display
cement bond amplitude and
(5 -ft) receiver is used for the VDL measurement. The eight segmented
for evaluation of the cement
Variable Density display for evalu-
receivers generate a radial image of the cement bond variation,
bond quality of a cemented
ation of the cement band quality
e®n19YW
casing in high-pressure and
of a cemented casing string as
MEMORY SUM
high-temperature environments,
the SSLT in high-pressure and
CEMENT BOND LOGGING TOOL
uW
ni.lra,q
high-temperature environments.
The Memory Slim Cement Bond Logging Tool provides through -tubing
CEMENT BOND LOG FROM
M.p!Fm
3 -ft CBL and 5 -ft VOL measurements with the same accuracy and
DIGITAL SONIC LOGGING TOOL
SUM CEMENT MAPPING TOOL
quality as surface -readout logs. Because of its slim size, the I IA -in
The Digital Sonic Logging Tool
The Slim Cement Mapping Tool
tool can be run into the zone of interest without having to remove the
(DSLT) uses the Sonic Logging
(SCMT) is a through -tubing
tubing from the well. The tool simultaneously records gamma ray,
Sonde (SLSI to measure the
cement evaluation tool combin-
casing collar location, pressure, temperature, and waveforms in a
cement bond amplitude and
able with the PS Platform' produc-
single pass, with the waveforms fully digitized downhole, More than
provide a Variable Density display
tion logging service for a variety of
40 It of combined tool running time is passible, including 16 h of contin-
for evaluation of the cement bond
well diagnostics. The two sizes are
uous waveform recording time. Depth -recording systems are available
quality of a cemented casing
11% in [4.29 cm) for the standard
for both hazardous and nonhazardous environments.
string. Variable Density orx-y
(302 degF 1150 degQ) temperature
The Memory Slim CBL Tool can be run with other Memory PS Platform'
waveform display of the sonic
rating and 2% in [5.24 cml with a
production logging tools for complete well and reservoir evaluation in
signal is presented in conjunction
392 degF 1200 degC] temperature
one descent. The toots and sensors can be conveyed in the borehole
with the band index and amplitude
rating. The SCMT is suitable for
by drillpipe, coiled tubing, slickline, or unintelligent tractor. PS Platform
signal. The DSLT is also used in
running workover operations and
software is used to perform onsite data processing or any necessary
the open borehole environment for
in new wells. SCMT operations
postprocessing and prepare the log presentation.
conventional sonic measurements
provide a clear advantage in
of BHC 13 -toy -ft) transit time and
workover wells because there
long -spacing depth -derived BHC
is no need to pull tubing above
(DDBHC)19-to 11 -ft [2.74 to 3.35-m1)
the zone of interest for cement
transit time.
evaluation. The SCMT is capable
of running through most tubings
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Schlumberger 15 20 December 2018
Loepp, Victoria T (DOA)
From: Dai, Weifeng<Weifeng.Dai@conocophillips.com>
Sent: Thursday, December 20, 2018 1:46 PM
To: Loepp, Victoria T (DOA)
Subject: RE: MT6-09 SCMT (PTD #218-134)
Attachments: MT6-09 Intrm 2 Casing test - FIT.xls.xlsm; MT6-09 Cement Job.pdf; MT6-09 SDL Cement
Schematic.pdf
Follow Up Flag: Follow up
Flag Status: Flagged
Victoria,
Enclosed are FIT, cement report and schematic for MT6-09 following the previous note with SCMT log file. Please let me
know if you have any questions and grant the approval of injection service if everything looks good to you.
Have a great holiday!
Regards
Weifeng Dai
Western North Slope Drilling Engineer
ConocoPhillips Alaska
Office: (907)-263-4324
Cell Phone: (907)-342-9508
From: Dai, Weifeng
Sent: Thursday, December 20, 2018 1:34 PM
To: Loepp, Victoria T (DOA) (victoria.loepp@alaska.gov) <victoria.loepp@alaska.gov>
Subject: MT6-09 SCMT (PTD #218-134)
Victoria,
Please see the attached SCMT file for MT6-09 7" liner cement job. The TOC interpretation from SLB is included in the file.
All in all, very good bond log despite partial return losses during the cement job.
I will include other relevant information for the well in a separate note due to the size of the attachment. Let me know if
you have any questions.
Regards
Weifeng Dai
Western North Slope Drilling Engineer
ConocoPhillips Alaska
Office: ( 907)-263-4324
Cell Phone: (907)-342-9508
From: Matt Roorda <MRoorda@slb.com>
Sent: Thursday, December 20, 2018 12:02 PM
To: Dai, Weifeng <Weifeng.Dai@conocophillips.com>; Jason Burt <JBurt2@slb.com>
Cc: Jenna Moore <1Houston2@slb.conv
Subject: RE: [EXTERNAL]Re: [Ext] MT6-09 SCMT
Weifeng
Attached is the processed report.
Let me know if you need anything else.
Thanks
Matt
Application for Permit to Drill, Well GMTU MT6-09
Saved: 8 -Dec -18
GMTU MT6-09
GMTU MT6-09 APD
Page 1 of 28
Printed: 8 -Dec -18
r,,:.T+ - Cement Detail Report
MTS -09
String: Liner Cement
Job: DRILLING ORIGINAL, 1111912018 00:00
Cement Details
o"criptic"
C•mn tag C e C atg •
WWDara NRTa
Liner Cement
12.'Q018 2090 128401 a"" 01:15
1.II6-W
Flood Ynesw hwale,. omasum tevtinesto 4000 os:. SLBpunp30bD112.5ppo Abd Push Q2bpm644pv swapm59.5bbl15.8ppgGCementQ1.9bpm
initia1675psicambngtd1200pvpetl poffendermtc Reaup mleto1bpm925pi amo "out FCP445psiQtbpm Chasew 20bol"terQ1
bpm. 400350 pal Swan to %to displeca 01 bpm w"1. up m 840 pwobwr"V bases 030%. Reduce rote to 5-.7bpm 980-1300 pt. 50%bsses. Cement
rounding shoe 000:00 firs. 119 bbl away CIP 001:13 firs1218/18. 32 bbl o159.5 batwhile Dement m open hole. 54% bss
Cement Stages
Stage r 1
D••O1ptICe OpNtlln UP cw1c IRK81
9cd:TD•pn(flKD)
hliR 1
YaU t...[Top P"IDta PWI?
Liner Cement Cement[ner 10.525.0
120269
W
No tto
0 Peep ae8 glee_AtIF e Pal
PAM WM
•qt) 1 Ro 1 PIGS RPstIRTI
2 1
1 1.277.0
Pio tto
Ty9,01)"IflKD1
Tag Moose
oqm Aq Dtia on To PMO)
DRIIOct CDT.kM1in1
Common
F l God hints w6h Ovate t, pte s .,v testinesto 4000 psi. SLB p ump 30 GN 12.5 ppg Wd Push m 02 bp644 psi, swap to 59.5 bb115.8 ppg G Cemen t 01.9 bpm
m X I e 1675 pv. cw ,; to 1200 psi pecking off a no eminx: Reduce Me m I bpm 925 pw. vroomed out FCP 445 psi 01 bpm. Ch o" wnh 20 bbl orate, Q1
bpm.400350psi Srmptorgtod4lomQ1bpm,nMmLupto840psiobmrl gbases03C%Reduceroleto.5-.7bpm980-1300psi.60%bsses. Cement
roundingsnGe QOO:00hm. 119Db!away UPQO1: 13 hm 1218/18.32 bblat 59.5 iovw a oememk open hole. 54% loss.
Cement Fluids 6 Additives
Fluid
rasa
v1,4ci,vV i:1
FOANiod top MANI
CA e 1
a IssmlC1sM
1CastMPwom
Tad Cement
10.5250
12,026.0
287
O
59.6
TIFM IOV•Ma{bXD1
RAa(Ineal.
F!•Bwk•rI%1
Dnetylesge{
Ptllba Ntntly (01iTtRMN91Mithl
CT-0IW t JPK)
1 16
10513
15.80
Add,bv
Adan" Ty Conan Cab U" woo
Page 1I1 Report Printed: 1212011018
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Summary
PRESSURE INTEGRITY TEST
CONOCOPHILLIPS Alaska, Inc.
Well Name:
MT6-09 I
Rig:
Doyon 19
1 Date:
1 12/11/2018
volume input
Volume/Stroke
Pump Rate:
Drilling Supervisor:
I Rick Bjorhus / Rob Reinhardt
Pump used:
#1 Mud Pump
strokes
0.1007
ebls/Strk
0.70
Bbl/min
Type of Test:
Casing Shoe Test LOT/FIT
Pumping down
annulus and OF.
Casing
Test
I Pressure Integrity
Test
Hole Size: 6-1/8" wl
Casing Shoe Depth
Hole De h
Pumping.Shut-in
Pumping
Shut-in
RKB-CHF: 36.8 Ft
12026.0 Ft-MD
7897.0 Ft-TVD
12126.0 Ft-MD 7905.0 Ft-ND
Strks
Min
psi
Strks
I psi
Min psi
Casing Size and Deserlotion. i, 7" 26#/Ft
L-80 BTC-MOD IV
0
-psi
0
0
3600
0
0
0.00
870
Casin Test
Pressure IntearltvTost
1
90
1
3600
1
60
0.25
800
Mud Weight: 10.5 ppg
Mud 10 min Gel: 15.0 Lb/100 Ft2
Test Pressure: 3500.0 psi
Rotating Weight: ###### Lbs
Blocks/Top Drive Weight 60.0 Lbs
Estimates for Test: 5 bbls
IV
Mud Weight: 10.2 ppg
Mud 10 min Gel: 11.0 Lb/100 Ft2
Rotating Weight: ###### Lbs
Blocks/Top Drive Weight: 1 60.0 Lbs
Desired PIT EMW: 12.5 ppg11
Estimates for Test: 944 psi 1.4 bb_Is
w
3
170
2
3600
2
120
0.50
750
5 300
3 3600
3 230
1.00
700
7 420
4 3600
4 280
1.50
700
9 610
5 3600
5 330
2.00
680
7701
6 3600
6 380
2.50
660
13 890
71 36001
71 430
3.00
650
15 1020
81 36001
8 520
3.50
650
EMW = Leak-off Pressure + Mud Weight = 680 +10.2
0.052 z TVD 0.052 x 7897Shut-in
EMW at 12026 Ft-MD (7897 Ft-TVD) = 11.9 ppg
PIT 15 Second
Pressure, psi
17
1100
9
3600
9
560
4.00
650
19 1180
10 3600
10 600
4.50
650
800
21 1310
15 3600
11 650
5.00
640
4000 Lost 0 psi during test,
3500
49
3000
w 2500
- 2000
a ts0o
loo0
500
o" k 1
0 1 2 3 4 5 a 0 5 10 15 20 25 30
Barrels Shut-In time, Minutes
�GASING TEST BLEAK-OFF TEST o PIT Point
23 1400
20 3600
12 700
5.50 640
25 1500
25 3600
13 750
6.00 630
27 1620
30 3600
14 790
6.50 630
29 1730
15 820
7.00 630
31 1850
16 840
7.50 630
33 200017
850
8.00 630
35 2120
1
18 870
8.50 620
37 2240
1
9.00 620
39 2390
9.50 620
411 25101
10.00 620
43 2630
45 2790
47 2960
49 3080
51 3200
53 3400
55 3600
Volume
PUMP
Um ed
Volume
Bled Back
Volume
Pumped
Volume
Bled Back
5.3 S
Bbls
Comments:
.n vvv aiu r < �.aau �y iwi - i I ..AI. ivv<i
Summary
MT6-09 4-1/2" Upper Completion
Well:
MT6-09
ConocoPhillips
Alaska, Inc.
4-1/2" 12.6# L-80 TSH Blue Tubing
Date:
1211812018
• A
A
Rig:
Doyon 19
Depth
Jt Number Joints
Well Equipment Description and Comments
Page 1
Length
Tops
RKB to Top Of String or RKB to tock Down Screws
RKB to ULDS
28.60
FMC 4-112" Tubing Hanger 563
2.20
28.60
Pup, 4 1/2",12.6#,L80, 563 Top Pin x TSH BLUE Pin Btm
2.42
30.80
Jts 293 to 293 1 Jts
TUBING,4 1/2",12.6#,L80,TSH Blue
40.42
33.22
Space out pups, 4 1/2",12.6#,L80,TSH Blue
9.80
73.64
Space out pups, 4 1/2",12.6#,L80,TSH Blue
3.83
83.44
Jts 245 to 292 48 As
TUBING,4 1/2",12.6#,L80,TSH Blue
1927.48
87.27
NIPPLE, LANDING,4 1/2",X,3.813", TSH Blue
1.05
2014.75
Jts 16 to 244 229 As
TUBING,4 1/2",12.6#,L80,TSH Blue
9201.89
2015.80
Pup,4 1/2",12.6#,L80,TSH Blue
9.82
11217.69
4-1/2" x 1" Camco KBG-2 GLM w/ DCK-2 SOV pinned for moo psi csg to tbg
shear, TSH Blue
7.21
11227.51
Pup,4 1/2",12.6#,L80,TSH Blue
9.55
11234.72
Jts 12 to 15 4 Jts
TUBING,4 1/2",12.6#,L80,TSH Blue
161.60
11244.27
NIPPLE,LANDING,4 1/2", 3.813" XN, TSH Blue with RHC Plug Body Installed :j
1.45
11405.87
Jts 1 to 11 11 Jts
TUBING,4 1/2",12.6#,L80,TSH Blue
446.25
11407.32
Pup,4 1/2",12.6#,LSO,TSH Blue
5.84
11853.57
Locator No-Go 5.75" OD
.93
11859.41
Seal Assembly
14.35
11874.69
11874.69
11874.69
TOL =11,864.22
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
Remarks
Seal Guard ECF
Up Wt
152 K
M/U torque target 5360 fUlbs
Dn Wt
121 K
Block Wt
60 K
Rig Supervisors: R. Bjorhus/A. Dorr/U Shirley
Jt Number Joints Well Equipment Description and Comments
Page 2
Length Tops
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
Remarks:
Rig Supervisors: R. Bjorhus IA. Dorr/ U Shirley
A Number Joints Well Equipment Description and Comments
Page 3
Length Tops
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
Remarks.
Rig Supervisors: R. Siorhus / A. Dorr / U Shirley
Jt Number ,joints Well Equipment Description and Comments Length
Page 4
Tops
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
11874.69
Remarks: Bottom Depth of Strin9�--------------->
11874.69
Rig Supervisors: R. Bjorhus /A. Dorr/ U Shirley
11874.69
Enter Bottom
Depth of String
[the Set Depth]
Tallied Piping Defaults
Fill in GREEN fields below
WELL PERMIT CHECKLIST Field & Pool GRTR MOOSES TOOTH, LOOKOUT OIL - 2821
Well Name: GMTU MT6-09 Program DEV _ Well bore seg ❑
PTD#:2181340 Company CONOCOPHILLIPS ALASKA INC. Initial Classrrype DEV
/ PEND GeoArea 890 Unit 10750 On/Off Shore Oo Annular Disposal ❑
Administration
17
Nonconven. gas conforms to AS31,05,0300.1.A),6.2.A-D) ......................
NA ..........
_ .. _ _ _ .. _ _ _ . _ _ _ _ ..............
7 -le
'1
Permit. fee attached ____
NA
�2
Lease number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes _ _
..3
_ _ _ Surface Location Jies. within FIEDA081796; Portion of Well Passes Thru FEDA081618; ..... _ _ _ _ ---
3
Unique well name and number ........ . ... . ...... _ _ . _ _
Yes
Top_Prod Int & TD lie withinFEDA092346. _
4
Well Jocated in a_defined pool _ _ . . .. . . . . . ... . ..........
Yes
Greater Mooses Tooth., Lookout Oil Pool —282100
5
Well located proper distance from drilling unit. boundary_ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes
Conservation Order No. 747, issued May 29, 2018, governs. Lookout Oil Pool.
6
Well located proper distance from other wells
Yes _
... No restrictions as, to well spacing except that no pay shall be opened to awell within 5QO.feet of an ......
7
Sufficient acreage available In drilling unit ...... ....... ... ...
Yes
external property line where the ownersandlandowners are not the same on. both_sides of the line, _ _
8
If deviated, is wellbore plat included _ _ _ _
Yes
As planned, this well conforms with spacing requirements,
9
Operator only affected party_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes _
_ _ _ 10/23; Request and receive_ revised directional survey program. _ _ _ _ _ _ _ _ _ _
10
Operator has. appropriate_ bond in force _ _ _ _ _ _ ..
Yes
.......... . . . . ............. . .. . . .
Appr Date
11
Permitcan be issued without conservation order. . . . ....... . . . . . . . .
Yes
12
Permit can be issued without administrative approval
Yes
SFD 10/25/2018
_ _ _ _ _ _
----------- --
_ _
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ ..... _ .. .
- ------ � ---
13
Can permit be approved before 15-day wait _ _ _ _ _ _ _ _ _ _ _ ..
Yes
..
14
Well located within area and strata authorized by Injection Order # (put 10# in comments) (For
Yes _ _
_ _ _ _ Area Injection Order No, 40, issued May 29,201% governs Lookout Oil Pool, ..................... .
15
All wells.within 1/4. mite area of review identified (For service well only)...............
Yes ......
Suspended well Lookout 1 Iles within %-mile Area of Review.
16
Pre-produced injector; duration of pre production less than 3 months (For service well only) _ _
No _ _
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ... _
18
Conductor string_ provided _ _ _ _ _ _ .. _ _ _
Yes _ _ _
_ _ _ _ 79' conductor set_
Engineering
19
Surface casing_ protects all known USDWs _
Yes _
_ _ Surface casing set to 2052'.0D ............. . .
20
CMT_vol adequate to circulate on conductor_& surf csg . . . . . . . . . . . . ........... .
Yes _ .....
155%.excess ..
21
CMT. vol adequate to tie-in Jong string to surf rag. . . . . . . . . . . . . . . . . . . . . . .
No..........
22
CMT will cover all known productive horizons_ _ _ _ _ _ _ _ _
No
_ Productive_ interval will be completed with. an uncemented open hole liner
23
Casing designs adequate for C, T, B &_permafrost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes
24
Adequate tankage of reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes _
_ _ Rig has steel tanks; all waste. to approved disposal wells.
25
Ifa.re-drill. has _a10-403 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 _ _ _ _ _ _ _ _ _ _
Yes _ _
_ _ _ _ Diverter waiver granted per 20 AAC 25.030(h)(2) _ ____
Appr Date
28
_
Drilling fluid program schematic & equip list adequate. _ _ _ _ _ _ ..
Yes
_ Max formation. pressure Js. 3800 psig(9.2 ppg EMW ); will drill w/ 8.8-11.0 ppgEMW
VTL 11/7/2018
i29
BOPEs, do they meet regulation------------ ---------- ----------- --
Yes. _..---...
_..............--_- -_ _-- --...---. _. _...
30
BOPE.press rating appropriate; test to.(put psig in comments).. . ................
Yes .....
MPSP Is 3006 psg; will test BOPs_to 3500_psig
31
Choke manifold complies w/API_ RP-53 (May B4)_ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes
32
Work will occur without operation shutdown_ _ _ _ _ _ _ __ _ _ _ _ _ _ _
Yes
_ _ _ _ _ _ _ _ _ _ _ _ _ _ . - - _ _ ..................
33
Is presence. of H25 gas. probable............ . ........
Yes
_ 112$ measures required...............
34
Meche Acaloondition of wells within AOR verified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes _ _ _
_ _ . _ Exploration well. Lookoutl Jn AOR and is suspended..
35
Permit can be issued w/o hydrogen. sulfide measures ....................... .
No.
.... H2S measures required,
Geology
36
Data. presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes _ _
Drilling fluid program appears adequate to control_ operator's forecast pressures.- The second section of
Appr Date
37
Seismic analysis of shallow gas zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA _ _
_ _ _ intermediate_ hole and the production interval will be drilled. with 8.8-9.5 ppg_mud _using Managed
SFD 10/22/2018
38
Seabed condition survey (if off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA _ _
_ _ _ _ Pressure_ Drilling Technique to stabilize shale and control formation pressure.
39
Contact name/phone for weekly.progress reports. [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ __ _ _
NA
Geologic Engineering
Public
Commissioner: Date: Commissiio0ler:
/ Date
Commi loner
Date
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