Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout218-1441. 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:
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 4050'feet None feet
true vertical 4050' feet None feet
Effective Depth measured 4050'feet 3475'feet
true vertical 4050' feet 3475' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 3515' MD 3515' TVD
Packers and SSSV (type, measured and true vertical depth) 3475' MD
N/A
3475' TVD
N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: Suspended (Exploration/Wildcat)
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title: Contact Phone:
319-190
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
~
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: Baker Premier Packer
SSSV: None
Nina Anderson
nina.anderson@conocophillips.com
(907) 265-6403Exploration Drilling Engineer
None
None
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
~
Gas-Mcf
MD
~
Size
119'
~ ~~
Suspended ~~
~
measured
TVD
7"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
218-144
50-103-20783-00-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
AA081834
Exploration/ Wildcat
Tinmiaq 13
Plugs
Junk measured
Length
Production
Liner
4006'
Casing
4044'4044'
1792'
119'Conductor
Surface
Intermediate
16"
9-5/8"
80'
1831' 1831'
Burst Collapse
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
CONFIDENTIAL4050'050'feetee NoneNonemeasuredmeasuredPlugsugsECONFIDENTIALN/AN/A ExplorationxploraECONFIDENTIAL
By Grace Christianson at 4:06 pm, Sep 23, 2024
Suspended Well Site Inspection Form
Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness
Well Name: Field/Pool:
Permit # (PTD): API Number:
Operator: Date Suspended: 4/15/2019
Surface Location: Section: 35 Township: 12N Range: 2W
Nearest active pad or road: Meridian: Umiat
Take to Location
Digital camera Map showing well location /Aerial photos
Brief well history Wellbore diagram showing downhole condition
Latest Sundry or Completion report
Past Site Visit documentation Site clearance documentation
Pressure gauges, fittings, tools Sample containers for fluids on or near pad
Condition of Surface Location AOGCC requires:
1) a description of the condition of the surface location, including discoloration, fluids or sheens visible
on the ground or in any nearby water,
2) photographs showing the condition of the location surrounding the well
General location condition:
Pad or location surface:
Location cleanup needed:
Pits condition:
Surrounding area condition:
Water/fluids on pad:
Discoloration, Sheens on pad, pits or water:
Samples taken: None
Access road condition:
Photographs taken (# and description):
Condition of Wellhead AOGCC requires:
1) a description of the condition of the wellhead, 2) well pressure readings, where practicable,
3) photographs showing the wellhead condition
Wellhead/tree/valve description, condition:
Cellar description, condition, fluids:
Rat Hole:
Wellhouse or protective barriers:
Well identification sign:
Tubing Pressure (or casing if no tubing):
Annulus pressures:
Wellhead Photos taken (# and description):
Work Required:
Operator Rep (name and signature):
AOGCC Inspector: Other Observers:
Inspection Date: AOGCC Notice Date:
Time of arrival: Time of Departure:
Site access method:
N/A
32' FNL 1706' FWL
ConocoPhillips Alaska, Inc.
218-144
Tinmiaq 13 Exploratory
50-103-20783-00-00
Great shape. Clean. No damage
Great shape
N/A
Great shape
None
None
None
N/A
5 pictures of well and surrounding area
Great shape. Valves in good condition
Minor water in cellar. No sheen
N/A
Damage to bird wrap. Currently being fixed
Attached. In great shape
IA= 0 psi. OA= 0 psi.
5 pictures of cellar and tree/valves
None
N/A
Grant Arend
Bob Noble
8-21-2024
helicopter
CONFIDENTIALetion reporttion report
ation Site clearance documentationation Site clearance documentation
tools Sample containers for fluids on or near patools Sample containers for fluids on or near pa
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
LAST TAG: TINMIAQ
13
jennalt
Last Rev Reason
Annotation Wellbore End Date Last Mod By
REV REASON: New Exploration Well TINMIAQ
13
6/1/2019 jennalt
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic10.0 6/1/2019 jennalt
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.25 39.2 119.2 119.2 62.50 H-40
SURFACE 9 5/8 8.84 39.4 1,831.1 1,831.0 40.00 L-80 TXPM
PRODUCTION 7 6.28 38.1 4,044.0 4,043.9 26.00 L-80 TXP-m
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
34.5
Set Depth
3,515.5
Set Depth
3,515.4
String Max No
3 1/2
Tubing Description
Tubing Completion Upper
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE-m
ID (in)
2.99
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)
34.5 34.5 0.03 HANGER 10.880 Hanger, 4-1/2" x 10-3/4" Gen 5,
FMC TC-1A EMS
FMC PN:
1000009
887,
MM#
1061994
0
3.920
67.3 67.3 0.18 XO REDUCING 4.500 Crossover 4-1/2" IBT-m x 3-1/2"
EUE
2.992
496.2 496.2 0.46 NIPPLE 4.500 Nipple, Camco, 2.875" DS, 2.906"
No-go, SN:T021908 (??° hole
angle)
HES PN:
1342871
, ser #
T021908
2.875
3,255.8 3,255.8 0.09 GAS LIFT 5.375 GLM, Camco 3-1/2" x 1" KBMG with
DCK-2 SOV, 2000 csg->tbg
SN:20813-25
CAMCO KBMG 2.920
3,314.4 3,314.3 0.09 NIPPLE 4.500 Nipple, HES, 2.813" X Profile,
SN:21605-08 (??° hole angle)
HES PN:
281GX0
336, ser
# 21605-
08
2.813
3,366.6 3,366.5 0.09 NIPPLE 4.500 Nipple, HES, 2.813" X Profile,
SN:21605-07 (??° hole
angle)
HES PN:
281GX0
336,
ser#
21605-
07
2.813
3,418.6 3,418.6 0.09 GAUGE 5.500 Gauge Carrier, SLB, SGM with
Sapphire tubing pressure gauge,
SN:C18GM 0399
HES PN:
1018930
76, ser#
C18GM0
399
2.992
3,475.5 3,475.4 0.08 PACKER 5.990 Packer, Baker 3 1/2" x 7" Premier Baker PN:
H784-63
-0255,
Control
#:
1063684
69 SN02
2.870
3,503.8 3,503.7 0.07 NIPPLE 4.480 Nipple, HES, 2.813" XN, 2.75" No-
go,SN:21605-06 (RHC plug
installed)
HES PN:
281GXN
0337-
275-A,
ser #
21605-
06
2.813
3,515.0 3,514.9 0.07 MULE SHOE 4.500 Baker Fluted WLEG (Wire line entry
guide)
Baker PN: 469-
21-3551,
Control
#: PO-
4510029
957
3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
VR plug - IA
#1
4/17/2019
VR Plug - IA
#2
4/17/2019
VR Plug - OA 4/17/2019
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)
3,255.8 3,255.8 0.09 1 GAS LIFT SOV DCK-
2
1 4/19/2019 Camco
TINMIAQ 13, 9/12/2024 4:31:12 PM
Vertical schematic (actual)
PRODUCTION; 38.1-4,044.0
SHOE; 4,041.9-4,044.0
MULE SHOE; 3,515.0
NIPPLE; 3,503.7
PACKER; 3,475.5
GAUGE; 3,418.6
NIPPLE; 3,366.6
NIPPLE; 3,314.4
GAS LIFT; 3,255.8
SURFACE; 39.4-1,831.1
SHOE; 1,828.7-1,831.1
NIPPLE; 496.2
CONDUCTOR; 39.2-119.2
Casing Intmdt - Pup; 38.5-41.1
HANGER; 39.4-39.5
HANGER; 38.1-38.5
HANGER; 34.5
NAK EXPLOR
KB-Grd (ft)
39.06
RR Date
4/19/2019
Other Elev
TINMIAQ 13
...
TD
Act Btm (ftKB)
4,050.0
Well Attributes
Field Name Wellbore API/UWI
501032078300
Wellbore Status
EXPLOR
Max Angle & MD
Incl (°)
0.61
MD (ftKB)
262.20
WELLNAME WELLBORETINMIAQ 13
Annotation
LAST WO:
End DateH2S (ppm) DateComment
SSV: NONE
OONFIDENTIALTop (ftKB)
p ( )
ftKB)
p
Item Des (in CoONFFIDDENTTIAL34.5 34.5 0.0 ANGER 10.880 Hanger, 4-1/2" x 10
TC-1A EMONFIDENTIALNFDNTNFDNTOCOOCCCC
Reviewed By:
P.I. Suprv
Comm ________
:ZϭϬͬϭϳͬϮϬϮϰ
/ŶƐƉĞĐƚEŽ͗ƐƵƐZEϮϰϬϴϮϵϬϵϰϵϱϳ
tĞůůWƌĞƐƐƵƌĞƐ;ƉƐŝͿ͗
ĂƚĞ/ŶƐƉĞĐƚĞĚ͗ϴͬϮϭͬϮϬϮϰ
/ŶƐƉĞĐƚŽƌ͗ŽďEŽďůĞ
/ĨsĞƌŝĨŝĞĚ͕,Žǁ͍'W^
^ƵƐƉĞŶƐŝŽŶĂƚĞ͗ϰͬϭϱͬϮϬϭϵ
η ϯϭϵͲϭϵϬ
dƵďŝŶŐ͗
/͗Ϭ
K͗Ϭ
KƉĞƌĂƚŽƌ͗ŽŶŽĐŽWŚŝůůŝƉƐůĂƐŬĂ͕/ŶĐ͘
KƉĞƌĂƚŽƌZĞƉ͗ĂŶZŝůĞLJ
ĂƚĞK'EŽƚŝĨŝĞĚ͗ϴͬϭϵͬϮϬϮϰ
dLJƉĞŽĨ/ŶƐƉĞĐƚŝŽŶ͗^ƵďƐĞƋƵĞŶƚ
tĞůůEĂŵĞ͗d/ED/Yϭϯ
WĞƌŵŝƚEƵŵďĞƌ͗ϮϭϴϭϰϰϬ
tĞůůŚĞĂĚŽŶĚŝƚŝŽŶ
tĞůůŚĞĂĚǁĂƐĨŽƵŶĚƚŽďĞŝŶŐŽŽĚĐŽŶĚŝƚŝŽŶ͘dŚĞƌĞǁĂƐƐŽŵĞďŝƌĚǁƌĂƉƚŚĂƚŶĞĞĚĞĚƌĞƉĂŝƌĂŶĚĂŶZŝůĞLJŚĂƐĐĂůůĞĚƚĞůůŝŶŐ
ŵĞƚŚĂƚŝƚŚĂƐďĞĞŶƌĞƉĂŝƌĞĚ͘
^ƵƌƌŽƵŶĚŝŶŐ^ƵƌĨĂĐĞŽŶĚŝƚŝŽŶ
'ŽŽĚĐůĞĂŶƚƵŶĚƌĂ͘
ŽŶĚŝƚŝŽŶŽĨĞůůĂƌ
^ŵĂůůĂŵŽƵŶƚŽĨĐůĞĂŶǁĂƚĞƌ͕
ŽŵŵĞŶƚƐ
^ƵƉĞƌǀŝƐŽƌŽŵŵĞŶƚƐ
WŚŽƚŽƐ;ϯͿĂƚƚĂĐŚĞĚ
^ƵƐƉĞŶƐŝŽŶƉƉƌŽǀĂů͗^ƵŶĚƌLJ
>ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚ͍
KĨĨƐŚŽƌĞ͍
&ůƵŝĚŝŶĞůůĂƌ͍
tĞůůďŽƌĞŝĂŐƌĂŵǀĂŝů͍
WŚŽƚŽƐdĂŬĞŶ͍
sZWůƵŐ;ƐͿ/ŶƐƚĂůůĞĚ͍
Ws/ŶƐƚĂůůĞĚ͍
dŚƵƌƐĚĂLJ͕KĐƚŽďĞƌϭϳ͕ϮϬϮϰ
9
9
9
9
9
9
9
9
2024-0821_Suspend_Tinmiaq-13_photos_bn
Page 1 of 2
Suspended Well Inspection – Tinmiaq-13
PTD 2181440
AOGCC Inspection Rpt # susRCN240829094957
Photos by AOGCC Inspector B. Noble
8/21/2024
2024-0821_Suspend_Tinmiaq-13_photos_bn
Page 2 of 2
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 333 W. 7th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99503
RE: Tinmiaq 13
Permit: 218-144
DATE: 05/10/2024
Transmitted:
NPRA, North Slope, Alaska
Tinmiaq 13
Via SFTP
Isotube Geochem analysis - Isotech
The enclosed data is from a well located on federal land (Federal Well Data).
This Federal Well Data is exploration well data that must be held confidential under AS 31.05.035(c) and 20 AAC 25.537(d).
This Federal Well Data also must be held confidential indefinitely (i.e., beyond two years) under 5 U.S.C. 552(b)(4) and (9).
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: Tinmiaq 13 - e-transmittal well folder
Receipt: Date:
Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
218-144
T38770
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.05.13 11:53:59 -08'00'
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
Well Log Information:
Digital
Med/Frmt ReceivedStart Stop
OH /
CH Comments
Log
Media
Run
No
Electr
Dataset
Number Name
Interval
List of Logs Obtained:GR/Res/CBL/Mud Log/ Den/Neu/Sonic/RSWC/MDT/CMR/FMI
YesYes YesMud Log Samples Directional Survey
REQUIRED INFORMATION
(from Master Well Data/Logs)
DATA INFORMATION
Log/
Data
Type
Log
Scale
C 7/3/201936 4050 Electronic Data Set, Filename: Tinmiaq 13
VISION_Service_RM_LAS_Dolomite.las
30956ED Digital Data
C 7/3/201936 4050 Electronic Data Set, Filename: Tinmiaq 13
VISION_Service_RM_LAS_LimeStone.las
30956ED Digital Data
C 7/3/201948 4006 Electronic Data Set, Filename: Tinmiaq 13
VISION_Service_RM_LAS_State of AK.las
30956ED Digital Data
C 7/3/201936 1836 Electronic Data Set, Filename: Tinmiaq 13
VISION_Service_RM_LAS_LWD001.las
30956ED Digital Data
C 7/3/20191712 3554 Electronic Data Set, Filename: Tinmiaq 13
VISION_Service_RM_LAS_LWD002.las
30956ED Digital Data
C 7/3/20193430 4050 Electronic Data Set, Filename: Tinmiaq 13
VISION_Service_RM_LAS_LWD003.las
30956ED Digital Data
C 7/3/201936 4050 Electronic Data Set, Filename: Tinmiaq 13
VISION_Service_RM_LAS_SandStone.las
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_RM_DLIS_Dolomite.dlis
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_RM_DLIS_Dolomite.html
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_RM_DLIS_LimeStone.dlis
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_RM_DLIS_LimeStone.html
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_LWD001_RM_DLIS.dlis
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_LWD001_RM_DLIS.html
30956ED Digital Data
Thursday, November 2, 2023AOGCC Page 1 of 12
Tinmiaq 13 ,q
VISION_Service_RM_LAS_State of AK.las
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_LWD002_RM_DLIS.dlis
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_LWD002_RM_DLIS.html
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_LWD003_RM_DLIS.dlis
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_LWD003_RM_DLIS.html
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_RM_DLIS_SandStone.dlis
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13
VISION_Service_RM_DLIS_SandStone.html
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq
13_MicroScope_30MD_RM_Image.pdf
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq
13_VISION_Service_RM_2_MD.pdf
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq
13_VISION_Service_RM_5_MD.pdf
30956ED Digital Data
C 7/3/2019 Electronic File:
Tinmiaq_13_VISION_Service_RM_2_TVD.pdf
30956ED Digital Data
C 7/3/2019 Electronic File:
Tinmiaq_13_VISION_Service_RM_5_TVD.pdf
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13 NAD27 ASP4 EOW
Compass Surveys [Canvas].txt
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13 NAD27 ASP4 EOW
Compass Surveys [Macro].txt
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13 NAD27 ASP4 EOW
Compass Surveys [Petrel].txt
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13 NAD27 ASP4 EOW
Compass Surveys [Surveys].txt
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13 NAD27 ASP4 EOW
Surveys.pdf
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13 NAD83 ASP4 EOW
Compass Surveys [Canvas].txt
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13 NAD83 ASP4 EOW
Compass Surveys [Macro].txt
30956ED Digital Data
Thursday, November 2, 2023AOGCC Page 2 of 12
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
C 7/3/2019 Electronic File: Tinmiaq 13 NAD83 ASP4 EOW
Compass Surveys [Petrel].txt
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13 NAD83 ASP4 EOW
Compass Surveys [Surveys].txt
30956ED Digital Data
C 7/3/2019 Electronic File: Tinmiaq 13 NAD83 ASP4 EOW
Surveys.pdf
30956ED Digital Data
C 7/3/20191795 3950 Electronic Data Set, Filename:
CPAI_Tinmiaq13_R1_FBST_SS_HNGS_Compos
ite_Main_Pass-Final.las
30957ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R1_FBST_SS_HNGS_Compos
ite_Main_Pass-Final.dlis
30957ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R1_5in_CALIPER_10Apr19_FI
NAL.Pdf
30957ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R1_5in_HNGS_SpectralGR_10
Apr19_FINAL.Pdf
30957ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R1_5in_SonicScanner_10Apr1
9_FINAL.Pdf
30957ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R1_60in_FMI_10Apr19_FINAL.
Pdf
30957ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R1_60in_FMI_ABDC_10Apr19
_FINAL.pdf
30957ED Digital Data
C 7/3/20193400 3956 Electronic Data Set, Filename:
CPAI_Tinmiaq13_R2_ZAIT_HRLT_PEX_Main_P
ass-Final.las
30958ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R2_ZAIT_HRLT_PEX_Main_P
ass-Final.dlis
30958ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R2_1in_PEX_Resistivity_10Apr
19_FINAL.Pdf
30958ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R2_2in_PEX_Resistivity_10Apr
19_FINAL.Pdf
30958ED Digital Data
Thursday, November 2, 2023AOGCC Page 3 of 12
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R2_2in_TCOM_10Apr19_FINA
L.Pdf
30958ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R2_5in_HRLA_10Apr19_FINA
L.Pdf
30958ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R2_5in_PEX_Porosity_10Apr1
9_FINAL.Pdf
30958ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R2_5in_PEX_Resistivity_10Apr
19_FINAL.Pdf
30958ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R2_5in_TCOM_10Apr19_FINA
L.Pdf
30958ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R2_5in_ZAIT_1D_Inversion_10
Apr19_FINAL.pdf
30958ED Digital Data
C 7/3/20193776 3950 Electronic Data Set, Filename:
CPAI_Tinmiaq13_R3_CMRT_ADT_NEXT_Log_4
_GR_TD_to3798ft-Final.las
30959ED Digital Data
C 7/3/20193483 3950 Electronic Data Set, Filename:
CPAI_Tinmiaq13_R3_CMRT_ADT_NEXT_Main_
Pass-Final.las
30959ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R3_CMRT_ADT_NEXT_Log_4
_GR_TD_to3798ft-Final.dlis
30959ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R3_CMRT_ADT_NEXT_Main_
Pass-Final.dlis
30959ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R3_5in_ADT_10Apr19_FINAL.
Pdf
30959ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R3_5in_CMR_10Apr19_FINAL.
pdf
30959ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R3_5in_NEXT_10Apr19_FINA
L.Pdf
30959ED Digital Data
Thursday, November 2, 2023AOGCC Page 4 of 12
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R3_5in_Temp_Log_10Apr19_F
INAL.Pdf
30959ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_L001Down_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_L004Up_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta001_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta002_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta003_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta004_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta005_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta006_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta007_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta008_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta009_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta010_MDT_EDTA-
Final.dlis
30960ED Digital Data
Thursday, November 2, 2023AOGCC Page 5 of 12
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta011_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta012_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta013_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta014_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta015_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta016_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta017_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta018_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta019_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta020_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta021_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta022_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta023_MDT_EDTA-
Final.dlis
30960ED Digital Data
Thursday, November 2, 2023AOGCC Page 6 of 12
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta024_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta025_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta026_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta027_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta028_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta029_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R04_Sta030_MDT_EDTA-
Final.dlis
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R4_MDT_11Apr19_FINAL.pdf
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R4_MDT_Insitu_Pretest_Table
_11Apr19.pdf
30960ED Digital Data
C 7/8/2019 Electronic File:
CPAI_Tinmiaq13_R4_MDT_Insitu_Sample_Sum
mary_11Apr19.pdf
30960ED Digital Data
DF 0 0 Electronic File: COPA_Willow_Tinmiaq-
13_8.5in_FE.pdf
30960ED Digital Data
C 7/3/20193656 3748 Electronic Data Set, Filename:
CPAI_Tinmiaq13_R5_L002Up_MSCT-Final.las
30961ED Digital Data
C 7/3/20190 27967 Electronic Data Set, Filename:
CPAI_Tinmiaq13_R5_Sta001_MSCT-Final.las
30961ED Digital Data
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R5_L002Up_MSCT-Final.dlis
30961ED Digital Data
Thursday, November 2, 2023AOGCC Page 7 of 12
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
C 7/3/2019 Electronic File:
CPAI_Tinmiaq13_R5_Sta001_MSCT-Final.dlis
30961ED Digital Data
C 7/3/2019 Electronic File: CPAI_Tinmiaq13_R5_XL-
Rock_Report_12Apr19_FINAL.Pdf
30961ED Digital Data
C 7/3/2019 Electronic File: CPAI_Tinmiaq13_R5_XL-
Rock_Core_Summary_Report_12Apr19_FINAL.p
df
30961ED Digital Data
C 7/9/2019110 4050 Electronic Data Set, Filename: Tinmiaq
13_Mudlog_RAW_Data_101_4050_ft.las
30966ED Digital Data
C 7/9/2019110 4050 Electronic Data Set, Filename: Tinmiaq
13_Mudlog_RAW_Data_110_4050ft.las
30966ED Digital Data
C 7/9/2019 Electronic File: LithLog - Tinmiaq 13.pdf30966EDDigital Data
C 7/9/2019 Electronic File: Tinmiaq 13 core chip
descriptions.xls
30966ED Digital Data
C 7/9/2019 Electronic File: Tinmiaq 13 Geological
Summary.doc
30966ED Digital Data
C 7/9/2019 Electronic File: Tinmiaq 13 sidewall core
descriptions.xls
30966ED Digital Data
C 7/9/2019 Electronic File: Tinmiaq 13 Wellsite Geology
Morning Report.xlsx
30966ED Digital Data
C 7/9/2019 Electronic File: Tinmiaq13 Geosurvey.xlsm30966EDDigital Data
C 7/9/2019 Electronic File: TINMIAQ-13_GEOLOG_Surface
Logging_End of well Report.doc
30966ED Digital Data
C 7/9/2019 Electronic File: TINMIAQ-13_GEOLOG_Surface
Logging_End of well Report.pdf
30966ED Digital Data
C 7/9/2019 Electronic File: DRILLING_LOG_1_INCH.pdf30966EDDigital Data
C 7/9/2019 Electronic File: DRILLING_LOG_2_INCH.pdf30966EDDigital Data
C 7/9/2019 Electronic File: DRILLING_LOG_5_INCH.pdf30966EDDigital Data
C 7/9/2019 Electronic File: GAS_RATIO_LOG_1_INCH.pdf30966EDDigital Data
C 7/9/2019 Electronic File: GAS_RATIO_LOG_2_INCH.pdf30966EDDigital Data
C 7/9/2019 Electronic File: GAS_RATIO_LOG_5_INCH.pdf30966EDDigital Data
C 7/9/2019 Electronic File: MUD_LOG_1_INCH.pdf30966EDDigital Data
C 7/9/2019 Electronic File: MUD_LOG_2_INCH.pdf30966EDDigital Data
C 7/9/2019 Electronic File: MUD_LOG_5_INCH.pdf30966EDDigital Data
Thursday, November 2, 2023AOGCC Page 8 of 12
Tinmiaq,q
13_Mudlog_RAW_Data_110_4050ft.las
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
C 7/9/2019 Electronic File: TINMIAQ 13 DRILLING LOG 1
INCH.tif
30966ED Digital Data
C 7/9/2019 Electronic File: TINMIAQ 13 DRILLING LOG 2
INCH.tif
30966ED Digital Data
C 7/9/2019 Electronic File: TINMIAQ 13 DRILLING LOG 5
INCH.tif
30966ED Digital Data
C 7/9/2019 Electronic File: TINMIAQ 13 GAS RATIO LOG 1
INCH.tif
30966ED Digital Data
C 7/9/2019 Electronic File: TINMIAQ 13 GAS RATIO LOG 2
INCH.tif
30966ED Digital Data
C 7/9/2019 Electronic File: TINMIAQ 13 GAS RATIO LOG 5
INCH.tif
30966ED Digital Data
C 7/9/2019 Electronic File: TINMIAQ 13 MUD LOG 1 INCH.tif30966EDDigital Data
C 7/9/2019 Electronic File: TINMIAQ 13 MUD LOG 2 INCH.tif30966EDDigital Data
C 7/9/2019 Electronic File: TINMIAQ 13 MUD LOG 5 INCH.tif30966EDDigital Data
C 8/29/20191750 3946 Electronic Data Set, Filename:
CPAI_Tinmiaq13_R7_USIT-CBL_Main-Final.las
31165ED Digital Data
C 8/29/20191750 3946 Electronic Data Set, Filename:
CPAI_Tinmiaq13_R7_USIT-CBL_Repeat-
Final.las
31165ED Digital Data
C 8/29/2019 Electronic File: WPSettings.dat31165EDDigital Data
C 8/29/2019 Electronic File: IndexerVolumeGuid31165EDDigital Data
C 8/29/2019 Electronic File: CPAI_Tinmiaq13_R7_USIT-
CBL_Main-Final.dlis
31165ED Digital Data
C 8/29/2019 Electronic File: CPAI_Tinmiaq13_R7_USIT-
CBL_Repeat-Final.dlis
31165ED Digital Data
C 8/29/2019 Electronic File:
CPAI_Tinmiaq13_R7_5in_CBL16Apr19_FINAL.P
df
31165ED Digital Data
C 8/29/2019 Electronic File:
CPAI_Tinmiaq13_R7_5in_USIT_Casing_16Apr19
_FINAL.Pdf
31165ED Digital Data
C 8/29/2019 Electronic File:
CPAI_Tinmiaq13_R7_5in_USIT_Cement_16Apr1
9_FINAL.Pdf
31165ED Digital Data
Thursday, November 2, 2023AOGCC Page 9 of 12
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
C 1/28/2020 Electronic File: T13_201901224-5019068330
Sample Quality Assessment Report.xlsx
31989ED Digital Data
C 1/28/2020 Electronic File: Tinmiaq13_RCAL_07-Jan-
2020.xlsx
31989ED Digital Data
C 1/28/2020 Electronic File: WPSettings.dat31989EDDigital Data
C 1/28/2020 Electronic File: IndexerVolumeGuid31989EDDigital Data
C 1/28/2020 Electronic File: 3553.0-3571.0.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 3553.0-3571.0uv.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 3571.0-3589.0.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 3571.0-3589.0uv.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 3589.0-3607.0.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 3589.0-3607.0uv.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 3607.0-3607.2.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 3607.0-3607.2uv.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 10R_3628.01.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 11R_3627.50.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 12R_3626.99.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 13R_3615.49.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 14R_3614.97.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 15R_3614.52.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 16R_3613.99.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 17R_3613.51.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 18R_3613.00.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 19R_3610.50.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 1R_3642.57.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 20R_3610.02.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 21R_3609.51.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 22R_3609.02.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 23R_3608.54.jpg31989EDDigital Data
Thursday, November 2, 2023AOGCC Page 10 of 12
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
C 1/28/2020 Electronic File: 24R_3604.98.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 25R_3604.51.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 26R_3604.08.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 27R_3603.52.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 28R_3603.00.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 29R_3602.47.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 2R_3642.06.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 30R_3602.01.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 31R_3601.52.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 32R_3599.48.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 33R_3599.02.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 34R_3598.52.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 35R_3598.03.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 36R_3597.52.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 37R_3596.98.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 38R_3596.56.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 39R_3595.96.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 3R_3641.56.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 40R_3595.52.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 41R_3595.02.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 42R_3594.52.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 4R-3640.99.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 5R_3640.46.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 6R_3635.05.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 7R_3631.97.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 8R_3628.87.jpg31989EDDigital Data
C 1/28/2020 Electronic File: 9R_3628.48.jpg31989EDDigital Data
C 1/28/2020 Electronic File: RSWC.zip31989EDDigital Data
DF 9/19/2023 Electronic File: T13_PVT_Redacted.pdf38002EDDigital Data
Thursday, November 2, 2023AOGCC Page 11 of 12
DATA SUBMITTAL COMPLIANCE REPORT
API No.50-103-20783-00-00Well Name/No.TINMIAQ 13
Completion Status SUSPCompletion Date 4/17/2019
Permit to Drill 2181440 Operator ConocoPhillips Alaska, Inc.
MD 4050 TVD 4050 Current Status SUSP
11/2/2023
UIC No
Well Cores/Samples Information:
ReceivedStart Stop Comments
Total
Boxes
Sample
Set
NumberName
Interval
INFORMATION RECEIVED
Completion Report
Production Test Information
Geologic Markers/Tops
Y
Y / NA
Y
Comments:
Compliance Reviewed By:Date:
Mud Logs, Image Files, Digital Data
Composite Logs, Image, Data Files
Cuttings Samples
Y / NA
Y
Y / NA
Directional / Inclination Data
Mechanical Integrity Test Information
Daily Operations Summary
Y
Y / NA
Y
Core Chips
Core Photographs
Laboratory Analyses
Y / NA
Y / NA
Y / NA
COMPLIANCE HISTORY
Date CommentsDescription
Completion Date:4/17/2019
Release Date:
DF 9/19/2023 Electronic File: T13_sample QA_PVT report.pdf38002EDDigital Data
4/11/20193553 3607 11714Core Chips
4/16/2019130 4050 41715Cuttings
Thursday, November 2, 2023AOGCC Page 12 of 12
M. Guhl
11/2/2023
MDT sample analysis received 9/19/2023, review complete 11/2/2023.
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 333 W. 7th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99503
RE: Tinmiaq 13
Permit: 218-144
DATE: 09/18/2023
Transmitted:
NPRA, North Slope, Alaska
Tinmiaq 13
Via SFTP
___Tinmiaq 13
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: Tinmiaq 13 - e-transmittal well folder
Receipt: Date:
Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
PTD: 218-144
T38002
9/19/2023
Kayla Junke
Digitally signed by Kayla
Junke
Date: 2023.09.19
09:59:57 -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 333 W. 7
th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99503
RE:: Tinmiaq 13
Permit: 218-144
DATE: 08/29/2023
Transmitted:
NPRA, North Slope, Alaska
Tinmiaq 13
Via SFTP
___Tinmiaq 13
Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: Tinmiaq 13 - e-transmittal well folder
Receipt: Date:
Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
218-144
added to T30960
delivered 7/08/2019
new 2023
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2023.09.05 11:00:30 -08'00'
From:Guhl, Meredith D (OGC)
To:Lemke, Sandra D
Cc:Elgarico, Richard E; Junke, Kayla M (OGC)
Subject:Tinmiaq 13, PTD 218-144, MDT fluid samples analyses and LAS
Date:Friday, July 7, 2023 7:32:00 AM
Hi Sandra,
I’m reviewing the data ConocoPhillips Alaska provided for Tinmiaq 13, PTD 218-144. An MDT log was
run, and 14 samples were taken, but I don’t have any analysis in the data for those samples. Also the
data set only has a DLIS file, no LAS file.
Could you please review ConocoPhillips’ records for Tinmiaq 13 and provide any required data not
yet supplied?
Thank you,
Meredith
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain
confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state
or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so
that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or
meredith.guhl@alaska.gov.
From:Sherry, Patrick F (LAW)
To:Guhl, Meredith D (OGC); Huber, Brett W (OGC); Wilson, Greg C (OGC); Chmielowski, Jessie L C (OGC)
Subject:Re: [EXTERNAL] Leases relinquished by ConocoPhillips
Date:Thursday, July 6, 2023 3:01:17 PM
Hi Meredith,
That is correct. Data can be released.
Thanks,
Pat
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Thursday, July 6, 2023 2:56:16 PM
To: Huber, Brett W (OGC) <brett.huber@alaska.gov>; Wilson, Greg C (OGC)
<greg.wilson@alaska.gov>; Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov>; Sherry,
Patrick F (LAW) <patrick.sherry@alaska.gov>
Subject: RE: [EXTERNAL] Leases relinquished by ConocoPhillips
Pat,
As I understand Judge Gleason’s ruling, the data from Tinmaiq 13 can now be released, as
ConocoPhillips no longer holds the NPRA lease the well is on. Please confirm if correct and I will
release the well history file and log data on 7/7.
Thank you,
Meredith
From: Guhl, Meredith D (OGC)
Sent: Thursday, July 6, 2023 1:35 PM
To: Huber, Brett W (OGC) <brett.huber@alaska.gov>; Wilson, Greg C (OGC)
<greg.wilson@alaska.gov>; Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov>; Sherry,
Patrick F (LAW) <patrick.sherry@alaska.gov>
Cc: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov>; Roby, David S (OGC)
<dave.roby@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC)
<victoria.loepp@alaska.gov>
Subject: RE: [EXTERNAL] Leases relinquished by ConocoPhillips
All,
I followed up with Rob Brumbaugh at the BLM today regarding the relinquishment of leases by
ConocoPhillips. The relinquishment is final as of April 13, 2023 (see attached PDF acceptance letter
and revised Exhibit A and B). Also attached is the original 2009 Bear Tooth Unit Agreement.
There is one CPAI well in suspended status on relinquished leases, Tinmiaq 13, PTD 218-144, SUSP
effective 4/17/2019. Although West Willow 1 and 2 are west of the Bear Tooth Unit, the two leases
the wells are on still show as active in the BLM ACRES system
(https://sdms.ak.blm.gov/acres/abstract/get_sernum). It appears there was perhaps a contraction
between 2009 and 2023 of the original Unit Area B, and re-leasing by ConocoPhillips, due to the
difference in lease numbers both past and current.
Blue numbers on map below are current BLM lease numbers. Orange boundaries denote leases pre-
relinquishment. Black outline is shape of Bear Tooth Unit post-relinquishment.
Please let me know if I can provide additional information.
Meredith
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain
confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state
or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so
that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or
meredith.guhl@alaska.gov.
From: Brumbaugh, Robert <rbrumbau@blm.gov>
Sent: Thursday, July 6, 2023 11:19 AM
To: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Cc: Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov>; Huber, Brett W (OGC)
<brett.huber@alaska.gov>; Wilson, Greg C (OGC) <greg.wilson@alaska.gov>
Subject: Re: [EXTERNAL] Leases relinquished by ConocoPhillips
Hello Meredeth,
Thanks for following up. Attached is the BLM's letter of approval and revised exhibits that are
referenced in the approval letter.
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.
----
Rob Brumbaugh
Oil and Gas Section Chief
BLM Alaska State Office
907-271-4429
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Thursday, July 6, 2023 11:05 AM
To: Brumbaugh, Robert <rbrumbau@blm.gov>
Cc: Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov>; Huber, Brett W (OGC)
<brett.huber@alaska.gov>; Wilson, Greg C (OGC) <greg.wilson@alaska.gov>
Subject: RE: [EXTERNAL] Leases relinquished by ConocoPhillips
Hello Rob,
Following up on the ConocoPhillips NPR-A lease relinquishment question I asked in March,
wondering if the process has been completed?
Thank you,
Meredith
From: Brumbaugh, Robert <rbrumbau@blm.gov>
Sent: Wednesday, March 22, 2023 11:42 AM
To: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Cc: Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov>; Huber, Brett W (OGC)
<brett.huber@alaska.gov>; Wilson, Greg C (OGC) <greg.wilson@alaska.gov>
Subject: Re: [EXTERNAL] Leases relinquished by ConocoPhillips
Hello Meredith,
I'm hoping to have the process completed in about 3-4 weeks. There is a lot to look at
including any unplugged exploration wells, lease segregations, unit contraction, etc.
----
Rob Brumbaugh
Oil and Gas Section Chief
BLM Alaska State Office
907-271-4429
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Wednesday, March 22, 2023 11:01 AM
To: Brumbaugh, Robert <rbrumbau@blm.gov>
Cc: Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov>; Huber, Brett W (OGC)
<brett.huber@alaska.gov>; Wilson, Greg C (OGC) <greg.wilson@alaska.gov>
Subject: [EXTERNAL] Leases relinquished by ConocoPhillips
This email has been received from outside of DOI - Use caution before clicking on links,
opening attachments, or responding.
Hello Rob,
I’m writing today to inquire when a list of leases relinquished by ConocoPhillips in NRP-A will be
available and when the relinquishment will be final. I understand this process can take some time,
we’re just looking to update our maps and evaluate if any of the drilled exploration wells fall on any
of the relinquished leases.
Thank you,
Meredith
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain
confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state
or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so
that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or
meredith.guhl@alaska.gov.
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:Brumbaugh, Robert
To:Guhl, Meredith D (OGC)
Cc:Chmielowski, Jessie L C (OGC); Huber, Brett W (OGC); Wilson, Greg C (OGC)
Subject:Re: [EXTERNAL] Leases relinquished by ConocoPhillips
Date:Thursday, July 6, 2023 11:19:28 AM
Attachments:BTU Acceptance Letter final.pdf
20230410 BTU Revised Exhibit A Exhibit B eff 20230317.pdf
Hello Meredeth,
Thanks for following up. Attached is the BLM's letter of approval and revised exhibits that are
referenced in the approval letter.
----
Rob Brumbaugh
Oil and Gas Section Chief
BLM Alaska State Office
907-271-4429
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Thursday, July 6, 2023 11:05 AM
To: Brumbaugh, Robert <rbrumbau@blm.gov>
Cc: Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov>; Huber, Brett W (OGC)
<brett.huber@alaska.gov>; Wilson, Greg C (OGC) <greg.wilson@alaska.gov>
Subject: RE: [EXTERNAL] Leases relinquished by ConocoPhillips
Hello Rob,
Following up on the ConocoPhillips NPR-A lease relinquishment question I asked in March,
wondering if the process has been completed?
Thank you,
Meredith
From: Brumbaugh, Robert <rbrumbau@blm.gov>
Sent: Wednesday, March 22, 2023 11:42 AM
To: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Cc: Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov>; Huber, Brett W (OGC)
<brett.huber@alaska.gov>; Wilson, Greg C (OGC) <greg.wilson@alaska.gov>
Subject: Re: [EXTERNAL] Leases relinquished by ConocoPhillips
Hello Meredith,
I'm hoping to have the process completed in about 3-4 weeks. There is a lot to look at
including any unplugged exploration wells, lease segregations, unit contraction, etc.
----
Rob Brumbaugh
Oil and Gas Section Chief
BLM Alaska State Office
907-271-4429
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Wednesday, March 22, 2023 11:01 AM
To: Brumbaugh, Robert <rbrumbau@blm.gov>
Cc: Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov>; Huber, Brett W (OGC)
<brett.huber@alaska.gov>; Wilson, Greg C (OGC) <greg.wilson@alaska.gov>
Subject: [EXTERNAL] Leases relinquished by ConocoPhillips
This email has been received from outside of DOI - Use caution before clicking on links,
opening attachments, or responding.
Hello Rob,
I’m writing today to inquire when a list of leases relinquished by ConocoPhillips in NRP-A will be
available and when the relinquishment will be final. I understand this process can take some time,
we’re just looking to update our maps and evaluate if any of the drilled exploration wells fall on any
of the relinquished leases.
Thank you,
Meredith
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain
confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state
or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so
that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or
meredith.guhl@alaska.gov.
United States Department of the Interior
BUREAU OF LAND MANAGEMENT
Alaska State Office
222 West Seventh Avenue, #13
Anchorage, Alaska 99513-7504
http://www.blm.gov
In Reply Refer to:
AA091675
(3137) 932
CERTIFIED MAIL
RETURN RECEIPT REQUESTED
ConocoPhillips Alaska, Inc.
Attn: Dennise Arzola
P.O. Box 100630
Anchorage, Alaska 99510
RE: Revised Exhibit A and Exhibit B, Bear Tooth Unit Agreement, BLM Lease No. AA091675;
CPAI No. 206223
Dear Ms. Arzola,
On April 13, 2023, the BLM-Alaska State Office received notice of revised Exhibit A and B
regarding the Bear Tooth Unit Agreement (BTUA) for ConocoPhillips Alaska, Inc. (CPAI).
Upon review by the BLM, Exhibits A and B are accepted and replace the original exhibits for the
updated BTUA.
Please provide a copy of the shapefile for Exhibit A that reflect the updated unit boundary and
leases.
For more information or if you have any questions or concerns regarding these matters, please
contact Robert Brumbaugh, Oil and Gas Section Chief, at (907) 271-4429 or
rbrumbau@blm.gov.
Sincerely,
Wayne M. Svejnoha
Chief, Branch of Energy and Minerals
Dennise Arzola
Senior Land Negotiator
Land & Business Development
P.O. Box 100630
Anchorage, AK 99510-0360
Office: 907-265-6297
Fax: 907-263-4966
dennise.arzola@cop.com
April 10, 2023
VIA ELECTRONIC MAIL (wsvejnoh@blm.gov)
Wayne M. Svejnoha
Branch Chief Energy and Minerals
United States Department of Interior
Bureau of Land Management
222 West 7th Avenue, #13
Anchorage, AK 99513
RE: Revised Exhibit A and Exhibit B
Bear Tooth Unit Agreement
BLM Lease No. AA-091675; CPAI No. 206223
Mr. Svejnoha:
Reference is made to the Bear Tooth Unit Agreement (“BTUA”) dated effective August 25, 2009.
Further reference is made to that certain letter dated March 17, 2023, wherein ConocoPhillips
Alaska, Inc. relinquished certain leases within the National Petroleum Reserve – Alaska, including
certain leases within the Bear Tooth Unit.
ConocoPhillips Alaska, Inc., as Unit Operator and sole Working Interest Owner of the Bear Tooth
Unit, hereby submits, pursuant to Section 3 of the BTUA a revised Exhibit A and a revised Exhibit
B to be attached to and made a part of the BTUA reflecting the current legal descriptions and
acreage subject to the BTUA as of March 17, 2023.
If you have any questions or need additional information, please contact me.
Regards,
CC: Rob Brumbaugh, Bureau of Land Management (Via Electronic Mail)
34
27
3
15
23
2
2
35
14
36
31
29
5
21
16
33
27
22
10
3
34
2
13
36
6
30
7
8
34
35
24
12
25
1
30
6
6
5
5
28
34
22
15
26
14
14
12
24
13
18
6
17
3
10
26
14
23
13
24
31
18
17
29
17
32
21
32
9
21
15
10
3
35
2
26
2
1
12
13
1
30
7 9
34
27
15
10
27
3
26
14
23
11
8 9
28
22
3
27
10
3
11
35
23
11
36
12
18
7
19
35
2
1
24
13
12
18
6
7
19
17
8
8
29
20
17
21
33
4
4
15
26
35
12
25
24
20
4
15
22
1
36
31
19
18
5
10
11
2
27
23
11
25
24
31
19
31
6
22
10
11
11
26
25
13
7
30
7
30
7
20
32
28
33
4
9
16
9
15
23
14
13
1
30
19
31
18
5
16
22
36
12
25
19
18
20
6
20
8
16
4
16
34
22
23
14
36
1
25
7
18
6
T10
N
,
R
2
W
,
U
M
T10
N
,
R
1
W
,
U
M
T10N, R2W, UM
T11N, R2W, UM
T10N, R2W, UM
T9N, R2W, UM
T9N, R1W, UM
T10N, R1W, UM
T9N
,
R
1
W
,
U
M
T9N
,
R
1
E
,
U
M
T9N, R1W, UM
T8N, R1W, UM
T9N
,
R
1
W
,
U
M
T9N
,
R
2
W
,
U
M
T11
N
,
R
1
E
,
U
M
T11
N
,
R
1
W
,
U
M
T11N, R1E, UM
T10N, R1E, UMT10N, R1W, UM
T11N, R1W, UM
T10
N
,
R
1
W
,
U
M
T10
N
,
R
1
E
,
U
M
T9N, R1E, UM
T8N, R1E, UM
T9N, R1E, UM
T10N, R1E, UM
T11
N
,
R
2
W
,
U
M
T11
N
,
R
1
W
,
U
M
T8N
,
R
1
W
,
U
M
T8N
,
R
1
E
,
U
M
AA081809
AA092673
AA081747
AA090710
AA081788
AA095291
AA081827
AA090708
AA081810
AA095288
AA081822
AA081807
AA095289
AA081787 AA095287
AA090711
AA094163
AA081825
AA094166
AA087891
AA094402 AA093931
AA093932
AA087898
AA081808
AA095290
AA092674
AA081824
AA081823
AA087899
AA095292
AA081746
AA090707
32
28
49
36
48
19
31
3534
33
40
17
29
26
21
20
25
39
27
22
46
45
444341
38
36
47
42
16
15
14
30
0 63
Miles¯3/29/2023
Bear Tooth Unit
Exhibit A
Effective March 17, 2023
Unit Boundary
CPAI Leases
Unit Tracts
Township & Range
Sections
Exhibit B
Bear Tooth Unit Agreement for the Exploration, Development, and Operation of the Bear Tooth Unit Area
Tract
No.Description of Lands Number of Acres Serial Number/Tobin
Number
Expiration
Date
Basic Royalty
Percentage
Basic
Royalty
Owner
Ownership
Percentage
Overriding
Royalty Owner
Overriding
Royalty
Percentage
Working Interest
Owner(s)
Ownership
Percentage
THERE ARE NO TRACTS 1 - 13
14 T11N-R2W, UM AA-081827 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 1: All 638.00 932562
Section 2: All 639.00
Section 3: All 639.00
Section 10: All 640.00
Section 11: All 640.00
Section 12: All 640.00
Section 13: All 640.00
Section 14: All 640.00
Section 15: All 640.00
Total 5756.00
15 T11N-R1W, UM AA-081747 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 4: All 640.00 953090
Section 5: All 640.00
Section 6: All 592.00
Section 7: All 595.00
Section 8: All 640.00
Section 9: All 640.00
Section 16: All 640.00
Section 17: All 640.00
Section 18: All 597.00
Total 5624.00
16 T11N-R1W, UM AA-081824 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 1: All 638.00 932559
Section 2: All 639.00
Section 3: All 639.00
Section 10: All 640.00
Section 11: All 640.00
Section 12: All 640.00
Section 13: All 640.00
Section 14: All 640.00
Section 15: All 640.00
Total 5756.00
Revised Effective 3/17/2023 1
Exhibit B
Bear Tooth Unit Agreement for the Exploration, Development, and Operation of the Bear Tooth Unit Area
Tract
No.Description of Lands Number of Acres Serial Number/Tobin
Number
Expiration
Date
Basic Royalty
Percentage
Basic
Royalty
Owner
Ownership
Percentage
Overriding
Royalty Owner
Overriding
Royalty
Percentage
Working Interest
Owner(s)
Ownership
Percentage
17 T11N-R1E, UM AA-081822 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 4: All 640.00 932557
Section 5: All 640.00
Section 6: All 592.00
Section 7: All 595.00
Section 8: All 640.00
Section 9: All 640.00
Section 16: All 640.00
Section 17: All 640.00
Section 18: All 597.00
Total 5624.00
THERE IS NO TRACT 18
19 T11N-R2W, UM AA-081825 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 22: All 640.00 932560
Section 23: All 638.00
Section 24: All 639.00
Section 25: All 639.00
Section 26: All 640.00
Section 27: All 640.00
Total 3836.00
20 T11N-R1W, UM AA-087891 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 19: All 600.00 307464
Section 20: All 640.00
Section 21: All 640.00
Section 28: All 640.00
Section 29: All 640.00
Section 30: All 603.00
Section 31: All 605.00
Section 32: All 640.00
Total 5008.00
Revised Effective 3/17/2023 2
Exhibit B
Bear Tooth Unit Agreement for the Exploration, Development, and Operation of the Bear Tooth Unit Area
Tract
No.Description of Lands Number of Acres Serial Number/Tobin
Number
Expiration
Date
Basic Royalty
Percentage
Basic
Royalty
Owner
Ownership
Percentage
Overriding
Royalty Owner
Overriding
Royalty
Percentage
Working Interest
Owner(s)
Ownership
Percentage
21 T11N-R1W, UM AA-087898 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 22: All 640.00 307471
Section 23: All 640.00
Section 24: All 639.00
Total 1919.00
22 T11N-R1E, UM AA-087899 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 19: All 600.00 307472
Section 20: All 640.00
Total 1240.00
THERE ARE NO TRACTS 23 & 24
25 T11N-R1W, UM AA-081746 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 33: All 640.00 953089
Total 640.00
26 T11N-R1W, UM AA-081823 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 25: All 639.00 932558
Section 26: All 640.00
Section 27: All 639.00
Section 34: All 639.00
Section 35: All 640.00
Section 36: All 640.00
Total 3837.00
27 T11N-R1E, UM AA-095289 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 30: All 603.00 367847
Section 31: All 605.00
Total 1208.00
Revised Effective 3/17/2023 3
Exhibit B
Bear Tooth Unit Agreement for the Exploration, Development, and Operation of the Bear Tooth Unit Area
Tract
No.Description of Lands Number of Acres Serial Number/Tobin
Number
Expiration
Date
Basic Royalty
Percentage
Basic
Royalty
Owner
Ownership
Percentage
Overriding
Royalty Owner
Overriding
Royalty
Percentage
Working Interest
Owner(s)
Ownership
Percentage
28 T10N-R2W, UM AA-094166 3/31/26 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 1: All 638.00 366607
Section 2: All 639.00
Section 3: All 640.00
Section 10: All 641.00
Section 11: All 641.00
Section 12: All 641.00
Section 13: All 640.00
Section 14: All 640.00
Section 15: All 641.00
T11N-R2W, UM
Section 34: All 640.00
Section 35: All 640.00
Section 36: All 640.00
Total 7681.00
29 T10N-R1W, UM AA-081810 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 4: All 640.00 932545
Section 5: All 640.00
Section 6: All 607.00
Section 7: All 611.00
Section 8: All 640.00
Section 9: All 640.00
Section 16: All 640.00
Section 17: All 640.00
Section 18: All 614.00
Total 5672.00
Revised Effective 3/17/2023 4
Exhibit B
Bear Tooth Unit Agreement for the Exploration, Development, and Operation of the Bear Tooth Unit Area
Tract
No.Description of Lands Number of Acres Serial Number/Tobin
Number
Expiration
Date
Basic Royalty
Percentage
Basic
Royalty
Owner
Ownership
Percentage
Overriding
Royalty Owner
Overriding
Royalty
Percentage
Working Interest
Owner(s)
Ownership
Percentage
30 T10N-R1W, UM AA-081808 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 1: All 639.00 932543
Section 2: All 640.00
Section 3: All 639.00
Section 10: All 640.00
Section 11: All 639.00
Section 12: All 640.00
Section 13: All 639.00
Section 14: All 640.00
Section 15: All 640.00
Total 5756.00
31 T10N-R1E, UM AA-095291 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 6: All 608.00 367848
Section 7: All 611.00
Section 18: All 613.00
Total 1832.00
32 T10N-R2W, UM AA-094163 3/31/26 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 22: All 641.00 366604
Section 23: All 641.00
Section 24: All 641.00
Section 25: All 641.00
Section 26: All 641.00
Section 27: All 641.00
Section 34: All 641.00
Section 35: All 641.00
Section 36: All 641.00
Total 5769.00
Revised Effective 3/17/2023 5
Exhibit B
Bear Tooth Unit Agreement for the Exploration, Development, and Operation of the Bear Tooth Unit Area
Tract
No.Description of Lands Number of Acres Serial Number/Tobin
Number
Expiration
Date
Basic Royalty
Percentage
Basic
Royalty
Owner
Ownership
Percentage
Overriding
Royalty Owner
Overriding
Royalty
Percentage
Working Interest
Owner(s)
Ownership
Percentage
33 T10N-R1W, UM AA-081809 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 19: All 615.00 932544
Section 20: All 640.00
Section 21: All 640.00
Section 28: All 640.00
Section 29: All 640.00
Section 30: All 619.00
Section 31: All 622.00
Section 32: All 640.00
Section 33: All 640.00
Total 5696.00
34 T10N-R1W, UM AA-081807 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 22: All 640.00 932542
Section 23: All 639.00
Section 24: All 640.00
Section 25: All 639.00
Section 26: All 640.00
Section 27: All 639.00
Section 34: All 640.00
Section 35: All 639.00
Section 36: All 640.00
Total 5756.00
35 T10N-R1E, UM AA-095292 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 19: All 616.00 367846
Section 30: All 619.00
Section 31: All 621.00
Total 1856.00
Revised Effective 3/17/2023 6
Exhibit B
Bear Tooth Unit Agreement for the Exploration, Development, and Operation of the Bear Tooth Unit Area
Tract
No.Description of Lands Number of Acres Serial Number/Tobin
Number
Expiration
Date
Basic Royalty
Percentage
Basic
Royalty
Owner
Ownership
Percentage
Overriding
Royalty Owner
Overriding
Royalty
Percentage
Working Interest
Owner(s)
Ownership
Percentage
36 T9N-R2W, UM AA-092674 10/31/20 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 1: All 640.00 341733
Section 2: All 640.00
Section 3: All 640.00
Section 10: All 640.00
Section 11: All 640.00
Section 12: All 640.00
Section 13: All 640.00
Section 14: All 640.00
Section 15: All 640.00
Total 5760.00
37 T9N-R1W, UM AA-092673 10/31/20 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 4: All 640.00 341732
Section 5: All 640.00
Section 6: All 626.00
Section 7: All 628.00
Section 8: All 640.00
Section 9: All 640.00
Section 16: All 640.00
Section 17: All 640.00
Section 18: All 631.00
Total 5725.00
38 T9N-R1W, UM AA-093932 2/28/25 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 2: All 641.00 347289
Section 3: All 641.00
Section 10: All 640.00
Section 11: All 640.00
Section 14: All 640.00
Section 15: All 640.00
Total 3842.00
39 T9N-R1W, UM AA-081788 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 1: All 640.00 932523
Section 12: All 640.00
Section 13: All 639.00
Total 1919.00
Revised Effective 3/17/2023 7
Exhibit B
Bear Tooth Unit Agreement for the Exploration, Development, and Operation of the Bear Tooth Unit Area
Tract
No.Description of Lands Number of Acres Serial Number/Tobin
Number
Expiration
Date
Basic Royalty
Percentage
Basic
Royalty
Owner
Ownership
Percentage
Overriding
Royalty Owner
Overriding
Royalty
Percentage
Working Interest
Owner(s)
Ownership
Percentage
40 T9N-R1E, UM AA-095290 8/31/09 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 6: All 624.00 367845
Section 7: All 626.00
Section 18: All 630.00
Total 1880.00
41 T9N-R2W, UM AA-090711 11/30/18 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 22: All 640.00 310092
Section 23: All 640.00
Section 24: All 640.00
Section 25: All 640.00
Section 26: All 640.00
Section 27: All 640.00
Section 34: All 640.00
Section 35: All 640.00
Section 36: All 640.00
Total 5760.00
42 T9N-R1W, UM AA-081787 8/31/19 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 19: All 632.00 932522
Section 20: All 640.00
Section 21: All 640.00
Section 28: All 640.00
Section 29: All 640.00
Section 30: All 635.00
Section 31: All 637.00
Section 32: All 640.00
Section 33: All 640.00
Total 5744.00
Revised Effective 3/17/2023 8
Exhibit B
Bear Tooth Unit Agreement for the Exploration, Development, and Operation of the Bear Tooth Unit Area
Tract
No.Description of Lands Number of Acres Serial Number/Tobin
Number
Expiration
Date
Basic Royalty
Percentage
Basic
Royalty
Owner
Ownership
Percentage
Overriding
Royalty Owner
Overriding
Royalty
Percentage
Working Interest
Owner(s)
Ownership
Percentage
43 T9N-R1W, UM AA-090710 11/30/18 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 22: All 640.00 310091
Section 23: All 640.00
Section 24: All 640.00
Section 25: All 640.00
Section 26: All 640.00
Section 27: All 640.00
Section 34: All 640.00
Section 35: All 640.00
Section 36: All 640.00
Total 5760.00
44 T9N-R1E, UM AA-095287 11/30/18 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 19: All 633.00 367844
Section 30: All 636.00
Section 31: All 639.00
Total 1908.00
45 T8N-R1W, UM AA-090708 11/30/18 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 4: All 640.00 310089
Section 5: All 640.00
Section 6: All 578.00
Section 7: All 581.00
Section 8: All 640.00
Section 9: All 640.00
Section 16: All 640.00
Section 17: All 640.00
Section 18: All 584.00
Total 5583.00
Revised Effective 3/17/2023 9
Exhibit B
Bear Tooth Unit Agreement for the Exploration, Development, and Operation of the Bear Tooth Unit Area
Tract
No.Description of Lands Number of Acres Serial Number/Tobin
Number
Expiration
Date
Basic Royalty
Percentage
Basic
Royalty
Owner
Ownership
Percentage
Overriding
Royalty Owner
Overriding
Royalty
Percentage
Working Interest
Owner(s)
Ownership
Percentage
46 T8N-R1W, UM AA-090707 11/30/18 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 1: All 640.00 310088
Section 2: All 640.00
Section 3: All 640.00
Section 10: All 640.00
Section 11: All 640.00
Section 12: All 640.00
Section 13: All 640.00
Section 14: All 640.00
Section 15: All 640.00
Total 5760.00
47 T8N-R1E, UM AA-095288 10/31/20 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 6: All 578.00 367843
Section 7: All 581.00
Section 18: All 584.00
Total 1743.00
48 T8N-R1W, UM AA-094402 3/31/27 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 20: N/2 320.00 366955
Section 21: N/2 320.00
Total 640.00
49 T8N-R1W, UM AA-093931 2/28/25 16.6667%U.S.100.00%None None ConocoPhillips 100.00%
Section 22: N/2 320.00 347288
Section 23: N/2 320.50
Total 640.50
Totals 133,130.50
Key: ConocoPhillips - ConocoPhillips Alaska, Inc. - Operator
U.S. - United States of America
Revised Effective 3/17/2023 10
CIE)-IL1q
ConocoPhillips
Alaska
July 7, 2021
Cord Feige, Commissioner
Alaska Department of Natural Resources (DNR)
State of Alaska
550 W. 7th Avenue, Suite 1400
Anchorage, Alaska 99501
corri.feige@alaska.gov
VIA EMAIL
John F. Schell, Jr.
VP, Strategy, Commercial, BD
& Land
P. O. Box 100360
Anchorage, AK 99510-0360
Phone 907.265.6022
Dr. Sara Longan, Deputy Commissioner
Alaska Department of Natural Resources (DNR)
State of Alaska
550 W. 7th Avenue, Suite 1400
Anchorage, Alaska 99501
sara.longan@alaska.gov
Re: Indefinite Confidentiality of All ConocoPhillips Alaska, Inc. Wells in the National Petroleum
Reserve — Alaska
Dear Commissioner Feige and Deputy Commissioner Longan:
ConocoPhillips Alaska, Inc. ("CPAI") greatly appreciates the continued careful consideration by the
Department of Natural Resources ("DNR") of our prior requests for recognition of indefinite confidentiality
of federal well data.' As you are aware, CPAI presently has 15 wells within the National Petroleum Reserve
— Alaska ("NPR -A") for which the data remains confidential:
Tinmiaq 7
501032076600
Tinmiaq 8
501032076700
Tinmiaq 9
501032076800
Tinmiaq 10
501032078000
Tinmiaq 11
501032078100
Tinmiaq 13
501032078300
Tinmiaq 15
501032078500
Tinmiaq 16
501032078600
Tinmiaq 18
501032081200
Tinmiaq 20 +PH1
501032081400/70
' CPAI respectfully requests that this letter be added to the record in Appeal No. 16-021, DNR's
consideration of CPAI's April 27, 2020 request for indefinite confidentiality, and other existing and future
matters regarding CPAI NPR -A Well Data confidentiality.
West Willow 1
501032076400
West Willow 2
501032078700
Rendezvous 3
501032068000
Stony Hill 1
501032076900
Harpoon 2
502872003000
(all data from the above wells, "CPAI NPR -A Well Data").
CPAI further appreciates that the Alaska Oil and Gas Conservation Commission ("AOGCC") continues to
hold CPAI NPR -A Well Data confidential until final adjudication by DNR and until any court appeal is
adjudicated and not appealable further.
In this regard, CPAI believes it would be useful to DNR and AOGCC to comprehensively set forth, as
provided for in the addendum attached to this letter, the reasons why CPAI NPR -A Well Data must be kept
confidential indefinitely under federal law. The addendum also includes an overview of state law
requirements that support extended confidentiality. We hope this information will be useful in DNR's
consideration of these issues.
As always, CPAI is willing to meet with DNR or AOGCC to discuss these matters further.
Sincerely,
9JoAFSchell, Jr.
VP, Strategy, Commercial, BD & Land
Addendum and Attachments
Cc via email:
AOGCC Commissioners Chmielowski, Seamount, and Price
c/o Samantha Carlisle, Executive Assistant(samantha.carlisle(o.alaska.gov)
Jody Colombie, AOGCC Special Assistant (jody.colombiera)-alaska.gov)
Tab Ballantine, Senior Assistant Attorney General (tab. ballantineCa.alaska.gov)
Tom Stokes, Director, DNR Division of Oil and Gas (tom.stokes a(,.alaska.gov)
John Ptacin, Chief Assistant Attorney General (john.ptacinaalaska.gov)
Dawn Crater, DNR Director of Appeals & Policy Implementation (dawn.crater(aalaska.gov)
Dominic Miocevic, Manager, Alaska Exploration (Dom.J.Miocevic(aconocophillips.com)
Ari Mitra, Greater Bear & Ops & Technology Manager(Ari.Mitra(a-conocophillips.com)
Jason Lyons, Staff Land Negotiator (Jason. Lyonsaconocophillips.com)
John Evans, Senior Counsel (iohn.r.evansO-)conocophillips.com)
ADDENDUM
SUMMARY OF FEDERAL AND STATE LAW REGARDING NPR -A WELL DATA
CONFIDENTIALITY
There are strong Alaska state law provisions and policies supporting well data confidentiality; however,
it is important to recognize that federal law requires authoritatively and unequivocally that CPAI NPR -
A Well Data must be kept confidential indefinitely.2 Congress expressly provided that this type of well
data from the NPR -A was to be held confidential and that any state law that provided for public access to
that information was expressly preempted.3 Any state employee that reveals confidential well information
in violation of this law is liable for damages.4
Congress expressly preempted contrary state law regarding the disclosure of CPAI NPR -A
Well Data from the NPR -A.
A. The federal statutes contain express preemption language.
The federal leases on which CPAI drilled these wells were issued pursuant to the Naval Petroleum
Reserves Production Act of 1976 (42 U.S.C. 6501 et seq.) ("NPRPA"), which transferred authority over the
NPR -A to the Secretary of Interior.5 Private petroleum exploration in the NPR -A was prohibited until 1980
when Congress, acting through a rider attached to an appropriations bill (Public Law 96-514) and "driven
by the fuel crisis of the previous decade, directed the Secretary to carry out an 'expeditious program of
competitive leasing of oil and gas' on the Reserve."6 In addition to appropriating more than $100 million to
facilitate this "expeditious program," Public Law 96-514 also added language to the NPRPA addressing
lessees' confidential exploration data.' Rather than reinvent the wheel regarding a statutory and regulatory
scheme to protect confidential exploration data, however, Public Law 96-514 incorporated the previously
developed statutes and regulations found in the Outer Continental Shelf Lands Act ("OCSLA").8
Specifically, Public Law 96-514 added the following language to the NPRPA:
Any agency of the United States and any person authorized by the Secretary may conduct
geological and geophysical explorations in the National Petroleum Reserve in Alaska
which do not interfere with operations under any contract maintained or granted previously.
Any information acquired in such explorations shall be subject to the conditions of 43
U.S.C. 1352(a) (1) (A),I91
2 All State agencies, including DNR, are required to follow federal law. See State, Dep't of Nat. Res. v.
Alaska Riverways, Inc., 232 P.3d 1203, 1221 (Alaska 2010) ("We hold that DNR's calculation of a lease fee
based on passenger count violates federal law and, consequently, .... [we] therefore vacate that portion
of the DNR leasing decision.").
3 See 42 U.S.C. § 6506a(m); 43 U.S.C. § 1352(a), (g).
4 See 43 U.S.C. § 1352(f).
5 N. Alaska Envtl. Ctr. v. Kempthorne, 457 F.3d 969, 973 (9th Cir. 2006).
6 Kempthorne, 457 F.3d at 973 (quoting 42 U.S.0 § 6508 (renumbered as 42 U.S.C. § 6506a)).
' See P.L. 96-514.
8 This incorporation was selective. OCSLA confidentiality terms were incorporated; other OCSLA terms
were not.
9 42 U.S.C. § 6506a(m) (emphasis added).
Title 43 U.S.C. 1352 (the "Confidential Information Statute") gives the federal government access to a
lessee's oil and gas exploration data and further mandates that "[s]uch data and information shall be
provided in accordance with regulations which the Secretary shall prescribe."10 It also directs the Secretary
to prescribe regulations to protect the confidentiality of the lessees' and permittees' data. I'
Subsection (g) of the Confidential Information Statute is entitled "Preemption of State Law by Federal Law,"
and it provides that "[a]ny provision of State or local law which provides for public access to any privileged
information received or obtained by any person pursuant to this subchapter is expressly preempted by the
provisions of this section, to the extent that it applies to such information."12 This is part of the same
subchapter that controls the treatment of information obtained from oil and gas exploration, and it is one of
the conditions of 43 U.S.C. 1352(a)(1)(A). As explained below, the applicable federal regulations confirm
that public disclosure of this confidential well data by a state agency is not permitted.
1. A decision to release CPAI NPR -A Well Data is expressly preempted
by federal law and would open the state up to significant civil liability.
Through Public Law 96-514 and the Confidential Information Statute, Congress expressly preempted any
contrary state law (including AS 31.05.035(c)) that purports to give the public access to CPAI NPR -A Well
Data. By incorporating the Confidential Information Statute into the NPRPA, Congress made clear that it
wanted to protect the confidentiality of data from lessees exploring in the NPR -A, including by expressly
preempting any contrary state laws or regulations. Congress intended NPR -A lessees' exploration data to
be kept confidential according to the regulations promulgated by the Secretary pursuant to the OCSLA.13
Congress also ensured that this prohibition would have "teeth" by making any state liable for civil damages
if a state employee reveals information (e.g., CPAI NPR -A Well Data) in violation of the confidentiality
regulations.14
The implementing regulations for the Confidential Information Statute (which is incorporated into the
NPRPA) contain detailed information about how a lessee must provide data to the federal government and
what sorts of protections the lessee's data will receive.15 The lessee is obliged to provide all data and
information obtained or developed from exploration activities for, or the development and production of, oil
and gas.16 The confidentiality protections are stringent: "Except as provided in [certain regulations that do
not apply here], no data or information determined by the Director to be exempt from public disclosure
under [the Freedom of Information Act ("FOIA") and certain other federal statutes and regulations] shall be
provided to ... the public unless the lessee ... agree[s] to such action."17 There is no serious dispute that
the CPAI NPR -A Well Data is exempt from public disclosure under FOIA Exemptions 4 (trade secrets) and
9 (geological and geophysical data concerning wells).18 Indeed, the federal government already confirmed
in the body of the leases that this data was "closed" to inspection by the public during the leases' term. It
10 See 43 U.S.C. § 1352(a)(1)(A).
11 See id. at 1352(c).
12 Id. at 1352(g) (emphasis added).
13 See 42 U.S.C. § 6506a(m); 43 U.S.C. §§ 1352(a)(1)(A), 1352(c); 30 C.F.R. § 252.1 et seq.
14 See 43 U.S.C. § 1352(f).
15 See 30 C.F.R § 252.1 et seq.
16 See id. § 252.3(a).
17 Id. § 252.6(b). The federal government has not determined that any of this information is available for
public disclosure at this time. To the contrary, the lease language specifically provides that any information
obtained is unavailable for public inspection during the term of the lease. See Attachment 1.
18 5 U.S.C. §§ 552(b)(4), (9).
2
is also undisputed that CPAI has not consented to the public disclosure of CPAI NPR -A Well Data.19
Accordingly, the CPAI NPR -A Well Data may not be provided to the public.
State agencies must abide by federal law regarding CPAI NPR -A Well Data on federal leases in the NPR -
A. Agencies must follow the express preemption language in the NPRPA that clearly displaces contrary
state laws and be cautious to avoid exposing the state to significant civil liability if CPAI NPR -A Well Data
is improperly disclosed. Further, given that the CPAI NPR -A Well Data contains significant information
relating to unleased land in the same vicinity as CPAI's NPR -A leases, it should be protected as confidential
for that reason alone. But even absent that information, CPAI NPR -A Well Data is entitled to confidential
treatment under governing federal law that preempts AS 31.05.035(c). Accordingly, DNR should recognize
that CPAI NPR -A Well Data are entitled to be kept confidential until the leases' terms end, unless CPAI
consents earlier to its publication.
2. A decision to release CPAI NPR -A Well Data would directly conflict
with federal law and impermissibly interfere with the accomplishment
of federal purposes.
In addition to the express preemption noted above, state law, including AS 31.05.035, is also preempted
under the separate legal test of conflict preemption. "[S]tate law is [] pre-empted to the extent it actually
conflicts with federal law, when it is impossible to comply with both state and federal law, or where the state
law stands as an obstacle to the accomplishment of the full purposes and objectives of Congress."20 Here,
disclosure of CPAI NPR -A Well Data would directly conflict with federal law, federal regulations, and the
federal leases. Disclosure also would clearly obstruct the accomplishment of Congress's purposes and
objectives.
a. Congress's intent is clear.
The policy statement informing the body of federal regulations addressing oil and gas leasing on the NPR -
A (43 C.F.R. 3130 et seq.) states that:
The oil and gas leasing program within the [NPR -A] shall be conducted in accordance with
the purposes and policy directions provided by the Department of the Interior
Appropriations Act, Fiscal Year 1981 (Pub.L. 96-514), and other executive, legislative,
judicial and Department of Interior guidance.["]
The purpose of Public Law 96-514 was to create an "expeditious program of competitive [private] leasing
of oil and gas in the" NPR-A.22 Congress's intent behind the creation of this program is exemplified by the
following discussion of Public Law 96-514's legislative history:
19 It is important to note that CPAI has consented to public disclosure of certain well data in other instances,
including where it determined that the data was of limited value or where CPAI had requested and received
tax credits that were conditioned on CPAI's willingness to disclose this data. This explains why some of
CPAI's other well data from NPR -A has been made public.
20 California Coastal Comm'n v. Granite Rock Co., 480 U.S. 572, 581 (1987).
21 43 C.F.R. § 3130.0-2.
22 Sovereign Inupiat for a Living Arctic v. Bureau of Land Mgmt., No. 3:20-CV-00290-SLG, 2021 WL
343925, at *8 (D. Alaska Feb. 1, 2021) (quoting P.L. 96-514) (alteration in original).
3
When Congress first enacted the NPRPA in 1976, only the federal government was
permitted to explore for petroleum, and the "production of petroleum" was generally
prohibited. A few years later, the nation experienced its second energy crisis of that decade,
the 1979 Oil Crisis, with 'oil prices beg[inning] to rise rapidly in mid-1979, more than
doubling between April 1979 and April 1980." In late 1980, Congress debated the future of
the government's inadequate exploration efforts and whether to open the NPR -A to private
oil and gas leasing and development. In December 1980, Congress added the rider to the
Department of Interior appropriations bill for the fiscal year ending September 30, 1981,
authorizing the "expeditious program of competitive [private] leasing of oil and gas in the
National Petroleum Reserve in Alaska[.]" Faced with a critical oil shortage and the federal
government's limited exploratory program, Congress likely opened the NPR -A to private
leasing and exploration and production in order to increase domestic oil supply as
expeditiously as possible.[23[
This legislative history makes clear that Congress intended to jumpstart private exploration on the NPR -A
by passing Public Law 96-514. The amendments Congress made to the NPRPA with Public Law 96-514
were critical to accomplishing this purpose. No private company would lease land in the NPR -A and begin
exploration activities without assurances that its data would be protected. Congress provided those
assurances through its amendment, which was eventually codified at 42 U.S.C. § 6506a(m), incorporating
by reference both the OCSLA's protections for confidential exploration data and the preemption of any
inconsistent state law.24 In so doing, Congress ensured that private companies' data would be protected
from public disclosure by states.
The body of regulations promulgated pursuant to the Confidential Information Statute crystalizes just how
important confidentiality was to Congress. In 30 C.F.R. § 252.1, which describes the Purpose of the
regulations, the regulation states that "this part establishes procedures for the Director to make available
certain information to the Governors of affected States and, upon request, to the executives of affected
local governments in accordance with the provisions of the Freedom of Information Act ["FOIA"] ...." In
Section 252.5, which describes information to be made available to the affected states, the regulation
provides that information will be provided to the state "in accordance with the requirements and subject to
the limitations of [FOIA] and implementing regulations." Section 252.6 provides the FOIA requirements for
data transmission, including by providing that "no data or information ... exempt from public
disclosure ... shall be provided to any affected State ... or to the public unless the lessee ... agree[s] to
such action." And finally, Section 252.7 again provides that any information provided to the states will be
kept confidential and provides for a civil cause of action available to the lessee if the information's
confidentiality is not protected. These regulations confirm the significant confidentiality protections to which
CPAI NPR -A Well Data is entitled.
This purpose is reiterated by the terms of CPAI's federal leases. The leases provide that CPAI NPR -A Well
Data will be kept confidential. CPAI's NPR -A wells are located on federal oil and gas leases wholly within
the NPR -A that are managed by the BLM. Geological and geophysical information and data obtained by
BLM from a lessee are subject to specific exemptions from the disclosure requirements of FOIA: 5 U.S.C.
§§ 552(b)(4) and (9). The NPR -A leases also specifically state that "[d]uring the existence of this lease,
23 Id. (quoting from and discussing P.L. 96-514's legislative history) (internal citations and footnotes
omitted).
24 See 30 C.F.R. § 252.1 et seq.
4
information obtained under this [section 5] shall be closed to inspection by the public in accordance with
the Freedom of Information Act."25
b. A decision to release CPA/ NPR -A Well Data would be preempted
because it would conflict with federal law and impermissibly interfere with
Congress's important objectives.
As explained above, Congress specifically intended to provide explicit protections for lessees' confidential
exploration data in NPR -A. Federal lessees, like CPAI, have relied on the confidentiality protections
provided by federal law and the federal leases in bidding on these leases and investing significant sums to
explore the NPR -A. This is exactly what Congress intended when it directed the Secretary to carry out an
`expeditious program of competitive [private] leasing of oil and gas' on the Reserve."26 Congress offered
confidentiality for valuable exploration data that private explorers generated in order to incentivize private
leasing and exploration in the NPR -A. Given Congress's desire to incentivize expeditious exploration of
NPR -A, it is clear that any state effort to disclose that confidential data to the public — thereby circumventing
Congress's protections and weakening those incentives —would create a direct conflict with federal law and
impermissibly interfere with Congress's intent and purposes.
A prior case is instructive. In 2001, the Alaska Permanent Fund Corporation requested an opinion from the
Office of Attorney General ("AG") regarding how the distribution of receipts from the NPR -A proceeds that
were deposited into the Permanent Fund should be calculated.27 The Alaska Constitution required that 25
percent of all receipts be deposited in the Fund. But, Public Law 96-514 provided that those communities
that are most directly impacted by oil and gas development in the NPR -A should be given funding priority.28
The AG determined that the Alaska Constitution was preempted by Public Law 96-514 because it conflicted
with federal law and because it impermissibly interfered with Congress's purposes. His analysis follows:
In this case, the Alaska Constitution requires an automatic deposit of twenty-five percent
of the total NPRA receipts into the Permanent Fund. But P.L. 96-514 requires that funding
priority for all of the NPRA receipts must be given to impacted communities. It is altogether
foreseeable that grants to impacted communities could exceed seventy-five percent of the
total NPRA receipts. In such case, it would be impossible to comply with both federal and
state law regarding distribution of the remaining twenty-five percent of the NPRA receipts.
Thus, there is a direct conflict between federal and state law.
Further, the state constitutional requirement of automatic deposit of NPRA receipts into the
Permanent Fund arguably stands "as an obstacle to the accomplishment and execution of
the full purposes and objectives" of P.L. 96-514 in that Congress intended that impacted
communities would get priority with respect to use of all of the NPRA receipts. The Alaska
Constitution interferes with the Congressional intent by instead giving the Permanent Fund
priority to a portion of the NPRA receipts.
25 See Attachment 1; see also Copper Valley Mach. Works, Inc. v. Andrus, 653 F.2d 595, 603 (D.C. Cir.
1981) (discussing, in the context of federal oil and gas leases in Alaska, the congressional intent behind
the terms included in federal leases issued pursuant to congressionally drafted statutes).
26 Kempthorne, 457 F.3d at 973 (quoting 42 U.S.0 § 6508 (renumbered as 42 U.S.C. § 6506a)).
27 No. File No.: 663-02-0012, 2001 WL 34396430, at *1 (Alaska A.G. Sept. 25, 2001).
28 Id. at *2.
5
... [W]e believe that the Alaska Constitution's requirement of automatic deposit of federal
mineral revenue sharing receipts into the Permanent Fund both obstructs and conflicts with
the federal requirement that priority for use of NPRA receipts be given to impacted
communities. Priority for the same money cannot be given for two different purposes.
Accordingly, P.L. 96-514 preempts the Alaska Constitution, and its requirement that 25
percent of NPRA receipts must be deposited in the Permanent Fund must give way to the
federal funding priority for impacted communities.
Moreover, in our view, under the frustration of purpose doctrine set forth above, federal law
preempts the Alaska Constitution even when there is enough NPRA receipts to go around.
This is because federal law requires a priority be given to impacted communities. This
priority is not mirrored in the Alaska Constitution and therefore the Alaska Constitution
arguably obstructs the purpose of and conflicts with federal law.[291
The same core analysis applies here. Congress's requirement and clear intention that NPR -A well data be
held confidential in order to incentivize exploration and production in NPR -A would be frustrated if the State
could freely disclose that same data, thereby undermining Congress's goal of encouraging private
development of federal land on federal leases.
A decision to release CPAI NPR -A Well Data would create a direct conflict with, and interfere with,
Congress's purposes. If the State makes CPAI NPR -A Well Data public, it cannot be made private again.
Its value is gone. And thus, the incentive Congress created to promote exploration of the NPR -A is similarly
gone. The State's interference would chill future exploration in the NPR -A. It would discourage private
leasing and private investment, which is exactly what Congress sought to attract and promote.
B. Forcing disclosure of the CPAI NPR -A Well Data without must compensation
would be impermissible under the "takings" clauses of the Alaska and U.S.
Constitutions.
Legal Standards
"Article I, section 18 of the Alaska Constitution provides: 'Private property shall not be taken or damaged
for public use without just compensation." 30 "The Fifth Amendment to the U.S. Constitution similarly
provides that private property shall not 'be taken for public use, without just compensation."'31 In determining
whether a taking has occurred, Alaska courts ask two questions: "(1) whether the claimant has a property
interest protected by the takings clause; and (2) if so, whether the government action in question effected
a taking of that property without just compensation."32 The Alaska Supreme Court discussed this test in
State, Department of Natural Resources v. Arctic Slope Regional Corporation33 ("ASRC"), a case
addressing whether the provision of AS 31.05.035 that allows DNR to review otherwise confidential data
29 Id. at "8.
30 Hageland Aviation Servs., Inc. v. Harms, 210 P.3d 444, 449 (Alaska 2009).
31 Pfeifer v. State, Dep't of Health & Soc. Servs., Div. of Pub. Assistance, 260 P.3d 1072, 1080 (Alaska
2011).
32 Id.
33 834 P.2d 134, 138 (Alaska 1991); see also Hageland, 210 P.3d at 449; Pfeifer, 260 P.3d at 1080.
as part of the process of obtaining extended confidentiality effected an unconstitutional taking of that
confidential data.
In ASRC, the court also answered the first question of the two -question inquiry for the purposes of CPAI
NPR -A Well Data, ruling that well data constitutes the oil companies' trade secrets and valuable property:
Since the value of the data depends on its secrecy and the companies obviously have
attempted to keep it secret we have no difficulty characterizing the data obtained by the oil
companies from the KIC well as trade secrets. We conclude that the information generated
by the KIC well is the property of the drillers.[341
Importantly, and as confirmed by Horne v. Department of Agriculture, the takings clause protects "private
property without any distinction between different types."35 Accordingly, CPAI NPR -A Well Data is CPAI's
valuable property that is protected by the takings' clause.
In answering the second question of the takings inquiry —whether a government action effects a taking —
courts first inquire into the character of the taking. Courts have differentiated between physical takings and
regulatory takings. A physical taking constitutes 'a permanent and exclusive occupation by the government
that destroys the owner's right to possession, use, and disposal of the property."36 The government may
effect a physical taking through occupation of real property or appropriation of private property —and both
are considered "per se" takings.37
The government may also affect a taking through regulation. A regulatory taking occurs when government
regulation "restricts the use of property or unduly burdens private property interests."38 "Regulatory takings
are subdivided into two categories: (1) categorical and (2) noncategorical."39 A categorical taking occurs
when all economically viable use —all economic value —has been taken by the regulatory imposition.40 Thus
.,when the owner of real [or private41] property has been called upon to sacrifice all economically beneficial
uses in the name of the common good, that is, to leave his property economically idle, he has suffered a
taking."42 "A categorical taking, like a permanent physical invasion of property, is deemed a per se taking."43
A regulatory taking is considered a noncategorical taking when it falls short of eliminating all economically
beneficial use of property.44 "A noncategorical taking is the 'consequence of a regulatory imposition that
34 ASRC, 834 P.2d at 139.
35 Horne v. Dept ofAgric., 576 U.S. 350, 358 (2015).
36 Cebe Farms, Inc. v. United States, 116 Fed. Cl. 179, 193 (2014).
37 See Horne, 576 U.S. at 361 (holding that the government's reserve requirement imposed by the Raisin
Committee was a clear physical taking when actual raisins were transferred from the growers to the
government).
38 Cebe Farms, Inc., 116 Fed. Cl. at 194.
39 Id.
40 See id.; see also Lucas v. S.C. Coastal Council, 505 U.S. 1003, 1015 (1992).
41 See Horne, 576 U.S. at 357 ("The first question presented asks 'Whether the government's 'categorical
duty' under the Fifth Amendment to pay just compensation when it 'physically takes possession of an
interest in property' applies only to real property and not to personal property.' The answer is no." (internal
citation omitted)).
42 Lucas, 505 U.S. at 1019.
43 Cebe Farms, Inc., 116 Fed. Cl. at 194 (emphasis in original).
44 See id.
7
prohibits or restricts only some of the uses that would otherwise be available to the property owners, but
leaves the owner with substantial viable economic use.1145 In determining whether a noncategorical taking
has occurred, courts examine three factors: "(1) the character of the government action, which includes
consideration of the legitimacy of the interest advanced by the action; (2) its economic impact; and (3) its
interference with reasonable investment -backed expectations."46 "Such a test for regulatory takings
requires a comparison of 'the value that has been taken from the property with the value that remains in
the property"147
In 1993, the Alaska Supreme Court adopted the framework discussed above in a case called Anchorage
v. Sandberg.46 In that case, the court noted that the United States Supreme Court "has recognized two
classes of per se takings: (1) cases of physical invasion and (2) cases where a regulation denies a
landowner of all economically feasible use of the property.1149 The court noted that when a case does not
fall into either of the categories of per se takings, the court will "engage in a case -specific inquiry to
determine whether governmental action effects a taking."50 The Alaska Supreme Court has also explained
that the Alaska Constitution's takings clause "must be interpreted generously in favor of the property
owner."51 The court has stated that "by requiring the state to pay when property is 'damaged,' and not just
when it is 'taken,' the clause offers Alaska property owners broader protection" than the federal takings
clause.52
2. Analysis:
a. CPAI NPR -A Well Data is a trade secret and CPAI's valuable personal
property.
As noted above, the law is clear that CPAI NPR -A Well Data is a trade secret and CPAI's valuable
property.53 DNR has previously conceded that drilling companies "possess property rights in the [well data]
specifically including the right to exclude the public from the enjoyment of such data by preventing its
disclosure."54 Instead, DNR argued that disclosure to it should be allowed because that was distinct from
disclosure to the public.55 The Alaska Supreme Court agreed and ultimately concluded that DNR's initial
review of the data under AS 31.05.035(c) did not constitute an unconstitutional taking.56 However, the court
expressly left open the question of whether such trade secret data could be disclosed to the public without
45 Id.
46 Hageland, 210 P.3d at 449-50; see also Cebe Farms, Inc., 116 Fed. Cl. at 195 (same); Penn Cent.
Transp. Co. v. City of New York, 438 U.S. 104, 124 (1978) (same).
47 Cebe Farms, Inc., 116 Fed Cl. at 195 (quoting Keystone Bituminous Coal Assn v. DeBenedictis, 480 U.S.
470, 497 (1987).
48 861 P.2d 554, 557 (Alaska 1993). Importantly, this case postdates the Alaska Supreme Court's decision
in ASRC, regarding oil companies' well data.
49 Id.
50 Id.
51 Tlingit-Haida Reg'I Elec. Auth. v. State, 15 P.3d 754, 764 (Alaska 2001).
52 Id.; see also id. at 764-65 ("[U]nder Alaska's takings clause, any state action that entirely denies a
property owner 'all the economically feasible use' of the owner's property amounts to a per se taking.").
53 ASRC, 834 P.2d at 139.
54 Id.
55 Id. at 139.
56 Id.
n.
compensation.57 The court went on to specifically distinguish its decision in ASRC from Noranda
Exploration, Inc. v. Ostrom, a Wisconsin Supreme Court decision that did address the public disclosure
question.58
In Noranda, the Wisconsin Supreme Court addressed whether a state statute requiring the public disclosure
of mineral exploration data resulted in a "taking" of trade secrets. The statute at issue required explorers to
disclose certain geographic data acquired while exploring for minerals. The statute further required that the
data would be publicly disclosed three years after its submission. A mineral exploration company
("Noranda") that had invested almost four million dollars over a seven-year period to acquire data related
to subsurface conditions challenged the statute.59
The court found that Noranda had a protectable property interest in the exploration data. The court also
found that the disclosure of confidential exploration data to the public at large bore no reasonable
relationship to legitimate government goals. The court concluded:
[T]his lack of rational relationship between the legislation's means and its goals is not cured
by the periods of confidentiality provided for. As the trial court found, the information that
is obtained has a continuing value as reference material in the explorer's "library," and: "the
information obtained by the explorer will have a negative value if turned over to the
explorer's competition; that is, disclosure will make the information available to the
competitor who will have to expend virtually no money to receive the information; and by
receipt of the disclosed information the competitor will be at a substantially more
competitive level without making a substantial outlay of capitol [sic]."[sod
The court went on to explain that it was the nature of the industry that neither the three-year nor the thirteen -
year period of confidentiality was adequate to ensure that the explorer retained the benefits which result
from the confidentiality of the information, since the ultimate benefit from the data might not be realized until
many years later.61
The court also noted that the case before it involved:
. . . the state's acquisition of a private citizen's property, and the distribution of that
property (after a period of confidentiality ends) to other private citizens for their benefit. In
such a case, the usual "police power" balancing analysis is not appropriate since the
government's acquisition of private property is in some ways more closely akin to a
permanent physical occupation of property which the U.S. Supreme Court has held is
always compensable. In Noranda's situation . . . a taking does not become a
noncompensable exercise of police power simply because the state allows the owner to
make some "reasonable" use of that property.[621
57 Id. at 144.
58 335 N.W.2d 596 (Wis. 1983).
59 Id. at 598-602.
so Id. at 604-05.
61 Id. at 605.
62 Id.
E
The court held that the provisions of the statute that required public disclosure of confidential mining
exploration data and core samples constituted an unconstitutional taking of private property without just
compensation.
The Noranda court's analysis and discussion of the issues surrounding public disclosure of well data are
instructive here. CPAI NPR -A Well Data is a trade secret and its valuable property. As in Noranda, there is
no reasonable relationship here between the public disclosure of CPAI NPR -A Well Data and any goals the
State might have supporting such disclosure. It follows that the CPAI NPR -A Well Data should continue to
be held confidential, and a failure to do so would subject the State to liability for the lost value of that data.
b. The disclosure of CPAI NPR -A Well Data would be a physical
appropriation of CPAI's property; a per se taking.
In Horne v. Department of Agriculture, the Court explained that the "classic taking [is one] in which the
government directly appropriates private property for its own use."63 The Court explained that a physical
taking occurs when personal property is appropriated the same as when real property is appropriated.64 If
DNR disclosed CPAI NPR -A Well Data to the public, it would effect a physical taking of CPAI's personal
property because DNR would have appropriated CPAI's personal property and distributed that property to
the public—i.e., CPAI's trade secrets would no longer be secret, and CPAI's rights of possession, use, and
disposal of its CPAI NPR -A Well Data would be forever destroyed.65
CPAI NPR -A Well Data constitutes its trade secrets and its valuable property.66 That data's value "depends
on its secrecy and [CPAI] obviously [has] attempted to keep it secret."67 CPAI made a significant investment
in its exploratory efforts in the NPR -A, it maintains the confidentiality of that data, and the CPAI NPR -A Well
Data has significant financial value that would be extinguished if it was made public.
In ASRC, the Alaska Supreme Court declined to apply the physical takings framework when the oil
companies had alleged that DNR's proprietary use of the well data provided to it by the oil companies
constituted a "physical invasion" of the companies' property.68 The court disagreed with the companies'
characterization of DNR's use of their well data.69 The court explained that "[t]his case does not involve the
kind of physical interference with real property at issue in the cases in which the United States Supreme
Court has found a per se taking."70 In an accompanying footnote, the court opined that "[w]e are unable to
comprehend how one can `physically' occupy or invade intangible property."71 Later in its opinion, the court
expressly distinguished Noranda, where the Wisconsin Supreme Court had held that compelled public
63 576 U.S. at 357.
64 Id. at 358.
65 Cebe Farms, Inc., 116 Fed. Cl. at 193.
66 ASRC, 834 P.2d at 139.
67 Id.
68 Id. at 142.
69 Id.
70 Id.
71 Id. Importantly, this dictum is no longer applicable given the Court's explanation in Horne regarding how
a physical taking can be accomplished by appropriation as well as by occupation. See Horne, 576 U.S. at
357-58 ("There is no dispute that the 'classic taking [is one] in which the government directly appropriates
private property for its own use."' (quoting Tahoe —Sierra Preservation Council, Inc. v. Tahoe Regional
Planning Agency, 535 U.S. 302, 324, (2002))).
10
disclosure of well data is a compensable taking.72 The court explained that the Noranda court had held that
public disclosure of well data was a compensable taking, and that public disclosure was not at issue in
ARSC.73 Two important differences between CPAI's case and the ASRC case require the application of the
physical takings framework here: (1) public disclosure is at issue here and (2) the United States Supreme
Court has since clarified that the physical takings analysis applies to appropriations of personal property
the same as it applies to occupation of real property.74
A physical taking occurs when the government appropriates private property for public use and in doing so
the owner is deprived of the property. 75 CPAI NPR -A Well Data is both its property and also a trade secret,
meaning that the value of the CPAI NPR -A Well Data is contingent on it remaining confidential. While CPAI
would still be able to access the CPAI NPR -A Well Data if it were disclosed to the public, its property interest
in the data would be extinguished due to the government's appropriation.76 The appropriation and public
disclosure of CPAI NPR -A Well Data would clearly constitute a per se physical taking for which just
compensation would be required.77
C. The disclosure of CPAI NPR -A Well Data, if required by state regulation,
would be a categorical regulatory taking; a per se taking.
While CPAI asserts that Alaska regulations support the continued confidentiality of CPAI NPR -A Well Data,
even if Alaska regulations required disclosure of CPAI NPR -A Well Data, they would be preempted for the
reasons described above, and if implemented to require disclosure of CPAI NPR -A Well Data to the public,
would constitute a categorical regulatory taking.
A categorical —per se —regulatory taking occurs when all economically viable use —all economic value —
has been taken by the regulatory imposition.78 Thus "when the owner of real [or private79] property has been
72 Id. at 144.
73 Id.
74 Horne, 576 U.S. at 357.
75 Id. at 360 ("a physical appropriation of property g[ives] rise to a per se taking").
76 A helpful analogy is a government taking of real property to build a public park or to allow a public right-
of-way. While the original owner of the real property can still access the property as it is now open to the
public, the owner's right to exclude others or dispose of the property as he or she wishes has been
extinguished. If CPAI NPR -A Well Data were made public, the same would be true. See Loretto v.
Teleprompter Manhattan CA TV Corp., 458 U.S. 419, 435 (1982) ("Property rights in a physical thing have
been described as the rights 'to possess, use and dispose of it."').
77 See Horne, 576 U.S. at 357 ("There is no dispute that the 'classic taking [is one] in which the government
directly appropriates private property for its own use."' (citation omitted)); Noranda, 335 N.W.2d at 605 "(.
. . the state's acquisition of a private citizen's property, and the distribution of that property (after a period
of confidentiality ends) to other private citizens for their benefit .... is in some ways more closely akin to a
permanent physical occupation of property which the U. S. Supreme Court has held is always compensable.
In Noranda's situation ... a taking does not become a noncompensable exercise of police power simply
because the state allows the owner to make some 'reasonable' use of that property." (emphasis added)).
78 See Cebe Farms, Inc., 116 Fed. Cl. at 194.; see also Lucas v. S.C. Coastal Council, 505 U.S. 1003, 1015
(1992).
79 See Horne, 576 U.S. at 357 ("The first question presented asks 'Whether the government's 'categorical
duty' under the Fifth Amendment to pay just compensation when it 'physically takes possession of an
interest in property' applies only to real property and not to personal property.' The answer is no." (internal
citation omitted)).
11
called upon to sacrifice all economically beneficial uses in the name of the common good, that is, to leave
his property economically idle, he has suffered a taking."80 "A categorical taking, like a permanent physical
invasion of property, is deemed a per se taking."S1
The Alaska Supreme Court has recognized a per se regulatory taking when a state action "entirely denies
a property owner'all economically feasible use' of the owner's property."82 In Tlingit-Haida Regional Electric
Authority, the court found a per se taking when the Alaska Public Utility Commission ("APUC") modified a
regional electric authority's certificate, disallowing it from providing power to Klawock, a rural Alaska village,
because the public would benefit from a cheaper option that was available.83 APUC's certificate modification
had the effect of denying the electric authority its use of its Klawock property previously utilized to provide
Klawock with electrical service. The court found a per se regulatory taking and ordered just compensation.84
Likewise, public disclosure of CPAI NPR -A Well Data would effect a per se regulatory taking of CPAI's
property. The public disclosure of CPAI NPR -A Well Data would convert it into public property, entirely
extinguishing its economic value to CPAI, resulting in a per se taking of CPAI's property that requires just
compensation.
d. Applying the factors for determining when a noncategorical regulatory
takings has occurred further demonstrates that public disclosure of CPAI
NPR -A Well Data would be a taking.
Courts weigh three factors in determining whether a government action effects a noncategorical regulatory
taking. Here, all three factors weigh in favor of finding a taking. Importantly, Alaska courts have
characterized the third factor —whether CPAI had a reasonable investment backed expectation that CPAI
NPR -A Well Data would be kept confidential —as the determinative factor.85 As applied to this case, the
third factor weighs most heavily of the three in favor of finding a taking of CPAI NPR -A Well Data.
(1) Releasing CPAI NPR -A Well Data would not advance a
legitimate government interest.
Factor one requires inquiry into the character of the government action, including weighing the legitimacy
of the interest advanced by the action.86 No legitimate reason exists for taking CPAI's trade secrets. In
ASRC, the court explained that the state had a legitimate interest in reviewing the oil companies' data to
inform the State's subsequent lease sales both to promote preservation of resources when necessary87
and to maximize profits when possible.88 But the court recognized both of these interests over "state land,"
which is not at issue here. The health and safety interests that support the State's review of well data have
80 Lucas, 505 U.S. at 1019.
81 Cebe Farms, Inc., 116 Fed. Cl. at 194 (emphasis in original).
82 Tlingit-Haida Reg'/ Elec. Auth. v. State, 15 P.3d 754, 765 (Alaska 2001).
83 Id.
84 Id. at 766.
85 ASRC, 834 P.2d at 139 ("As in Monsanto, we conclude that the determinative factor in this case is the
drillers' reasonable investment -backed expectation.").
86 Hageland, 210 P.3d at 449-50.
87 ASRC, 834 P.2d at 139 ("First, knowledge of the production potential of state land in various areas is
critical to DNR's determination of where development should occur and where preservation is
appropriate.").
88 See id. ("Second, knowledge of the oil and gas production potential of the state's lands promotes the
state's economic welfare by maximizing the amount it receives for the lease of its lands.").
12
nothing to do with the disclosure of that data to the general public. The State has no legitimate interest in
such action, especially since it frustrates the federal promise of confidentiality.89
Factor one weighs in favor of finding an unconstitutional taking.
(2) Publicizing CPAI NPR -A Well Data would have a significant
economic impact on CPAI.
CPAI NPR -A Well Data has significant economic value. This is self-evident. CPAI has invested tens of
millions of dollars exploring these portions of NPR -A, and if the data is publicly disclosed then CPAI's
competitors will receive the benefit of CPAI's enormous investments for free. CPAI will lose any advantage
it otherwise had from its years of labor and investments. The Alaska Supreme Court recognized this in the
ASRC case:
The superior court found that "the KIC well data allow the [companies] to evaluate the
potential for oil and gas development of the land surrounding the well and provide [them]
with a competitive advantage as to the valuation of these lands." The state does not argue
that such finding is clearly erroneous. Since the value of the data depends on its secrecy
and the companies obviously have attempted to keep it secret we have no difficulty
characterizing the data obtained by the oil companies from the KIC well as trade secrets.
We conclude that the information generated by the KIC well is the property of the drillers.1901
The value of CPAI NPR -A Well Data depends on its secrecy. If the CPAI NPR -A Well Data were publicly
disclosed, its value would be erased. This factor clearly weighs in favor of finding an unconstitutional
taking.91
(3) CPAI had a reasonable investment -backed expectation that the
CPAI NPR -A Well Data would remain confidential.
As explained above, the federal leases and federal law provide that CPAI NPR -A Well Data will remain
confidential. CPAI invested tens of millions of dollars to obtain its federal leases and the CPAI NPR -A Well
Data in reliance on the federal lease terms. CPAI also explicitly provided CPAI NPR -A Well Data to AOGCC
with a disclaimer that the data was being provided pursuant state and federal laws and lease terms that
required indefinite confidentiality of that data.92 CPAI clearly had a reasonable investment -backed
expectation that the CPAI NPR -A Well Data would remain confidential when it entered into federal leases
that specifically provided for confidentiality and when it drilled wells on those federal leases.
In ASRC, the court concluded that the oil companies did not have a reasonable investment -backed
expectation because "Alaska's oil conservation act and regulations contain no 'guarantee' or 'express
89 See Noranda, 335 N.W.2d at 604 ("We conclude that the disclosure of the confidential information to the
public at large bears no reasonable relationship to [a legitimate government interest]"); see also Anchorage
v. Sandberg, 861 P.2d 554, 557 (Alaska 1993) ("The legitimacy of the interest advanced by the regulation
or land -use decision is also relevant to [the takings] inquiry.").
90 ASRC, 834 P.2d at 138-39.
91 Compare Hageland, 210 P.3d at 450 (concluding that the economic impact factor was obviously met
when the appealing parties' property rights were eliminated by the government action).
92 See AS 31.05.035(d) (requiring well data voluntarily provided to AOGCC to be kept confidential); see,
e.g., Attachment 2.
13
promise' that DNR would not, upon review of the[] well data under AS 31.05.035(c), use the data for internal
departmental purposes.... Moreover, the companies were 'on notice' that DNR in fact used confidential
data filed under AS 31.05.035(c) in its decision making on state oil and gas leasing."93 But here, CPAI
reasonably relied on the supremacy of federal law and the durability of federal lease terms, both of which
confirm that the CPAI NPR -A Well Data will not be publicly disclosed.
This reasonable reliance is not affected by the CPAI's voluntary release of other NPR -A well data in the
past. First, several of these leases had expired before the data was released, after which the federal
promise of confidentiality was no longer in effect. Second, CPAI requested state exploration tax credits for
several of these wells (e.g., Scout #1, Spark #4, Pioneer and Grandview), and public disclosure of that data
was a condition to receipt of the credit imposed by the State.94 In other words, CPAI consented to the
disclosure of that information in exchange for certain tax credits. In other instances, CPAI has consented
to the disclosure of well data --even without obtaining any tax credits —because the data had negligible
value to CPAI. CPAI has not consented to any such disclosure here. Instead, CPAI reasonably relied on
the confidentiality afforded by federal law, by the federal lease language, and state law protections (AS
31.05.035(d)) when investing tens of millions of dollars in obtaining the CPAI NPR -A Well Data and sharing
this data confidentially with the State.
C. AS 31.05.035(d) requires DNR to maintain the confidentiality of CPAI NPR -A
Well Data that was voluntarily provided to AOGCC.
CPAI is required to submit CPAI NPR -A Well Data to the BLM in accordance with Section 5 of the federal
leases, and BLM is required to maintain the confidentiality of the CPAI NPR -A Well Data during the
"existence of [the] lease."95 CPAI accepted this promise of confidentiality when entering into the federal
leases. In an effort to allow overlapping state and federal regulations to be applied without conflict, CPAI
also provided the CPAI NPR -A Well Data to AOGCC, with express claims to indefinite confidentiality under
federal law.96
CPAI provides CPAI NPR -A Well Data to AOGCC in an effort to allow overlapping state and federal
regulations to work in harmony. When there are two overlapping regulatory or statutory schemes, it is
inevitable that conflict between them is possible.97 Keeping CPAI NPR -A Well Data confidential under AS
31.05.035(d) would avoid such a conflict. Federal law is clear that AOGCC is not empowered to require the
filing of reports that may be publicly disclosed for exploratory well data in NPR -A. CPAI may choose to
consent to the public disclosure of this information, either in exchange for certain tax credits (which are
contingent upon such consent) or because CPAI has determined that the data is of negligible value. If
CPAI so consents, then AS 31.05.035(c) establishes the timeline and terms for that public disclosure. If
93 ASRC, 834 P.2d at 140.
94 Each request for an exploration tax credit required ConocoPhillips to acknowledge the following:
In accordance with the requirements of AS 43.55.023, we, the undersigned, agree that all the
required data for the geophysical, geological, or well exploration project referred to ... above may
be provided to the State of Alaska. We acknowledge and understand that the data provided will
be publicly disclosed as part of the requirements under AS 43.55.023.
95 See Attachment 1.
96 See Attachment 2; CPAI also claimed indefinite confidentiality under AS 31.05.035 ("Engineering,
geological, and other information not required by (a) of this section but voluntarily filed with the commission
shall be kept confidential if the person filing the information so requests.").
97 See, e.g., State v. Dupier, 118 P.3d 1039, 1044 (Alaska 2005) (examining whether there was a conflict
for the purposes of preemption between state and federal laws regulating Alaska fisheries).
14
CPAI does not consent, then the information should be deemed to have been voluntarily filed with the
AOGCC for purposes of any public disclosure because the AOGCC cannot "require" the filing of data that
must be publicly disclosed in violation of federal law.98
D. The history and text of AS 31.05.035(c) provide support for an exercise of
discretion that aligns the state and federal approaches to well data
confidentiality for well data from federal lands.
It is entirely unclear whether AS 31.05.035(c) is supposed to apply to
federal lands.
AS 31.05.035(c) provides that reports and information required to be submitted to the AOGCC shall be held
confidential for 24 months following the 30-day filing period and may be held confidential for a longer period
"[i]f the commissioner of natural resources finds that the required reports and information contain significant
information relating to the valuation of unleased land in the same vicinity ...... A DNR regulation effective
March 30, 1984, provides in pertinent part that:
The commissioner will, in his or her discretion, extend confidentiality to reports or
information required under AS 31.05.035 from a well located more than three miles from
any unleased land if the owner of the well from which these reports or information are
derived makes a sufficient showing that the reports or information contain significant
information relating to the valuation of unleased land beyond the three-mile radius.1991
Prior to its adoption, there is nothing to suggest that this provision was contemplated to apply to federal
lands. In fact, the time limit concept embodied in AS 31.05.035(c) appears to have come from the initial
statute governing oil and gas leasing on state lands and included in the old DL-1 state lease form. The DL-
1 lease form was never applicable to federal lands, and nothing in its language or intent ever contemplated
application of this limited confidentiality concept to federal lands.
Prior Attorney General Opinions have examined the history of the 24-month confidentiality provision in AS
31.05.035.100 That particular Attorney General Opinion describes DNR as the agency "with expertise in
valuing unleased land" but does not address the issue of DNR's lack of authority regarding federal policy
and procedure for federal lands. To the contrary, in describing DNR's authority under AS 31.05.035, the
Attorney General Opinion states: AS 31.05.035 allows the Commissioner of Natural Resources to stay the
release of the information to the public if he finds that its release will significantly affect the value of unleased
state lands.101
Oddly enough, if this same proprietary geological data is submitted directly to DNR, DNR must hold all such
data confidential pursuant to AS 38.05.035(a)(9).102 In the normal course of events, only a state lessee
would submit proprietary geological data to DNR under this statutory confidentiality provision. This creates
a glaring ambiguity as to why DNR would be given authority to force disclosure through the AOGCC of data
from federal lands that (a) DNR has no access to otherwise; (b) DNR has no expertise on or authority over;
98 AS 31.05.035(d) (stating that engineering, geological, and other information "not required" by subsection
(a) shall be kept confidential if the person filing the information so requests).
99 11 AAC 83.153(a).
100 See, e.g., 1980 Op. Atty. Gen. Alas. No. 23.
101 Id. at 5 (emphasis added).
102 Id. at 4.
15
and (c) if obtained from state lands and submitted to DNR, that DNR would be prohibited from disclosing.
No legitimate state interest in such an action is discernible. If DNR's authority to force disclosure of
proprietary data is limited to state lands, over which DNR has authority and maintains expertise, as the
Attorney General Opinion cited above describes it, the ambiguity is resolved.
The Alaska Supreme Court recognized DNR's authority with respect to state land issues in the ASRC case:
DNR is responsible in large part for implementing the constitutional mandate that the
legislature "provide for the utilization, development, and conservation of all natural
resources belonging to the State . . . for the maximum benefit of its people. . . ."
The assessment of the state's oil and gas resources serves at least two legitimate
government objectives. First, knowledge of production potential of state lands in various
areas is critical to DNR's determination of where development should occur and where
preservation is appropriate.... Second, knowledge of the oil and gas production potential
of the state's lands promotes the state's economic welfare by maximizing the amount it
receives for the lease of its lands.[1031
It follows that DNR's expertise in valuing unleased land is an expertise in valuing unleased state lands; that
is, from the viewpoint of the state and for the benefit of the state. Valuing federal lands requires a different
perspective and analysis that is much broader and accounts for national policies. DNR has neither the
required expertise nor the authority to value federal lands or to make any other land management decisions
involving oil and gas leases for or on behalf of a federal land agency.
Indeed, the Alaska Legislature has recognized differences in DNR's role with respect to state and federal
lands before the AOGCC:
(a) The Department of Natural Resources shall have standing before the commission
to raise all issues relating to state-owned land without regard to the type of
proprietary interest held by the state in that land.
(b) With respect to federal land from which the state or any subdivision of the state is
entitled under federal law to receive a share of the federal royalty interest, the
Department of Natural Resources shall have the same standing before the
commission as if it were the holder of the equivalent royalty interest.[1041
The statute expressly provides that DNR has a broad role (i.e., standing to raise "all issues") with respect
to state-owned lands, while DNR serves as an indirect royalty owner with respect to federal lands.
Releasing confidential well data from federal lands (which is protected by federal law) would go far beyond
DNR's limited role with respect to federal lands.
2. DNR has discretion when interpreting a regulation to avoid conflicts
with BLM and to acknowledge changed circumstance over time.
The discussion above demonstrates that the extended confidentiality provisions of AS 31.05.035(c) were
focused on state lands and the potential impact of well data on state lands. To the extent that state agencies
103 ASRC, 834 P.2d at 143.
104 AS 31.05.026(a), (b) (emphasis added).
16
have some overlapping105 authority with BLM as to the confidentiality of CPAI NPR -A Well Data, state
agencies are obliged to carry out their statutory responsibilities in a way that "fully enforce the requirements
of its own statute, but must do so, insofar as possible, in a way that minimizes the impacts of its actions on
the policies of the other statute."106 "Furthermore, an administrative agency 'should be particularly careful
in its choice of remedy ... because of the possible effects of its decision on the functioning of [another
statutory policy]."'107 If there is the possibility for interfering with BLM's responsibilities, state agencies must
choose the approach that avoids or at least minimizes that interference.108 BLM has primary oversight
responsibility over federal leases on federal lands in NPR -A. BLM has expressly promised CPAI that the
CPAI NPR -A Well Data would be held confidential while the lease remained in effect. In order to avoid
disrupting BLM's confidentiality protections to federal lessees on federal lands, the state agencies should
interpret AS 31.05.035(c) to be limited to well data involving state lands.
It is also important to recognize that the regulation109 imposing a three-mile radius for the "significance"
threshold — under which the Commissioner may conclude that extended confidentiality is warranted
pursuant to AS 31.05.035(c) — was promulgated in 1984, when there was no active leasing and drilling in
the NPR -A by private lessees. To the east, the Kuparuk River Unit (all state land and state leases) was
barely two years in existence (December 1981) and the North Slope areas being explored through drilling
were for the most part on state lands and much closer to existing infrastructure. Many of the current
restrictions on exploration operations were not in place. State leases, which are restricted to much smaller
acreages (5,760 acres maximum size, per AS 38.05.180(m)) than federal leases within the NPR -A (60,000
acres maximum size, per 42 U.S.C. § 6506a), were the focus of DNR's attention. A three-mile radius may
not be sufficient when the lease size is more than ten times larger, the location is even more remote, and
the continued pressure to minimize "footprints" has increased costs commensurately.'10
The ability of the Commissioner to use her discretion to consider such factors is recognized by the Alaska
Supreme Court in Conoco Phillips v. State of Alaska, DNR.111 That case involved the question of whether
various oil companies were entitled to a discovery royalty rate in connection with oil produced from the
Midnight Sun Reservoir. In analyzing this issue, the Alaska Supreme Court discussed how technology and
perspectives change over time and how decisions and interpretations of statutes and regulations by the
Commissioner can appropriately reflect such change. The court specifically commented on the
Commissioner's interpretation of the Midnight Sun Reservoir and stated:
While recognizing that this broader approach might lead the department to reach different
results now that it reached in the past, the commissioner justified the differing outcomes
by emphasizing that 'our increased knowledge and ability to incorporate new information
has led us to a more sensible view of the geology and the role that the discovery royalty
program should play in North Slope exploration.' The Commissioner pointed to advances
105 The authority is not overlapping because, under the Supremacy Clause, BLM's federal law protections
for the CPAI NPR -A Well Data prevail over any inconsistent state law disclosure rights.
106 1996 Op. Atty. Gen. Alas. No. 3, at 38 (quoting N. Y. Shipping Assn v. Fed. Maritime Comm'n, 854 F.2d
1338, 1367 (D.C. Cir. 1988)).
107 Id. (quoting N.Y. Shipping Assn, 854 F.2d at 1370).
108 See id. at 40.
109 11 AAC 83.153(a).
110 For example, the federal land management agency for the Outer Continental Shelf (an area more
analogous to remote onshore North Slope exploration locations as far as cost and risk), provides for a 50-
mile radius in its consideration of confidentiality. See 30 C.F.R. 250.196(b)(6).
111 109 P.3d 914, 918 (Alaska 2005).
17
in data collection (e.g., 3-D seismic technology), to the establishment of industry
infrastructure that makes drilling wells easier and to the general development of the North
Slope as a mature oil province in the years since the program was established.0121
The court went on to state later in the decision that "[t]he crucial question, then, is whether this standard
describes a fixed and immutable test or a more flexible process — one grounded in the department's
exercise of discretion and expertise and having the capacity to evolve as contemporary scientific knowledge
advances."13
The statute and regulation at issue here would appear to be similarly affected by the changes that have
occurred in exploration and development on the North Slope.14 This is especially true in light of the fact
that the statute and regulation at issue were promulgated over 30 years ago, and changes in circumstances
(increased activity in very remote areas and on non -state lands, under more stringent environmental
requirements, all leading to higher costs and risks), technology, and law have occurred. In this case,
although technology has progressed since 1984, it has not commensurately reduced or mitigated the high
costs involved in obtaining remote NPR -A data —costs expressly recognized by Congress when passing
Public Law 96-514. The implications of what is "significant" with today's tools and what is the appropriate
"vicinity" must be considered and updated if this standard is to be applied outside of state lands. The
Commissioner should extend her discretion to consider factors that affect the significance of the data from
wells now being considered for extended confidentiality, including the federal position on confidential
protection for data from federal lands, and the high cost, remoteness, short operating seasons, and other
protective restrictions associated with the acquisition of the CPAI NPR -A Well Data, its value to CPAI, and
the effect of forced disclosure upon the competitive position of CPAI.
3. Principles of comity provide further support for an exercise of
discretion that aligns the state and federal approaches to
confidentiality for well data from federal lands.
In Younger v. Harris,15 the United States Supreme Court noted that the Framers rejected both "blind
deference to 'States' Rights"' as well as "centralization of control over every important issue in our National
Government ...." Instead, it found that the "notion of 'comity"' was central to the Framers' view of
Federalism, and "represents a system in which there is sensitivity to the legitimate interests of both State
and National Governments ...."16 In this system, each Government, as it seeks to "vindicate and protect
its rights and interests, [should] always endeavor[] to do so in ways that will not unduly interfere with the
legitimate activities" of the other."' This principle applies between the state and federal governments.
Principles of comity properly apply here, and an appropriate exercise of the Commissioner's discretion
would recognize these principles and align the state's approach with the federal approach to confidentiality
of CPAI NPR -A Well Data from federal leases. While the State is entitled to "vindicate its rights and
interests," those interests, as they may relate to well data from federal land, are not so compelling as to
12 Id. at 918-19.
113 Id. at 920.
114 The area of the North Slope now being explored in the NPR -A, however, certainly is not close to being
"a mature oil province."
115 401 U.S. 37, 44 (1971).
116 Id.
117 Id. Younger discussed comity in the context of whether federal courts had sufficient grounds to enjoin
an ongoing state criminal prosecution, but the underlying principle is the same.
18
require the State to refuse to respect the policy choice of the United States with regard to the confidential
treatment of that data. Accepting extended confidentiality for well data from NPR -A leases as a matter of
comity is essential to avoid "unduly interfer[ing] with the legitimate activities" of the federal government in
leasing NPR -A lands. State disclosure of CPAI NPR -A Well Data would undermine BLM's authority to
negotiate federal leases in NPR -A and otherwise promote oil and gas development on federal lands.18 If
the holders of federal leases cannot be assured that BLM's assurances of confidentiality will be respected
by Alaska's state agencies, it increases the risks and thus the costs of doing business in NPR -A as opposed
to another location — this would undermine both the State's and Congress's efforts to promote oil and gas
development.19 Even if DNR's and AOGCC's statutory authority extended far enough to enable them to
find that CPAI NPR -A Well Data may not be entitled to confidentiality under AS 31.05.035(c), this would
likely constitute an abuse of agency discretion.120 These agencies have alternatives to public disclosure of
this confidential CPAI NPR -A Well Data — including by finding that the data contain "significant information"
relating to the valuation of other unleased land or that the statute applies only to state lands —that do not
conflict with BLM's statutory responsibilities, the state agencies must choose one of those alternatives.12t
118 1996 Op. Atty. Gen. Alas. No. 3, at 40.
119 See id.
120 See id. at 41.
121 See id.
19
ATTACHMENT 1
SECTION 5 OF FEDERAL LEASES
Sec 5 Documents, esidence, and inspection t essee shaU file with the proper office of lessor, not later than 30 days
after effective date thereof, any contract or evidence of other arrangement for sale or disposal of pir ductwn At such
tames and to such form as lessor may prescribe. lessee shall fumcsh detailed statemaru showing anoints and quarry
of all products removed and sold, proceeds therefrom, and amount used for production purposes or unavoidably lost
Lessee may be required to provide plats and schematic diagrams stowing development work and improvements. and
reports with respect to parties in interest eupencbhues, and depreciation costs in the form presmbed by lessor, lessee
shall keep a daily drilling record, a log, information on well sur%eyz and tests, and a record of subsurface
investigations and fumrsh copies to lessor when required Lessee shall keep open at all reasonable times for inspection
by any autfhortxed officer of lessor, the leased pre ruses and all "is, improvernerrts, machinery, and fixtures thereon,
and all books, accounts. maps.. and records relative to operations, surveys, or tnvesbganorts on or to the leased lands
lessee shall maintain copies of all contracts. sales agreements accounting records. and documentation such as
billings, invoices. or strrular documentation that support costs claimed as manufactunng, preparation, andor
transportation costs All such records shall be maintained in lessee's accounting office for future audit by lessor
Less" shall maintain required records for 6 years after they are generated or, if an audit or investignm is underway.
until released of the obligation to maintain such records by lessor
Dunng existence of this lease, information obtained under this section shall be closed to inspection by the public in
accordance with the Freedom of Information Act (5 U S C 552)
20
ATTACHMENT
EXAMPLE WELL DATA TRANSMITTAL TO AOGCC (EXCERPT)
PRESERVING RIGHTS TO INDEFINITE CONFIDENTIALITY
Conn d"ihiillp5
TRANSMITTAL
CONFIDENTIAL DATA
FROM: Sandra D. Lemke, ATO-704
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage AK 99510-0360
RE: Stony Hill 1
Permit: 217-172-0
DATE: 07/03/2018
Waters Petroleum Mud log report -
Stony Hill 1 - field Core Report Final.pdf
�! Stony Hill 12MD lithology Log.pdf
Stony Hill 12TVD Lithology Log.pdf
Will
Stony Hill 15MD Lithology Log.pdf
Stony Hill 15TVD Lithology Logpdf
Stony Hill 1 Core Chip Description Report.xlsm
Stony Hill 1 Geological Summary.pdf
TO: Abby Bell
AOGCC
333 W. 71� Ave., Suite 100
Anchorage, Alaska 99501
The enclosed data is from a well located on federal land (Federal Well Data).
This Federal Well Data is exploration well data that must be held confidential under AS 31.05.035(c) and 20 AAC 25.537(d).
This Federal Well Data also must be held confidential indefinitely (i.e., beyond two years) under 5 U.S.C. 552(b)(4) and (9).
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra. D.Lemke( COA
CC: Stony Hill 1 - e-transmittal I folder
Receipt:_ Date:
Alaskaff-GGRE I ConocoPhillips Alaska I Office: 907 265.6947 Mobile 907 440.4512
21
2 18 144
31989
FROM: Sandra D. Lemke, ATO-704
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage AK 99510-0360
RE: Tinmiaq 13
Permit: 218-144
DATE: 01/29/2020
NPRA, North Slope, Alaska
Tinmiaq 13
USB drive
Name
ConociPhillips
TRANSMITTAL
CONFIDENT/AL DATA
RECEIVE
TO: Meredith Guhl
AOGCC
333 W. Th Ave., Suite 100
Anchorage, Alaska 99503
Transmitted:
Tinmiaq 13—Box Photos
Tinmiaq 13—RS7VVC photos
EP T1 32019012,24-5019063330 Sample Quality Assessment Report.xl,,-,,-
EP Tinmiaql 3_RCA L-07-Jan-2020.x1sx
----------------------folder details ---------
> T13 data Tinmiaq 13—Box Photos
Name
Size
14 3553.0-3571.0.jpg
221999
KB
[i]W 3553.0-3571.0uv.jpg
19,894
K8
3571.0-3589.0.jpg
20,371
KI3
3571.0-3589.0uvjpg
19fi06
KB
3589.0-3607.0.jpg
22;613
KE,
2.3, 5 3 9
K 6
36D7.0-3607.2.jpg
1,110
KB
D 3 607. C, - 3 607.2 uv.j p 9
1,087
KB
AN � 8 Zlii3
A 0 G IC-"? C/'
KC :m T1 3 data -- Tin niiaq 13-RSINC ph-os
1R_3W.57.jpq
Fq 2R-3642,06.jpg
[Q) 3R-3641.561pg
[4 411-3640,99.jp4
5R-3640,46.jpg
Ing 6R-3635.05,jpg
Fg 7R-3631.97.jpg
F191 8R-3628.37,jpg
FIRI 9R_3628.48jpq
Fio 1OR-3628.01jpg
[4 11R3627.50.jpg
�4112R_3626.99jpg
[4 13R3615,49.jp9
F4 14R3614.97.jpg
F4 15R3614.52.jpg
Fg 16R3613.99.jpg
F501 17R-3613.51.jpg
fi-01 18R_3613.00.jpq
19R3610.50,jpg
[1-01 2OR-3610.02.jpg
[4 21 R3609,51.j p g
[19-1 22R-3609,02,jpg
23R 3608.54,jpg
Liu] 24R3604.98.jpg
[idj 25R_3W4.51jpq
liol 26R - 3604.08.jpq
[i]W 27R_3603,52.jpg
[i]a 28R_3603,ODjpg
F4 29R_3602.47.1pq
[4 30R-3602.01jpg
[10] 31R3601.52.jpg
Fg32R_3599.49jpg
F4 33R3599.02.jpg
[1]2 34R3598,52.jpg
Fiial 35R3598.03.jpg
Fial 36R3597,52jpq
F4 37R_3596.98.jpq
[4 38R-3596.56,jpg
39R3595.96.1pg
4DR-3 595,52,j pg
41 R-3595.02,j p g
42R3594.52.jpg
RSWC.zip
The enclosed data is from a well located on federal land (Federal Well Data).
This Federal Well Data is exploration well data that must be held confidential under AS 31.05.035(c) and 20 AAC 25.537(d).
This Federal Well Data also must be held confidential indefinitely (i.e., beyond two years) under 5 U.S.C. 552(b)(4) and (9).
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra. Q. Lemke(dconoo2gh lips.com
CC: Tinmiaq 3 - e-transmittal well folder
Receipt: Date:
AlaskalIT-GGRE I Cono'c'Ormillps Alaska I Office: 907.265.6947; Mobile 907.440.4512
21 81 44
31 165
ConocoPhillips
TRANSMITTAL
CONFIDENTIAL DATA
FROM: Sandra D. Lemke, ATO-704 TO: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W. Th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99503
RE: Tinmiaq 13
Permit: 218-144
DATE: 07/03/2019
Transmitted:
NPRA, North Slope, Alaska
(Tinmiaq 13
USB drive
Tinmiaq 13 - WL_Cased Hole CBL data; 176 MB; 7 files; 4 folders
RECEWE®
AUG 2 9 2019
AOGCC
I he enclosed data is from a well located on federal land (Federal Well Data).
This Federal Well Data is exploration well data that must be held confidential under AS 31.05.035(c) and 20 AAC 25.537(d).
This Federal Well Data also must be held confidential indefinitely (i.e., beyond two years) under 5 U.S.C. 552(b)(4) and (9).
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemkenaconocoohi//ips.com
CC: Tinmiaq 13 - e-transmittal well folder
Receipt: Date:
Alaska/IT-GGRE I Cono Phillips Alaska I Office.- 907.265.6947; Mobile 907.440.4512
STATE OF ALASKA rs+�aCIDc I C�TI A
ALA, , OIL AND GAS CONSERVATION COMMISaiON I W N
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Abandon FXPlug Perforations ❑
Fracture Stimulate ❑
Pull Tubing ❑ Operations shutdown ❑
Performed: Suspend` Perforate ❑
Other Stimulate ❑
Alter Casing ❑ Change AD-oroved Program [�
Plug for Redrill ❑ 'erforate New Pool ❑
Repair Well ❑
Re-enter Susp Well ❑ Other:
2. Operator
ConocoPhillips Alaska, Inc.
4. Well Class Before Work:
5. Permit to Drill Number:
Name:
Development ❑
Exploratory ❑✓ 218-144
3. Address: P. O. BOX 100360, Anchorage, Alaska
Stratigraphic ❑
Service ❑ 6. API Number:
99510
50-103-20783-00-00
7. Property Designation (Lease Number):
8. Well Name and Number:
Tinmiaq 13
AA 081834
9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10.
Field/Pool(s):
Exploratory
11. Present Well Condition Summary:
Total Depth measured 4,050 feet Plugs
measured None feet
true vertical 4,505 feet
Junk
measured None feet
Effective Depth measured 4,050 feet
Packer
measured 3475 feet
true vertical 4,505 feet
true vertical 3,775 feet
Casing Length Size
MD
TVD Burst Collapse
Conductor 119 feet 16"
119' MD
119' MD
Surface 1,831 feet 9.5/8"
181' MD
1,831' MD
Production 4,050 feet 7"
4,050' MD
4,050' MD
Tubing (size, grade, measured and true vertical depth)
3.5 " 9.3#, L-80 EUE 3,516' MD 3,516' TVD
Packers and SSSV (type, measured and true vertical depth)
Packer - Baker Premier 3,475' MD 3,775' TVD
SSSV
N/A N/A
12. Stimulation or cement squeeze summary: N/A
Intervals treated (measured): N/A
Treatment descriptions including volumes used and final pressure:
N/A
13.
Representative Daily
Average Production or Injection Data
Oil-Bbl
Gas-Mcf
Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: -
Subsequent to operation: -
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
15. Well Class after work:
Daily Report of Well Operations 2
Exploratory 0
Development ❑ Service ❑ Stratigraphic ❑
Copies of Logs and Surveys Run ❑
16. Well Status after work:
Oil ❑ Gas ❑ WDSPL ❑
Printed and 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:
319-190
Contact Name: Sara Carlisle / Rachel Kautz
Authorized Name: jS t
Authorized Title: Well Integrity & Compliance Specialist
Contact Email: N2549@conocophillips.com
Authorized Signature: ��� 0"-Date:
— I Z— Contact Phone: 907-659-7126
96DMS �AUG 2 7 2019
Form 10-404 Revised 4/2017 � � ` /
Submit Original Only
CONFIDENTIAL
Conoco'Phillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 12th, 2019
Commissioner Jessie Chmielowski
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Re: Suspended Well Inspection 10-404 Sundry for Tinmiaq 13 (PTD 218-144)
Commissioner Chmielowski,
Enclosed please find the initial suspended well inspection documentation as required by
20 AAC 25.110 for ConocoPhillips Alaska, Inc. well Tinmiaq 13 (PTD 218-144).
The following documents are attached:
- 10-404 Sundry
- Suspended Well Check List
- Wellbore Schematic
- Location Plot Plan
- Photographs
The well continues to be held for future development of the area.
Please contact Rachel Kautz or me at 659-7126 if you have any questions.
Sincerely,
G+n w cw•r Klt/
Sara Carlisle
Well Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
Suspended Well Site Inspection Form
Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness
Well Name: Tinmiaq 13 Field/Pool: Exploratory
Permit # (PTD): 218-144 API Number: 50-103-20783-00-00
Operator: ConocoPhillips Alaska, Inc.
Surface Location: 32' FNL 1706' FWL Section
Nearest active pad or road: N/A
Take to Location
Digital camera
Brief well history
Latest Sundry or Completion report
Past Site Visit documentation
Pressure gauges, fittings, tools
35
Date Suspended: 4/15/2019
Township: 12N Range: 2W
Meridian: Umiat
Map showing well location /Aerial photos
Wellbore diagram showing downhole condition
Site clearance documentation
Sample containers for fluids on or near pad
Condition of Surface Location AOGCC requires:
1) a description of the condition of the surface location, including discoloration, fluids or sheens visible
on the ground or in any nearby water,
2) photographs showing the condition of the location surrounding the well
General location condition: Clean tundra
Pad or location surface:
Location cleanup needed:
Pits condition:
Clean tundra
None
N/A
Surrounding area condition: Clean tundra
Water/fluids on pad: Natural standing water, clean
Discoloration, Sheens on pad, pits or water: None
Samples taken: None
Access road condition: N/A
Photographs taken (# and description): 3 aerial photographs of wellhead and surrounding tundra.
Condition of Wellhead AOGCC requires:
1) a description of the condition of the wellhead, 2) well pressure readings, where practicable,
3) photographs showing the wellhead condition
Wellhead/tree/valve description, condition: Tree and wellhead wrapped with herculite. Looked
throuoh small ooenina in liner - clean and dry tree/wellhead.
Cellar description, condition, fluids: Steel cellar. Clean standing water below grating.
Rat Hole: N/A
Wellhouse or protective barriers: Inner bird barrier, outer herculite wrap tied with banding and rope.
Well identification sign: Visibly hung & in good condition.
Tubing Pressure (or casing if no tubing): Not accessible, tubing has BPV installed.
Annulus pressures: Not accessible, IA and OA have VR plugs installed.
Wellhead Photos taken (# and description): 2 photos, front and back of wrapped well.
Work Required: None
Operator Rep (name and signature): Sara Carlisle 2. cot:�Juw
AOGCC Inspector: Matt Herrera Waived Withess Other Observers: N/A
Inspection Date: 10-Aug-19 AOGCC Notice Date: 7-Jul-19
Time of arrival: 9:41 am Time of Departure: 9:48am
Site access method:
NAK EY- ORVELLNAME TINMIAQ 13
COno4hilli s Well Attributes
Field Name Wellbore API/UWI Wellbore Status
Alaska, Inc. NORTH ALASKA TIGHT HOLE 501032078300 EXPLOR
Comment HIS (ppm) Date Annotation
SSV: NONE LAST WO:
WELLBORE 'NMIAQ 13
Max Angle & I- TD
Vcl (°) MD (ftKB) Act Bum (ftKB)
262.20 4.050.0
End Date I KB-Grd (I I Rig Release Date
39.06 4/19/2019
TINMIAQ 13, 9Y11/20191:09:18 PM
Last Tag
Vertical schematic (actuaq
Annotation
Depth (ftKB)
End Date
Wellbore
Last Mod By
HANGER, 34.5
LAST TAG:
JTINMIAQ
13 Ijennalt
Last Rev Reason
Annotation
End Date
Wellbore
I Last Mod By
REV REASON: New Exploration Well
6/1/2019 JTINMIAQ
13
liennalt
...........................................................
....................................................
.n CONDUCTOR; 39,2-119.2
2 NIPPLE; 496
.
SURFACE; 39A-1,931.1
GAS LIFT; 3,255.9
NIPPLE; 3,314.4
NIPPLE', 3, 366.6
GAUGE; 3,419.E
PACKER, 3.475.5
NIPPLE; 3,SD3.7
MULE SHOE; 3.515 0-
PRODUCTION: 38.14,044.0
.................
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
Dim,
15.25
Top (ftKB)
39.2
Set Depth (ftKB)
119.2
Set Depth (TVD)
119.2
(,,, WtlLen (I...
62.50
Grade
H-40
Top Connection
Casing Description
SURFACE
OD (in)
95/8
ID (in)
8.84
Top (ftKB)
39.4
Set Depth (ftKB)
1,831.1
Set Depth (TVD)
1,831.0
(... WtlLen (I...
40.00
Grade
L-80
Top Connection
TXPM
Casing Description
PRODUCTION
OD (in)
7
ID (in)
6.28
Top (ftKB)
38.1
Set Depth INKS)
4'044.0
Set Depth (TVD)
4,043.9
(... WtlLen (L..
26.00
Grade
L-80
Top Connection
TXP-m
Tubing Strings
Tubing Description Suing Me... ID (in) Top (ftKB) Set Depth (ft... Set Depth (TVD) if... Wt (Iblft) Grade Top Connection
UPPER COMPLETION 31/2 2.91 34.5 3,515.5 3,515.4 9.30 L-80 I EUE-m
Completion Details
Top (ftKB)
Top (TVD)
(ftKB) Top
Incl (°)
Item Des
Core
Nominal
ID (in)
34.5
34.5
0.03
HANGER
Hanger, 4-1/2" x 10-3/4" Gen 5, FMC TC-lA EMS
3.920
67.3
67.3
0.18
XO REDUCING
Crossover 4-1/2" IBT-m x 3-1/2" EUE
2.992
496.2
496.2
0.46
NIPPLE
Nipple, Camco, 2.875" IDS, 2.906" No-go, SN:T021908 (??° hole
angle)
2.875
3,314.4
3,314.3
0.09
NIPPLE
Nipple, HES, 2.813" X Profile, SN:21605-08 (??° hole angle)
2.813
3,366.6
3,366.5
0.09
NIPPLE
Nipple, HES, 2.813" X Profile, SN:21605-07 (??° hole
angle)
2.813
3,418.6
3,418.6
0.09
GAUGE
Gauge Carrier, SLB, SGM with Sapphire tubing pressure gauge,
SN:Cl8GM 0399
2.992
3,475.5
3,475.4
0.08
PACKER
Packer, Baker 3 1/2" x 7" Premier
2.870
3,503.8
3,503.7
0.07
NIPPLE
Nipple, HES, 2.813" XN, 2.75' No-go,SN:21605-06 (RHC plug
installed)
2.813
3,515.0
3,514.9
0.07
MULE SHOE
Baker Fluted WLEG (Wire line entry guide)
3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD) Top
(ftKB)
Incl
V)
Des
Co. Run
Date
ID (in)
VR
plug - IA #1
4/17/2019
VR
Plug - IA #2
4/17/2019
VR
Plug - CA
4/17/2019
Mandrel Inserts
St
"I
N Top (ftKB)
Top (TVD)
(ftKB)
Make
Model
OD (in)
S.,
Valve
Type
Latch Port
Type
Sire
(in)
TRORun
(psi)
Run Date
Com
1 3,255.8
3,255.8
CAMCO
KBMG
1
GAS LIFT SOV
DCK-2 1
14/19/2019
Notes: General & Safety
End Date
Annotation
6/1/2019
NOTE: View Schematic w/ Alaska Schematic10.0
NOTES:
1. WELL LOCATION COORDINATES ARE NAD83,
ALASKA STATE PLANE ZONE 4 PROVIDED
BY OTHERS ON 08/21 /2018.
2. DISTANCES ARE TRUE. ALL DISTANCES
ARE IN US SURVEY FEET.
TINMIAQ
13
LOCATED WITHIN PROTRACTED
SECTION 35, T. 12 N., R 2 W.
UMIAT MERIDIAN, ALASKA
32' FNL 1706'
FWL
NAD83 Datum
NAD 27 Datum
N 70°21'27.40"
N 70'21'28.72"
W 152'19'48.80"
W 152'19'37.36"
ASPIC ZN4
ASPIC ZN4
(Y) 5,985,729
(Y) 5,985,987
(X) 1,353,576
(X) 213,543
N
0 200
SCALE IN FEET
willp
DRAINAGE
(TYP)
low
CO
*. 49 TH * I
......................
KENNETH J. PINARD.'
No. 11545 i
�tt PR�FESSIONA��A�..?'
arm-
fg
r �
� �
_;ate
. �
INV
� �
T ',. �•�
NMI
DIM,
0
6p0
� r
•� Y d
o / PREVAILING
WIND ^
2pp p
a
0 _....... 200
UMIAQ Design & Municipal SCALE IN FEET
Services, LLC 1 AECL1316
CONOCOPHILUPS OF ALASKA, INC.
KUUKPIK TINMIAQ 13
U I Q PROPOSED PAD LAYOUT
ALPINE, ALASKA
ALPINE SURVEY OFFICE PHONE : 907-670-0739 DATE: 10/09/20 8 7DRAWN BY: CZ SHEET: 1
SCALE: 1" = 200' 1 CHECKED BY: SZ W.O. No: 18-08-21-1
o!§0
U- H .2 g
j O
0 o ? 3
o 6 N 2.
r -V =r
rD �osUj
N
fD - O '9
-o
v' v O
N D o NJ
Q N .O -
O < 00
N a
OQ F
o A
C 7 ,may A
O n (b
� Q
N
fD Q
Q
C�r�r�o�hili s
ftLEf?@VE@TRANSMITTAL
CONF/DENT/AL DATA , o �n
FROM: Sandra D. Lemke, ATO-704 TO: Meredith Guhl AWL Af
ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W. 71h Ave., Suite 100 AOW
Anchorage AK 99510-0360 Anchorage, Alaska 99501
RE: 2019 Drilling Season Directional Surveys
Permit: 218-141
DATE: 07/09/2019
Transmitted:
11 North Slope, NPRA, Alaska
I USB
redistribution of final directional surveys for 2019 drilling season. Schlumberger version delivered with logging data
package for these wells was missing ZONE 5 Coordinates required by AOGCC.
inw.��1D- 216-1y0 T3o5G9
Tinmiaq 10, 11, 13, 15, 16, West Willow 2
NAD27 ASP4 'T1nYv\. al e'142 T3D-11 g
NAD27 ASP5 �'n i3 _ 216-IyN
NAD83 ASP 4
NAD83 ASP 5 �-:
T 30e'D
1(�'2-to-1y
W
I he enclosed data is trom a well located on federal land (Federal Well Data)
This Federal Well Data is exploration well data that must be held confidential under AS 31 05.035(c) and 20 AAC 25.537(d)
This Federal Well Data also must be held confidential indefinitely (i e , beyond two years) under 5 U S C 552(b)(4) and (9)
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra. D.Lemke0conocophilli
pi.
com
CC: Tinmiaq 10 - nsmittal well folder --7
Receipt: Date: t �' I
Alaska/IT-GGRE I Cono ip5 Alaska I Office: 907.265. 6947,E Mobile 907, 440. 4512
0710
a CO 3.0 q - m O
w w 3 3 3 31 3. o 3 3 3. 3 3 <O
- 1 �.
Q uj w U' w w w w u� 1 1 1 D D C7 (n
o. Gy "j 9 7 I- Ir Im w w � 1 A W n O O= 7
a m a' `a a-v CD O `o O CD 0 n�
1p '* C a= Q a 61 a, p O O O
!D 2 ko 7 in cc CO X
1/I .Z CD 1
C) 6n O N m 0- 0 D O CD
C p' n Ln 3] C L � w -N 3
3 `< 0 C v � D SD
61
¢ v
f7l En D
a o' x m C L O
D W = O LO
CDV
X CD CD .A
� m O
F a n�
0
cn
6 �J
oZ
o
Z(
Lj L UN EN �s�, fin, N EN DE El �a, � �. I' � (D �
r
3 3 L" Iv' rt r �
cli Di �
-Z- N J D w
I�" I ' IIlGJy' IIGr,l IGj� Ir rr (DD
CQ ID �DQIIQ 0 0 w Cy D
c c Z C3 C1 Q IGS m Li mm m r & ra - J v+ 0)
C C� #!r■
O 9 T I S IIG) IGG] I n II ' I_a r r t' `t'
tI,O tIC3 '� .0 -0 I I I z Z Z Q > D .�' .���. .�-., 3 CD D C
—— n n n � s s
L 0. n n n T T 2 Ic Ic D m
m
T T = T3 e3 is =1, acn , "
i3 i3
9 a ro
r�ro j
rD
I IJ 4l0 '" C CI7 1
L 0- 0—
Ib #jam� le • cn—e �' e� rn O O
Q Lo LO w O
m m r
x' �x
I j j !lf m R
C1 Cl
w O O ,
In cuPo 710
m m N O r
��.a M
CD
Lo
�� w n o rnCD
LOW
c�
2
(
R
c (A
\ \
� 2
0
W
\
E
7�
»
n
LO
CO
M
RECEIVED
JUL 032019
C
AOGC
FROM: Sandra D. Lemke, ATO-704
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage AK 99510-0360
RE: Tinmiaq 13
Permit: 218-144
DATE: 07/03/2019
Cono coPhilli
TRANSMITTAL
,CONFIDENTIAL DATA
TO: Meredith Guhl
AOGCC
333 W. 7ch Ave., Suite 100
Anchorage, Alaska 99503
Transmitted:
F*Limestone/Dolomite/Sandstone
orth Slope, Alaska
PW Gg23PQfrGn
Vision Service Log Images: 3 0 95 6
TVD
cope
LW
ision Service Log digital data
ata *Limestone/Dolomite/Sandstone RM data
LAS
Directional survey NAD27/NAD83
Wireline Open Hole run 1: FMI-MSIP-HNGS Log Images
5" Caliper
5" HNGS Spectral-GR
5" sonic scanner
60" FMI
60" FMI ABDC
Wireline Open Hole run 1: FMI-MSIP-HNGS digital data
DLIS/LAS
Wireline Open Hole run 2: ZAIT-HRLA-PEX Log Images
1, 2 &5" PEX Resistivity
5" PEX Porosity
2&5" TCOM
5" HRLA
5" ZAIT 1 D Inversion
Wireline Open Hole run 2: ZAIT-HRLA-PEX digital data
DLIS/LAS
30 95 7
30958
218144
Wireline Open Hole run 3: CMR-ADT-NEX T Log Images 30 9 5 9
5" ADT
5" CMR
5" NEXT LithoScanner
5" Temperature
Wireline Open Hole run 3: CMR-ADT-NEX T digital
DLIS/LAS
Wireline Open Hole run 4 - MDT Log Images 30
9 5 O
CD MDT
l0 Wireline Open Hole run 4 - MDT Log digital
Insitu MDT pretest table
C
10 Insitu MAD sample summary
dDLIS
Wireline Open Hole run 5 - XL -ROCK Log Images 30 96 1
v_l IIXL Rock report
tD Wireline Open Hole run 5 - XL -ROCK digital
v� XL -Roc - Core Summary report; DLIS/LAS data
0
M
Wireline cased hole Cement CBL Log Images
5" CBL
5" USIT casing
5 "Usit cement
Wireline cased hole Cement CBL digital
DLIS/LAS data
DM LWD Field data
WL OH Run 1: FMI-MSIP-HNGS, run 2 ZAIT-HRLA-PEX, run 3 CMR-NEXT-ADT, run 4 - MDT, run 5 XL -Rock
WL Cased hole - run 7Cement CBL
The enclosed data is from a well located on federal land (Federal Well Data).
This Federal Well Data is exploration well data that must be held confidential under AS 31.05.035(c) and 20 AAC 25.537(d).
This Federal Well Data also must be held confidential indefinitely (i.e., beyond two years) under 5 U.S.C. 552(b)(4) and (9).
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.Q.Lemke(a)conocophi//ips.com
CC: Tinmiaq 13 - e-transmittal well folder
Receipt: 4 4 'UL Date:
(�Wlq
Alaska/IT-GGRE I d9coPhIllIps Alaska I Office: 907.265.6947; Mobile 907.440.4512
M =v Lm I V N'W U�-
MAY 16 2019
STATE OF ALASKA CONFIDENTIAL
ALASKA OIL AND GAS CONSERVATION COMMISSION
'CL�COMPLETION OR RECOMPLETION REPORT AND LOG
1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0
20AAC 25.105 20AAC 25.110
GINJ ❑ WINJ ❑ WAGE WDSPL ❑ No. of Completions:
1b. Well Class:
Development ❑ Exploratory 0
Service ❑ Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Aband.: 4/17/2019
14. Permit to Drill Number / Sundry:
218-144/319-190
3. Address:
P.O. Box 100360 Anchorage, AK 99510 0360
7. Date Spudded:
4/1/2019
15. API Number:
50-103-20783-00-00
4a. Location of Well (Governmental Section):
Surface: 32' FNL, 3573' FEL, Sec 35, T12N, R2W, UM
Top of Productive Interval:
23' FNL, 3585' FEL, Sec35, T12N, R2W, UM
Total Depth:
23' FNL, 3585' FEL, Sec 35, T12N, R2W, UM `
8. Date TD Reached:
4/8/2019
16. Well Name and Number:
Tinmiaq 13
9. Ref Elevations: KBA48 •
GL: 121 ' BF:
17. Field / Pool(s):
EXPLORATORY
10. Plug Back Depth MD/TVD:
3960/3960
18. Property Designation:
AA081834
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 705961 y- 5983340 Zone- 5
TPI: x- 705949 y- 5983348 Zone- 5
Total Depth: x- 705949 y- 5983348 - Zone- 5
11. Total Depth MD/TVD:
4050/4050
19. DNR Approval Number:
N/A
12. SSSV Depth MD/TVD:
N/A
20. Thickness of Permafrost MD/TVD:
939/939
5. Directional or Inclination Survey: Yes I] (attached) No ❑
Submit electronic and printed information per 20 AAC 25.050
13. Water Depth, if Offshore:
N/A (ft MSL)
21. Re-drill/Lateral Top Window MD/TVD:
N/A
22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days
of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential,
gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and
perforation record. Acronyms may be used. Attach a separate page if necessary
GR/Res/CBUMud Log/Den/Neu/Sonic/RSWC/MDT/CMR/FMI
PEx,TCOMr 14CLAr, ZPtr r XL/20Uc
111(.3 It
23. CASING, LINER AND CEMENTING RECORD
CASING
WT. PER
FT
GRADE
SETTING DEPTH MD
SETTING DEPTH TVD
HOLE SIZE
CEMENTING RECORD
AMOUNT
PULLED
TOP
BOTTOM
TOP
BOTTOM
16
62.5
H40
39
119
39
119
24
Pre -Installed
9 5/8
40
L80
39
1831
39
1831
12 1/4
495sx 11.0ppg, Type III Cement,
235sx 15.8ppg, Type 1
7
16
L80
38
4044
38
4044
8 1/2
249sx 15.8ppg cement
24. Open to production or injection? Yes ❑ No F/�
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd): �Q
/I J SU
�D� PGri n `x
DATE
11 �./
flZa�f
ies
/ VE tIFIED
25. TUBING RECORD
SIZE
DEPTH SET (MD)
PACKER SET (MD/TVD)
3 1/2
3515
3475/3475
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes ❑ No ❑
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD)
AMOUNT AND KIND OF MATERIAL USED
27. PRODUCTION TEST
Date First Production:
N/A
Method of Operation (Flowing, gas lift, etc.): ,
SUSPENDED - NOT PRODUCED
Date of Test:
Hours Tested:
Production for
Test Period
Oil-Bbl:
Gas-MCF:
Water-Bbl:
Choke Size:
Gas -Oil Ratio:
Flow Tubing
Pre§s.
Casinq Press:
Calculated
24-Hour Rate
Oil-Bbl:
Gas-MCF:
Water-Bbl:
Oil Gravitv - API (corr):
F rQm 10-407 elfcevised 5/2017 `� /�l/� _. /j S �Z j' CONTINUED ON PAGE 2 RBDMS�� MAY 1 % 2019 Submit ORIGINIAL on
28. CORE DATA Conventional Core(s): Yes 21 No ❑ Sidewall Cores: Yes 0 No ❑
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Cores: West Willow Lower sands: 3553'-3606'
Sidewall Cores: Silty Shale-3597'-3642', 42 cores, 42 recovered
See Lithological description attached
NAME
MD
TVD
Well tested? Yes ❑ No I]
If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Surface
Permafrost - Base
939
939
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
3580
3580 •
information, including reports, per 20 AAC 25.071.
Formation @ TPI -Willow B
K3
2304
2304
Falcon c
3260
3260
Wasilla Silt
3437
3437
Top Willow B
3580
3580
Top Willow A
3645
3645
Formation at total depth:
Willow A
31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic, Lithology
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
leon of i I r rod c i n or well test results, r 20 AAC 25.070.
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: G.L. Alvord Contact Name: David Lee
Authorized Title: Alaska Drilling Manager Contact Email: David. L.Lee co .com
Authorized Contact Phone: 263-3741
Signature: — Date:
INSTRUCTIONS
General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Form 10-407 Revised 5/2017 Submit ORIGINAL Only
a)
u
�
1O
3
0
U)
a -
o
a `-
ch _
O M
s 1 .M
ao
r-
E
_0o a 0)
a)
U
ma u�
a) co 42
Q
—� In 3
O
3
N
—
O E O
_0
c
Q
O_—
— O
U
~
❑
U �
LO
a)
u
C
N
L
3
i..... .............. ........ ... K .+
0
❑
cM
O
0
LL
w
E
a)
Q.
m
rn
c
.N
V
m
u ❑
3
U�
X ❑
o �-
ch
COo
8—
co
rn
4
lO
r-
cco
CL
O
O
N
O
Y
_
m
ch
M
a)
a
Z
X
c'co
ao
N
co
co
a)
a
Z
X
coU
fV
o)
rn
�
�
3
d
`
m
O-
0)
°
a)
LL
_0
c
m
O
V)
I
a)
d
a
Z
X
CV
?D
r
Cl)I
C
v
-0
W
0
0
m
m
c
r-
3
�
Y
co
❑
❑
❑
O
N
l
N
M
M
Y
Q
Q
3
3
C
10
C
c
C
l�¢g
Z
(!J
(n
O
O
O
U
_
f7
S
Y
ll. L
�i
�o
O
ti
C N
E E
a) 0
U
H
m
❑
LO
d0'
❑
i—
NAK EXPLOFZaELLNAME TINMIAQ 13 WELLBORE TINMIAQ 13
Conocolhillipsa
Well Attribute Max Angle TD
Field Name Wellbore APW WI Wellbore Status ncl (°) MD (ftr. AtBtm (ftKB)
Alaska, INC.NORTH ALASKA TIGHT HOLE 501032078300 EXPLOR 7.61 262.20 4,050.0
Release Date
39.06
TINMIAQ13,5/7MI911:28:49AM
Casing Strings
Vertical schematic (actual)
Casing Description
Conductor
OD (in)
16
I 1. (in) Top
15.25 39.2
(ftKB)
Set Depth (ttl(B) Set
119.2 1
Depth nVD)...
19 .2
WtlLen (I... Grade
62.50 H40
Top
Thread
........................................................................................
Hanger, 34.5
Casing Description
Surface
OD (in)
95/8
ID (in) Tap
8.84 39.4
(ftKB)
Set Depth (ftKB) Set
1,831.1 1,831.0
Depth (TVD)...
WtlLen (I... Grade
40.00 L-80
Top
TXPM
Thread
Casing Description
Production
OD (in)
7
I ID (in) Top
6,28 38.1
(ftKB)
Set Depth (ftKB) Set
4,044.0 4,043.9
Depth (TVD)...
WtlLen (I... Grade
26.00 L-80
Top
TXP-m
Thread
Tubing Strings
Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft,. Set Depth (TVD) (... Wt (Ibt t) Grade Top Connection
Upper Completion 31/2 2.99 34.5 3,515.5 3,515.4 9.30 L-80 EUE-m
Completion Details
Top(TVD) Top
Intl
Nominal
Top (ftKB)
(ftKB)
(°)
Item Des
Com
ID (in)
34.5
34.5
0.03
Hanger
Hanger, 4-1/2" x 10-3/4" Gen 5r FMC TC-1A EMS
3.920
67.3
67.3
0.18 XO
Reducing
Crossover 4-1/2" IBT-m x 3-1/2" EUE
2.992
496.2
496.2
0.46 Nipple
- DB, XN,
Nipple, Camco, 2.875" DS, 2.906" No-go, SN.T021908 (??°
2.875
DS,
D
hole angle)
3,314.4
3,314.3
0.09 Nipple
- DB, XN,
Nipple, HES, 2.813" X Profile, SN:21605-08 (??° hole
2.813
DS,
D +
angle)
3,366.6
3,366.5
0.09 Nipple
- DB, XN,
Nipple, HES, 2.813" X Profile, SN:21605-07 (??° hole
2.813
DS,
D
angle)
3,418.6
3,418.6
0.09 Gauge
/ Pump
Gauge Carrier, SLB, §GM with Sapphire tubing pressure gauge,
2.992
Sensor
SN:C18GM 0399
3,475.5
3,475.4
0.08 Packer
Packer, Baker 3 1/2" x 7" Premier
2.870
3,503.8
3,503.7
0.07 Nipple
- DB, XN,
Nipple, HES, .813" XN, 2.75" No-go,SN:21605-06 (RHC plug
2.813
DS,
D
installed)
3,515.0
3,514.9
0.07 Mule
Shoe
Baker Fluted WLEG (Wire line entry guide)
3.000
Other In
Hole (Wireline retrievable plugs,
valves, pumps, fish, etc.)
CwWuctor; 39.2-119.2
Top (NDI Top
Incl
Top (ftKB)
(ftKB)
V
Des
Com
Run Oate
ID (in)
VR
plug - IA #1
4/17/2019
VR
Plug - CA
4/17/2019
VR
Plug - IA #2
4/17/2019
Mandrel Inserts
St
ati
N Top(ttKB)
Top(TVD)
(ftKB)
Make
Model
DID (in)
S.,
Valve
Type
Latch
Type
PortSize
(in)
TRORun
(psi)
Run Date
Com
1 3,255.8
3,255.8
CAMCO
PN:
SOV
DCK-2
4/19/2019
11131-
01 VC
Surface; 39.4-1,831.1
S, set #
20813-
25
Mandrel; 3,255.E
Gauge / Pump Sensor; 3,418.E
Packer; 3,475.5
Mule Sloe; 3,515.0
Production; 38.1-4,044.0
a1
N
N
N
N
a)
a1
N
a1
a)
-T@
N
a)
N
N
U
N
�2
a
a-2-2
a
a@
w
m
@
m
m
m
3
E-2�2
E
w
E
o
0
>
0
>
0
>
0
>
0
>
0
>
0
>
0
>
0
>
0
�
w
o
o
U
_
O
01
01
01
01
D
O
N
O
O
O
O
O
0
tf
N
aJ
>.
>+
>+
>.
N
N
a
a)
N
N
N
N
N
N
a
to
T
T
v
C
C=
N
3
0>
C
O
C
O
C
O
C
O
C
O
C
O
C
O
C
O
C
O
>
9
C
a>>>>
L
L
L
L
_
•p
c
C
C
C
C
C
C
C
C
>
>
-
n
y
Y
a
Y
a
Y
a
Y
a
C
r
o
3
3
r
r
3
3
3—
N
=
o
o
d
m
m
a1
a
0
0
0
a1
_�
a
3
3
E
a
i
-
x V
p
p
IL
c
O
c
O
c
O
C
O
C
O
C
O
C
O
C
O
C
O-
1]
Y
@
-�
J
z
1]
4
4
Y
@
a
C
CV
c
c
c
c
C
C
C
C
C
a)
3
>
>
>
L
L
L
3
@
c
(�
N>
y
a
a
u1
N
in
m
a)
C
ci hi
N
a
m
C
>.
m
2
a1
01
0O
>
T
>,
O
O
0
y
O
O
OC
OC
O
O
O
a
>T
T
T
A
m
l
U
3
C
C
C
coO
C
C
C
o
> CD
0
0
0
Cl
O
0
11
0
0
0
L
LL
m
W
i
m
0
W
O)
O
O
V
`
O O IX
0)
LL
N
N
c
a
l
m
a1
0
0
0
a1
a1
3
d
3
c
o
C
C
c
c
3
00
V U
c
3
o
0
V
C
c
o
c
0
c
0
c
0
c
0
c
0
c
0
c
0
c
0
O
c
0
0
3
0
c
0
3
0
2
3
0
2
3
0
2
3
0°
2
a
,S
c
c
c
c
c
C
c
c
c
a
c.0
c
p
r
(+1
O 1000
p
C
C
C
C
c
C
c
c
03
0
U
m�
2
2
m
2
0
0L,
a1
CD
N
�
O
O
:0
V
O
0
0
0
O
O
O
OO
N0
1�
toQ;
>
>
>
N
d) �
O'pa
a
p 00
z ?i
�.
(0
a E
•�
0
0
0
0
O
O
O
O
O
O
O
0
`
O
0
O
8
0
0
`
N
n styE
`
p
0
0
0
0
0
anan0
0
0
0
0
0
nnrnao
0
0
0
0
m
�
o
am.�
0
D
rncm
o
m
\
Q +..
a)
+.,
0
y�
0 y
p•
m
c
d
w a1
L N
a,9
a
c
O C
O
_
a
0
E
O
p N
M U
0
ao .R.
o
W ar
'S.
c
a
o
0
0
a
0
o
o
a
0
3
a
0
a
o
E
U
o
N a
0
p
y
O 0
O
0
O1
a
0
01
'�
o-
o
CD
a
0
0)
0
0)
@
j0
�O
p
v
c
y
_
2
p
m
E 0
c
M
O LO
r-
0 1V
V%
C
�..
.N
T
@
T
@
T
@
T
@
T
@
T
@
T
@
T
(0
5
>
N
T
0)
>
01
>
01
>
Ol
>
CA
>
>
co a
@
Q co
M
•�
U
U
U
U
U
U
U
U
.N
@>>
U
.-�
N
.N
N
@
Cl
O
.O c
E
0
• • 5i
a N
o
E
E
@
@
@
@
@
(a
@
@
L
L
r
O
rN
=
N
O_
O_
d
CL
O_
O_
Cl
0_
a
O
C 0
O
V7
l00
OU
E
N
N
N
N
N
N
N
N
@
E
_
N
@
E
@
E
_a
N
@
E
@
E
@
E
@
E
.-
N
L cm
3 -
C r
0
U
W
0_
a
co
O
`
{0
.�
I
c
N
C
o1
6
.�
N
C
c
c
01
@
a
-�
O
O
O
(
a
0)c')0)
N
C,)O
O >
O
U
d
QO
O
p
C
U
@
U
@
U
@
U
@
U
.N
U
3
@
0
@
0
U
@
Y
ih L
(00
o
-
'u
c�
-
'N
'Z,
m
o
w
U
N
-
N
_-
N
N
-
N
m
U
3
=
K
_
>
a`
E
o
• W
N
O` N
c
'C
Y
T
@
(6
fa
N
f6
(O
(0
@
(d
@
@
@
@
N
(0
(0
(6
(0
p Z.
O
Wo
O
@
O1
m
m
01
m
01
m
01
O1
01
O1
m
0)
01
m
0I
m
N >
CD
(O
t
• o
m
Z
O
fU
c)
=
a
N
a
d
a
a1
a
0
a
a)
a
a1
a
0
a
a
C
-0
0
C
a
C
a
a
a
C
3
C
3
C
3
C
3
C
3
C O
v U
O
r--
F
s
a7 0
E
E
E
E
E
E
E
E
�-
E
�-
E
o
0
0
0
o
N a1
(0
N
o p
CD
m
m
c
0@@@@@
a
o
N@
o
w
o
w
c
o
N
0
0
0
N
0
N
o
N0
(? o
O
O
a
Op
d
NLL
C
L
L
N
a
c
L
N
a
c
a
c
a
C
a
C
a
C
a
C
a
C
a)r
a1 >
p
Z
@
@
@
"m
@
@
@
@
@
U O
N
2
C
•
E
o
s
E m
'O
o
w
M
aJ
O
1l-
O
M
co
O)
(N
1O
OD
V
h
U 3
!.
C1
y
Q
1A
1nL'1L'1
M
M
Ln
M
CO
Tl-rf
(O
1n
m
rN
1n
("1
W
M
OO
L7
M
No
L)
M
(n
M
m
(n
M
M
W
M
m
M
M
(O
M
O
O
co
O
(Oc
M
L'10
O
0
a
U m
Ul
�o
C
C U
a)
a)
E
@
_
@
r
C
N
E
cu
a
a
c a
O
O L
3
� 0
o
ca
� c
@ N
cu
C a
7
m
O_
OI
S
O)
a)
N T
o
p
N
a)
C
a)
C
@
a)
-
N
c
N
c
-
-
-
-
N
c
N
c
-
a)
c
-
-
-
-
a)
-
-
-
a)
N
N
C
N
C
a)
C
a)
C
-
`O�
C
p
%
O
O
C
O
O
C
C
C
C
O
O
C
O
C
C
c
C
T
C
C
C
T
T
O
O
O
O
c@
O
C
C
O
C
c
c
c
c
c
y
@
y
@
y
@
C
C
C
C
U a)
°
3
3
3
ca 0
me
c >
@
a
t@
E
C
C
C
C
LL
O
O0
c
O
O
UO.
O LE
c
c
c
CC
LLmOU
d
a
v
>
>
>
>
m
>
OV
O
U
Q)
m
m
c N
� w
O
U
d
w
O
N
C
C
N
C
CO
L
L
L
C
C6
U
C
C6
'c
L
r
L
-_
C
-c
L
If
9
'C
L
r
L
a)
a)
a)
C
_ N
L
O
`
O
C
O
C
O
o
O
C
O
C
o
0
0
o
O
C
O
c
o
o
O
c
O
c
o
0
0
0
0
0
o
O
c
O
C
O
c
o
01 0
W
O
7
C
'6_
O
N
O
O
'C
O
M
O
c)
O
N
O
O
N
O
L
O
c0
O
N
O
N
O
I-
O
u)
O
M
= U
C > "O
N
LL
Z)
-o
a
C
a)
aC)
)
a)
aU
a
a
a
a
will
N
ID
'
a)
OO
'
(D
@ .n
N
O
(a
U
@
c
c
U
@
C
@
CNN
CO
CO
CO
>`
OO
C
C
O
O
O
O
O
c
O
c
:
O
c
O
c
O
c
:
O
C
C
C
C
CccU
CD OLC
co
'o c
C �
as
d
@ N
a �@
Z
L
L'
O E
0
0
C
@
C
@
c
Y
@
@
c
aJ
C
@
C
@
c
Y
@
Y
@
Y
@
Y
@
Y
@
Y
@
@
c
aJ
c
Y
@
Y
@
Y
@
Y
@
Y
@
c))
m@
c
c
c
c
c
c
C
y
@
L @
a
Y"
E
a
O
O
c
O
c
O
c
a)
3
O
c
O
c
O
c
O
c
N
3
al
3
a)
3
a)
3
a)
3
a)
3
O
c
O
c
a)
3
a)
3
O`
N
a)
3
N
3
@
3
Q
N
O`
N
O
c
o
c
O
c
O
c
@
3
{
O d O
0
y
c
caN
O rn
yW
V
E
c
o—
@(vv
U
L
C
C,C
•oc
oaaaooa�nnaanoaoa�0
C)
0
c U
m@ 2
a) N
o
o_
o_
o_
n
o.
Z°°oaaa 3
o N
C)
a
o N E y
0
o
O U -o
ate+
V
D1 N
C
O
0
0
0
0
0
O
O
0
0
o
o
o
O °
D
O.
d
0.
Q
�.
0.
0_
0
0_
0_
O.
d
d
d
d
d
a
o-
Q
Q
0.
a
R
Q
M c)
0
0
0
0
a N O E
tl)
Q
E
D_
E
E
N 'C O
ay
N
O
O
O
O
L N ap 4
E
E
E
E
w
D
D
D
Z
L>
>
`>
>
L>
O
O
`>
>>>
m
Z
2��
_�
_rn
>>
o
N
N
N
N
N
o a o
-O -O N O
c
W
L
Z
.N
N
N
N
O
N
N
N C>
ca �
m
ooa
m
C7
E a
T
t
o `
N
a
s
v
v
v
o
o
v
E 4)L
@ o
C
W 0
a)
a)
ao
a)
a)
a)
'
a
U)y�-p
S0C]
C
cL
C
C
c
Lo
Lo
E@
E@
a7
LaC)
Ea
N
COO-
L.@..
L.@..
C
Y@
.0
C
U3
U3
U
OCO CO
LUU
LNLN
UUULL
La)
U
w
FF
TF
cry♦�77"+)
N
aa
A
p
0
0
rn
m
@
@
`m
El
o)
@
@
m
o)
@
@
rn
o)
rn
o)
o)
o)
.
c 3 r U
@
N
N
N
N
ca-
a)
(A
a
(a a) O c
a) 3
•
a
x
t E
T
m T
@@ N
N
a)
O
E
01
E
O)
E
m
T
@
T
@
T
@
T
@
T
N
T
@
01
E
0)
T
@
T
m
O)
E
O)
N
(0
N
Ol
O)
O)
@
l6
0)
0)
O)
O)
d 2
C
m
O
"O
N
"O
a)
'O
a)
m
m
O!
N
O)
o)
01
'O
N
'O
a)
D)
01
..
U
a)
U
m
O)
«.
O)
O1
-O
'O
'O
O)
m
'O
0
-0
a)
'D
N
'O
a)
O)
O N w
U of
E
E
E
_
_..
E
E
E
-..
E
E
-
E
E
E
-.
E
E
E
E
_.
y@
—
o r
>
U O
(D
>
a)
N
m
N
N
N
N
N
C
N
CCco
N
a)
Na)
a)
(D
w a)
> N
c
>
O
L
LR
L
0
0
N
/
0
N
N
D
O
O
�
2
•
O
`Fn
J
-_
N
NNN
N
N
N
N
N
N
N
N
U)
�
N
I0
c0
M
Q)
N
O
O
O
N
CO
CO
N
N
N
C
c") 0- O U
y
•�
L
Ln
o
In
rn
V
v
0
o
rn
m
v
o
Ln
m
M
rn
Ln
rn
Ln
o
Ln
o
rn
Ln
o
Ln
o
A
Ln
N O -
O.
a1
N
V
N
V
7
O
V
O
to
M
M
W
N
Lp
N
0
N
r
N
(0
N
V
.-
V
M
M
M
O
m
O
V
O
V
O
V
O
M
O
N
O
O
N n' @
-0-
O T U 3
LL
O
0
UJ
M
M
M
(0
MM
(0
a7
m
O
M
(0
(")M
(0
(0
M
a7
M
(0
M
(D
(fl
O
CO
(D
(O
(O
(0
(0
(O
CO
(0
(0
LO
M
N = @ O
c
C�
IL U
Whole Core
1. Formation: Willow Formation
2. Cored interval: 3553-3606'MD/TVD
3. Lithology: 3553-3578'md was shale; 3578-3606'md was sand
4. Fluid(s): Cored sands were oil -filled
5. Detailed core descriptions: See attached wellsite core chip descriptions
6. Physical core chips: are submitted separately to the State by Mike McCracken at AK Archives
7. Core photographs: Photographs are too numerous/large to email, please provide me with a
folder location where I can place copies
8. Laboratory analysis: Lab analysis is on -going, results will not be available for several months to a
year from now.
Sidewall Cores (42 rotary sidewall cores were cut and 42 recovered)
1. Formation: Willow Formation
2. Cored interval: 3597-3642'MD/TVD
3. Lithology: Varied, from sandstone to silty shale (see descriptions)
4. Fluid(s): Cored sands were oil -filled
5. Detailed core descriptions: See attached wellsite core chip descriptions
6. Physical core chips: are not required from RSWC's, only whole core
7. Core photographs: Photographs are too numerous/large to email, please provide me with a
folder location where I can place copies
8. Laboratory analysis: Lab analysis is on -going, results will not be available for several months to a
year from now
Operations Summary (with Timelog Depths)
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
Start Depth
(ftKB)
End Depth (ftKB)
3/19/2019
3/19/2019
6.00
MIRU
MOVE
DMOB
T
Rig was Released from CD1-14 @
12:00
18:00
12:00. Remove beaver slide. Hang
and secure skate track. Blow down
steam and water systems. Disconnect
interconnects.
3/19/2019
3/19/2019
3.00
MIRU
MOVE
DMOB
T
Pull support mods apart and stage on
18:00
21:00
pad.
3/19/2019
3/20/2019
3.00
MIRU
MOVE
MOB
T
Move Sub, Rock Wash and pipeshed
21:00
00:00
modules towards XBC
3/20/2019
3/20/2019
5.50
MIRU
MOVE
MOB
T
Stage Sub and Pipe shed on ice pad
00:00
05:30
3/20/2019
3/20/2019
6.00
MIRU
MOVE
MOB
T
Move Pump room moduel, Rock
05:30
11:30
washer, Motor room complex & Pit to
ice pad staging area and fuel trucks
3/20/2019
3/20/2019
3.50
MIRU
MOVE
MOB
T
Continue Move Pump room module,
11:30
15:00
Rock washer, Motor room complex &
Pit to ice pad staging area and fuel
trucks
3/20/2019
3/20/2019
4.50
MIRU
MOVE
MOB
T
Move Substructure, Pipe shed and
15:00
119:30
Shop to XBC
3/20/2019
3/20/2019
2.00
MIRU
MOVE
MOB
T
Spread herculite (wait for loader to be
19:30
21:30
deliverd
3/20/2019
3/21/2019
2.50
MIRU
MOVE
MOB
T
Laydown mats and herculite and spot
21:30
00:00
sub.
3/21/2019
3/21/2019
1.00
MIRU
MOVE
RURD
T
Continue Spotting Sub
00:00
01:00
3/21/2019
3/21/2019
1.50
MIRU
MOVE
RURD
T
R/U Stompers, Prep for skidding rig
01:00
02:30
floor
3/21/2019
3/21/2019
1.00
MIRU
MOVE
RURD
T
Skid floor
02:30
03:30
3/21/2019
3/21/2019
4.50
MIRU
MOVE
RURD
T
Lay herculite, set mats and spot Pit
03:30
08:00
module, Pump room, and motor
complex.
3/21/2019
3/21/2019
1.00
MIRU
MOVE
RURD
T
Lay herculite, set mats and set pipe
08:00
09:00
shed
3/21/2019
3/21/2019
4.50
MIRU
MOVE
RURD
T
Hook up service line.insure are
09:00
13:30
landing on each modules are down
and walk ways are secure.
3/21/2019
3/21/2019
1.50
MIRU
MOVE
RURD
T
Install Beaver slide in place
13:30
15:00
3/21/2019
3/22/2019
9.00
MIRU
RIGMNT
SVRG
T
C/O upper IBOP, Install NC-50 saver
15:00
00:00
sub, inspect pit #4-4 equalizer valves,
inspect mix pump, inspect. #1
centrifugal
3/22/2019
3/22/2019
12.00
MIRU
RIGMNT
SVRG
T
Preform a BWD on the upper rams,
00:00
12:00
lower rams and Blind/Shear rams.
Housekeeping on the rig floor and
BOPE deck. Change out mix pump.
Rebuild the MCWS on the Top Drive.
3/22/2019
3/22/2019
4.50
MIRU
RIGMNT
SVRG
T
Replace steam Isolation valve in the
12:00
16:30
cellar. Work on steam line in cellar.
Housekeeping in the pipeshed.
3/22/2019
3/23/2019
7.50
MIRU
RIGMNT
SVRG
T
Wait on Weather Phase 3
16:30
00:00
3/23/2019
3/23/2019
9.00
MIRU
RIGMNT
WAIT
T
Phase 3 weather conditions.
0.0
0.0
00:00
09:00
3/23/2019
3/23/2019
3.00
MIRU
RIGMNT
SVRG
T
Remove plumbing for steam heaters
0.0
0.0
09:00
12:00
in cellar for repair. take apart flow line
and inspect. Inspect energy track.
Check and tighten bolts on all stairs
and platforms on the rig.
Page 1/18 Report Printed: 5/6/2019
¢�
Operations Summary (with Timelog Depths)
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(MB)
End Depth (ftKB)
3/23/2019
3/24/2019
12.00
MIRU
RIGMNT
SVRG
T
Cut out and replace 1002 fitting on
0.0
0.0
12:00
00:00
drip pan for a 1502 fitting. Clean out
under rotary table. Offload equipment
on staging pad.
3/24/2019
3/24/2019
12.00
MIRU
RIGMNT
SVRG
T
Change out filters on pipe skate
00:00
12:00
hydraulic system. Remove inspection
hatches from flow line and inspect.
Complete wire rope sling, nylon sling
and chain inventory and inspection.
Continue to work on cellar steam
system. change out, off drillers side
tugger cable. Perform derrick
inspection.
3/24/2019
3/25/2019
12.00
MIRU
RIGMNT
SVRG
T
Continue to work on cellar steam
12:00
00:00
system. Inspect Top Drive. Change
out rollers on cellar wind walls. Work
on rock washer shaker. Adjust rig
spacer markers
3/25/2019
3/25/2019
12.00
MIRU
RIGMNT
SVRG
T
Inspect energy track. Paint and clean
00:00
12:00
throughout rig. Continue with plumbing
of steam system in cellar. Inspect all
outside hydraulic lines.lnstall
remaining rollers on off drillers side
cellar wall. Change out 3" ball valves
in
rock washer.
3/25/2019
3/26/2019
12.00
MIRU
RIGMNT
SVRG
T
Inspect energy track, install pins. Paint
12:00
00:00
and clean throughout rig.
Continue with plumbing of steam
system in cellar. inspect hydraulic
lines.
change out 3" ball valves in rock
washer. Rig down beaverslide.
Remove
inspection cover on gear end of mud
pump #1. Change filters on rig
hydraulics. Adjust hydraulic lines and
re -install clamps on beaver slide.
3/26/2019
3/26/2019
12.00
MIRU
RIGMNT
SVRG
T
Inspect and clean desnader and
0.0
0.0
00:00
12:00
desilter. Prep 4" ball valve for
conductor. Continue to work on MP2's.
Grease choke manifold. Clean and
inspect bolts for BOPE and diverter.
Continue to fabricate steam lines in
cellar. Inspect gear end of pump #1.
3/26/2019
3/27/2019
12.00
MIRU
RIGMNT
SVRG
T
Change out 5 7/8" derrick fingers to
0.0
0.0
12:00
00:00
5". Continue to fabricate steam lines in
cellar. Install repaired steam heater
cores in cellar. Continue cleaning and
inspecting BOPE bolts. Remove 5 7/8"
derrick fingers from rig floor. Install
inspection cover on gear end of mud
pump #1.
3/27/2019
3/27/2019
12.00
MIRU
RIGMNT
SVRG
T
Perform preventative maintenance on
0.0
0.0
00:00
12:00
centrifuge and air slips. Plumb steam
lines to cellar heaters. Sikaflex
removable wall seams around drilling
line spool. Remove gear end
inspection cover and perform
maintenance on mud pump #2.
3/27/2019
3/28/2019
12.00
MIRU
RIGMNT
SVRG
T
Work on MP2's. Continue to plumb
0.0
0.0
12:00
00:00
steam lines to cellar heaters. Continue
with mud pump #2 gear end
maintenance. Cut off and replace 30'
drilling line. Rig down pipe skate rail.
Page 2/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
3/28/2019
3/28/2019
6.00
MIRU
MOVE
RURD
P
Check tire pressures on rig modules.
0.0
0.0
00:00
06:00
Build air hose for inflating sub tires.
Off load blow down water form pit #5.
Secure pipe skate in shed. Perform
pre -rig move and pre -skid checklists.
Blow down steam system. Disconnect
alll interconnects. Lift and pin cellar
walls
3/28/2019
3/28/2019
4.50
MIRU
MOVE
MOB
P
Rig down and blow down water
0.0
0.0
06:00
10:30
system in camp.
3/28/2019
3/28/2019
1.50
MIRU
MOVE
MOB
P
Move camp from CD-4 ice pad
0.0
0.0
10:30
12:00
towards Tinmiaq 13. Sim-
ops/Continue to prep rig fomove.
Clean up around pad. Secure loads on
parts house. Jack up support
modules.
3/28/2019
3/28/2019
5.50
MIRU
MOVE
MOB
P
Move camp to Tinmiaq 13.
0.0
0.0
12:00
17:30
3/28/2019
3/28/2019
3.50
MIRU
MOVE
RURD
P
Set mats for camp. Spot and set camp
0.0
0.0
17:30
21:00
and SDU. Rig up camp. Sim-
ops/Seperate support modules and
stage on XBC pad.
3/28/2019
3/28/2019
1.50
MIRU
MOVE
RURD
P
Skid rig floor to move position.
0.0
0.0
21:00
22:30
3/28/2019
3/29/2019
1.50
MIRU
MOVE
MOB
P
Move support modules from XBC
0.0
0.0
22:30
00:00
towards Tinmiaq 13.
3/29/2019
3/29/2019
4.25
MIRU
MOVE
MOB
P
Move support modules to and stage
0.0
0.0
00:00
04:15
on Tinmiaq 13.
3/29/2019
3/29/2019
3.00
MIRU
MOVE
MOB
P
Return to XBC with trucks. Hook up to
0.0
0.0
04:15
07:15
sub and pull off of mats. Clear
herculite and pull mats. Fuel all
equipment and allow field change out
from West Willow to take place.
3/29/2019
3/29/2019
4.75
MIRU
MOVE
MOB
P
Move sub from XBC to Tinmaq 13.
0.0
0.0
07:15
12:00
3/29/2019
3/29/2019
2.00
MIRU
MOVE
MOB
P
Move sub into position to spot on well.
0.0
0.0
12:00
14:00
Set mats and herculite. Spot sub over
Tinmiaq 13.
3/29/2019
3/29/2019
0.50
MIRU
MOVE
RURD
P
Set stompers and remove load hitch
0.0
0.0
14:00
14:30
from sub.
3/29/2019
3/29/2019
0.50
MIRU
MOVE
RURD
P
Skid rig floor to drill position and lay
0.0
0.0
14:30
15:00
mats for pits.
3/29/2019
3/29/2019
1.50
MIRU
MOVE
MOB
P
Spot pit room.
0.0
0.0
15:00
16:30
3/29/2019
3/29/2019
2.00
MIRU
MOVE
MOB
P
Spot pump room,
0.0
0.0
16:30
18:30
3/29/2019
3/29/2019
1.00
MIRU
MOVE
MOB
P
Spot motor room.
0.0
0.0
18:30
19:30
3/29/2019
3/29/2019
3.00
MIRU
MOVE
MOB
P
Lay herculite and spot pipe shed.
0.0
0.0
19:30
22:30
3/29/2019
3/30/2019
1.50
MIRU
MOVE
RURD
P
Rig up interconnects, pipe skate and
0.0
0.0
22:30
00:00
beaver slide.
3/30/2019
3/30/2019
2.00
MIRU
MOVE
RURD
P
Perform rig acceptance checklist. Sim-
0.0
0.0
00:00
02:00
ops/Transport rock washer and shop
from XBC to Tinmiaq 13
3/30/2019
3/30/2019
2.00
MIRU
MOVE
RURD
P
Set herculite for shop and rock washer
0.0
0.0
02:00 104:00
I
and spot same.
Page 3/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
F TINMIAQ 13
r,
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (W[3)
3/30/2019
3/30/2019
2.00
MIRU
MOVE
RURD
P
Finish berming around rock washer,
0.0
0.0
04:00
06:00
shop and motor room. Rig up
geronimo line. Set cuttings tank in
place. Complete pump room
interconnect of mud lines. Complete
rig acceptance checklist.
Rig accepted at 06:00 hrs 3/30/19
3/30/2019
3/30/2019
2.50
MIRU
MOVE
RURD
P
Check all bolts on diverter line. Torque
0.0
0.0
06:00
08:30
bolts on diverter tee, starting head and
annular connections. Make up flanged
riser to annular top. Set containment
box at end of diverter line.
3/30/2019
3/30/2019
1.00
MIRU
MOVE
SFTY
P
Perform hazard hunt on rig and pad
0.0
0.0
08:30
09:30
focusing on Slips, Trips and Falls.
Address all findings and document on
SAFE cards or Action Item List.
3/30/2019
3/30/2019
1.50
MIRU
MOVE
RURD
P
Secure annular and adjust for rig floor
0.0
0.0
09:30
11:00
riser. Install riser to rig floor and inflate
air boots. Install 4" annulus valves on
conductor.
3/30/2019
3/30/2019
1.00
MIRU
MOVE
BOPE
P
Pick up 2 jts 5" DP. Perform diverter
0.0
0.0
11:00
12:00
XZ,
test. Witness waived byAOGCC rep
Jeff Jones and BLM rep Amanda
(
Eagle. Kni a valve open in 3.4 sec's,
s,
�2
�f
annular closed in 38 sec. Perform
h
' \g
accumulator test. Starting system
pressure =2925 psi. Pressure after
closure=1900 psi. Time to 200 psi=9
secs. Full recharge time=57 secs. 6
nitrogen bottles at 2070 psi. Tested
gas, PVT and flow alarms.
3/30/2019
3/30/2019
8.00
MIRU
MOVE
PULD
P
Strap and tally 5" DP. Pick up and
0.0
0.0
12:00
20:00
stand back 129 joints of 5" DP. Sim-
ops/Lay herculite in contingency
cuttings pit.
3/30/2019
3/30/2019
3.00
MIRU
MOVE
BHAH
P
Pick up and rack back BHA #1
0.0
0.0
20:00
23:00
3/30/2019
3/31/2019
1.00
MIRU
MOVE
SFTY
P
Conduct pre -spud meeting with both
0.0
0.0
23:00
00:00
crews.
3/31/2019
3/31/2019
1.00
MIRU
MOVE
RURD
P
Fill mud lines and conductor with mud
0.0
0.0
00:00
01:00
and check for leaks. Good.
3/31/2019
3/31/2019
1.00
MIRU
MOVE
SEQP
P
Test both mud pumps and mud lines
0.0
0.0
01:00
02:00
to 3200 psi. Test upper IBOP to 3500
ps/5 minsi.
3/31/2019
3/31/2019
10.00
MIRU
MOVE
WAIT
T
Ice roads closed due to warm weather.
0.0
0.0
02:00
12:00
Wait on ice roads to reopen. Sim-ops/
Load, strap and drift 120 jts of 3 1/2"
tubing, 112 jts of 7" casing.
3/31/2019
3/31/2019
9.00
MIRU
MOVE
WAIT
T
Ice roads closed due to warm weather.
0.0
0.0
12:00
21:00
Wait on ice roads to reopen. Sim-ops/
Load, strap and drift 50 jts 9 5/8"
casing. Finish making up BHA#1.
Work on MP2's. Take on 230 bbls 10.5
ppg spud mud. Conduct rig audit.
3/31/2019
4/1/2019
3.00
MIRU
MOVE
WAIT
T
Ice roads open to essential rig traffic
0.0
21:00
00:00
at 21:00 hrs. Waiting on equipment to
arrive on location.
4/1/2019
4/1/2019
1.50
MIRU
MOVE
RURD
P
Rig up mud loggers equipment. Take
0.0
0.0
00:00
01:30
on 230 bbls spud mud.
4/1/2019
4/1/2019
0.75
MIRU
MOVE
RURD
P
Continue to rig up mud loggers. Sim-
0.0
104.0
01:30
02:15
ops/RIH and tag up at 109' MD. PU 5'.
Establish circulation. 450 gpm, 460
psi.
Page 4/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Uepths)
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
4/1/2019
4/1/2019
1.50
MIRU
MOVE
RURD
P
Set up Geolog gas watch equipment.
104.0
104.0
02:15
03:45
Test connections and readings.
Circulate at 150 gpm, 200 psi, 7% FO.
4/1/2019
4/1/2019
4.00
SURFAC
DRILL
DDRL
P
Clean out conductor from 109' MD to
104.0
408.0
03:45
07:45
120' MD. Drill 12 1/4" surface hole
from 120' MD to 408' MD. 454 gpm
536 psi. 13% F/O, 80 rpm 3K tq. 12K
WOB, off bottom:491 psi/1 K tq.
n
PU=58K SO=64K Rot=60K C
ADT=2.85 Bit hrs=2.85
4/1/2019
4/1/2019
0.25
SURFAC
DRILL
OWFF
P
Blow down TD. Monitor well. Static.
408.0
408.0
07:45
08:00
4/1/2019
4/1/2019
0.75
SURFAC
DRILL
PMPO
P
POOH from 408' MD. Encounter 18K
408.0
40.0
08:00
08:45
overpull at 398' MD. Pump OOH from
398' MD to 120' MD. 450 gpm, 500
psi, 13% FO. POOH on elevators from
120' MD to 40' MD.
4/1/2019
4/1/2019
2.50
SURFAC
DRILL
BHAH
P
PJSM-Blow down TD. Make up BHA
40.0
206.0
08:45
11:15
#2.
4/1/2019
4/1/2019
1.25
SURFAC
DRILL
DLOG
P
Establish circulation and pump up
206.0
408.0
11:15
12:30
survey. Wash down from 206' MD to
408' MD to obtain logs. 300 FPH, 450
gpm, 596 psi, 15% FO.
4/1/2019
4/1/2019
5.50
SURFAC
DRILL
DDRL
P
Drill 12 1/4" surface hole from 408' MD
408.0
806.0
12:30
18:00
to 806' MD. 806' TVD 500 gpm 790
psi. 20% F/0, 80 rpm 2K tq. 10K
WOB, off bottom:707 psi/1 K tq.
PU=86K SO=95K Rot=88K Max
gas=23 units ADT=3.63 Bit hrs=6.48
Jar hrs=21.76
4/1/2019
4/2/2019
6.00
SURFAC
DRILL
DDRL
P
Drill 12 1/4" surface hole from 806' MD
806.0
1,273.0
18:00
00:00
to 1273' MD. 1273' TVD 700 gpm
1375 psi. 22% F/0, 80 rpm 3K tq. 25K
WOB, off bottom:1382 psi/1 K tq.
PU=87K SO=100K Rot=91K Max
gas=54 units ADT=4.40 Bit hrs=10.88
lr
Jar hrs=26.16
1
4/2/2019
4/2/2019
5.00
SURFAC
DRILL
DDRL
P
Drill 12 1/4" surface hole from 1273'
1,273.0
1,836.0
00:00
05:00
MD to 1836' MD. 1835' TVD700 aam,_
1639 psi. 22% F/0, 80 rpm 4K tq. 20-
30K WOB, off bottom:1475 psi/2K tq.
PU=103K SO=110K Rot=110K Max
gas=36 unitsADT=4.23 Bit hrs=15.11
Jar hrs=30.39
4/2/2019
4/2/2019
1.00
SURFAC
CASING
CIRC
P
Obtain final survey. Pump 40 bbls hi-
1,836.0
1,745.0
05:00
06:00
vis sweep surface to surface. 20%
increase in cuttings when sweep at
surface. 700 gpm, 1435 psi, 22% FO,
80 rpm, 2K tq, Ream up to 1745' MD
and rack back stand.
Page 5/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
bs a
' TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth(ftKB)
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
End Depth (ftKB)
4/2/2019
4/2/2019
3.50
SURFAC
CASING
BKRM
P
BROOH from 1745' MD to 1559' MD.
1,745.0
700.0
06:00
09:30
Obtain 1 bottoms up for each stand.
Monitor well. Static. Continue BROOH
from 1559' MD to 700' MD. 700 gpm,
1455 psi, 22% FO, 80 RPM, 2K tq,
Rot=95K PU=100K SO=105K.
4/2/2019
4/2/2019
0.25
SURFAC
CASING
CIRC
P
CBU x3. 700 gpm, 1324 psi, 22% FO,
700.0
700.0
09:30
09:45
80 rpm, 1.5K tq
4/2/2019
4/2/2019
0.50
SURFAC
CASING
TRIP
P
POOH on elevators form 700' MD to
700.0
555.0
09:45
10:15
555' MD. PU=79K SO=84K. Observe
10-25K
4/2/2019
4/2/2019
0.25
SURFAC
CASING
PMPO
P
RIH to 615' MD. Pump OOH from 615'
555.0
426.0
10:15
10:30
MD to 426' MD. 450 gpm, 680 psi,
21 % FO.
4/2/2019
4/2/2019
0.25
SURFAC
CASING
OWFF
P
Blow down TD. Monitor well. Static.
426.0
426.0
10:30
10:45
4/2/2019
4/2/2019
3.50
SURFAC
CASING
BHAH
P
POOH racking back HWDP, jars,collar
426.0
0.0
10:45
14:15
stand. Unload nuclear sources and lay
down BHA.
4/2/2019
4/2/2019
1.00
SURFAC
CASING
BHAH
P
Clean and clear rig floor.
0.0
0.0
14:15
15:15
4/2/2019
4/2/2019
1.25
SURFAC
CASING
RURD
P
Rig up to run 9 5/8" casing.
0.0
0.0
15:15
16:30
4/2/2019
4/2/2019
0.50
SURFAC
CASING
SFTY
P
Conduct PJSM for running 9 5/8"
0.0
0.0
16:30
17:00
casing.
4/2/2019
4/2/2019
4.25
SURFAC
CASING
PUTB
P
Make up 9 5/8" shoe track. Pump
0.0
896.0
17:00
21:15
through floats at 6 bpm, Check floats
integrity. Pick up and RIH with 9 5/8"
40# L-80 TXP-m casing to 896' MD.
Make up connections to 25K. Fill on
the fly and top off every 5 jts. Install 1
bow spring mid joint on shoe track and
then every other joint.
4/2/2019
4/2/2019
0.50
SURFAC
CASING
CIRC
P
CBU x2 staging rate up to 8 bpm, 59
896.0
896.0
21:15
21:45
psi, 10% FO
4/2/2019
4/3/2019
2.25
SURFAC
CASING
PUTB
P
Pick up and RIH with 9 5/8" 40# L-80
896.0
1,552.0
21:45
00:00
TXP-m casing from 896' MD to 1552'
MD. Make up connections to 25K. Fill
on the fly and top off every 5 jts.lnstall
1 bow spring centralizer every other
joint.
4/3/2019
4/3/2019
1.00
SURFAC
CASING
PUTB
P
Pick up and RIH with 9 5/8" 40# L-80
1,552.0
1,788.0
00:00
01:00
TXP-m casing from 1552' MD to 1788'
MD. Make up connections to 25K. Fill
on the fly and top off every 5 jts. Install
1 bow spring centralizer every other
joint. Total of 23 centralizers and 5
stop rings ran.
4/3/2019
4/3/2019
0.50
SURFAC
CASING
HOSO
P
Make up X-O joint, hanger and landing
1,788.0
1,831.0
01:00
01:30
joint. Land hanger on depth at
1831.13' MD. PU=103K SO=101K
4/3/2019
4/3/2019
1.75
SURFAC
CEMENT
CIRC
P
Circulate and condition mud for
1,831.0
1,831.0
01:30
03:15
cement job. Reciprocate casing from
1831' MD to 1809' MD. PU=103K
SO=105K. Stage pump rate up from
25 bpm to 8 bpm. 113 psi, 13% FO.
4/3/2019
4/3/2019
0.25
SURFAC
CEMENT
RURD
P
Blow down TD. Rig up cement hose.
1,831.0
1,831.0
03:15
03:30
1
I
I
Page 6/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
4/3/2019
4/3/2019
2.00
SURFAC
CEMENT
CIRC
P
Circulate and condition mud for
1,831.0
1,831.0
03:30
05:30
cement job. Reciprocate casing from
1831' MD to 1809' MD. PU=103K
SO=106K. Stage pump rate up from
25 bpm to 8 bpm. 228 psi, 11 % FO.
Sim-ops/Conduct PJSM on cement
job.
4/3/2019
4/3/2019
4.25
SURFAC
CEMENT
CMNT
P
Line up & HES pump 5 bbls water.
1,831.0
1,831.0
05:30
09:45
Pressure test lines to 3500 psi, good.
Pump 61.17 bbls of 10.5 ppg
CleanSpacer @ 2-3.5 bpm, 75 psi, FO
1-2%. Drop bottom plug & start
batching lead. Pump 213 bbls of 11.0
ppg lead cement at 4 bpm, 148-87 psi,
FO 2%. PU 108K, SO 111 K. Land
/
/Ilk
C
bottom plug at 133 bbls pumped.
Batch and pump 48.4 bbls of 15.8 ppg
�7�'
tail cement @ 4 bpm, 70-130 psi, FO
y
1 %. Drop top plug & kick out with 10
bbls of fresh H2O. Swap to rig &
c4
1
displace w/ 10.3 ppg spud mud @ 6
bpm, 230-480 psi, FO 6%.11 ppg lead
cement at surface at 70 bbls of
displacement away. Reduced rate to 3
bpm. Land hanger at 104 bbls
displacement pumped. Bump plug
with 1200 strokes, Pressure up to
1088 psi & hold for 5 minutes. Bleed
off pressure, floats held. CIP 09:42 hrs
04/03/19. 50 bbl 11 ppg cement to
surface.
4/3/2019
4/3/2019
0.50
SURFAC
CEMENT
OWFF
P
Monitor well. Static.
1,831.0
1,831.0
09:45
10:15
4/3/2019
4/3/2019
0.75
SURFAC
CEMENT
RURD
P
Back out landing joint. Break out 10'
1,831.0
0.0
10:15
11:00
pup joint and lay down. Clear rig floor
of casing running tools.
4/3/2019
4/3/2019
2.50
SURFAC
CEMENT
CLEN
P
Open annulus valves. Drain diverter
0.0
0.0
11:00
13:30
and flush with black water pill. Make
up stack washer tool and flush
diverter.
4/3/2019
4/3/2019
2.50
SURFAC
CEMENT
NUND
P
Nipple down diverter system.
0.0
0.0
13:30
16:00
4/3/2019
4/3/2019
3.00
SURFAC
WHDBOP
NUND
P
Nipple up wellhead as per FMC rep.
0.0
0.0
16:00
19:00
Test wellhead seals to 1000 psi/10
mins, witnessed by Co Man.
4/3/2019
4/4/2019
5.00
SURFAC
WHDBOP
NUND
P
Nipple up BOPE. Sim-ops/Prep for
0.0
0.0
19:00
00:00
BOPE test.
4/4/2019
4/4/2019
2.50
SURFAC
WHDBOP
NUND
P
Continue to nipple up BOPE. Obtain
0.0
0.0
00:00
02:30
RKB's. RF to annular=19.45', RF to
upper rams= 23.35', RF to blind
rams=25.83', RF to lower
rams=29.91', RF to wellhead=34.7',
RF to ULDS=34.98', RF to
LLDS=37.15.
4/4/2019
4/4/2019
1.00
SURFAC
WHDBOP
BOPE
P
Set test plug and make up 5" test joint.
0.0
0.0
02:30
03:30
Flood BOPE and lines with water.
Page 7/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftK6)
4/4/2019
4/4/2019
5.75
SURFAC
WHDBOP
BOPE
P
R/U & test BOPE with 5" test joint,
0.0
0.0
03:30
09:15
Test 1-Annular preventer, Choke
manifold valve 1,12,13,14 and 4" Kill
line on mud manifold, 4-1/2 IF Dart
Valve. Test 2- Top Rams Choke
manifold with valves 9 & 11, Mezz. Kill
line and 4-1/2 IF FOSV., Test -3:
Choke manifold valves 8,10 and
Manual Kill. Test -4: valves 6 and 7.
Test -5: Super choke and manual
t
choke, test to 2000 psi. Test-6: Choked
manifold valves 2 and 5, Manual Kill.
Test -7: HCR choke and upper IBOP
valve. Test -8: Manual choke and
lower IBOP valve. Test -9: Lower
rams. Test - 10: Blinds choke
manifold valves 3A and 6. All tested to
250 low/5 mins and 3500 high/10
mins. Accumulator draw down test/
Starting pressure=3000 psi, after
function=1750 psi, 200 psi
attained=10 sec's, full recovery=78
sec. 6 nitrogen bottles at 2325 psi.
Test gas alarms, PVT and flow show.
(Test witnessed by Alaska State
Rep.Guy Cook. Witness waived by
BLM Rep Quinn Sawyer.) HCR on kill
line failed to test.
4/4/2019
4/4/2019
0.50
SURFAC
WHDBOP
BOPE
P
Install riser, pump out BOPE. Blow
0.0
0.0
09:15
09:45
down testing equipment and lines.
4/4/2019
4/4/2019
3.25
SURFAC
WHDBOP
RGRP
T
Rig down kill line. Change out kill line
0.0
0.0
09:45
13:00
HCR valve. Function test and grease
valve.
4/4/2019
4/4/2019
1.75
SURFAC
WHDBOP
BOPE
P
Test kill line HCR to 250 psi/5 mins
0.0
0.0
13:00
14:45
and 3500 psi/10 mins. Rig down test
equipment.
4/4/2019
4/4/2019
0.50
SURFAC
CEMENT
RURD
P
Install 9" ID wear ring.
0.0
0.0
14:45
15:15
4/4/2019
4/4/2019
0.75
SURFAC
CEMENT
PRTS
P
Rig up and test 9-5/8" casing to 3000
0.0
0.0
15:15
16:00
psi/30 mins. 21 stks to pressure up
and 2 bbls bled back.
4/4/2019
4/4/2019
3.00
SURFAC
CEMENT
BHAH
P
Make up 8 1/2" RSS BHA #3.
0.0
496.0
16:00
19:00
4/4/2019
4/4/2019
1.25
SURFAC
CEMENT
TRIP
P
RIH from 496' MD to 1536' MD.
496.0
1,536.0
19:00
20:15
4/4/2019
4/4/2019
1.00
SURFAC
CEMENT
COCF
P
Wash down from 1536' MD to 1749'
1,536.0
1,749.0
20:15
21:15
MD. Tag up at 1749' MD.450 gpm, 778
psi, 16% FO.
4/4/2019
4/5/2019
2.75
SURFAC
CEMENT
DRLG
P
Drill out plugs, FC and cement from
1,749.0
1,828.0
21:15
00:00
1749' MD to 1828' MD. 350 gpm, 432
psi, 13% FO, 40 rpm, 2-6K WOB while
drilling FC. 500 gpm, 867 psi, 15%
FO, 80 rpm, 2K WOB while drilling
cement.
4/5/2019
4/5/2019
1.00
SURFAC
CEMENT
DRLG
P I
Drill out cement,, float shoe and clean
1,828.0
1,836.0
out rat hole from 1828' MD to 1836'
00:00
01:00
MD
Page 8/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
TINMIAQ 13
h.
x
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
4/5/2019
4/5/2019
0.25
SURFAC
CEMENT
DDRL
P
Drill 8-1/2" production hole from 1836'
1,836.0
1,856.0
01:00
01:15
MD to 1856' MD. 1856' TVD 500 gpm
973 psi. 15% F/O, 100 rpm 1 K tq. 5K
WOB, off bottom:925 psi/1 K tq.
PU=94K SO=105K Rot=102K Max
gas=36 units ADT=.17 Bit hrs=.17 Jar
hrs=30.75
4/5/2019
4/5/2019
1.00
SURFAC
CEMENT
CIRC
P
Circulate and condition mud for
1,856.0
1,816.0
01:15
02:15
FIT.Reciprocate from 1856' MD to
1826' MD. 500 gpm, 916 psi, 15% FO,
100 rpm, 1 K tq, ECD=11.24. Pull up to
1816' MD.
SPR: 1849' MD 1849' TVD, MW 10
ppg. @ 02:08 hrs
#1) 30spm=70 psi 40spm=120 psi
#2) 30 spm=75 psi 30 spm=120 psi
4/5/2019
4/5/2019
0.25
SURFAC
CEMENT
OWFF
P
Monitor well. Static. Blow downTD.
1,816.0
1,816.0
02:15
02:30
Rig up to conduct FIT.
4/5/2019
4/5/2019
0.75
SURFAC
CEMENT
FIT
P
Perform FIT to 16.4 ppg EMW.
1,$16.0
1,816.0
02:30
03:15
Pump .48 bbl, 610 psi. Monitor for 10
mins. Pressure bled to 430 Bleed
(
1,0
psi.
16
back .5 bbls. Rig down lines.
4/5/2019
4/5/2019
0.50
PROD1
DRILL
DISP
P
Make up stand of DP and wash down
1,816.0
1,856.0
03:15
03:45
to 1856' MD. Displace mud system.
Pump 30 bbls 10 ppg hi-vis spacer.
Follow with 9.5 ppg 3% KCL mud. 400
gpm, 710 psi, 12% FO, 80 rpm, 1 K tq,
PU=94K, SO=105K, Rot=1014K
4/5/2019
4/5/2019
2.25
PROD1
DRILL
DDRL
P
Drill 8-1/2" production hole from 1856'
1,856.0
2,033.0
03:45
06:00
MD to 2033' MD. 2033' TVD 580 gpm
1170 psi. 19% F/O, 120 rpm 2K tq. 5K
WOB, off bottom:1190 psi/1 K tq.
PU=96K SO=112K Rot=105K Max
gas=9 units ADT=1.99 Bit hrs=2.16
Jar hrs=32.74
SPR: 1910' MD 1910' TVD, MW 9.5
ppg. @ 04:30 hrs
#1) 30 spm=130 psi 40 spm=180 psi
#2) 30 spm=130 psi 40 spm=180 psi
4/5/2019
4/5/2019
6.00
PROD1
DRILL
DDRL
P
Drill 8-1/2" production hole from 2033'
2,033.0
2,574.0
06:00
12:00
MD to 2574' MD. 2574' TVD 580 gpm
1437 psi. 20% F/O, 140 rpm 4K tq. 5K
WOB, off bottom:1420 psi/1.2K tq.
PU=112K SO=119K Rot=110K Max
gas=76 units ADT=3.70 Bit hrs=5.86
Jar hrs=36.44
Page 9/18 Report Printed: 5/6/2019
a" Operations Summary (with Timelog Depths)
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
4/5/2019
4/5/2019
4.50
PROD1
DRILL
DDRL
P
Drill 8-1/2" production hole from 2574'
2,574.0
3,100.0
12:00
16:30
MD to 31 00'MD. 31 00'TVD 580 gpm
1564 psi. 19% F/O, 140 rpm 3K tq. 5K
WOB, off bottom:1523 psi/1 K tq.
PU=126K SO=125K Rot=123K Max
gas=36 units ADT=3.62 Bit hrs=9.48
Jar hrs=40.06
SPR: 2665' MD 2665' TVD, MW 9.5
ppg. @ 12:05 hrs
#1) 30 spm=140 psi 40 spm=200 psi
#2) 30 spm=140 psi 40 spm=200 psi
4/5/2019
4/5/2019
3.50
PROD1
DRILL
CIRC
P
Circulate and condition mud while
3,100.0
3,100.0
16:30
20:00
preparing to displace to coring mud.
Reciprocate drill string 45' strokes.
500 gpm, 1164 psi, 16% FO, 80 rpm.
4/5/2019
4/6/2019
4.00
PROD1
DRILL
DDRL
P
Displace to 9.5 ppg 3% coring mud .
3,100.0
3,286.0
20:00
00:00
Drill 8-1/2" production hole from 3100'
MD to 3286' MD. 3286' TVD 550 gpm
1346 psi. 17% F/O, 130 rpm 2K tq. 2K
WOB, off bottom:1341 psi/1 K tq.
PU=126K SO=136K Rot=124K Max
gas=20 unitsADT=2.57 Bit hrs=12.05
Jar hrs=42.63
4/6/2019
4/6/2019
1.00
PROD1
DRILL
DDRL
P
Drill 8-1/2" production hole from 3286'
3,286.0
3,331.0
00:00
01:00
MD to 3331' MD. 3331' TVD 580 gpm
1500 psi. 19% F/O, 130 rpm 2K tq. 2K
WOB, off bottom:1432 psi/1 K tq.
PU=126K SO=136K Rot=124K.
ECD=11.30 Max gas=20 units
ADT=1.00 Bit hrs=13.05 Jar
hrs=43.63
4/6/2019
4/6/2019
1.00
PROD1
DRILL
CIRC
P
Circulate while emptying pits and rock
3,331.0
3,331.0
01:00
02:00
washer of old mud. Reciprocate and
rotate from 3235' MD to 3260' MD.
580 gpm, 1479' MD, 18% FO, 100
rpm, .9K tq,
4/6/2019
4/6/2019
2.00
PROD1
DRILL
CIRC
P
Add tritium tracer to mud. Circulate 3
3,331.0
3,331.0
02:00
04:00
complete surface system and hole
volumes. Reciprocate from 3235' MD
to 3328' MD. 580 gpm,
SPR: 3331' MD 3331' TVD, MW 9.5
ppg. @ 03:50 hrs
#1) 30 spm=120 psi 40 spm=180 psi
#2) 30 spm=120 psi 40 spm=180 psi
4/6/2019
4/6/2019
2.00
PROD1
DRILL
DDRL
P
Drill 8-1/2" production hole from 3331'
3,331.0
3,460.0
04:00
06:00
MD to 3460' MD. 3460' TVD 580 gpm
1520 psi. 19% F/O, 130 rpm 2K tq. 2K
WOB, off bottom:1502 psi/1 K tq.
PU=122K SO=136K Rot=124K.
ECD=11.11 Max gas=20 units
ADT=1.72 Bit hrs=14.77 Jar
hrs=45.35
Page 10/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
s TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
4/6/2019
4/6/2019
2.25
PROD1
DRILL
DDRL
P
Drill 8-1/2" production hole from 3460'
3,460.0
3,553.0
06:00
08:15
MD to 3553' MD. 3553' TVD 580 gpm
1525 psi. 19% F/0, 130 rpm 2K tq. 2K
WOB, off bottom:1514 psi/1 K tq.
PU=122K SO=139K Rot=129K.
ECD=11.18 Max gas=20 units
ADT=1.71 Bit hrs=16.48 Jar
hrs=47.06
4/6/2019
4/6/2019
0.75
PROD1
EVALFM
CIRC
P
Downlink to RSS. CBU. Reciprocate
3,553.0
3,553.0
08:15
09:00
from 3553' MD to 3515' MD. 580 gpm,
1535 psi, 18% FO, 130 rpm, 2K tq.
SPR: 3553' MD 3553' TVD, MW 9.5
ppg. @ 08:50 hrs
*1) 30 spm=140 psi 40 spm=160 psi
*2) 30 spm=140 psi 40 spm=160 psi
4/6/2019
4/6/2019
5.00
PROD1
EVALFM
BKRM
P
BROOH from 3553' MD to 1831' MD.
3,553.0
1,831.0
09:00
14:00
580 gpm, 1375 psi, 130 rpm, 1 K tq.
4/6/2019
4/6/2019
0.50
PROD1
EVALFM
CIRC
P
CBU. 580 gpm, 1300 psi, 18% FO,
1,831.0
1,831.0
14:00
14:30
130 rpm,1 K tq.
4/6/2019
4/6/2019
0.25
PROD1
EVALFM
OWFF
P
Monitor well. Static.
1,831.0
1,831.0
14:30
14:45
4/6/2019
4/6/2019
1.25
PROD1
EVALFM
TRIP
P
POOH on elevators from 1831' MD to
1,831.0
496.0
14:45
16:00
496' MD.
4/6/2019
4/6/2019
2.00
PROD1
EVALFM
BHAH
P
Lay down BHA. Clean and clear rig
496.0
0.0
16:00
18:00
floor.
4/6/2019
4/6/2019
0.50
PROD1
EVALFM
RURD
P
PJSM- Mobilize Baker coring
0.0
0.0
18:00
18:30
equipment to rig floor.
4/6/2019
4/6/2019
3.50
PROD1
EVALFM
BHAH
P
Make up coring BHA to 534' MD as
0.0
534.0
18:30
22:00
per Baker reps.
4/6/2019
4/7/2019
2.00
PROD1
EVALFM
TRIP
P
RIH with coring BHA from 534' MD to
534.0
1,763.0
22:00
00:00
1763' MD. Fill pipe on the fly and top
off every 5 stds. Max running speed in
cased hole=33 fpm. PU-88K
SO=100K
4/7/2019
4/7/2019
0.50
PROD1
EVALFM
CIRC
P
Fill pipe and break circulation. Stage
1,763.0
1,763.0
00:00
00:30
up to 250 gpm, 160 psi. Blow down
TD.
4/7/2019
4/7/2019
1.50
PROD1
EVALFM
TRIP
P
RIH with coring BHA from 1763' MD to
1,763.0
3,367.0
00:30
02:00
3367' MD. Fill pipe on the fly and top
off every 5 stds. Max running speed in
open hole=25 fpm. PU-121 K
SO=131 K
4/7/2019
4/7/2019
0.50
PROD1
EVALFM
WASH
P
Wash down from 3367' MD to 3462'
3,367.0
3,462.0
02:00
02:30
MD. 277 gpm, 263 psi, 7% FO,
PU=121K SO=131K.
4/7/2019
4/7/2019
2.00
PROD1
EVALFM
CIRC
T
Pick up 2 DP pup joints (9.76', 12.03')
3,462.0
3,542.0
02:30
04:30
Circulate and wash down from 3462'
MD to 3542' MD while Geolog mud
loggers trouble shoot and repair
hydrogen generator. 269 gpm, 280
psi, 6% FO, 10 rpm, 1 K tq, PU=126K,
S0=138K Rot=134K.
4/7/2019
4/7/2019
0.25
PROD1
EVALFM
WASH
P
Wash down from 3542' MD to 3551'
3,542.0
3,551.0
04:30
04:45
MD. 270 gpm, 308 psi, 8% FO,
PU=123K SO=135K, Max gas=34
units.
Page 11/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
y.
k}
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
4/7/2019
4/7/2019
7.25
PROD1
EVALFM
CORE
P
Drop1.25" OD flow diverter ball.
3,551.0
3,565.0
04:45
12:00
Obtain SPR's. Core drill 8 1/2"
production hole from 3553' MD to
3568' MD, 3568' TVD. 273 gpm 665
psi. 8% F/O, 65 rpm 1.1 K tq. 15K
WOB, . PU=123K SO=137K
Rot=135K. Max gas=11 units
ADT=6.75 Bit hrs=6.75 Jar hrs=53.81
SPR: 3546' MD 3546' TVD, MW 9.5
ppg. @ 05:10 hrs
#1) 30 spm=300 psi 40 spm=370 psi
#2) 30 spm=300 psi 40 spm=370 psi
4/7/2019
4/7/2019
8.50
PROD1
EVALFM
CORE
P
Core drill 8 1/2" production hole from
3,568.0
3,606.0
12:00
20:30
3568' MD to 3606' MD, 3606' TVD.
273 gpm 645 psi. 7% F/O, 70 rpm
1.4K tq. 13K WOB, . Max gas=23 units
ADT=8.25 Bit hrs=15 Jar hrs=62.06
4/7/2019
4/7/2019
0.50
PROD1
EVALFM
CIRC
T
Core barrel jammed. Pick up to 3600'
3,606.0
3,600.0
20:30
21:00
MD. CBU
4/7/2019
4/7/2019
0.25
PROD1
EVALFM
TRIP
P
POOH as per trip schedule from 3600'
3,600.0
3,467.0
21:00
21:15
MD to 3467' MD.
4/7/2019
4/7/2019
0.25
PROD1
EVALFM
OWFF
P
Monitor well. Static.
3,467.0
3,467.0
21:15
21:30
4/7/2019
4/8/2019
2.50
PROD1
EVALFM
TRIP
P
POOH as per trip schedule from 3467'
3,467.0
2,270.0
21:30
00:00
MD to 2270' MD.
4/8/2019
4/8/2019
0.75
PROD1
EVALFM
TRIP
P
POOH as per trip schedule from 2270'
2,270.0
1,763.0
00:00
00:45
MD to 1763' MD. PU=86K.
4/8/2019
4/8/2019
0.50
PROD1
EVALFM
OWFF
P
Monitor well. Static.
1,763.0
1,763.0
00:45
01:15
4/8/2019
4/8/2019
2.25
PROD1
EVALFM
TRIP
P
POOH as per trip schedule from 1763'
1,763.0
534.0
01:15
03:30
MD to 534' MD. PU=65K.
4/8/2019
4/8/2019
0.50
PROD1
EVALFM
OWFF
P
Monitor well. Static
534.0
534.0
03:30
04:00
4/8/2019
4/8/2019
1.00
PROD1
EVALFM
TRIP
P
POOH as per trip schedule from 534'
534.0
250.0
04:00
05:00
MD to 250' MD. PU=65K.
4/8/2019
4/8/2019
0.50
PROD1
EVALFM
OWFF
P
Monitor well. Static. Sim-ops/Conduct
250.0
250.0
05:00
05:30
PJSM on laying down cores.
4/8/2019
4/8/2019
0.25
PROD1
EVALFM
TRIP
P
POOH as per trip schedule from 250'
250.0
161.0
05:30
05:45
MD to 161' MD. PU=58K.
4/8/2019
4/8/2019
2.25
PROD1
EVALFM
RECR
P
POOH laying down inner core barrels
161.0
161.0
05:45
08:00
as per Baker Coring Reps.
4/8/2019
4/8/2019
2.00
PROD1
EVALFM
RECR
P
POOH laying down outer core barrels
161.0
0.0
08:00
10:00
as per Baker Coring Reps. 3 plugged
nozzles on core bit. Clear coring
equipment from rig floor.
4/8/2019
4/8/2019
1.75
PROD1
DRILL
BHAH
P
Make up 8 1/2" RSS BHA#5 to 496'
0.0
496.0
10:00
11:45
MD. Sim-ops/Process cores. Recover
53' of core.
4/8/2019
4/8/2019
1.25
PROD1
DRILL
TRIP
P
RIH with BHA#5 from 496' MD to
496.0
1,820.0
11:45
13:00
1820' MD.
4/8/2019
4/8/2019
0.50
PROD1
DRILL
DHEQ
P
Shallow hole test MWD. 500 gpm, 995
1,820.0
1,820.0
13:00
13:30
psi, 17% FO, PU=94K SO=106K
Page 12/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
Start Depth
(ftKB)
End Depth (ftKB)
4/8/2019
4/8/2019
1.00
PROD1
DRILL
TRIP
P
RIH with BHA#5 from 1820' MD to
1,820.0
3,429.0
13:30
14:30
3429' MD. Break circ and obtain
SPR's. PU=126K SO=140K
SPR: 3425' MD 3425' TVD, MW 9.5
ppg. @ 14:30 hrs
#1) 30 spm=200 psi 40 spm=250 psi
#2) 30 spm=200 psi 40 spm=260 psi
4/8/2019
4/8/2019
3.00
PROD1
DRILL
DLOG
P
MAD pass from 3429' MD to 3606' MD
3,429.0
3,606.0
14:30
17:30
at 75 fph. 550 gpm, 1412 psi, 18%
FO, 120 rpm, 1 K tq. PU=126K
SO=140K Rot=129K
4/8/2019
4/8/2019
6.00
PROD1
DRILL
DDRL
P
Drill 8-1/2" production hole from 3606'
3,606.0
4,050.0
17:30
23:30
MD to 4050' MD. 4050' TVD 550 gpm
1555 psi. 17% F/O, 120 rpm 4K tq.
11 K WOB, off bottom:1481 psi/4K tq.
PU=144K SO=149K Rot=145K.�
ECD=11.42 Max gas=31 units
ADT=4.54 Bit hrs=21.41 Jar hrs=67
4/8/2019
4/9/2019
0.50
PROD1
CASING
CIRC
P
CBU. 550 gpm, 1450 psi, 17% FO,
4,050.0
4,050.0
23:30
00:00
120 rpm, 1 K tq.
SPR: 4550' MD 4550' TVD, MW 9.5
ppg. @ 23:30 hrs
#1) 30 spm=160 psi 40 spm=240 psi
#2) 30 spm=170 psi 40 spm=240 psi
4/9/2019
4/9/2019
1.00
PROD1
CASING
CIRC
P
Continue CBU. 550 gpm, 1450 psi,
4,050.0
4,050.0
00:00
01:00
17% FO, 120 rpm, 1 K tq.
4/9/2019
4/9/2019
0.50
PROD1
CASING
OWFF
P
Monitor well. (No Flow)
4,050.0
4,050.0
01:00
01:30
4/9/2019
4/9/2019
7.25
PROD1
CASING
BKRM
P
BROOH F/4,050' - T/1,820' MD- GPM
4,050.0
1,820.0
01:30
08:45
546, Psi. 1347. rpm= 120 TQ. 1.2 P/U
118k S/O 124k. Rot. 110k, Pullin tight
@ 3,811' - 3,543' - Max Gas 15 Units
4/9/2019
4/9/2019
1.25
PROD1
CASING
CIRC
P
CBU. 545 gpm, 1110 psi, 17% FO,
1,820.0
1,820.0
08:45
10:00
120 rpm, 1 K tq. Pumped totaal of
7188 stks. until shakers clean up
4/9/2019
4/9/2019
0.50
PROD1
CASING
OWFF
P
Monitor well. (No Flow)
1,820.0
1,820.0
10:00
10:30
4/9/2019
4/9/2019
0.50
PROD1
CASING
TRIP
P
POOH F/1,820' - T/596' stand back
1,820.0
596.0
10:30
11:00
hwdp & MN flex dc.
4/9/2019
4/9/2019
0.50
PROD1
CASING
OWFF
P
Monitor well. (No Flow) PJSM on L/D
596.0
596.0
11:00
11:30
BHA & unload source
4/9/2019
4/9/2019
2.00
PROD1
CASING
BHAH
P
Laydown BHA
596.0
0.0
11:30
13:30
4/9/2019
4/9/2019
1.00
PROD!
CASING
BOPE
P
Clear floor, drain BOP stack, pull wear
13:30
14:30
bushing, blow down choke & kill
4/9/2019
4/9/2019
2.00
PROD1
CASING
BOPE
T
Atempt to install test plug, but would
14:30
16:30
not seal. pull test plug, install wear
ring, clean out BOPE. pull wear ring,
install test plug. fill BOPE. (good seal)
4/9/2019
4/9/2019
0.50
PROD1
CASING
BOPE
P
Shell Test BOPE
16:30
17:00
1
Page 13/18 Report Printed: 5/6/2019
4
Operations Summary (with Timelog Depths)
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
4/9/2019
4/9/2019
6.00
PROD1
CASING
BOPE
P
Test BOPE with 5" test joint & 3 % test
17:00
23:00
joint, Test Annular preventer, Choke
manifold valve 1,12,13,14 and 4" Kill
line on mud manifold, 4-1/2 IF Dart
Valve. Test Top Rams Choke manifold
with valves 9 & 11, Mezz. Kill line and
4-1/2 IF FOSV., Test Choke manifold
valves 8,10 and Manual Kill. Test
valves 6 and 7. Super choke and
manual choke, test to 2000 psi. Test
Choke manifold valves 2 and 5,
Manual Kill. Test HCR choke and
upper IBOP valve. Test Manual choke
and lower IBOP valve. Test Lower
rams. Test Blinds choke manifold
valves 3,4 and 6. 3 '% test joint to 250
low/5 mins and 3500 high/10 mins. 5"
test joint 250 low/5 min 3500 high/5
min. Accumulator draw down test/
Starting pressure=3000 psi, after
function=1800 psi, 200 psi
attained=10 sec's, full recovery=68
sec. 6 nitrogen bottles at 2083 psi.
Test gas alarms, PVT and flow show.
(Test witnessed by BLM Rep. Quinn
Sawyer. Witness waived by AOGCC
Austin McLeod.) Manual kill valve line
failed to test. Change out Manual kill
line valve and test to 250 psi/5 mins,
3500 psi/10 mins.
4/9/2019
4/10/2019
1.00
PROD1
CASING
BOPE
T
Atempt to re -test the manual kill line
23:00
00:00
valve and failed. replace with new
manual kill line valve
4/10/2019
4/10/2019
4.25
PROD1
CEMENT
BOPE
T
Replace manual kill line valve and test
00:00
04:15
to 250/low 5min 3500 high for 10min
4/10/2019
4/10/2019
0.75
PROD1
EVALFM
RURD
P
Spot Schlumberger a -line unit.
04:15
05:00
Simops: drain stack, blow down
equipment. install wear bushing
4/10/2019
4/10/2019
0.50
PROD1
EVALFM
SFTY
P
PJSM on rigging up & running wireline
05:00
05:30
logs
4/10/2019
4/10/2019
3.00
PROD!
EVALFM
RURD
P
Rig up wireline sheaves. Pick up wire
05:30
08:30
line tools from pipeshed. Function test
to @ floor level.
4/10/2019
4/10/2019
1.75
PROD1
EVALFM
ELOG
P
RIH with caliper run #1 to 4,050'
0.0
4,050.0
08:30
10:15
4/10/2019
4/10/2019
1.75
PROD1
EVALFM
ELOG
P
Log up from 4,050' to 1,831'.
4,050.0
1,831.0
10:15
12:00
4/10/2019
4/10/2019
1.00
PROD1
EVALFM
ELOG
P
POOH with caliper run from 1831'
1,831.0
0.0
12:00
13:00
4/10/2019
4/10/2019
2.25
PROD1
EVALFM
RURD
P
Laydown caliper tools and pick up
0.0
3,600.0
13:00
15:15
BHA#2 tripple combo. RIH to 3,600'
4/10/2019
4/10/2019
1.00
PROD1
EVALFM
ELOG
P
Log out of the hole @ 900 fpm
3,600.0
0.0
15:15
16:15
4/10/2019
4/10/2019
1.75
PROD1
EVALFM
RURD
P
Laydown wireline BHA#2 pick up BHA
0.0
16:15
18:00
#3 CMR-NEST-ADT.
4/10/2019
4/10/2019
0.75
PROD1
EVALFM
ELOG
P
RIH with BHA#3 CMR-NEST-ADT. to
0.0
4,050.0
18:00
18:45
4,050'
4/10/2019
4/10/2019
2.00
PROD1
EVALFM
ELOG
P
Log out of the hole @ 900 fpm from
4,050.0
0.0
18:45
20:45
4,050'
4/10/2019
4/10/2019
0.75
PROD1
EVALFM
RURD
P
Laydown BHA #3 CMR-NEST-ADT.
0.0
20:45
21:30
4/10/2019
4/11/2019 i
2.50
PROD1
EVALFM
ELOG
P
Make up wireline BHA#4 MDT. RIH to
0.0
3,641.0
21:30
00:00
3,641.
Page 14/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
4/11/2019
4/11/2019
0.75
PROD1
EVALFM
ELOG
P
Continue wireline BHA #4 MDT
3,641.0
00:00
00:45
4/11/2019
4/11/2019
0.25
PROD1
EVALFM
ELOG
P
POOH with BHA #4 MDT due to tool
3,641.0
0.0
00:45
01:00
not responding.
4/11/2019
4/11/2019
1.00
PROD1
EVALFM
ELOG
P
Replace tool that not responding,
0.0
01:00
02:00
Make up BHA#4 MDT. function test
tool @ surface.
good test
4/11/2019
4/11/2019
4.00
PROD1
EVALFM
ELOG
P
RIH with BHA #4 MDT to 3,641'
0.0
3,641.0
02:00
06:00
Phase 3 called 17:00
4/11/2019
4/12/2019
18.00
PROD1
EVALFM
ELOG
P
Continue logging with BHA#4 MDT @
3,641.0
2,284.0
06:00
00:00
2,284' SIMOPS: clean and paint
BOPE
4/12/2019
4/12/2019
4.00
PROD1
EVALFM
ELOG
P
Continue logging with BHA #4 MDT @
2,284.0
3,641.0
00:00
04:00
2,284' SIMOPS: clean and paint
BOPE
4/12/2019
4/12/2019
0.75
PROD1
EVALFM
ELOG
P
POOH with wireline BHA #4 MDT.
3,641.0
0.0
04:00
04:45
4/12/2019
4/12/2019
0.50
PROD1
EVALFM
ELOG
P
PJSM with wireline operation on laying
0.0
0.0
04:45
05:15
down BHA #4 and Picking up BHA *5
4/12/2019
4/12/2019
4.75
PROD1
EVALFM
ELOG
P
Laydown BHA#4 MDT in to the
0.0
0.0
05:15
10:00
pipeshed, Pick up BHA#5 XL -Rock
assy. and function test @ surface.
4/12/2019
4/12/2019
10.00
PROD1
EVALFM
ELOG
P
RIH with schlumberger wireline XL-
3,620.0
3,210.0
10:00
20:00
Rock assy. for 52 samples 3,620'
4/12/2019
4/13/2019
4.00
PROD1
EVALFM
ELOG
P
POOH, trouble shoot wireline XL -Rock
3,210.0
0.0
20:00
00:00
assy. Attempt to fix the assembly with
no success. Lay down tool. 42 core
samples recovered
4/13/2019
4/13/2019
10.00
PROD1
EVALWB
WAIT
T
Wait on phase 3 conditions to clear
0.0
00:00
10:00
4/13/2019
4/13/2019
0.75
PROD1
EVALFM
RURD
P
Rig down SLB wireline tools and
10:00
10:45
equipment
4/13/2019
4/13/2019
0.75
PROD1
EVALFM
BHAH
P
Make up clean out BHA, RIH to 380'
0.0
380.0
10:45
11:30
4/13/2019
4/13/2019
0.75
PROD1
EVALFM
TRIP
P
RIH with 5" drill pipe to 1,793' PUW=
380.0
1,793.0
11:30
12:15
89k SOW= 83k
4/13/2019
4/13/2019
1.25
PROD1
EVALFM
CIRC
P
Circ at the shoe stagingg pumps up to
1,793.0
12:15
13:30
420 gpm. 14% F/O 540 psi.
4/13/2019
4/13/2019
2.50
PROD1
EVALFM
TRIP
P
RIH with 5" drill pipe from 1,793' - to
1,793.0
3,774.0
13:30
16:00
3,974'
4/13/2019
4/13/2019
0.50
PROD1
EVALFM
WASH
P
Wash down from 3,974' - to 4.050' @
3,794.0
4,050.0
16:00
16:30
500 gpm 950psi. 40 rpm 1.5k tq
4/13/2019
4/13/2019
1.50
PROD1
EVALFM
CIRC
P
Clrc hole clean Per mud engineer @
4,050.0
16:30
18:00
500 gpm 998 psi. 40 rpm max gas
1000 units at B/U
4/13/2019
4/13/2019
1.50
PROD1
EVALFM
CIRC
P
Pump 25bbl. Hi-vis sweep. Sweep
18:00
19:30
brought back 10% more cuttings
4/13/2019
4/13/2019
0.50
PROD1
EVALFM
OWFF
P
Monitor well. (No Flow)
19:30
20:00
4/13/2019
4/13/2019
0.50
PROD1
EVALFM
TRIP
P
POOH with 5 stands on the trip tank.
4,050.0
3,406.0
20:00
20:30
hole swab. .5 bbl. and pulled tight from
3,560' - to 3,406'
4/13/2019
4/14/2019
3.50
PROD1
EVALFM
BKRM
P
BROOH From 3,406' - to 2,558'
3,406.0
2,558.0
20:30
00:00
500gpm 850 psi. 40 rpm 1.7 tq. 18%
f/o max gas 9 units
4/14/2019
4/14/2019
2.00
PROD1
EVALFM
REAM
P
BROOH F/2,558'-T/1,797'500
2,558.0
1,797.0
00:00
02:00
gpms 873psi. 19% F/O PUW 83K
4/14/2019
4/14/2019
0.50
PROD1
EVALFM
OWFF
P
Monitor well (no flow) blow down top
1,797.0
0.0
02:00
02:30
drive
Page 15/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
M TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
4/14/2019
4/14/2019
1.00
PROD1
EVALFM
TRIP
P
POOH on elevators F/1,797' - T/379'
1,797.0
379.0
02:30
03:30
4/14/2019
4/14/2019
0.25
PROD1
EVALFM
OWFF
P
Monitor well (no flow)
379.0
0.0
03:30
03:45
4/14/2019
4/14/2019
1.25
PROD1
EVALFM
BHAH
P
Lay down BHA: 5" HWDP, JAR,
379.0
0.0
03:45
05:00
NMDC, Near Bit Stabe, and bit
4/14/2019
4/14/2019
1.25
PROD1
EVALFM
OTHR
P
Make up stack washer and clean out
0.0
0.0
05:00
06:15
BOPE.
4/14/2019
4/14/2019
0.75
PROD1
CASING
OTHR
P
Close blind rams, open annulas valve,
0.0
0.0
06:15
07:00
change upper pipe rams 4.5" X 7"
VBR pipe rams
4/14/2019
4/14/2019
1.00
PROD1
CASING
RURD
P
Pull wear ring with FMC Rep. and
0.0
0.0
07:00
08:00
install Testr plug
4/14/2019
4/14/2019
1.50
PROD1
CASING
BOPE
P
Test 4.5" X 7" VBR pipe rams 250/low
0.0
0.0
08:00
09:30
for 5min 3500/high for 10 min. Test
was witness by CPIA rep.
4/14/2019
4/14/2019
1.00
PROD1
CASING
RURD
P
Rig down, blow down test eqipment
0.0
0.0
09:30
10:30
4/14/2019
4/14/2019
1.00
PROD1
CASING
RURD
P
Rig up to run 7" 26# 563 Hydril casing
0.0
0.0
10:30
11:30
4/14/2019
4/14/2019
0.25
PROD1
CASING
SFTY
P
Pre -job safety meeting with GBR and
0.0
0.0
11:30
11:45
rig crew
4/14/2019
4/14/2019
1.25
PROD1
CASING
PUTB
P
Pick shoe track, run in the hole to 82'
0.0
82.0
11:45
13:00
and check floats,
4/14/2019
4/14/2019
2.00
PROD1
CASING
PUTB
P
RIH with 7", 26 ppf, L-80, TXP-m
i82.1
1,135.0
casing T/1,135'
13:00
15:00
4/14/2019
4/14/2019
0.50
PROD1
CASING
RGRP
T
Change out wash pipe and presure
1,135.0
0.0
15:00
15:30
test to 3000 psi.
4/14/2019
4/14/2019
1.00
PROD1
CASING
PUTB
P
Continue RIH with 7", 26 ppf, L-80,
1,135.0
1,831.0
15:30
16:30
TXP-mcasing 1,135-T/1,831'
4/14/2019
4/14/2019
0.75
PROD1
CASING
CIRC
P
Circ. bottoms up at 1,831' 250 gpm
i 1,831.0
0.0
16:30
17:15
165psi.
4/14/2019
4/14/2019
2.50
PROD1
CASING
PUTB
P
Continue RIH with 7", 26 ppf, L-80,
1,831.0
2,433.0
17:15
19:45
TXP-m casing F/1,831' - to 2,433'
Continue RIH with 7", 26 ppf, L-80,
TXP-m casing F/1,831' - to 2,433'
encountered tight hole
4/14/2019
4/14/2019
0.50
PROD1
CASING
WASH
P
Washed trough F/2,433' - T/2,461' @
2,433.0
2,461.0
19:45
20:15
168 gpm 205 psi.
4/14/2019
4/14/2019
3.00
PROD1
CASING
PUTB
P
Continue RIH with 7", 26 ppf, L-80,
2,461.0
3,922.0
20:15
23:15
TXP-m casing, F/2,461 - T/3,922'
4/14/2019
4/15/2019
0.75
PROD1
CASING
CIRC
T
Circ. condition mud @ 3,922'. 7"
3,922.0
23:15
00:00
hanger and running tool would not
mack up. waiting on new landing joint
and new hanger.
4/15/2019
4/15/2019
2.50
PROD1
CASING
PUTB
T
Circ and Recip. casing @ 2120gpm
3,881.0
3,992.0
00:00
02:30
290psi. 8%F/O pumped 4460 stks
4/15/2019
4/15/2019
0.50
PROD1
CASING1HOSO
PUTB
P
RIH F/3,922' - T/4,005' PUW=125
3,992.0
4,005.0
02:30
03:00
SOW=129
4/15/2019
4/15/2019
1.50
PROD1
CASING
P
Make FMC Mandrel casing hanger,
4,005.0
4,044.0
03:00
04:30
Wash down From 4,005' - T/4,044'
295gpm 456 psi. PUW= 124, SOW=
124
4/15/2019
4/15/2019
0.75
PROD1
CASING
RURD
P
Rig up cement hose, Recip casing 30'
4,044.0
04:30
05:15
at 4bpm 250 psi. 6% F/O PUW= 138k
SOW=138k
4/15/2019
4/15/2019
0.50
PROD1
CEMENT
SFTY
P
PJSM with Halliburton cementers,
0.0
0.0
05:15
05:45
Jacobs truck drivers, ACS, rig crews
Page 16/18 Report Printed: 5/6/2019
Operations Summary (with Timelog Depths)
TINMIAQ 13
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
4/15/2019
4/15/2019
3.75
PROD1
CEMENT
CMNT
P
Pump 5 bbls water. Test lines to 2500
0.0
05:45
09:30
psi. Mix and pump 60 bbls 11.5 ppg
Mud Push 11 at 5 bpm, 210 psi, 4%
FO. Drop bottom plug. Mix and pump
52 bbls (249 sks) of 15.8 ppg cement
at 2 bpm, 230 psi, 4% FO. Drop top
plug. Pump 1 bbls water. Displace with
C.b
rig pumps 9.5 ppg corrosion inhibited
KCI at 4 bpm, 500 psi, Reciprocate in
ll
20' strokes. reduce rate to 2 bpm at
1375 stks. Land hanger at 1400 stks
pumped, 1212psi., 4% F/O. Bump
plugs at 1537 stks. Pressure up to
1815 psi and held for 5 mins. CIP at
09:13 hrs. Checked floats floats did
not hold, Pressure up well to 400 psi.
held for 1 Hour, check floats, not
holding,. Reciprocated pipe
throughout job. 100% returns
4/15/2019
4/15/2019
8.50
PROD1
CEMENT
CMNT
T
Pressure up Well to 400 PSI Hold For
0.0
0.0
09:30
18:00
1 Hour, Check Floats, Not Holding,
Pressure Up to 1300 PSI, Hold For 5
Hours, Check Floats, Floats Held,
4/15/2019
4/15/2019
1.50
PROD1
CEMENT
RURD
P
Lay down landing joint clear rig floor
0.0
0.0
18:00
19:30
4/15/2019
4/15/2019
2.00
PROD1
CEMENT
WWSP
P
Install 7" pack off and test to 5000 psi.
0.0
0.0
19:30
21:30
hied for 10 min.
4/15/2019
4/16/2019
2.50
PROD1
CEMENT
FRZP
P
Rig up Little Red and Rig mud pumps
0.0
0.0
21:30
00:00
to O/A. PT lines to 2000 psi.
4/16/2019
4/16/2019
0.75
PROD1
CEMENT
FRZP
P
Injected 53bbl. of fresh water with rig
0.0
0.0
00:00
00:45
pumps @ 2bpm. Broke down
formation @ 600psi. injection rate was
510 @ 2bpm.
4/16/2019
4/16/2019
0.75
PROD1
CEMENT
FRZP
P
LSR inject 28bbl. freeze protect down
0.0
0.0
00:45
01:30
the C/A @ 2bpm 650psi.
4/16/2019
4/16/2019
1.50
PROD1
CEMENT
PRTS
P
Rig up and Test casing to 3500 psi.
0.0
0.0
01:30
03:00
hold for 30 min. bled back 2.1 bbl. in
trip tank
4/16/2019
4/16/2019
1.00
PROD1
RPCOMP
SFTY
P
PJSM with schlumberger wireline
0.0
0.0
03:00
04:00
4/16/2019
4/16/2019
1.50
PROD1
RPCOMP
ELOG
P
Make up 6.1 gauge ring, junk catcher
0.0
3,955.0
04:00
05:30
and RIH to 3,955'
4/16/2019
4/16/2019
0.50
PROD1
RPCOMP
ELOG
P
POOH with 6.1 gauge ring, junk
3,955.0
0.0
05:30
06:00
catcher
4/16/2019
4/16/2019
0.50
PROD1
RPCOMP
ELOG
P
Make up CBL logging tools RIH 3,955'
.0
3,955.0
06:00
06:30
02,
4/16/2019
4/16/2019
3.00
PROD1
RPCOMP
ELOG
P
Log up from 3,955'- T/1,831' POOH,
3,955.0
0.0
06:30
09:30
R/D wireline equipment.
4/16/2019
4/16/2019
1.00
PROD1
RPCOMP
RURD
P
Change out upper pipe rams to 3.5 x
0.0
09:30
10:30
6" VBR M/U, R/U test equipment.
4/16/2019
4/16/2019
1.50
PROD1
RPCOMP
BOPE
P
Test with 3.5 & 4.5 Test jnt. 4" TIW and
10:30
12:00
Dart valve. Test 250/low 5min
3500/high 10min
4/16/2019
4/16/2019
1.00
PROD1
RPCOMP
RURD
P
Rig down & blow down test equipment
0.0
0.0
12:00
13:00
4/16/2019
4/16/2019
1.00
PROD1
RPCOMP
RURD
P
Rig up casing equipment with GBR.
0.0
0.0
13:00
14:00
4/16/2019
4/16/2019
9.50
PROD1
RPCOMP
PUTB
P
RIH with 3.5", 9.3# L-80 EUE-m
0.0
3,515.0
14:00
23:30
tubing to 3,515
4/16/2019
4/17/2019
0.50
PROD1
RPCOMP
THGR
P
Make up Hanger, terminate control
3,515.0
0.0
23:30
00:00
line.
4/17/2019
4/17/2019
1.00
PROD1
RPCOMP
THGR
P
Test Tech wire hanger penetration
0.0
00:00
01:00
5000 for 10min
Page 17/18 Report Printed: 5/6/2019
�t
Operations Summary (with Timelog Depths)
TINMIAQ 13
! ! • R
Rig: DOYON 142
Job:
DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
(ftKB)
End Depth (ftKB)
4/17/2019
4/17/2019
0.50
PROD1
RPCOMP
THGR
P
Test Tech wire hanger penetration
01:00
01:30
5000 for 10min
4/17/2019
4/17/2019
0.50
PROD1
RPCOMP
PACK
P
Drop ball and rod Set Packer per
01:30
02:00
Baker Hughes Rep. 2600psi.
4/17/2019
4/17/2019
1.50
PROD1
RPCOMP
PRTS
P
Perssured up to 4600 psi to pressure
02:00
03:30
test tubing
Hold 4600psi for 30 minutes
4/17/2019
4/17/2019
1.00
PROD1
RPCOMP
PRTS
P
Bleed tubing to 2000psi. Pressure up
t
03:30
04:30
Inner Annulus to 3500psi hold for 30
min.
4/17/2019
4/17/2019
1.00
PROD1
RPCOMP
PRTS
P
Bleed pressure on tubing to 0 and
04:30
05:30
sheared SOV. Pumped both ways to
verify the it sheared
4/17/2019
4/17/2019
0.50
PROD1
RPCOMP
MPSP
P
Lay down landing joint and install BPV,
05:30
06:00
and test 2500psi/10 min
4/17/2019
4/17/2019
5.00
PROD1
RPCOMP
NUND
P
ND BOP Stack N/U Tree and adapter.
06:00
11:00
4/17/2019
4/17/2019
2.50
PROD1
RPCOMP
THGR
P
Pressure test the tubing hanger x
11:00
13:30
adaptor void to 5000psi for 10
minutes.
4/17/2019
4/17/2019
1.50
PROD1
RPCOMP
PULD
P
Freeze Protect the IA with 38bbl. of
13:30
15:00
diesel pumping at 1.5bpm 120psi. let
L-
U iabe ---- --- ---- - -- _
4/17/2019
4/17/2019
1.00
PROD1
RPCOMP
MPSP
P
Install H-BPV, and test 2500psi/10 min
15:00
16:00
install VR plugs in O/A and I/A
4/17/2019
4/17/2019
6.00
PROD1
RPCOMP
PULD
P
La mouse
16:00
22:00
hole,
4/17/2019
4/17/2019
1.00
PROD1
RPCOMP
CLEN
P
Clean pits, flush lines, blow down
22:00
23:00
equipment.
4/17/2019
4/18/2019
1.00
PROD1
MOVE
DMOB
P
Prepair rig to move to 3 G-27
23:00
00:00
Rlg released @ 20:00 4/17/2019
Page 18118
Report Printed: 5/6/2019
NADConversion
North Alaska ASP4
Willow North
Tinmiaq 13
Tinmiaq 13
NAD 27 ASP 5
ConocoPhillips
Definitive Survey Report
01 May, 2019
Final Definitive Survey
Verified and Signed -off
All targets andAlor well position objectives have been achieved
l have checked to the best of my ability that the following data is correct:
C7 Surface Coordinates
1-1 Declination & Convergence
GRS Surrey Corrections
, _ Surrey Too] Codes
sus Imo; Brandon Te rl i e Digitally signed by Brandon Temple
f Date, 2019.GS.O1 , 3:25. t 2 -08"00 '
Client Representative:
Date: 511 M I9
ConocoPhillips
ConocoPhillips N A D 27 ASP 5
Definitive Survey Report
Company:
NADConversion
Local Co-ordinate Reference:
Well Tinmiaq 13
Project:
North AlaskaASP4
TVD Reference:
D 141 ACTUAL @ 148.3usft (D 14 1)
Site:
Willow North
MD Reference:
D141 ACTUAL @ 148.3usft (D141)
Well:
Tinmiaq 13
North Reference:
True
Wellbore:
Tinmiaq 13
Survey Calculation Method:
Minimum Curvature
Design:
Tinmiaq 13
Database:
OAKEDMPI
project North Alaska ASP4
Aap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
3eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Aap Zone: Alaska Zone 05 Using geodetic scale factor
Well
Tinmiaq 13
Well Position
+N/-S
0.0 usft Northing:
5,983,339.57 usft Latitude:
70' 21' 28.718 N
+E/-W
0.0 usft Easting:
705,960.61 usft Longitude:
152' 19' 37.362 W
Position Uncertainty
0.0 usft Wellhead Elevation:
usft Ground Level:
120.6 usft
Wellbore
Tinmiaq 13
Magnetics
Model Name
Sample Date
Declination Dip Angle
Field Strength
BGGM2018
4/1/2019
15.81 80.67
57,350.85287003
Design
Tinmiaq 13
Audit Notes:
Version:
1.0
Phase: ACTUAL
Tie On Depth: 27.7
Vertical Section:
Depth From (TVD)
+N/-S
+E/-W Direction
(usft)
(usft)
(usft) (°)
27.7
0.0
0.0 122.90
Survey Program
Date
From
To
(usft)
(usft) Survey (Wellbore)
Tool Name
Description
Survey Date
137.9
262.2 Survey #1 BHA01 INC (Tinmiaq 13)
INC
Inclinometer (Totco/Teledrift)
4/8/2019
1:23:0
353.8
353.8 Survey #2 BHA01 MWD (Tinmiaq 13)
MWD OWSG
OWSG MWD - Standard
5/1/2019
9520
448.0
1,835.9 Survey #3 BHA02 MWD (Tinmiaq 13)
MWD OWSG
OWSG MWD - Standard
5/1/2019
9:53:0
1,929.6
2,024.8 Survey #4 BHA03 INC (Tinmiaq 13)
INC
Inclinometer (Totco/Teledrift)
5/1/2019
9:54:0
2,119.3
3,444.7 Survey #5 BHA03 MWD (Tinmiaq 13)
MWD OWSG
OWSG MWD - Standard
5/1/2019
9:55:0
3,539.1
3.973.1 Survey #6 BHA04 MWD (Tinmiaq 13)
MWD OWSG
OWSG MWD - Standard
5/1/2019
9560
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/-S
+E/-W
Northing
Easting
DLS
Section
(usft)
(°)
(I
(usft)
(usft)
(usft)
(usft)
(ft)
(ft)
(°/100')
(ft) Survey Tool Name
27.7
0.00
0.00
27.7
-120.6
0.0
0.0
5,983,339.6
705,960.6
0.0
0.00 UNDEFINED
137.9
0.51
322.84
137.9
-10.4
0.4
-0.3
5,983,339.9
705,960.3
0.5
-0.46 INC (1)
168.2
0.51
325.51
168.2
19.9
0.6
-0.5
5,983,340.2
705,960.1
0.1
-0.71 INC (1)
262.2
0.61
316.06
262.2
113.9
1.3
-1.0
5,983,340.9
705,959.5
0.1
-1.59 INC (1)
353.8
0.51
331.02
353.8
205.5
2.0
-1.6
5,983,341.5
705,959.0
0.2
-2.42 MWD OWSG (2)
448.0
0.49
333.10
448.0
299.7
2.7
-2.0
5,983,342.3
705,958.6
0.0
-3.14 MWD OWSG (3)
542.3
0.44
325.48
542.3
394.0
3.4
-2.3
5,983,342.9
705,958.2
0.1
-3.82 MWD OWSG (3)
636.1
0.52
321.07
636.1
487.8
4.0
-2.8
5,983,343.5
705,957.7
0.1
-4.56 MWD OWSG (3)
731.1
0.45
320.28
731.1
582.8
4.7
-3.3
5,983,344.1
705,957.2
0.1
-5.32 MWD OWSG (3)
826.4
0.58
316.79
826.4
678.1
5.3
-3.9
5,983,344.8
705,956.6
0.1
-6.15 MWD OWSG (3)
5/1/2019 1:17:50PM Page 2 COMPASS 5000.14 Build 85D
ConocoPhillips N A D 27 ASP 5
Definitive Survey Report
Company:
NADConversion
Local Co-ordinate Reference:
Well Tinmiaq 13
Project:
North AlaskaASP4
TVD Reference:
D141 ACTUAL@ 148.3usft (D141)
Site:
Willow North
MD Reference:
D141 ACTUAL @ 148.3usft (D141)
Well:
Tinmiaq 13
North Reference:
True
Wellbore:
Tinmiaq 13
Survey Calculation Method:
Minimum Curvature
Design:
Tinmiaq 13
Database:
OAKEDMPI
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+NI-S
+E/-W
Northing
Easting
DLS
Section
(usft)
(°)
(')
(usft)
(usft)
(usft)
(usft)
(ft)
(it)
(°/100-)
(ft)
Survey Tool Name
920.2
0.52
324.88
920.2
771.9
6.0
-4.5
5,983,345.4
705,956.0
0.1
-7.00
MWD OWSG (3)
1,015.5
0.32
303.44
1,015.5
867.2
6.5
-4.9
5,983,345.9
705,955.5
0.3
-7.67
MWD OWSG (3)
1,109.9
0.54
306.93
1,109.8
961.5
6.9
-5.5
5,983,346.3
705,954.9
0.2
-8.38
MWD OWSG (3)
1,204.0
0.60
299.34
1,203.9
1,055.6
7.4
-6.3
5,983,346.8
705,954.1
0.1
-9.31
MWD OWSG (3)
1,298.7
0.47
315.56
1,298.6
1,150.3
7.9
-7.0
5,983,347.3
705,953.4
0.2
-10.19
MWD OWSG (3)
1,393.7
0.35
299.02
1,393.7
1,245.4
8.4
-7.5
5,983,347.7
705,952.9
0.2
-10.86
MWD OWSG (3)
1,487.3
0.49
280.65
1,487.2
1,338.9
8.6
-8.2
5,983,347.9
705,952.2
0.2
-11.51
MWD OWSG (3)
1,582.9
0.54
288.19
1,582.9
1,434.6
8.8
-9.0
5,983,348.1
705,951.4
0.1
-12.33
MWD OWSG (3)
1,677.0
0.55
284.92
1,676.9
1,528.6
9.0
-9.9
5,983,348.3
705,950.5
0.0
-13.18
MWD OWSG (3)
1,764.9
0.46
272.02
1,764.8
1,616.5
9.2
-10.6
5,983,348.4
705,949.7
0.2
-13.89
MWD OWSG (3)
1,835.9
0.20
260.16
1,835.8
1,687.5
9.1
-11.0
5,983,348.4
705,949.3
0.4
-14.22
MWD OWSG (3)
1,929.6
0.06
193.78
1,929.6
1,781.3
9.1
-11.2
5,983,348.3
705,949.2
0.2
-14.33
INC (4)
2,024.8
0.04
192.00
2,024.7
1,876.4
9.0
-11.2
5,983,348.2
705,949.2
0.0
-14.30
INC (4)
2,119.3
0.06
184.11
2,119.3
1,971.0
8.9
-11.2
5,983,348.2
705,949.1
0.0
-14.26
MWD OWSG (5)
2,213.2
0.04
201.73
2,213.1
2,064.8
8.8
-11.2
5,983,348.1
705,949.1
0.0
-14.23
MWD OWSG (5)
2,308.7
0.10
253.96
2,308.6
2,160.3
8.8
-11.3
5,983,348.0
705,949.0
0.1
-14.28
MWD OWSG (5)
2,403.3
0.06
152.43
2,403.2
2,254.9
8.7
-11.4
5,983,348.0
705,949.0
0.1
-14.29
MWD OWSG (5)
2,495.9
0.09
199.96
2,495.9
2,347.6
8.6
-11.4
5,983,347.8
705,949.0
0.1
-14.24
MWD OWSG (5)
2,592.3
0.10
88.79
2,592.2
2,443.9
8.5
-11.3
5,983,347.8
705,949.0
0.2
-14.15
MWD OWSG (5)
2,686.9
0.09
70.54
2,686.9
2,538.6
8.6
-11.2
5,983,347.8
705,949.2
0.0
-14.04
MWD OWSG (5)
2,781.4
0.13
316.86
2,781.4
2,633.1
8.7
-11.2
5,983,347.9
705,949.2
0.2
-14.09
MWD OWSG (5)
2,876.6
0.10
178.41
2,876.5
2,728.2
8.6
-11.3
5,983,347.9
705,949.1
0.2
-14.15
MWD OWSG (5)
2,971.1
0.08
51.04
2,971.1
2,822.8
8.6
-11.2
5,983,347.9
705,949.2
0.2
-14.08
MWD OWSG (5)
3,065.7
0.10
202.57
3,065.6
2,917.3
8.6
-11.2
5,983,347.8
705,949.2
0.2
-14.05
MWD OWSG (5)
3,160.0
0.12
70.19
3,159.9
3,011.6
8.5
-11.1
5,983,347.8
705,949.3
0.2
-13.97
MWD OWSG (5)
3,255.3
0.09
194.00
3,255.2
3,106.9
8.5
-11.0
5,983,347.8
705,949.3
0.2
-13.89
MWD OWSG (5)
3,349.5
0.09
177.92
3,349.5
3,201.2
8.3
-11.1
5,983,347.6
705,949.3
0.0
-13.82
MWD OWSG (5)
3,444.7
0.09
290.33
3,444.7
3,296.4
8.3
-11.1
5,983,347.6
705,949.3
0.2
-13.85
MWD OWSG (5)
3,539.1
0.06
37.03
3,539.1
3,390.8
8.4
-11.2
5,983,347.6
705,949.2
0.1
-13.92
MWD OWSG (6)
3,633.5
0.09
298.21
3,633.4
3,485.1
8.4
-11.2
5,983,347.7
705,949.2
0.1
-13.99
MWD OWSG (6)
3,728.1
0.06
216.62
3,728.0
3,579.7
8.4
-11.3
5,983,347.7
705,949.1
0.1
-14.07
MWD OWSG (6)
3,823.2
0.06
218.43
3,823.2
3,674.9
8.4
-11.4
5,983,347.6
705,949.0
0.0
-14.08
MWD OWSG (6)
3,917.3
0.10
308.94
3,917.3
3,769.0
8.4
-11.5
5,983,347.6
705,948.9
0.1
-14.16
MWD OWSG (6)
3,973.1
0.09
117.32
3,973.1
3,824.8
8.4
-11.5
5,983,347.6
705,948.9
0.3
-14.17
MWD OWSG (6)
4,050.0
0.09
117.32
4,049.9
3,901.6
8.3
-11.3
5,983,347.6
705,949.0
0.0
-14.05
PROJECTED to TD
5/1/2019 1:17 50PM Page 3 COMPASS 5000.14 Build 85D
.
Cement Detail Report
TINMIAQ 13
String: Conductor Cement
Job:
Cement Details
Description
Conductor Cement
Cementing Start Date
3/27/2019 2&
Cementing End Date
3/27/2019 23:00
Wellbore Name
TINMIAQ 13
Comment
Cement Stages
Stage # <Stage Number?>
Description
Conductor Cement
Objective
1
Top Depth (ftKB)
39.4
Bottom Depth (ftKB)
119.0
Full Return?
No
Vol Cement...
Top Plug?
No
I Btm Plug?
No
Q Pump ]nit (bbl/m...
Q Pump Final (bbl/...
Q Pump Avg (bbl/...
P Pump Final (psi)
P Plug Bump (psi)
Recip?
No
I Stroke (ft)
Rotated?
No
I Pipe RPM (rpm)
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB) Drill
Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Btm (ftKB)
Amount (sacks)
Class
Volume Pumped (bbl)
Yield (ft'/sack)
Mix H2O Ratio (gal/sa...
Free Water (%)
Density (lb/gal) Plastic
Viscosity (cP)
Thickening Time (hr)
CmprStr 1 (psi)
Additives
Additive
Type
Concentration
Cone Unit label
Page 1/1
Report Printed: 5/6/2019
Cement Detail Report
TINMIAQ 13
String: Surface Casing Cement
Job: DRILLING ORIGINAL, 3/19/2019 12:00
Cement Details
Description
Cementing Start Date
Cementing End Date
Wellbore Name
Surface Casing Cement
4/3/2019 05:30
4/3/2019 09:45
TINMIAQ 13
Comment
Line up & HES pump 5 bbls water. Pressure test lines to 3500 psi, good. Pump 61.17 bbls of 10.5 ppg CleanSpacer @ 2-3.5 bpm, 75 psi, FO 1-2%. Drop bottom
plug & start batching lead. Pump 213 bbls of 11.0 ppg lead cement at 4 bpm, 148-87 psi, FO 2%. PU 108K, SO 111 K. Land bottom plug at 133 bbls pumped.
Batch and pump 48.4 bbls of 15.8 ppg tail cement @ 4 bpm, 70-130 psi, FO 1 %. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/
10.3 ppg spud mud @ 6 bpm, 230-480 psi, FO 6%.11 ppg lead cement at surface at 70 bbls of displacement away. Reduced rate to 3 bpm. Land hanger at 104
bbls displacement pumped. Bump plug with 1200 strokes, Pressure up to 1088 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 09:42 hrs 04/03/19.
50 bbI 11 ppg cement to surface.
Cement Stages
Stage # 1
Description
Objective
Top Depth (ftKB)
Bottom Depth (ftKB)
Full Return?
Vol Cement...
Top Plug?
Btm Plug?
Surface Casing Cement
Cement to surface.
39.0
1,836.0
Yes
50.0
Yes
Yes
Q Pump Init (bbI/m...
Q Pump Final (bbl/...
Q Pump Avg (bbll...
P Pump Final (psi)
P Plug Bump (psi)
Recip?
Stroke (ft)
Rotated?
Pipe RPM (rpm)
6
3
6
480.0
1,088.0
Yes
20.00
No
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB) Drill
Out Diameter (in)
Comment
Line up & HES pump 5 bbls water. Pressure test lines to 3500 psi, good. Pump 61.17 bbls of 10.5 ppg CleanSpacer @ 2-3.5 bpm, 75 psi, FO 1-2%. Drop bottom
plug & start batching lead. Pump 213 bbls of 11.0 ppg lead cement at 4 bpm, 148-87 psi, FO 2%. PU 108K, SO 111 K. Land bottom plug at 133 bbls pumped.
Batch and pump 48.4 bbls of 15.8 ppg tail cement @ 4 bpm, 70-130 psi, FO 1 %. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/
10.3 ppg spud mud @ 6 bpm, 230-480 psi, FO 6%.11 ppg lead cement at surface at 70 bbls of displacement away. Reduced rate to 3 bpm. Land hanger at 104
bbls displacement pumped. Bump plug with 1200 strokes, Pressure up to 1088 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 09:42 hrs 04/03/19.
50 111 pog cement to surface.
Cement Fluids & Additives
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Btm (ftKB)
Amount (sacks)
Class
Volume Pumped (bbl)
CleanSpacer
0.0
0.0
1
1
61.2
Yield (ft31sack)
Mix H2O Ratio (gal/sa...
Free Water (%)
Density (lb/gal)
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr 1 (psi)
%50
Additives
Additive
Type
Concentration
Conc Unit label
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Btm (ftKB)
Amount (sacks)
Class Volume
Pumped (bbI)
Lead Cement
43.0
1,068.0
495
Type III Cement 213.0
Yield (ft /sack)
Mix H2O Ratio (gal/sa...
Free Water (%)
Density (lb/gal)
Plastic Viscosity (cP)
Thickening Time (hr) CmprStr
1 (psi)
2.42
10.68
11.00
6.00
Additives
Additive
Type
Concentration
Conc Unit label
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Btm (ftKB)
Amount (sacks)
Class Volume
Pumped (bbI)
Tail Cement
1,068.0
1,836.0
235
Type 1 48.4
Yield (ft3/sack)
Mix H2O Ratio (gal/sa...
Free Water (%)
Density (lb/gal)
Plastic Viscosity (cP)
Thickening Time (hr) CmprStr
1 (psi)
1.16
5.01
15.80
3.00
Additives
Additive
Type
Concentration
Conc Unit label
Page 1/1 Report Printed: 5/6/2019
Cement Detail Report
TINMIAQ 13
String: Production Casing Cement
Job:
Cement Details
Description
Cementing Start Date
Cementing End Date
Wellbore Name
Production Casing Cement
4/15/2019 Of
4/15/2019 09:15
TINMIAQ 13
Comment
Pump 5 bbls water. Test lines to 2500 psi. Mix and pump 60 bbls 11.5 ppg Mud Push II at 5 bpm, 210 psi, 4% FO. Drop bottom plug. Mix and pump 52 bbls (249
sks) of 15.8 ppg cement at 2 bpm, 230 psi, 4% FO. Drop top plug. Pump 1 bbls water. Displace with rig pumps 9.5 ppg corrosion inhibited KCI at 4 bpm, 500 psi,
Reciprocate in 20' strokes. reduce rate to 2 bpm at 1375 stks. Land hanger at 1400 stks pumped, 1212psi., 4% F/O. Bump plugs at 1537 stks. Pressure up to
1815 psi and held for 5 mins. CIP at 09:13 hrs. Checked floats floats did not hold, Pressure up well to 400 psi. held for 1 Hour, check floats, not holding,
Pressure up to 1300 PSI, held for 5 hours, check floats, Foats Held. Reciprocated pipe throughout job. 100% returns v'
Cement Stages
Stage # 1
Description
Objective
Top Depth (ftKB)
Bottom Depth (ftKB)
Full Return?
Vol Cement...
Top Plug?
Btm Plug?
Production Casing
Place
2,760.0
4,050.0
Yes
Yes
I
Yes
Cement
Q Pump Init (bbl/m...
Q Pump Final (bbl/...
O Pump Avg (bbl/...
P Pump Final (psi)
P Plug Bump (psi)
Recip?
Stroke (ft)
Rotated?
Pipe RPM (rpm)
1,212.0
1,815.0
Yes
20.00
No
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB) Drill
Out Diameter (in)
Comment
Pump 5 bbls water. Test lines to 2500 psi. Mix and pump 60 bbls 11.5 ppg Mud Push II at 5 bpm, 210 psi, 4% FO. Drop bottom plug. Mix and pump 52 bbls (249
sks) of 15.8 ppg cement at 2 bpm, 230 psi, 4% FO. Drop top plug. Pump 1 bbls water. Displace with rig pumps 9.5 ppg corrosion inhibited KCI at 4 bpm, 500 psi,
Reciprocate in 20' strokes. reduce rate to 2 bpm at 1375 stks. Land hanger at 1400 stks pumped, 1212psi., 4% F/O. Bump plugs at 1537 stks. Pressure up to
1815 psi and held for 5 mins. CIP at 09:13 hrs. Checked floats floats did not hold, Pressure up well to 400 psi. held for 1 Hour, check floats, not holding,
Pressure up to 1300 PSI, held for 5 hours, check floats, Foats Held. Reciprocated pipe throughout job. 100% returns
Cement Fluids & Additives
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Btm (ftKB)
Amount (sacks)
Class
Volume Pumped (bbl)
Yield (ft /sack)
Mix H2O Ratio (gal/sa...
Free Water (%)
Density (lb/gal)
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr 1 (psi)
Additives
Additive
Type
Concentration
Conc Unit label
Page 1/1 Report Printed: 5/6/2019
c
cn
0 =
O
7 _ n
CD >
(� cn
Q a O
O O m
cn
A --I
�_ W
CO Cfl Z
N �
O
n
T
m
CD
-{
C
3
3
D)
C
(D
3
(D
PRE- _URE
N N W W
O O O O O O O O
o =,
u
°
N
n
N
oz,
o
CD CL
w o 3 CA
CO)
o.
N�
wN(0 _0Ofl
(D
oo
(�D
r
k (D
O 3
N_
rt N
c
—1 N N N
CD
y
Q,
W
a
Q
c 3 cD Er
tD
0
A
— r«
(D
T
i 3,
N
o 3
a
RC,
.
ID �.
rt
A �I O
O W
CV7O
3
�'
r �+% W
v m
crcrcr� ��0
H Cl) N Q (0
00
T <
i
00 11
O
1�
-' (D
CI
i
rt
ON
o
S
Q
O
h
�
cn
co
w
x
v N 0)
w
O
—
(D
U
II x _L
O
a
m n
Go
n
T
S
(D
-�
CA m
o
�°
, O
w
(On
n
CD CL
N
o
o =1 � co
3
c
3 3
p
�mm m 3 m
-•
p
ca c' G) (a
m
Ul
(C U)
S mt
C
CD
-�
Q
G
v
=
(n
'
=
�:
3CA
r
-�000 oo
cn
'aN cr
00
CD
(D Cl)y'
N
0
�
Q
N
O
y
N 0
O
Cfl
O
(�D CL
TI
w FS
v
o
H
0 0
(�
rD C
0000
?
N000
OA
PI)
O
3
A
N
O
0)
W
(O
W
W
O
_l
A�
N
=
'
O/ Q
U7
Ut-4—
a)--N
v0)NN
—
tl1 C
O
000
0000
Ul
OOO
rt
O
(D O G
N
—
—
:3
(A
O
O
CD
O
(fl
00
V
O
tT
A
CO
C
co
W
Cl)GJ
W
W
W
W
W
W
W
W
C.)N
N
NNN
N)II
NNNN
(`0
N
N
NNN
NN
W
W
AA(ncn
N
—
\
N
O
cn
(T
cn
cn
Ul
Ul
O
Ul
O
M
O
Ocn
'c
O
Icn
,
ODA
(A
C
V" I Ul
CA CDO
00 A IA cn co
W
U7
O
m
m
In,AA',�`L 13
P716 14
Regg, James B (DOA)
From: Lee, David L<David.L.Lee@conocophillips.com>
Sent: Tuesday, April 16, 2019 8:25 AM <e ( 411C,1,L
To: Regg, James B (DOA); Schwartz, Guy L (DOA); Loepp, Victoria T (DOA); Bixby, Brian D
(DOA)
Cc: Herbert, Frederick 0; Alvord, Chip; Pedam, Sandeep; Doyon 142 Company Man
Subject: RE: [EXTERNAL]RE: Doyon 142 BOP Extension Request - Tinmiaq 13 - PTD# 218-144
Attachments: T-13 7 Production Casing Test.pdf
Jim, attached please find the successful casing test at Tinmiaq 13. If you need anything else please let me know.
Thanks
DL
From: Regg, James B (DOA) <jim.regg@alaska.gov>
Sent: Monday, April 15, 2019 9:44 AM
To: Lee, David L <David.L.Lee @conocophill ips.com>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Loepp, Victoria
T (DOA) <victoria.loepp@alaska.gov>; Bixby, Brian D (DOA) <brian.bixby@alaska.gov>
Cc: Herbert, Frederick 0 <Frederick.O.Herbert@conocophi Ili ps.com>; Alvord, Chip <Chip.Alvord@conocophillips.com>;
Pedam, Sandeep <Sandeep.Pedam@conocophillips.com>; Doyon 142 Company Man <d142cm@conocophillips.com>
Subject: [EXTERNAL]RE: Doyon 142 BOP Extension Request - Tinmiaq 13 - PTD# 218-144
With a successful casing pressure test, the BOPE test (Doyon 142; Tinmiaq #13) is waived since the wellbore is isolated
from the formation and CPAI has no plans to perforate the well before demob.
Jim Regg
Supervisor, Inspections
AOGCC
333 W.7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.
The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907-
793-1236 or iim.regg@alaska.gov.
From: Lee, David L <David.L.Lee 2conocophillips.com>
Sent: Monday, April 15, 2019 9:10 AM
To: Schwartz, Guy L (DOA) <guv.schwartz@alaska.gov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Bixby,
Brian D (DOA) <bnan.bixby@alaska. ov>; Regg, James B (DOA) <jim.regg-alaska.&ov>
Cc: Herbert, Frederick 0 <Frederick.O.Herbert@conoco_hillips.com>; Alvord, Chip <Chip.Alvord@conocophillips.com>;
Pedam, Sandeep <Sandeep.Pedam conocophillips.com>; Doyon 142 Company Man <d142cm@conocophillips.com>
Subject: Doyon 142 BOP Extension Request - Tinmiaq 13 - PTD# 218-144
Guy, Victoria, Jim and Brian, ConocoPhwips would like to request a BOP extension on Doyon 142 out at Tinmiaq
13. Doyon 142 last BOP test was completed on April 10th, 2019, making us due to complete our next test on Doyon 142
on April 17th. Currently we have cemented our production casing string and plan forward is to do our casing pressure
test, CBL, and then run upper completion. RR is estimated to be Wednesday April 171h, 2019. There is no plan to
perforate this well prior to rigging down our BOP's (will not perforate until we plan to come back in a future season to
test). In case we have some trouble time that slips our RR date I would like to proactively request an extension.
Pending the results from our casing pressure test, would the AOGCC be willing to grant Doyon 142 at Tinmiaq 13 a BOP
test extension / waiver as we are isolated from the reservoir?
Thanks, and if you have any questions please let me know.
David Lee
I (Apt 1 413
-ZI6 (yq�
Regg, James B (DOA)
From: Regg, James B (DOA)
Sent: Monday, April 15, 2019 9:44 AM
To: Lee, David L; Schwartz, Guy L (DOA); Loepp, Victoria T (DOA); Bixby, Brian D (DOA)
Cc: Herbert, Frederick 0; Alvord, Chip; Pedam, Sandeep; Doyon 142 Company Man
Subject: RE: Doyon 142 BOP Extension Request - Tinmiaq 13 - PTD# 218-144
With a successful casing pressure test, the BOPE test (Doyon 142; Tinmiaq #13) is waived since the wellbore is isolated
from the formation and CPAI has no plans to perforate the well before demob.
Jim Regg
Supervisor, Inspections
AOGCC
333 W.7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.
The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907-
793-1236 or iim.regg@alaska.gov.
From: Lee, David L<David,L.Lee@conocophillips.com>
Sent: Monday, April 15, 2019 9:10 AM
To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Bixby,
Brian D (DOA) <brian.bixby@alaska.gov>; Regg, James B (DOA) <jim.regg@alaska.gov>
Cc: Herbert, Frederick 0 <Frederick.O.Herbert@conocophillips.com>; Alvord, Chip <Chip.Alvord@conocophillips.com>;
Pedam, Sandeep <Sandeep.Pedam@conocophillips.com>; Doyon 142 Company Man <d142cm@conocophillips.com>
Subject: Doyon 142 BOP Extension Request - Tinmiaq 13 - PTD# 218-144
Guy, Victoria, Jim and Brian, ConocoPhillips would like to request a BOP extension on Doyon 142 out at Tinmiaq
13. Doyon 142 last BOP test was completed on April 10th, 2019, making us due to complete our next test on Doyon 142
on April 171h. Currently we have cemented our production casing string and plan forward is to do our casing pressure
test, CBL, and then run upper completion. RR is estimated to be Wednesday April 17th, 2019. There is no plan to
perforate this well prior to rigging down our BOP's (will not perforate until we plan to come back in a future season to
test). In case we have some trouble time that slips our RR date I would like to proactively request an extension.
Pending the results from our casing pressure test, would the AOGCC be willing to grant Doyon 142 at Tinmiaq 13 a BOP
test extension / waiver as we are isolated from the reservoir?
Thanks, and if you have any questions please let me know.
David Lee
,:?� / g- /Llq
REV
DATE
BY
CK
APP
DESCRIPTION
REV
DATE
BY
CK APP
DESCRIPTION
1
03/29/19
TB
CZ
I DL
ISSUED PER K190003ACS
_
NOTES:r
1. BASIS OF COORDINATES: OPUS SOLUTION OF GPS
STATIC OBSERVATIONS ON 08/26/2018.
COORDINATES
34/
s
36 31 32
2. ARE NAD83, ALASKA STATE PLANE
T12N
THIS i
ZONE 5.
T11
P T
3. ELEVATIONS ARE CONVERTED FROM OPUS NAVD88
2�
1 —
s
TO B.P.M.S.L. VERTICAL DATUM (-3.5' ±DIFF.).
b
```t
4. DISTANCES ARE TRUE. ALL DISTANCES AND
ELEVATIONS ARE IN US SURVEY FEET.
D
5. REFERENCE FIELD BOOK: 2019-09, PG. 45.
` 1
6. DATE OF SURVEY: 03/29/2019.
�15 1
13
17
KUUKPIK
I
UMIAQ
23
? 19
/
ALPINE SURVEY OFFICE
PHONE:907-670-4739
VICINITY MAP
NOT TO SCALE
TINMIAQ 13
LOCATED WITHIN PROTRACTED
j�E '.J. EVE
SECTION 35, T. 12 N., R 2 W.
UMIAT MERIDIAN, ALASKA
32' FNL1706' FWL PREVAILING
AP 2 9 2019
GND ELEV. = 91.2' BPMSL WIND
ICE PAD ELEV. = 93.5' BPMSL //�✓%
TOP OF COND. ELEV. = 93.44' BPMSL
r
NAD83 Datum NAD 27 Datum
N 70°21'27.400" N 70°21'28.715"
f
W 152°19'48.804" W 152°19'37.362"
6°0
ASPC ZN5 ASPIC ZN5
(Y) 5,983,055.502 (Y) 5,983,339.567
(X) 1,845,980.702 (X) 705,960.613
0 200
N
N
N �
M/
^
\
SCALE IN FEET
SEC. 26, T 12 N., R. 2 W.
SEC. 35, T. 12 N., R. 2 W.
1706'
3 3
N
N
33 °
z z o
o,
N N
�L
UJ
AGE P p,0
rn
0
o.
ALPINE
MODULE:AP00 UNIT: AP
ConocoPhillips
TINMIAQ 13
EXPLORATORY
WELL
CONDUCTOR
Alaska, Inc.
AS —BUILT LOCATION
CADD FILE NO.
18-11-09-1A 03 29 2019
DRAWING NO:
1 CE—AP00-1225
PART:
1 1 of 1
REV:
1
THE STATE
P 0 % I
44115k] Walk
GOVERNOR MIKE DUNLEAVY
Sandeep Pedam
Staff Completions Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re: Exploratory Field, Exploratory Pool, Tinmiaq 13
Permit to Drill Number: 218-144
Sundry Number: 319-190
Dear Mr. Pedam:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www,aogcc.olaska.gov
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
Daniel T. Seamount, Jr.
Commissioner
DATED this i S day of April, 2019.
®ms RW APR 1 s 2a�g
aEE'
APR 11 2019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
CONMERAL
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑
Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
ConocoPhllll s Alaska Inc.
Exploratory 0 ' Development ❑
Stratigraphic ❑ Service ❑
218-144
3. Address:
6. API Number
P. O. Box 100360, Anchorage, Alaska 99510
50-103-20783-00-00 '
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? N/A
Tinmiaq 13
Will planned perforations require a spacing exception? Yes ❑ No �
9. Property Designation (Lease Number):
10. Field/Pool(s):
AA081834
Exploratory
11, PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft):
Total Depth TVD (ft):
Effective Depth MD:
Effective Depth TVD:
MPSP (psi).
Plugs (MD):
Junk (MD):
4,050'
4,050'
4050'
4050'
Casing
Length
Size
MD
TVD
Burst
Collapse
Structural
Conductor
119,
16"
119,
119,
Surface
1,831'
9-5/8"
1,831'
1,831'
Intermediate
Production
4050"
7"
4,050'
4,050'
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
N/A
N/A
3-1 /21,
L-80
3516'
Packers and SSSV Tvbe:
Packers and SSSV MD (ft) and TVD (ft):
Packer: Baker Premier Packer
Packer: Baker Premier Packer: 3475' MD and 3475' TVD
SSSV: None
SSSV: N/A
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: 4/15/2019
OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ "
GAS ElWAG ElGSTOR [ISPLUG ElCommission
16. Verbal Approval: Date:
Representative:
GINJ ❑ Op Shutdown 0 Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: Sandeep Pedam Contact Name: Sandeep Pedam
Authorized Title: Staff Completions Engineer Contact Email: Sandeep.Pedam@conocophillips.com
� Contact Phone: (907) 263-4724
r' /2,0
Authorized Signature: Date:
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
�I-I�Ib
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Clearance El
/Location
Other , 1 _l _ ( (�U `� J
el -
l
Post Initial Injection MIT Req'd? Yes ❑ No ❑
�
Spacing Exception Required? Yes ❑ No FV Subsequent Form Required: `- 91BDMS APR 16 2019
L' APPROVED BY / 1
�C
Approved by COMMISSIONER THE COMMISSION Date: 4
is f 1�� / \ Submit Form and
Form o Rews p � 01 � Approved applicatio i v 1 o he date of approval. Att chments in Duplicate
ConocoPhillips
Post Office Box 100360
Anchorage, Alaska 99510-0360
��NFlDENiIAI.
April 11, 2019
Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Sundry Permit — Request to Suspend Tinmiaq 13
Dear Commissioners:
ConocoPhillips Alaska, Inc hereby applies for an Application for Sundry Approval to suspend
Tinmiaq 13 (PTD 218-144, API # 50-103-20783-00-00)
Suspension for the Tinmiaq 13 well will enable continued collection of reservoir pressure data via
the permanent downhole gauge installed in the well as part of the completion and the surface
data acquisition system. This data will aid in delineation of the field and future development.
Additional future utility includes retesting the well and/or interference testing as part of the future
appraisal and development efforts.
Attached to this application is:
• Proposed Suspension procedure outline
• Current well schematic
• Proposed well suspension schematic
If you have any questions or require further information, please contact me at (907) 263-4724.
Si cerely,
Sandeep Pedam
Completions Engineer
CPAI Drilling and Wells
J
Conocophidips
Post Office Box 100360
Anchorage, Alaska 99510-0360
Well Suspension:
CONRENIIAL
Slickline/Little Red:
1. Ensure AOGCC Suspension Sundry and BLM Suspension Sundry has been approved to
suspend well before proceeding with the long-term suspension of the well.
2. Upon the well being rig released the tubing will be pressure tested to 4600 psi, the 7" x 3-1/2"
annulus will be pressure tested to 3500 psi, the tubing hanger and tree will be tested to 5000
psi and the tubing x IA will be freeze protected with diesel with a H-BPV in the tubing hanger.
3. Well has not been perforated and ball and rod will be left in the well
4. VR plugs will be installed in casing valves
FMC or Valve Crew
1. Install surface BPV in tubing hanger (document installation)
2. Install VR plugs in the wellhead valves (document installation).
3. Raven wrap/proof the wellhead.
4. RDMO.
Well Status (Post suspension):
• Well Shut-in (2 x master valves at surface)
• KWF in tubing and IA (9.5ppg + 1000' of 6.8ppg freeze protect)
• Tubing pressure tested to 4600 psi / 30 minutes
• IA pressure tested to 3500 psi / 30 minutes
• BPV installed in tubing hanger
• VR plugs installed in wing valves
• Wellhead Raven proofed
C noco `nillip
Post Office Box 100360
Anchorage, Alaska 99510-0360
Current Well Schematic
Canductor tDrlvenl:
I U Candacior 119' MD'7VD
Surrace Casing:
9-5�6• 40A a-6G, ?xa
1 C 31' VC111TIM
Production Tubing:
3 :, 6 30 L 90 EUE TA-3
Production Casing:
aLi3' tt�G'Tti1D
7', As L80 TXF {O 41921
CONFIDENTIAL
rulmiaq #13 '
ConocoPhillips
Sketch Well Diagram Au_ ka
ace Cement-11.0 PPG LAC Llte CRETE & 15.8 PPG Class G
Sari;xc .331'r O
13311- 1631' PAC
3 Y' Tubing:
TaG w FKR 0337 x. 3475 - 30.23 f3DL5
P%R w TT: 3D87 x 41'- 35 DDLS
TaLr' 33 S-L 30LS
3 Y' Tubing x 7' Rad Cuing:
3 !? x 7" .0264 x 3175' = 51.74 CO-13 '5 x 7"..0264 x 11 - 1.03 aDLS
Ta:-- = 92 31- DOLS
7" Prod Casing Rom TT to TD:
7' x -D: 0132 a 53:' - 20.45 DGLS
Depth
tcp$
IMDRTl
12' Tubing Hanger
56.20'
Gamco Landing Nipple 2.875"j
496'
vl" Mandrel with 1" DV
3256'
ipple (2.813"1
3314'
ip le (2.813"
3367'
art Gauge Mandrill (v.,/- SI,13 6'arrrll Watch
3419'
mier Packer
3475'
roduction Cement -15.8 PPG Van G
7 ' 40-0
ConocoPhidips
Post Office Box 100360
Anchorage, Alaska 99510-0360
Proposed Well Suspension Schematic
Conductor (Driven
16' ionduchu 119' UD�,7\/D
Surface Csalnd:
93�0'.400, -10. TY.P
Production Tubing:
SS 6;3A LAO EUE Tutm4
Production Casing:
40W' MtD`ff D
7', 26N, LBO, TXP` (0'-4182-1
CONFIDENTRI.,
T Imiaq #13 'W
onocoPhili ps
Sketch Well diagram
SurfaC9 CONITt-11.0 PPG AM Lib CRETE & 15.3 PPG Close G
; XJ* surfaee - 1331' MD
Tas 1331` 1631'W
Ufriers
Cemented "
KVVf « Freeze Protect
Cemented'"' P=uction Casing (common with prima^r
el I dame r'•
Pr"uaton Casing and Production Packer - pressure tested
T1bin Hanger- vressure tested in di rectfon of flow, aPV
stalled
14 waive with Vp plug instaaied
LOWer Master Valve
Upper NlaveI V*ve
Depth -
4 Item tops
(MDRT)
t 4-112" Tubing Hanger 56.20'
s
2 DS Camco Landing Tipple (2,975") 496'
3 KPMG Mandrel with 1" DV 3256'
4 x Nipple le (2.813") 3314'
5 X Nipple 2.813" 3367'
6 Smart Gauge Mandrel w/• SLB Well Watch 3419'
# 7 Premier Packer 3475'
Production Cement —15.8 PPG Claea G
2 7 01." . 4050
SAMPLE TRANSMITTAL
TO: AOGCC
333 WEST 7T" SUITE 100
ANCH. AK. 99501
2791433
OPERATOR: CPAI
SAMPLE TYPE: DRIES
SAMPLES SENT:
TINMIAQ 13
130 - 4050 TVD
130 — 4050 MD
DATE: April 16, 2019
AIR BILL: N/A
CPAI: 2019041601
CHARGE CODE: N/A
NAME: TINMIAQ 13
NUMBER OF BOXES: 4 Box
APR 16 20119
AOGCC
SENT BY: M. McCRACKEN
UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY
OF THIS FORM TO:
CONOCOPHILLIPS, ALASKA
700 G ST
ATO-380
ANCHORAGE, AK. 99510
ATTN: MIKE McCRACKEN
Mike.mccracken@conocophillips.com
RECEIVE
The enclosed data is from well loc ed on federal land (Federal Well Data).
This Federal Well Data is exploration well data that must be held confidential under AS 31.05.035(c) and 20
AAC 25.537(d).
This Federal Well Data also must be held confidential indefinitely (i.e., beyond two years) under 5 U.S.C.
552(b)(4) and (9)
aJ(8lILIY
04t
:at External Chain of CustodyRecord
try.
se�aren io�x ■ ECEIVE ccJ
ECoc#:6541 APR 11 2019
Date: 10 Apr 2019 AOGCC
Client: CONOCOPHILLIPS ALASKA INC
PO BOX 2200 BARTLESVILLE OK
States 74005
Contact: Brett Wendt
Phone:
6316 Windfern Road ] J
Houston, TX 77040
Phone: 1-713-328-2673
Fax:
Contact: Daniel Burch
Phone: +1 713 328 2471
EMail: Daniel. Burch@corelab.com
Consignee: Meredith Guhl
United Petroleum Geology Assistant
333 W. 7th Ave., Suite 100
Anchorage, Alaska 99501-3539
Job(201901254) has 55 Samples, 0 Boxes, 0 Pallets.
Well: Tinmiaq 13
Client Ref#
Tool Depthl
Tool Depth2 Sample Type
1
3553.17
CHUNK
2
3554
CHUNK
3
3555
CHUNK
4
3556
CHUNK
5
3557.1
CHUNK
6
3558
CHUNK
7
3559
CHUNK
8
3559.8
CHUNK
9
3560.85
CHUNK
10
3562
CHUNK
11
3563.3
CHUNK
12
3564
CHUNK
13
3565
CHUNK
14
3566
CHUNK
15
3567
CHUNK
16
3568
CHUNK
17
3569.05
CHUNK
18
3570
CHUNK
19
3571
CHUNK
20
3572.1
CHUNK
21
3573
CHUNK
22
3574
CHUNK
23
3575
CHUNK
24
3576
CHUNK
25
3577
CHUNK
26
3578.05
CHUNK
27
3579
CHUNK
28
3580
CHUNK
29
3581.15
CHUNK
30
3582.2
CHUNK
31
3583
CHUNK
Contact:
Phone: 907-793-1235
Box Num Pallet Num
Page 1 of 2
32
3584
CHUNK
34
3586
CHUNK
35
3587
CHUNK
36
3588
CHUNK
37
3589
CHUNK
38
3590
CHUNK
39
3591
CHUNK
40
3592
CHUNK
41
3593
CHUNK
42
3594
CHUNK
43
3595
CHUNK
44
3596
CHUNK
45
3597
CHUNK
46
3598
CHUNK
47
3599
CHUNK
48
3600.3
CHUNK
49
3601
CHUNK
50
3602
CHUNK
51
3603
CHUNK
52
3604
CHUNK
53
3605.1
CHUNK
54
3606
CHUNK
55
3607
CHUNK
33
�85)
CHUNK
Total: Sample:55
Prepared By
Date
Notes :
Boxes:0 Pallets:0
Daniel Burch Please sign, date, & return copy to Core Lab via e-mail, fax, or mail.
10 Apr 2019 Total Samples : 5�5/-1To,,tal Boxes : 0; Total Pallets : 0
Received B� / V ( Date: q11 2 Ik �l
i
Page 2 of 2
THE STATE
90 �011
GOVERNOR MIKE DUNLEAVY
Chip Alvord
Drilling Manager
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
Re: Exploratory Field, Exploratory Pool, Tinmiaq 13
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 218-144
Surface Location: 32' FNL, 3573' FEL, SEC. 35, T12N, R2W
Bottomhole Location: 32' FNL, 3573' FEL, SEC. 35, T12N, R2W
Dear Mr. Alvord:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.00gcc.alaska.gov
Enclosed is the approved application for the permit to drill the above referenced exploration well.
All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals
from below the permafrost or from where samples are first caught and 10' sample intervals through
target zones.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run
must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this
well.
This permit to drill does not exempt you from obtaining additional permits or approvals 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. A weekly status report is required from
the time the well is spudded until it is suspended or plugged and abandoned. The report should be a
generalized synopsis of the week's activities and is exclusively for the AOGCC's internal use.
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,
ox �-
Hollis S. French
Chair
DATED this day of January, 2019.
STATE OF ALASKA
AL ,KA OIL AND GAS CONSERVATION COMN,. _ ;ION
RECEIVED
PERMIT TO DRILL
20 AAC 25.005
NOV 0 2 2018
1 a. Type of Work:
Drill H Lateral ❑
Redrill ❑ Reentry ❑
1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑
Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone ❑
Exploratory - Oil Q Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑'
1 c. Specify if well is proposed,for:
Coalbed Gas ❑ Gas Hydrates ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
ConocoPhillips
5. Bond: Blanket 0 Single Well ❑
CFS25�A
Bond No. �, Z r,r-„-��
11. Well Name and Number:
Tinmiaq 13
3. Address:
700 G Street AT010-1036
6. Proposed Depth: ;5� 1,8, ]/ Z
MD: 4330 TVD: 4330
12. Field/Pool(s):
l!3
Exploratory
4a. Location of Well (Governmental Section):
Surface: 32' FNL 3573' FEL Sec. 35 T12N R2W
Top of Productive Horizon:
32' FNL 3573' FEL Sec. 35 T12N R2W
Total Depth:
32' FNL 3573' FEL Sec. 35 T12N R2W
7. Property Designation:
AA081834
8. DNR Approval Number:
NA
13. Approximate Spud Date:
3/19/2019
9. Acres in Property:
5756
14. Distance to Nearest Property:
5250'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
Surface: x-705961 y- 5983340 Zone-5
10. KB Elevation above MSL (ft): 128
GL / BF Elevation above MSL (ft): 100
15. Distance to Nearest Well Open
to Same Pool: 20524'
16. Deviated wells: N/A Kickoff depth: feet
Maximum Hole Angle: degrees
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Downhole: 1936 Surface:
18. Casing Program:
Specifications
Top - Setting Depth - Bottom
Cement Quantity, c.f. or sacks
Hole
Casing
Weight
Grade
I Coupling
Length
MD
TVD
MD
TVD
(including stage data)
24"
16"
62.5#
H40
Welded
108
Surf
Surf
108
108
Pre -Installed
12 1 /4"
9 5/8"
40#
L80
TXP
1850
Surf
Surf
1850
1 850
220bbl 11 ppg Deeperete, 40bbi 15 8ppg Class G
8 1/2"
7"
26#
L80
TXP
4330
Surf
Surf
4330
4330
55 bbl 15.8 ppg Class G
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft):
Total Depth TVD (ft):
Plugs (measured):
Effect. Depth MD (ft):
Effect. Depth TVD (ft):
Junk (measured):
Casing
Length
Size
Cement Volume
MD
TVD
Conductor/Structural
Surface
Intermediate
Production
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Hydraulic Fracture planned? Yes No ❑
20. Attachments: Property Plat P-1 BOP Sketch
Diverter Sketch
Drilling Program
❑✓ Seabed Report
Time v. Depth Plot
❑ Drilling Fluid Program
Shallow Hazard Analysis
❑✓ 20 AAC 25.050 requirements❑✓
21. Verbal Approval: Commission Representative: Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be David Lee
deviated from without prior written approval. Contact Name:
Authorized Name: Chip Alvord Contact Email: David. L.Lee(a)conocophillips.com
Authorized Title: Drilling Manager Contact Phone: 907-231-7613
Authorized Signature: Azc,-,A Date: ri
Commission Use Only
Permit to Drill
Number: a 1 $ — I-�150-103—?%o
API Number:
3 —00 —00
Permit Approval
Date: I
See cover letter for other
requirements.
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Other: CX� o j � Samples req'd: Yes LV No ❑ Mud log req'd: Yes X No ❑
HZS measures: Yes ❑ No Y Directional svy req'd: Yes [9' No ❑
47,( 96 �� 1 1��5 " C ( Spacing exception req'd: Yes ❑ No I;J Inclination -only svy req'd: Yes ❑ No
UJ" Post initial injection MIT req'd: Yes ❑ No ❑
� Sr,iLLC�v� G� 1
J APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date: �'ci
v i ^ ) rm 10-401 Revised 5/2017 This permit is valid f r 4K44[
Nd
Submit Form and
approval per 20 AAC25.005jg) t ach Tents in Duplicate
_) _ ��/ills/ff 4-3' "C, 0. iz-/l`f-he
November 1, 2018
Commissioner
Alaska Oil and Gas Conservation Commission
333 West 71h Avenue, Suite 100
Anchorage, Alaska 99501
RE: Application for Permit to Drill:
Dear Commissioners:
Post Office Box 100360
Anchorage, Alaska 99510-0360
Tinmiaq 13
ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore exploratory well
Tinmiaq 13. This vertical delineation well will be drilled off an ice road / pad originating from 2L
Pad using Doyon 141. The objective of this well is to core the Willow sand, perform extensive
logging analysis (LWD and wireline) and then conduct an evaluation program to help justify future
development. A Geopressure and Shallow Hazards analysis was undertaken in preparation for
drilling this well.
As indicated in the attachments, the drilling program calls for drilling 12-1/4" surface hole to
approx. 1850' MD / TVD, followed by an 8-1/2" production hole section to approx. 4330' MD /
TVD, which will penetrate the Falcon and Willow sand.
The evaluation program in the production hole section of Tinmiaq 13 will first include obtaining full
core through the Willow sand section (-180'). After the well is TD'd, a wireline logging program
will be carried out consisting of MDT, GR/SonicScanner/RtScanner, NMR/Dielectric/Lithoscanner
and rotary side wall core logs. The well will then be cased completed and suspended fora test
in a future ice road season. Once the rig is off location the well will be suspended in accordance
to the regulations.
The planned spud date for Tinmiaq 13 is March 19, 2019.
Please find attached for the review of the Commission forms 10-401 and the information required
by 20 ACC 25.005 for this well bore.
If you have any questions or require further information, please contact myself at (907) 263-3741.
SincereI
David Lee
Staff Drilling Engineer
16" 62.5# H40 Conductor
108' MD / TVD.
12 %' Hole
Base PermaFrost - 928' MD / TVD
v
9 518" 40# L80 TXP Surface Casing
1850. MD / TVD
K-3/Top Nanushuk - 2300' MD !TVD
8 112' Hole
Falcon Sand Top - 3260' MD / TVD
Willow Sand Top - 3530' MD / TVD -
Parts @ XXXX
TD - 4328' MD I TVD 7' 26# L80 TXP Production Casing
From 0 - 4328'
Conductor Cemented to Surface
Surface Cemented - Lead of 11.0 PPG Arctic LiteCRETE.
Tail of 15.8 PPG'G'
Lead from Surface to -1400'
Tail from 14W to 1850'
Completion
-3 Y,,' tubing to surface
-3 'i,' x 7' packers
Nipple XXXX� �2 S
Guage - XXXX'
Packer -XXXX'
Production Cemented -
Tail of 15.8 PPG'G' from 2700' to 4328'
Is
App Dn for Permit to Drill, Well Tinmiaq 13
Saved: 30-Oct-18
Permit It — Tinmiaq 13 M�h�
Application for Permit to Drill Documen
MaxWeII
&I O x i r n i z p
Vielly41ue
Table of Contents
1. Well Name..................................................................................................................
2
Requirements of 20 AAC 25.00569.............................................................................................................
2
2. Location Summary.....................................................................................................
2
Requirements of 20 AAC 25.005(c) (2).........................................................................................................
2
Requirements of 20 AAC 25.050(b).............................................................................................................
3
3. Blowout Prevention Equipment Information...............................................................
3
Requirements of 20 AAC 25.005(c) (3).........................................................................................................
3
4. Drilling Hazards Information.....................................................................................
3
Requirements of 20 AAC 25.005(c)(4)........................................................................................................
3
5. Procedure for Conducting Formation Integrity Tests ..................................................
4
Requirements of 20 AAC 25.005 (c)(5)........................................................................................................
4
6. Casing and Cementing Program.................................................................................
4
Requirements of 20 AAC 25.005(c)(6).........................................................................................................
4
7. Diverter System Information......................................................................................
4
Requirements of 20 AAC 25.005(c)(7).........................................................................................................
4
8. Drilling Fluid Program...............................................................................................
4
Requirements of 20 AAC 25.005(c)(8).........................................................................................................
4
9. Abnormally Pressured Formation Information...........................................................
5
Requirements of 20 AAC 25.005 (c) (9)........................................................................................................
5
10. Seismic Analysis.........................................................................................................
5
Requirements of 20 AAC 25.005 (c)(10)......................................................................................................
5
11. Seabed Condition Analysis..........................................................................................
5
Requirements of 20 AAC 25.005 (c)(11)......................................................................................................
5
12. Evidence of Bonding...................................................................................................
5
Requirements of 20 AAC 25.005 (c)(12)......................................................................................................
5
13. Proposed Drilling Program.........................................................................................
5
Requirements of 20 AAC 25.005 (c)(13)......................................................................................................
5
Tinmiaq 13 APD
Prepared by: David Lee
Page 1 of 7
Printed: 30-Oct-18
App on for Permit to Drill, Well Tinmiaq 13
Saved: 30-Oct-18
14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7
Requirements of 20 AAC 25.005 (c)(14)...................................................................................................... 7
15. Attachments............................................................................................................... 7
Attachment 1: Location Maps..................................................................................................................... 7
Attachment 2: Directional Plan.................................................................................................................. 7
Attachment 3: Drilling Hazards Summary.................................................................................................... 7
Attachment 4: Cement Summary................................................................................................................. 7
Attachment 5: Shallow Hazard and Pore Pressure Conclusions.................................................................... 7
Attachment 5: Seismic Analysis.................................................................................................................. 7
Attachment 6: Well Schematic................................................................................................................... 7
Attachment7: BOP Equipment.................................................................................................................. 7
Attachment 8: Wellhead Schematic............................................................................................................ 7
Attachment 9: LWD and Wireline Logging Program................................................................................... 7
1. Well Name
Requirements of 20 AAC 25.005 (fi
Each well must be identified by a unique name designated by the operator and a unique AP/ number assigned by the commission under 20 AAC
25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix
to the name designated for the well by the operator and to the number assigned to the well by the commission.
The well for which this application is submitted will be designated as Tinmiaq 13. This will be an exploratory
delineation well.
2. Location Summary
Requirements of 20 AAC 25.005(c) (2)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(2) a plat identifying the property and the properryy's owners and showing
(A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to
governmental section lines.
(B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained
by the National Geodetic Survey in the National Oceanic and Atmospheric Administration;
(C) the proposed depth of the well at the top of each objective formation and at total depth: and (D) other information required by 20 AAC
25.050(b);
Location at Surface
32' FNL, 3573' FEL, Sec 35, Twn 12 N,
Rg 2 W
NAD 27
Northings: 5,983,340 Eastings: 705,961
1RKB Elevation
128' AMSL
Pad Elevation
100' AMSL
Location at Top of Productive Interval
Falcon
32' FNL, 3573' FEL, Sec 35, Twn 12 N, Rg 2 W
NAD 27
Northings: 5,983,340 Eastings: 705,961
Measured Depth, RKB:
3,261'
Total Vertical Depth, RKB:
3,26 V
Total Vertical Depth, SS:
3,133'
Location at Top of Productive Interval
Willow
32' FNL, 3573' FEL, Sec 35, Twn 12 N, Rg 2 W
NAD 27
Northings: 5,983,340 Eastings: 705,961
Measured Depth, RKB:
3,535'
Total Vertical Depth, RKB:
3,535'
Total Vertical Depth, SS:
3,407'
Location at Total Depth 32' FNL, 3573' FEL, Sec 35, Twn 12 N, Rg 2 W
NAD 27
Northings: 5,983,340 Eastings: 705,961
Measured Depth, RKB:
4,330'
Total Vertical Depth, RKB:
4,330'
Total Vertical Depth, SS:
4,202'
Tinmiaq 13 APD
Prepared by: David Lee
Page 2 of 7
Printed: 30-Oct-18
Apo on for Permit to Drill, Well Tinmiaq 13
Saved: 30-Oct-18
Plats showing the Ice Pad Configuration and Proposed Ice Pad and Ice Road Route are included. Please refer to
Attachment 1: Ice Pad Configuration & Proposed Ice Pad and Ice Road route
Requirements of 20 AAC 25.050(b)
If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must
(1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any
portion of the proposed well;
Application is for vertical Exploratory (delineation) well. There are no wells within 200 feet of the proposed
wellbore. Please refer to Attachment 2: Directional Plan.
and
(2) for all wells within 200 feet of the proposed wellbore
(A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that
each named operator has been furnished a copy of the application by certified mail; or
(B) state that the applicant is the only affected owner.
N/A — Application is for a vertical Exploratory (delineation) well. There are no wells within 200 feet of the
proposed wellbore
3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c) (3)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037,
as applicable;
Please reference BOP schematics for Doyon 141 in Attachment 7.
4. Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(4) information on drilling ha_ards, including
(A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on
a methane gradient;
Expect normal with possible overpressure (1936 psi) towards TD @ 4330' TVD.
Equivalent Mud Weight @ TD = 1936 psi / (4330'*.052) = 8.6 ppg
Equivalent Mud Weight @ Willow Sand = 1581 psi / (3535'*.052) = 8.6 ppg
The maximum potential surface pressure (MPSP) while drilling Tinmiaq 13 is calculated using the predicted 1581
psi reservoir pressure, a 0.11 psi/ft gas gradient and Willow sand top TVD of 3535' ft.
MPSP = FPP — (0.1 l x TVD) _
MPSP = 1581 — (0.11 x 3535) ' 3� �y33D C-1��) /SUS /�5`
= 1191 psi
10
(B) data on potential gas :ones;
The well bore is not expected to penetrate any gas zones.
and
(C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation :ones, and =ones that have a
propensity for differential sticking;
A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this
well. Please refer to Attachment 3: Drilling Hazards Summary
Tinmiaq 13 APD
Prepared by: David Lee
Page 3 of 7
Printed: 30-Oct-18
App on for Permit to Drill, Well Tinmiaq 13
Saved: 30-Oct-18
5. Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(5)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030 f ;
Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT / FIT procedure that
ConocoPhillips Alaska has on file with the Commission.
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated
liner, or screen to be installed;
Casing and Cementing
Program
Hole
Top
Btm
CsglTbg
Size
Weight
Length
MD/TVD
MD/TVD
OD in
in
Ib/ft
Grade
Conn.
ft
ft
ft
Cement Program
Pre -installed
16
24
62.5
H-40
Welded
108
Surf
108/108
Cemented to Surface with
9 5/8
12 1/4
40
L 80
TXP
1850
Surf
1850/1850
2201obl 11 ppg Deeperete, 40bbl 15.8ppgClass
G
Cement top planned @ 2700' MD/2700' TVD.
7
8 1/2
26
L-80
TXP
4330
Surf
4330 / 4330
Cemented with
55bbl 15.8 ppg Class G
Please refer to Attachment 4: Cement Summary
7. Diverter System Information
Requirements of 20 AAC 25.005(c)(7)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission tinder
20 AAC 25.035(h) (2);
Please reference diverter schematic for Doyon 141 in Attachment 7.
8. Drilling Fluid Program
Requirements of 20 AAC 25.005(c) (8)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033;
Drilling will be done using water based mud systems having the following properties:
Surface
108'— 1850'
Mud Type
KLA-SHIELD
Density
10.5
Plastic Viscosity
ALAP
Yield Point
25 - 40
API Fluid Loss m1130min
NC — < 8
H
9.5 — 10
Production
1850'— 3530'
Mud Type
KLA-SHIELD
Density
9.5
PV
As low as possible
Yield Point
20 - 30
Tinmiaq 13 APD
Prepared by: David Lee
Page 4 of 7
Printed: 30-Oct-18
App4 )n for Permit to Drill, Well Tinmiaq 13
Saved: 30-Oct-18
API Fluid Loss (ml/30min
< 10
H
1 9.5 — 10
Production
3530' — 4330'
Mud Type
Low Invasion Coring
Fluid
Density
9.5
YP (W100 t^2)
25 - 40
API Fluid Loss m1.30min
< 10
H
9.5 — 10
PV
As low as possible
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
9. Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by
20 AAC 25.033 f;
A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this
well. Please refer to Attachment 5: Shallow Hazards and Pore Pressure Conclusions
10. Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(10) for an exploratory or stratigraphic test well, a seismic refraction or refection analysis as required by 20 AAC 25.061(a);
A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this
well. Please refer to Attachment 5: Shallow Hazards and Pore Pressure Conclusions
11. Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(11) for a well drilled from an offshore platform, mobile bottom founded stricture, jack -tip rig, or floating drilling vessel, an analysis of seabed
conditions as required by 20 AAC 25.061(b);
N/A - Application is not for an offshore well.
12. Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(12) evidence showing that the requirements of 20 AAC 25.025 (Bonding)have been met;
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
The proposed drilling program for Tinmiaq 13 is listed below.
1. Install 6' diameter by 5' long corrugated cellar and backfill at the wellbore.
2. Auger 24" conductor hole with NES conductor rig down to 80'. POOH and run 16" 639 H40 welded conductor
pipe. The 16" conductor is centered in the 24" augured hole and cemented from the bottom up with conduit
pipe strapped to the conductor. The cement is Schlumberger Ar, �with a density of 15.7ppg and
Tinmiaq 13 APD
Prepared by: David Lee
Page 5 of 7
Printed: 30-Oct-18
App Dn for Permit to Drill, Well Tinmiaq 13
Saved: 30-Oct-18
yield of 0.93 cuft/sk. The cement top is brought back to the cellar base and a 4' square steel base plate is placed
over the 16" conductor and welded. Approximately 2' of the Arctic Set cement is then poured on top of the
baseplate. Total volume of cement slurry utilized is approximately 200 sacks of slurry or 188 cu ft.
3. MIRU Doyon 141 on Tinmiaq 13 conductor. ( Ll � fa r
4. NU and function test diverter system and prepare spud mud. J
5. Place warning signs on location indicating the rig has diverter equipment rigged up.
6. Spud and drill vertical 12-1/4" hole to the 9 5/8" surface casing point (1850' MD/ 1850' TVD) according to the
directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and
formation data gathering.
7. Run and cement New 9 5/8" 40# L-80 TXP casing to surface. Centralize surface casing with 1 bow spring
centralizer per joint on first three joints and then 1 bow spring centralizer every 41h joint to within 100' of
conductor shoe (208'MD). Adequate excess cement will be pumped to ensure cement reaches the surface
during the cement job. Displace cement with mud. If cement returns are not seen at surface run a 1" string into
surface casing x conductor annulus to feel for top of cement. Once top of cement is felt record this depth and
perform top job to bring cement to surface. See. A 6,,z i bx / 3-0-01
8. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE, install 3-1/2" x 6" VBR's,
test to 250 / 3500 psi. COD P,; 2 svCA
9. Shut in BOP s and pressure test casing toe3A6Tp-si per AOGCC regulations. Record results.
10. Drill out cement and 20' minimum to 50' maximum of new hole. Perform FIT up to 16.0 ppg EMW FIT
(minimum acceptablgA+.<ppg EMW)
iL•s
11. Drill vertical 8 1/2" hole to core point of -3530' MD / TVD. Swap mud system over to low invasion coring
fluid with tracer.
12. POOH and lay down drilling BHA and pick up coring BHA. Core from 3530' to 3710' in 1 - 2 runs then
C� POOH to pick up directional BHA. RIH and log and survey cored section of the well prior to getting back to
bottom.
13. Once back on bottom Drill vertical 8 1/2" hole to TD of 4330' MD / 4330' TVD. Run MWD/L,WD logging
tools in drill string as required for directional monitoring and formation data gathering.
14. POOH with DP and stand back. R/U and run wireline logs.
15. Perform wiper trips as hole conditions dictate between logging runs.
Lk W e,r
16. POOH and R/D wireline. Close blind RAMS, change 3-1/2" x 6" VBR's to 7" RAMS, test to 250 / 3500 psi.
RU and run New 7" 26# L-80 TXP from TD to surface and cement. Displace cement with filtered brine.
Centralize production casing with 1 bow spring centralizer on bottom three joint followed by 1 bow
spring centralizer on every other joint from this point to 500' above hydrocarbon bearing zones (27001).
17. Change upper pipe RAMS f/ 7" to 3-1/2" x 6" VBR's
18. Freeze protect 9 5/8" x 7" annulus to the surface casing shoe. Bullhead water in the annulus to confirm
injectivity in the annulus. Flush with 75 bbl of water prior to pumping diesel. Once the water is pumped,
bullhead diesel down the annulus with sufficient volume to reach the surface casing shoe (110% of annular
volume - 60 bbl). The collapse rating of the 7" casing is the weak point so ensure 80% of the collapse rating of
the 7" production casing is not exceeded during bullheading operation. 80% of the 7" collapse rating is
4328psi.
3
19. LD 5" DP and PU 4" DP with casin� scrapping BHA and perform casing scrapper run. "
7Z'I
20. Shut in BOP's and pressure test casing to 3,000 psi per AOGCC regulations. Record results.
r-
21. POOH with DP and lay down drill pipe and BHA.
22. R/U and perform CBL. CBL will be run from PBTD to the 9-5/8" surface casing shoe. The CBL will be used
to verify sufficient cement top height above the highest hydrocarbon bearing zone. L/D CBL tools
Tinmiaq 13 APD
Prepared by: David Lee
Page 6 of 7
Printed. 30-Oct-18
App )n for Permit to Drill, Well Tinmiaq 13
Saved: 30-Oct-18
23. R/U and run completion and RIH with 3 '/2" tubing, land tubing hanger and drop ball to set packer. Pressure test
tubing hanger to 5000 psi, tubing to 5000 psi and packer to 35Osi.
24. N/D BOP and rig down and move out rig.
25. After Rig is off location we will suspend the well, clean the location and block off ice road access to location.
Please refer to Attachment 6: Well Schematic.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
ic�
Requirements of 20 AA 25.005 (c)(14)
An application for a Permit to Drill music be accompanied by each of the following items, except far an item already on file ivith the commission
and identified in the application:
(14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to
request authori_ation under 20 AAC 25.080 for an annular disposal operation in the well.;
Drill cuttings and drilling mud form the wells will be disposed of by hauling to Prudhoe Bay, Kuparuk or Alpine
where they will be disposed at an approved facility. Prior to hauling, the cuttings will be temporarily stored in an
ice-bermed drilling storage cell on each ice pad. The volume of wastes placed in each storage cell will be
minimized as will snow accumulation in the cell. Upon completion of activities at the well site, the ice-bermed
drilling waste storage cells will be broken up and hauled to Alpine, Prudhoe Bay or Kuparuk for disposal at an
injection well. Drilling waste liquids will also be hauled to Alpine, Kuparuk or Prudhoe Bay for injection in an
approved Class II disposal well.
The Tinmiaq 13 surface/production casing annulus will be filled with diesel after setting production casing and
prior to continuing of the drilling operation. If isolation is required per regulations over significant hydrocarbons,
then sufficient cement volume will be pumped during the production cement job to cover those formations.
ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at
a later date provided the well meets the regulatory requirements.
15. Attachments
Attachment 1: Location Maps
Attachment 2: Directional Plan
Attachment 3: Drilling Hazards Summary
Attachment 4: Cement Summary
Attachment 5: Shallow Hazard and Pore Pressure Conclusions
Attachment5: Seismic Analysis
Attachment 6: Well Schematic
Attachment 7: BOP Equipment
Attachment 8: Wellhead Schematic
Attachment 9: LWD and Wireline Logging Program
Tinmiaq 13 APD
Prepared by David Lee
Page 7 of 7
Printed: 30-Oct-18
NOTES:
1. WELL LOCATION COORDINATES ARE NAD83,
ALASKA STATE PLANE ZONE 4 PROVIDED
BY OTHERS ON 08/21 /2018.
2. DISTANCES ARE TRUE. ALL DISTANCES
ARE IN US SURVEY FEET.
TINMIAQ
13
LOCATED WITHIN PROTRACTED
SECTION 35, T. 12 N„ R 2 W.
UMIAT MERIDIAN, ALASKA
32' FNL 1706'
FWL
NAD83 Datum
NAD 27 Datum
N 70°21'27.40"
N 70°21'28.72"
W 152°19'48.80"
W 152°19'37.36"
ASPIC ZN4
ASPC ZN4
(Y) 5,985,729
(Y) 5,985,987
(X) 1,353,576
(X) 213,543
I
0 200
SCALE IN FEET
DRAINAGE
(TYP)
'--�� °F• A�gs1 -1
'�
Aw
CO �
*. 49 TH
R ......................
/
KENNETH J. PINARD:
No. 11545 a� i
�! f`c'�i�p � ' • ... ' • Spy ��
P�'OfES81O0t�p�.�'�
Vicinity • NOT TO SCALE
ao
o.
♦ 7p 0
600
r
o / PREVAILING
WIND ^
0 200 � sY
R\Gj �3� �•3
1V 1`�y S S PNK
d
o �Ppp4 0
MM o�p�R
Cp p L\M�jS
0 200
UMIAQ Design & Municipal SCALE IN FEET
Services, LLC / AECL1316
CONOCOPHILUPS OF ALASKA, INC.
KUUKPIK TINMIAQ 13
U I PROPOSED PAD LAYOUT
ALPINE, ALASKA
ALPINE SURVEY OFFICE PHONE : 907-fi7D-4739 DATE: 10/09/2018 DRAWN BY: CZ SHEET: 1
SCALE: 1" = 200' 1 CHECKED BY: SZ W.O. No: 18-08-21-1
12:25, October 15 2018 1
Tin m iaq .i 3 wp02
T
UJ
N
to
m
N
0
0 1125 - 2250 3375 4500
9 5/8 x 12 1/4 Measured Depth
Y �
Plan @ 127.50usft (D141)
a �
9 5/8 x 12 1 /4 _ _ 000
innn
U O
O
> N
7 x 8 1/2 _ 000
-90 -60 -30 0 30 60 90
Horizontal Departure
0
750
Permit Pack j Plan S u m m a
O
000
t6
611
i
�I
sO�
0
90
1500 2250 3000 3750 4500 5250 `yu `u
Measured Denth i
EY PROGRAM Surface Location See Proposa
North / Y:
.41
Depth From Depth To Survey/Plan Tool
East / X: Pad Reports
210
150
27.50 1845.00 Tnmiaq 13 wp02 (rinmiaq 13)MWD
Elevation: 100.00
1845.00 4327.50 Tnmiaq 13 wp02 (Tnmiaq 13)MWD
180
TVD MD
Name
1848.501848.50
9 5/8 x 12 114
4327.504327.50
7 x 81/2
Magnetic Model & Date:
BGGM2003-Feb-19
Magnetic North is 15.90' East of
True North (Magnetic Declination)
Magnetic Dip & Field Strength:
80.67' 57355nT
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace
VSect Target
Annotation
1 27.50 0.00 0.00 27.50 0.00
0.00 0.00 0.00
a 00
Lithology Column
2 4327.50 0.00 0.00 4327.50 0.00
0.00 0.00 0.00
0.00
TD at 4319.00
127.1
Surface Location
is subject to Change
Note: Passes AC Base Perm
Compass Bug causing Flagged Scans
See TC View
2',E-3
K-3 Base
2—k
Seg97
32fi1.e
Top Upperr'F"al
358�i� V yy
Cr By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's
completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and collision
1 PAS
avoidance plan as set out in the audit pack.) approve it as the basis for the final well plan and wellsite drawings. I also
acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance.
repared by
by
ccepted by
Approved by:
B. Temple
[hecked
V. Osara
J. Ryan
D. Lee
L
O
LO
N
M
d'
'O
N
(ui/4sn p) twiy}JON
w
�CD
0
—
O
_
N
=
o
�
a=
w
N
M
m
o W
O
d
N
N
13
3
X
CC) 00
M
N
1
w
L
CD I-
0
y
C
O
o
y
r
O
�
Q
CD
EZ:
_
■�
i
o
�n o Ln o o Ln
o f-- co CY) o
(+)uIJoN/(-)ulnoS
0
O
O
cM
A♦
O
LO
a
Oo
■�
O
O
LO
I
LL
E
L
CL
3 _>O
O
cnN
(�
m D
O
(E '
m
M
I
c7 � Q
I N O
Q U)
O (a
O
Co
Y
Y CO F-
k- 00
LO
I
O
O
0
O,
0
o `
0
0
0
00
���1
O
}
m
O
r
O
N I`
O
ce)
O
� I ` ill
C:
O
`
Q
a)
U)
N
r
N
U
I
X I
co
I
I I I
I
r
00
p
I
LO i, �
I I I
X
_ LO
N
I
I
I
i
I
I
I
I
I
I i i
I I
I ! I
O
1
I
I
i
I I
I
1
I
I i i
I l i
I I I
1
I i
I
I
I I
I ! I
I
I
I
I I
O
O
LO
M
i
I
I
I
I I
I
I
I
I
I
I
I I I
I II
I I I
I I I
I
I
I
I
I
I
I
I I I
I I I
I I I
cr
1
I I
I
I i t
O
I
I
I I
I
I
I
I
I II
I I I
I i t
LO
N
N
■�
I
� �
I
I II
�
I
I
I
I
I I
I I
I I
I I
I
I
I
I
I I I
I I I
I I I
I I I
I
I
I
I !
I I
I I
I
I
I
I I I
I I I
I I I
I
I I
I
I I I
O
O
Q
I
I
I
I I
I
I
I I I
I I I
M
�
O o
LO
O
o
O
Ln
O
O
O
LO
f-
LO
N
N
O
C`M
f-
M
yjdaa leoi:Pan anjl
Plan Report
NADConversion
North Alaska ASPS
Willow North
Plan: Tinmiaq 13
50103xxxxx00
Tinmiaq 13
Plan: Tinmiaq 13 wp02
Standard Proposal Report
15 October, 2018
NAD 8 AS
ConocoPhillips
ConocoPs
philli
Database:
OAKEDMP1
Company:
NADConversion
Project:
North Alaska ASPS
Site:
Willow North
Well:
Plan: Tinmiaq 13
Wellbore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
L,NAD 83 AS P ConocoPhillips
Standard Proposal Report
Local Co-ordinate Reference: Well Plan: Tinmiaq 13
TVD Reference: Plan @ 127.50usft (D141)
MD Reference: Plan @ 127.50usft (D141)
North Reference: True
Survey Calculation Method: Minimum Curvature
Project North Alaska ASP5
Map System: US State Plane 1983 System Datum: Mean Sea Level
Geo Datum: North American Datum 1983 Using Well Reference Point
Map Zone: Alaska Zone 4 Using geodetic scale factor
Site
Willow North
Site Position:
Northing:
5,995,523.24 usft Latitude:
70° 2' 40.176 N
From:
Map Easting:
239,781.66 usft Longitude:
161 ° 15' 37.620 W
Position Uncertainty:
0.00 usft Slot Radius:
13-3/16 " Grid Convergence:
-- -10.61 °
Well
Plan: Tinmiaq 13
Well Position
+N/-S 195,014.61 usft Northing:
5,985,729.00 usft Latitude:
70° 21' 27.404 N
+E/-W 1,094,228.50 usft Easting:
1,353,576.00 usft Longitude:
152° 19' 48.796 W
Position Uncertainty
0.00 usft Wellhead Elevation:
Ground Level:
100.00 usft
Welibore
Tinmiaq 13
Magnetics
Model Name Sample Date
Declination Dip Angle
Field Strength
(nT)
BGGM2018 2/1/2019
15.90 80.67
57,355.16023143
Design
Tinmiaq 13 wp02
Audit Notes:
Version:
Phase: PLAN
Tie On Depth: 27.50
Vertical Section:
Depth From (TVD)
+N/-S +E/-W Direction
(usft)
(usft) (usft) (°)
27.50
0.00 0.00 0.00
Plan Survey Tool Program
Date
Depth From Depth To
(usft) (usft)
Survey (Welibore)
Tool Name Remarks
1 27.50 1,845.00
Tinmiaq 13 wp02 (Tinmiaq 13)
MWD
MWD - Standard
2 1,845.00 4,327.50
Tinmiaq 13 wp02 (Tinmiaq 13)
MWD
MWD - Standard
Plan Sections
Measured
Vertical
Depth Inclination Azimuth
Depth
(usft) (°) (°)
(usft)
27.50 0.00 0.00
27.50
4,327.50 0.00 0.00
4,327.50
Dogleg Build Turn
+N/-S +E/-W Rate Rate Rate TFO
(usft) (usft) (°1100usft) (°/100usft) (°/100usft) (°) Target
0.00 0.00 0.00 0.00 0.00 0.00
0.00 0.00 0.00 0.00 0.00 0.00
10/15/2018 12:53:51 PM Page 2 COMPASS 5000.14 Build 85D
A D 8 3 ASP' ConocoPhillips
ConocoPh i I I i ps Standard Proposal Report
Database:
OAKEDMPI
Company:
NADConversion
Project
North Alaska ASP5
Site:
Willow North
Well:
Plan: Tinmiaq 13
Wellbore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
Planned Survey
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well Plan: Tinmiaq 13
Plan @ 127.50usft (D141)
Plan @ 127.50usft (D141)
True
Minimum Curvature
Measured
Vertical
Vertical
Dogleg
Build
Turn
Depth
Inclination
Azimuth
Depth
+N/S
+E/-W
Section
Rate
Rate
Rate
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(°/100usft)
(°I100usft)
27.50
0.00
0.00
27.50
0.00
0.00
0.00
0.00
0.00
0.00
100.00
0.00
0.00
100.00
0.00
0.00
0.00
0.00
0.00
0.00
200.00
0.00
0.00
200.00
0.00
0.00
0.00
0.00
0.00
0.00
300.00
0.00
0.00
300.00
0.00
0.00
0.00
0.00
0.00
0.00
400.00
0.00
0.00
400.00
0.00
0.00
0.00
0.00
0.00
0.00
500.00
0.00
0.00
500.00
0.00
0.00
0.00
0.00
0.00
0.00
600.00
0.00
0.00
600.00
0.00
0.00
0.00
0.00
0.00
0.00
700.00
0.00
0.00
700.00
0.00
0.00
0.00
0.00
0.00
0.00
800.00
0.00
0.00
800.00
0.00
0.00
0.00
0.00
0.00
0.00
900.00
0.00
0.00
900.00
0.00
0.00
0.00
0.00
0.00
0.00
1,000.00
0.00
0.00
1,000.00
0.00
0.00
0.00
0.00
0.00
0.00
1,100.00
0.00
0.00
1,100.00
0.00
0.00
0.00
0.00
0.00
0.00
1,200.00
0.00
0.00
1,200.00
0.00
0.00
0.00
0.00
0.00
0.00
1,300.00
0.00
0.00
1,300.00
0.00
0.00
0.00
0.00
0.00
0.00
1,400.00
0.00
0.00
1,400.00
0.00
0.00
0.00
0.00
0.00
0.00
1,500.00
0.00
0.00
1,500.00
0.00
0.00
0.00
0.00
0.00
0.00
1,600.00
0.00
0.00
1,600.00
0.00
0.00
0.00
0.00
0.00
0.00
1,700.00
0.00
0.00
1,700.00
0.00
0.00
0.00
0.00
0.00
0.00
1,800.00
0.00
0.00
1,800.00
0.00
0.00
0.00
0.00
0.00
0.00
1,900.00
0.00
0.00
1,900.00
0.00
0.00
0.00
0.00
0.00
0.00
2,000.00
0.00
0.00
2,000.00
0.00
0.00
0.00
0.00
0.00
0.00
2,100.00
0.00
0.00
2,100.00
0.00
0.00
0.00
0.00
0.00
0.00
2,200.00
0.00
0.00
2,200.00
0.00
0.00
0.00
0.00
0.00
0.00
2,300.00
0.00
0.00
2,300.00
0.00
0.00
0.00
0.00
0.00
0.00
2,400.00
0.00
0.00
2,400.00
0.00
0.00
0.00
0.00
0.00
0.00
2,500.00
0.00
0.00
2,500.00
0.00
0.00
0.00
0.00
0.00
0.00
2,600.00
0.00
0.00
2,600.00
0.00
0.00
0.00
0.00
0.00
0.00
2,700.00
0.00
0.00
2,700.00
0.00
0.00
0.00
0.00
0.00
0.00
2,800.00
0.00
0.00
2,800.00
0.00
0.00
0.00
0.00
0.00
0.00
2,900.00
0.00
0.00
2,900.00
0.00
0.00
0.00
0.00
0.00
0.00
3,000.00
0.00
0.00
3,000.00
0.00
0.00
0.00
0.00
0.00
0.00
3,100.00
0.00
0.00
3,100.00
0.00
0.00
0.00
0.00
0.00
0.00
3,200.00
0.00
0.00
3,200.00
0.00
0.00
0.00
0.00
0.00
0.00
3,300.00
0.00
0.00
3,300.00
0.00
0.00
0.00
0.00
0.00
0.00
3,400.00
0.00
0.00
3,400.00
0.00
0.00
0.00
0.00
0.00
0.00
3,500.00
0.00
0.00
3,500.00
0.00
0.00
0.00
0.00
0.00
0.00
3,600.00
0.00
0.00
3,600.00
0.00
0.00
0.00
0.00
0.00
0.00
3,700.00
0.00
0.00
3,700.00
0.00
0.00
0.00
0.00
0.00
0.00
3,800.00
0.00
0.00
3,800.00
0.00
0.00
0.00
0.00
0.00
0.00
3,900.00
0.00
0.00
3,900.00
0.00
0.00
0.00
0.00
0.00
0.00
4,000.00
0.00
0.00
4,000.00
0.00
0.00
0.00
0.00
0.00
0.00
4,100.00
0.00
0.00
4,100.00
0.00
0.00
0.00
0.00
0.00
0.00
4,200.00
0.00
0.00
4,200.00
0.00
0.00
0.00
0.00
0.00
0.00
4,300.00
0.00
0.00
4,300.00
0.00
0.00
0.00
0.00
0.00
0.00
4,327.50
0.00
0.00
4,327.50
0.00
0.00
0.00
0.00
0.00
0.00
10/15/2018 12:53:51PM Page 3 COMPASS 5000.14 Build 85D
ConocoPhilli s
p
Database: OAKEDMP1
Company: NADConversion
Project: North Alaska ASPS
Site: Willow North
Well: Plan: Tinmiaq 13
Wellbore: Tinmiaq 13
Design: Tinmiaq 13 wp02
Casing Points
Measured Vertical
Depth Depth
(usft) (usft)
1,848.50 1,848.50 9 5/8 x 12 1/4
4,327.50 4,327.50 7 x 8 1/2
N A D � 3 AS �� ConocoPhillips
Standard Proposal Report
Local Co-ordinate Reference: Well Plan: Tinmiaq 13
TVD Reference: Plan @ 127.50usft (D141)
MD Reference: Plan @ 127.50usft (D141)
North Reference: True
Survey Calculation Method: Minimum Curvature
Casing Hole
Diameter Diameter
Name
9-5/8 12-1/4
7 8-1/2
Formations
Measured
Vertical
Dip
Depth
Depth
Dip Direction
(usft)
(usft)
Name
Lithology (1) (�)
927.50
927.50
Base Perm
0.00
2,313.10
2,313.10
K-3
0.00
2,410.30
2,410.30
K-3 Base
0.00
2,967.60
2,967.60
Seg97
0.00
3,261.00
3,261.00
Top Upper Falcon
0.00
3,535.30
3,535.30
Top Willow
0.00
3,589.10
3,589.10
Base Willow
0.00
Plan Annotations
Measured
Vertical
Depth
Depth
(usft)
(usft)
4,327.50
4,327.50
Local Coordinates
+N/-S +El-W
(usft) (usft) Comment
0.00 0.00 TD at 4319.00
1011512018 12:53:51PM Page 4 COMPASS 5000.14 Build 85D
NADConversion
North Alaska ASP5
Willow North
Plan: Tinmiaq 13
50103xxxxx00
Tinmiaq 13
Plan: Tinmiaq 13 wp02
Standard Proposal Report
15 October, 2018
ConocoPhillips
ConocoPhilli s
Database:
OAKEDMPI
Company:
NADConversion
Project:
North Alaska ASPS
Site:
Willow North
Well:
Plan: Tinmiaq 13
Wellbore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
ConocoPhillips
n ,.
� ASP
�� � r' 83 HJ '
.._
Standard Proposal Report
Local Co-ordinate Reference:
Well Plan: Tinmiaq 13
TVD Reference:
Plan @ 127.50usft (D141)
MD Reference:
Plan @ 127.50usft (D141)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Project North Alaska ASP5
Map System: US State Plane 1983 System Datum: Mean Sea Level
Geo Datum: North American Datum 1983 Using Well Reference Point
Map Zone: Alaska Zone 5 Using geodetic scale factor
Site Willow North
Site Position: Northing: 5,919,666.36 usft Latitude: 70° 2' 40.176 N
From: Map Easting: 734,695.87 usft Longitude: 161° 15' 37.620 W
Position Uncertainty: 0.00 usft Slot Radius: 13-3/16 " Grid Convergence: -6.83 °
Well Plan Tinmiaq 13
Well Position +N/-S 194,917.78 usft Northing: 5,983,055.92 usft Latitude:
+E/-W 1,094,952.27 usft Easting: 1,845,980.95 usft Longitude:
Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level:
Wellbore Tinmiaq 13
Magnetics Model Name Sample Date Declination
BGGM2018 _ 2/1/2019
Design Tinmiaq 13 wp02
Audit Notes:
Version: Phase: PLAN
Vertical Section: Depth From (TVD) +N/-S
(usft) (usft)
27.50 0.00
Plan Survey Tool Program Date
Depth From Depth To
(usft) (usft) Survey (Wellbore) Tool Name
1 27.50 1,845.00 Tinmiaq 13 wp02 (Tinmiaq 13) MWD
MWD - Standard
2 1,845.00 4,327.50 Tinmiaq 13 wp02 (Tinmiaq 13) MWD
MWD - Standard
Dip Angle
80.67
Tie On Depth: 27.50
+E/-W Direction
(usft) (°)
0.00 0.00
Remarks
70° 21' 27.404 N
152° 19' 48.796 W
100.00 usft
Field Strength
(nT)
57;35617183883
Plan Sections
Measured Vertical Dogleg Build Turn
Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO
(usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) (°) Target
27.50 0.00 0.00 27.50 0.00 0.00 0.00 0.00 0.00 0.00
4,327.50 0.00 0.00 4,327.50 0.00 0.00 0.00 0.00 0.00 0.00
10/15/2018 12:56:30PM Page 2 COMPASS 5000.14 Build 85D
ConocoPhillips
ConocoPh i I I i ps A D 8 3 ASP Standard Proposal Report
Database:
OAKEDMPI
Company:
NADConversion
Project
North Alaska ASPS
Site:
Willow North
Well:
Plan: Tinmiaq 13
Wellbore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
Planned Survey
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well Plan: Tinmiaq 13
Plan @ 127.50usft (D141)
Plan @ 127.50usft (D141)
True
Minimum Curvature
Measured
Vertical
Vertical
Dogleg
Build
Turn
Depth
Inclination
Azimuth
Depth
+N/-S
+El-W
Section
Rate
Rate
Rate
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(°/100usft)
(°1100usft)
27.50
0.00
0.00
27.50
0.00
0.00
0.00
0.00
0.00
0.00
100.00
0.00
0.00
100.00
0.00
0.00
0.00
0.00
0.00
0.00
200.00
0.00
0.00
200.00
0.00
0.00
0.00
0.00
0.00
0.00
300.00
0.00
0.00
300.00
0.00
0.00
0.00
0.00
0.00
0.00
400.00
0.00
0.00
400.00
0,00
0.00
0.00
0.00
0.00
0.00
500.00
0.00
0.00
500.00
0.00
0.00
0.00
0.00
0.00
0.00
600.00
0.00
0.00
600.00
0,00
0.00
0.00
0.00
0.00
0.00
700.00
0.00
0.00
700.00
0.00
0.00
0.00
0.00
0.00
0.00
800.00
0.00
0.00
800.00
0.00
0.00
0.00
0.00
0.00
0.00
900.00
0.00
0.00
900.00
0.00
0.00
0.00
0.00
0.00
0.00
1,000.00
0.00
0.00
1,000.00
0.00
0.00
0.00
0.00
0.00
0.00
1,100.00
0.00
0.00
1,100.00
0.00
0.00
0.00
0.00
0.00
0.00
1,200.00
0.00
0.00
1,200.00
0.00
0.00
0.00
0.00
0.00
0.00
1,300.00
0.00
0.00
1,300.00
0.00
0.00
0.00
0.00
0.00
0.00
1,400.00
0.00
0.00
1,400.00
0.00
0.00
0.00
0.00
0.00
0.00
1,500.00
0.00
0.00
1,500.00
0.00
0.00
0.00
0.00
0.00
0.00
1,600.00
0.00
0.00
1,600.00
0.00
0.00
0.00
0.00
0.00
0.00
1,700.00
0.00
0.00
1,700.00
0.00
0.00
0.00
0.00
0.00
0.00
1,800.00
0.00
0.00
1,800.00
0.00
0.00
0.00
0.00
0.00
0.00
1,900.00
0.00
0.00
1,900,00
0.00
0.00
0.00
0.00
0.00
0.00
2,000.00
0.00
0.00
2,000.00
0.00
0.00
0.00
0.00
0.00
0.00
2,100.00
0.00
0.00
2,100.00
0.00
0.00
0.00
0.00
0.00
0.00
2,200.00
0.00
0.00
2,200.00
0.00
0.00
0.00
0.00
0.00
0.00
2,300.00
0.00
0.00
2,300.00
0.00
0.00
0.00
0.00
0.00
0.00
2,400.00
0.00
0.00
2,400.00
0.00
0.00
0.00
0.00
0.00
0.00
2,500.00
0.00
0.00
2,500.00
0.00
0.00
0.00
0,00
0.00
0.00
2,600.00
0.00
0.00
2,600.00
0.00
0.00
0.00
0.00
0.00
0.00
2,700.00
0.00
0.00
2,700.00
0.00
0.00
0.00
0.00
0.00
0.00
2,800.00
0.00
0.00
2,800.00
0.00
0.00
0.00
0.00
0.00
0.00
2,900.00
0.00
0.00
2,900.00
0.00
0.00
0.00
0.00
0.00
0.00
3,000.00
0.00
0.00
3,000.00
0.00
0.00
0.00
0.00
0.00
0.00
3,100.00
0.00
0.00
3,100.00
0.00
0.00
0.00
0.00
0.00
0.00
3,200.00
0.00
0.00
3,200.00
0.00
0.00
0.00
0.00
0.00
0.00
3,300.00
0.00
0.00
3,300.00
0.00
0.00
0.00
0.00
0.00
0.00
3,400.00
0.00
0.00
3,400.00
0.00
0.00
0.00
0.00
0.00
0.00
3,500.00
0.00
0.00
3,500.00
0.00
0.00
0.00
0.00
0.00
0.00
3,600.00
0.00
0.00
3,600.00
0.00
0.00
0.00
0.00
0.00
0.00
3,700.00
0.00
0.00
3,700.00
0.00
0.00
0.00
0.00
0.00
0.00
3,800.00
0.00
0.00
3,800.00
0.00
0.00
0.00
0.00
0.00
0.00
3,900.00
0.00
0.00
3,900.00
0.00
0.00
0.00
0.00
0.00
0.00
4,000.00
0.00
0.00
4,000.00
0.00
0.00
0.00
0.00
0.00
0.00
4,100.00
0.00
0.00
4,100.00
0.00
0.00
0.00
0.00
0.00
0.00
4,200.00
0.00
0.00
4,200.00
0.00
0.00
0.00
0.00
0.00
0.00
4,300.00
0.00
0.00
4,300.00
0.00
0.00
0.00
0.00
0.00
0.00
4,327.50
0.00
0.00
4,327.50
0.00
0.00
0.00
0.00
0.00
0.00
1011512018 12:56:30PM Page 3 COMPASS 5000.14 Build 85D
ConocoPhilli s
p
Database:
OAKEDMPI
Company:
NADConversion
Project:
North Alaska ASPS
Site:
Willow North
Well:
Plan: Tinmiaq 13
Welibore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
Casing Points
Measured
Vertical
Depth
Depth
(usft)
(usft)
1,848.50
1,848.50 9 5/8 x 12 1/4
4,327.50
4,327.50 7 x 8 1/2
N A D Q 3 n f1CJ ConocoPhillips
C� Standard Proposal Report
imam
Local Co-ordinate Reference: Well Plan: Tinmiaq 13
TVD Reference: Plan @ 127.50usft (D141)
MD Reference: Plan @ 127.50usft (D141)
North Reference: True
Survey Calculation Method: Minimum Curvature
Casing Hole
Diameter Diameter
Name O O
9-5/8 12-1/4
7 8-1/2
Formations
Measured Vertical Dip
Depth Depth Dip Direction
i (usft) (usft) Name Lithology (1) (�)
927.50 927.50 Base Perm 0.00
2,313.10 2,313.10 K-3 0.00
2,410.30 2,410.30 K-3 Base 0.00
2,967.60 2,967.60 Seg97 0.00
3,261.00 3,261.00 Top Upper Falcon 0.00
3,535.30 3,535.30 Top Willow 0.00
3,589.10 3,589.10 Base Willow 0.00
Plan Annotations
Measured Vertical Local Coordinates
Depth Depth +N/-S +EI-W
(usft) (usft) (usft) (usft) Comment
4,327.50 4,327.50 0.00 0.00 TD at 4319,00
1011512018 12.56:30PM Page 4 COMPASS 5000.14 Build 85D
NADConversion
North Alaska ASP5
Willow North
Plan: Tinmiaq 13
50103xxxxx00
Tinmiaq 13
Plan: Tinmiaq 13 wp02
Standard Proposal Report
15 October, 2018
NAD 27 ASP 4
A ConocoPhillips
ConocoPh i I I i ps
Database:
OAKEDMP1
Company:
NADConversion
Project:
North Alaska ASP5
Site:
Willow North
Well:
Plan: Tinmiaq 13
Wellbore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
ConocoPhillips
N A D 27 ASP 4
Standard Proposal Report
Local Co-ordinate Reference: Well Plan: Tinmiaq 13
TVD Reference: Plan @ 127.50usft (D141)
MD Reference: Plan @ 127.50usft (D141)
North Reference: True
Survey Calculation Method: Minimum Curvature
Project North Alaska ASP5
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
:e Willow North
e Position: Northing: 5,995,789.91 usft Latitude: 70° 2' 42.193
Dm: Map Easting:-900,251.45 usft Longitude: 161 ° 15' 25.715
sition Uncertainty: 0.00 usft Slot Radius: 13-3/16 " Grid Convergence: -10.6'
Well Plan: Tinmiaq 13
Well Position +N/S 194,947.43 usft Northing:
+E/-W 1,094,242.15 usft Easting:
Position Uncertainty 0.00 usft Wellhead Elevation:
Wellbore Tinmiaq 13
Magnetics Model Name Sample Date
BGGM2018 2/1/2019
5,985,987.42 usft Latitude: 70° 21' 28.722 N
213,542.93 usft Longitude: 152° 19' 37.354 W
Ground Level: 100.00 usft
Declination Dip Angle Field Strength
(nT)
15.90 80.67 57,356.17183883
Design
Tinmiaq 13 wp02
Audit Notes:
Version:
Phase:
PLAN
Vertical Section:
Depth From (TVD)
+N/S
(usft)
(usft)
27.50
0.00
Plan Survey Tool Program
Date
Depth From
Depth To
(usft)
(usft)
Survey (Wellbore)
Tool Name
1 27.50
1,845.00
Tinmiaq 13 wp02 (Tinmiaq 13)
MWD
MWD - Standard
2 1,845.00
4,327.50
Tinmiaq 13 wp02 (Tinmiaq 13)
MWD
MWD - Standard
Plan Sections
Measured
Vertical
Depth Inclination
Azimuth Depth
(usft) (°)
(°) (usft)
27.50 0.00
0.00 27.50
4,327.50 0.00
0.00 4,327.50
Tie On Depth:
+E/-W
(usft)
0.00
Remarks
27.50
Direction
(°)
0.00
Dogleg Build Turn
+N/S +EI-W Rate Rate Rate TFO
(usft) (usft) (°1100usft) (°/100usft) (°/100usft) (°) Target
0.00 0.00 0.00 0.00 0.00 0.00
0.00 0.00 0.00 0.00 0.00 0.00
1011512018 1:01:31 PM Page 2 COMPASS 5000.14 Build 85D
NAD 27 ASP 4 ConocoPhillips
ConocoPh i I I i ps Standard Proposal Report
Database:
Company:
Project
Site:
Well:
Wellbore:
Design:
Planned Survey
Measured
Depth
(usft)
27.50
100.00
200.00
300.00
400.00
500.00
600.00
700.00
800.00
900.00
1,000.00
1,100.00
1,200.00
1,300.00
1,400.00
1,500.00
1,600.00
1,700.00
1,800.00
1,900.00
2,000.00
2,100.00
2,200.00
2,300.00
2,400.00
2,500.00
2,600.00
2,700.00
2,800.00
2,900.00
3,000.00
3,100.00
3,200.00
3,300.00
3,400.00
3,500.00
3,600.00
3,700.00
3,800.00
3,900.00
4,000.00
4,100.00
4,200.00
4,300.00
4,327.50
OAKEDMP1
NADConversion
North Alaska ASP5
Willow North
Plan: Tinmiaq 13
Tinmiaq 13
Tinmiaq 13 wp02
Inclination Azimuth
(1) (1)
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0,00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Local Co-ordinate Reference:
TVD Reference:
MD Reference;
North Reference:
Survey Calculation Method:
Well Plan: Tinmiaq 13
Plan @ 127.50usft (D141)
Plan @ 127.50usft (D141)
True
Minimum Curvature
Vertical
Vertical
Dogleg
Build
Turn
Depth
+NI-S
+El-W
Section
Rate
Rate
Rate
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(*1100usft)
(°/100usft)
27.50
0.00
0.00
0.00
0.00
0.00
0.00
100.00
0.00
0.00
0.00
0.00
0.00
0.00
200.00
0.00
0.00
0.00
0.00
0.00
0.00
300.00
0.00
0.00
0.00
0.00
0.00
0.00
400.00
0.00
0.00
0.00
0.00
0.00
0.00
500.00
0.00
0.00
0.00
0.00
0.00
0.00
600.00
0.00
0.00
0.00
0.00
0.00
0.00
700.00
0.00
0.00
0.00
0.00
0.00
0.00
800.00
0.00
0.00
0.00
0.00
0.00
0.00
900.00
0.00
0.00
0.00
0.00
0.00
0.00
1,000.00
0.00
0.00
0.00
0.00
0.00
0.00
1,100.00
0.00
0.00
0.00
0.00
0.00
0.00
1,200.00
0.00
0.00
0.00
0.00
0.00
0.00
1,300.00
0.00
0.00
0.00
0.00
0.00
0.00
1,400.00
0.00
0.00
0.00
0.00
0.00
0.00
1,500.00
0.00
0.00
0.00
0.00
0.00
0.00
1,600.00
0.00
0.00
0.00
0.00
0.00
0.00
1,700.00
0.00
0.00
0.00
0.00
0.00
0.00
1,800.00
0.00
0.00
0.00
0.00
0.00
0.00
1,900.00
0.00
0.00
0.00
0.00
0.00
0.00
2,000.00
0.00
0.00
0.00
0.00
0.00
0.00
2,100.00
0.00
0.00
0.00
0.00
0.00
0.00
2,200.00
0.00
0.00
0.00
0.00
0.00
0.00
2,300.00
0.00
0.00
0.00
0.00
0.00
0.00
2,400.00
0.00
0.00
0.00
0.00
0.00
0.00
2,500.00
0.00
0.00
0.00
0.00
0.00
0.00
2,600.00
0.00
0.00
0.00
0.00
0.00
0.00
2,700.00
0.00
0.00
0.00
0.00
0.00
0.00
2,800.00
0.00
0.00
0.00
0.00
0.00
0.00
2,900.00
0.00
0.00
0.00
0.00
0.00
0.00
3,000.00
0.00
0.00
0.00
0.00
0.00
0.00
3,100.00
0.00
0.00
0.00
0.00
0.00
0.00
3,200.00
0.00
0.00
0.00
0.00
0.00
0.00
3,300.00
0.00
0.00
0.00
0.00
0.00
0.00
3,400.00
0.00
0.00
0.00
0.00
0.00
0.00
3,500.00
0.00
0.00
0.00
0.00
0.00
0.00
3,600.00
0.00
0.00
0.00
0.00
0.00
0.00
3,700.00
0.00
0.00
0.00
0.00
0.00
0.00
3,800.00
0.00
0.00
0.00
0.00
0.00
0.00
3,900.00
0.00
0.00
0.00
0.00
0.00
0.00
4,000.00
0.00
0.00
0.00
0.00
0.00
0.00
4,100.00
0.00
0.00
0.00
0.00
0.00
0.00
4,200.00
0.00
0.00
0.00
0.00
0.00
0.00
4,300.00
0.00
0.00
0.00
0.00
0.00
0.00
4,327.50
0.00
0.00
0.00
0.00
0.00
0.00
1011512018 1:01:31PM Page 3 COMPASS 5000.14 Build 85D
ConocoPs
philli
Database:
OAKEDMP1
Company:
NADConversion
Project:
North Alaska ASPS
Site:
Willow North
Well:
Plan: Tinmiaq 13
Wellbore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
Casing Points
Measured
Vertical
Depth
Depth
(usft)
(usft)
1,848.50
1,848.50 9 5/8 x 12 1/4
4,327.50
4,327.50 7 x 8 1/2
Formations
Measured
Vertical
Depth
Depth
(usft)
(usft)
Name
927.50
927.50
Base Perm
2,313.10
2,313.10
K-3
2,410.30
2,410.30
K-3 Base
2,967.60
2,967.60
Seg97
3,261.00
3,261.00
Top Upper Falcon
3,535.30
3,535.30
Top Willow
3,589.10
3,589.10
Base Willow
NAD 27 ASP 4 ConocoPhillips
Standard Proposal Report
Local Co-ordinate Reference: Well Plan: Tinmiaq 13
TVD Reference: Plan @ 127.50usft (D141)
MD Reference: Plan @ 127.50usft (D141)
North Reference: True
Survey Calculation Method: Minimum Curvature
Casing Hole
Diameter Diameter
Name () ()
9-5/8 12-1/4
7 8-1/2
Lithology
Plan Annotations
Measured Vertical Local Coordinates
Depth Depth +N/-S +El-W
(usft) (usft) (usft) (usft) Comment
4,327.50 4,327.50 0.00 0.00 TD at 4319.00
Dip
Dip Direction
0.00
0.00
0.00
0.00
0.00
0.00
0.00
1011512018 1:01:31PM Page 4 COMPASS 5000.14 Build 85D
NADConversion
North Alaska ASP5
Willow North
Plan: Tinmiaq 13
50103xxxxx00
Tinmiaq 13
Plan: Tinmiaq 13 wp02
Standard Proposal Report
15 October, 2018
NAD 27 ASPS
ConocoPhillips
ConocoPhilli s
p
Database:
OAKEDMP1
Company:
NADConversion
Project:
North Alaska ASP5
Site:
Willow North
Well:
Plan: Tinmiaq 13
Wellbore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
ConocoPhillips
Standard Proposal Report
Local Co-ordinate Reference: Well Plan: Tinmiaq 13
TVD Reference: Plan @ 127.50usft (D141)
MD Reference: Plan @ 127.50usft (D141)
North Reference: True
Survey Calculation Method: Minimum Curvature
Project North Alaska ASP5
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 05 Using geodetic scale factor
Site Willow North
Site Position: Northing: 5,919,958.53 usft Latitude: 70' 2' 42.193 N
From: Map Easting:-405,325.63 usft Longitude: 161 ° 15' 25.724 W
Position Uncertainty: 0.00 usft Slot Radius: 13-3/16 " Grid Convergence: -6.83 °
Well Plan: Tinmiaq 13
Well Position +N/S 194,851.07 usft Northing: 5,983,339.99 usft Latitude: 70' 21' 28.722 N
+E/-W 1,094,966.11 usft Easting: 705,960.86 usft Longitude: 152' 19' 37.354 W
Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 100.00 usft
Wellbore Tinmiaq 13
Magnetics
Model Name Sample Date
Declination
Dip Angle
Field Strength
(°)
(I
(nT)
BGGM2018 2/1/2019
15.90
80.67 57,356.27254760
Design
Tinmiaq 13 wp02
Audit Notes:
Version:
Phase:
PLAN
Tie On Depth:
27.50
Vertical Section:
Depth From (TVD)
+N/S
+E/-W
Direction
(usft)
(usft)
(usft)
(I
27.50
0.00
0.00
0.00
Plan Survey Tool Program Date
Depth From Depth To
(usft) (usft) Survey (Wellbore) Tool Name Remarks
1 27.50 1,845.00 Tinmiaq 13 wp02 (Tinmiaq 13) MWD
MWD - Standard
2 1,845.00 4,327.50 Tinmiaq 13 wp02 (Tinmiaq 13) MWD
MWD - Standard
Plan Sections
Measured Vertical Dogleg Build Turn
Depth Inclination Azimuth Depth +N/S +E/-W Rate Rate Rate TFO
(usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target
27.50 0.00 0.00 27.50 0.00 0.00 0.00 0.00 0.00 0.00
4,327.50 0.00 0.00 4,327.50 0.00 0.00 0.00 0.00 0.00 0.00
1011512018 12:59:05PM Page 2 COMPASS 5000.14 Build 85D
✓ NAD 27 ASP 5 ConocoPhillips
ConocoPhillips Standard Proposal Report
Database:
OAKEDMP1
Company:
NADConversion
Project
North Alaska ASPS
Site:
Willow North
Well:
Plan: Tinmiaq 13
Wellbore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
Planned Survey
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well Plan: Tinmiaq 13
Plan @ 127.50usft (D141)
Plan @ 127.50usft (D141)
True
Minimum Curvature
Measured
Vertical
Vertical
Dogleg
Build
Turn
Depth
Inclination
Azimuth
Depth
+N/-S
+E/-W
Section
Rate
Rate
Rate
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(°1100usft)
(°1100usft)
27.50
0.00
0.00
27.50
0.00
0.00
0.00
0.00
0.00
0.00
100.00
0.00
0.00
100.00
0.00
0.00
0.00
0.00
0.00
0.00
200.00
0.00
0.00
200.00
0.00
0.00
0.00
0.00
0.00
0.00
300.00
0.00
0.00
300.00
0.00
0.00
0.00
0.00
0.00
0.00
400.00
0.00
0.00
400.00
0.00
0.00
0.00
0.00
0.00
0.00
500.00
0.00
0.00
500.00
0.00
0.00
0.00
0.00
0.00
0.00
600.00
0.00
0.00
600.00
0.00
0.00
0.00
0.00
0.00
0.00
700.00
0.00
0.00
700.00
0.00
0.00
0.00
0.00
0.00
0.00
800.00
0.00
0.00
800.00
0.00
0.00
0.00
0.00
0.00
0.00
900.00
0.00
0.00
900.00
0.00
0.00
0.00
0.00
0.00
0.00
1,000.00
0.00
0.00
1,000.00
0.00
0.00
0.00
0.00
0.00
0.00
1,100.00
0.00
0.00
1,100.00
0.00
0.00
0.00
0.00
0.00
0.00
1,200.00
0.00
0.00
1,200.00
0.00
0.00
0.00
0.00
0.00
0.00
1,300.00
0.00
0.00
1,300.00
0.00
0.00
0.00
0.00
0.00
0.00
1,400.00
0.00
0.00
1,400.00
0.00
0.00
0.00
0.00
0.00
0.00
1 1,500.00
0.00
0.00
1,500.00
0.00
0.00
0.00
0.00
0.00
0.00
1,600,00
0,00
0,00
1,610,00
0,00
0.00
0,00
0,00
0,00
0,00
1,700.00
0.00
0.00
1,700.00
0.00
0.00
0.00
0.00
0.00
0.00
1,800.00
0.00
0.00
1,800.00
0.00
0.00
0.00
0.00
0.00
0.00
1,900.00
0.00
0.00
1,900.00
0.00
0.00
0.00
0.00
0.00
0.00
2,000.00
0.00
0.00
2,000.00
0.00
0.00
0.00
0.00
0.00
0.00
2,100.00
0.00
0.00
2,100.00
0.00
0.00
0.00
0.00
0.00
0.00
2,200.00
0.00
0.00
2,200.00
0.00
0.00
0.00
0.00
0.00
0.00
2,300.00
0.00
0.00
2,300.00
0.00
0.00
0.00
0.00
0.00
0.00
2,400.00
0.00
0.00
2,400.00
0.00
0.00
0.00
0.00
0.00
0.00
2,500.00
0.00
0.00
2,500.00
0.00
0.00
0.00
0.00
0.00
0.00
2,600.00
0.00
0.00
2,600.00
0.00
0.00
0.00
0.00
0.00
0.00
2,700.00
0.00
0.00
2,700.00
0.00
0.00
0.00
0.00
0.00
0.00
2,800.00
0.00
0.00
2,800.00
0.00
0.00
0.00
0.00
0.00
0.00
2,900.00
0.00
0.00
2,900.00
0.00
0.00
0.00
0.00
0.00
0.00
3,000.00
0.00
0.00
3,000.00
0.00
0.00
0.00
0.00
0.00
0.00
3,100.00
0.00
0.00
3,100.00
0.00
0.00
0.00
0.00
0.00
0.00
3,200.00
0.00
0.00
3,200.00
0.00
0.00
0.00
0.00
0.00
0.00
3,300.00
0.00
0.00
3,300.00
0.00
0.00
0.00
0.00
0.00
0.00
3,400.00
0.00
0.00
3,400.00
0.00
0.00
0.00
0.00
0.00
0.00
3,500.00
0.00
0.00
3,500.00
0.00
0.00
0.00
0.00
0.00
0.00
3,600.00
0.00
0.00
3,600.00
0.00
0.00
0.00
0.00
0.00
0.00
3,700.00
0.00
0.00
3,700.00
0.00
0.00
0.00
0.00
0.00
0.00
3,800.00
0.00
0.00
3,800.00
0.00
0.00
0.00
0.00
0.00
0.00
3,900.00
0.00
0.00
3,900.00
0.00
0.00
0.00
0.00
0.00
0.00
4,000.00
0.00
0.00
4,000.00
0.00
0.00
0.00
0.00
0.00
0.00
4,100.00
0.00
0.00
4,100.00
0.00
0.00
0.00
0.00
0.00
0.00
4,200.00
0.00
0.00
4,200.00
0.00
0.00
0.00
0.00
0.00
0.00
4,300.00
0.00
0.00
4,300.00
0.00
0.00
0.00
0.00
0.00
0.00
4,327.50
0.00
0.00
4,327.50
0.00
0.00
0.00
0.00
0.00
0.00
1011512018 12:59:05PM Page 3 COMPASS 5000.14 Build 85D
ConocoPhilli s
p
Database:
OAKEDMPI
Company:
NADConversion
Project:
North Alaska ASP5
Site:
Willow North
Well:
Plan: Tinmiaq 13
Wellbore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
Casing Points
Measured
Vertical
Depth
Depth
(usft)
(usft)
1,848.50
1,848.50 9 5/8 x 12 1/4
4,327.50
4,327.50 7 x 8 1/2
ConocoPhillips
IV A D 2 7 ASP 5 Standard Proposal Report
Local Co-ordinate Reference: Well Plan: Tinmiaq 13
ND Reference: Plan @ 127.50usft (D141)
MD Reference: Plan @ 127.50usft (D141)
North Reference: True
Survey Calculation Method: Minimum Curvature
Casing Hole
Diameter Diameter
Name ('7 (")
9-5/8 12-1/4
7 8-1/2
Formations
Measured
Vertical
Dip
Depth
Depth
Dip Direction
(usft)
(usft)
Name
Lithology (I (�)
927.50
927.50
Base Perm
0.00
2,313.10
2,313.10
K-3
0.00
2,410.30
2,410.30
K-3 Base
0.00
2,967.60
2,967.60
Seg97
0.00
3,261.00
3,261.00
Top Upper Falcon
0.00
3,535.30
3,535.30
Top Willow
0.00
3,589.10
3,589.10
Base Willow
0.00
Plan Annotations
Measured Vertical Local Coordinates
Depth Depth +N/-S +El-W
(usft) (usft) (usft) (usft) Comment
4,327.50 4,327.50 0.00 0.00 TD at 4319.00
1011512018 12:59:05PM Page 4 COMPASS 5000.14 Build 85D
AC Summary
N
C
t6
U
-0
a)
LL
CD
U)
U
�
�
U
�
m N
U)
U) >
x
.
W
(D
E a)
O
O N y
z
C) U) O
U
� N
O.
c a m y o
a o
Ao•u
� o' o
w2-3
Cm_C
d C N x
m o
o
-
Q
m
i
N
N y L
^O
c m o ❑ U 3
^
E
�/
E
LL
cnerr
c a LL
■—
Ile■—
O
i
ar
U J
0
a._I
Z N N � N
�� toLL
O
�_
0
3
O=
�_
o
rN�Yoo m=
v
L
M
x
M
v
ca
O
N
��m°-
O
0
r
x
r
O
i
Z a o L C�
ak
�(
s
■—
a❑ ui w u o
3
°
CQ
L
O
=o
O
O
�a=�aa
U i V � d' � O FT
V
�
V
Q
j_ j •` C G
C C
N N N
C1 U
y
�� o��(>U)U)
^H^
CL
s
i°-
u
O
a
V
s
�CL
O
O
c
u
E
m
c
0
m
c
0
a
w E
m
E
E
y
d
U �
� O
m «
i U
A LL
W
U
a
m
� a y
m � �
c
I m x
_a y
a=
w m
a
m
y O y
1° m �
N
C a
CL m
Cl) > > cOi
r y E r m
G C y
O O
O y
Vr
= c 3 y m
y � x
fy F
L
M O M y
m 'E c
r d F y C
i t LT
7 = O
� a o
c
a iE s
c v E
L U m lL 2
O m v u G
O 'on y a d
d o U
X 3 N
c
O IL 3 y o
0
GA C O M
O O 0 C
Z
d
v c m m
C y L�57 'O Z O.
ci T C « O
++ U mof IrUi U
Q F R co In
E
a
>
N
7
N N
3 3
M M
W
CO
a
O
O
v
0
N
co
0
N
O
U
O
V+
CL
^s
a.
0
r.
A
u
L
O
z
O
N
O
CL
M
r
cr
R
i=
V/
^s
li
0
0
V
f
m
E
E
co
V
L
Al
r.
0
V
El
N
co
N
O
A
U)
C
ca
U
LL
U)
D
U
LY] N
cn >
E
® N y
U � a
3
p,
N -
Oci
am
3 O
U)
GI
W
ty
N
W
E N
x
�
C �
F
� 2
M
O
D
W
a r
E
� N
'
C
C
N
H
N
o
L
aM�-
a W
y0
m
m o
❑
E m
v
a
W U
m M
a o
L
a
O U m
t6
o
y a
L
O
❑ C t
N y
W N U O
2
m m
c 0
d V
N p F
w—
d
C
m O i
,u
�(D>�
c
O
a
m E
ID E
E
y
Q)
C p
i U
m N
4) U.
U
m
N
O
3
M
rr
E
r_
p
M
r
rr
AS
E
`C
r
c4
a
L
L
^O
CL
NN�
O
N
O
V
C
a
Q
3
E
M
m
E
co
L
Q or
Z E
3 F
O
G
d
CO
a
0
U
v
0
N
Q)
O)
a
co
Tinmiaq -13 wp02 Ladder View
0
0 650 1300 1950 2600 3250 3900
Measured Depth
c
0
`as
Q
m
U)
a)
n
Depth From Depth To Survey/Plan Tool I TVD MD Name
27.50845.00 Tinmiaq 13 wp02 (Tinmiaq 1WVD 1848:1SA8.509 5/8 x 12 1/4
1845.04327.50 Tinmiaq 13 wp02 (TinnMW[)3) 4327.,CM7.50 7 x 8 1/2
0 300 600 900 1200
Partial Measured Depth
1500
Ti n m iaq '1 3
wp02
TC
View
From To Tool
27.50 1845.00 MWD
1845.00 4327.50 MWD
MD Inc Azi TVD Dleg TFace Target
27.50 0.00 0.00 27.50 0.00 0.00
4327.50 0.00 0.00 4327.50 0.00 0.00
Annotation
TD at 4319.00
TVD MD Name
1848.50 1848.50 9 5/8 x 12 1 /4
4327.50 4327.50 7 x 8 1/2
270
0
M
180
Errors Report
ConocoPhillips (Alaska) Inc.
-Expl
North Alaska ASP4
Willow North
Plan: Tinmiaq 13
50103xxxxx00
Tinmiaq 13
Plan: Tinmiaq 13 wp02
Error Ellipse
Survey Report
15 October, 2018
Company:
ConocoPhillips (Alaska) Inc. -Expl
Project:
North Alaska ASP4
Site:
Willow North
Well:
Plan: Tinmiaq 13
Wellbore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
ConocoPhillips
Error Ellipse Report
Local Co-ordinate Reference:
Well Plan: Tinmiaq 13
TVD Reference:
Plan @ 127.50usft (D141)
MD Reference:
Plan @ 127.50usft (D141)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Output errors are at
1.00 sigma
Database:
OAKE D M P 1
Project North Alaska ASP4
Map System: US State Plane 1983 System Datum: Mean Sea Level
Geo Datum: North American Datum 1983 Using Well Reference Point
Map Zone: Alaska Zone 4 Using geodetic scale factor
Site Willow North
Site Position: Northing: 5,920,304.82 usft Latitude: 70' 10' 53.146 N
From: Map Easting: 1,378,070.92 usft Longitude: 152' 6' 46.685 W
Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: — — — -1.99 °
Well Plan: Tinmiaq 13 T
Well Position +N/S 0.00 usft Northing: 5,985,729.00 usft Latitude: 70° 21' 27.404 N
+E/-W 0.00 usft Easting: 1,353,576.00 usft Longitude: 152' 19' 48.796 W
Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 100.00 usft
Wellbore Tinmiaq 13
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
(1) (1 (nT)
BGGM2018 2/1/2019 15.90 80.67 57,355
Design Tinmiaq 13 wp02
Audit Notes:
Version: Phase: PLAN Tie On Depth: 27.50
Vertical Section: Depth From (TVD) +N/S +E/-W Direction
(usft) (usft) (usft) (1)
27.50 0.00 0.00 0.00
i
Survey Tool Program Date 9/27/2018
From To
(usft) (usft) Survey (Wellbore) Tool Name Description
27.50 1,845.00 Tinmiaq 13wp02(Tinmiaq 13) MWD MWD- Standard
1,845.00 4,327.50 Tinmiaq 13wp02(Tinmiaq 13) MWD MWD- Standard
Plan Survey Tool Program Date 9/2712018
Depth From Depth To
(usft) (usft) Survey (Wellbore) Tool Name Remarks
1 27.50 1,845.00 Tinmiaq 13 wp02 (Tinmiaq 13) MWD
MWD - Standard
2 1,845.00 4,327.50 Tinmiaq 13 wp02 (Tinmiaq 13) MWD
MWD - Standard
1011512018 12:21:50PM Page 2 COMPASS 5000.14 Build 85D
ConocoPhillips
Error Ellipse Report
Company:
ConocoPhillips (Alaska) Inc. -Expl
Local Co-ordinate Reference:
Well Plan: Tinmiaq 13
Project:
North Alaska ASP4
ND Reference:
Plan @ 127.50usft (D141)
Site:
Willow North
MD Reference:
Plan @ 127.50usft (D141)
Well:
Plan: Tinmiaq 13
North Reference:
True
Wellbore:
Tinmiaq 13
Survey Calculation Method:
Minimum Curvature
Design:
Tinmiaq 13 wp02
Output errors are at
1.00 sigma
Database:
OAKEDMPI
Position uncertainty and bias at survey station
Measured
Inclination
Azimuth
Vartical
Highside
Lateral
Vertical
Magnitude
Semitrtajor
Semi -minor
Depth
Depth
Error
Bias
Error
Bias
Error
Bias
of Bias
Error
Error
Azimuth Tool
(usft)
(")
(")
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°)
27.50
0.00
0.00
27.50
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
UNDEFINED
100.00
0.00
0.00
100.00
0.04
0.00
0.04
0.00
1.15
0.00
0.00
0.04
0.04
0.00
MwD (1)
200.00
0.00
0.00
200.00
0.15
0.00
0.15
0.00
1.15
0.00
0.00
0.15
0.15
0.00
MwD (1)
300.00
0.00
0.00
300.00
0.27
0.00
0.27
0.00
1.15
0.00
0.00
0.27
0.27
0.00
MwD (1)
400.00
0.00
0.00
400.00
0.38
0.00
0.38
0.00
1.15
0.01
0.01
0.38
0.38
0.00
MWD (1)
500.00
0.00
0.00
500.00
0.49
0.00
0.49
0.00
1.15
0.02
0.02
0,49
0.49
0.00
MWD (1)
600.00
0.00
0.00
600.00
0.60
0.00
0.60
0.00
1.15
0.03
0.03
0.60
0.60
0.00
MWD (1)
700.00
0.00
0.00
700.00
0.72
0.00
0.72
0.00
1.16
0.04
0.04
0.72
0.72
0.00
MWD (1)
800.00
0.00
0.00
800.00
0.83
0.00
0.83
0.00
1.16
0.06
0.06
0.83
0.83
0.00
MwD (1)
900.00
0.00
0.00
900.00
0.94
0.00
0.94
0.00
1.16
0.08
0.08
0.94
0.94
0.00
MWD (1)
1,000.00
0.00
0.00
1,000.00
1.05
0.00
1.05
0.00
1.17
0.10
0.10
1.05
1.05
0.00
Mw)(1)
1,100.00
0.00
0.00
1,100.00
1.16
0.00
1.16
0.00
1.17
0.13
0.13
1.16
1.16
0.00
MwD(1)
1,200.00
0.00
0.00
1,200.00
1.28
0.00
1.28
0.00
1.18
0.15
0.15
1.28
1.28
0.00
MWD(1)
1,300.00
0.00
0.00
1,300.00
1.39
0.00
1.39
0.00
1.18
0.18
0.18
1.39
1.39
0.00
MWD (1)
1,400.00
0.00
0.00
1,400.00
1.50
0.00
1.50
0.00
1.19
0.22
0.22
1.50
1.50
0.00
MWD(1)
1,500.00
0.00
0.00
1,500.00
1.61
0.00
1.61
0.00
1,19
0.25
0.25
1.61
1.61
0.00
Mwo (1)
1,600.00
0.00
0.00
1,600.00
1.73
0.00
1.73
0.00
1.20
0.29
0.29
1.73
1.73
0.00
MWD (1)
1,700.00
0.00
0.00
1,700.00
1.84
0.00
1.84
0.00
1.21
0.33
0.33
1.84
1.84
0.00
MWD (1)
1,800.00
0.00
0.00
1,800.00
1.95
0.00
1.95
0.00
1.22
0.38
0.38
1.95
1.95
0.00
MWD (1)
1,900.00
0.00
0.00
1,900.00
2.01
0.00
2.01
0.00
1.22
0.42
0.42
2.01
2.01
0.00
MWD (2)
2,000.00
0.00
0.00
2,000.00
2.01
0.00
2.01
0.00
1.23
0.47
0.47
2.01
2.01
0.00
MWD (2)
2,100.00
0.00
0.00
2,100.00
2.03
0.00
2.03
0.00
1.24
0.52
0.52
2.03
2.03
0.00
MWD (2)
2,200.00
0.00
0.00
2,200.00
2.05
0.00
2.05
0.00
1.25
0.58
0.58
2.05
2.05
0.00
MWD (2)
2,300.00
0.00
0.00
2,300.00
2.07
0.00
2.07
0.00
1.26
0.63
0.63
2.07
2.07
0.00
MWD (2)
2,400.00
0.00
0.00
2,400.00
2.10
0.00
2.10
0.00
1.27
0.69
0.69
2.10
2.10
0.00
MWD (2)
2,500.00
0.00
0.00
2,500.00
2.14
0.00
2.14
0.00
1.28
0.75
0.75
2.14
2.14
0.00
MWD (2)
2,600.00
0.00
0.00
2,600.00
2.18
0.00
2.18
0.00
1.29
0.82
0.82
2.18
2.18
0.00
MWD(2)
2,700.00
0.00
0.00
2,700.00
2.22
0.00
2.22
0.00
1.30
0.89
0.89
2.22
2.22
0.00
MWD(2)
2,800.00
0.00
0.00
2,800.00
2.27
0.00
2.27
0.00
1.32
0.96
0.96
2.27
2.27
0.00
MWD (2)
2,900.00
0.00
0.00
2,900.00
2.33
0.00
2.33
0.00
1.33
1.03
1.03
2.33
2.33
0.00
MWD (2)
3,000.00
0.00
0.00
3,000.00
2.39
0.00
2.39
0.00
1.34
1.11
1.11
2.39
2.39
0.00
MWD (2)
3,100.00
0.00
0.00
3,100.00
2.45
0.00
2.45
0.00
1.35
1.18
1.18
2.45
2.45
0.00
MWD(2)
3,200.00
0.00
0.00
3,200.00
2.52
0.00
2.52
0.00
1.36
1.27
1.27
2.52
2.52
0.00
MWD (2)
3,300.00
0.00
0.00
3,300.00
2.59
0.00
2.59
0.00
1.38
1.35
1.35
2.59
2.59
0.00
MWD (2)
3,400.00
0.00
0.00
3,400.00
2.66
0.00
2.66
0.00
1.39
1.44
1.44
2.66
2.66
0.00
MWD (2)
3,500.00
0.00
0.00
3,500.00
2.73
0.00
2.73
0.00
1.40
1.53
1.53
2.73
2.73
0.00
MWD (2)
3,600.00
0.00
0.00
3,600.00
2.81
0.00
2.81
0.00
1.42
1.62
1.62
2.81
2.81
0.00
MWD (2)
3,700.00
0.00
0.00
3,700.00
2.89
0.00
2.89
0.00
1.43
1.71
1.71
2.89
2.89
0.00
MWD (2)
3,800.00
0.00
0.00
3,800.00
2.97
0.00
2.97
0.00
1.45
1.81
1.81
2.97
2.97
0.00
MWD (2)
3,900.00
0.00
0.00
3,900.00
3.06
0.00
3.06
0.00
1.46
1.91
1.91
3.06
3.06
0.00
MWD (2)
4,000.00
0.00
0.00
4,000.00
3.14
0.00
3.14
0.00
1.48
2.01
2.01
3.14
3.14
0.00
MWD (2)
4,100.00
0.00
0.00
4,100.00
3.23
0.00
3.23
0.00
1.49
2.12
2A2
3.23
3.23
0.00
MWD (2)
4,200.00
0.00
0.00
4,200.00
3.32
0.00
3.32
0.00
1.51
2.22
2.22
3.32
3.32
0.00
MWD (2)
4,300.00
0.00
0.00
4,300.00
3.41
0.00
3.41
0.00
1.52
2.33
2.33
3.41
3.41
0.00
MWD (2)
4,327.50
0.00
0.00
4,327.50
3.43
0.00
3.43
0.00
1.53
2.37
2.37
3.43
3.43
0.00
MWD (2)
1011512018 12:21:50PM Page 3 COMPASS 5000.14 Build 85D
Company:
ConocoPhillips (Alaska) Inc. -Expl
Project:
North Alaska ASP4
Site:
Willow North
Well:
Plan: Tinmiaq 13
Wellbore:
Tinmiaq 13
Design:
Tinmiaq 13 wp02
Casing Points
ConocoPhillips
Error Ellipse Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Well Plan: Tinmiaq 13
Plan @ 127.50usft (D141)
Plan @ 127.50usft (D141)
True
Minimum Curvature
1.00 sigma
OAKEDMPI
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
(usft) Name
(in)
(in)
1 1,848.50
1,848.50 9 5/8 x 12 1/4
9.625
12.250
4,327.50
4,327.50 7 x 8 112 — -
7.000
8.500
— ---
—
Formations
I Measured
Vertical
Dip
Depth
Depth
Dip
Direction
(usft)
(usft) Name
Lithology (1)
(�)
927.50
927.50 Base Perm
0.00
2,313.10
2,313.10 K-3
0.00
2,410.30
2,410.30 K-3 Base
0.00
2,967.60
2,967.60 Seg97
0.00
3,261.00
3,261.00 Top Upper Falcon
0.00
3,535.30
3,535.30 Top Willow,
0.00
3,589.10
3,589.10 Base Willow
0.00
Plan Annotations
Measured Vertical Local Coordinates
Depth Depth +N/-S +E/-W I
(usft) (usft) (usft) (usft) Comment
4,327.50 4,327.50 0.00 0.00 TD at 4319.00
Checked By: Approved By: Date:
1011512018 12:21:50PM Page 4 COMPASS 5000.14 Build 85D
Pool Report
O
I
N
w
z
I
I
O
a
E
_
w
O
w
C�
a
o
�
O
O
N
m
w
3
N
M
O ,
O
CO
r
C
O
� G
1
I
I
i
O +
N 3
i
1
O
O
co
G�
o
c
...
O
00
L C1
i
I
3
O
O
0
N
�
a
O
O
O
I 00
I
O O O O O
O O O O
N (o N
O
O
00
N
(ui/llsn 009) (+)4}aoN/(-)ulnoS r-
N
i
ITinmiaci 13wp02 NAD83 ASP4 Surface & TD I
M CPAI Coordinate
Datum: NAD83 Region: alaska
f Latitude/Longitude DecimalDegrees
• UTM Zone: [_ F South
{7 State Plane Zone: F----]- Units: us-ft +
r Legal Description (NAD27 only)
Starting Coordinates: --- - —
X: 11353576.00
Y: 5985729.00
- To:
Datum: NAD83 Region: alaska +
r Latitude/Longitude Decimal Degrees +
r UTM Zone: True r South
(-- State Plane Zone: q Units: us -it +
f" Legal Description (NAD27 only)
Ending Coordinates: ----
X: 11353576.00000011
Y: 15985728.99999774
t Transform Quit Help
Tinmiaq 13wp02 NAD83 ASP4 Surface & TD
M CPAI Coordinate Converter .� ..___. I o 191 I?_K� JI
Datum: NAD83 Region: alaska ..
(- Latitude/Longitude Decimal Degrees J
* UTM Zone: f— F South
* State Plane Zone. q + Units: Fit +
!" Le.gai Lia;cription (NAD27 only)
(-Starting Coordinates:
X: 11353576.00
Y: 5985729.00
- To:
Datum: NAD83—:. Region: alaska�:_1
f Latitude/Longitude Decimal Degrees +
r UTM Zone: True r- South
f State Plane Zone: F Units: us ft +
fi Legal Description (NAD27 only)
- Legal Description ---
Township: 012 N . Range: 002 F,/
Meridian: F--] Section:35
FNL 31.186226 FEL 3573.8334
r:._..._....:.:...::_:-...:...-.....:.._.:_...
.Transform Quit Help
Tinmiaq 13wp02 NAD83 ASP5 Surface & TD
M CPAi Coordinate Converter
From:
Datum: NAD83 Region: alaska
! Latitude/Longitude Decimal Degrees
i UTM Zone: r- South
(� State Plane Zone: 4 Units: us-ft
f" Legal Description (NAD27 only)
Starting Coordinates:-- --- -
X: 11353576.00
Y: 15985729.00
—
Datum: NA683 Region: alaska
• Latitude/Longitude Decimal Degrees
f•UTM Zone: True F South
r+ State Plane Zone: 5 Units: us-ft
r Legal Description (NAD27 only)
Ending Coordinates: - -- -- -- _ _
X: 1845980.95165158
Y: 5983055.91881759
Transform Quit Help
Tinmiaq 13wp02 NAD83 ASP5 Surface & TD
M CPAt Coordinate Converter L--L Q I� 1
. From: - -
Datum: NAD83 Region: alaska
C Latitude/Longitude Decimal Degrees
r UTM Zone: f— r South
t` State Plane Zone: I' � Units: us -Tit +
(- Legal Drscriphun (NAD27 only!
Starting Coordinates: -----
X: 11353576.00
Y: 15985729.00
To:
Datum: NAD83 Region: alaska +
i Latitude/Longitude IDecimal Degrees
i UTM Zone: True r South
f State Plane Zone: 5 + Units: us ft D-
r- Legal Description (NAD27 only) j
Legal Description - - ---
Township: o12 N + Range: Opt W +
U 5ection:35
Meridian:
FNL 31.1 22226 FEL + 3573.8334
Transform ) Quit Help
Tinmiaq 13wp02 NAD27 ASP4 Surface & TD
M CPAI Coordinate Converter L I >^
Datum: NAD83 Region: alaska
(" Latitude/Longitude IDecimalDegrees
f UTM Zone: )` South
i
r:• State Plane Zone: 4 - Units: Pit
r" Legal Description (NAD27 only)
Starting Coordinates: --
X: 11353576.00
Y: 15985729.00
-To:
Datum: NAD27 Region: alaska
r•`• Latitude/Longitude j6ecimal Degrees
r UTM Zone: True r South
r State Plane Zone: 4 - Units: us•ft
r Legal Description (NAD27 only)
Ending Coordinates: - --- —
X: 213542.920251037
Y: 5985987.41276544
Transform Quit Help I
Tinmiaq 13wp02 NAD27 ASP4 Surface & TD
M CPAI Coordinate Converter [ — I
From: --------
Datum: NAD83 Region: alaska
i` Latitude/Longitude (Decimal Degrees
r UTM Zone: �� r South
4-• State Plane Zone: 4 ]- Units: us-ft
r" Legal De.zctiption (•d,AD27 oniyj
Starting Coordinates:—
X: 11353576.00
E
Y: 15985729.00
To: -- —
Datum: NAD27 � Region: alaska
• Latitude/Longitude Decimal Degrees
C• UTM Zone: True F South
• State Plane Zone: 4 Units: us•ft
r- Legal Description (NAD27 only)
Legal Description --- --
Township: 012 N Range: 002 y�
Meridian: U Section:35
FNL 31.186226 FEL 3573.8334
Transform Quit Help
Tinmiaq 13wp02 NAD27 ASP5 Surface & TD
M CPAI Coordinate Converter
From:--
Datum: NAD83 Region: alaska ,
' ' LatitudOl-on itude
9 Decimal Degrees .
j C' UTM Zone. r- South
r State Plane Zone: q Units: us ft
i
C Legal Description (NAD27 only)
Starting Coordinates: - -- - -- - -
X: 1353576.00
Y: 15985729.00 i
i
Datum: NAD27 Region: alaska .
C' Latitude/Longitude Decimal Degrees
UTM Zone: True F South
G Skate Plane Zone: g Units: us-ft
i` Legal Description (NAD27 only)
Ending Coordinates - —
X: 7 55960 862163595
Y: I5983339.98431978
Transform Quit Help
Tinmiaq 13wp02 NAD27 ASP5 Surface & TD
M CPAI Coordinate Converter
11 From:
Datum: INAD83 Region: alaska
Latitude/Longitude Decimal Degrees
t UTM Zone:[— F South
State Plane Zone: 4 ] Units: us ft
f Legal DF�criptior(hl.�G27 or�lyl
Starting Coordinates: --- —�
X: 1353576.00
Y: 15985729.00 .�
To: __..._._........
Datum: NAD27 Region: alaska
C' Latitude/Longitude IDecimal Degrees
C' UTM Zone: True i South
C State Plane Zone: F--:-] Units: us-ft
Legal Description (NAD27 only) j
Legal Description-- —
Township: 012 F.] Range: 002 W
Meridian: U D Section:35
FNL 31.1 66226 FEL . 13573.8334
............................................................
Transform Quit Help
As-built
NOTES:
1. BASIS OF COORDINATES: OPUS SOLUTION OF GPS
STATIC OBSERVATIONS ON 08/26/2018.
2. COORDINATES ARE NAD83, ALASKA STATE PLANE
ZONE 4
3. ELEVATIONS ARE CONVERTED FROM OPUS NAD88
TO B.P.M.S.L. VERTICAL DATUM (-3.5' ±DIFF.).
4. DISTANCES ARE TRUE. ALL DISTANCES AND
ELEVATIONS ARE IN US SURVEY FEET.
5. DATE OF SURVEY: 08/26/2018.
TINMIAQ 13
LOCATED WITHIN PROTRACTED
SECTION 35, T. 12 N., R 2 W.
UMIAT MERIDIAN, ALASKA
32' FNL 1706' FWL
NAD83 Datum NAD 27 Datum
°' rinll
IN 702127.40" IN 7r'°"''"o
W 152019'48.80" W 1!
ASPIC ZN4 ASP(
(Y) 5,985,729 (Y)
(X) 1,353,576 (X)
y
DRAINAGE m� /
(Typ) 1 I Q 13
9a 1 0 200
SCALE N EET
CONOCOPHILLIPS OF ALASKA, INC.
KUUKPIK TI N M IAQ 13
U 1VI I A Q SITE TOPOGRAPHY SURVEY
ALPINE, ALASKA
ALPINE SURVEY OFFICE
PHONE:907-670-4739 DATE: 08/26/2018 DRAWN BY: SZ SHEET: 1
PHONE
SCALE: AS SHOWN I CHECKED BY: DB W.O. No: 18-08-21-1
Revision:
Appendix
M
L.
O
N
i
4J
F-
L
0
v
O
d.l
a-J
O
Ln
ro
a�
4
■
U
N
t1A
C�
E
4-
O
0
O
M
N
4-1 O
4-U
U
O
-0 41
jo 4-1
Z 0
Q O
O O
CQ �
C �
U a"'
o
i
f� QJ
O N
N L
0
o X
O
OM �
E
cu
Ln
�^ W
CAI
4-
Ln
w
■
(U
0)
Ln
cz
i
U
rn
L
N
a�
N
E
N
O
Q
++
E
N
,
+��
`+-
O
w
-0
O
+�+
�
C
U
CU
U
ca
O
O
ai
C
QJ
E
Ln
Ln
N
N
Q
Y
O
CL
c
N
N
�
O_
•�
c
v
_
U
ro
O
Q
U
v
O
O
U
aj
ca
N
Ln
Q
bA
O
J
O
4J
NO
O
C
c°
Q
s
tai
V)
U
0
4-
O
L(1
O
},
bn
fB
N
N
a-+
la
L
+�
N
C:
O
O
—
J
bn
U
UD
O
O
L7
Ln
�L
N_
L
O
(a
O
O
U
�
hA
C:
aj
C
O
U
N
a
+-
c
a
L
Qj
ai
co
-
-
N
cB
L
LU
_
ru
Li-
■
ul
t�A
v
U
M
L
(U
fB
N
(U
d-J
C
c
O
c
O
U
Q)
Ln
0)
Eb
c
L.
v
4.J
N
N
C
N
L
f0
N
O
c�
an
E
f�
U
aJ
Q
N
O
U
O
N
o
U
fB
0
f0
>
bA
N
O
c�
rl
c 4
L
L
QJ
■
a)
L
Q
m
O
L
fB
a
N
4J
S
a-
f6
U
Q N
=
co 0-
(31
C) N
4,
>� N
m
N
U QJ
y_ C Q1
O L
O c6 (3j
(� CO iJ
Lf)� N (Ij
C o
U N Q
4-J — N
O U
QJ >
bA t O L
M U a
U N
O O
� � L L
O O
aJ N
N
O
L- • N
U 0
Q U
■ ■ ■
aJ
4
4�
U
O
M
O
N
L
>
L
41
_�
O
+-'
O
cn
�
U
Y
N
4�
•�
�L
U
GJ
Q
O
S
O
U
+-+
(A
>,
O
U
�u
N
cr
f�
Q1
�
L
>
N-�
>
s
i—
QJ
to
a
i
c
s
L
aJ
N
(B
f0
—
U
N
a
E
s
++
a_'
L
O
N
O
U
O
L
O
j
L..f6
Nb.0
N
O
>
.�
U
U
CO
V
O
O
u
c
�
0-
O
s
-0
>
CL 4)
O•
�[
U
N
M L
O
(AO
>,
U
V
i
O
O N
>
v
Q
(II
N
OU
O
m
U
N
(A 4-1
QJ
L-
L
fB
i
—
N
)
c
C O
■
■
■
■
■
Tinmiaq 13 Drilling Hazards Summary
12 1/4" Hole / 9 5/8" Casing Interval
Event
Risk Level
Mitigation Strategy
Broach of Conductor
Low
Monitor cellar continuously during interval.
Gas Hydrates
Moderate
If observed - control drill, reduce pump rates,
reduce drilling fluid temperatures, Additions of
Lecithin.
Shallow Gas Pressure
Low
Shallow hazard study has noted that there are no
Anomalies
significant shallow hazards. Follow best practices
and increase mud weight if needed. Mudloggers
will be logging interval.
Gravel / Sand Sloughing / Clay
Moderate
Increase mud weight / viscosity, High viscosity
Sections
sweeps. Monitor fill on connections
Hole Swabbing/Tight Hole on
Moderate
Circulate hole clean prior to trip. Proper hole fill
Trips
use of trip sheets), Pumping out of hole as needed.
Washouts / Hole Sloughing
Low
Cool mud temperatures, minimize circulating times
when possible
Lost Circulation
Low
Prevent by keeping hole clean. If losses occur -
reduce pump rates and mud rheology, use LCM
8 1/2" Hole / 7" Casing Interval
Event
Risk Level
Mitigation Strategy
Shale stability
Moderate
Control with higher MW and proper drilling
practices.
High ECD and swabbing with
Moderate
Condition mud prior to trips. Monitor ECD's with
higher MW's required
PWD tool while drilling to casing point. Pump and
rotate out on trips as a last resort.
Abnormal pressure in zone of
Low
Use PWD to monitor hole. Follow mud weight
interest
schedule as needed. Per shallow hazard study and
offset well data, anticipate normal pressure
Lost Circulation
Low
Use PWD and TAD to monitor hole cleaning.
Reduced pump rates, Mud rheology, LCM. Use GKA
LC decision tree.
Hole cleaning
Low
Use PWD and TAD to monitor hole cleaning. Control
the ROP and use the best hole cleaning practice.
Core Jamming
Moderate
Monitor trend lines and use coring best practices. If
jamming is suspected, stop coring operation and
perform a pull test.
Well Name: Tinmiaq 13
String: 9-5/8 Surface Casing
Company: CPAI
Drilling Engineer: David Lee
Field:
Kuparuk
Rig:
Doyon 141
State:
Alaska
Proposal Number: 1
Date: 10/12/2018
Made By: Stephen Lauper
Objective: Fully Cement Surface Casing with
successful Shoe Formation test for drilling
next section
Acceptance Criteria: Pump per Design (Volume, Density, Rate)
Disclaimer Notice
Schlumberger submits this document with the benefit of its judgment, experience, and good oilfield practices.
This ls,mestionisprovidss m tionsancewithgenaalltarenotedindustrypractice,relyinganfactsainformatimprovidedbyothers,limitations,computer SchlumbepUep
models,measurements,ossumptions and Merences that are not infallible.
Calculations are estimates based on provided mfamation. All proposals, recommendations, or predictions are opinions only.
NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA, INFORMATION PRESENTED, EFFECTIVENESS OF MATERIAL, PRODUCTS OR
SUPPUES,RECOMMENDATIONS MADE, OR RESULTS OF THE SERVICES RENDERED.
Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby.
Document Control
Once approved by Schlumberger and the Operator, any deviation from this program requires document agreement (SLB QHSE
Standard S010 Management of Change and Exemption Standard)
Approvals
Name
Date
Author
Stephen Lauper
Schlumberger Review
Rianne Campbell
via BPM
Customer Approval
David Lee
By signing this document (or confirmation email), I confirm I have reviewed and approved it as the basis for the well cementing program. "
Cementing Program Generated From
Cementics File t13 surface.jdcx
Cementics Version 2017.1.53
Revision History
Date
Version
Description
Author
10/12/2018
V1
Initial Design
slauper
2o" Schlumhepgep
The cementing program incorporates the following data :
RigType
Land
BHST
58 de F
Well Data Summary
Section MD 1900.0 ft
Section TVD 1900.0 ft
Tubulars and Casing Hardware
�MMMMM�-.. M-�
Prev Casing 108.0 16 65.0 151/4 1 H-40 1 630 1640 API
Casing 1850.0 9 5/8 40.0 8.835 1 L-80 1 3087 5745 Antares
Landing Collar 1 1770.0
Inclination (deg)
-0.5 -025 0 025 0.5
0
0
— tncinatfan (deg)
0
N
O
C) #
I
O
O
00
L W
Q
m
p O
O
V
CO
00
m
OI I
O
N
Horizontal Departure (ft)
-0.5 -025 0 025 0.5
0
O
— Horizontal Departure (
0
N
p_ _ __......
V
L O
CO
0 O
O
Geothermal Profile (degF)
20 30 40 50 60 70
0
1
0
— C*otherrral temp. fdegF)
0
N
O
O
O
L m
Q
m
p O
CDO
CO,
R O
E N
O
V
O
m
3o14 Schlumhepgep
Open Hole
Total Volume
401.3 bbl
Minimum Diameter
12.250 in
Maximum Diameter
12.250 in
Mean Diameter
12.250 in
Mean Annular Excess
147.68 %
Mean Equivalent Diameter
15.183 in
Open Hole Excess
Bottom MD
ft
Diameter
in
Excess
Top MD
ft
108.0
928.0
12.250
250.0
928.0
1900.0
12.250
50.0
Temperature
Bottom MD
ft
Bottom TVD
ft
Temperature
de F
0.0
0.0
20
800.0
800.0
32
1850.0
1850.0
58
1900.0
1900.0
60
1950.0
1950.0
61
Formation
Name
Bottom
Bottom
Frac
Pore
Lithology
Res.
MD
TVD
ED
ED
Fluid
ft
ft
lb/gal
lb/gal
Base
928.0
928.0
12.50
8.00
Permafrost
1950.0
1950.0
13.50
8.60
MD ND
4 of 14 Schlumhepgep
Fluids Summary
Fluids
Herschel-Bulkley
Bin hamplastic
Type
Name
Density
Conditions
K
n
Ty
PV
Ty
lb/gal
Ibf.s^n/ft2
Ibf/100ft2
cP
Ibf/100ft2
Drilling
spud mud
10.50
Custom 80 degF [
4.64E-3
0.73
1.72
30.517
12.02
Fluid
T1
Spacer
MUDPUSH II*
10.70
Custom 65 degF [
2 22E-2
0.43
10.19
20.787
21.94
Wash
fresh water
8.32
Manual
1.04E-4
1.00
0.00
5.000
0.00
Slurry
DeepCRETE* lead slurry
11.00
Custom 73 degF [
2.25E-3
0.99
20.98
100.781
21.15
Slurry
15.8 ppg Surface Tail
15.80
Custom 73 degF [
1.16E-2
0.81
0.00
156.773
14.11
W
0
0
m
0
CI I
0
0
0
erg
o L
0
— Rheokagy spud mud (lbfil00ft2)
— Rheology MUDPUSH II* (IbVIOCfit2)
Rheokxgy fresh water (Ibflt CC;ft2)
Rheology DeepCRETE* lead
slurry (ibflI DM)
_ Rheokrgy 15.8 ppg Surface
Tail (IbL+1 gCft2}
200 400 600 800
Shear Rate (11s)
1000 1200
5o,1. Schlumbepgep
Mud Circulation
This model is for estimation of circulating pressures and temperatures. It is not the proposed pre -job circulation schedule.
Fluid
spud mud
Number of Circulation
3.30
Total Volume at Ambient T
1295.0 bbl
Pumping Stages
Fluid Pump Rate Duration Volume Injection T
bbl/min hr:mn bbl de F
spud mud 7.0 03:05 1 1295.0 70
Well Security
Status
Description
Min Diff. Pressure
psi
At Depth
ft
At Time
hr:mn
Success
Fracturing
11
108.0
03:05
Success
Production/Influx
14
108.0
03:05
Success
Burst
5729
0.0
00:00
Success
Collapse
3004
1850.0
03:05
psi
0 200 400 600 800 1000 1200 140C
a
0 o A Pare Pressure (psi)
Frac Pressure (psi}
0 0 — Max Annular Pressure (psi)
Min Annular Pressure jps l
o
= o �
n cv o
o ,
a o o
o �
w o0
m j\
�g
00
0
ti
®
a
= o
m m
m
LO
o_
m LCD
r O
0
m �
2
U
� Q
We temp. (dqF)
Jr
M
Time (hymn)
6o" Schlumhepgep
MD
Oft
Fluid Placement
Fluid Placement in
Annulus
Fluid Name
Top MD
Bottom MD
Length
Volume
Density
ft
ft
ft
bbl
Ib/ al
spud mud
0.0
0.0
0.0
0.0
10.50
MUDPUSH II*
0.0
0.0
0.0
80.0
10.70
DeepCRETE* lead
0.0
1450.0
1450.0
218.4
11.00
slur
15.8 ppg Surface Tail
1450.0
1850.0
400.0
33.5
15.80
Fluid Placement in •.
Fluid Name Top MD
ft
Bottom MD
ft
Length
ft
Volume
bbl
Density
Ib/ al
spud mud
0.0
1638.1
1638.1
124.2
10.50
fresh water
1638.1
1770.0
131.9
10.0
8.32
15.8 ppg Surface Tail
1770.0
1850.0
80.0
6.1
15.80
Pumping Schedule
Pumping•
Fluid Name
Volume
bbl
Pump Rate
bbl/min
Comment
Duration
hr:mn
Total Time
hr:mn
MUDPUSH II*
80.0
4.0
Mix/Pump Spacer (2-7 BPM)
00:20
00:20
Plug
Drop Bottom Plug
00:00
00:20
DeepCRETE* lead slurry
218.4
4.0
Mix/Pump Lead (2-7 BPM)
00:55
01:15
15.8 ppg Surface Tail
39.5
4.0
Mix/Pump Tail (2-7 BPM)
00:10
01:24
Top Plug
Drop Top Plug
00:00
01:24
fresh water
10.0
4.0
Pump Out Plug with Water
00:03
01:27
spud mud
124.2
00:18
> spud mud
114.2
8.0
Displace with Rig
00:14
01:41
> spud mud
10.0
3.0
Slow Rate for Plug Bump
00:03
01:45
Maximum Required Hydraulic Horsepower (HHP) 75.9 hhp (at 01:41 hr:mn)
7 of 14 Schlumhepgep
w
,A qpr
c CO
E
.n
n un
Q
Cl)
00:00 0010 00:40 01:00 01:20 0140
Time (rmn)
r
N
1
Bottom hole pressure ED (Man Static pressure at bottom Pore Pressure At Bottom Hole _ Frac Pressure At Bottom Hole
-- ED (Vgai ED (IbhgaD ED tMal)
00
00:00 00:20 00:40 01:00 01:20
Time ftnn)
8of14
01:40
SchludepUep
Contingencies
Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Any
time a stoppage in the job occurs, follow checklist to determine maximum shutdown time and contingencies. Contingency
minimum displacement rate to be determined from field blend thickening time.
Note any issues in job report.
1. If well has losses prior to cementing
a) Use CemNET (1-2 Ib/bbl; 2 lb MAX). Discuss with town engineer.
b) Attempt to establish max. rate at which full circulation is achieved
c) Pump job at this rate if possible
2. Cement unit failure while mixing
a) Attempt to continue pumping cement at 0.5 bpm
b) Attempt to remedy issue: time <20 min
c) If issue is with mixing system — switch to back-up mixing system
d) If issue is with triplex pump — continue job with secondary triplex pump on unit.
3. Mud pump failure during displacement
a) Attempt to continue displacement with secondary pump
b) Attempt to repair issue: time <10 min
c) Note displacement volume pumped by mud pumps: verify with co. rep/WSL
d) Subtract pumped volume from total volume = volume to be pumped by cement unit
e) Rig up hoses to get mud to cement unit
f) Begin displacement with cement unit: remaining displacement volume verified by co. rep/WSL
4. Top plug does not bump at calculated volume
a) Pump an additional half shoe track volume maximum. DO NOT OVERDISPLACE.
b) If bump still not seen, shut in and hold pressure
5. If floats do not hold
a► Pump back any returned volume
b) Shut in at cement head until the tail cement reaches 50 psi compressive strength
9of 14 SchiumbepUep
Well Security
Well Security
Status
Description
Min Differential Pressure
psi
At Depth
ft
At Time
hr:mn
Success
Fracturing
7
108.0
01:45
Success
Production/Influx
14
108.0
01:28
Success
Burst
5570
0.0
01:45
Success
Collapse
2863
1850.0
01:45
N/A
Dead -End Collapse
0
0.0
00:00
N/A
Dynamic u-tubing in Dead -End
0
0.0
00:00
N/A
Balanced u-tubing in Dead -End
0
0.0
00:00
psi
0 200 400 600 800 1000 1200 140(
O
00
N
O O
C
O
w
Q O
O O- O
N O
m
O
O
• •
10 of 14
Pore Pressure (psi) Max Annular Pressure fpsi Min Annular Pressure (psl
— Frac Pressure (psii
i
1
f
C
r .
1
Schlumbrgep
u:
Temperature Outputs
Temperature Summary Table
Static Temperature at TOC
20 degF
Simulated HCT at TOC
65 degF
Max First Sk Temperature
70 degF
at time
00:00 hr:mn
Static Temperature at BH
58 degF
Simulated HCT at BH
68 degF
Max Last Sk Temperature
70 degF
at time
00:00 hr:mn
T at Bottom Hole (degF)
— spud mud i MUDPUSH II' Interface
Temp{degF)
MUDPUSH IN DeepCRETE'
lead slurry Interface Temp
^� (degF)
-- DeepCRETE° lead slurry I
— 15.8 ppg Surface Tag Interface
Temp (degF)
—__ — 15.8 ppg Surface Tail I fresh
water Interface Temp (degF)
_ fresh water J spud mud InterFace
Temp (degF)
LD I
co
00:00 00:20 00:40 01:00 01:20
Time (hymn)
degF
20 30 40
0
N
O C,
O O
Q W O
C4
O O
m O
v O
rn
m
�c V' O
O
CO O
r O
�2 O
O
O O
" O
01:40
50 60 70
11 of 14 Schlumhepgep
Centralization
Centralizers
Commercial
Alias
Manufacturer
Name
Type
Config
Csg OD
Min OD
Max OD
Count
in
in
in
CE_0958-1214S
Centek
Semi rigid
bow-
9 5/8
9.790
12.250
46
spring
F— Pattern Placement
Bottom MD Joints Centralizer Alias Pattern Min STO Depth
ft ft
1850.0 46.25 CE 0958-1214S 1/1 100.00 0.0
99.5 99.75 100 100.25 100.'
0
O
N
®o
co
L pp
d
N
O 0
O
O
o
O
Y
O
O
Ce
O
O
C2
O
O
O
CV
Standoff Ww centrakmrs
r Standoff at centraftzers
1'ga
MD
Computation time: Cement Turns 00:55
12�14 Schlumhepgep
a
4
WELLCLEAN* III
Average fluid concentration in annulus
Average Concentration (%)
0 20 40 60 80 100
CD
O
N
0
v
0
!a
O
m
Q
-j O
m O)
(O
O
O
CV
O
O
Q
O
CO
— spud mud in ann. (%)
— MUDPUSH II* in ann. (%)
— fresh water in ann. (%)
DeepCRETE' lead slurry in
an I%)
_ 15.E pN Surface Tad in
i
i
oI
O
13 of 14
Average fluid concentration in pipe
Average Concentration
0 20 40 60 60 100 120
0
0
N
"o
T.r
0
CD
0
00
O
O
T�
O
CO
— spud mud in Ao (%)
— h1UDPUSH II* in pipe (%)
— fresh water in pipe (%)
DeepCRETE* lead slum in
pipe (%)
_ 15.5 ppg Surfer Tail in
pipe (%)
Schlumhepgep
Final Fluid Concentrations
Fluids Concentrations
Spud mud
MUDPUSH II'
fresh water
DeepCRETE' lead slurry
. 15.8 ppg Surface Tall
r
19501
Mud On Wall Risk
None
Low
Medium
High
14• a SchlumbepUep
Well Name: Tinmiaq 13
String: Tin Production Casing
Company: CPAI
Drilling Engineer: David Lee
Field: Willow
Rig: Doyon 141
State: Alaska
Proposal Number: 1
Date: 10/12/2018
Made By: Stephen Lauper
Objective: Cementing Casing with isolation for well
test
Acceptance Criteria: Pump per program (Volume, Density, Rate)
Disclaimer Notice
Son lumberger submits this document with the benefit of its judgment, experience. and goad oilfield practices.
This in,noessonisprs, assmtions ancewith generallt are
dillible practice, relying mfacts ainformation provided by others, limitations, computer SchlumbepUep
models,measurements, assumptions and mferencesthat are net infallihle.
Calculations are estimates based on provided information. All proposals, recommendations, or predictions are opinions anly.
NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS Of DATA, INFORMATION PRESENTED, EFFECTVENESS OF MATERIAL, PRODUCTS OR
SUPPLIES,RECOMMENOATIONS MADE, OR RESULTS OF THE SERVICES RENDERED.
Freedom from infringement of any intellectual property rights of Sdilumbarger or others is not to be inferred and no intellectual property rights are granted hereby.
Document Control
Once approved by Schlumberger and the Operator, any deviation from this program requires document agreement (SLB QHSE
Standard S010 Management of Change and Exemption Standard)
Approvals
Name
Date
Author
Stephen Lauper
Schlumberger Review
Rianne Campbell
via BPM
Customer Approval
David Lee
"By signing this document (or confirmation email), I confirm I have reviewed and approved it as the basis for the well cementing program. "
Cementing Program Generated From
Cementics File t13 pc.jdcx
Cementics Version 2017.1.53
Revision History
Date
Version
Description
Author
10/12/2018
V1
Initial Design
slauper
2af 14 Schlumhepgep
79�
wa
Well Data Summary
The cementing program incorporates the following data
Ri T e Land Section MD 4330.0 ft
BHST I 111 de F Section TVD 4330.0 ft
ibulars and Casing Hardware
MMMMMM�-.. M-M
Prev Casing
1850.0
9 5/8
40.0
8.835
L-80
3087
5745
Antares
108.0
16
1 65.0
151/4
H-40
630
1640
API
Casing 4328.0 7 26.0 6.276 L-80 5410 1 7240 API
Landing Collar 4250.0
Inclination (deg) Horizontal Departure (ft) Geothermal Profile (def)
-0.5 -025 0 025 05 -0-5 -0.25 0 025 0.5 20 40 60 80 100 120
0 I 0 0
0
0
0
00
L o
N
O
a
m
N o
m o
m
COo
0
0
v
0
0
LO
1
t
3o14 Schlumbepgep
Open Hole
Total Volume
196.4 bbl
Minimum Diameter
8.500 in
Maximum Diameter
8.500 in
Mean Diameter
8.500 in
Mean Annular Excess
40.00
Mean Equivalent Diameter
9.030 in
Open Hole Excess
Bottom MD Diameter Excess
ft in %
Top MD
ft
1850.0
4330.0 8.500 40.0
Temperature
Bottom MD
ft
Bottom TVD
ft
Temperature
de F
0.0
0.0
20
800.0
800.0
32
1770.0
1770.0
57
4029.0
4029.0
105
4328.0
4328.0
111
4330.0
4330.0
111
Name
Bottom
MD
ft
Formation
Bottom
TVD
ft
Frac
ED
lb/gal
Pore
ED
lb/gal
Lithology
Res.
Fluid
1990.0
1990.0
12.50
8.40
4330.0
4330.0
15.00
8.80
4of14
MD TVD
Oft Oft
1335 ft 1335 ft
1850 @ 1 E53 f: '
Schlumhepgep
drr
u
Fluids Summary
Fluids
Herschel-Bulkley
Bin hamplastic
Type
Name
Density
lb/gal
Conditions
K
Ibf.s^n/ft2
n
Ty
Ibf/100ft2
PV
cP
Ty
Ibf/100ft2
Drilling
Fluid
Mud
9.50
Custom 80 degF [
T1
1.14E-2
0.52
6.45
14.122
18.68
Spacer
MUDPUSH II`
12.50
Custom 65 degF [
5.45E-2
0.36
9.66
29.987
30.85
Wash
fresh water
8.32
Manual
1.04E-4
1.00
1 0.00
5.000
0.00
Slurry
15.8 ppg Class G
15.80
Customr73 degF [
1.16E-2
0.81
0.00
156.773
14.11
Drilling
Fluid
Brine
9.50
Downhole 100 degF
5.95E-3
0.59
7.10
14.507
14.29
Ln
cn
0
Cn
0
Ln
N
N
O
O C),
N
N
S/3 C>
iv
0
Ln
0
— Rheology Mud (bf/1DOU)
— Rheology MUDPUSH II' (1bfdIOM)
— Rheobgy Brine (IbNWft2i
— RheolDgy fresh water (bV1D=)
_ RheoNy 15.8 ppg Glass G
(�',fi1 uGfit2)
i
1
i
i
Shear Rate (11s)
5o14 Schlumhepgep
r
Mud Circulation
This model is for estimation of circulating pressures and temperatures. It is not the proposed pre -job circulation schedule.
Fluid
Mud
Number of Circulation
2.19
Total Volume at Ambient T
650.0 bbl
Pumping Stages
Fluid
Pump Rate
bbl/min
Duration
hr:mn
Volume
bbl
Injection T
de F
Mud
2.0
00:15
30.0
80
4.0
00:15
60.0
80
7.0
01:20
560.0
80
Well Security
Status
Description
Min Diff. Pressure
psi
At Depth
ft
At Time
hr:mn
Success
Fracturing
172
1850.0
01:50
Success
Production/Influx
106
1850.0
01:50
Success
Burst
6955
0.0
01:50
Success
Collapse
5189
4328.0
01:50
C
C
L C
r, C
C
N C
m q.
N
Ct`
C
C
C
Lf
6of14
psi
0 500 1000 1500 2000 2500 3000 350C
Porn Pressure (psi)
— Frac Pressure (psi)
— Max Annular Pressure (psi)
Min Annular Pressure (psi)
0
L
0
= o
m r
m
m o
E Q
N
Q �
E
m
rn
M
U M
'O
— Eo3ttDm hok temp. (degF)
n
00:00 D020 0040 01,00 0120 01:40
Time (hrmn)
Schlumhepgep
MD
Oft
Fluid Placement
Fluid Placement in
Fluid Name
Annulus
Top MD
ft
Bottom MD
ft
Length
ft
Volume
bbl
Density
lb/gal
Mud
0.0
1385.1
1385.1
39.1
9.50
MUDPUSH III
1385.1
2700.0
1314.9
40.0
12.50
15.8 ppg Class G
2700.0
4328.0
1628.0
51.5
15.80
Fluid Placement in Pipe
Fluid Name Top MD
ft
Bottom MD
ft
Length
ft
Volume
bbl
Density
lb/gal
Brine
0.0
3986.6
3986.6
152.5
9.50
fresh water
3986.6
4248.0
261.4
10.0
8.32
15.8 ppg Class G
4248.0
4328.0
80.0
3.1
15.80
Pumping Schedule
Pumping•
Fluid Name
Volume
bbl
Pump Rate
bbl/min
Comment
Duration
hr:mn
Total Time
hr:mn
MUDPUSH II'
40.0
4.0
Mix/Pump Spacer (2-7 BPM)
00:10
00:10
Plug
Drop Bottom Plug
00:10
00:20
15.8 ppg Class G
54.5
4.0
Mix/Pump Slurry (2-7 BPM)
00:14
00:34
Top Plug
Drop Top Plug
00:10
00:44
fresh water
10.0
4.0
Pump out Plug
00:03
00:46
Brine :
152.5
00:21
> Brine
142.5
8.0
00:18
01:04
> Brine
1 10.0
3.0
Slow Rate for Plug Bump
00:03
01:07
Maximum Required Hydraulic Horsepower (HHP) 245.8 hhp (at 01:04 hr:mn)
7o,1. Schlumbepgep
i
00:00 00:10 00:20 00:30 00:40 00:50 01:00
Time (hrmn)
0
v r,
00:00 00:10 00:20 00:30 00:40 00:50 01:00
Time (hr.mn)
ti
co - .. — Bottom hole pressure ED Wgalj Static pressure at bottom Pore Pressure At Bottom. Hale Frac Pressure At Bottom Hole
ED (Vgalj ED (ib/pa ED (Vgal)
u�
N
rn
00:00 00:10 00:20 00:30 00:40 00:50 01:00
Time (hymn)
8o,1. Schlumhepgep
Contingencies
Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Any
time a stoppage in the job occurs, follow checklist to determine maximum shutdown time and contingencies. Contingency
minimum displacement rate to be determined from field blend thickening time.
Note any issues in job report.
1. If well has losses prior to cementing
a) Use CemNET (1-2 Ib/bbl; 2 lb MAX). Discuss with town engineer.
b) Attempt to establish max. rate at which full circulation is achieved
c) Pump job at this rate if possible
2. Cement unit failure while mixing
a) Attempt to continue pumping cement at 0.5 bpm
b) Attempt to remedy issue: time <20 min
c) If issue is with mixing system — switch to back-up mixing system
d► If issue is with triplex pump — continue job with secondary triplex pump on unit.
3. Mud pump failure during displacement
a) Attempt to continue displacement with secondary pump
b) Attempt to repair issue: time <10 min
c) Note displacement volume pumped by mud pumps: verify with co. rep/WSL
d) Subtract pumped volume from total volume = volume to be pumped by cement unit
e) Rig up hoses to get mud to cement unit
f) Begin displacement with cement unit: remaining displacement volume verified by co. rep/WSL
4. Top plug does not bump at calculated volume
a) Pump an additional half shoe track volume maximum. DO NOT OVERDISPLACE.
b) If bump still not seen, shut in and hold pressure
5. If floats do not hold
a► Pump back any returned volume
b) Shut in at cement head until the tail cement reaches 50 psi compressive strength
9o,14 SchlumbepUep
�x
Well Security
Well Security
Status
Description
Min Differential Pressure
psi
At Depth
ft
At Time
hr:mn
Success
Fracturing
99
4328.0
01:04
Success
Production/Influx
106
1850.0
01:03
Success
Burst
6161
0.0
01:04
Success
Collapse
4460
4328.0
01:07
N/A
Dead -End Collapse
0
0.0
00:00
N/A
Dynamic u-tubing in Dead -End
0
0.0 1
00:00
N/A
Balanced u-tubing in Dead -End
0
0.0 1
00:00
psi
0 500 1000 1500 2000 2500 3000 350(
O
10 of 14
i
Pore Pressure () -- Max Annular Pressure (psi) Min Annular Pressure (psi)
jFrac Pressure (psnj
i
i
a
1 I
j 4
Schlumbepgep
'N. P-e",V-
Static Temperature at TOC
77 degF
Simulated HCT at TOC
80 degF
Max First Sk Temperature
80 degF
at time
01:01 hr:mn
LL
0
r_
r�
m
re
U
Temperature Outputs
Static Temperature at BH
111 degF
Simulated HCT at BH
80 degF
Max Last Sk Temperature
80 de F
at time
00:00 hr:mn
T at Bottom Hole (degF) _ fresh water / Brine Interface
_ Mud r MUDPUSH II` Interface Temp (degF)
Temp (degF)
_ MUDPUSH IN 15.8 ppg Class
G Interface Temp (degF)
_ 15.8 ppg Class G J fresh
water Interface Temp (degF)
00:00 00:10 00:20 00:30 00:40 00:50 01:00
Time (hrmn)
degF
20 40 60 80 100
O
0
0
0
L o
a O
m N
U
O
O
m M
O
O
O
O
O
O
Ln
120
I I of 14 Schlumbepgep
9s
`g
,
Centralization
Centralizers
Alias Manufacturer
Commercial
Name
Type
Config Csg OD
in
Min OD Max OD Count
in in
ma 1501270-7-6 Positive Hou
1501270
ri id
Positive 7
8.252 8.252 38
Pattern Placement
Bottom MD
Joints Centralizer Alias
Pattern Min STO Depth
ft
ft
2800.0
70.00
0 100.00 0.0
4328.0
38.20 1501270-7-6-Positive
1 /1 100.00 2801.8
99.5 99.75
0
u Qo
o
cIj
a>
0
v
a>
o
o
m
0
0
c
0
0
MD
0�+
_ Standoff bM centraleers
t °�1
Standoff at centralizers
i
Computation time: Cement Turns 00:59
12o14 SchlumbepUep
WELLCLEAN* III
Average Concentrations
Average fluid concentration in annulus Average fluid concentration in pipe
Average Concentration (%)
Average Concentration (%)
0 20 40 60 80� 1OG
C:)0 21 4D 60 BD 100 120
0
0
CV
0
0
Ln
CV
C>
O
Cl)
Q
N
0
5D
00
m
iE O
CD
M
C3
O
V
13 of 14
— Mud in ann. (%)
— MUDPUSH II* in ann. (%)
Brine in ann. jgb)
— fresh water in ann. %%)
_ 15.3 ppg Glass G in ann.
N
0
CD
C)
C)
O
CD
C)
V
C
f
4
SchlumbepUep
Final Fluid
Concentrations
1385 ft
1650 ft
15 8 ppg Class G
2700 ft
-- ti
I
f
i
I
39Vft _�. I fresh •.va:er
15,3 ppg Class_ G
424Bft ti1uC -
4328 ft__.—.
4330 ft ,.
14 of 14
Fluids Concentrations
Mud On Wall Risk
■ Mud
Nan.
MUDPUSH II'
Low
. Brine
. Medurh
fre5hwa[er
High
1S.8 ppg Class G
SchlumbepUep
n
a
o
TvD.. (ft)
5 additional pages redacted, as they contain information about
indefinite confidential wells in NPRA. M. Guhl 7/7/2023
Doyon 141 Well Control Equipment and Schematics
1t'FT T. CONTROL EQL'IP14ENT
BOP Equipment
• '- ee. — Hydril annular ditierterBOP. 21 `/." x 2000 psi
• 1 ea. - Hydril anui►rlar BOP nth nitrile element, model GK 13 54x 5000 psi, flanged, NACE trim.
a 3 ea. - Hvdril single gate. model NTL: 13 51" x 5000 psi fianggA NACE trim cririth 19' operators.
BOP Rams for 13 S18" x Sm
a 1 -set of Hydril blind rams-
* 1- set of Hydril 2 74" rams.
a 1- set of Hydril 3 UY rams.
a 2 - sets of I �vdril 5" rams.
a 1- set of Hydril Trams.
Variable or other rams shall be provided per contractual agreement
Spools and ahws
a 1 ea. - mud cross, 13 51" x 13 51" x 5000 psi with two ea.- 3 PS" x 5000 psi side outlets, RACE trim,
a 1 ea. - adapter spooL 13 5=8" x 1l" x 5000 psi. MACE than.
2 ea. - 3 1,,Y' x 5000 psi, hydraulically operated ( choke and kill HCR.) gate vahes, MACE trim
a 2 ea. - 3 IW x 5000 psi manual vah es . NACE trim
a I ea. - di -eater spool, 2014" x 20114" x 2000 psi, with one ea. 16" 1150 psi outlet fir knife gate vah e
a 1 ea. - adapter spool, 201?4" x 16" x 2000 psi
6
Choke lfaar►rfold
• 1 ea. - 2 V15" x 5000 psi, manual gate valve, NACE trim
12 ea. - 3 118" x 5000 psi, manual gate csalves, MACE trim
• 1 ea. - 3 W x 5000 psi, manual choke
• 1 ea. - 3 14" x 10,000 psi., remote operated hydraulic choke
• All valves have MACE trim and color coded handle: for sequen_me.
• The remote choke control panel is located on the drill floor
BOP Closing unit
• lea. - Koomey, Type 80, 5 station, 3000 psi, 180 gallon accumulator unit_
• Primary closing hydraulics is pro-Med by an electrically dri,.Tn triplex pump. Secondary back-up is a 30:1
au pump; and emergency pressure is prm ded 8sy bottled nitrogen
• The remote closing operator panels are located in the doghouse, and on the accumulze:ur unit.
BOP rest Funap
• 1 ea. -triplex pump capable of 5;GCC psi with 30 gallon dedicated te-t quid tom.
• 1 ea. - two pin. chart recorder for BOP tests
Drinstaing I a IVS
• 1 ea. - HydriL 10,000 psi.. 4112 IF upper kelly cock
• 2 ea. - Hydril. 10.WO psi, 41/2 IF lower kelly cocks
• lea. - HydriL 10,000 psi , 41a2 IF, IBOP -.alve
1 VALVE tEGEN0
: BrrAss
3 CHOKE
tt�� a BOtIf%1 AAK
_. _. _.___._._._._ _
rwm na)sa�a wrwu w �w 3 BL9W KILS
ar_ ilk Krl01kY, 1r1'E-80, tla GAL b SiArKIN 8 tOP PWC RAY$
'r mt anf.me .ICE a00 YAC. 20 NP 7 4WVW
+'epY�Aramwi
*
—
allrmnc+l vur
Y+a'oeu u[
�iii �.�••—..�++ry�rwm
a lArmnas rm
an �c Iw atwm �<
O
�� a `'L�� YDIIattL
. ruc O O O y r
lEk
O
AC tinATOR
20 BOMEi. 11 GAIL0; Lt4
i IY�
eamae22 Blracw B
.+mwo w.r 9Jr m,m � a wrltEs, xxs CU.
3. "., a om av
p�
> nee cn ue Iwmc•h•® e�
euA6 0^IFAm C++m^C-••kArLyy n y.' rm R rgtl
r.ox.t w aua ur.t. oYdsmen
Wtlu,emeer,J.�
i
ac
Stlwh
,.;y m:
oei..... 'J,Wp umae
4 H
AI
U) IxS &)
fla
iu "1 aa1
f
fl)
1. IOx 88tl
1
1,
I
1) )A)
1 11,4 1.19
! �
Y f1eW IJt p1 ma
10.1
t4 ).fl
s.zs u.
(
�
la.x
i6
s3o 11 ).0
ili"Q
(
1y 1n• Jwi
1 .4
i41 11.9 ).>!
am w.�mn
{ i
ib�—
1.9
S6] �i7 r96
Sa) a.1 601
x 65 tlAtl
11'
i
1
fl19 1.1
ex
1
1 t0.5
�x9 tp.e qy
1
6
1 i
0 1 sa1
12.8
fl84 I7.3 &00
�1 GAS
—TEB ELEYA11011
Mw
9 ^
V iLpoymv !W1LL1,wW 1#AC.
MATERIAL LIST
I em Description
A
3.111 V 10M TR1fLOW Remote
Operated Hydroule Choke
B
3-W5MTWeH2A4usM*Ch*e
1
2.111 r SM Manual Gate Valve
2-14
3-118' 5M Manual Gate Valve
RIG - 141
White Handle Valves
Normally Open
Red Handle Valves
Normally Closed
Date: 11-27-01 Rev. 1
ADAPTER, A-4-M,
II-5K STDD BTM X
TUBING HANGER, TC-IA-EMS
4 i/16-5K STDD TOP
F/ 10.880 BOWL,
BORED F/7.115 OD EN
4 1/2 BTBG-MOD BTM X
P119036-0002
4 1/2 BTBG TOP,
W/ 7.115 EN
TUBING HEAD SECTION ASSY,
PIOOOOO9887
10.380 THRU-BORE,
II-5K STDD BTM
X II-5K FLG TOP
.47
P120190-0002
13.00
2 1/16-5K M120 PLUS GV
O
10
26.42 01 0
01 0
57.78 PACKOFF, A-75
10.380 BOWL X 7
UNIHEAD SECTION ASSY,
12-150-016 ? !=.�.z.Y.�.
r•=y G 10.380 BOWL,
12 INCH NOM TAPER M-TO-M SEAL BTM
_--- -------
-------_ -----_ X II-SK FLG TOP
.16
P1000137865
2 1/16-5K M120 PLUS GV
13.60
CASING HANGER, C-21
10.38 X 7
1
12-093-112
!
22.75
O
O�O
CASING HANGER, MANDREL, FLUTED
F/ 10'380 BOWL,
BELL NIPPLE,
7 TSH 563 26.0 LB/FT IFIBTM
9 5/8 SOW W/ TP
X 8.000-4 NA-2G-LH (M)TOP
12'NOM TAPER M-TO-M SEAL TOP
P1000124695
PI 18334- 0005
CASING HANGER MANDREL, LANDING RING,
10.22 FLUTED. F/ 15.27 BOWL.
16.46
9.625 TSH 563 (40 LB/FT) (F) X
CASING HANGER, C-21
10.750-4 SAM2-2G-LH (F),
G SE W/ 5 DENOM M-TO-M AL PREP TOP
15.25 BOWL X 9 5/B
P1000124693
W/STEP-DOWN OD -
12-090-184
LANDING RING
16 SOW BTM PREP X
16.00 SLICK NECK TOP,
14.60 ID X 15.27 BOWL
13-140-660
16' 00 CASING
9 5/8' OD CASING
IL
7' DO CASING
4 1/2'OD TBG
GEN 5
SLIM
HOLE
COOHOOCCIPHDLLENS
ALASKA
16 X 9 5/8
X
7 X 4 1/2 QUOTE LAYOUT
REF: DMID0153363
DMI00271949
PRIVATE AND CONFIDENTIAL
DESCRIPTION
)RAWN BY:
DATE:
T. PHAM
10-25-17
UNLESS OTHERWISE AGREED TO IN WflITING.THIS DOCUMENT AND ALL THE
INFORMATION CONTAINED HEREIN ARE THE CONFIDENTIAL AND EXCLUSIVE
RAFTING CHECK:
DATE:
SURFACE WELLHEAD LAYOUT
�TechnlpFMC
i
AND
OIEl RINDOUCEILE.. S[LOSE0. OR MADE PUBLIC IN ANY MANNEflTPREOR ETO EXPRESS SWRITTEN
16 X 9 5/8 X 7 X 4 1 /2
Z. MAROUEZ
10-25- 7
ESIGN REVIEW:
DATE:
SHEET SIZE
AUTHORIZATION BY TBOhnIDFMC. THIS DOCUMENT IS ACCEPTED BY
CASING PROGRAM,
RECIPIENT PURSUANT i0 AS
TREEMENT TO THE FOREGOING.
ANDMUSTBE P
-5K X 4 1/16-5K,
C. McNELIS
0-25-17
NA
MANUFACTURER ALREE5 THAT ARTICLES MADE IN ACCORDANCE WITH THIS
MANUFACTURING APPROVAL:
DATE:
ECN NUMBER
REV.
CONOC OPHI LL I PS,
DOCUMENT SHALL BE CONSIDERED T-h,,IDFMC'S DESIGN AND THAT
0 - 2 5 - 1 7
A
UR IDENTICAL ARTICLES DR PARTS THEREOF SHALL NOT BE MANUFACTED
FOR THE USE OR SALE BY MANUFACTURER OR ANY OTHER PERSON
ALASKA
PPRDVED BY:
DATE:
DRAWING NUMBER
HEFT
WITHOUT THE PRIOR EXPRESS WRITTEN AUTHORIZATION BY TeChnIDFMC.
J. GARZA
10- 25 -1 7
D M I 0 02 7 2004
1 / 1
COPYRIGHT TBChnIpFMC
W1
G
f9
L
O
L.
a
DO
_O
M
rj -1
6m
o a
m
c O v
c ° a w-
cu c
m
a `o c
Ci C�- O
c O m
3 O a =
c �
w
CO v O 00 C
I u m E
0 0' N
LA LA LLL M
•
d
O
2
I
0
o
a,
m
>
..
'a
a
au
O
o
c
E
f0
~
m
m
o
=
u
°
3
c
3
m
o
c
o
m
"
m
m
a
�+
=
,vvQ
OcL
EOcYcO3O
v O
-a
d
o
•O u
N
Y y
m w
Y
v
rR
Q
£c
c`
O
E
U
v a
v
Q s
N Z
U O
NN
LO
b O
Q > N
•
c
�
fc6 O
L
ct • o
V �
E
..
Q. . N
6 '
bD
O
c
Q
. L
•
•
O
U
V)
•
2 LO
U 141
v
CL
�
•,
L
i
�
L
O
M
V
V
N
O
p i
? w
�
i 6 N
@
4`
U
L
O
•
OD
�\
\
$ $
\
C_
E § .ED
` :
{
i a
§}
o
c
c
=
E 1 \ ;
& _
\
G \ ;
w
.
u
\
E
8 0
}
/ / 0
E
\ G ;
/
/
® \
a)
(
Q
\
/
®
® E
c c
c:_
®
E }
Q
\
k
>
\
In
_ ..
. \
c
E.
\
CL c
E
®
/ § c
§CL )
\
§ E 0 .
-
B
a t
\
f
76
\ ~ \
\
J
§ /
\ \
\ \
\
\
\
\
§ 2
L \
§
o c;
cr- 3
%
j
u
q
/
c
\
\
\
CL(
)
2
�)
4
a
\
CL
—
e
e
CL
§
u
k
/
.
-
)
}
2
w
$
,
e
2
}
/
/
/
u
e
e
Transform Points
Source coordinate system Target coordinate system
State 'Plane 1927 - Adaska Zone 5 Albers Equal Area (-154)
rI Datum: Datum:
NAD 1927 - North America Datum of 1927 (Mean) NAD 1927 - North America Datum of 1927 (I'ittean)
- -
Northing Easting Easting Northing
1 5983340 05961 1 53936.2 2265664.9
2 2
(Type values into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctrl+C to
Opy and +Vto paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system.
E e Back I G Finish i Cancel j Help
Office
Project
26 November 2018
INPUT
State Plane, NAD83
5005 -Alaska 5, U.S. Feet
OUTPUT
State Plane, NAD27
5005 -Alaska 5, U.S. Feet
Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm.
Northing/Y: 5983055.92
Easting/X: 1845980.95
Convergence: 1 34 21.58773
Scale Factor: 0.999948006
Tinmiag 13 1/1
Northing/Y: S983339.986
Easting/X: 705960.860
Convergence: 1 34 32.37787
Scale Factor: 0. 999948188
Grid Shift (U.S. ft.): X/Easting =-1140020.1, Y/Northing = 284.1
Datum Shift (m.): Delta Lat. = 40.836, Delta Lon =-119.286
Remark:
Corpscon v6.0.1, U.S. Army Corps of Engineers
From: Lee, David L
To: Boyer, David L (DOA)
Cc: Davies Steybgn F (DOA); Allen. Troyce B L rbis Engineering, Inc.) )
Subject: RE: [EXTERNAL]Digital Copies of Surveys for Tinmiaq & West Willow Wells
Date: Monday, November 5, 2018 1:53:22 PM
David, I double checked, you are right, bond number should be 5952180.
5752570 is for the BLM.
We will correct go forward.
Thanks
David
From: Boyer, David L (DOA) <david.boyer2@alaska.gov>
Sent: Monday, November 05, 2018 1:40 PM
To: Lee, David L<David,L.Lee@conocophiIIips.com>
Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov>
Subject: RE: [EXTERNAL] Digital Copies of Surveys for Tinmiaq & West Willow Wells
David,
Thank you for the digital survey files. According to Steve, so long as we have the surface and BHL in
NAD 27 on the permit, we should be O.K. with our program. It looks like Zone 5 was used for the
official location of the well on the PTD.
Also, we noticed that the bond no. 5752570 does not match the bond held by AOGCC (No. 5952180)
shown as active here. Is it possible that the 5752570 bond is one held by DNR instead? Please check
on this.
Best regards,
Dave Boyer
From: Lee, David L <David.L.LeePconocophillipscom>
Sent: Monday, November 5, 2018 6:23 AM
To: Boyer, David L (DOA) <david boyer2(@alaska gov>
Cc: Davies, Stephen F (DOA) <steve.daviesr@alaska Ov>
Subject: RE: [EXTERNAL] Digital Copies of Surveys for Tinmiaq & West Willow Wells
Dave, attached please find the surveys for the 10 wells. I have attached two text files for each.
Please note, ConocoPhillips works in NAD83 Zone 4 so all these files are in this coordinate system. If
you want a different file please let know.
David Lee
From: Boyer, David L (DOA) < vi yer2@alaska.gov>
Sent: Friday, November 02, 2018 1:47 PM
To: Lee, David L <David.LL.eei«�cono hilli s rnn,>
Cc: Davies, Stephen F (DOA) <steve davies(@alaskar v>
Subject: [EXTERNAL] Digital Copies of Surveys for Tinmiaq & West Willow Wells
Hi David,
Today we received PTD applications for 10 exploration wells from ConocoPhillips. These include
Tinmiaq 10-16 and West Willow 2,4 & 5. We have to load the survey data into our Geographic
program here to process the applications. If you can provide digital copies of the surveys for these
10 wells by e-mail, they really help to speed up the process vs. scanning hard copies with scanning
errors all too frequent. If possible, please provide the survey files in Excel or ASCII format. The
whole files are fine, whatever is easier, but we only load MD, Inclination, and Azimuth, and the
program generates the rest.
Thank you. You are going to be very busy this winter season!
Best,
Dave Boyer
Senior Geologist
AOGCC
FIELD:
TRANSMITTAL LETTER CHECKLIST
WELL NAME: T I h vv� i o-q 1.3
PTD: a 1$ " i tf-
Development Servicey Exploratory Stratigraphic Test Non -Conventional
POOL:
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing well Permit
LATERAL
No. , API No. 50- - - -
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50- -
- -� from records, data and logs acquired for well
name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool —
Well Name: TINMIAQ 13 __- .Program EXP Well bore seg ❑
PTD#:2181440 Company CONOCOPHILLIPS ALASKA_INC. Initial Class/Type
EXP / PEND GeoArea 890 Unit 00000On/Off Shore On Annular Disposal ❑
Administration 117
Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) - - - -
NA
1
Permit fee attached
NA
2
Lease number appropriate
Yes
3
Unique well name and number
Yes
4
Well located in a defined pool -
No
5
Well located proper distance from drilling unit boundary
Yes
6
Well located proper distance from other wells
Yes
7
Sufficient acreage available indrillingunit
Yes
8
If deviated, is wellbore plat included
Yes
Property plat included, well is -a- vertical hole.
9
Operator only affected party
Yes -
10
Operator has appropriate bond in force
Yes -
Bond no. corrected to AOGCC Blanket Bond.
Appr Date
11
Permit can be issued without conservation order-
Yes
i12
Permit can be issued without administrative approval
Yes
DLB 11/26/2018
13
Can permit be approved before 15-day-wait - - - -
Yes -
14
Well located within area and strata authorized by Injection Order # (put 10# in comments) (For
NA
15
All wells within 1/4 mile area of review identified (For service well only)
NA
16
Pre -produced injector: duration of pre -production less than 3 months (For service well only)
NA
18
Conductor string provided
Yes
16" conductor set at 80 ft. (cemented in place)
Engineering
19
Surface casinoprotectsallknownUSDWs -
NA
Permafrost area
20
CMT vol adequate to circulate on conductor & surf csg
Yes
9 5/8" caisng will be fully cemented
21
CMT vol adequate to tie-in long string to surf csg
No
7" production will cemented to 2700 ft-
22
CMT will coverall known -productive horizons
Yes
23
Casing designs adequate for C, T, B & permafrost
Yes
24
Adequate tankage or reserve pit -
Yes -
Doyon 141 has steel pits.. All waste will be transported to approved disposal site. - -
25
If a re -drill, has a 10-403 for abandonment been approved
NA
26
Adequate wellbore separation proposed - -
Yes
Vertical well,.
27
If-diverter required, does it meet regulations ---------------
Yes
Doyon 141-rig has 16" diverter line
Appr Date 28
Drilling fluid program schematic & equip list adequate
Yes
Max form pressure= 1936 psi (8.6 psi EMW) Will drill with 9.5 ppg mud
GLS 12/27/2018 29
BOPEs, do they meet_ regulation
Yes
Doyon 141 has 13 5/8" 5000 psi WP BOPE
30
BOPE press rating appropriate; test to _(put psig in comments)
Yes
MASP = 1503 psi ( will test BOPE 3500 psi - annular to 2500 psi )
31
Chokemanifoldcomplies w/API-RP-53 (May 84)
Yes -
32
Work will occur without_ operation shutdown
Yes
Well plan is to run casing and tubing then suspend well until next year. -
33
Is presence of H2S gas probable -
Yes
H2S measure are required for exploration wells.
34
Mechanical condition of wells within AOR verified (For service well only)
NA
f35
Permit -can be issued w/o hydrogensulfidemeasures
Yes
Geology I36
Data presented on potential overpressure zones
Yes
Appr Date
Seismic analysis of shallow gas zones
Yes
�37
DLB 11/26/2018
38
Seabed condition survey (if off -shore)
NA
39
Contact name/phone for weeklyprogressreports- [exploratory only]
Yes
Geologic Engineering Public After drilling well will suspend. Not perforating or fracing until next ice season. GIs
Commissioner: Date: Commissioner: Date Commissi er Date
