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Alaska Oil and Gas Conservation Commission
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ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
Date: May 27, 2025
FFROM:Anu Ambatipudi TO: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
700 G Street 333 W.7th Ave., Suite 100
Anchorage AK 99501 Anchorage, Alaska
DATA TRANSMITTAL
Kuparuk River Unit/Field
Well API #PTD #Comments
1H-112 50029237870100 2240320
3B-16A 50029212890100 2231250
2B-03B 50029211510200 2230800
2M-39 50103207950000 2181710
3S-612 50103207770000 2181110
3S-611 50103207740000 2181030
1H-108B 50029236080200 2180820
1H-110 50029236010000 2180310
1H-116 50029235940000 2180120
2S-06 50103207470000 2160850
2M-37 50103207450000 2160820
1D-39 50029229970000 2002160
1D-40A 50029229690100 2001900
2N-302 50103203800000 2011150
1R-03A 50029214060100 2000210
3H-37 50103208220000 2191940
2S-09A 50103207490100 2161280
T40450
T40451
T40452
T40453
T40454
T40455
T40456
T40457
T40458
T40459
T40460
T40461
T40462
T40463
T40464
T40465
T40466
By Gavin Gluyas at 1:15 pm, May 28, 2025
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
Colville River Unit/Field
Well API # PTD # Comments
CD5-31 50103208280000 2210020
CD5-96 50103208110000 2191620
CD4-499 50103208100000 2191610
CD5-26 50103208060000 2191070
CD5-98 50103208030000 2190590
CD5-24 50103207990000 2190060
CD5-23 50103207610000 2171550
CD5-19 50103207600000 2171210
CD5-22 50103207590000 2170890
CD5-316 50103207560000 2170400
CD3-111A 50103205260100 2170040
CD3-198 50103206370000 2110240
CD4-24 50103206020000 2090970
CD4-26 50103206000000 2090490
CD2-15 50103203860000 2011590
CD2-12 50103204550000 2030730
CD4-214 50103205370000 2061450
CD4-17 50103205340000 2061180
CD2-73 50103205900000 2081960
T40467
T40468
T40469
T40470
T40471
T40472
T40473
T40474
T40475
T40476
T40477
T40478
T40479
T40480
T40481
T40482
T40483
T40484
T40487
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
Greater Mooses Tooth Unit/Field
Well API # PTD # Comments
MT7-99 50103208450000 2221020 T40485MT7-99 50103208450000 2221020
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, August 29, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Sully Sullivan
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
MT7-99
GMTU MT7-99
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 08/29/2024
MT7-99
50-103-20845-00-00
222-102-0
G
SPT
8265
2221020 2066
3433 3434 3434 3434
0 0 0 0
4YRTST P
Sully Sullivan
7/15/2024
4 year MIT-IA no isues
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 MT7-99
Inspection Date:
Tubing
OA
Packer Depth
950 2390 2335 2320IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSTS240717100311
BBL Pumped:3.5 BBL Returned:3.7
Thursday, August 29, 2024 Page 1 of 1
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James B. Regg Digitally signed by James B. Regg
Date: 2024.08.29 15:42:19 -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
MT7-96 50-103-20834-00
221100_MT7-96_ChemCut_06Nov2022
221100_MT7-96_LDL_05Nov2022
221100_MT7-96_PlugShoot_08Oct2022
221100_MT7-96_PlugShoot_26Dec2022
221100_MT7-96_Plug_04Nov2022
221100_MT7-96_PPROF_08Mar2023
221100_MT7-96_PPROF_18Aug23
221100_MT7-96_PPROF_27Jul22
221100_MT7-96_Puncher_06Nov2022
MT7-97 50-103-20849-00
222150_MT7-97_CHC_04Apr2023
222150_MT7-97_LDL_09Mar2023
MT7-98 50-103-20843-00
222081_MT7-98_PPROF_10Dec2022
MT7-99 50-103-20845-00
222102_MT7-99_PPROF_15Dec2022
3of 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
T38431
T38432
T38433
T38434
2/29/2024
MT7-99 50-103-20845-00
222102_MT7-99_PPROF_15Dec2022
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2024.02.29
11:03:29 -09'00'
PTD: 222-102
T38319
1/18/2024Kayla Junke
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2024.01.18
14:04:55 -09'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Wednesday, April 26, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Adam Earl
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
MT7-99
GMTU MT7-99
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 04/26/2023
MT7-99
50-103-20845-00-00
222-102-0
W
SPT
8265
2221020 2066
995 997 1001 1006
114 127 128 127
INITAL P
Adam Earl
3/26/2023
MIT IA tested as per Sundry 323-070
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 MT7-99
Inspection Date:
Tubing
OA
Packer Depth
550 2500 2435 2420IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitAGE230329093127
BBL Pumped:4.2 BBL Returned:3.7
Wednesday, April 26, 2023 Page 1 of 1
9
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&RQYHUWWRLQMHFWRU
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James B. Regg Digitally signed by James B. Regg
Date: 2023.04.26 13:54:59 -08'00'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
RECEIVED
By Kayla Junks at 10:08 am, Mar 29, 2023
1. Operations Susp Well Insp❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑
Performed: Install Whipstock❑ Perforate ❑ Other Stimulate ❑ After Casing ❑ Change Approved Program ❑
Mod Artificial Lift❑ Perforate New Pool ❑ Repair Well ❑ Coiled Tubing Ops ❑ Other: Convert Prod to InjO
2. Operator Name
4. Well Class Before Work:
5. Permit to Drill Number:
ConocoPhillips Alaska Inc
Development Q Exploratory ❑
Stratigraphic ❑ Service ❑
222-102
3. Address: PO Box 100360, Anchorage AK 99510
6. API Number:
50-103-20845-00-00
7. Property Designation (Lease Number):
8. Well Name and Number:
AA081800, AA081781
GMT MT7-99
9. Logs (List logs and submit electronic data per 20AAC25.071):
10. Field/Pool(s):
NA
Greater Mooses Tooth / Rendezvous
11. Present Well Condition Summary:
Total Depth measured 17315 feet Plugs measured feet
true vertical 8320 feet Junk measured feet
Effective Depth measured 17315 feet Packer measured 10335 feet
true vertical 8320 feet true vertical 8246 feet
Casing
Length
Size
MD
TVD
Burst
Collapse
Structural
Conductor
80
20"
120'
120'
Surface
3203
13 3/8"
3243'
3046'
5020
2260
Intermediate
8444
9 5/8"
8484'
7426'
6330
3810
Production
1727
7"
10028'
8312'
8160
7030
Liner
10247
41/2"
20115'
8450'
8430
7500
Perforation depth Measured depth 9868 - 20115 feet
True Vertical depth 8288 _ 8450 feet
Tubing (size, grade, measured and true vertical depth) 4 1/2" L-80 9868' 8265'
Packers and SSSV (type, measured and true vertical depth) Baker 9868' 8265' NA
12. Stimulation or cement squeeze summary:
Intervals treated (measured): NA
Treatment descriptions including volumes used and final pressure: NA
13a. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf I Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 11270 14300 10 1605 1450
Subsequent to operation:0 10 13500 1643 1239
13b. Pools active after work: Rendezvous
14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283)
15. Well Class after work:
Daily Report of Well Operations
Exploratory ❑ Development ❑ Service Q Stratigraphic ❑
Copies of Logs and Surveys Run ❑
16. Well Status after work: Oil Gas WDSPL Lj
Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑
17. 1 hereby certify that the foregoing is true and correct t0 the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
Digitally signed by Dana Gleaner
Authorized Name and Dana G essnerDate: 2023.032909:42:55-06'0V
Digital Signature with Date: Contact Name: Dana Glessner
Contact Email: lessd(akonOCCDhillips.Com
Authorized Title: Staff Production Engineer Contact Phone: 907-265-6478
Sr Pet Eng: ISr Pet Geo: I ISr Res Eng:
Form 10-404 Revised 10/2022
RBDMS JSB 033023
Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
WNS PROD WELLNAME MT7-99 WELLBORE MT7-99
ConocoPhillips
Alaska, Inc.
mod,apv
CONDUCTOR'.
Dead ahoe, l
MTERMFDUTF
Gnpa
LaMiry Cape,, 9939
Corer-FION;...a
Rve enoe; lccae.:
INTEPMENIEi
FRRC eWvasPOR
Seek Palm,; 10513.1
FPNC SlnvelPert
Svnl Padua, 108 1
FRAC 9wwNoR
avnl Paden, 12107.1
1. slowelpak
Sam. Peaver; C2 Seal
FRPC shavelPert
Svnl Padn' las 4.:
P. SIxvWPOR
sure. Fadvir; 1 a 3T '
1. MnwrPok
saw, Padke 15131.'
FMC 9xve/P.,
Seek ..No 1. M.i
real slaewrpom
awe. Fad r; leeae(
FRAC ahw.Po,S
and Planar, 1748a.F
FRPC SeevisPOR
swa. Fecnar; la, 1..1
Feat MnwrPok
Well Attributes I Max Angle & MD
TO
OWN! Name WNIbore APMae WOu"'SlAua Id(')
MD(XKBI
MBim(be.)
RENDE 501032084500 PROD
5.25
21,981.63
22,013.0
Command 11251ppm) Date
Mnota ion
End DON
KBGra IXI
RR Dade
OIM1er Elev...
I
I 39.15
I 9122120 1
Annoralion
DeptM1 runs) 1
WOIWm 1
End Data I Lap
Mod By
Last Tag:
IMT'-se
I a"a"U"
IS.,
Last Rev Reason
Annolalion
WeIIWrt I
End Data I Law
Mond By
Rev Reason: Inlccacm Conversion, DV., CIRC, MITIA IMT7-99
1111,11.11
label,
Casing Strings
set Death set
Diane
Cap Do'
OD lint
ID lint Top
reMu
(XKBI INDIIRK61
WdM1en OM1MI Oracle
Top Thmad
CONDUCTOR
20 19.12
40.0
120.0
120.0
M.00
SURFACE
13
W 12.42
39.4
3,243.0
3,046.2
68.00 LAO
H563
INTERMEDIATE
9518
8.68
37.0
8,483.9
7,426.3
47.00 T95
N/A
INTERMEDIATE
7 6.18
8,300.9
10,028.0
8,312.3
29.00 L-80
TSH563
LINER
4112
3.96
9,868.2
20,115.0
8,4497
12.60 L-80
Hyd563
Tubing Strings: string max indicates LONGEST
segment of string
Top(RKB) sn rep[n... srt Depm._5[dnq Ma... Tuhi,q Description Wtnaft) Onde Top con"m lD (in,
9,873.1 8,267.2 41/2 Tubing-Complegon Upper 12.60 L-80 Hy1563 3.9fi
Completion Details: excludes tubing, pup, space out, thread, RKB...
9D
To, f1vD)
Top Intl
Naminy
Nominal
Top BIKBI
IBKBI
r)
kem Des
(in)
Corn Melee
Mudd
ID (in)
MA
MA
0.00
Hanger
11.000
FMC 0.1/2' Tubing Harper Hydril FMC
TC-EMS
3.958
HYD 563 Min ID 3.ST
1,870.1
1,852.8
17.37
Nipple-%
4.500
NIPPLE,LANDING,41Yd', x',3.813', HES
%Nipple
3.813
H553 (SW 00045488374)
3,8212
3,530.3
33.54
Mandrd
4.500
4LQ"x 1"KBG4d GLM Cam.
KBG4
3.865
6770.9
5,997.7
33.17
Mandrd
4.500
4-112"x1"KBG48 GLM Cam.
KBG45
3.860
9534.3
8.130.7
61.51
Mandrel
4.500
4-12"x1"KBG45 GLM Carrico
KBG4
3.860
9,6427
8,179.9
64.52
Gauger Pump
4.500
Hallibun. Oasis Mandrel al HES
DHG
3.920
Smmar
Dawnbale guage(SN#18417-0)
9.8425
8,257.0
69.98
Nipple - DR
4.500
NIPPLE,IANDING.41/2';OB,375" SITE
DB
3.750
Nipple
9S6C7
S264.5
70.61
Wiallne Guide
4.940
WLEG Sbearrype .Donor. shear Baker
WILED
3.910
screas1.01, from top
Mandrel Inserts : excludes pulled inserts
st
an
Top IRKB)
Top (TVD)
(M(B)
Top on
Ind I.) No
valve
SON Type
L.h
Type
OD
(In)
TRO Run
Pop
Runoab
Com Make
SteelSkelln)
pod
3,823.2
3,530.3
33.54 1
DMy
BK
11
0.0
21192023
CAMCO1
10.000
6,770.9
5,9977
33.17 2
DMy
BK
1
0.0
2111W23
CAMCO
o.000
9,534.3
8,130.7
6151 3
OMy
BK
1
0.0
2120I2023
CAMCO
0.000
Liner Details: Excludes
Liner, Pup, Joints, casing, float, sub, shoe...
00
Top INDI
Top Ind
Nominal
Nominal IS
Top repro
(MB)
(")
kem Dea
(in)
Com
Make
Mudd
Qnl
10,380.3
8,387.1
8078 FRAC
5.000 Advanced
Upstream SP Re-
Advance
3.450
Sleevelpart
Closeable
Fmc Sleeve #14,
d
HydM3(SN:107205000006)-
Upstral
Opened
9-28-2022
m
10,512.4
8,405.4
83.33 Swell
Packer
4.500 Baker
575"OD Swell Packer
Baker
Rapidawell
3.900
13(easy),
4-112", 12.69, L80,
922
H563
(SN:0(D3585001.39)
10,7317
8,425.1
85.29 FRAC
5.000 Advanced
Upstream SP Re-
Advance
3.450
Slaeedpon
Closeable
Fr4c Sleeve#13.
Or
Hyd563(SN:1072084I00005)-
Upatrea
Opened
9.28-2022
ar
10,946.1
8A38.9
88.56 Swell
Packer
4.500 Baker
5.75"OD Swell Packer#
Baker
Rapidawell
3.900
12(assy).
4-112%12.61, LSO,
922
H563(Sk1:003585-001-18)
11,289.7
8,438.8
90.59 FRAC
5.000 Advanced
Upstream SP Lock
Advance
3.450
skenewpml
Open
Fret Sleeve#12, Hyd563
d
(SN:107394-0000M)-Opened!
Upd.
28-20M
in
12,107.1
8,447.4
87.77 Swell
Pecker
4.500 Baker
5.75.OD Swell Flicker
Baker
Rapickswell
3.900
11
bmsy). 4112",12.60, L80,
922
H563(SN:003585001-24)
12,488.3
9A61.5
38.15 FRAC
5000 Advanced
Ulowrsam SP Lock
Advance
3.450
Skeve/porl
Open
Fmc Sleeve#11. Hyd563
Or
(SN:107390.000)18)-Opened
9-
Updrea
28-2022
in
I
12,860.8
8,471.9
89.61 Swell
Packer
4.500 Baker
575'OD Swell Packer
Baker
Rapidsvell
3.900
10
(easy ). 0.1/2",12.6#, L80,
922
H563(Sk1:003585001-10)
13,245.7
8,470.9
90.08 FRAC
5.000 Advanced
Upstream SP Lock
Advance
3450
SleevelPan
Open
Frac Sleeve#10, Hyd563
d
(SN:10739L000012)-Opened!
9-
Umbras
28-2022
in
13,614.2
8,470.5
90OR Swell
Packer
4.500 Baker
5.75"OD Swell Packer#9
Baker
Rapickwell
3.900
besy),
a-to",12.6#, L80, H563
922
(SN:003585
00140)
13,997.9
9,470.1
90.07 FRAC
5.000 Advanced
Upstream SP Lock
Advance
3.450
Sissaw1Port
Open
Frac Sleeve#9, Hyd563
d
(SN:10739,k000011)-Opened
9-
Upsires
8-2022
in
14,372.4
BA67.8
90.59 Swell
Packer
4.500 Baker
EF OD Swell Packer #8
Baker
Rapicia"ll
3.900
Away),
0.112",12.6#, 180, H563
922
(SWW3585-0O1-17)
14,757.5
8,465.4
90.09 FRAC
5.000 Advanced
Upstream SP Lock
Advance
3.450
Sleme/Pan
Open
Free Sleeve#B, Hyd563
d
(SN:10739
00001 0) - Opened 9-
Upetea
28-2022
ar
15,133.4
8A65.0
DOLOR Swell
Packer
4.500 Baker
SY OD Swell Packer #7
Baker
Rapidewall
3.900
(any),
0.11T.12.0, LBO. H563
922
(SN:003585-001£)
WNS PROD WELLNAME MT7-99 WELLBORE MT7-99
mum
C0Il0C0Phill!p5
Alaska, Inc.
H0R120NFAL, ar., 2/21202i82d 02AM
VwtloleoMmelb (ewmll
He�ean 34e
caeme wee.; 37we.e
N AVeIN1elAV�IAVM11A39.3.a.6a
Cie.xean
CONDUCTOR. 40.N1C00
Nlpwo-x:1 ero.1
Fi,ei: 32ao sa2a3D
SURFACE 6&332A3.0
Mantlre1:302:t.2
M.wrweP0.9
Pecker; 0,b0.B Cao
r eee,S31d08.32i.3
Cohr-Fper ; 0,3N.9e390.6
Ceolre 6Foe;.....acc 9
MreRMEDUTE I; 3F.0d40i
Merrier s 53e.3
Gepe l Punp ri,, B6e21
Pecker(Tievi 9.i01.5
NlreGne culae;%w
Parker (Liner Top):eSc8.2-
9.634.5
HengR a881..893.8
LaM.ry Unlbr, D DRU 'ark 0
Color-FbN; 9.SBO.M,982.0
fbal6M1x; 10,025.3100ID.0
IMEHMEgPTE 2: 8.3]O.P
03ei
F.SlxvelPOR 1 e3P03
10.352.0
re —I Packer; 110EICtrte5327
FHAC k aevelPert 10,7311-
10.7331
6vnl Pecker; 10 awkii MA,4
FRAC 9xxNoR 112e9.]-
11.H1.3
Svnl Pai 12, 107.112, 121A
FR,C Slnnrporo 12.4EI
12409.9
Spend Peekee, 128i 881.1
FRAC SleevelPert13,2e5.7-
112ei.3
SmlPecker; 13610.2-1363 5
FRAC Menewp R Pea?.4
1e9W.5
fixed Pecker; 14372.N4392.7
FReC MWWPOM 14.]5]s
14,7592
S-1 Pei 15131.o-151 ST.]
FRAC 9xwIPm51e fri
11.117.1
Seal Pecker; Ie86A7-1e96ee
FRAc 6bevei 16.272a
1e2T4.o
.1 Pecker ; le.8-1e o67.1
F. 6liker 5 17,1A3.]-
17,1..3
6vnl pecker; 17481 5o7.2
FRAC geeve/POR 17.7E8.7-
1].]10.3
fixed Pecker; 18, 189.9Aa, 1..1
FReC ma"Wre r[ 18,55.E
105]4
fiend Pei 1. 010.00. C..3
FRAC 9xweii 18474E
19.470.4
Seal Pecker; 10,0eo. a070.3
FRAC BIxvJPOR MRc8.1-
0,0297
.h., N.11e?]0.115.0
LINER: 9,81115.0�
I-1012.6N, LBO, H563
585-001-1)
E Upstream SP Lack
ac Sleeve N5, H,1563
39L000008)-OpeRetl 9-
7OD Swell Packer N4
L112", 12.61f, LBO, H563
58541
J Upstream SP Lock
ac Sleeve M, HyB553
394 000006)-Opeeed 9
5"OD Swell Packer N3
L11T,12.64, LBO. H563
685-002-29)
E Upstream SP Lock
ac Sleeve 13, Hytl563
39L0a0005)-0,real9.
Be OD Swell Packer IT
L112",12.fip, LBO, H563
1585-01
J Upstream SP Lock
no Sleeve N2, Hytl563
39L0000U4)-operand 9-
Daily Event Data
Date
Description
Service T e
(ISW) MT7-99 INITIAL STATE WITNESSED (ADAM EARL) MITIA PASSED TO 2500 PSI Initial T/I/O = 995/550/114 IA FL @ SF
Pressured IA with 4.2 bbls to TWO = 997/2500/127 15 min TWO = 1001/2435/128 (-65 psi) 30 min TWO = 1006/2420/127 (-15 psi)
3/26/2023
Bled IA to 550 psi 3.7 bbls back Final TWO = 1006/5501115
3/14/2023
PRE SW MIT - IA TO 2500 PSI FOR UPCOMING SW MIT -IA PASSED
WELL INTEGRITY
CIRC-OUT. PUMP 440 BBLS OF S/W FOLLOWED BY 180 DSL FREEZE PROTECT TAKING RETURNS UP THE IA. YOUTUBE.
2/20/2023
JOB COMPLETE
PUMPING
SET 3.75" DBP @ 9842' RKB. SET BAITED P-PRONG IN DBP @ 9842' RKB. PULL OV FROM ST#3 @ 9534' RKB. PULL LV
FROM ST#2 @ 6771' RKB. SET DV IN ST#2 @ 6771' RKB. PULL LV FROM ST#1 @ 3823' RKB. SET DV IN ST#1 @ 3823' RKB.
LRS CIRC WELL W/ 445 BBLS CISW & 180 BBL DIESEL FREEZE PROTECT (U-TUBE). SET DV IN ST#3 @ 9534' RKB, RIH TO
CHECKSET DV IN STA#3 @ 9534' RKB,. FLUID LEVEL IN TBG @ 3450' POOH, CONFIRMED DV SET IN STA#3, GAS TO
SURFACE TAA TM 500/350 PSI. PULL DBP PLUG FROM 9842' RKB, NO SIGNS OF LEAK. SET 3.75" CSV @ 9842' RKB,
TESTED TO 1500 PSI, GOOD, PULL DV @ IN STA#3 @ 9534' RKB, FLUID LEVEL DROPPED IN TBG f/ SURFACE TO 1000 PSI
WHILE POOH, Pump 2nd CIRC OUT, 445 BBLS CHSW, 18OBBLS DIESEL FP. SET DV IN ST#3 @ 9534' RKB, RIH TO
2/18/2023
CHECKSET DV IN STA#3 @ 9534' RKB, MITIA 2500 PSI `" PASSED" PULL 3.75" CSV FROM 9842' RKB. JOB COMPLETE.
SLICK LINE
2/16/2023
FREEZE PROTECT TBG 45BBLS DIESEL 5BBLS DOWN FLOWLINE JOB COMPLETE
PUMPING
12/16/2022
HOT FLUSH PUMP 50BBLS HOT DSL DOWN TBG JOB COMPLETE
PUMPING
12/15/2022
CONTINUE LOGGING ELINE, PERFORM SHUT IN PASS, RDMO JOB COMPLETE
ELECTRIC LINE
12/14/2022
CONTINUE LOGGING PRODUCTION PROFILE LOG
ELECTRIC LINE
12/13/2022
CONTINUE TRACTORING DOWN PERFORM PRODUCTION PROFILE LOG
ELECTRIC LINE
12/12/2022
RIH WITH ELINE
ELECTRIC LINE
12/11/2022
RIGUP SLB ELINE TO PERFORM PRODUCTION PROFILE LOG
ELECTRIC LINE
LRS CONTINUES TO FLOW WELL PER PROCEDURE. DIVERTED WELL TO PRODUCTION BEGING BLOW DOWN/ RIG
10124/2022
DOWN
WELL TESTING
10/23/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE.
WELL TESTING
10/22/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE.
WELL TESTING
10121/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE.
WELL TESTING
10120/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE.
WELL TESTING
10/19/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE.
WELL TESTING
10118/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE.
WELL TESTING
10/17/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE.
WELL TESTING
10/16/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE.
WELL TESTING
10/15/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE.
WELL TESTING
10/14/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE.
WELL TESTING
LRS CONTINUES TO FLOW WELL PER PROCEDURE. LRS CONTINUES CONDUCTING THE "MINI" SURGES IN AN
ATTEMPT TO GET THE 4 REMAINING COMPUTER BOARDS TO SURFACE. - (CONDUCTING THE "MINI" SURGES AS A
10/13/2022
MEANS TO LESSEN THE IMPACT ON THE PLANT, PER OPS REQUEST)
WELL TESTING
LRS CONTINUES TO FLOW WELL PER PROCEDURE. LRS CONTINUES CONDUCTING THE "MINI" SURGES IN AN
ATTEMPT TO GET THE 4 REMAINING COMPUTER BOARDS TO SURFACE. - (CONDUCTING THE "MINI" SURGES AS A
10/12/2022
MEANS TO LESSEN THE IMPACT ON THE PLANT, PER OPS REQUEST)
WELL TESTING
LRS CONTINUES TO FLOW WELL PER PROCEDURE. LRS CONDUCTING SOME "MINI" SURGES IN AN ATTEMPT TO GET
THE 4 REMAINING COMPUTER BOARDS TO SURFACE. - (CONDUCTING THE "MINI" SURGES AS A MEANS TO LESSEN
10/11/2022
THE IMPACT ON THE PLANT, PER OPS REQUEST)
WELL TESTING
LRS CONTINUES TO FLOW WELL PER PROCEDURE. DIRECTED LRS TO SURGE WELL 3-4 TIMES IN AN ATTEMPT TO
BRING UP/ RECOVER ADDITIONAL DART MATERIAL SUSPECTED TO STILL BE DOWN HOLE. 3 AM, LRS RETRIEVED
10/10/2022
SOME DART DEBRIS FROM BALLCATCHER
WELL TESTING
LRS CONTINUES TO FLOW WELL PER PROCEDURE. WELL SLUGGED AT —9AM, BRINGING UP QUITE A BIT OF DART
DEBRIS AND GRAVEL. DIRECTED LRS TO SURGE WELL 3-4 TIMES IN AN ATTEMPT TO BRING UP/ RECOVER ADDITIONAL
10/9/2022
DART MATERIAL SUSPECTED TO STILL BE DOWN HOLE.
WELL TESTING
10/8/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE. LRS RETRIEVED SOME DART DEBRIS FROM BALLCATCHER
WELL TESTING
1 OM2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE. LRS RETRIEVED SOME DART DEBRIS FROM BALLCATCHER
WELL TESTING
10/6/2022
LRS CONTINUES TO FLOW WELL PER PROCEDURE.
WELL TESTING
LRS CONTINUES TO FLOW WELL PER PROCEDURE. CHOKE WAS BYPASSED AT 3AM. LRS RETRIEVING GRAVEL FROM
10/5/2022
BALLCATCHER.
WELL TESTING
LRS CONTINUES TO FLOW WELL PER PROCEDURE. CHOKE WAS WORKED UP TO WIDE OPEN (128 BEANS) AT 11 PM.
10/4/2022
LRS RETRIEVING GRAVEL FROM BALLCATCHER.
WELL TESTING
LRS WILL CONTINUE TO FLOW/UNLOAD WELL PER PROCEDURE, INCREASING CHOKE AS CONDITIONS ALLOW. LRS
10/3/2022
RETRIEVING GRAVEL AND DART DEBRIS FROM BALLCATCHER.
WELL TESTING
LRS WILL CONTINUE TO FLOW/UNLOAD WELL PER PROCEDURE, INCREASING CHOKE AS CONDITIONS ALLOW. LRS
RETRIEVING GRAVEL AND DART DEBRIS FROM BALLCATCHER. DHD SHOT IA F/L AT 11:30AM, WAS AT 6450' (-321'
10/2/2022
ABOVE 2ND STAT)
WELL TESTING
LRS COMPLETED RU, CONDUCTED WALKDOWN / SIGNOFF WITH OPS. LRS DID PT ON INLET PIPING (GOOD). LRS POP
10/1/2022
WELL AT 8:35PM. LRS HAD TO FLOW WELL TO TANK FARM 2 TIMES TO GET WELL TO UNLOAD/FLOW.
WELL TESTING
9/28/2022
Dart DRP SLW Own Land Early Seat PSI Peak PSI Diff. BH Seat PSI
9/27/2022
Rigged in the dart launcher and the frac pupdown tie in.
PUMPING
RIH W/A 4.5" GR SD @ 9,858' WORKED JARS LATCHED DB SUB JAR FREE, POOH REC SUB, THEN RIH W/TANDEM BHP
GAUGES MADE A GRADIENT STOP @ 10,000- FOR 30 MIN AND ANOTHER GRADIENT STOP @ 9,850' FOR 15 MIN THEN
9/27/2022
POOH. MAX BOTTOM HOLE PRESSURE: #3904 MAX TEMP: 200 deg.
SLICK LINE
SHAKE BAIT SUB BELL GUIDE ASSEMBLY OFF TOOL STRING ON TOP OF BALL AND ROD, PULLED ALL 3 GLV STA. SET
5/16" OV IN STA #3 @ 9534' RKB, SET GLV (TRO= 1730psi 3/16" PORT) IN STA # 2 @ 6770' RKB, SET GLV (TRO= 1754 psi
9/26/2022
3/16" PORT) IN STA # 1 @ 3823' RKB PULLED, BAIT SUB, BELL GUIDE AND BALL & ROD. JOB IN PROGRESS.
SLICK LINE
9/25/2022
TRVL TO MT7 AND WAIT FOR RIG MOVE AND RIG MATS TO BE REMOVED
SLICK LINE
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert Prod to Inj
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address: Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception? Yes No
9. Property Designation (Lease Number): 10. Field: Current Pools:
Greater Mooses Tooth / Rendezvous / Rendezvous
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
Casing Collapse
Structural
Conductor
Surface 2260
Intermediate 3810
Production 7030
Liner 7500
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
Baker / NA 9868 / 8265 & NA
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:Dana Glessner
Contact Email:
glessd@conocophillips.com
Contact Phone: 907-265-6478
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
AOGCC USE ONLY
Staff Production Engineer
8430
Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size:
L-80 9868
3/1/2023
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
AA081800, AA081781
222-102
PO Box 100360, Anchorage AK 99510 50-103-20845-00-00
ConocoPhillips Alaska Inc
GMT MT7-99
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
8160
MD
6330
5020
120'
3046'
7426'
120'
3243'
8312'10028'
20"
13 3/8"
80
3203
Perforation Depth MD (ft):
8484'
9868 - 20115
1727
4 1/2"
8266 - 8450
20115'10247
4 1/2"
8450'
7"
9 5/8"8444
Perforate
Repair Wepair Well
Exploratory Stratigraphic Development Service
BOP TestMechanical Integrity Test Location Clearance
No
No
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Meredith Guhl at 1:47 pm, Feb 02, 2023
323-070
Dana Glessner Digitally signed by Dana Glessner
Date: 2023.02.02 13:42:55 -09'00'
X
VTL 02/28/2023
X 10-404
DSR-2/2/23
X
DLB 02/02/2023JLC 3/1/2023
3/1/23Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.03.01 12:01:12
-09'00'
RBDMS JSB 030223
Attachment 1 – MT7-99 Area of Review (AOR)
An Area of Review plot is show below of the MT7-99 Injector planned wellpath and offset wells. MT7-02
is the only offset well from the planned MT7-99 injector.
Well
Name Status
Top of
Alpine
Pool
(MD/TVD)
TOC
(MD/TVD)
TOC –
Determined
By
Reservoir
Status
Zonal
Isolation
Cement
Operations
Summary
MT7-02 Producing 10,654’ /
8,295’
9,370’ /
7692’ Sonic Log Liner TOC and
Packer
72 bbls of 15.8
ppg Class G
MT7-02 intermediate 2 section was drilled and cased with 7” liner down to 10,756’ MD in the Alpine D.
The Alpine C zone was penetrated at 10,923’ MD. The intermediate casing was cemented to isolate the
Alpine pool with 72 bbls of Class G cement (plugs bumped and floats held) and top of cement was
measured with a Sonic LWD at 9,370’. A horizontal production section was drilled in the Alpine C to
24,256’ MD and completed with a liner.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
RECEIVED
By Antra Prysunka at 1:24 pm, Nov 30, 2022
1. Operations Susp Well Insp❑ Plug Perforations
❑
Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑
Performed: Install Whipstock❑ Perforate
❑
Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑
Mod Artificial Lift❑ Perforate New Pool
❑
Repair Well ❑ Coiled Tubing Ops ❑ Other: Pre -produced Injector ❑✓
2. Operator Name
4. Well Class Before Work:
5. Permit to Drill Number:
ConocoPhillips Alaska Inc
Development ❑ Exploratory ❑
Stratigraphic ❑ Service Q
222-102
3. Address: PO Box 100360, Anchorage AK 99510
6. API Number:
50-103-20845-00-00
7. Property Designation (Lease Number):
8. Well Name and Number:
AA081800, AA081781
GMT MT7-99
9. Logs (List logs and submit electronic data per 20AAC25.071):
10. Field/Pool(s):
NA
Greater Mooses Tooth / Rendezvous
11. Present Well Condition Summary:
Total Depth measured 17315
feet
Plugs measured feet
true vertical 8320
feet
Junk measured feet
Effective Depth measured 17315
feet
Packer measured 10335 feet
true vertical 8320
feet
true vertical 8246 feet
Casing
Length
Size
MD
TVD
Burst
Collapse
Structural
Conductor
80
20"
120'
120'
Surface
3203
13 3/8"
3243'
3046'
5020
2260
Intermediate
8444
9 5/8"
8484'
7426'
6330
3810
Production
1727
7"
10028'
8312'
8160
7030
Liner
10247
41/2"
20115'
8450'
8430
7500
Perforation depth Measured depth 9868 - 20115
feet
True Vertical depth 8288 _ 8450
feet
Tubing (size, grade, measured and true vertical depth)
4 1/2" L-80 9868' 8265'
Packers and SSSV (type, measured and true vertical depth)
Baker 9868' 8265' NA
12. Stimulation or cement squeeze summary:
Intervals treated (measured): NA
Treatment descriptions including volumes used and final pressure:
NA
13a.
Representative Daily Average Production or Injection Data
Oil-Bbl
Gas-Mcf I Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 0
10 10 10 10
Subsequent to operation:3425
15360 1120 1790 1537
13b. Pools active after work: Rendezvous
14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283)
15. Well Class after work:
Daily Report of Well Operations
Explomtory❑ Development ❑✓ Service ❑ Stratigraphic ❑
Copies of Logs and Surveys Run ❑
16. Well Status after work: Oil Gas WDSPL Lj
Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑
17. 1 hereby certify that the foregoing is true and correct to the
best of my knowledge. Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date:
Contact Name: Dana Glessner
Contact Email: lessd(akonocophillips.com
Authorized Title: Staff Production Engineer
Contact Phone: 907-265-6478
Sr Pet Eng: VTL 02/15/23
Sr Pet Geo: I ISr Res Eng:
RBDMS JSB 120822
Form 10-404 Revised 1012022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
-11
conoco`Phillips
Well History
MT7-99 : 501032084500 : 11/29/2022
Date Event
10/24/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE. DIVERTED WELL TO
PRODUCTION BEGING BLOW DOWN/ RIG DOWN
10/23/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE.
10/22/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE.
10/21/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE.
10/20/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE.
10/19/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE.
10/18/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE.
10/17/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE.
10/16/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE.
10/15/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE.
10/14/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE.
10/13/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE. LRS CONTINUES CONDUCTING
THE "MINI" SURGES IN AN ATTEMPT TO GET THE 4 REMAINING COMPUTER
BOARDS TO SURFACE. - (CONDUCTING THE "MINI" SURGES AS A MEANS TO LESSEN
THE IMPACT ON THE PLANT, PER OPS REQUEST)
10/12/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE. LRS CONTINUES CONDUCTING
THE "MINP' SURGES IN AN ATTEMPT TO GET THE 4 REMAINING COMPUTER
BOARDS TO SURFACE. - (CONDUCTING THE "MINP' SURGES AS A MEANS TO LESSEN
THE IMPACT ON THE PLANT, PER OPS REQUEST)
10/11/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE. LRS CONDUCTING SOME "MINP'
SURGES IN AN ATTEMPT TO GET THE 4 REMAINING COMPUTER BOARDS TO
SURFACE. - (CONDUCTING THE "MINP' SURGES AS A MEANS TO LESSEN THE
IMPACT ON THE PLANT, PER OPS REQUEST)
10/10/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE. DIRECTED LRS TO SURGE WELL
3-4 TIMES IN AN ATTEMPT TO BRING UP/ RECOVER ADDITIONAL DART MATERIAL
SUSPECTED TO STILL BE DOWN HOLE. 3 AM, LRS RETRIEVED SOME DART DEBRIS
FROM BALLCATCHER
10/09/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE. WELL SLUGGED AT —9AM,
BRINGING UP QUITE A BIT OF DART DEBRIS AND GRAVEL. DIRECTED LRS TO
SURGE WELL 3-4 TIMES IN AN ATTEMPT TO BRING UP/ RECOVER ADDITIONAL
DART MATERIAL SUSPECTED TO STILL BE DOWN HOLE.
10/08/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE. LRS RETRIEVED SOME DART
DEBRIS FROM BALLCATCHER
10/07/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE. LRS RETRIEVED SOME DART
DEBRIS FROM BALLCATCHER
10/06/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE.
10/05/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE. CHOKE WAS BYPASSED AT 3AM.
LRS RETRIEVING GRAVEL FROM BALLCATCHER.
10/04/2022 LRS CONTINUES TO FLOW WELL PER PROCEDURE. CHOKE WAS WORKED UP TO
WIDE OPEN (128 BEANS) AT I IPM. LRS RETRIEVING GRAVEL FROM BALLCATCHER.
10/03/2022 LRS WILL CONTINUE TO FLOW/UNLOAD WELL PER PROCEDURE, INCREASING
CHOKE AS CONDITIONS ALLOW. LRS RETRIEVING GRAVEL AND DART DEBRIS
FROM BALLCATCHER.
10/02/2022 LRS WILL CONTINUE TO FLOW/UNLOAD WELL PER PROCEDURE, INCREASING
CHOKE AS CONDITIONS ALLOW. LRS RETRIEVING GRAVEL AND DART DEBRIS
FROM BALLCATCHER. DHD SHOT IA F/L AT 11:30AM, WAS AT 6450' (-321' ABOVE 2ND
STAT)
10/O1/2022 LRS COMPLETED RU, CONDUCTED WALKDOWN / SIGNOFF WITH OPS. LRS DID PT
ON INLET PIPING (GOOD). LRS POP WELL AT 8:35PM. LRS HAD TO FLOW WELL TO
TANK FARM 2 TIMES TO GET WELL TO UNLOAD/FLOW.
09/28/2022 Dart DRP SLW Dwn Land Early Seat PSI Peak PSI Diff. BH Seat PSI 1 416 656 7119.8 2,352
3,823 1,471 5,647 2 764 995 1,049 11.4 2,291 3,822 1,531 5,578 3 1,074 1,291 1,347 9.4 2,083
3,777 1,694 5,476 4 1,365 1,569 1,629 5.5 1,944 3,755 1,811 5,379 5 1,649 1,846 1,903 7.7 2,054
3,798 1,744 5,3716 1,922 2,105 2,163 6.6 1,998 3,807 1,809 5,3117 2,191 2,362 2,419 8.1 1,968
3,816 1,848 5,2918 2,442 2,602 2,658 8.6 1,764 3,656 1,892 5,083 9 2,683 2,831 2,889 7 1,776
3,453 1,677 5,098 10 2,911 3,048 3,104 8.6 1,759 3,839 2,080 5,083 113,137 3,262 3,320 7.1
2,034 3,904 1,870 5,363 12 3,335 3,442 3,496 10.8 1,390 3,257 1,867 4,702 13 3,788 3,886 3,943
8.3 1,355 3,805 2,450 4,673 14 4,515 4,608 4,132 541 1,288 3,700 2,412 4,591
09/27/2022 Rigged in the dart launcher and the frac pupdown tie in.
09/27/2022 RIH W/A 4.5" GR SD @ 9,858' WORKED JARS LATCHED DB SUB JAR FREE, POOH REC
SUB, THEN RIH W/'TANDEM BHP GAUGES MADE A GRADIENT STOP @ 10,000' FOR 30
MIN AND ANOTHER GRADIENT STOP @ 9,850' FOR 15 MIN THEN POOH. MAX
BOTTOM HOLE PRESSURE: #3904 MAX TEMP: 200 deg.
09/26/2022 SHAKE BAIT SUB BELL GUIDE ASSEMBLY OFF TOOL STRING ON TOP OF BALL AND
ROD, PULLED ALL 3 GLV STA. SET 5/16" OV IN STA #3 @ 9534' RKB, SET GLV (TRO=
1730psi 3/16" PORT) IN STA # 2 @ 6770' RKB, SET GLV (TRO= 1754 psi 3/16" PORT) IN
STA # 1 @ 3823' RKB PULLED, BAIT SUB, BELL GUIDE AND BALL & ROD. JOB IN
PROGRESS.
[I%'7!►Ti Iri17�7��71Y:a�/�IIC�7uil�/:��I�I�i7: I�:C� C C fluC�P/.�/: ► � C �:Y�1.'TIC� C U �]�f�.1
29 records retrieved for Well History
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 2097' FSL, 127' FWL SESW S5 T9N R2E 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 100.8 BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" H-40 120'
13 3/8" L-80 3,046'
9 5/8" L-80 7,426'
7" L-80 8,312'
4 1/2" L-80 8,450'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
Sr Res EngSr Pet GeoSr Pet Eng
100
N/A
0.79
Oil-Bbl: Water-Bbl:
3425
Water-Bbl:
PRODUCTION TEST
10/1/2022
Date of Test: Oil-Bbl:
687351225
10/18/2022 1/24/1900
Flow Tubing
68
5694
16625694
Gas Lift
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date perf'd or liner run):
Liner: 9,868'MD/8,266'TVD - 20,115MD/8,450'TVD
3425
Gas-Oil Ratio:Choke Size:
suspension, or abandonment; or within 90 days of acquisition of the log, 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 only if necessary.
N/A
GR, RES, DEN, DIR, AZI, PWD, SONIC, CALIPER
40'
40'
Per 20 AAC 25.283 (i)(2) attach electronic information
47
10,028'
40'
7277'
94
68
120'
40' 8,484'
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
9,868'
42"
12.6
5915845
Greater Mooses Tooth/Rendevous Pool
AA081800, AA081781
932535000, 932516000
40'
29
40'
8,301'
3,243'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
WT. PER
FT.GRADE
9/16/2022
CEMENTING RECORD
5911689
982'MD/980'TVD
SETTING DEPTH TVD
5900962
TOP HOLE SIZE AMOUNT
PULLED
288103
293268
TOP
SETTING DEPTH MD
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
9/22/2022 222-102
501-103-20845-00-00
GMT/MT7-99
8/27/2022
22,013'MD/8,453'TVD
N/A
139.9
P.O.Box 100360, Anchorage, AK 99510-0360
290044
1025' FSL, 1965' FWL SESW S32 T10N R2E
2076' FSL, 273' FWL SESW S16 T9N R2E
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
65bbls 15.8ppg Class G8.5"x9 7/8"
TUBING RECORD
20,115'
Lead: 73.2bbl 13ppg Class G
Tail: 258.2ppg 15.8ppg Class G
8266'
12 1/4"
6 1/2"
9,873'4.5 8,300'MD/7,276'TVD
9,742'MD/8,220'TVD
9,868'MD/8,266' TVD
BOTTOM
16" Lead: 382bbl 11ppg
DeepCRETE
Tail: 73bbl 15.8ppg Class G
CASING
WINJ
SPLUGOther Abandoned Suspended
Stratigraphic Test
No
No
(attached) No
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 10:00 am, Oct 24, 2022
24
37
Completed
9/22/2022
JSB
RBDMS JSB 102522
GDSR-11/3/22DLB 11/15/2022
O.K. DLB
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
982 980
C-30 1083 1415
2019 1994
3190 3002
K-2 3606 3746
Albian 97 3937 4077
Albian 96 4168 4308
HRZ 8483 8623
Kalubik 8580 8720
Kuparuk C 8727 8867
8730 8870
Top of Productive Interval 10092 10232
22013 22153
31. List of Attachments:
Directional Survey, Well Schematic, Cement Operations, Operations Summary
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Brad Gorham
Digital Signature with Date:
Contact Phone:907-265-6487
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
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.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
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).
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.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
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.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
LCU/Miluveach
C-10
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.
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.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
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.
TPI (Top of Producing Interval).
Authorized Name and
INSTRUCTIONS
Contact Email: brad.gorham@conocophillips.com
Authorized Title: Drilling Engineer
K-3
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Formation Name at TD:
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
No
NoSidewall Cores: Yes No
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Alpine C
Alpine C
Tubing / Liner Completion:
1) 4-½” Landing Nipple (3.813" ID)
2) 4-½” x 1” GLM (2-3x)
3) HES Downhole Gauge
4) Production Packer
5) 4-½” Landing Nipple (3.75" ID)
6) Liner Top Packer / Hanger w/ Tie Back
sleeve
7) Frac Sleeves / Swell Packers
4-½” 12.6# L-80 Hyd563 Liner
Shoe set @ 20,115' MD
With 13 swell packers and 3 closeable Advanced Upstream frac
sleeves and 11 lock open Advanced Upstream frac sleeves
Tubing
4-1/2" 12.6# L-80 Hyd563
X
GLGL
9/24/2022
Production
Packer
Liner Top
Packer
Downhole
Gauge
Logged Int1 TOC
4,350' MD / 3,971' TVD
MT7-99 4-String Southern Injector As Drilled Schematic
Updated 9.24.2022
20" 94 ppf H-40 Insulated
Conductor
80 feet, cemented to surface
16" Surface Hole
Surface Casing
13-3/8" 68# L-80 Hyd563
Set at 3,243' MD / 3,046' TVD
12-¼” Intermediate 1 Hole
Intermediate 1 Casing
9-5/8" 43.5# L-80 HYD563 & 47# T-95 H563
Set @ 8,484' MD / 7,426' TVD
Top Susitna
7,276' MD /
6,421' TVD
Top Alpine D
9,934 MD / 8,289' TVD
Top Alpine C
10,092' MD / 8,328' TVD
6-1/8” Production Hole
Liner top at 9,868' MD / 8,265' TVD
TD at 23,820' MD / 8,449' TVD
Logged Int2 TOC
8,740' MD / 7,628' TVD
8-½” X 9-7/8" Intermediate 2 Hole
Intermediate 2 Liner
7" 29# L-80 HYD563
Liner top at +/- 8,301' MD / 7,275' TVD
Shoe set @ 10,028' MD / 8,312' TVD
Top Sub-Albian 93
5,986' MD /
5,341' TVD
Casing Strings
Casing Description
CONDUCTOR
OD (in)
20
ID (in)
19.12
Top (ftKB)
40.0
Set Depth (ft…
120.0
Set Depth …
120.0
Wt/Len (lb/ft)
94.00
Grade Top Connection
Casing Description
SURFACE
OD (in)
13 3/8
ID (in)
12.42
Top (ftKB)
39.4
Set Depth (ft…
3,243.0
Set Depth …
3,046.2
Wt/Len (lb/ft)
68.00
Grade
L-80
Top Connection
H563
Casing Description
INTERMEDIATE 1
OD (in)
9 5/8
ID (in)
8.68
Top (ftKB)
37.0
Set Depth (ft…
8,483.9
Set Depth …
7,426.3
Wt/Len (lb/ft)
47.00
Grade
T95
Top Connection
N/A
Casing Description
INTERMEDIATE 2
OD (in)
7
ID (in)
6.18
Top (ftKB)
8,300.9
Set Depth (ft…
10,028.0
Set Depth …
8,312.3
Wt/Len (lb/ft)
29.00
Grade
L-80
Top Connection
TSH 563
Casing Description
LINER
OD (in)
4 1/2
ID (in)
3.96
Top (ftKB)
9,868.2
Set Depth (ft…
20,115.0
Set Depth …
8,449.7
Wt/Len (lb/ft)
12.60
Grade
L-80
Top Connection
Hyd 563
Liner Details: excludes liner, pup, joints, casing, sub , shoe , float...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com Make Model
Nominal ID
(in)
10,380.3 8,387.1 80.78 FRAC Sleeve/Port Advanced Upstream SP Re-Closeable
Frac Sleeve #14, Hyd563 (SN:107208-
000006)
Advance
d
Upstrea
m
3.450
10,512.4 8,405.4 83.33 Swell Packer Baker 5.75" OD Swell Packer # 13
(assy ), 4-1/2",12.6#, L80, H563
(SN:003585-001-39)
Baker Rapidsw
ell 922
3.900
10,731.7 8,425.1 85.29 FRAC Sleeve/Port Advanced Upstream SP Re-Closeable
Frac Sleeve #13, Hyd563 (SN:107208-
000005)
Advance
d
Upstrea
m
3.450
10,944.1 8,438.9 88.56 Swell Packer Baker 5.75" OD Swell Packer # 12
(assy ), 4-1/2",12.6#, L80, H563
(SN:003585-001-18)
Baker Rapidsw
ell 922
3.900
11,289.7 8,438.8 90.59 FRAC Sleeve/Port Advanced Upstream SP Lock Open
Frac Sleeve #12, Hyd563 (SN:107394-
000022)
Advance
d
Upstrea
m
3.450
12,107.1 8,447.4 87.77 Swell Packer Baker 5.75" OD Swell Packer # 11
(assy ), 4-1/2",12.6#, L80, H563
(SN:003585-001-24)
Baker Rapidsw
ell 922
3.900
12,488.3 8,461.5 88.15 FRAC Sleeve/Port Advanced Upstream SP Lock Open
Frac Sleeve #11, Hyd563 (SN:107394-
000018)
Advance
d
Upstrea
m
3.450
12,860.8 8,471.9 89.61 Swell Packer Baker 5.75" OD Swell Packer # 10
(assy ), 4-1/2",12.6#, L80, H563
(SN:003585-001-10)
Baker Rapidsw
ell 922
3.900
13,245.7 8,470.9 90.08 FRAC Sleeve/Port Advanced Upstream SP Lock Open
Frac Sleeve #10, Hyd563 (SN:107394-
000012)
Advance
d
Upstrea
m
3.450
13,614.2 8,470.5 90.06 Swell Packer Baker 5.75" OD Swell Packer # 9
(assy ), 4-1/2",12.6#, L80, H563
(SN:003585-001-40)
Baker Rapidsw
ell 922
3.900
13,997.9 8,470.1 90.07 FRAC Sleeve/Port Advanced Upstream SP Lock Open
Frac Sleeve #9, Hyd563 (SN:107394-
000011)
Advance
d
Upstrea
m
3.450
14,372.4 8,467.8 90.59 Swell Packer Baker 5.5" OD Swell Packer # 8 (assy ),
4-1/2",12.6#, L80, H563 (SN:003585-
001-17)
Baker Rapidsw
ell 922
3.900
14,757.5 8,465.4 90.09 FRAC Sleeve/Port Advanced Upstream SP Lock Open
Frac Sleeve #8, Hyd563 (SN:107394-
000010)
Advance
d
Upstrea
m
3.450
15,133.4 8,465.0 90.06 Swell Packer Baker 5.5" OD Swell Packer # 7 (assy ),
4-1/2",12.6#, L80, H563 (SN:003585-
001-6)
Baker Rapidsw
ell 922
3.900
15,515.5 8,463.4 90.98 FRAC Sleeve/Port Advanced Upstream SP Re-Closeable
Frac Sleeve #7, Hyd563 (SN:107208-
000004)
Advance
d
Upstrea
m
3.450
15,968.7 8,451.9 91.74 Swell Packer Baker 5.5" OD Swell Packer # 6 (assy ),
4-1/2",12.6#, L80, H563 (SN:003585-
001-12)
Baker Rapidsw
ell 922
3.900
16,272.3 8,443.0 91.71 FRAC Sleeve/Port Advanced Upstream SP Lock Open
Frac Sleeve #6, Hyd563 (SN:107394-
000009)
Advance
d
Upstrea
m
3.450
16,646.8 8,442.3 88.87 Swell Packer Baker 5.5" OD Swell Packer # 5 (assy ),
4-1/2",12.6#, L80, H563 (SN:003585-
001-1)
Baker Rapidsw
ell 922
3.900
17,193.7 8,458.2 88.10 FRAC Sleeve/Port Advanced Upstream SP Lock Open
Frac Sleeve #5, Hyd563 (SN:107394-
000008)
Advance
d
Upstrea
m
3.450
17,486.9 8,466.8 88.03 Swell Packer Baker 5.5" OD Swell Packer # 4
(assy ), 4-1/2",12.6#, L80, H563
(SN:003585-001-9)
Baker Rapidsw
ell 922
3.900
17,708.7 8,474.5 87.99 FRAC Sleeve/Port Advanced Upstream SP Lock Open
Frac Sleeve #4, Hyd563 (SN:107394-
000006)
Advance
d
Upstrea
m
3.450
18,169.9 8,484.7 90.34 Swell Packer Baker 5.5" OD Swell Packer # 3 (assy ),
4-1/2",12.6#, L80, H563 (SN: 003585-
002-29)
Baker Rapidsw
ell 922
3.900
18,555.8 8,482.2 90.09 FRAC Sleeve/Port Advanced Upstream SP Lock Open
Frac Sleeve #3, Hyd563 (SN:107394-
000005)
Advance
d
Upstrea
m
3.450
19,010.0 8,477.0 91.52 Swell Packer Baker 5.5" OD Swell Packer # 2 (assy ),
4-1/2",12.6#, L80, H563 (SN: 003585-
001-22)
Baker Rapidsw
ell 922
3.900
HORIZONTAL, MT7-99, 10/20/2022 2:22:35 PM
Vertical schematic (actual)
LINER; 9,868.2-20,115.0
Shoe; 20,110.2-20,115.0
FRAC Sleeve/Port; 20,028.1-
20,029.7
Swell Packer; 19,850.0-19,870.3
FRAC Sleeve/Port; 19,474.8-
19,476.4
Swell Packer; 19,010.0-19,030.3
FRAC Sleeve/Port; 18,555.8-
18,557.4
Swell Packer; 18,169.9-18,190.2
FRAC Sleeve/Port; 17,708.7-
17,710.3
Swell Packer; 17,486.9-17,507.2
FRAC Sleeve/Port; 17,193.7-
17,195.3
Swell Packer; 16,646.8-16,667.1
FRAC Sleeve/Port; 16,272.3-
16,274.0
Swell Packer; 15,968.7-15,989.0
FRAC Sleeve/Port; 15,515.4-
15,517.5
Swell Packer; 15,133.4-15,153.7
FRAC Sleeve/Port; 14,757.5-
14,759.2
Swell Packer; 14,372.4-14,392.7
FRAC Sleeve/Port; 13,997.9-
13,999.5
Swell Packer; 13,614.2-13,634.5
FRAC Sleeve/Port; 13,245.7-
13,247.3
Swell Packer; 12,860.8-12,881.1
FRAC Sleeve/Port; 12,488.3-
12,489.9
Swell Packer; 12,107.1-12,127.4
FRAC Sleeve/Port; 11,289.7-
11,291.3
Swell Packer; 10,944.1-10,964.4
FRAC Sleeve/Port; 10,731.7-
10,733.7
Swell Packer; 10,512.4-10,532.7
FRAC Sleeve/Port; 10,380.3-
10,382.4
INTERMEDIATE 2; 8,300.9-
10,028.0
Float Shoe; 10,025.3-10,028.0
Collar - Float; 9,980.2-9,982.0
Landing Collar; 9,939.6-9,943.0
Hanger; 9,884.5-9,893.8
Packer (Liner Top); 9,868.2-
9,884.5
Packer (Tubing); 9,741.5
Gauge / Pump Sensor; 9,642.7
Mandrel; 9,534.3
INTERMEDIATE 1; 37.0-8,483.9
Casing Shoe; 8,480.8-8,483.9
Collar - Float; 8,391.9-8,394.6
Hanger; 8,318.0-8,327.3
Packer; 8,300.9-8,318.0
Mandrel; 6,770.9
Mandrel; 3,823.2
SURFACE; 39.3-3,243.0
Float Shoe; 3,240.8-3,243.0
Nipple - DB, XN, DS, D; 1,870.1
CONDUCTOR; 40.0-120.0
Casing Hanger; 39.3-40.6
Casing Hanger; 37.0-38.4
Hanger; 34.4
WNS PROD
KB-Grd (ft)
39.15
RR Date
9/22/2022
Other Elev…
MT7-99
...
TD
Act Btm (ftKB)
22,013.0
Well Attributes
Field Name
RENDE
Wellbore API/UWI
501032084500
Wellbore Status
PROD
Max Angle & MD
Incl (°)
95.25
MD (ftKB)
21,981.63
WELLNAME WELLBOREMT7-99
Annotation End DateH2S (ppm) DateComment
Liner Details: excludes liner, pup, joints, casing, sub , shoe , float...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com Make Model
Nominal ID
(in)
19,474.8 8,465.2 91.03 FRAC Sleeve/Port Advanced Upstream SP Lock Open
Frac Sleeve #2, Hyd563 (SN:107394-
000004)
Advance
d
Upstrea
m
3.450
19,850.0 8,456.9 91.51 Swell Packer Baker 5.5" OD Swell Packer # 1 (assy ),
4-1/2",12.6#, L80, H563 (SN: 003583-
001-11)
Baker Rapidsw
ell 922
3.900
20,028.1 8,452.1 91.54 FRAC Sleeve/Port Advanced Upstream SP Lock Open
Frac Sleeve #1, Hyd563 (SN:107394-
000003)
Advance
d
Upstrea
m
3.450
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
34.4
Set Depth …
8,267.2
String Ma…
4 1/2
Tubing Description
Tubing – Completion
Upper
Set Depth (ftKB)
9,873.1
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
Hyd563
ID (in)
3.96
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
34.4 34.4 0.00 Hanger 11.000 FMC 4-1/2" Tubing Hanger Hydril
HYD 563 Min ID 3.92"
FMC TC-EMS 3.958
1,870.1 1,852.8 17.37 Nipple - DB,
XN, DS, D
4.500 NIPPLE,LANDING,4 1/2","X",3.813",
H563 (SN#: 0004548837-3)
HES X Nipple 3.813
3,823.2 3,530.3 33.54 Mandrel 4.500 4-1/2" x 1" KBG 4-5 GLM w/ 2000
psi SOV,12.6# H563, BEK
(SN#23288-15)
Camco KBG4-5 3.865
6,770.9 5,997.7 33.17 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM w/ DV,
12.6# H563 BK Latch (SN#23288-6)
Camco KBG4-5 3.860
9,534.3 8,130.7 61.51 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM w/ DV,
12.6# H563 BK Latch (SN#23288-
16)
Camco KBG4-5 3.860
9,642.7 8,179.9 64.52 Gauge / Pump
Sensor
4.500 Halliburton Opsis Mandrel w/
Downhole guage (SN# 18417-4)
HES DHG 3.920
9,842.5 8,257.0 69.98 Nipple - DB,
XN, DS, D
4.500 NIPPLE,LANDING,4
1/2",DB,3.75",w/RHC Plug, H563
(SN# 8120-9)
SLB 3.750
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
3,823.2 3,530.3 33.54 1 OV BK 1 9/21/2022 VALV
E,SH
EAR,1
",DCK
-
2,CA
MCO,
DUM
P
KILL
CAMCO
6,770.9 5,997.7 33.17 2 DMY BK 1 9/21/2022 VALV
E,DU
MMY,
1",DK,
W/LA
TCH,
CAM
CO
CAMCO
9,534.3 8,130.7 61.51 3 DMY BK 1 9/21/2022 CAMCO
HORIZONTAL, MT7-99, 10/20/2022 2:22:36 PM
Vertical schematic (actual)
LINER; 9,868.2-20,115.0
Shoe; 20,110.2-20,115.0
FRAC Sleeve/Port; 20,028.1-
20,029.7
Swell Packer; 19,850.0-19,870.3
FRAC Sleeve/Port; 19,474.8-
19,476.4
Swell Packer; 19,010.0-19,030.3
FRAC Sleeve/Port; 18,555.8-
18,557.4
Swell Packer; 18,169.9-18,190.2
FRAC Sleeve/Port; 17,708.7-
17,710.3
Swell Packer; 17,486.9-17,507.2
FRAC Sleeve/Port; 17,193.7-
17,195.3
Swell Packer; 16,646.8-16,667.1
FRAC Sleeve/Port; 16,272.3-
16,274.0
Swell Packer; 15,968.7-15,989.0
FRAC Sleeve/Port; 15,515.4-
15,517.5
Swell Packer; 15,133.4-15,153.7
FRAC Sleeve/Port; 14,757.5-
14,759.2
Swell Packer; 14,372.4-14,392.7
FRAC Sleeve/Port; 13,997.9-
13,999.5
Swell Packer; 13,614.2-13,634.5
FRAC Sleeve/Port; 13,245.7-
13,247.3
Swell Packer; 12,860.8-12,881.1
FRAC Sleeve/Port; 12,488.3-
12,489.9
Swell Packer; 12,107.1-12,127.4
FRAC Sleeve/Port; 11,289.7-
11,291.3
Swell Packer; 10,944.1-10,964.4
FRAC Sleeve/Port; 10,731.7-
10,733.7
Swell Packer; 10,512.4-10,532.7
FRAC Sleeve/Port; 10,380.3-
10,382.4
INTERMEDIATE 2; 8,300.9-
10,028.0
Float Shoe; 10,025.3-10,028.0
Collar - Float; 9,980.2-9,982.0
Landing Collar; 9,939.6-9,943.0
Hanger; 9,884.5-9,893.8
Packer (Liner Top); 9,868.2-
9,884.5
Packer (Tubing); 9,741.5
Gauge / Pump Sensor; 9,642.7
Mandrel; 9,534.3
INTERMEDIATE 1; 37.0-8,483.9
Casing Shoe; 8,480.8-8,483.9
Collar - Float; 8,391.9-8,394.6
Hanger; 8,318.0-8,327.3
Packer; 8,300.9-8,318.0
Mandrel; 6,770.9
Mandrel; 3,823.2
SURFACE; 39.3-3,243.0
Float Shoe; 3,240.8-3,243.0
Nipple - DB, XN, DS, D; 1,870.1
CONDUCTOR; 40.0-120.0
Casing Hanger; 39.3-40.6
Casing Hanger; 37.0-38.4
Hanger; 34.4
WNS PROD MT7-99
...
WELLNAME WELLBOREMT7-99
Page 1/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/25/2022
00:00
8/25/2022
06:00
6.00 MIRU, MOVE MOB P Grease and shell test choke manifold.
Install slip ring adapter on MT7-99.
RAise c-section and pin. Prep to skid rig
floor.
8/25/2022
06:00
8/25/2022
08:30
2.50 MIRU, MOVE MOB P Prep cellar at MT7-99. Diconnect
electrical inter-connects. Skid rig flor.
Stomp motor complex out
8/25/2022
08:30
8/25/2022
10:00
1.50 MIRU, MOVE MOB P Lay derrick over. Stomp pumppit
complex out. Lift sub and stomp
pipeshed out.
8/25/2022
10:00
8/25/2022
12:00
2.00 MIRU, MOVE MOB P Stomp sub out and spot over MT7-99
well. Stage pits and motor complex. Lift
sub and stomp pipeshed under sub.
8/25/2022
12:00
8/25/2022
15:00
3.00 MIRU, MOVE MOB P Spot pipe shed. Shim and pin to sub.
Spot and shim pits. Raise derrick.
8/25/2022
15:00
8/25/2022
18:00
3.00 MIRU, MOVE MOB P Skid rig floor to drilling position. Spot
pump and motor complex. Raise cattle
chute.
8/25/2022
18:00
8/26/2022
00:00
6.00 MIRU, MOVE MOB P Connect electrical lines. MU
interconnects. Install stand pipe/cement
line and kelly hose.
8/26/2022
00:00
8/26/2022
03:30
3.50 MIRU, MOVE RURD P NU surface riser/Joes box and chink up
same. Install 90' MH. Calibrate blocks.
Inspect saver sub. Take on mud to pits.
0.0 0.0
8/26/2022
03:30
8/26/2022
06:30
3.00 MIRU, MOVE PULD P Stage BHA tools to rig floor. MU and
rack back HWDP and jars for BHA#1
0.0 0.0
8/26/2022
06:30
8/26/2022
07:00
0.50 MIRU, MOVE OTHR P MU muleshoe and RIH to check for ice
plugs in conductor. Tag @ 102'. POOH.
0.0 0.0
8/26/2022
07:00
8/26/2022
07:30
0.50 MIRU, MOVE OTHR P Fill hole. Check for leaks on riser/hole
fill/flowline. (observedd leak on 4" ball
valve on conductor).
0.0 0.0
8/26/2022
07:30
8/26/2022
09:00
1.50 MIRU, MOVE PRTS P Pressure test mudlines back to pump to
380psi. Good test.
SimOps: CO 4" ball valve on conductor.
0.0 0.0
8/26/2022
09:00
8/26/2022
12:00
3.00 MIRU, MOVE BHAH P MU BHA #1 and RIH to 63'. Wash down
and tag @ 102'.
0.0 102.0
8/26/2022
12:00
8/26/2022
13:30
1.50 MIRU, MOVE DDRL P Drill 16" surface hole f/ 102' to 243'.
5k WOB
675 GPM
1100 PSI
40 RPM
3k TQ
68k PU
102.0 243.0
8/26/2022
13:30
8/26/2022
14:00
0.50 MIRU, MOVE BKRM P BROOH to 63'.
610 GPM
660 PSI
40 RPM
3k TQ
243.0 63.0
8/26/2022
14:00
8/26/2022
17:30
3.50 MIRU, MOVE BHAH P MU and RIH w/ BHA #1 f/ 63' to 242'. 63.0 242.0
8/26/2022
17:30
8/27/2022
00:00
6.50 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 242' to 795'.
Start weighting up to 11.0ppg @ 705'
850 GPM
2200 PSI
60 RPM
5k TQ
5k WOB
242.0 795.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 2/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/27/2022
00:00
8/27/2022
06:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 795' MD' to
1456'MD/1450' TVD.
900 GPM
2500 PSI
60 RPM
5k TQ
5k WOB
11.0ppg MW in/out
795.0 1,500.0
8/27/2022
06:00
8/27/2022
12:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 1456' MD' to
2118'MD/2085' TVD.
900 GPM
2680 PSI
60 RPM
6k TQ
10k WOB
11.0ppg MW in/out
11.4ppg ECD
1.9hrs AST
2.4hrs ART
13.1hrs ttl bit hrs
5.3hrs ttl jar hrs
1,500.0 2,118.0
8/27/2022
12:00
8/27/2022
18:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 2118' MD' to
2793'MD/2668' TVD.
900 GPM
2880 PSI
60 RPM
9k TQ
22k WOB
123k PU
113k SO
115k ROT
11.0ppg MW in/out
11.5ppg ECD
1.8hrs AST
2.4hrs ART
17.3hrs ttl bit hrs
13.8hrs ttl jar hrs
2,118.0 2,793.0
8/27/2022
18:00
8/27/2022
22:15
4.25 SURFAC, DRILL DDRL P Drill 16" surface hole f/ 2793' MD' to
3253'MD/xxxxx' TVD.
900 GPM
2880 PSI
60 RPM
9k TQ
22k WOB
123k PU
113k SO
115k ROT
11.0ppg MW in/out
11.5ppg ECD
1.8hrs AST
2.4hrs ART
17.3hrs ttl bit hrs
13.8hrs ttl jar hrs
2,793.0 3,253.0
8/27/2022
22:15
8/27/2022
23:30
1.25 SURFAC, TRIPCAS CIRC P Circulate and BROOH at 1 BU per std f/
2 stds. 3253' to 3063'
900 GPM
2850 PSI
60 RPM
3k TQ
3,253.0 3,063.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 3/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/27/2022
23:30
8/28/2022
00:00
0.50 SURFAC, TRIPCAS OWFF P Flow check. Static 3,063.0 3,063.0
8/28/2022
00:00
8/28/2022
08:00
8.00 SURFAC, TRIPCAS BKRM P BROOH f/ 3063' to 1400'. 400-600 ft/hr.
900 GPM
2730 PSI
80 RPM
5k TQ
11.8ppg ECD
3,063.0 607.0
8/28/2022
08:00
8/28/2022
08:30
0.50 SURFAC, TRIPCAS CIRC P CBU.
900 GPM
2290 PSI
80 RPM
2k TQ
607.0 607.0
8/28/2022
08:30
8/28/2022
12:00
3.50 SURFAC, TRIPCAS BHAH P FLOW check. Static.
POOH. Rack back HWDP and DC. LD
BHA.
607.0 0.0
8/28/2022
12:00
8/28/2022
12:30
0.50 SURFAC, CASING CLEN P Clean/clear rig floor. PJSM 0.0 0.0
8/28/2022
12:30
8/28/2022
14:30
2.00 SURFAC, CASING RURD P RU CRT and handling equipment. 0.0 0.0
8/28/2022
14:30
8/28/2022
18:30
4.00 SURFAC, CASING PUTB P RIH w/ 1 3 3/8" 68# L-80 H563 casing to
1060'.
0.0 1,060.0
8/28/2022
18:30
8/28/2022
19:00
0.50 SURFAC, CASING CIRC P CBU. Staging pumps up to 8BPM.
115PSI.
1,060.0 1,060.0
8/28/2022
19:00
8/29/2022
00:00
5.00 SURFAC, CASING PUTB P RIH w/ 1 3 3/8" 68# L-80 H563 casing f/
1060' to 2983'
1,060.0 2,983.0
8/29/2022
00:00
8/29/2022
01:00
1.00 SURFAC, CASING PUTB P RIH w/ 1 3 3/8" 68# L-80 H563 casing f/
2983' to 3200'
2,983.0 3,200.0
8/29/2022
01:00
8/29/2022
04:00
3.00 SURFAC, CASING PUTB P MU csg hanger and landing joint. Wash
down and land.
2-5 BPM
140-300PSI
FS @ 3243'
3,200.0 3,243.0
8/29/2022
04:00
8/29/2022
06:00
2.00 SURFAC, CASING CIRC P Stage pumps up to 8 BPM. Circulate
and condition mud. Reciprocating
casing 5-15'. SD RU cement line. Stage
pumps back up.
8 BPM
200 PSI
213k PU
185k SO
3,243.0 3,243.0
8/29/2022
06:00
8/29/2022
10:00
4.00 SURFAC, CEMENT CMNT P Swap over to cementers. Pump 5bbls
FW ahead. Pressure test line sto
3500psi. pump 113bbls 10.9ppg
MudPush. SD. Drop bottom plug. Mix
and pump 382bbls of 11ppg lead
cement/73bbls of 15.8ppg tail cement.
SD. Drop top plug. Pump 20bbls FW w/
cement unit. Swap over to rig and
displace cement. Displace @ 8bpm.
Slow pumps to 3bpm and bump plug.
FCP360psi.Bump plug and hold 500psi
over at 960psi. Check floats. Good.
160bbls cement back to surface.
Plug down @ 09:30hrs 8/29/22
3,243.0 3,243.0
8/29/2022
10:00
8/29/2022
13:00
3.00 SURFAC, CEMENT RURD P Flush lines and riser w/ blackwater pill.
Drain riser. Pull landing joint. RD casing
equipment. Clean and clear rig
floor/BOP deck.
3,243.0 3,243.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 4/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/29/2022
13:00
8/29/2022
16:00
3.00 SURFAC, WHDBOP NUND P ND surface riser. 0.0 0.0
8/29/2022
16:00
8/29/2022
17:00
1.00 SURFAC, WHDBOP NUND P NU and orientate WH. 0.0 0.0
8/29/2022
17:00
8/29/2022
23:00
6.00 SURFAC, WHDBOP NUND P Nipple up drilling riser & BOPE
SIMOPS- Clean pits, slide Joe's box,
install flow line, choke & kill lines, N/U
MPD equipment Test FMC wellhead
seal t/ 1,000 psi f/ 10 minutes test
witnessed by COPA
0.0 0.0
8/29/2022
23:00
8/30/2022
00:00
1.00 SURFAC, WHDBOP NUND P C/O IBOP assembly and saver sub. 0.0 0.0
8/30/2022
00:00
8/30/2022
02:00
2.00 SURFAC, WHDBOP NUND P C/O IBOP assembly and Saver sub. 0.0 0.0
8/30/2022
02:00
8/30/2022
04:00
2.00 SURFAC, WHDBOP MPDA P Install test plug per FMC. Install MPD
test cap. Test MPD equipment.
0.0 0.0
8/30/2022
04:00
8/30/2022
12:00
8.00 SURFAC, WHDBOP BOPE P Test BOPE all test T/ 250 low for 5 min
and 5,000 high for 10 min charted. W/
exception of annular T/ 250 low for 5
min and 3,500 high for 10 min. Manual
operated & super choke tested T/2,000
psi charted, W/ 5" test JT test annular,
2 7/8" X 5 1/2" UPR, 2 7/8" X 5 1/2"
LPR,Test choke valves 1-15, manual
operated & super choke, Choke & kill
manuals, HCR's, 4" valves on kill line, 5"
FOSV, 5" Dart valve, Upper and lower
IBOP on TD; Blind/shear rams; Perform
KOOMEY drawdown, ACC = 3000 PSI.
MANIF. = 1500 PSI. ACC = 1650 PSI
After all functions on bottles, 15 sec for
200 psi. Build W/ 2 Elec. pumps, 93 sec
T/ Build full system. Pressure W/ 2 Elec.
& 2 Air pumps, Closing times, Annular =
23 sec. UPR = 18 sec. Blind / Shears =
16 sec. LPR = 16 sec. Choke HCR = 2
Ssec. Kill HCR = 2 sec; Test PVT G/L
and flow out alarms, Test LEL and H2S
alarms.
0.0 0.0
8/30/2022
12:00
8/30/2022
12:30
0.50 SURFAC, WHDBOP NUND P Install wear bushing. ID= 12.315" 0.0 0.0
8/30/2022
12:30
8/30/2022
13:00
0.50 SURFAC, WHDBOP RURD P RD test equipment. Line up choke
manifold f/ drilling.
0.0 0.0
8/30/2022
13:00
8/30/2022
14:00
1.00 SURFAC, WHDBOP PRTS P Line up and pressure test 13 3/8"
cassing to 3500 psi f/ 30 minutes. Good
test.
0.0 0.0
8/30/2022
14:00
8/30/2022
17:00
3.00 SURFAC, DRILLOUT BHAH P PJSM. MU BHA and RIH to 575'. 0.0 575.0
8/30/2022
17:00
8/30/2022
19:00
2.00 SURFAC, DRILLOUT TRIP P RIH w/ BHA #2 f/ 575' to 2935' 575.0 2,935.0
8/30/2022
19:00
8/30/2022
20:00
1.00 SURFAC, DRILLOUT CIRC P Fill Pipe. Shallow Test MWD (good).
Wash down and tag @ 3149'.
2,935.0 3,149.0
8/30/2022
20:00
8/31/2022
00:00
4.00 SURFAC, DRILLOUT DRLG P Drill out cement/plugs/FC/shoetrack to
3241'.
275-600 GPM
275-1150 PSI
40-70 RPM
5-20k WOB
3,149.0 3,241.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 5/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/31/2022
00:00
8/31/2022
00:30
0.50 SURFAC, DRILLOUT DRLG P Drill out FS. Clean out RH. Drill 20' new
formation to 3273'.
850 GPM
2200 PSI
80 RPM
10k TQ
10k WOB
3,241.0 3,273.0
8/31/2022
00:30
8/31/2022
01:00
0.50 SURFAC, DRILLOUT CIRC P BROOH while CBU to 3213'.
850 GPM
2130 PSI
80 RPM
10k TQ
3,273.0 3,213.0
8/31/2022
01:00
8/31/2022
02:30
1.50 SURFAC, DRILLOUT FIT P RU and perform FIT to 18,5ppg EMW.
RD test equipment.
11.0 Current MW + 1200PSI
3,213.0 3,213.0
8/31/2022
02:30
8/31/2022
03:00
0.50 SURFAC, DRILLOUT WASH P MU STD. Wash/Ream back to bottom
@ 3273'. Pump 40bbl HiVis pill for
displacement to 12.0ppg LSND mud
3,213.0 3,273.0
8/31/2022
03:00
8/31/2022
05:00
2.00 INTRM1, DRILL DDRL P Drill 3273'MD to 3407' MD/3181'TVD.
Displace to 12.0ppg LSND mud.
WOB: 7 k
GPM: 850
PSI: 1700
ECD: 12.4ppg
RPM: 150
TQ: 8k
PU: k
SO: k
ROT: k
3,273.0 3,407.0
8/31/2022
05:00
8/31/2022
06:00
1.00 INTRM1, DRILL PMPO T MWD tools not working. Troubleshoot.
No Success. POOH f/ tool swap. Pump
out to shoe cleaning hole. Flow check.
Good.
3,407.0 3,218.0
8/31/2022
06:00
8/31/2022
08:00
2.00 INTRM1, DRILL TRIP T POOH to 576'. Flow check before BHA. 3,218.0 576.0
8/31/2022
08:00
8/31/2022
13:00
5.00 INTRM1, DRILL BHAH T Swap out BHA smart tools. RIH to 576'. 576.0 576.0
8/31/2022
13:00
8/31/2022
15:00
2.00 INTRM1, DRILL TRIP T RIH f/ 576' to 3215' 576.0 3,215.0
8/31/2022
15:00
8/31/2022
15:30
0.50 INTRM1, DRILL WASH T Wash down f/ 3215' to 3407'.
GPM 850
PSI 1700
RPM 80
TQ 6k
576.0 3,215.0
8/31/2022
15:30
9/1/2022
00:00
8.50 INTRM1, DRILL DDRL P Drill 3407'MD to 4630' MD/ 'TVD.
WOB: 16 k
GPM: 1000
PSI: 2760
ECD: 12.7ppg
RPM: 170
TQ: 10k
PU: k
SO: k
ROT: k
TBH: 6.0hrs
TJH: 24.3hrs
3,215.0 4,630.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 6/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/1/2022
00:00
9/1/2022
07:45
7.75 INTRM1, DRILL DDRL P Drill 4630'MD to 5510' MD. Decrease
ROP for ECD.
WOB: 12 k
GPM: 1000
PSI: 3134
ECD: 12.8ppg
RPM: 170
TQ: 9k
PU:160k
SO: 141k
ROT: 135k
TBH: 12.2hrs
TJH: 30.8hrs
4,630.0 5,510.0
9/1/2022
07:45
9/1/2022
08:45
1.00 INTRM1, DRILL OTHR T Swapped over to HiLine power.
Computers and comms went down.
Troubleshoot and found that battery
backups did not switch over.
5,510.0 5,510.0
9/1/2022
08:45
9/1/2022
18:00
9.25 INTRM1, DRILL DDRL P Drill 5510'MD to 6583' MD / 5841' TVD.
Decrease ROP for ECD as needed.
WOB: 17 k
GPM: 1000
PSI: 3350
ECD: 12.8ppg
RPM: 170
TQ: 11k
PU:187k
SO: 160k
ROT: 160k
TBH: 18.7hrs
TJH: 37hrs
5,510.0 6,583.0
9/1/2022
18:00
9/2/2022
00:00
6.00 INTRM1, DRILL DDRL P Drill 6583'MD to 7147' MD / 6335' TVD.
Decrease ROP for ECD as needed.
WOB: 17 k
GPM: 1000
PSI: 3750
ECD: 12.8ppg
RPM: 170
TQ: 12k
PU:192k
SO: 165k
ROT: 162k
TBH: 25.1hrs
TJH: 41hrs
6,583.0 7,147.0
9/2/2022
00:00
9/2/2022
06:00
6.00 INTRM1, DRILL DDRL P Drill 7147'MD to 7740' MD. Decrease
ROP for ECD as needed. Observed
losses @ 7400' 50-100bbls/hr. Slow
pumps and ROP.Start adding 5ppb nut
plug fine/5ppb nut plug medium
background LCM.
WOB: 17 k
GPM: 875
PSI: 3025
ECD: 12.7ppg
RPM: 170
TQ: 16k
PU:214k
SO: 173k
ROT: 194k
TBH: 30.1hrs
TJH: 50.4hrs
7,147.0 7,740.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 7/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/2/2022
06:00
9/2/2022
16:00
10.00 INTRM1, DRILL DDRL P Drill 7147'MD to 8494' MD / 7434' TVD.
TD section @ 16:00hrs 9/2/22.
WOB: 8 k
GPM: 950
PSI: 3710
ECD: 12.8ppg
RPM: 170
TQ: 17k
PU:235k
SO: 173k
ROT: 195k
TBH: 37.4hrs
TJH: 55.7hrs
7,740.0 8,494.0
9/2/2022
16:00
9/2/2022
18:00
2.00 INTRM1, TRIPCAS BKRM P Circulate and clear HRZ. BROOH at 1
BU per std for 3 stds to 8214'.
GPM 950
PSI 3550
RPM 170
TQ 14k
ECD 12.6ppg
8,494.0 8,214.0
9/2/2022
18:00
9/2/2022
19:30
1.50 INTRM1, TRIPCAS BKRM P Flow check. Static. CBU @ 1 BU/Std to
8120'.
GPM 950
PSI 3550
RPM 170
TQ 14k
ECD 12.6ppg
8,214.0 8,120.0
9/2/2022
19:30
9/3/2022
00:00
4.50 INTRM1, TRIPCAS BKRM P BROOH f/ 8120' to 6705'
GPM 950
PSI 3475
RPM 170
TQ 14k
ECD 12.8ppg
8,120.0 6,705.0
9/3/2022
00:00
9/3/2022
12:00
12.00 INTRM1, TRIPCAS BKRM P BROOH f/ 6705' to 3780'
GPM 1000
PSI 3175
RPM 170
TQ 9k
ECD 12.8ppg
6,705.0 3,780.0
9/3/2022
12:00
9/3/2022
14:30
2.50 INTRM1, TRIPCAS BKRM P BROOH f/ 3780' to 3218'. Ream through
shoe @ 60 RPM w/ no torque/pressure
spikes or OP observed.
GPM 1000
PSI 3175
RPM 170
TQ 9k
ECD 12.8ppg
3,780.0 3,218.0
9/3/2022
14:30
9/3/2022
15:30
1.00 INTRM1, TRIPCAS CIRC P Circulate 50bbl nut plug sweep around.
GPM 1000
PSI 2650
RPM 60
TQ 4k
ECD 12.5ppg
3,218.0 3,218.0
9/3/2022
15:30
9/3/2022
18:00
2.50 INTRM1, TRIPCAS TRIP P POOH f/ 3218' to 575'. 3,218.0 575.0
9/3/2022
18:00
9/3/2022
18:30
0.50 INTRM1, TRIPCAS OWFF P Flow check. Static. PJSM f/ BHA. 575.0 575.0
9/3/2022
18:30
9/3/2022
21:30
3.00 INTRM1, CASING BHAH P Rack back HWDP and DC. LD BHA. 575.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 8/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/3/2022
21:30
9/3/2022
22:30
1.00 INTRM1, CASING CLEN P Retrieve Wear bushing. Install test plug.
Clean/clear rig floor. Install 9 5/8" test
joint.
SimOps: Swapping rams in BOP.
0.0 0.0
9/3/2022
22:30
9/3/2022
23:30
1.00 INTRM1, CASING BOPE P Test 9 5/8" casing rams 250/3500psi
5/10min low/high. RD test equipment
and LD test joint.
Witness waived per Brian Bixby AOGCC
email 06:41hrs 9/3/22
SimOps: Bringing casing handling
equipment to rig floor.
0.0 0.0
9/3/2022
23:30
9/4/2022
00:00
0.50 INTRM1, CASING RURD P RU csg handling equipment. 0.0 0.0
9/4/2022
00:00
9/4/2022
01:30
1.50 INTRM1, CASING RURD P RU csg handling equipment. 0.0 0.0
9/4/2022
01:30
9/4/2022
07:30
6.00 INTRM1, CASING PUTB P PJSM. MU and RIH w/
FS/shoetrack/FC. Check floats. Ok.
Continue RIH w/ 9 5/8" 47# T95 H563
casing to 3230' Filling pipe every 10jts.
9 4/8" 47# T95 H563 MU TQ = 15.8k
0.0 3,230.0
9/4/2022
07:30
9/4/2022
08:30
1.00 INTRM1, CASING CIRC P Stage up pumps to 6BPM. CBU.
6 BPM
174 PSI
20 RPM
5k TQ
155k PU
153k SO
3,230.0 3,230.0
9/4/2022
08:30
9/4/2022
12:00
3.50 INTRM1, CASING PUTB P RIH w/ 9 5/8" 47# T95 H563 casing f/
3230' to 5081'. Filling pipe every 10jts.
9 4/8" 47# T95 H563 MU TQ = 15.8k
3,230.0 5,081.0
9/4/2022
12:00
9/4/2022
13:30
1.50 INTRM1, CASING CIRC P Stage up pumps to 6BPM. CBU.
6 BPM
174 PSI
20 RPM
5k TQ
155k PU
153k SO
5,081.0 5,081.0
9/4/2022
13:30
9/4/2022
16:00
2.50 INTRM1, CASING PUTB P RIH w/ 9 5/8" 47# T95 H563/43.50# L80
H563 casing f/ 5081' to 7015'. Filling
pipe every 10jts.
9 4/8" 47# T95 H563 MU TQ = 15.8k
9 5/8" 43.5# L80 H563 MU TQ = 14.3k
5,081.0 7,015.0
9/4/2022
16:00
9/4/2022
18:00
2.00 INTRM1, CASING CIRC P Stage up pumps to 6BPM. CBU.
6 BPM
174 PSI
20 RPM
5k TQ
155k PU
153k SO
7,000.0 7,000.0
9/4/2022
18:00
9/4/2022
19:30
1.50 INTRM1, CASING PUTB P RIH w/ 9 5/8" 43.50# L80 casing f/ 7000'
to 8140'. Filliing pipe every 10jts.
7,000.0 8,140.0
9/4/2022
19:30
9/4/2022
22:00
2.50 INTRM1, CASING CIRC P Set down 25-35k. PU and MU CRT.
Wash down from 8140' to 8440'
3 BPM
430 PSI
220-235k SO
8,140.0 8,440.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 9/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/4/2022
22:00
9/4/2022
23:00
1.00 INTRM1, CASING PUTB P MU hanger and landing joint. Wash
down @ 3 BPM. Land hanger.
FS @ 8483.90'
FC @ 8391.85'
8,440.0 8,484.0
9/4/2022
23:00
9/5/2022
00:00
1.00 INTRM1, CEMENT CIRC P Stage up pumps to 6 BPM.
6 BPM
480 PSI
250 PSI FCP
8,484.0 8,484.0
9/5/2022
00:00
9/5/2022
01:30
1.50 INTRM1, CEMENT CIRC P Circulate and condition mud f/ cement
job.PJSM
6 BPM
480 PSI
250 PSI FCP
8,484.0 8,484.0
9/5/2022
01:30
9/5/2022
05:30
4.00 INTRM1, CEMENT CMNT P Line up cement unit. flush w/ 3 bbls FW.
Test lines to 4500psi. Good test. Mix
and pump 60bbls 12.5ppg mud push II
at 4 bpm. SD and drop bottom plug. Mix
and pump 74bbls 13 ppg G lead cement
at 4.5 bpm, Mix and pump 152bbls 15.8
ppg G Tail cement at 4.5 bpm. SD and
drop top plug. Pump 20 bbls FW w/
cement. Swap over to rig pumps and
Displace cement at 6bpm10psi 500bbls
slow rate to 5bpm 1060psi slow rate to
3bpm 1068psi. Plug bumped @ 5086
stks (calculated stks5163). Pressure up
to 1600psi. Check floats. Good. Cement
in place @ 05:05hrs 9/5/22
8,484.0 8,484.0
9/5/2022
05:30
9/5/2022
06:30
1.00 INTRM1, CEMENT PRTS P Test casing to 3500psi f/ 30
minutes.Good test. 9.3bbls pumped. 9.3
bbls returned
8,484.0 8,484.0
9/5/2022
06:30
9/5/2022
07:30
1.00 INTRM1, CEMENT RURD P Blow down lines. RD casing handling
equipment.
8,484.0 0.0
9/5/2022
07:30
9/5/2022
09:30
2.00 INTRM1, WHDBOP PRTS P Drain stack. MU/set/ test packoff.
5000psi f/ 10 min. COP witness. Good
test.
0.0 0.0
9/5/2022
09:30
9/5/2022
15:00
5.50 INTRM1, WHDBOP BOPE P Swap out UPRs 9 5/8" to 4 1/2" x 7"
VBR. Test w/ 5" and 7" test joint.
250/3500psi f/ 5/10min each.
SimOps: Cleaning pits and staging BHA.
0.0 0.0
9/5/2022
15:00
9/5/2022
16:00
1.00 INTRM1, WHDBOP RURD P Retrieve test plug and install 8.75" wear
bushing.
0.0 0.0
9/5/2022
16:00
9/5/2022
19:00
3.00 INTRM1, DRILLOUT BHAH P PJSM. PU and RIH w/ BHA to 547'. 0.0 547.0
9/5/2022
19:00
9/5/2022
20:30
1.50 INTRM1, DRILLOUT TRIP P TIH w/ BHA #4 f/ 547' to 2900'. 547.0 2,900.0
9/5/2022
20:30
9/5/2022
21:00
0.50 INTRM1, DRILLOUT CIRC P Perform shallow test. Good.
570 GPM
1950 PSI
2,900.0 2,900.0
9/5/2022
21:00
9/6/2022
00:00
3.00 INTRM1, DRILLOUT TRIP P RIH w/ BHA #4 f/ 2900' to 8004' 2,900.0 8,004.0
9/6/2022
00:00
9/6/2022
00:30
0.50 INTRM1, DRILLOUT TRIP P TIH f/ 8004 to 8184' 8,004.0 8,184.0
9/6/2022
00:30
9/6/2022
03:00
2.50 INTRM1, DRILLOUT SLPC P Slip/cut drill line. 87 ft. Calibrate blocks
and reset crown saver.
8,184.0 8,184.0
9/6/2022
03:00
9/6/2022
03:30
0.50 INTRM1, DRILLOUT SVRG P Service TD and change out teflon
guides
8,184.0 8,184.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 10/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/6/2022
03:30
9/6/2022
04:30
1.00 INTRM1, DRILLOUT CIRC P Wash down to 8363'. Set down 5k.
Wash/ream to 8389' Set down 10k.
600 GPM
3600 PSI
8,184.0 8,389.0
9/6/2022
04:30
9/6/2022
09:00
4.50 INTRM1, DRILLOUT DRLG P Drill plugs/FC and shoetrack. Clean out
rathole and drill 20' new formation to
8514'.
600 GPM
3250 PSI
5k WOB
30 RPM
7k TQ
8,389.0 8,514.0
9/6/2022
09:00
9/6/2022
09:30
0.50 INTRM1, DRILLOUT CIRC P Circulate hole while BROOH to 8469'
600 GPM
3180 PSI
5k WOB
80 RPM
8k TQ
8,514.0 8,469.0
9/6/2022
09:30
9/6/2022
10:30
1.00 INTRM1, DRILLOUT FIT P Perform FIT to 14.oppg EMW. 2.5bbbls
pumped 2.5bbl returned.
960psi + 11.5ppg current MW.
8,469.0 8,469.0
9/6/2022
10:30
9/6/2022
11:30
1.00 INTRM1, DRILLOUT MPDA P Retrieve trip nipple and install MPD
bearing assembly.
8,469.0 8,469.0
9/6/2022
11:30
9/6/2022
12:00
0.50 INTRM2, DRILL CIRC P Wash/ream 8469' to 8514'. 8,469.0 8,514.0
9/6/2022
12:00
9/6/2022
15:00
3.00 INTRM2, DRILL DDRL P Drill 8 1/2" x 9 7/8" hole f/ 8514' to
8599'.
630 GPM
3735 PSI
100 RPM
9-16k TQ On bttm
8K TQ Off bttm
13.0ppg ECD
210k PU
178k SO
184k ROT
8,514.0 8,599.0
9/6/2022
15:00
9/6/2022
16:30
1.50 INTRM2, DRILL CIRC P Record parameters and drop 1.25"
activation ball for reamer. Pump down
@ 250 900 PSI. Observed shear. check
parameters and perform ledge test
(good).
8,599.0 8,599.0
9/6/2022
16:30
9/6/2022
18:00
1.50 INTRM2, DRILL DDRL P Drill 8 1/2" x 9 7/8" hole f/ 8599' MD to
8677' MD / 7582' TVD.
630 GPM
3250 PSI
140 RPM
12k TQ On bttm
8K TQ Off bttm
13.0ppg ECD
540 PSI MPD on connections.
210k PU
178k SO
184k ROT
3.8 Bit hrs.
58.1 Jar hrs.
8,599.0 8,677.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 11/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/6/2022
18:00
9/7/2022
00:00
6.00 INTRM2, DRILL DDRL P Drill 8 1/2" x 9 7/8" hole f/ 8677' MD to
9126' MD / 7900' TVD.
630 GPM
3285 PSI
140 RPM
16k TQ On bttm
10K TQ Off bttm
13.1ppg ECD
620 PSI MPD on connections.
210k PU
178k SO
184k ROT
8.7 Bit hrs.
63.0 Jar hrs.
8,677.0 9,126.0
9/7/2022
00:00
9/7/2022
01:30
1.50 INTRM2, DRILL DDRL P Drill 8 1/2" x 9 7/8" hole f/ 9126' MD to
9243' MD.
630 GPM
3285 PSI
140 RPM
16k TQ On bttm
10K TQ Off bttm
13.1ppg ECD
620 PSI MPD on connections.
210k PU
178k SO
184k ROT
8.7 Bit hrs.
63.0 Jar hrs.
9,126.0 9,243.0
9/7/2022
01:30
9/7/2022
02:30
1.00 INTRM2, DRILL CIRC T Observed leak on MP #1 @ pulsation
dampener. Circulate on MP # 2 and
troubelshoot.
9,243.0 9,243.0
9/7/2022
02:30
9/7/2022
13:30
11.00 INTRM2, DRILL DDRL P Drill 8 1/2" x 9 7/8" hole f/ 9243' MD to
10043'' MD / 8316' TVD. Section TD.
630 GPM
3310 PSI
165 RPM
16k TQ On bttm
10K TQ Off bttm
13.0ppg ECD
620 PSI MPD on connections.
165k ROT
17.3 Bit hrs.
71.6 Jar hrs.
9,243.0 10,043.0
9/7/2022
13:30
9/7/2022
15:00
1.50 INTRM2, TRIPCAS CIRC P Take parameters. Drop 1.625" closing
ball f/ underreamer. Verify closed.
10,043.0 10,043.0
9/7/2022
15:00
9/7/2022
22:30
7.50 INTRM2, TRIPCAS BKRM P BROOH f/ 10035' to 8490'
630 GPM
3480 PSI
125 RPM
9.5 TQ
10,043.0 8,490.0
9/7/2022
22:30
9/8/2022
00:00
1.50 INTRM2, TRIPCAS CIRC P Circulate and BROOH at 1 BU/std f/ 3
stds f/ 8490' to 8280'
630 GPM
3000 PSI
60 RPM
7k TQ
12.9ppg ECD
8,490.0 8,280.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 12/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/8/2022
00:00
9/8/2022
01:15
1.25 INTRM2, TRIPCAS CIRC P Circulate and BROOH at 1 BU/std f/ 3
stds f/ 8490' to 8280'.
630 GPM
3000 PSI
60 RPM
7k TQ
12.9ppg ECD
8,280.0 8,280.0
9/8/2022
01:15
9/8/2022
02:30
1.25 INTRM2, TRIPCAS CIRC P CBU @ 8280' while prep to displace to
13.2ppg OBM. Observed losses @
60bbls/hr. Slow rates and drop ECD to
12.1ppg. Losses decreased to
45bbls/hr. Discuss w/ town and decision
made to SOOH holding 12.0 to 12.1ppg
EMW w/ MPD.to 2700' and displace to
13.2ppg OBM to have 12.1ppg EMW at
shoe.Flow check static.
8,280.0 8,280.0
9/8/2022
02:30
9/8/2022
09:30
7.00 INTRM2, TRIPCAS SMPD P SOOH f/ 8280' to 2525' as per MPD
schedule f/ a 12.1ppg EMW. Adjust as
needed for losses. Losing 60-75bbls/hr
at beginning and dropped to no losses.
8,280.0 2,525.0
9/8/2022
09:30
9/8/2022
10:30
1.00 INTRM2, TRIPCAS CIRC P Displace to 13.2ppg OBM f/ 2525' to
surface. No losses
350 GPM
850 PSI
25 RPM
3k TQ
2,525.0 2,525.0
9/8/2022
10:30
9/8/2022
12:30
2.00 INTRM2, TRIPCAS SMPD P SOOH f/ 2525' to 735'. 2,525.0 735.0
9/8/2022
12:30
9/8/2022
14:00
1.50 INTRM2, TRIPCAS CIRC T Circulate across top of well maintaining
160 psi w/ MPD. while waiting on
delayed flight w/ service hands due to
weather.
SimOps: Service rig. Stage BHA tools
735.0 735.0
9/8/2022
14:00
9/8/2022
15:00
1.00 INTRM2, TRIPCAS MPDA P Retrieve MPD bearing assembly. Install
trip nipple.
735.0 735.0
9/8/2022
15:00
9/8/2022
18:00
3.00 INTRM2, TRIPCAS BHAH P LD BHA as per DD. 735.0 0.0
9/8/2022
18:00
9/8/2022
18:30
0.50 INTRM2, CASING CLEN P Clean/clear rig floor. Stage liner running
tools.
0.0 0.0
9/8/2022
18:30
9/8/2022
20:30
2.00 INTRM2, CASING RURD P RU liner running equipement. PU
cement head and MU pup joint. Lay
back down. PJSM.
0.0 0.0
9/8/2022
20:30
9/9/2022
00:00
3.50 INTRM2, CASING PUTB P MU FS/Shoetrack. Bakerlock
connections. Check floats. OK., RIH w/
7" 29# TN110 H563 Liner to 1727' Top
filling every 10 jts.
0.0 1,727.0
9/9/2022
00:00
9/9/2022
00:30
0.50 INTRM2, CASING PUTB P Change out elevators to 5" and P/U
Baker hanger assy. Fill with Zan Plex.
Install PS21 slips. RIH w/ 1 std of 5"
DP.to 1821'.
PU 80k
SO 84k.
SIMOPS: R/D casing running equipment
1,727.0 1,821.0
9/9/2022
00:30
9/9/2022
02:00
1.50 INTRM2, CASING MPDA P Flow Check. Retrieve trip nipple and
install MPD bearing assembly.
1,821.0 1,821.0
9/9/2022
02:00
9/9/2022
02:30
0.50 INTRM2, CASING RUNL P RIH w/ liner on 5" DP to 2575'. 1,821.0 2,575.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 13/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/9/2022
02:30
9/9/2022
03:30
1.00 INTRM2, CASING CIRC P Displace 13.2ppg OBM mud cap w/
11.5ppg OBM. Stage up rates to 250
GPM 275 PSI. No losses.
Observed 13.0ppg out at beginning and
fell to 12.2ppg before spacer returned.
2,575.0 2,575.0
9/9/2022
03:30
9/9/2022
09:00
5.50 INTRM2, CASING SMPD P SIH w/ liner on 5" DP f/ 2575' to 8422'
as per MPD schedule. Filling Pipe
every 10 Stds.
2,575.0 8,422.0
9/9/2022
09:00
9/9/2022
10:30
1.50 INTRM2, CASING CIRC P Circulate BU at shoe. Stage up to 250
GPM/540 PSI. No losses.
PU 206k
SO 162k
ROT 179k
8K TQ @ 15 RPM
7k TQ @ 20 RPM
8,422.0 8,422.0
9/9/2022
10:30
9/9/2022
12:00
1.50 INTRM2, CASING SMPD P SIH w/ liner on 5" DP f/ 8422' to 10038'
as per MPD schedule. Filling Pipe
every 10 Stds. Set down 5k @ 10038'.
8,422.0 10,038.0
9/9/2022
12:00
9/9/2022
12:30
0.50 INTRM2, CASING RURD P Rack back tag std. MU cement head.
Liner on depth.
FS @ 10028'
TOL @ 8300'
10,038.0 10,028.0
9/9/2022
12:30
9/9/2022
15:00
2.50 INTRM2, CEMENT CIRC P Stage pumps to 250 GPM/ 660 PSI.
Circulate annd condition mud f/ cement
job.
SimOps: Stage trucks and RU
cementers.
10,028.0 10,028.0
9/9/2022
15:00
9/9/2022
17:00
2.00 INTRM2, CEMENT CMNT P Pump 3 bbls FW w/ cement unit. Test
lines to 4200psi. Pump 70bbls KCL. SD
and drop bottom dart. Mix and pump 64
bbls of 15.8 ppg cement. Drop top dart.
Pump 20bbls FW w/ cement unit. Swap
over to rig and displace @ 5-6 bpm.
Plug down and cement in place (5.8bbls
early) @ 16:42hrs 9/9/22. FCP 360psi/
870psi Held f/ 5 minutes and check
floats. Floats held. 0.75bbls returned.
No Loss to formation
TOL at 8,300' MD/ Shoe at 10,028' MD.
10,028.0 10,028.0
9/9/2022
17:00
9/9/2022
18:00
1.00 INTRM2, CEMENT PRTS P Set liner hanger and packer as per
Baker. Preeure test to 1000psi. Charted
and witnessed by COP DSV.
10,028.0 10,028.0
9/9/2022
18:00
9/9/2022
18:30
0.50 INTRM2, CEMENT RURD P RD cement head and LD same. 10,028.0 10,028.0
9/9/2022
18:30
9/9/2022
20:00
1.50 INTRM2, CEMENT CIRC P PU out of liner top and circulate wiper
ball through DP. CBU. SOOH f/ 8320' to
8236'
330 GPM
570 PSI
10,028.0 8,236.0
9/9/2022
20:00
9/9/2022
21:30
1.50 INTRM2, CEMENT RURD P RU test equipment. Test 7" liner to
3500psi f/ 30 minutes. good test. RD
test equipment.
9.5bbls pumped
9bbls returned
8,236.0 8,236.0
9/9/2022
21:30
9/9/2022
23:00
1.50 INTRM2, CEMENT MPDA P Retrieve MPD bearing assembly and
install trip nipple.
8,236.0 8,236.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 14/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/9/2022
23:00
9/10/2022
00:00
1.00 INTRM2, CEMENT TRIP P Pump slug and TOOH f/ 8236' to 5160'. 8,236.0 5,160.0
9/10/2022
00:00
9/10/2022
01:30
1.50 INTRM2, CEMENT TRIP P POOH f/ 5160' to 1425'. 5,160.0 1,425.0
9/10/2022
01:30
9/10/2022
03:00
1.50 INTRM2, CEMENT PULD P LD excess 5" DP. 14 Stds. 1,425.0 0.0
9/10/2022
03:00
9/10/2022
04:00
1.00 INTRM2, CEMENT PULD P LD running tool. 0.0 0.0
9/10/2022
04:00
9/10/2022
04:30
0.50 INTRM2, CEMENT BOPE P Close Blind/Shear rams, change UPR
from 4-1/2" x 7" to 2-7/8" x 5-1/2",
0.0 0.0
9/10/2022
04:30
9/10/2022
10:30
6.00 INTRM2, CEMENT PULD P CO handling equipment.PU and rack
back 4" DP. (30 Stds)
0.0 0.0
9/10/2022
10:30
9/10/2022
12:00
1.50 INTRM2, WHDBOP OTHR P CO handling equipment. MU jetting tool.
Jet stack. Drain stack and retrieve wear
bushing.
0.0 0.0
9/10/2022
12:00
9/10/2022
13:00
1.00 INTRM2, WHDBOP BOPE P Fill stack. RU test equipment. 0.0 0.0
9/10/2022
13:00
9/10/2022
19:00
6.00 INTRM2, WHDBOP BOPE P BOPE Test All tests to 250psi/5min
3500psi/10min Annular 250psi/5min
3500psi/10min w/ exception of manual
and super choke t/ 2000 psi. 5” Test jt:
test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5
1/2" LPR, W/ 4" Test jt: test annular/2
7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR,Test
choke valves 1-15. Manula operated
and super choke. Choke manuals and
HCR valves. 4" kill line valve. Test 2x 4"
FO safety valves. 4" dart valve. 2x 5"
FO safety valves. 5" dart valve. Test
upper and lower IBOP. Blind/Shear
rams.
Performed Koomey draw down, ACC =
3000 psi, Manifold = 1500 psi, ACC =
1800 psi after all functions on bottles,12
sec for 200 psi. Build w/ 2 electric
pumps, 77 sec to build full system
pressure w/ 2 electrical and 2 air pumps,
closing times annular = 23 sec. UPR =
18 sec, Blind / Shears = 16 sec, LPR =
16 sec, choke HCR = 2 sec, Kill HCR =
2 sec. Test PVT gain/loss and flow out
alarms. Test LEL and H2S alarms
AOGCC waived witness.
0.0 0.0
9/10/2022
19:00
9/10/2022
20:00
1.00 INTRM2, WHDBOP BOPE P RD test equipment. Retrieve test plug.
Install 8.75" wear bushing.
0.0 0.0
9/10/2022
20:00
9/10/2022
22:00
2.00 INTRM2, DRILLOUT BHAH P Stage BHA components to rig floor. Prep
BHA components in pipeshed.
Note: Primary tools arrived @ 20:30hrs.
0.0 0.0
9/10/2022
22:00
9/11/2022
00:00
2.00 INTRM2, DRILLOUT BHAH P PU BHA #5 and RIH to 82'. 0.0 82.0
9/11/2022
00:00
9/11/2022
03:00
3.00 INTRM2, DRILLOUT BHAH P PU and RIH w/ BHA #5 to 240'
Note: Programmed tools on rig floor due
to late arrival.
Sonic tool programmed to turn on
@04:00hrs.
82.0 240.0
9/11/2022
03:00
9/11/2022
04:30
1.50 INTRM2, DRILLOUT TRIP P RIH w/ BHA #5 w/ 4" DP f/ 240' to 3076'. 240.0 3,076.0
9/11/2022
04:30
9/11/2022
05:00
0.50 INTRM2, DRILLOUT DHEQ P Fill pipe. Perform Shallow hole test. 3,076.0 3,076.0
9/11/2022
05:00
9/11/2022
15:00
10.00 INTRM2, DRILLOUT DLOG P Single in hole w/ 5" DP f/ 3076' to 9703'
at 1800ft/hr f/ logging.
3,076.0 9,703.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 15/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/11/2022
15:00
9/11/2022
16:30
1.50 INTRM2, DRILLOUT WASH P Wash down and tag TOC @ 9840'.
215 GPM
2115 PSI
35 RPM
8k TQ
10k WOB
9,703.0 9,943.0
9/11/2022
16:30
9/11/2022
23:00
6.50 INTRM2, DRILLOUT DRLG P Drillout cement/plugset/Landing
collar/shoetrack f/ 9840' to 10020'
Cement- 1hr
Landing collar- 3hrs
shoetrack-
215 GPM
2115 PSI
35 RPM
8k TQ
10k WOB
9,943.0 10,020.0
9/11/2022
23:00
9/12/2022
00:00
1.00 INTRM2, DRILLOUT CIRC P LD Single of DP to be able to work full
stand while displacing. CBU and prep to
displace to 8.8ppg FloPro.
10,020.0 10,020.0
9/12/2022
00:00
9/12/2022
03:00
3.00 INTRM2, DRILLOUT DISP P Displace hole to 8.8ppg FloPro
40bbls LVT
110bbls 13.5ppg Transition spacer
80bbls cleaning spacer
50bbls HiVis spacer
8.8ppg FloPro
10,020.0 10,020.0
9/12/2022
03:00
9/12/2022
04:30
1.50 INTRM2, DRILLOUT CLEN P Clean pits/shakers after displacement.
SimOps: Install 4" MPD bearing
assembly.
10,020.0 10,020.0
9/12/2022
04:30
9/12/2022
06:00
1.50 INTRM2, DRILLOUT SLPC P Cut/Slip drill line. (71'). Calibrate
Amphion and Pason.
10,020.0 10,020.0
9/12/2022
06:00
9/12/2022
06:30
0.50 INTRM2, DRILLOUT MPDA P Break in MPD bearing. 10,020.0 10,020.0
9/12/2022
06:30
9/12/2022
08:30
2.00 INTRM2, DRILLOUT DRLG P Wash down and drill out shoetrack and
FS. Clean out RH and drill new
formation f/ 10043' to 10063'.
10k WOB
253 GPM
1280 PSI
50 RPM
5k TQ
9.2ppg ECD
10,020.0 10,063.0
9/12/2022
08:30
9/12/2022
10:00
1.50 INTRM2, DRILLOUT CIRC P BROOH to inside shoe. Circulate and
condition mud f/ FIT test.
10,063.0 10,063.0
9/12/2022
10:00
9/12/2022
10:30
0.50 INTRM2, DRILLOUT FIT P Perform FIT to 12.0ppg EMW.
current MW 8.8ppg + 1383psi surface
pressure.
10,063.0 10,063.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 16/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/12/2022
10:30
9/12/2022
18:00
7.50 PROD1, DRILL DDRL P Driil 6 1/8" production hole f/ 10063' to
10750' MD/ 8424' TVD. Controlled
Drilled until drill n ream out of shoe.
11k WOB
313 GPM
1910 PSI on bttm
1870 PSI off bttm
120 RPM
7.5k TQ on bttm
4k TQ off bttm
8.8ppg Current MW
9.5ppg ECD
175k PU
140k SO
150k ROT
0psi MPD on connection
6.2 bit hrs.
10,063.0 10,754.0
9/12/2022
18:00
9/13/2022
00:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" production hole f/ 10750' to
11446' MD/ 8437' TVD.
12k WOB
315 GPM
2110 PSI on bttm
2000 PSI off bttm
130 RPM
7.5k TQ on bttm
5k TQ off bttm
8.8ppg Current MW
9.7ppg ECD
175k PU
140k SO
150k ROT
0psi MPD on connection
10.7 bit hrs.
10,754.0 11,446.0
9/13/2022
00:00
9/13/2022
06:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" production hole f/ 11446' to
12129' MD/ 8337' TVD.
16k WOB
315 GPM
2290 PSI on bttm
2270 PSI off bttm
130 RPM
7.5k TQ on bttm
5k TQ off bttm
8.9ppg Current MW
9.9ppg ECD
179k PU
135k SO
158k ROT
0psi MPD on connection
15.2 bit hrs.
11,446.0 12,129.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 17/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/13/2022
06:00
9/13/2022
12:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" production hole f/ 12129' MD
to 12846' MD/ 8473' TVD.
12k WOB
300 GPM
2300 PSI on bttm
2290 PSI off bttm
130 RPM
10k TQ on bttm
6k TQ off bttm
8.9ppg Current MW
10.1ppg ECD
182k PU
131k SO
144k ROT
0psi MPD on connection
19.5 bit hrs.
12,129.0 12,846.0
9/13/2022
12:00
9/13/2022
18:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" production hole f/ 12846' MD
to 13699' MD/ 8470' TVD.
12k WOB
280 GPM
2230 PSI on bttm
2150 PSI off bttm
130 RPM
11k TQ on bttm
6.5k TQ off bttm
9.0ppg Current MW
10.2ppg ECD
182k PU
130k SO
145k ROT
0psi MPD on connection
24.5 bit hrs.
12,846.0 13,699.0
9/13/2022
18:00
9/14/2022
00:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" production hole f/ 13699' MD
to 14522' MD/ 8466' TVD.
10k WOB
280 GPM
2350 PSI on bttm
2320 PSI off bttm
130 RPM
10.5k TQ on bttm
7k TQ off bttm
9.1ppg Current MW
10.3ppg ECD
183k PU
130k SO
146k ROT
0psi MPD on connection
29.1 bit hrs.
13,699.0 14,522.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 18/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/14/2022
00:00
9/14/2022
06:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" x 6 3/16" production hole
From 14,522' MD to 15,312' MD 8,464'
TVD.
17k WOB
300 GPM
2450 PSI on bttm
2410 PSI off bttm
130 RPM
10k TQ on bttm
6k TQ off bttm
8.9ppg Current MW
10.2ppg ECD
180k PU
126k SO
153k ROT
0psi MPD on connection
4.6 ADT
33.7 bit hrs.
Note: Perform 500bbl dump and dilute
@ 14,600' @ 00:30hrs
14,522.0 15,312.0
9/14/2022
06:00
9/14/2022
11:30
5.50 PROD1, DRILL DDRL P Driil 6 1/8" x 6 3/16" production hole
From 15,312' MD to 15,929' MD 8,453'
TVD.
17k WOB
300 GPM
2500 PSI on bttm
130 RPM
11k TQ on bttm
9.1ppg Current MW
10.2ppg ECD
183k PU
130k SO
155k ROT
0psi MPD on connection
3.6 ADT
37.3 bit hrs.
15,312.0 15,929.0
9/14/2022
11:30
9/14/2022
12:30
1.00 PROD1, DRILL MPDA P OWFF (Static) Pull 4" RCD and install 5"
RCD
15,929.0 15,929.0
9/14/2022
12:30
9/14/2022
18:00
5.50 PROD1, DRILL DDRL P Driil 6 1/8" x 6 3/16" production hole
From 15,929' MD to 16,650' MD 8,442'
TVD.
12k WOB
300 GPM
2580 PSI on bttm
2550 PSI off bttm
130 RPM
12k TQ on bttm
6k TQ off bttm
8.9ppg Current MW
10.1ppg ECD
180k PU
130k SO
150k ROT
70psi MPD on connection
4.2 ADT
41.5 bit hrs.
15,929.0 16,650.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 19/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/14/2022
18:00
9/15/2022
00:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" x 6 3/16" production hole
From 16,650' MD to 17,469' MD 8,464'
TVD.
10k WOB
300 GPM
2670 PSI on bttm
2630 PSI off bttm
130 RPM
12k TQ on bttm
7k TQ off bttm
9.0ppg Current MW
10.4ppg ECD
185k PU
126k SO
157k ROT
65psi MPD on connection
4.9 ADT
46.4 bit hrs.
16,650.0 17,469.0
9/15/2022
00:00
9/15/2022
06:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" x 6 3/16" production hole
From 17,469' MD to 18,245' MD 8,483'
TVD
16k WOB
300 GPM
2660 PSI on bttm
2670 PSI off bttm
130 RPM
11k TQ on bttm
7k TQ off bttm
9.0ppg Current MW
10.2ppg ECD
195k PU
135k SO
168k ROT
125psi MPD on connection
4.7 ADT
51.1 bit hrs.
17,469.0 18,245.0
9/15/2022
06:00
9/15/2022
12:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" x 6 3/16" production hole
From 18,245' MD to 18,995' MD 8,477'
TVD
16k WOB
300 GPM
2560 PSI on bttm
2570 PSI off bttm
130 RPM
19k TQ on bttm
14k TQ off bttm
8.9ppg Current MW
10.3ppg ECD
205k PU
135k SO
170k ROT
190psi MPD on connection
4.4 ADT
55.5 bit hrs.
18,245.0 18,995.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 20/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/15/2022
12:00
9/15/2022
18:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" x 6 3/16" production hole
From 18,995' MD to 19,822' MD 8,457'
TVD
11k WOB
300 GPM
2730 PSI on bttm
2630 PSI off bttm
130 RPM
13k TQ on bttm
8k TQ off bttm
8.9ppg Current MW
10.4ppg ECD
218k PU
134k SO
170k ROT
145psi MPD on connection
4.9 ADT
60.4 bit hrs.
18,995.0 19,822.0
9/15/2022
18:00
9/16/2022
00:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" x 6 3/16" production hole
From 19,822' MD to 20,495' MD 8,441'
TVD
8k WOB
300 GPM
2810 PSI on bttm
2670 PSI off bttm
130 RPM
14k TQ on bttm
9k TQ off bttm
9ppg Current MW
10.7ppg ECD
201k PU
135k SO
177k ROT
220psi MPD on connection
5.0 ADT
65.4 bit hrs.
19,822.0 20,495.0
9/16/2022
00:00
9/16/2022
06:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" x 6 3/16" production hole
From 20,495' MD to 21,165' MD 8,458'
TVD
15k WOB
300 GPM
2650 PSI on bttm
2700 PSI off bttm
130 RPM
13k TQ on bttm
9k TQ off bttm
8.9ppg Current MW
10.6ppg ECD
225k PU
126k SO
182k ROT
220psi MPD on connection
5.0 ADT
70.4 bit hrs.
20,495.0 21,165.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 21/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/16/2022
06:00
9/16/2022
12:00
6.00 PROD1, DRILL DDRL P Driil 6 1/8" x 6 3/16" production hole
From 21,165' MD to 21,825' MD 8,468'
TVD
17k WOB
300 GPM
2820 PSI on bttm
2800 PSI off bttm
130 RPM
19k TQ on bttm
9k TQ off bttm
9.0ppg Current MW
10.8ppg ECD
230k PU
123k SO
181k ROT
100psi MPD on connection
4.1 ADT
74.5 bit hrs.
21,165.0 21,825.0
9/16/2022
12:00
9/16/2022
13:30
1.50 PROD1, DRILL DDRL P Driil 6 1/8" x 6 3/16" production hole
From 21,825' MD to 22,013' MD 8,452'
TVD
10k WOB
300 GPM
2925 PSI on bttm
2900 PSI off bttm
130 RPM
15k TQ on bttm
10k TQ off bttm
9.1ppg Current MW
10.9ppg ECD
234k PU
121k SO
178k ROT
93psi MPD on connection
1.3 ADT
75.8 bit hrs.
21,825.0 22,013.0
9/16/2022
13:30
9/16/2022
15:30
2.00 PROD1, TRIPCAS CIRC P Final survey and circulate btms up at
22,013' MD
300 GPM
2925 PSI on bttm
150 RPM
11k TQ off bttm
10.6ppg ECD
22,013.0 22,013.0
9/16/2022
15:30
9/16/2022
17:00
1.50 PROD1, TRIPCAS OWFF P OWFF, Fingerprint Initial 84psi and final
64 psi. EMW 9.5ppg with safety margin.
Pore Pressure 9.29ppge
22,013.0 21,917.0
9/16/2022
17:00
9/16/2022
22:30
5.50 PROD1, TRIPCAS CIRC P Circulate clean up cycles at 21,917' MD
350 GPM
3433 PSI on bttm
120/150 RPM
10k TQ off bttm
10.6ppg ECD
21,917.0 21,917.0
9/16/2022
22:30
9/17/2022
00:00
1.50 PROD1, TRIPCAS CIRC P Circulate, pump 95bbls Hi-Vis spacer
and displace to 9.5ppg Vis Brine.
300 GPM
2145 PSI on bttm
150 RPM
1012k TQ off bttm
10.3ppg ECD
21,917.0 21,917.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 22/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/17/2022
00:00
9/17/2022
01:30
1.50 PROD1, TRIPCAS CIRC P Continue and displace to 9.5ppg Vis
Brine.
80bbls interface fluid
13bbls Fluid loss
300 GPM
2145 PSI on bttm
150 RPM
1012k TQ off bttm
10.3ppg ECD
21,917.0 21,917.0
9/17/2022
01:30
9/17/2022
02:30
1.00 PROD1, TRIPCAS OWFF P Obtain SPR's and OWFF (static) 21,917.0 21,917.0
9/17/2022
02:30
9/17/2022
06:00
3.50 PROD1, TRIPCAS SMPD P SOOH from 21,917' MD to 18,500' MD 21,917.0 18,500.0
9/17/2022
06:00
9/17/2022
08:30
2.50 PROD1, TRIPCAS SMPD P SOOH from 18,500' MD to 15,912' MD 18,500.0 15,912.0
9/17/2022
08:30
9/17/2022
09:00
0.50 PROD1, TRIPCAS OWFF P OWFF (Static) 15,912.0 15,912.0
9/17/2022
09:00
9/17/2022
10:00
1.00 PROD1, TRIPCAS MPDA P Pull 5" RCD and install 4" RCD. 15,912.0 15,886.0
9/17/2022
10:00
9/17/2022
12:00
2.00 PROD1, TRIPCAS SMPD P SOOH L/D 4" drill pipe from 15,886' MD
to 15,218' MD
15,886.0 15,218.0
9/17/2022
12:00
9/17/2022
14:00
2.00 PROD1, TRIPCAS SMPD P SOOH L/D 4" drill pipe from 15,218' MD
to 13,986' MD
15,218.0 13,986.0
9/17/2022
14:00
9/17/2022
16:00
2.00 PROD1, TRIPCAS CIRC P Circulate at 13,986' MD
350 GPM
2200 PSI
120 RPM
7k TK
Shakers clean
13,986.0 13,986.0
9/17/2022
16:00
9/17/2022
19:30
3.50 PROD1, TRIPCAS SMPD P SOOH L/D 4" drill pipe from 13,986' MD
to 12,151' MD
13,986.0 12,151.0
9/17/2022
19:30
9/17/2022
20:30
1.00 PROD1, TRIPCAS CIRC P Circulate at 12,151' MD
350 GPM
2050 PSI
120 RPM
7k TK
Shakers clean
12,151.0 12,151.0
9/17/2022
20:30
9/18/2022
00:00
3.50 PROD1, TRIPCAS SMPD P SOOH L/D 4" drill pipe from 12,151' MD
to 10,255' MD
Using manuel tongs to break 4" DP
connections (Break out 35/40k)
12,151.0 10,255.0
9/18/2022
00:00
9/18/2022
00:30
0.50 PROD1, TRIPCAS SMPD P SOOH L/D 4" drill pipe from 12,151' MD
to 10,002' MD.
Using manuel tongs to break 4" DP
connections (Break out 35/40k)
10,255.0 10,002.0
9/18/2022
00:30
9/18/2022
01:00
0.50 PROD1, TRIPCAS CIRC P Circulate at 10,002' MD.
350 GPM
1929 PSI
Shakers clean
10,002.0 10,002.0
9/18/2022
01:00
9/18/2022
01:15
0.25 PROD1, TRIPCAS OWFF P OWFF (Static) 10,002.0 10,002.0
9/18/2022
01:15
9/18/2022
03:30
2.25 PROD1, TRIPCAS SMPD P SOOH L/D 4" drill pipe from 10,002' MD
to 8,300' MD.
10,002.0 8,367.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 23/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/18/2022
03:30
9/18/2022
06:00
2.50 PROD1, TRIPCAS CIRC P Circulate at 8,367' MD to 8,294' MD
350 GPM
1930 PSI
30 RPM
3k TQ
8,367.0 8,294.0
9/18/2022
06:00
9/18/2022
07:30
1.50 PROD1, TRIPCAS MPDA P OWFF (static) Blow down top drive, Pull
4" RCD (strip off joint) and install trip
nipple.
8,294.0 8,294.0
9/18/2022
07:30
9/18/2022
08:30
1.00 PROD1, TRIPCAS TRIP P Drop 2.125" hallow drift and POOH from
8294' MD to 6,496' MD rack back 18
stands 4" drill pipe.
8,294.0 6,496.0
9/18/2022
08:30
9/18/2022
13:00
4.50 PROD1, TRIPCAS PULD P POOH L/D 4" drill pipe from 6,496' MD
to 2,923' MD.
6,496.0 2,923.0
9/18/2022
13:00
9/18/2022
13:30
0.50 PROD1, TRIPCAS SVRG P Service PS-21 slips and ST-80 2,923.0 2,923.0
9/18/2022
13:30
9/18/2022
18:00
4.50 PROD1, TRIPCAS PULD P POOH L/D 4" drill pipe from 2,923' MD
to 236' MD.
Culled 41 joints 4" drill pipe.
Culled 3 joints 4" HWT drill pipe.
2,923.0 236.0
9/18/2022
18:00
9/18/2022
19:00
1.00 PROD1, TRIPCAS OWFF P OWFF (Static)
SIMOPS: Clean and clear rig floor, Load
Centrilizers on rig floor, PJSM L/D BHA.
236.0 236.0
9/18/2022
19:00
9/18/2022
21:00
2.00 PROD1, TRIPCAS BHAH P L/D BHA tools and equipment. 236.0 0.0
9/18/2022
21:00
9/18/2022
22:30
1.50 COMPZN, CASING CLEN P Clean and clear rig floor.
SIMOPS: Stage 4.5" liner running
equipment to rig floor.
0.0 0.0
9/18/2022
22:30
9/19/2022
00:00
1.50 COMPZN, CASING SLPC P PJSM, Cut and slip 103' drill line.
Calibrate block hieght and check COM.
0.0 0.0
9/19/2022
00:00
9/19/2022
06:00
6.00 COMPZN, CASING PUTB P PJSM, Rig up and run 4.5" 12,6# L80
H563 liner from surface to 6,113' MD at
(Floating liner)
0.0 6,113.0
9/19/2022
06:00
9/19/2022
09:30
3.50 COMPZN, CASING PUTB P Run 4.5" 12,6# L80 H563 liner from
6,113' MD to 10,212' MD at (Floating
liner)
PU: 84k
SO: 78k
6,113.0 10,212.0
9/19/2022
09:30
9/19/2022
10:00
0.50 COMPZN, CASING PULD P PU and MU 4 1/2" liner hanger and ZXP
packer per Baker. Fill tie back sleeve w/
Zan Plex, RIH from 10,212' MD to
10,254' MD
10,212.0 10,254.0
9/19/2022
10:00
9/19/2022
10:30
0.50 COMPZN, CASING RURD P R/D 4.5" equipment and R/U 4" handling
equipment. RIH from 10,254' MD to
10,349' MD.
PU: 87k
SO: 80k
ROT: 84k
10,254.0 10,349.0
9/19/2022
10:30
9/19/2022
12:00
1.50 COMPZN, CASING RUNL P Run 4.5" 12,6# L80 H563 liner on 4" drill
pipe from 10,349' MD to 11,960' MD.
10,349.0 11,960.0
9/19/2022
12:00
9/19/2022
12:30
0.50 COMPZN, CASING MPDA P Change out handling tools from 4" to 5",
Pull trip nipple and install 5" RCD.
11,960.0 11,960.0
9/19/2022
12:30
9/19/2022
19:30
7.00 COMPZN, CASING RUNL P SIH with 4.5" 12,6# L80 H563 liner on 5"
drill pipe from 11960' MD to 20,115' MD
PU: 228k
SO: 170k
11,960.0 20,115.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 24/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/19/2022
19:30
9/19/2022
23:00
3.50 COMPZN, CASING CIRC P Shear floatation sub with 1,500psi, Fill
and displace liner 154bbls 9.5ppg brine.
Continue circiulate out air at 250gpm
1050psi. Max gas 827units (route to gas
buster) at 6090 stks.
20-25bph losses
20,115.0 20,115.0
9/19/2022
23:00
9/20/2022
00:00
1.00 COMPZN, CASING HOSO P Drop 1.5" Ball, pump down at 160gpm
558psi, slow down pump to 2bpm
227psi (ball on seat 1389stks) Pressure
up to 2000psi, SO on string to 100K
(slips are set)
20,115.0 20,115.0
9/20/2022
00:00
9/20/2022
01:00
1.00 COMPZN, CASING HOSO P Pressure up to 4250psi with rig pump,
bled off and line up rig pump and test
pump, Pressure up to 4200psi with rig
pump and continue pressure up to
5000psi with test pump (No shear
indication) Bled to 0psi P/U expose dog
sub, S/O rotating at 40rpm, witness
shear 30k (PKR set with 70k)
Shoe: 20,115' MD
Liner top: 9,868.17' MD
20,115.0 20,115.0
9/20/2022
01:00
9/20/2022
02:00
1.00 COMPZN, CASING PRTS P Pressure test liner pkr to 3,500psi 30min
(good test)
20,115.0 20,115.0
9/20/2022
02:00
9/20/2022
04:00
2.00 COMPZN, WELLPR DISP P PJSM, displace well 9.5ppg clear brine
at 345gpm 565psi. 39bbls interace.
9,832.0 9,832.0
9/20/2022
04:00
9/20/2022
05:00
1.00 COMPZN, WELLPR OWFF P PJSM, OWFF (Static) Pull 5" RCD and
install trip nipple. Blow down top drive.
9,832.0 9,832.0
9/20/2022
05:00
9/20/2022
12:00
7.00 COMPZN, WELLPR PULD P PJSM, POOH L/D 5" drill pipe from
9,832' MD to 2,324' MD,
9,832.0 2,324.0
9/20/2022
12:00
9/20/2022
15:00
3.00 COMPZN, WELLPR PULD P Continue POOH L/D 5" drill pipe from
2,324' MD to surface. L/D Baker running
tools.
Note: 1/3 of one cup seal missing.
2,324.0 0.0
9/20/2022
15:00
9/20/2022
16:30
1.50 COMPZN, WELLPR WWWH P Pull wear ring and wash stack with
500gpm 85psi 20rpm.
SIMOPS: clean and clear rig floor.
0.0 0.0
9/20/2022
16:30
9/20/2022
18:30
2.00 COMPZN, RPCOMP RURD P PJSM, rig up Halliburton tec wire spool
& spooler, Remove PS-21's, Install
master bushings & cavin air slips, Rig
tec wire clamp tools, Hang tec wire
sheave in derrick.
0.0 0.0
9/20/2022
18:30
9/20/2022
20:15
1.75 COMPZN, RPCOMP RCST P RIH w/ Baker index shoe, mechanical
locator, 3.75" landing nipple, Halliburton
production packer & Halliburton Opsis
Mandrel w/ Down hole gauge (S/N OPS-
001632)
0.0 231.0
9/20/2022
20:15
9/20/2022
20:45
0.50 COMPZN, RPCOMP PRTS P P/U HES downhole gauge assembly &
test to 10,000psi. 10min Good test.
CPAI witness
231.0 231.0
9/20/2022
20:45
9/21/2022
00:00
3.25 COMPZN, RPCOMP RCST P RIH w/ upper completion f/ 231' to
2,523' MD. Runningf TEC line and
installing Cannon clamps every joint.
Checking control line every 1000' MD.
231.0 2,523.0
9/21/2022
00:00
9/21/2022
06:00
6.00 COMPZN, RPCOMP RCST P RIH w/ upper completion from 2,523'
MD to 7,300' MD. Runningf TEC line
and installing Cannon clamps every
joint. Checking control line every 1000'
MD.
2,523.0 7,300.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 25/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/21/2022
06:00
9/21/2022
09:30
3.50 COMPZN, RPCOMP RCST P RIH w/ upper completion from 7,300'
MD to 9,812' MD. Runningf TEC line
and installing Cannon clamps every
joint. Checking control line every 1000'
MD.
PU: 136k
SO: 122k
7,300.0 9,812.0
9/21/2022
09:30
9/21/2022
12:00
2.50 COMPZN, RPCOMP RCST P Observe shear at 9874' slack of to 122K
10K down at 9875' MD confirmed NO
GO. Calculate space out for 2 - 9.72'
pup joints. L/D joint #242, #241 and
#240, install 9.72' and 9.72' pup and
rerun joint #240. Make up FMC hanger
and landing joint , install headpin and
circulating hose.
9,812.0 9,838.0
9/21/2022
12:00
9/21/2022
14:00
2.00 COMPZN, RPCOMP CIRC P Pump 350 BBL's 9.5 inhibited brine from
Vac trucks at 4 BPM from WLEG to
SOV and chase with 150 BBL's 9.5
clear brine to displace to tubing tail.
9,838.0 9,838.0
9/21/2022
14:00
9/21/2022
15:30
1.50 COMPZN, RPCOMP HOSO P Land hanger at 9,873' MD w/ 122k sow
2' from Locater, RILDS and Test FMC
hanger seals t/ 2,500 psi f/ 15 minutes
Test Good
9,838.0 9,873.0
9/21/2022
15:30
9/21/2022
17:30
2.00 COMPZN, RPCOMP OTHR P R/D service lines and XO's on tubing
hanger, Drop 1-5/16'' ball & rod, R/U to
pump on tubing . Ball and rod took
longer time than expected to seat. This
design of ball and rod did't have rollers.
Set HES TNT packer with 3500 PSI for
30 minutes charted.
9,873.0 9,873.0
9/21/2022
17:30
9/21/2022
18:30
1.00 COMPZN, RPCOMP OTHR P Bleed tubing pressure down to 3000 PSI
and hold,Pressure test IA to 3500 PSI
for 30 m minutes charted. bleed tubing
to 0psi and witness SOV shear at
1000psi.
9,873.0 9,873.0
9/21/2022
18:30
9/21/2022
19:30
1.00 COMPZN, RPCOMP PRTS P OWFF, (Static) Continue blow down
circulating lines and L/D 4.5" landing
joint.
9,873.0 9,873.0
9/21/2022
19:30
9/21/2022
20:30
1.00 COMPZN, RPCOMP PRTS P Install HP BPV and test to 2500 PSI for
15 minutes charted pump down IA and
return in direction of floow up tbg. Blow
down injection line.
9,873.0 9,873.0
9/21/2022
20:30
9/21/2022
21:30
1.00 COMPZN, WHDBOP RURD P Clean and clear rig floor, R/D 4.5"
handling equipment pull master
bushings and Vac out BOP stack. P/U
and R/U slings for N/D
9,873.0 9,873.0
9/21/2022
21:30
9/22/2022
00:00
2.50 COMPZN, WHDBOP NUND P Pull maste bushings, clean Joe's box
and pull trip nipple. R/D MPD piping and
related equipment Bleed accumulator
and N/D BOP stack.
9,873.0 9,873.0
9/22/2022
00:00
9/22/2022
01:00
1.00 COMPZN, WHDBOP NUND P Finish N/D BOP's and riser.
SIMOPS: Move Ball Mill
0.0 0.0
9/22/2022
01:00
9/22/2022
02:00
1.00 COMPZN, WHDBOP NUND P Complete control line termination at WH.
NU adapter flange. Test to 5,000psi
5min. Witness by CPAI
0.0 0.0
9/22/2022
02:00
9/22/2022
05:30
3.50 COMPZN, WHDBOP NUND P Install 5k tree. Fill tree w/ desiel, Test
250psi low f/ 10 min. 5,000psi f/ 10 min.
Test witnessed by COPA rep Blow down
testing equipment & rig down same.
0.0 0.0
9/22/2022
05:30
9/22/2022
06:30
1.00 COMPZN, WHDBOP OTHR P Pull BPV and R/U LRS for freeze
protect.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 26/26
MT7-99
Report Printed: 10/24/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/22/2022
06:30
9/22/2022
07:30
1.00 COMPZN, WHDBOP FRZP P Presure test lines to 3,500psi with LRS.
Pump 85bbls diesel down IA and up
tubing.
0.0 0.0
9/22/2022
07:30
9/22/2022
09:00
1.50 COMPZN, WHDBOP OTHR P Continue freeze protect well letting
diesel U-Tube from IA to tubing. BD
service lines and R/D. Secure well.
0.0 0.0
9/22/2022
09:00
9/22/2022
10:30
1.50 DEMOB, MOVE DMOB P Scope down derrick, Spool off drill line. 0.0 0.0
9/22/2022
10:30
9/22/2022
12:00
1.50 DEMOB, MOVE DMOB P Disconnect and stomp Power complex.
Rig released at 1200 Hrs 9-22-22
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 9/22/2022
Page 1/1
MT7-99
Report Printed: 10/24/2022
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
8/29/2022 06:00
Cementing End Date
8/29/2022 09:30
Wellbore Name
MT7-99
Comment
SLB pump 5 bbls of fresh H2O. Tested lines to 3500 psi, pump 100 bbls of 10.9 ppg Mud Push II @ 4.2 bbls/min, 225 psi, 6.7% F/O, Dropped bottom plug. Start
batching lead. Pump 381 bbls of 11.0 ppg DeepCRETE cement at 5.1 bbls/min, 320 psi ICP, F/O 4.2%. Batch and pump 73 bbls of G Blend Tail 15.8 ppg cement
@ 4.5 bbls/min, 203 psi, F/O 4.6%. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace w/ 11 ppg mud @ 8 bbls/min,Slow to 3bpm 360 psi,
F/O 18.6%. Bump plug with 960 psi, final circ. PSI 360 @ 3 bpm, Pressure up to 960 psi & hold for 5 minutes. Bleed off pressure, Check floats, Floats holding,
160 bbls 11.0 ppg cement to surface.
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
39.2
Bottom Depth (ftKB)
3,243.0
Full Return?
Yes
Vol Cement …
160.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
8
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
5
P Pump Final (psi)
360.0
P Plug Bump (psi)
960.0
Recip?
Yes
Stroke (ft)
8.00
Rotated?
Yes
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
Lead Cement
Fluid Description Estimated Top (ftKB)
39.2
Est Btm (ftKB)
2,903.0
Amount (sacks)
1,110
Class
Blend
Volume Pumped (bbl)
382.0
Yield (ft³/sack)
1.92
Mix H20 Ratio (gal/sack)
6.72
Free Water (%) Density (lb/gal)
11.00
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
2,903.0
Est Btm (ftKB)
3,243.0
Amount (sacks)
336
Class
G
Volume Pumped (bbl)
73.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.05
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/1
MT7-99
Report Printed: 10/24/2022
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
9/5/2022 01:30
Cementing End Date
9/5/2022 05:00
Wellbore Name
MT7-99
Comment
Line up cement unit. flush w/ 3 bbls FW. Test lines to 4500psi. Good test. Mix and pump 60bbls 12.5ppg mud push II at 4 bpm. SD and drop bottom plug. Mix and
pump 74bbls 13 ppg G lead cement at 4.5 bpm, Mix and pump 152bbls 15.8 ppg G Tail cement at 4.5 bpm. SD and drop top plug. Pump 20 bbls FW w/ cement.
Swap over to rig pumps and Displace cement at 6bpm10psi 500bbls slow rate to 5bpm 1060psi slow rate to 3bpm 1068psi. Plug bumped @ 5086 stks (calculated
stks5163). Pressure up to 1600psi. Check floats. Good. Cement in place @ 05:05hrs 9/5/22
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
5,486.0
Bottom Depth (ftKB)
8,483.9
Full Return?
No
Vol Cement …Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
5
Q Pump Avg (bbl/…P Pump Final (psi)
1,060.0
P Plug Bump (psi)
1,600.0
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
Lead Cement
Fluid Description Estimated Top (ftKB)
5,486.0
Est Btm (ftKB)
6,494.0
Amount (sacks)
217
Class
G
Volume Pumped (bbl)
73.2
Yield (ft³/sack)
1.91
Mix H20 Ratio (gal/sack)
10.27
Free Water (%) Density (lb/gal)
13.00
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
6,494.0
Est Btm (ftKB)
8,483.9
Amount (sacks)
729
Class
G
Volume Pumped (bbl)
258.2
Yield (ft³/sack)
1.17
Mix H20 Ratio (gal/sack)
5.08
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
Page 1/1
MT7-99
Report Printed: 10/24/2022
Cement
Cement Details
Description
Intermediate String 2 Cement
Cementing Start Date
9/9/2022 15:00
Cementing End Date
9/9/2022 16:45
Wellbore Name
MT7-99
Comment
Pump 3 bbls FW w/ cement unit. Test lines to 4200psi. Pump 70bbls KCL. SD and drop bottom dart. Mix and pump 64 bbls of 15.8 ppg cement. Drop top dart.
Pump 20bbls FW w/ cement unit. Swap over to rig and displace @ 5-6 bpm. Plug down and cement in place (5.8bbls early) @ 16:42hrs 9/9/22. FCP 360psi/
870psi Held f/ 5 minutes and check floats. Floats held. 0.75bbls returned. No Loss to formation
Cement Stages
Stage # 1
Description
Intermediate String 2
Cement
Objective
CMT 7" Liner T/10,507'
Top Depth (ftKB)
9,380.0
Bottom Depth (ftKB)
10,028.0
Full Return?
Yes
Vol Cement …Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
3
P Pump Final (psi)
360.0
P Plug Bump (psi)
870.0
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
Pump 3 bbls FW w/ cement unit. Test lines to 4200psi. Pump 70bbls KCL. SD and drop bottom dart. Mix and pump 64 bbls of 15.8 ppg cement. Drop top dart.
Pump 20bbls FW w/ cement unit. Swap over to rig and displace @ 5-6 bpm. Plug down and cement in place (5.8bbls early) @ 16:42hrs 9/9/22. FCP 360psi/
870psi Held f/ 5 minutes and check floats. Floats held. 0.75bbls returned. No Loss to formation
Cement Fluids & Additives
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
9,380.0
Est Btm (ftKB)
10,028.0
Amount (sacks)
215
Class
G
Volume Pumped (bbl)
65.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.03
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 2 Cement
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Certificate Of Completion
Envelope Id: D556BE3D9A7548138A76873FD9E4F723 Status: Delivered
Subject: Here is your signed document: MT7-99 Completion Report.pdf
Source Envelope:
Document Pages: 42 Signatures: 1 Envelope Originator:
Certificate Pages: 4 Initials: 0 Brad Gorham
AutoNav: Enabled
EnvelopeId Stamping: Disabled
Time Zone: (UTC-06:00) Central Time (US & Canada)
600 N Dairy Ashford Rd
Houston, TX 77079-1100
Brad.Gorham@conocophillips.com
IP Address: 138.32.8.5
Record Tracking
Status: Original
10/24/2022 12:15:45 PM
Holder: Brad Gorham
Brad.Gorham@conocophillips.com
Location: DocuSign
Signer Events Signature Timestamp
Brad Gorham
Brad.Gorham@conocophillips.com
ConocoPhillips
Security Level: Email, Account Authentication
(None)Signature Adoption: Pre-selected Style
Using IP Address: 138.32.8.5
Sent: 10/24/2022 12:15:48 PM
Viewed: 10/24/2022 12:15:58 PM
Signed: 10/24/2022 12:16:46 PM
Freeform Signing
Electronic Record and Signature Disclosure:
Accepted: 11/17/2020 1:40:42 PM
ID: 515f5087-2ab8-40c0-8058-8ccd6a202c68
In Person Signer Events Signature Timestamp
Editor Delivery Events Status Timestamp
Agent Delivery Events Status Timestamp
Intermediary Delivery Events Status Timestamp
Certified Delivery Events Status Timestamp
Carbon Copy Events Status Timestamp
Brad.gorham@cop.com
Security Level: Email, Account Authentication
(None)
Electronic Record and Signature Disclosure:
Not Offered via DocuSign
Witness Events Signature Timestamp
Notary Events Signature Timestamp
Envelope Summary Events Status Timestamps
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Certified Delivered Security Checked 10/24/2022 12:15:58 PM
Signing Complete Security Checked 10/24/2022 12:16:46 PM
Payment Events Status Timestamps
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From:Taylor, Jenna
To:Brooks, James S (OGC)
Subject:RE: [EXTERNAL]RE: MT7-99 Completion Report (PTD 222-102)
Date:Tuesday, October 25, 2022 2:23:40 PM
James – There must have been a hidden formula – but hours tested was 24 and the oil gravity is 37,
0.79 is the gas gravity.
Jenna
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Tuesday, October 25, 2022 12:54 PM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: [EXTERNAL]RE: MT7-99 Completion Report (PTD 222-102)
CAUTION:This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Hi,
Having some issues with this 407:
Could someone take a look at section 27 (test section) and correct information ?
Hours tested is date not number
Oil Gravity value is not in range (should be between 10-70) / value listed is 0.79
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Sent: Monday, October 24, 2022 9:59 AM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: FW: MT7-99 Completion Report (PTD 222-102)
From: Taylor, Jenna <Jenna.L.Taylor@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.
Sent: Monday, October 24, 2022 9:50 AM
To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Cc: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S
<Greg.S.Hobbs@conocophillips.com>; Gorham, Brad <Brad.Gorham@conocophillips.com>
Subject: MT7-99 Completion Report (PTD 222-102)
Hello - See attached MT7-99 Completion Report (10-407).
Thank you,
Jenna
Jenna Taylor
kGMG~
ConocoPhillips Alaska, Inc.
700 G Street
Anchorage, AK 99501
907-263-4522
jenna.l.taylor@conocophillips.com
From:Brooks, James S (OGC)
To:Guhl, Meredith D (OGC)
Subject:FW: [EXTERNAL]FW: MT7-99 Completion Report (PTD 222-102)
Date:Thursday, October 27, 2022 12:41:37 PM
Here you go.
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Sent: Thursday, October 27, 2022 12:40 PM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: Re: [EXTERNAL]FW: MT7-99 Completion Report (PTD 222-102)
Alpine C
Get Outlook for iOS
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Thursday, October 27, 2022 12:37:22 PM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: [EXTERNAL]FW: MT7-99 Completion Report (PTD 222-102)
CAUTION:This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Hi,
What is the formation name for TD and TPI as they are not listed on the form ?
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
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: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Sent: Monday, October 24, 2022 9:59 AM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: FW: MT7-99 Completion Report (PTD 222-102)
From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Sent: Monday, October 24, 2022 9:50 AM
To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Cc: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S
<Greg.S.Hobbs@conocophillips.com>; Gorham, Brad <Brad.Gorham@conocophillips.com>
Subject: MT7-99 Completion Report (PTD 222-102)
Hello - See attached MT7-99 Completion Report (10-407).
Thank you,
Jenna
Jenna Taylor
kGMG~
ConocoPhillips Alaska, Inc.
700 G Street
Anchorage, AK 99501
907-263-4522
jenna.l.taylor@conocophillips.com
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1
WSC Rig Advisor
From:Schoessler, Allie M <aschoessler@blm.gov>
Sent:Sunday, September 11, 2022 2:09 PM
To:WSC Rig Advisor
Cc:Drilling Supervisor, Doyon 25; Njoku, Johnson; Operations Engineer, Doyon 25; Gorham,
Brad
Subject:Re: [EXTERNAL] RE: Doyon 25 BOP test
Justin,
Thank you for the additional data. As per our discussion BLM will accept the test in question as a pass.
Allie
From: WSC Rig Advisor <wscrigadvisor@conocophillips.com>
Sent: Sunday, September 11, 2022 2:05 PM
To: Schoessler, Allie M <aschoessler@blm.gov>
Cc: Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>;
Operations Engineer, Doyon 25 <Doyon25.OperationsEngineer@conocophillips.com>; Gorham, Brad
<Brad.Gorham@conocophillips.com>
Subject: [EXTERNAL] RE: Doyon 25 BOP test
This email has been received from outside of DOI - Use caution before clicking on links, opening attachments, or
responding.
Allie, as promised, I am attaching the Pason data for the test #2 (page 1) and zoomed in for times and
pressures. I also put the image in this email if that’s more convienent for you.
Thanks for your quick responses on the weekend!
2
Justin Montague | John Egbejimba
CPAI WSC Rig Advisor
wscrigadvisor@conocophillips.com
1-907-263-4546
From: WSC Rig Advisor
Sent: Sunday, September 11, 2022 1:28 PM
To: Schoessler, Allie M <aschoessler@blm.gov>; qsawyer@blm.gov
Cc: Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>;
Operations Engineer, Doyon 25 <Doyon25.OperationsEngineer@conocophillips.com>; Gorham, Brad
<Brad.Gorham@conocophillips.com>
Subject: Doyon 25 BOP test
Allie –
3
A couple further comments below.
We pulled up the last ten minutes of test #2 in pason and noted a digital drop of ~25 psi. This falls within
industry standards of less than 5 psi/min pressure drop.
Additional, we have pulled up Pason data from the last BOP test that was BLM witnessed on MT7-
98. Comparing the digital pressure losses during those tests shows this test is comparable – the tests on MT7-
98 lost 15-20 psi on the digital reading. I have attached MT7-98 BOP test for your reference.
Operational, to re-test the upper VBR’s, we would need to mobilize people and equipment to hang off the drill-
string. We would need to rig down our MPD system and install a trip nipple, then go through the test plug
procedure. All these extra operational steps increase our exposure to HSE risks.
I would like to follow this email up with a phone conversation if possible. But we feel this test passed our
internal requirements and is within industry standards.
Thank you
Justin Montague | John Egbejimba
CPAI WSC Rig Advisor
wscrigadvisor@conocophillips.com
1-907-263-4546
From: WSC Rig Advisor
Sent: Sunday, September 11, 2022 12:27 PM
To: Schoessler, Allie M <aschoessler@blm.gov>
Cc: Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com >;
Operations Engineer, Doyon 25 <Doyon25.OperationsEngineer@conocophillips.com >; Gorham, Brad
<Brad.Gorham@conocophillips.com>
Subject: RE: [EXTERNAL] Doyon 25 9-10-22
Thank you Allie –
We are making preparations to retest these components as they were changed out, but would like to have a
conversation regarding test #2. Through the entirety of the test in question, there was a gradual decrease in
pressure, but we feel the last ten minutes of the test held as per required. I have attempted to block out the
start of the test as I feel it is easier to just focus on the last ten minutes.
1RWLQ$3,6WDQGDUGZKDWVWDQGDUG"MEU
%DGUHDVRQIRUQRWGRLQJD
SURSHUWHVWMEU
industry standards of less than 5 psi/min pressure drop.
extra operational steps increase our exposure to HSE risks.
4
Justin Montague | John Egbejimba
CPAI WSC Rig Advisor
wscrigadvisor@conocophillips.com
1-907-263-4546
5
From: Schoessler, Allie M <aschoessler@blm.gov>
Sent: Sunday, September 11, 2022 11:41 AM
To: Rig 25 <rig25@doyondrilling.com>; AOGCC <AOGCC.Inspectors@alaska.gov>; jim.regg@alaska.gov; Brooks, Poebe
L)CED <phoebe.brooks@alaska.gov>; BLM_AK_AKSO_EnergySection_Notifications
<BLM_AK_AKSO_EnergySection_Notifications@blm.gov >
Cc: Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Bill Walter <bwalter@doyondrilling.com >; Ben Wedin
<bwedin@doyondrilling.com>; WSC Rig Advisor <wscrigadvisor@conocophillips.com>; Hobbs, Greg S
<Greg.S.Hobbs@conocophillips.com>
Subject: Re: [EXTERNAL] Doyon 25 9-10-22
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
Thank you for the results.
Test #2 does not appear to pass a 10 min high interval from the chart provided.
If the components were not changed from the previous BOPE test (10 minute high within 30 days) then a 5
minute pass is acceptable for the State required testing frequency. If the components were changed this need
to be retested.
Please let me know if you have any questions,
Allie Schoessler
Petroleum Engineer / Inspector
Office: 907-271-3127
Cell: 907-202-2445
222 W 7th Ave Stop 13
Anchorage, AK 99513
From: Rig 25 <rig25@doyondrilling.com>
Sent: Sunday, September 11, 2022 9:23 AM
To: AOGCC <AOGCC.Inspectors@alaska.gov>; jim.regg@alaska.gov <jim.regg@alaska.gov>; Brooks, Poebe L)CED
<phoebe.brooks@alaska.gov>; BLM_AK_AKSO_EnergySection_Notifications
<BLM_AK_AKSO_EnergySection_Notifications@blm.gov >
Cc: Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Bill Walter <bwalter@doyondrilling.com >; Ben Wedin
<bwedin@doyondrilling.com>; WSC Rig Advisor <wscrigadvisor@conocophillips.com>;
Greg.S.Hobbs@conocophillips.com <Greg.S.Hobbs@conocophillips.com>
Subject: [EXTERNAL] Doyon 25 9-10-22
This email has been received from outside of DOI - Use caution before clicking on links, opening attachments, or
responding.
BOPE test report attached
6
Roy Fritts
Rig 25 Toolpusher
rig25@doyondrilling.com
907-670-4971
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:25 DATE: 9/10/22
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2221020 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: Other: X
Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2978
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 4P
Test Fluid Water Inside BOP 2P
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 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8"x5000psi P Time/Pressure Test Result
HCR Valves 2 3-1/8"x5000psi P System Pressure (psi)3000 P
Kill Line Valves 2 3-1/8"x5000psi P Pressure After Closure (psi)1800 P
Check Valve 0NA200 psi Attained (sec)12 P
BOP Misc 0NAFull Pressure Attained (sec)77 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 / 2058 P
No. Valves 15 P ACC Misc 0P
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 23 P
#1 Rams 18 P
Coiled Tubing Only:#2 Rams 16 P
Inside Reel valves 0NA #3 Rams 16 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:6.0 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 9/7/22 17:56
Waived By
Test Start Date/Time:9/10/2022 13:00
(date) (time)Witness
Test Finish Date/Time:9/10/2022 19:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Jim Regg
Doyon
Test Annular, Ram #1 & #3 to 250/3500psi w/ 4" & 5" test joint. Test Ram #2 to 250/3500psi. Test 2 ea 4" & 5" FOSV and 1 ea 4"
& 5" Dart valve. All tests for 5/10 mins. Function primary & remote BOPE control stations. Test LEL & H2S alarms. Witness of test
verbally waived by AOGCC Rep. Jim Regg.
R.Fritts / Z.Coleman
CPAI
J.Benedict / L.Shirley
GMTU MT7-99
Test Pressure (psi):
rig25@doyondillining.com
d25cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2022-0910_BOP_Doyon25_GMTU_MT7-99
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MT7-99 9/10/2022 250 Low for 5 min – 3500 High for 10 min
5” Test Jt
1. Annular Preventer, Valves: 1, 13, 14, 15, 4” Kill Line Valve, UIBOP
2. Upper Pipe Rams (2.87” x 5.5” VBR’S), Valves: 2, 10, 12 & LIBOP
3. Valves: 6, 9 ,11, HCR Kill, 5” Dart Valve
4. Valves 5, 7, 8 & 5” FOSV # 1
5. Valves 3 & 5” FOSV # 2
6. Lower Pipe Rams (2.87” x 5.5” VBR’S), 4” Dart Valve
7. Blind Shear Rams, Valve 4 & 4” FOSV # 1
8. Manually Operated & Super Choke (8A = Man Choke – 8B = Super Choke)
4” Test Jt
9. Annular Preventer, HCR Choke & 4” FOSV # 2
10. Upper Pipe Rams (2.87” x 5.5” VBR’S) & Manual Choke
11. Lower Pipe Rams (2.87” x 5.5” VBR’S)
T + 1 337.856-7201
1058 Baker Hughes Drive
Broussard, LA 70518, USA
Sep 30, 2022
AOGCC
Attention: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Alaska 99501-3539
Subject:Final Log Distribution for ConocoPhillips Alaska, Inc.
MT7-99
Greater Mooses Tooth
API #: 50-103-20845-00
Permit No: 222-102
Rig: Doyon 25
The final deliverables were uploaded via https://copsftp.sharefile.com/ for the above well.
Items delivered: MWD/LWD Digital Las Data, Graphic Images CGM/PDF and Survey Files.
MT7-99 is located in a federal oil and gas unit. Only with respect to the MT7-99 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).
Thank you.
Signature of receiver & date received:
Please return transmittal letter to:
Garrett Brown
PTD:222-102
T37098
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2022.10.05
09:36:32 -08'00'
T + 1 337.856-7201
1058 Baker Hughes Drive
Broussard, LA 70518, USA
Garrett.Brown@conocophillips.com
Luis Arismendi
Luis.arismendi@bakerhughes.com
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STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:25 DATE: 8/30/22
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2221020 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: X Weekly: Bi-Weekly: Other:
Rams:250/5000 Annular:250/3500 Valves:250/5000 MASP:2978
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 2P
Test Fluid Water 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"X 5000psi P Pit Level Indicators PP
#1 Rams 1 2 7/8x5 1/2 vbr P Flow Indicator PP
#2 Rams 1 Blind Shear P Meth Gas Detector PP
#3 Rams 1 13 5/8"X 5000psi P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3 1/8 x 5000 psi P Time/Pressure Test Result
HCR Valves 1 3 1/8 x 5000 psi P System Pressure (psi)3000 P
Kill Line Valves 1 3 1/8 x 5000 psi P Pressure After Closure (psi)1650 P
Check Valve 0NA200 psi Attained (sec)15 P
BOP Misc 0NAFull Pressure Attained (sec)93 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge: 1000 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 1946 P
No. Valves 15 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 23 P
#1 Rams 18 P
Coiled Tubing Only:#2 Rams 16 P
Inside Reel valves 0NA #3 Rams 16 P
#4 Rams NA
Test Results #5 Rams NA
#6 Rams NA
Number of Failures:0 Test Time:8.0 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 8/26/22 6:17
Waived By
Test Start Date/Time:8/30/2022 4:00
(date) (time)Witness
Test Finish Date/Time:8/30/2022 12:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Bob Noble
Doyon
Test annular 250/3500 w/ 5" test joint, Ram #1 and #3 w/ 5" test joint to 250/5000 psi f/ 5/10 min. Test ram #2 to 250/5000 psi for
5/10 min. Test 2 ea 5" FOSV and 1 ea 5" dart valve. Function primary and remote BOPE control stations. Test LEL and H2S gas
alarms. BLM waived witness.
E. Potter/ C. Bali
CPAI
R. Reinhardt
GMTU MT7-99
Test Pressure (psi):
rig25@doyondrilling.com
d25cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2022-0830_BOP_Doyon25_GMTU_MT7-99
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MT7-99 8/30/2022 250 Low for 5 min – 5000 High for 10 min
5” Test Jt
1. Annular Preventer
2. Upper 2 7/8” x 5 ½ VRB’s, Valves: # 1, 13, 14, 15, 4” Kill Valve
3. Valves: # 2, 10, 12, Manual Kill, 5” FOSV # 1
4. Valves: # 6, 9 ,11, HCR Kill, 5” FOSV # 2
5. Valves: # 5, 7, 8 & UIBOP
6. Valves: # 3 & LIBOP
7. HCR Choke
8. Manual Choke, 5” Dart Valve
9. Lower 2 7/8” x 5 ½ VRB’s,
10.Valves: #4, Blind Shear Rams
11. Manually Operated & Super Choke ( 11A = Man Choke – 11B = Super)
37'
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333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Chris Brillon
Drilling Manager
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Re: Greater Mooses Tooth Field, Rendezvous Pool, MT7-99
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 222-102
Surface Location: 1025' FSL, 1965' FWL, SESW Sec. 32, T10N, R2E,UM
Bottomhole Location: 471' FSL, 1072' FWL, SWSW, Sec. 16, T9N, R2E, UM
Dear Mr. Brillon:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Jeremy M. Price
Chair
DATED this ___ day of August, 2022.
Jeremy
Price
Digitally signed by Jeremy Price
Date: 2022.08.24 10:22:03 -08'00'
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8/24/22
Jeremy Price Digitally signed by Jeremy Price
Date: 2022.08.24 10:22:23 -08'00'
GMTU MT7-99
Conditions of Approval:
Approval is granted to run the LWD-Sonic on upcoming well with the following provisions:
1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as
soon as they become available. The evaluation is to include/highlight the intervals of competent
cement that CPAI is using to meet the objective requirements for annular isolation, reservoir
isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation
is not acceptable.
2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must
start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC.
Starting the log below the actual TOC based on calculations predicting a different TOC will not
be acceptable.
3. CPAI will provide a cement job summary report and evaluation along with the cement log and
evaluation to the AOGCC when they become available
4. CPAI will provide the results of the FIT when available.
5. Depending on the cement job results indicated by the cement job report, the logs and the FIT,
remedial measures or additional logging may be required.
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
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dŚĞŝŶƚĞƌŵĞĚŝĂƚĞϮͲŚŽůĞƐĞĐƚŝŽŶǁŝůůďĞĚƌŝůůĞĚǁŝƚŚKDǁĞŝŐŚƚĞĚƚŽϭϭ͘ϱƉƉŐ͘ ŶƐƵƌĞŐŽŽĚŚŽůĞĐůĞĂŶŝŶŐďLJ
ŵĂdžŝŵŝnjŝŶŐĨůƵŝĚĂŶŶƵůĂƌǀĞůŽĐŝƚLJ͘dŚĞƌĞŝƐĂƐůŝŐŚƚƉŽƚĞŶƚŝĂůĨŽƌůŽƐƚĐŝƌĐƵůĂƚŝŽŶ͕ƉĂƌƚŝĐƵůĂƌůLJĂĨƚĞƌƚŚĞƌĞƐĞƌǀŽŝƌŝƐ
ƉĞŶĞƚƌĂƚĞĚ͘ ŶƐƵƌĞĂĚĞƋƵĂƚĞ>DŵĂƚĞƌŝĂůŝƐĂǀĂŝůĂďůĞŽŶůŽĐĂƚŝŽŶĂŶĚŝŶƚŚĞĨŝĞůĚƚŽĂĚĚƌĞƐƐĂŶLJĞdžƉĞĐƚĞĚůŽƐƐĞƐ͘
DĂŝŶƚĂŝŶŵƵĚǁĞŝŐŚƚǁŝůůďĞϭϭ͘ϱƚĂƌŐĞƚŝŶŐϭϯ͘Ϭ DtƵƐŝŶŐDW͘'ŽŽĚĨŝůƚĞƌĐĂŬĞƋƵĂůŝƚLJ͕ŚŽůĞĐůĞĂŶŝŶŐĂŶĚ
ŵĂŝŶƚĞŶĂŶĐĞŽĨůŽǁĚƌŝůůƐŽůŝĚƐ;ďLJĚŝůƵƚŝŶŐĂƐƌĞƋƵŝƌĞĚͿǁŝůůĂůůďĞŝŵƉŽƌƚĂŶƚŝŶŵĂŝŶƚĂŝŶŝŶŐǁĞůůďŽƌĞƐƚĂďŝůŝƚLJ͘EŽƚĞ͗
ĞŶƐŝƚLJ WW'ϭϬ͘ϱʹϭϭ͘ϱϭϭ͘ϬʹϭϮ͘ϬϭϬ͘Ϭʹϭϯ͘Ϭϴ͘ϴʹϵ͘ϱ
ƌŝůůŝŶŐ&ůƵŝĚWƌŽŐƌĂŵ
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DĂŶĂŐĞĚWƌĞƐƐƵƌĞƌŝůůŝŶŐ;DWͿǁŝůůďĞƵƚŝůŝnjĞĚĨŽƌĂĚĚŝŶŐďĂĐŬƉƌĞƐƐƵƌĞĚƵƌŝŶŐĐŽŶŶĞĐƚŝŽŶƐƚŽŵŝƚŝŐĂƚĞƐŚĂůĞ
ŝŶƐƚĂďŝůŝƚLJĂŶĚĐLJĐůŝŶŐ͘
WƌŽĚƵĐƚŝŽŶ,ŽůĞ͗
dŚĞŚŽƌŝnjŽŶƚĂůƉƌŽĚƵĐƚŝŽŶŝŶƚĞƌǀĂůǁŝůůďĞĚƌŝůůĞĚǁŝƚŚ&ůŽͲWƌŽǁĞŝŐŚƚĞĚƚŽϴ͘ϴͲϵ͘ϱƉƉŐ͘DWǁŝůůďĞƵƐĞĚƚŽŚŽůĚ
ďĂĐŬƉƌĞƐƐƵƌĞ͕ŬĞĞƉŝŶŐƚŚĞǁĞůůĚLJŶĂŵŝĐĂůůLJďĂůĂŶĐĞĚ͘
ŝĂŐƌĂŵŽĨŽLJŽŶϮϱDƵĚ^LJƐƚĞŵŽŶĨŝůĞ͘
ƌŝůůŝŶŐĨůƵŝĚƉƌĂĐƚŝĐĞƐǁŝůůďĞŝŶĂĐĐŽƌĚĂŶĐĞǁŝƚŚĂƉƉƌŽƉƌŝĂƚĞƌĞŐƵůĂƚŝŽŶƐ͘
ϵ͘ďŶŽƌŵĂůůLJWƌĞƐƐƵƌĞĚ&ŽƌŵĂƚŝŽŶ/ŶĨŽƌŵĂƚŝŽŶ;ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϵͿͿ
EͬͲƉƉůŝĐĂƚŝŽŶŝƐŶŽƚĨŽƌĂŶĞdžƉůŽƌĂƚŽƌLJŽƌƐƚƌĂƚŝŐƌĂƉŚŝĐƚĞƐƚǁĞůů͘
ϭϬ͘^ĞŝƐŵŝĐŶĂůLJƐŝƐ;ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϭϬͿͿ
EͬͲƉƉůŝĐĂƚŝŽŶŝƐŶŽƚĨŽƌĂŶĞdžƉůŽƌĂƚŽƌLJŽƌƐƚƌĂƚŝŐƌĂƉŚŝĐƚĞƐƚǁĞůů͘
ϭϭ͘^ĞĂďĞĚŽŶĚŝƚŝŽŶŶĂůLJƐŝƐ;ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϭϭͿͿ
EͬͲƉƉůŝĐĂƚŝŽŶŝƐŶŽƚĨŽƌĂŶŽĨĨƐŚŽƌĞǁĞůů͘
ϭϮ͘ ǀŝĚĞŶĐĞŽĨŽŶĚŝŶŐ;ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϭϮͿͿ
ǀŝĚĞŶĐĞŽĨďŽŶĚŝŶŐĨŽƌŽŶŽĐŽWŚŝůůŝƉƐůĂƐŬĂ͕/ŶĐ͘ŝƐŽŶĨŝůĞǁŝƚŚƚŚĞŽŵŵŝƐƐŝŽŶ͘
ϭϯ͘ŝƐĐƵƐƐŝŽŶŽĨDƵĚĂŶĚƵƚƚŝŶŐƐŝƐƉŽƐĂůĂŶĚŶŶƵůĂƌŝƐƉŽƐĂů;ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϭϰͿͿ
/ŶĐŝĚĞŶƚĂůĨůƵŝĚƐĚĞǀĞůŽƉĞĚĨƌŽŵĚƌŝůůŝŶŐŽƉĞƌĂƚŝŽŶƐŽŶǁĞůůDdϳͲϵϵǁŝůůďĞŝŶũĞĐƚĞĚŝŶƚŽĂƉĞƌŵŝƚƚĞĚĂŶŶƵůƵƐŽŶ
ƚŚĞDdϳƉĂĚŽƌŚĂƵůĞĚƚŽƚŚĞůĂƐƐϭĚŝƐƉŽƐĂůǁĞůůŽŶϭ͘
dŚĞDdϳͲϵϵƐƵƌĨĂĐĞͬŝŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐĂŶŶƵůƵƐǁŝůůďĞĨůƵƐŚĞĚǁŝƚŚϯϬϬďďůƐŽĨĨƌĞƐŚǁĂƚĞƌƉƌŝŽƌƚŽĨƌĞĞnjĞ
ƉƌŽƚĞĐƚŝŶŐǁŝƚŚĚŝĞƐĞůƚŽΕϮϬϬϬΖds͘^ŝŐŶŝĨŝĐĂŶƚŚLJĚƌŽĐĂƌďŽŶnj ŽŶĞƐŝŶĐůƵĚĞŽŶůLJƚŚĞůƉŝŶĞƐĂŶĚďĂƐĞĚŽŶƉƌĞͲĚƌŝůů
ŝŶƚĞƌƉƌĞƚĂƚŝŽŶƐ͘
KŶĐĞDdϳͲϵϵŚĂƐďĞĞŶĚƌŝůůĞĚĂŶĚĐŽŵƉůĞƚĞĚ͕ĐŽŶƐŝĚĞƌĂƚŝŽŶŵĂLJďĞŐŝǀĞŶƚŽƉĞƌŵŝƚƚŚŝƐǁĞůůĨŽƌĂŶŶƵůĂƌŝŶũĞĐƚŝŽŶ͘
ŶĂƉƉůŝĐĂƚŝŽŶĨŽƌ^ƵŶĚƌLJKƉĞƌĂƚŝŽŶƐĨŽƌŵϭϬͲϰϬϯǁŝůůƚŚĞŶďĞĨŝůĞĚ͘ŶŶƵůĂƌƉƵŵƉŝŶŐŽĨĨůƵŝĚƐŽĐĐƵƌƌŝŶŐĚƵĞƚŽ
ĚƌŝůůŝŶŐŽƉĞƌĂƚŝŽŶƐ͕ƉĞƌƌĞŐƵůĂƚŝŽŶϮϬϮϱ͘ϬϴϬĐŽƵůĚƚŚĞŶďĞŐŝŶŽŶĐĞƉƌŽƉĞƌůLJƉĞƌŵŝƚƚĞĚ͘ƐƐƚĂƚĞĚĂďŽǀĞ͕ĂŶLJ
njŽŶĞƐĐŽŶƚĂŝŶŝŶŐƐŝŐŶŝĨŝĐĂŶƚŚLJĚƌŽĐĂƌďŽŶƐǁŝůůďĞŝƐŽůĂƚĞĚƉƌŝŽ ƌƚŽŝŶŝƚŝĂƚŝŶŐĂŶŶƵůĂƌƉƵŵƉŝŶŐ͘dŚĞƌĞǁŝůůďĞŶŽ
h^tΖƐŽƉĞŶďĞůŽǁƚŚĞƐŚŽĞŽƌƉŽƚĂďůĞͬŝŶĚƵƐƚƌŝĂůǁĂƚĞƌǁĞůůƐǁŝƚŚŝŶŽŶĞŵŝůĞŽĨƚŚĞƌĞĐĞŝǀŝŶŐnjŽŶĞ͘ZĞĨĞƌĞŶĐĞ
ƚŚĞĞŶĐůŽƐĞĚĚŝƌĞĐƚŝŽŶĂůĚƌŝůůŝŶŐƉůĂŶĨŽƌŽƚŚĞƌĨŽƌŵĂƚŝŽŶŵĂƌŬĞƌƐŝŶƚŚŝƐǁĞůů͘
^ƵƌĨĂĐĞĐĂƐŝŶŐǁŝůůďĞƐĞƚŶĞĂƌƚŚĞďĂƐĞŽĨƚŚĞϭϬĨŽƌŵĂƚŝŽŶ͕ǁŝƚŚŝŶƚŚĞ<ϯĨŽƌŵĂƚŝŽŶ͘dŚĞƐĞϰϱϬͲϱϬϬΖƚŚŝĐŬƐŚĂůĞƐ
ĂƌĞƉĂƌƚŽĨƚŚĞŽůǀŝůůĞ'ƌŽƵƉĂŶĚĂƌĞŬŶŽǁŶƚŽƉƌŽǀŝĚĞǀĞƌƚŝĐĂůďĂƌƌŝĞƌƐƚŽĨůƵŝĚĨůŽǁŝŶŽƚŚĞƌĂƌĞĂƐ͘
dŚĞŵĂdžŝŵƵŵǀŽůƵŵĞŽĨĨůƵŝĚƐƚŽďĞƉƵŵƉĞĚĚŽǁŶƚŚĞĂŶŶƵůƵƐŽĨƚŚŝƐǁĞůůǁŝůůŶŽƚĞdžĐĞĞĚϯϱ͕ϬϬϬďďůǁŝƚŚŽƵƚƚŚĞ
ƐƉĞĐŝĨŝĐƉĞƌŵŝƐƐŝŽŶŽĨƚŚĞK'͘&ůƵŝĚĚĞŶƐŝƚŝĞƐǁŝůůƌĂŶŐĞĨƌŽŵĚŝĞƐĞůƚŽĂŵĂdžŝŵƵŵŽĨϭϮ͘ϬƉƉŐĨŽƌĚƌŝůůŝŶŐĨůƵŝĚ
ǁĂƐƚĞƐ͘hƐŝŶŐϭϮ͘ϬƉƉŐĨůƵŝĚĂŶĚƚŚĞƌŝŐ͛ƐƐƉĞĐŝĨŝĞĚŵĂdžŝŵƵŵƉƵŵƉŝŶŐƉƌĞƐƐƵƌĞŽĨϭ͕ϱϬϬƉƐŝĨŽƌĂŶŶƵůĂƌŝŶũĞĐƚŝŽŶ͕
ƚŚĞŵĂdžŝŵƵŵƉƌĞƐƐƵƌĞĂƚƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐƐŚŽĞŝƐĞƐƚŝŵĂƚĞĚďLJ͗
DĂdž^ŚŽĞWƌĞƐƐƵƌĞ с;ϭϮ͘ϬƉƉŐͿΎ;Ϭ͘ϬϱϮͿΎ;^ƵƌĨ͘^ŚŽĞdsͿнϭ͕ϱϬϬƉƐŝ
с;ϭϮ͘ϬƉƉŐͿΎ;Ϭ͘ϬϱϮͿΎ;ϯϬϰϬ͛Ϳнϭ͕ϱϬϬƉƐŝ
сϯϯϵϲƉƐŝ
WŽƌĞWƌĞƐƐƵƌĞ сϭϯϳϱƉƐŝ
dŚĞƌĞĨŽƌĞ
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dŚĞŝŶƚĞƌŶĂůĐĂƐŝŶŐƉƌĞƐƐƵƌĞŝƐĐŽŶƐĞƌǀĂƚŝǀĞƐŝŶĐĞĨƌŝĐƚŝŽŶĂůůŽƐƐĞƐǁŚŝůĞƉƵŵƉŝŶŐŚĂǀĞŶŽƚďĞĞŶƚĂŬĞŶŝŶƚŽ
ĐŽŶƐŝĚĞƌĂƚŝŽŶ͘dŚĞƐƵƌĨĂĐĞĂŶĚŝŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐƐƚƌŝŶŐƐĞdžƉŽƐĞĚƚŽƚŚĞĂŶŶƵůĂƌƉƵŵƉŝŶŐŽƉĞƌĂƚŝŽŶƐŚĂǀĞ
ƐƵĨĨŝĐŝĞŶƚƐƚƌĞŶŐƚŚďLJƵƐŝŶŐƚŚĞϴϱйĐŽůůĂƉƐĞĂŶĚďƵƌƐƚƌĂƚŝŶŐƐůŝƐƚĞĚŝŶƚŚĞĨŽůůŽǁŝŶŐƚĂďůĞ͗
Ktƚ
;ƉƉĨͿ'ƌĂĚĞZĂŶŐĞŽŶŶĞĐƚŝŽŶ
dLJƉĞŽůůĂƉƐĞϴϱйŽĨ
ŽůůĂƉƐĞƵƌƐƚϴϱйŽĨ
ƵƌƐƚ
ϭϯ͘ϯϳϱ͟ϲϴ>ͲϴϬϯ ,ϱϲϯϮϮϲϬƉƐŝϭϵϮϭƉƐŝϱϬϮϬƉƐŝϰϮϲϳƉƐŝ
ϵ͘ϲϮϱ͟ϰϯ͘ϱͬϰϳ>ͲϴϬϯ ,ϱϲϯϯϴϭϬƉƐŝϯϮϯϴƉƐŝϲϯϯϬƉƐŝϱϯϴϬƉƐŝ
ŶŶƵůĂƌ>Kd͕ǁĂƚĞƌĨůƵƐŚ͕ĂŶĚĨƌĞĞnjĞƉƌŽƚĞĐƚƉƌŽĐĞĚƵƌĂůƐƚĞƉƐ
ϭ͘sĞƌŝĨLJ^ƵƌĨĂĐĞ&/dͬ>KdĚĂƚĂĂŶĚĐĂůĐƵůĂƚĞŵĂdžŝŵƵŵƐƵƌĨĂĐĞŝŶũĞĐƚŝŽŶƉƌĞƐƐƵƌĞĨŽƌƵƉĐŽŵŝŶŐƉƵŵƉŝŶŐ
ŽƉĞƌĂƚŝŽŶƐďĂƐĞĚŽŶƐƉĞĐŝĨŝĐĨůƵŝĚǁĞŝŐŚƚďĞŝŶŐƉƵŵƉĞĚ͘ ŶƐƵƌĞĐƵƌƌĞŶƚĂŶŶƵůƵƐĨůƵŝĚǁĞŝŐŚƚŝƐ
ĐŽŶƐŝĚĞƌĞĚ͘
Ϯ͘ZŝŐƵƉĂŶĚďĞŐŝŶƚŚĞϭϯͲϯͬϴ͟džϵͲϱͬϴ͟ŶŶƵůĂƌ>KdďLJƉƵŵƉŝŶŐĚƌŝůůŝŶŐŵƵĚ ĚŽǁŶƚŚĞĂŶŶƵůƵƐ͘
ϯ͘^ƚĂƌƚǁŝƚŚϬ͘ϱʹϬ͘ϳϱďƉŵŚŽůĚŝŶŐĂĐŽŶƐƚĂŶƚƌĂƚĞƚŚƌŽƵŐŚŽƵƚƚŚĞƚĞƐƚ͘ZĞĐŽƌĚŝŶũĞĐƚŝŽŶƉƌĞƐƐƵƌĞƐĂŶĚ
ǀŽůƵŵĞƉƵŵƉĞĚĞǀĞƌLJϬ͘ϱʹϭ͘ϬďďůƉƵŵƉĞĚ͘
ϰ͘KŶĐĞůĞĂŬŽĨĨŝƐŽďƐĞƌǀĞĚ͕ƉƵŵƉĂŶĂĚĚŝƚŝŽŶĂůϯďďůƐƚŽĚĞĨŝŶĞŝŶũĞĐƚŝŽŶƉƌĞƐƐƵƌĞ͘
ϱ͘^ŚƵƚĚŽǁŶƚŚĞƉƵŵƉƐ͘DŽŶŝƚŽƌĂŶĚƌĞĐŽƌĚƐŚƵƚŝŶƉƌĞƐƐƵƌĞƐĨŽƌϭϬŵŝŶƵƚĞƐ͘
ϲ͘&ůƵƐŚƚŚĞĂŶŶƵůƵƐǁŝƚŚϯϬϬďďůƐŽĨĨƌĞƐŚǁĂƚĞƌ͘DŽŶŝƚŽƌƉƌĞƐƐƵƌĞǁŚŝůĞƉƵŵƉŝŶŐƚŽĞŶƐƵƌĞǁŝƚŚŝŶ
ĞdžƉĞĐƚĞĚƌĂŶŐĞĨŽƌƉƵŵƉĞĚĨůƵŝĚ͘
ϳ͘WƵŵƉŝĞƐĞůĨƌĞĞnjĞƉƌŽƚĞĐƚƚŽϮϬϬ͛dsďĞůŽǁƉĞƌŵĂĨƌŽƐƚǁŚŝůĞĐŽŶƚŝŶƵŽƵƐůLJŵŽŶŝƚŽƌŝŶŐŝŶũĞĐƚŝŽŶ
ƉƌĞƐƐƵƌĞƐ͘
ϴ͘ZĞĐŽƌĚĂůůƉĂƌĂŵĞƚĞƌƐĂŶĚƐƵďŵŝƚƚŽĞŶŐŝŶĞĞƌŝŶŐ͘
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ϭϰ͘ƌŝůůŝŶŐ,ĂnjĂƌĚƐ^ƵŵŵĂƌLJ
;dŽďĞƉŽƐƚĞĚŝŶZŝŐ&ůŽŽƌŽŐŚŽƵƐĞWƌŝŽƌƚŽ^ƉƵĚͿ
ϭϲΗ,ŽůĞͬϭϯ͘ϯϳϱ͟ĂƐŝŶŐ/ŶƚĞƌǀĂů
ǀĞŶƚZŝƐŬ>ĞǀĞůDŝƚŝŐĂƚŝŽŶ^ƚƌĂƚĞŐLJ
ŽŶĚƵĐƚŽƌƌŽĂĐŚ>ŽǁDŽŶŝƚŽƌĐĞůůĂƌĐŽŶƚŝŶƵŽƵƐůLJĚƵƌŝŶŐŝŶƚĞƌǀĂů͘
tĞůůŽůůŝƐŝŽŶ>Žǁ&ŝƌƐƚǁĞůůŽŶWĂĚ͕ƚƌĂǀĞůŝŶŐĐLJůŝŶĚĞƌĚŝĂŐƌĂŵƐ
'ĂƐ,LJĚƌĂƚĞƐ>Žǁ/ĨŽďƐĞƌǀĞĚʹĐŽŶƚƌŽůĚƌŝůů͕ƌĞĚƵĐĞƉƵŵƉƌĂƚĞƐĂŶĚĐŝƌĐƵůĂƚŝŶŐƚŝŵĞ͕
ƌĞĚƵĐĞŵƵĚƚĞŵƉĞƌĂƚƵƌĞƐ
ůĂLJĂůůŝŶŐDĞĚŝƵŵDĂŝŶƚĂŝŶƉůĂŶŶĞĚŵƵĚƉĂƌĂŵĞƚĞƌƐĂŶĚĨůŽǁƌĂƚĞƐ͕/ŶĐƌĞĂƐĞŵƵĚǁĞŝŐŚƚ͕
ƵƐĞǁĞŝŐŚƚĞĚƐǁĞĞƉƐ͕ƌĞĚƵĐĞĨůƵŝĚǀŝƐĐŽƐŝƚLJ͕ĐŽŶƚƌŽůZKW
ďŶŽƌŵĂůWƌĞƐƐƵƌĞŝŶ
^ƵƌĨĂĐĞ&ŽƌŵĂƚŝŽŶƐ>ŽǁŝǀĞƌƚĞƌĚƌŝůůƐ͕ŝŶĐƌĞĂƐĞĚŵƵĚǁĞŝŐŚƚ͘^ŚĂůůŽǁŚĂnjĂƌĚƐƚƵĚLJŶŽƚĞĚ
ŵŝŶŝŵĂůƌŝƐŬ
>ŽƐƚŝƌĐƵůĂƚŝŽŶDĞĚŝƵŵZĞĚƵĐĞƉƵŵƉƌĂƚĞƐ͕ŵƵĚƌŚĞŽůŽŐLJ͕ĂĚĚůŽƐƚĐŝƌĐƵůĂƚŝŽŶŵĂƚĞƌŝĂů͕ƵƐĞŽĨ
ůŽǁĚĞŶƐŝƚLJĐĞŵĞŶƚƐůƵƌƌŝĞƐ͕ƉŽƌƚĐŽůůĂƌ͕ĐŽŶƚƌŽůƉŝƉĞƌƵŶŶŝŶŐƐƉĞĞĚƐ
ϭϮ͘Ϯϱ͟,ŽůĞͬϵ͘ϲϮϱ͟ĂƐŝŶŐ/ŶƚĞƌǀĂů
ǀĞŶƚZŝƐŬ>ĞǀĞůDŝƚŝŐĂƚŝŽŶ^ƚƌĂƚĞŐLJ
>ŽƐƚĐŝƌĐƵůĂƚŝŽŶ>ŽǁZĞĚƵĐĞƉƵŵƉƌĂƚĞƐ͕ƌĞĚƵĐĞƚƌŝƉƐƉĞĞĚƐ͕ƌĞĂůƚŝŵĞ ŵŽŶŝƚŽƌŝŶŐ͕ŵƵĚ
ƌŚĞŽůŽŐLJ͕ĂĚĚůŽƐƚĐŝƌĐƵůĂƚŝŽŶŵĂƚĞƌŝĂů
,ŽůĞƐǁĂďďŝŶŐŽŶƚƌŝƉƐDĞĚŝƵŵZĞĚƵĐĞƚƌŝƉƐƉĞĞĚƐ͕ĐŽŶĚŝƚŝŽŶŵƵĚƉƌŽƉĞƌƚŝĞƐ͕ƉƌŽƉĞƌŚŽůĞĨŝůůŝŶŐ͕ƉƵŵƉ
ŽƵƚŽĨŚŽůĞ͕ƌĞĂůƚŝŵĞ ŵŽŶŝƚŽƌŝŶŐ͕DWƐƚƌŝƉƉŝŶŐƉƌĂĐƚŝĐĞƐ
ďŶŽƌŵĂůWƌĞƐƐƵƌĞŝŶ
KǀĞƌďƵƌĚĞŶ
&ŽƌŵĂƚŝŽŶƐ
>ŽǁtĞůůĐŽŶƚƌŽůĚƌŝůůƐ͕ĐŚĞĐŬĨŽƌĨůŽǁĚƵƌŝŶŐĐŽŶŶĞĐƚŝŽŶƐ͕ŝŶĐƌĞĂƐ ĞŵƵĚ
ǁĞŝŐŚƚ͘^ŚĂůůŽǁŚĂnjĂƌĚƐƚƵĚLJŶŽƚĞĚŵŝŶŝŵĂůƌŝƐŬ
,ŽůĞůĞĂŶŝŶŐ>ŽǁDŽŶŝƚŽƌ ĂŶĚƚŽƌƋƵĞͬĚƌĂŐƚƌĞŶĚƐ͕ĐŽŶƚƌŽůĚƌŝůůĂŶĚƵƐĞďĞƐƚŚŽůĞ
ĐůĞĂŶŝŶŐƉƌĂĐƚŝĐĞƐ
ϴ͘ϱϬΗdžϵ͘ϴϳϱ͟,ŽůĞͬϳ͟>ŝŶĞƌͲĂƐŝŶŐ/ŶƚĞƌǀĂů
ǀĞŶƚZŝƐŬ>ĞǀĞůDŝƚŝŐĂƚŝŽŶ^ƚƌĂƚĞŐLJ
^ůŽƵŐŚŝŶŐƐŚĂůĞ͕dŝŐŚƚ
ŚŽůĞ,ŝŐŚ
DWĨŽƌƐŚĂůĞƐƚĂďŝůŝƚLJ͕^ƚĞĞƌĂďůĞƌŝůůŝŶŐ>ŝŶĞƌ͕/ŶĐƌĞĂƐĞŵƵĚǁĞŝŐŚƚ͕
ĐŽŶƚƌŽůZKW͕ĐŽŶŶĞĐƚŝŽŶĂŶĚƚƌŝƉƐƉĞĞĚƐ͕ƐǁĞĞƉƐ͕ĂŶĚƌĞĂůƚŝŵĞ
ĞƋƵŝǀĂůĞŶƚĐŝƌĐƵůĂƚŝŶŐĚĞŶƐŝƚLJ; ͿŵŽŶŝƚŽƌŝŶŐ͕ƌƵŶĐĂƐŝŶŐĂƐůŝŶĞƌ
>ŽƐƚĐŝƌĐƵůĂƚŝŽŶ >Žǁ
ZĞĚƵĐĞƉƵŵƉƌĂƚĞƐ͕ƌĞĚƵĐĞƚƌŝƉƐƉĞĞĚƐ͕ƌĞĂůƚŝŵĞ ŵŽŶŝƚŽƌŝŶŐ͕ŵƵĚ
ƌŚĞŽůŽŐLJ͕ĂĚĚůŽƐƚĐŝƌĐƵůĂƚŝŽŶŵĂƚĞƌŝĂů
,ŽůĞƐǁĂďďŝŶŐŽŶƚƌŝƉƐDĞĚŝƵŵZĞĚƵĐĞƚƌŝƉƐƉĞĞĚƐ͕ĐŽŶĚŝƚŝŽŶŵƵĚƉƌŽƉĞƌƚŝĞƐ͕ƉƌŽƉĞƌŚŽůĞĨŝůůŝŶŐ͕ƉƵŵƉ
ŽƵƚŽĨŚŽůĞ͕ƌĞĂůƚŝŵĞ ŵŽŶŝƚŽƌŝŶŐ͕>ŝŶĞƌǁŝůůďĞŝŶƉůĂĐĞĂƚd
ďŶŽƌŵĂůZĞƐĞƌǀŽŝƌ
WƌĞƐƐƵƌĞ>ŽǁtĞůůĐŽŶƚƌŽůĚƌŝůůƐ͕ĐŚĞĐŬĨŽƌĨůŽǁĚƵƌŝŶŐĐŽŶŶĞĐƚŝŽŶƐ͕ŝŶĐƌĞĂƐ ĞŵƵĚ
ǁĞŝŐŚƚ
,LJĚƌŽŐĞŶ^ƵůĨŝĚĞŐĂƐ>Žǁ,Ϯ^ĚƌŝůůƐ͕ĚĞƚĞĐƚŝŽŶƐLJƐƚĞŵƐ͕ĂůĂƌŵƐ͕ƐƚĂŶĚĂƌĚǁĞůůĐŽŶƚƌŽůƉƌĂĐƚŝĐĞƐ͕
ŵƵĚƐĐĂǀĞŶŐĞƌƐ
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ϲ͘ϭϮϱ͟,ŽůĞͬϰ͘ϱ͟WƌĞͲWĞƌĨŽƌĂƚĞĚ>ŝŶĞƌͲ,ŽƌŝnjŽŶƚĂůWƌŽĚƵĐƚŝŽŶ,ŽůĞ
ǀĞŶƚZŝƐŬ
>ĞǀĞůDŝƚŝŐĂƚŝŽŶ^ƚƌĂƚĞŐLJ
>ŽƐƚĐŝƌĐƵůĂƚŝŽŶ
>Žǁ
ZĞĚƵĐĞƉƵŵƉƌĂƚĞƐ͕ƌĞĚƵĐĞƚƌŝƉƐƉĞĞĚƐ͕ƌĞĂůƚŝŵĞ ŵŽŶŝƚŽƌŝŶŐ͕ŵƵĚ
ƌŚĞŽůŽŐLJ͕ĂĚĚůŽƐƚĐŝƌĐƵůĂƚŝŽŶŵĂƚĞƌŝĂů
,ŽůĞƐǁĂďďŝŶŐŽŶƚƌŝƉƐDĞĚŝƵŵZĞĚƵĐĞƚƌŝƉƐƉĞĞĚƐ͕ĐŽŶĚŝƚŝŽŶŵƵĚƉƌŽƉĞƌƚŝĞƐ͕ƉƌŽƉĞƌŚŽůĞĨŝůůŝŶŐ͕ƉƵŵƉŽƵƚ
ŽĨŚŽůĞ͕ƌĞĂůƚŝŵĞ ŵŽŶŝƚŽƌŝŶŐ
ďŶŽƌŵĂůZĞƐĞƌǀŽŝƌ
WƌĞƐƐƵƌĞ>ŽǁtĞůůĐŽŶƚƌŽůĚƌŝůůƐ͕ĐŚĞĐŬĨŽƌĨůŽǁĚƵƌŝŶŐĐŽŶŶĞĐƚŝŽŶƐ͕ŝŶĐƌĞĂƐ ĞĚŵƵĚǁĞŝŐŚƚ
ŝĨĨĞƌĞŶƚŝĂů^ƚŝĐŬŝŶŐ>ŽǁhŶŝĨŽƌŵƌĞƐĞƌǀŽŝƌƉƌĞƐƐƵƌĞĂůŽŶŐůĂƚĞƌĂů͕ŬĞĞƉƉŝƉĞŵŽǀŝŶŐ͕ĐŽŶƚƌŽůŵƵĚ
ǁĞŝŐŚƚ
,LJĚƌŽŐĞŶ^ƵůĨŝĚĞŐĂƐ>Žǁ,Ϯ^ĚƌŝůůƐ͕ĚĞƚĞĐƚŝŽŶƐLJƐƚĞŵƐ͕ĂůĂƌŵƐ͕ƐƚĂŶĚĂƌĚǁĞůůĐŽŶƚƌŽůƉƌĂĐƚŝĐĞƐ͕ŵƵĚ
ƐĐĂǀĞŶŐĞƌƐ
tĞůůWƌŽdžŝŵŝƚLJZŝƐŬƐ͗
DdϳǁŝůůďĞĂŵƵůƚŝͲǁĞůůƉĂĚ͕ĐŽŶƚĂŝŶŝŶŐĂŶŽƌŝŐŝŶĂůƉůĂŶŽĨϯϲǁĞůůƐ͘ŝƌĞĐƚŝŽŶĂůĚƌŝůůŝŶŐͬĐŽůůŝƐŝŽŶĂǀŽŝĚĂŶĐĞ
ŝŶĨŽƌŵĂƚŝŽŶŝƐƉƌŽǀŝĚĞĚŝŶƚŚĞĨŽůůŽǁŝŶŐĂƚƚĂĐŚŵĞŶƚƐ͘
ƌŝůůŝŶŐƌĞĂZŝƐŬƐ͗
ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞ͗KĨĨƐĞƚŝŶũĞĐƚŝŽŶŚĂƐƚŚĞƉŽƚĞŶƚŝĂůƚŽŝŶĐƌĞĂƐĞƌĞƐĞƌǀŽŝƌƉƌĞƐƐƵƌĞŽǀĞƌƉƌĞĚŝĐƚĞĚ͘ůƚŚŽƵŐŚƚŚŝƐ
ŝƐƵŶůŝŬĞůLJ͕ƚŚĞƌŝŐǁŝůůďĞƉƌĞƉĂƌĞĚƚŽǁĞŝŐŚƚƵƉŝĨƌĞƋƵŝƌĞĚ͘
tĞĂŬƐĂŶĚƐƚƌŝŶŐĞƌƐĐŽƵůĚďĞƉƌĞƐĞŶƚŝŶƚŚĞŽǀĞƌďƵƌĚĞŶ͘>DŵĂƚĞƌŝĂůǁŝůůďĞĂǀĂŝůĂďůĞƚŽƐĞĂůŝŶůŽƐƐĞƐŝŶƚŚĞ
ŝŶƚĞƌŵĞĚŝĂƚĞƐĞĐƚŝŽŶ͘
>ŽǁĞƌ^ŚĂůĞ^ƚĂďŝůŝƚLJ͗,Zͬ<ĂůƵďŝŬͬDŝůƵǀĞĂĐŚŝŶƚŚĞŝŶƚĞƌŵĞĚŝĂƚĞĂŶĚŝŶƚĞƌŵĞĚŝĂƚĞηϮŚŽůĞƐĞĐƚŝŽŶƐǁŝůůƌĞƋƵŝƌĞ
ŚŝŐŚĞƌŵƵĚǁĞŝŐŚƚƐƚŚĂŶŚŝƐƚŽƌŝĐĂůůLJƵƐĞĚƚŽĞŶŚĂŶĐĞǁĞůůďŽƌĞƐƚĂďŝůŝƚLJ͘DĂŶĂŐĞĚWƌĞƐƐƵƌĞƌŝůůŝŶŐǁŝůůďĞƵƐĞĚŝŶ
ĐŽŶũƵŶĐƚŝŽŶǁŝƚŚĂϰͲƐƚƌŝŶŐĐĂƐŝŶŐĚĞƐŝŐŶƚŽŵŝƚŝŐĂƚĞƐŚĂůĞŝŶƐƚĂďŝůŝƚLJŝŶƚŚĞƐĞĨŽƌŵĂƚŝŽŶƐ͘^ƚĂŶĚĂƌĚ>DŵĂƚĞƌŝĂů
ĂŶĚǁĞůůďŽƌĞƐƚƌĞŶŐƚŚĞŶŝŶŐƉŝůůƐĂƌĞĞdžƉĞĐƚĞĚƚŽďĞĞĨĨĞĐƚŝǀĞŝŶĚĞĂůŝŶŐǁŝƚŚůŽƐƚĐŝƌĐƵůĂƚŝŽŶŝĨŶĞĞĚĞĚ͘
'ŽŽĚĚƌŝůůŝŶŐƉƌĂĐƚŝĐĞƐǁŝůůďĞƐƚƌĞƐƐĞĚƚŽŵŝŶŝŵŝnjĞƚŚĞƉŽƚĞŶƚŝĂůŽĨƚĂŬŝŶŐƐǁĂďďĞĚŬŝĐŬƐ͘
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ϭϱ͘DdϳͲϵϵWƌŽƉŽƐĞĚ/ŶũĞĐƚŝŽŶŽŵƉůĞƚŝŽŶ^ĐŚĞŵĂƚŝĐ
ƚƚĂĐŚŵĞŶƚϭʹDdϳͲϵϵƌĞĂŽĨZĞǀŝĞǁ;KZͿ
ŶƌĞĂŽĨZĞǀŝĞǁƉůŽƚŝƐƐŚŽǁďĞůŽǁŽĨƚŚĞDdϳͲϵϵ/ŶũĞĐƚŽƌƉůĂŶŶĞĚǁĞůůƉĂƚŚĂŶĚŽĨĨƐĞƚǁĞůůƐ͘DdϳͲϬϮ
ŝƐƚŚĞŽŶůLJŽĨĨƐĞƚǁĞůůĨƌŽŵƚŚĞƉůĂŶŶĞĚDdϳͲϵϵŝŶũĞĐƚŽƌ͘
tĞůů
EĂŵĞ^ƚĂƚƵƐ
dŽƉŽĨ
ůƉŝŶĞ
WŽŽů
;DͬdsͿ
dK
;DͬdsͿ
dKʹ
ĞƚĞƌŵŝŶĞĚ
LJ
ZĞƐĞƌǀŽŝƌ
^ƚĂƚƵƐ
ŽŶĂů
/ƐŽůĂƚŝŽŶ
ĞŵĞŶƚ
KƉĞƌĂƚŝŽŶƐ
^ƵŵŵĂƌLJ
DdϳͲϬϮWƌŽĚƵĐŝŶŐϭϬ͕ϲϱϰ͛ͬ
ϴ͕Ϯϵϱ͛
ϵ͕ϯϳϬ͛ͬ
ϳϲϵϮ͛^ŽŶŝĐ>ŽŐ>ŝŶĞƌdKĂŶĚ
WĂĐŬĞƌ
ϳϮďďůƐŽĨϭϱ͘ϴ
ƉƉŐůĂƐƐ'
DdϳͲϬϮŝŶƚĞƌŵĞĚŝĂƚĞϮƐĞĐƚŝŽŶǁĂƐĚƌŝůůĞĚĂŶĚĐĂƐĞĚǁŝƚŚϳ͟ůŝŶĞƌĚŽǁŶƚŽϭϬ͕ϳϱϲ͛DŝŶƚŚĞůƉŝŶĞ͘
dŚĞůƉŝŶĞnjŽŶĞǁĂƐƉĞŶĞƚƌĂƚĞĚĂƚϭϬ͕ϵϮϯ͛D͘dŚĞŝŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐǁĂƐĐĞŵĞŶƚĞĚƚŽŝƐŽůĂƚĞƚŚĞ
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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:Gorham, Brad
To:Loepp, Victoria T (OGC)
Subject:RE: [EXTERNAL]MT7-99(PTD 222-102) PTD questions
Date:Monday, August 22, 2022 10:25:38 AM
Attachments:MT7-99 PTD.msg
Victoria,
We are not planning to fracture stimulate this well. The frac sleeves are acting as sliding sleeves and
are purely just to control which intervals are injected in to. The kick tolerance spreadsheet was
included in the original permit to drill application, see attached email. Please let me know if you
need any other information or have any other questions.
Thanks,
Brad
From: Loepp, Victoria T (OGC) victoria.loepp@alaska.gov
Sent: Monday, August 22, 2022 10:02 AM
To: Gorham, Brad Brad.Gorham@conocophillips.com
Cc: Loepp, Victoria T (OGC) victoria.loepp@alaska.gov
Subject: [EXTERNAL]MT7-99(PTD 222-102) PTD questions
CAUTION:This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Brad,
1. Is this well planned to be fracture stimulated? If not, why the frac sleeves? Why is the
planned hydraulic fracture box marked “no”?
2. Please provide kick tolerance calculations for the surface casing supporting the 11.5 ppg EMW
minimum LOT to drill ahead?
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria.Loepp@alaska.gov
MT7-99 KT 8/24/2022 8:48 AM
Well: MT7-99 <== Data Input
Name: Brad Gorham <== Data Input
Mud Weight (ppg) 9.90 <== Data Input
Weak point or LOT - Measured depth (ft) 10,043'<== Data Input
Weak point or LOT True vertical depth (ft) 7,438'<== Data Input
Weak point or LOT - Hole angle (deg) 76.0º<== Data Input
Weak point or LOT - Hole size (in) 9.875"<== Data Input
Weak point pressure or LOT - EMW (ppg) 10.10 <== Data Input
Zone of interest - Measured depth (ft) 23,820'<== Data Input
Zone of interest - True vertical depth (ft) 8,449'<== Data Input
Zone of interest - Hole angle (deg) 90.0º<== Data Input
Zone of interest - Hole size (in) 6.125"<== Data Input
Zone of interest - Pore pressure EMW (ppg) 9.90 <== Data Input
Gas gradient (psi/ft) 0.10 <== Data Input
Bottom hole assembly OD (in) 4.750"<== Data Input
Bottom hole assembly length (ft) 300'<== Data Input
Drill pipe OD (in) 4.000"<== Data Input
BHA annular vol. @ zone of interest (bbl/ft)0.0145
DP annular vol. @ zone of interest (bbl/ft)0.0209
DP annular vol. @ weak point (bbl/ft)0.0792
Additional safety margin (psi) 0.00 <== Data Input
Weak point pressure (psi):Plo 3,906 psi
Weak point pressure - Safety margin:Pmax 3,906 psi
Pmax EMW 10.10 ppg
Max anticipated formation pressure (psi):Pf 4,350 psi
Weak Pt to Zone of Interest distance (TVD ft):OH {TVD}1,011'
Weak Pt to Zone of Interest distance (MD ft):OH {MD}13,777'
Maximum influx height at the bit (TVD ft):H {TVD}186'
Maximum influx height at the bit (MD ft):H {MD}###############
Calc. volume of {H} around BHA:V1bha 4.4 bbl
Calc. volume of {H} around drill pipe:V1dp #################
Calc. volume that H equals @ initial shut in:V1 ###############
Calc. vol. that H equals @ weak point (MD ft):Vwp 61.0 bbl
Calc. volume of Vwp @ initial shut in:V2 54.8 bbl
Kick Tolerance: V2 54.8 bbl
NOTE:
Spreadsheet revised by: G. S. Walz 3/9/99
MT7-99 KT 8/24/2022 8:47 AM
Well: MT7-99 <== Data Input
Name: Brad Gorham <== Data Input
Mud Weight (ppg) 9.90 <== Data Input
Weak point or LOT - Measured depth (ft) 10,043'<== Data Input
Weak point or LOT True vertical depth (ft) 7,438'<== Data Input
Weak point or LOT - Hole angle (deg) 76.0º<== Data Input
Weak point or LOT - Hole size (in) 9.875"<== Data Input
Weak point pressure or LOT - EMW (ppg) 10.10 <== Data Input
Zone of interest - Measured depth (ft) 23,820'<== Data Input
Zone of interest - True vertical depth (ft) 8,449'<== Data Input
Zone of interest - Hole angle (deg) 90.0º<== Data Input
Zone of interest - Hole size (in) 6.125"<== Data Input
Zone of interest - Pore pressure EMW (ppg) 9.90 <== Data Input
Gas gradient (psi/ft) 0.10 <== Data Input
Bottom hole assembly OD (in) 4.750"<== Data Input
Bottom hole assembly length (ft) 300'<== Data Input
Drill pipe OD (in) 4.000"<== Data Input
BHA annular vol. @ zone of interest (bbl/ft)0.0145
DP annular vol. @ zone of interest (bbl/ft)0.0209
DP annular vol. @ weak point (bbl/ft)0.0792
Additional safety margin (psi) 0.00 <== Data Input
Weak point pressure (psi):Plo 3,906 psi
Weak point pressure - Safety margin:Pmax 3,906 psi
Pmax EMW 10.10 ppg
Max anticipated formation pressure (psi):Pf 4,350 psi
Weak Pt to Zone of Interest distance (TVD ft):OH {TVD}1,011'
Weak Pt to Zone of Interest distance (MD ft):OH {MD}13,777'
Maximum influx height at the bit (TVD ft):H {TVD}186'
Maximum influx height at the bit (MD ft):H {MD}###############
Calc. volume of {H} around BHA:V1bha 4.4 bbl
Calc. volume of {H} around drill pipe:V1dp #################
Calc. volume that H equals @ initial shut in:V1 ###############
Calc. vol. that H equals @ weak point (MD ft):Vwp 61.0 bbl
Calc. volume of Vwp @ initial shut in:V2 54.8 bbl
Kick Tolerance: V2 54.8 bbl
NOTE:
Spreadsheet revised by: G. S. Walz 3/9/99
MT7-99 KT 8/24/2022 8:46 AM
Well: MT7-99 <== Data Input
Name: Brad Gorham <== Data Input
Mud Weight (ppg) 9.90 <== Data Input
Weak point or LOT - Measured depth (ft) 10,043'<== Data Input
Weak point or LOT True vertical depth (ft) 7,438'<== Data Input
Weak point or LOT - Hole angle (deg) 76.0º<== Data Input
Weak point or LOT - Hole size (in) 9.875"<== Data Input
Weak point pressure or LOT - EMW (ppg) 10.10 <== Data Input
Zone of interest - Measured depth (ft) 23,820'<== Data Input
Zone of interest - True vertical depth (ft) 8,449'<== Data Input
Zone of interest - Hole angle (deg) 90.0º<== Data Input
Zone of interest - Hole size (in) 6.125"<== Data Input
Zone of interest - Pore pressure EMW (ppg) 9.90 <== Data Input
Gas gradient (psi/ft) 0.10 <== Data Input
Bottom hole assembly OD (in) 4.750"<== Data Input
Bottom hole assembly length (ft) 300'<== Data Input
Drill pipe OD (in) 4.000"<== Data Input
BHA annular vol. @ zone of interest (bbl/ft)0.0145
DP annular vol. @ zone of interest (bbl/ft)0.0209
DP annular vol. @ weak point (bbl/ft)0.0792
Additional safety margin (psi) 0.00 <== Data Input
Weak point pressure (psi):Plo 3,906 psi
Weak point pressure - Safety margin:Pmax 3,906 psi
Pmax EMW 10.10 ppg
Max anticipated formation pressure (psi):Pf 4,350 psi
Weak Pt to Zone of Interest distance (TVD ft):OH {TVD}1,011'
Weak Pt to Zone of Interest distance (MD ft):OH {MD}13,777'
Maximum influx height at the bit (TVD ft):H {TVD}186'
Maximum influx height at the bit (MD ft):H {MD}###############
Calc. volume of {H} around BHA:V1bha 4.4 bbl
Calc. volume of {H} around drill pipe:V1dp #################
Calc. volume that H equals @ initial shut in:V1 ###############
Calc. vol. that H equals @ weak point (MD ft):Vwp 61.0 bbl
Calc. volume of Vwp @ initial shut in:V2 54.8 bbl
Kick Tolerance: V2 54.8 bbl
NOTE:
Spreadsheet revised by: G. S. Walz 3/9/99
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WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:MOOSES TOOTH MT7-99Initial Class/TypeSER / PENDGeoArea890Unit10750On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2221020GRTR MOOSES TOOTH, RENDEZV OIL - 2822NA1Permit fee attachedYes2Lease number appropriateYes3Unique well name and numberYes4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitYesAIO No. 43 applies at GMTU2.14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYes15All wells within 1/4 mile area of review identified (For service well only)YesMT7-99 will be pre-produced for less than 30 days, per operator e-mail.16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes80.5' conductor18Conductor string providedYesSC shoe at 3241' MD19Surface casing protects all known USDWsYes77% excess20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoProductive interval will be completed with uncemented frac sleeves and perf joints22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete: no major risk failures26Adequate wellbore separation proposedYesDiverter variance granted per 20 AAC 25.035(h)27If diverter required, does it meet regulationsYesMax formation pressure is 3823 psig(8.8 ppg EMW); will drill w/ 8.8-13.0 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 2978 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYes33Is presence of H2S gas probableYesMT7-02 good int cement and packer34Mechanical condition of wells within AOR verified (For service well only)YesH2S not expected; rig has sensors and alarms35Permit can be issued w/o hydrogen sulfide measuresYes36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate8/5/2022ApprVTLDate8/22/2022ApprDLBDate8/4/2022AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate-03JLC 8/24/2022
