Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout219-194 P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 9, 2025
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner Jessie Chmielowski:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of
these wells were found to have a void in the conductor. These voids were filled with cement if
needed and corrosion inhibitors, engineered to prevent water from entering the annular space.
As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification
that the treatments took place and meets the requirements of form 10-404, Report of Sundry
Operations. The attached spread sheet presents the well name, top of cement depth prior to filling
and volumes used on each conductor.
Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions.
Sincerely,
ConocoPhillips Well Integrity Field Supervisor
RBDMS JSB 081425
Digitally signed by Brennen Green
DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@
conocophillips.com
Reason: I am the author of this document
Location:
Date: 2025.08.11 16:34:01-08'00'
Foxit PDF Editor Version: 13.1.6
Brennen Green
ConocoPhillips Alaska Inc.Well Name API # PTD #Initial top of cementVol. of Portland Type I cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant datein gal in gal1C-17 50-029-22872-00-00 198-224 N/AN/A post SC Repair8" N/A 0.85 8/7/20251C-150 50-029-23496-00-00 213-120 N/AN/A Rig cemented to surface4" N/A 3 8/7/20251C-152 50-029-23548-00-00 215-114 50" 34.4 9" 7/31/2025 2.13 8/7/20251C-153 50-029-23549-00-00 215-116 N/AN/A Rig cemented to surface9" N/A 1.73 8/7/20251C-154 50-029-23559-00-00 215-166 70" 51.8 10" 7/31/2025 3.4 8/7/20251C-155 50-029-23561-00-00 215-180 64" 35.8 8" 7/31/2025 1.7 8/7/20251C-15650-029-23750-00-00 223-023 25" 12.00 10" 7/31/2025 5.1 8/7/20251C-157 50-029-23754-00-00 223-038 57" 30.28 9" 7/31/2025 2.2 8/7/20251C-15850-029-23761-00-00 223-056 3"N/A Rig cemented to surface10" 7/31/2025 4.25 8/7/20251C-501 50-029-23757-00-00 223-045 139" 11.40 8" 7/31/2025 3.8 8/7/20251H-107 50-029-23795-00-00 224-092 34" 14.80 10" 7/31/2025 5.25 8/7/20251H-11250-029-23787-01-00 224-032 47" 33.19 7" 7/31/2025 4.25 8/7/20251H-12050-029-23794-01-00 224-081 30" 13.70 8" 7/31/2025 4 8/7/20253H-3550-103-20805-00-00 219-064 45" 32.20 7" 8/1/2025 3.6 8/8/20253H-3650-103-20838-00-00 222-014 60" 44.20 8" 8/1/2025 3.4 8/8/20253H-3750-103-20822-00-00 219-194 35" 23.00 8" 8/1/2025 3.4 8/8/2025Date 08/09/251C, 1H, and 3H PadsKuparuk FieldReport of Sundry Operations (10-404)Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off3H-3750-103-20822-00-00219-19435"23.008"8/1/20253.48/8/2025
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
Date: May 27, 2025
FFROM:Anu Ambatipudi TO: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
700 G Street 333 W.7th Ave., Suite 100
Anchorage AK 99501 Anchorage, Alaska
DATA TRANSMITTAL
Kuparuk River Unit/Field
Well API #PTD #Comments
1H-112 50029237870100 2240320
3B-16A 50029212890100 2231250
2B-03B 50029211510200 2230800
2M-39 50103207950000 2181710
3S-612 50103207770000 2181110
3S-611 50103207740000 2181030
1H-108B 50029236080200 2180820
1H-110 50029236010000 2180310
1H-116 50029235940000 2180120
2S-06 50103207470000 2160850
2M-37 50103207450000 2160820
1D-39 50029229970000 2002160
1D-40A 50029229690100 2001900
2N-302 50103203800000 2011150
1R-03A 50029214060100 2000210
3H-37 50103208220000 2191940
2S-09A 50103207490100 2161280
T40450
T40451
T40452
T40453
T40454
T40455
T40456
T40457
T40458
T40459
T40460
T40461
T40462
T40463
T40464
T40465
T40466
By Gavin Gluyas at 1:15 pm, May 28, 2025
3H-37 50103208220000 2191940
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
Colville River Unit/Field
Well API # PTD # Comments
CD5-31 50103208280000 2210020
CD5-96 50103208110000 2191620
CD4-499 50103208100000 2191610
CD5-26 50103208060000 2191070
CD5-98 50103208030000 2190590
CD5-24 50103207990000 2190060
CD5-23 50103207610000 2171550
CD5-19 50103207600000 2171210
CD5-22 50103207590000 2170890
CD5-316 50103207560000 2170400
CD3-111A 50103205260100 2170040
CD3-198 50103206370000 2110240
CD4-24 50103206020000 2090970
CD4-26 50103206000000 2090490
CD2-15 50103203860000 2011590
CD2-12 50103204550000 2030730
CD4-214 50103205370000 2061450
CD4-17 50103205340000 2061180
CD2-73 50103205900000 2081960
T40467
T40468
T40469
T40470
T40471
T40472
T40473
T40474
T40475
T40476
T40477
T40478
T40479
T40480
T40481
T40482
T40483
T40484
T40487
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
Greater Mooses Tooth Unit/Field
Well API # PTD # Comments
MT7-99 50103208450000 2221020
T40485
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϭϵϭϵϰϬ Ͳ^Ğƚ͗ϯϲϮϳϰJRBy Abby Bell at 1:43 pm, Dec 21, 2021
1H-11950029235910000 KRU WLIPROFFINAL FIELD24-Jun-211H-11750029236020000 KRU WLIPROFFINAL FIELD16-Jun-213H-31A50103202050100 KRU WLCUTTERFINAL FIELD31-Jul-213S-61150103207740000 KRU WLCUTTERFINAL FIELD11-Oct-211R-10150029214040300 KRU WLSAMPLINGFINAL FIELD30-Jun-213H-3750103208220000 KRU WLGLSFINAL FIELD29-May-213F-0450029214490000 KRU WLIPROFFINAL FIELD23-Feb-211J-10150029232860000 KRU WLPPROFFINAL FIELD2-Mar-211D-0250029204290000 KRU WLIPROFFINAL FIELD17-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD18-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD20-Feb-21MP-150029205730000 KRU WLSCMTFINAL FIELD28-Mar-211G-0250029208130000 KRU WLIPROFFINAL FIELD1-Apr-211C-19050029231360000 KRU WLIPROFFINAL FIELD30-Oct-212L-31850103206810000 KRU WLIPROFFINAL FIELD24-Jul-21
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Company:
Conoco Phillips Alaska, Inc.
Well:
31-1-37
Field:
Kuparuk River
State:
Alaska
Country:
USA
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By Samantha Carlisle at 10:38 am, Dec 01, 2020
Sandeep Pedam Digitally signed by Sandeep Pedam
Date: 2020.11.30 17:29:31 -09'00'
CDW 2/24/2021
VTL 3/3/21
RBDMS HEW 12/1/2020
DSR-12/2/2020
SFD 12/1/2020
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Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
LAST TAG:3H-37 jennalt
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: UPDATED FRAC INFORMATION 11/30/2020 3H-37 pproven
Casing Strings
Casing Description
CONDUCTOR
OD (in)
20
ID (in)
19.12
Top (ftKB)
37.5
Set Depth (ftKB)
156.5
Set Depth (TVD) …
156.5
Wt/Len (l…
94.00
Grade
H-40
Top Thread
Casing Description
SURFACE
OD (in)
10 3/4
ID (in)
9.95
Top (ftKB)
37.5
Set Depth (ftKB)
3,620.5
Set Depth (TVD) …
2,946.5
Wt/Len (l…
45.50
Grade
L-80
Top Thread
Hyd563
Casing Description
INTERMEDIATE
OD (in)
7 5/8
ID (in)
6.88
Top (ftKB)
34.4
Set Depth (ftKB)
14,038.6
Set Depth (TVD) …
5,947.9
Wt/Len (l…
29.70
Grade
L-80
Top Thread
HYD563
Casing Description
LINER
OD (in)
4.55
ID (in)
3.91
Top (ftKB)
13,795.8
Set Depth (ftKB)
20,274.0
Set Depth (TVD) …
5,992.5
Wt/Len (l…
12.60
Grade
L-80
Top Thread
HYD 563
Liner Details
Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com
Nominal ID
(in)
13,795.8 5,892.8 74.66 PACKER 5" X 7" Baker " HRDE" ZXP Liner top packer w/11.31'
Tie-back
4.810
13,815.5 5,897.9 75.00 NIPPLE 5 1/2" RS Packoff seal Nipple - 5 1/2" HYD 563 box
by box
4.250
13,817.8 5,898.5 75.04 HANGER Flex Lock DG liner hanger - 5.50" X 7.625" Q125 - 5
1/2" 17# Hyd 563 pin x pin - H294-24-0002
4.800
13,827.1 5,900.9 75.20 XO REDUCING Crossover 5-1/2" H 563 X 5" H 5614.400
13,838.5 5,903.8 75.39 SBE 80-40- seal bore extension - 5" hyd 521 pin X 4.5"
Hyd 521 box - H024747203
4.000
14,114.5 5,959.4 82.30 FRAC SLEEVE Baker Frac Sleeve #11 W/ 2.595" Ball OD (Seat ID =
2.555")
2.555
14,213.4 5,970.1 85.32 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "N" 3.910
14,396.3 5,975.4 90.24 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "M" 3.910
14,666.2 5,975.2 90.08 FRAC SLEEVE Baker Frac Sleeve #10 W/ 2.545" Ball OD (Seat ID =
2.545")
2.545
14,764.9 5,975.4 89.90 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "L" 3.910
15,032.5 5,977.3 88.18 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "K" 3.910
15,301.8 5,986.7 88.34 FRAC SLEEVE Baker Frac Sleeve #9 W/ 2.495" Ball OD (Seat ID =
2.465")
2.465
15,523.2 5,989.8 90.03 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "J" 3.910
15,754.6 5,987.6 90.63 FRAC SLEEVE Baker Frac Sleeve #8 W/ 2.455" Ball OD (Seat ID =
2.425")
2.425
15,977.8 5,986.9 89.45 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "I" 3.910
16,209.2 5,989.7 90.03 FRAC SLEEVE Baker Frac Sleeve #7 W/ 2.415" Ball OD (Seat ID =
2.385")
2.385
16,391.3 5,988.7 90.23 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "H" 3.910
16,621.3 5,987.8 91.04 FRAC SLEEVE Baker Frac Sleeve #6 W/ 2.375" Ball OD (Seat ID =
2.345")
2.345
16,885.4 5,985.3 90.08 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "G" 3.910
17,319.0 5,982.2 90.25 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "F" 3.910
17,592.5 5,981.5 90.83 FRAC SLEEVE Baker Frac Sleeve #5 W/ 2.335" Ball OD (Seat ID =
2.305")
2.305
17,816.5 5,979.9 89.27 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "E" 3.910
18,048.1 5,979.2 90.70 FRAC SLEEVE Baker Frac Sleeve #4 W/ 2.295" Ball OD (Seat ID =
2.265")
2.265
18,270.6 5,977.1 90.43 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "D" 3.910
18,541.7 5,976.2 90.08 FRAC SLEEVE Baker Frac Sleeve #3 W/ 2.255" Ball OD (Seat ID =
2.225")
2.225
18,757.8 5,976.5 90.09 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "C" 3.910
19,019.7 5,977.2 89.77 FRAC SLEEVE Baker Frac Sleeve #2 W/ 2.215" Ball OD (Seat ID =
2.185")
2.185
19,239.3 5,977.7 89.83 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "B" 3.910
19,507.7 5,981.3 89.10 FRAC SLEEVE Baker Frac Sleeve #1 W/ 2.175" Ball OD (Seat ID =
2.145")
2.145
19,731.5 5,986.0 89.58 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "A" 3.910
20,246.0 5,992.4 89.66 BAFFLE Alpha Pressure Sleeve W/#16 Rupture disk - Hyd 563 3.000
20,255.5 5,992.5 89.81 FRAC SLEEVE 4.5" Baker WIV 12.6# P110 - Ball OD 1.25"-1.75" - 2
pins @ 990 PSI
1.125
Tubing Strings
Tubing Description
3 1/2" COMPLETION
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
33.5
Set Depth (ft…
13,851.9
Set Depth (TVD) (…
5,907.2
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
33.5 33.5 0.00 HANGER Cameron 4-1/2" Tubing Hanger, H563 3.900
158.7 158.7 0.35 XO REDUCING XO, 2', 4-1/2" 12.6# L-80 H563 box x 3-1/2" 9.3# EUE 2.990
HORIZONTAL, 3H-37, 11/30/2020 5:50:48 PM
Vertical schematic (actual)
LINER; 13,795.8-20,274.0
Mini frac; 19,743.2
Stage-Hyd Frac-Open Hole;
19,250.9
Stage-Hyd Frac-Open Hole;
18,769.4
Stage-Hyd Frac-Open Hole;
18,282.3
Stage-Hyd Frac-Open Hole;
18,048.0
Stage-Hyd Frac-Open Hole;
18,048.0
Stage-Hyd Frac-Open Hole;
17,593.0
Stage-Hyd Frac-Open Hole;
17,593.0
Stage-Hyd Frac-Open Hole;
16,621.0
Stage-Hyd Frac-Open Hole;
16,621.0
Stage-Hyd Frac-Open Hole;
16,209.0
Stage-Hyd Frac-Open Hole;
16,209.0
Stage-Hyd Frac-Open Hole;
15,755.0
Stage-Hyd Frac-Open Hole;
15,302.0
Stage-Hyd Frac-Open Hole;
15,302.0
Stage-Hyd Frac-Open Hole;
14,666.0
Stage-Hyd Frac-Open Hole;
14,666.0
Stage-Hyd Frac-Open Hole;
14,115.0
Stage-Hyd Frac-Open Hole;
14,115.0
INTERMEDIATE; 34.4-14,038.6
PACKER; 13,684.4
GAUGE; 13,627.0
GAS LIFT; 12,719.5
GAS LIFT; 11,318.1
GAS LIFT; 9,213.4
GAS LIFT; 6,016.1
SURFACE; 37.5-3,620.5
GAS LIFT; 2,744.5
CONDUCTOR; 37.5-156.5
HANGER; 33.5
KUP PROD
KB-Grd (ft)
37.87
Rig Release Date
4/18/2020
3H-37
...
TD
Act Btm (ftKB)
20,296.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032082200
Wellbore Status
PROD
Max Angle & MD
Incl (°)
91.58
MD (ftKB)
17,670.13
WELLNAME WELLBORE3H-37
Annotation
LAST WO:
End DateH2S (ppm) DateComment
SSSV: None
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
1,997.2 1,949.8 28.59 NIPPLE NIPPLE,LANDING,3 1/2", X, 2.81" min ID, 2.81 packing bore
S/N=4277509-04
2.813
13,627.0 5,846.6 73.99 GAUGE Halliburton Gauge Mandrel, EUE S/N = 19-575 2.957
13,684.4 5,862.4 74.04 PACKER Baker Premier Production Packer 3.5"x7.63" 2.890
13,742.7 5,878.4 74.09 NIPPLE NIPPLE,LANDING,3 1/2",XN, 2.813", min ID 2.75", EUE BXP w/
dual flapper valve installed S/N=C2763026
2.750
13,792.5 5,891.9 74.61 SUB Baker Fluted NO GO sub 2.990
13,849.7 5,906.6 75.58 MULE SHOE Baker Indexing Mule shoe - Material # H444-08-005 2.980
Frac Summary
Start Date
10/16/2020
Proppant Designed (lb)
100,000.0
Proppant In Formation (lb)
100,277.0
Stg #
1
Start Date
10/16/2020
Top Depth (ftKB)
19,743.2
Btm (ftKB)
19,743.2
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
2,519.00
Vol Slurry (bbl)
2,625.00
Start Date
10/16/2020
Proppant Designed (lb)
100,000.0
Proppant In Formation (lb)
100,745.0
Stg #
2
Start Date
10/16/2020
Top Depth (ftKB)
19,250.9
Btm (ftKB)
19,731.5
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
1,720.00
Vol Slurry (bbl)
1,826.00
Start Date
10/16/2020
Proppant Designed (lb)
100,000.0
Proppant In Formation (lb)
102,792.0
Stg #
3
Start Date
10/16/2020
Top Depth (ftKB)
18,769.4
Btm (ftKB)
19,239.3
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
1,676.00
Vol Slurry (bbl)
1,785.00
Start Date
10/16/2020
Proppant Designed (lb)
100,000.0
Proppant In Formation (lb)
101,748.0
Stg #
4
Start Date
10/16/2020
Top Depth (ftKB)
18,282.3
Btm (ftKB)
18,757.8
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
1,253.00
Vol Slurry (bbl)
1,361.00
Start Date
10/18/2020
Proppant Designed (lb)
100,000.0
Proppant In Formation (lb)
62,405.0
Stg #
5
Start Date
10/18/2020
Top Depth (ftKB)
18,048.0
Btm (ftKB)
18,051.0
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
1,098.00
Vol Slurry (bbl)
1,181.00
Start Date
10/23/2020
Proppant Designed (lb)
80,000.0
Proppant In Formation (lb)
53,432.0
Stg #
6
Start Date
10/23/2020
Top Depth (ftKB)
17,593.0
Btm (ftKB)
17,596.0
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
1,453.00
Vol Slurry (bbl)
1,510.00
Start Date
10/23/2020
Proppant Designed (lb)
100,000.0
Proppant In Formation (lb)
100,679.0
Stg #
7
Start Date
10/23/2020
Top Depth (ftKB)
16,621.0
Btm (ftKB)
16,624.0
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
1,678.00
Vol Slurry (bbl)
1,784.00
Start Date
10/23/2020
Proppant Designed (lb)
100,000.0
Proppant In Formation (lb)
100,173.0
Stg #
8
Start Date
10/23/2020
Top Depth (ftKB)
16,209.0
Btm (ftKB)
16,212.0
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
1,215.00
Vol Slurry (bbl)
1,321.00
Start Date
10/23/2020
Proppant Designed (lb)
100,000.0
Proppant In Formation (lb)
97,742.0
Stg #
9
Start Date
10/23/2020
Top Depth (ftKB)
15,755.0
Btm (ftKB)
15,758.0
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
1,340.00
Vol Slurry (bbl)
1,443.00
Start Date
10/24/2020
Proppant Designed (lb)
100,000.0
Proppant In Formation (lb)
101,312.0
Stg #
10
Start Date
10/24/2020
Top Depth (ftKB)
15,302.0
Btm (ftKB)
15,305.0
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
1,439.00
Vol Slurry (bbl)
1,546.00
Start Date
10/24/2020
Proppant Designed (lb)
100,000.0
Proppant In Formation (lb)
102,621.0
Stg #
11
Start Date
10/24/2020
Top Depth (ftKB)
14,666.0
Btm (ftKB)
14,669.0
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
1,197.00
Vol Slurry (bbl)
1,305.00
Start Date
10/24/2020
Proppant Designed (lb)
100,000.0
Proppant In Formation (lb)
85,379.0
Stg #
12
Start Date
10/24/2020
Top Depth (ftKB)
14,115.0
Btm (ftKB)
14,118.0
Link to Fluid System
Crosslink, 30# Hybor G
Vol Clean (bbl)
1,269.00
Vol Slurry (bbl)
1,359.00
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 2,744.5 2,510.0 Camco KBMG 1 GAS LIFT GLV BK 0.156 1,308.0 10/28/2020
2 6,016.1 3,698.1 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,322.0 10/29/2020
3 9,213.4 4,603.3 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 10/28/2020
4 11,318.1 5,200.7 Camco KBMG 1 GAS LIFT DMY BK 4/17/2020
5 12,719.5 5,596.0 Camco KBMG 1 GAS LIFT DMY BK 4/17/2020
Notes: General & Safety
End Date Annotation
NOTE:
HORIZONTAL, 3H-37, 11/30/2020 5:50:49 PM
Vertical schematic (actual)
LINER; 13,795.8-20,274.0
Mini frac; 19,743.2
Stage-Hyd Frac-Open Hole;
19,250.9
Stage-Hyd Frac-Open Hole;
18,769.4
Stage-Hyd Frac-Open Hole;
18,282.3
Stage-Hyd Frac-Open Hole;
18,048.0
Stage-Hyd Frac-Open Hole;
18,048.0
Stage-Hyd Frac-Open Hole;
17,593.0
Stage-Hyd Frac-Open Hole;
17,593.0
Stage-Hyd Frac-Open Hole;
16,621.0
Stage-Hyd Frac-Open Hole;
16,621.0
Stage-Hyd Frac-Open Hole;
16,209.0
Stage-Hyd Frac-Open Hole;
16,209.0
Stage-Hyd Frac-Open Hole;
15,755.0
Stage-Hyd Frac-Open Hole;
15,302.0
Stage-Hyd Frac-Open Hole;
15,302.0
Stage-Hyd Frac-Open Hole;
14,666.0
Stage-Hyd Frac-Open Hole;
14,666.0
Stage-Hyd Frac-Open Hole;
14,115.0
Stage-Hyd Frac-Open Hole;
14,115.0
INTERMEDIATE; 34.4-14,038.6
PACKER; 13,684.4
GAUGE; 13,627.0
GAS LIFT; 12,719.5
GAS LIFT; 11,318.1
GAS LIFT; 9,213.4
GAS LIFT; 6,016.1
SURFACE; 37.5-3,620.5
GAS LIFT; 2,744.5
CONDUCTOR; 37.5-156.5
HANGER; 33.5
KUP PROD 3H-37
...
WELLNAME WELLBORE3H-37
Hydraulic Fracturing Fluid Product Component Information DisclosureHydraulic Fracturing Fluid Composition:Job Start Date:10/16/2020Job End Date:10/24/2020State:AlaskaCounty:Harrison BayAPI Number:50-103-20822-00-00Operator Name:ConocoPhillips Company/Burlington ResourcesWell Name and Number:3H-37Latitude:70.41175000Longitude:-150.01408300Datum:NAD83Federal Well:NOIndian Well:NOTrue Vertical Depth:5,992Total Base Water Volume (gal):745,848Total Base Non Water Volume:0Trade NameSupplierPurposeIngredientsChemicalAbstractServiceNumber(CAS #)MaximumIngredientConcentrationin Additive (% by mass)**MaximumIngredientConcentrationin HF Fluid (% by mass)**CommentsSea WaterOperatorBase FluidWater7732-18-596.0000080.52780Density = 8.480IngredientsListed AboveListed AboveWater7732-18-5100.000000.10796
OPTIFLO-IIDELAYEDRELEASEBREAKERHalliburtonBreakerListed BelowSP BREAKERHalliburtonBreakerListed BelowWanli 20/40Wanli Proppant CompanyProppantListed BelowMO-67HalliburtonpH Control AdditiveListed BelowLOSURF-300DHalliburtonNon-ionicSurfactantListed BelowLVT 200PencroFreeze ProtectListed BelowWG-36 GELLING AGENTHalliburtonGelling AgentListed BelowCL-31CROSSLINKERHalliburtonCrosslinkerListed BelowCL-22 UCHalliburtonCrosslinker
Listed BelowOPTIFLO-IIIDELAYEDRELEASEBREAKERHalliburtonBreakerListed BelowCorundum1302-74-565.000009.69924Mullite1302-93-845.000006.71486Sodium chloride7647-14-54.000003.35687Hydrotreated Distillate, light64742-47-8100.000000.61496Guar gum9000-30-0100.000000.27524Potassium formate590-29-460.000000.06826Borate saltsProprietary60.000000.06826Ethanol64-17-560.000000.04608Potassium metaborate13709-94-960.000000.03299Oxylated phenolic resinProprietary30.000000.03072Heavy aromatic petroleum naphtha64742-94-530.000000.02304Ammonium persulfate7727-54-0100.000000.01816Sodium hydroxide1310-73-230.000000.01225Cured acrylic resinProprietary30.000000.00545Crystalline silica, quartz14808-60-730.000000.00525Naphthalene91-20-35.000000.00384Poly(oxy-1,2-ethanediyl),alpha-(4-nonylphenyl)-omega-hydroxy-,branched127087-87-05.000000.00384Potassium hydroxide1310-58-35.000000.00275Sodium carboxymethyl cellulose9004-32-41.000000.00114Items above are Trade Names with the exception of Base Water . Items below are the individual ingredients.
* Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100%*** If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green lineNote: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS)Acrylate polymerProprietary1.000000.00114Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871-6226Sodium glycollate2836-32-01.000000.001141,2,4 Trimethylbenzene95-63-61.000000.00077Sodium persulfate7775-27-1100.000000.00023Sodium sulfate7757-82-60.100000.00000
Sales Order#
Prepared By:
Keegan Lambe
Chad Burkett
Nanook Crew
0906757288
Intervals 1-12
Notice: Although the information contained in this report is based on sound engineering practices, the
copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any
loss or damage arising from the possession or use of the report whether in terms of correctness or
otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user’s
own risk.
3H-37
Conoco Phillips
County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20822
Prepared for: Scott Pessetto
October 24, 2020
Kuparuk A-Sand Formation
30# HyborG
Table of Contents
Section Page(s)
Executive Summary
Wellbore Information
Actual Design
Interval Summary
Fluid System-Proppant Summary
Interval 1 Plots
Interval 2 Plots
Interval 3 Plots
Interval 4 Plots
Interval 5 Plots
Interval 6 Plots
Interval 7 Plots
Interval 8 Plots
Interval 9 Plots
Interval 10 Plots
Interval 11 Plots
Interval 12 Plots
Appendix
Well Summary
Chemical Summary
Planned Design
Water Straps Day 1
Water Straps Day 2
Water Straps Day 3
Water Straps Day 4
Water Analysis Interval 01-04
Water Analysis Intervals 05-05
Water Analysis Intervals 06-09
Water Analysis Intervals 10-12
Real-Time QC
Fann 15 Zone 1
Prejob Break Test Day 1
Prejob Break Test Day 2
Prejob Break Test Day 3
Prejob Break Test Day 4
Fann Test Interval 1
Fann Test Interval 2
Fann Test Interval 3
Fann Test Interval 4
Fann Test Interval 5
Fann Test Interval 6
Fann Test Interval 7
Fann Test Interval 8
Fann Test Interval 9
Fann Test Interval 10
Fann Test Interval 11
Fann Test Interval 12
Event Log Day 1
Event Log Day 2
Event Log Day 3
Event Log Day 4
121
123
116
117
118
119
120
111
112
113
114
115
106
107
108
109
110
101
102
103
104
105
96
97
98
99
100
90
91 - 92
93
94
95
89
69 - 72
73 - 79
80 - 83
84 - 87
88
43 - 46
47 - 53
54 - 60
61 - 64
65 - 68
8 - 22
23
24 - 34
35 - 38
39 - 42
3
4
5 - 7
Conoco Phillips - 3H-37 TOC 2
710,750 gallons of 30# Hybor G
28,705 gallons of 30# Waterfrac G
4,620 gallons of Freeze Protect
1,200,000 pounds of 20/40 Wanli
720,029 gallons of 30# Hybor G
25,819 gallons of 30# Waterfrac G
5,306 gallons of Freeze Protect
1,200,000 pounds of 20/40 Wanli
Thank you,
Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may
have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions
provider for future projects.
Engineering Executive Summary
On October 16, 2020 a stimulation treatment was performed in the Kuparuk A-Sand formation on the 3H-37 well in County,
AK. The 3H-37 was a 12 stage Horizontal Sleeve Design. The proposed treatment consisted of:
The actual treatment fully completed 9 of 12 stages. 0 stages were skipped, 1 stage screened out and 2 stages were cut short of
design. The actual treatment consisted of:
A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided
to summarize events and changes to the proposed treatment:
Interval 05 was screened out during the 5ppg stage.
After the screen out occurred in interval 05, the design was altered. Pad size for the remaining stages was increased and the
designs for intervals 6-7 were changed. Intervals 07 and 12 were cut short from design due to downhole pressure trends.
Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid
volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are
performed before each job in order to optimize the performance of the treatment fluids.
After the pad volumes were increased the breaker setpoint was reduced. This was due to total available chemical on the slope
being less than the needed amount to finish the job at the designed setpoints. Additional lab testing was completed with the
reduced setpoints.
Keegan Lambe
-
Halliburton Energy Services
Conoco Phillips - 3H-37 Executive Summary 3
Conoco PhillipsKuparuk A-Sand3H-3750-103-20822*Exceeds 80% of burst pressure*Description OD (in) ID (in) Wt (#) GradeFUF (gal/ft)MD Top (ft)MD Btm (ft) Volume (gal)Tubular Burst Pressure (psi)Tubing3.5 2.992 9.3 L-80 0.3652 0 13,845 5,056 10,160Tubing4.5 3.958 12.6 L-80 0.6392 13,845 20,274 4,109 8,430Total20,2749,166ft1.60ft155.9ftTop MD (ft)Btm MD (ft)Average TVD (ft)Interval #Formation DescriptorAverage Interval Temperature (F)Ball Drop Time (HH:MM)Ball Hit Time (HH:MM)JSV Drop (bbl)JSV Slow Down (bbl)JSV Hit (bbl)Early (bbl)Surface Seat Pressure (psi)Surface Peak Pressure (psi)Surface Differential (psi)BH Seat Pressure (psi)BH Peak Pressure (psi)BH Differential (psi)Rate at Shift (bpm)Toe20,246 20,249 5,9921Kuparuk Sands155.9NA NA NA NA NANANA NA NA NA NA NA NA19,508 19,511 5,9812Kuparuk Sands155.712:40:00 PM 12:51:00 PM 2,600 2,777 2,8051.64,113 7,224 3,111 5,481 8,378 2,897 14.819,020 19,023 5,9773Kuparuk Sands155.61:54:00 PM 2:04:00 PM 4,435 4,604 4,6295.13,479 6,762 3,283 5,146 7,618 2,472 12.918,542 18,545 5,9764Kuparuk Sands155.63:02:00 PM 3:10:00 PM 6,237 6,399 6,4262.93,747 7,087 3,340 4,877 7,478 2,601 15.118,048 18,051 5,9795Kuparuk Sands155.710:14:00 AM 10:22:00 AM 75 229 2554.93,707 7,007 3,300 4,766 7,373 2,607 14.717,593 17,596 5,9816Kuparuk Sands155.78:53:00 AM 9:02:00 AM 98 245 2723.73,843 7,370 3,527 5,315 7,729 2,414 14.616,621 16,624 5,9887Kuparuk Sands155.89:56:00 AM 10:03:00 AM 1,510 1,643 1,6720.63,653 7,419 3,766 5,096 7,435 2,339 14.916,209 16,212 5,9908Kuparuk Sands155.811:14:00 AM 11:21:00 AM 3,293 3,419 3,4490.43,361 7,057 3,696 5,026 7,523 2,497 14.715,755 15,758 5,9889Kuparuk Sands155.812:14:00 PM 12:20:00 PM 4,615 4,734 4,7640.53,124 6,779 3,655 4,526 7,390 2,864 14.915,302 15,305 5,98710Kuparuk Sands155.89:27:00 AM 9:41:00 AM 35 148 1707.83,283 6,746 3,463 4,367 6,905 2,538 14.814,666 14,669 5,97511Kuparuk Sands155.610:39:00 AM 10:45:00 AM 1,542 1,645 1,6722.93,175 4,729 1,554 4,376 5,081 705 15.5Heel14,115 14,118 5,95912Kuparuk Sands155.311:34:00 AM 11:40:00 AM 2,848 2,942 2,9702.53,411 7,481 4,070 4,752 6,964 2,212 15.0KOPAvg. TVDTotal MD78910112345612Sleeve/Perf DepthSleevesInterval #1Max Pressure (psi)9,000Isolation TypeSwell PackersTreatment TubularsCustomerFormationLeaseAPIDateTemperature DataTemp. Gradient (°F/100 ft)BHST (°F)Directional Data5,9811,99220,27410/16/20208,364199.18,0597,7437,452Displacement to Top Sleeve/Perf (gal)(BBLS)9,148217.88,676206.6191.9184.4177.45,2296,8316,5676,2775,9885,581162.6156.4149.5142.6132.9124.5Conoco Phillips - 3H-37 Wellbore Information4
CUSTOMERConoco PhillipsAPIBFD (lb/gal)8.48LAT 70.41205042LEASE3H-37SALES ORDERBHST (°F)156LONG-150.0109514FORMATIONKuparuk A-SandDATE Max Pressure (psi)9000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated SlurryDesign Prop Calculated Prop LoSurf-300D CL-31 CL-22 UC MO-67 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SPTreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalSurfactant Crosslinker Crosslinker Buffer Freeze Protect Gel Biocide Breaker BreakerBreakerInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In-1-2 Freeze Protect Freeze Protect 2.0 2,100 1,260 30 301000.001-3 Shut-In Shut-In-1-4 30# Hybor G Establish Stable Fluid 15.0 4,200 10,832 258 258 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-5 30# Hybor G Minifrac 30.0 12,600 12,769 304 304 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-6 30# Waterfrac G Flush 30.0 9,156 9,224 220 220 1.00 30.00 0.15 2.00 0.251-7 Shut-In Shut-In-1-8 30# Hybor G Establish Stable Fluid 30.0 4,200 2,903 69 69 1.00 0.501.00 0.40 30.00 0.15 2.00 0.251-9 30# Hybor G Pad 30.0 25,000 24,972 595 595 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-10 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 30.0 13,200 13,169 314 328 13,200 13,700 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-11 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 30.0 12,000 12,001 286 313 24,000 25,500 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-12 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 30.0 12,000 12,003 286 327 36,000 38,506 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-13 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 30.0 6,700 6,269 149 173 26,800 22,571 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-14 30# Hybor G Spacer and Ball Drop 15.0 1,000 1,639 39 39 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-1 30# Hybor G Pad 30.0 25,000 25,010 595 595 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 30.0 13,200 13,206 314 325 10,052 10,052 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 30.0 12,000 12,023 286 312 24,000 24,241 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 30.0 12,000 12,022 286 324 36,000 35,776 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 30.0 6,700 8,724208 240 29,948 30,676 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-6 30# Hybor G Spacer and Ball Drop 15.0 1,000 1,244 30 30 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.253-1 30# Hybor G Pad 30.0 25,000 25,000 595 595 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.253-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 30.0 13,200 13,204 314 329 13,200 13,925 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.253-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 30.0 12,000 12,016 286 313 24,000 25,399 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.253-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 30.0 12,000 12,000 286 325 36,000 37,207 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.253-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 30.0 6,700 7,389176 204 26,800 26,261 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.253-6 30# Hybor G Spacer and Ball Drop 15.0 1,000 776 18 18 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.254-1 30# Hybor G Pad 30.0 15,000 15,014 357 357 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.254-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 30.0 3,200 3,20476 79 3,200 3,016 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.254-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 30.0 3,300 3,32479 86 6,600 6,525 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.254-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 30.0 5,000 5,010119 135 15,000 14,793 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.254-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 30.0 5,500 5,504131 154 22,000 21,410 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.254-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 30.0 5,000 5,000119 145 25,000 24,100 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.250.254-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 30.0 4,700 6,726160 194 28,200 31,904 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.250.254-8 30# Waterfrac G Flush 30.0 8,064 7,134 170 170 1.00 30.00 0.15 2.00 0.250.504-9 Freeze Protect Freeze Protect 15.0 840 1,710 41 411000.005-1 Shut-In Shut-In-5-2 30# Hybor G Establish Stable Fluid 30.0 4,200 2,655 63 63 1.00 0.501.00 0.40 30.00 0.15 2.00 0.255-3 30# Hybor G Spacer and Ball Drop 15.0 1,000 689 16 16 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-4 30# Hybor G Pad 30.0 15,000 15,320 365 365 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 30.0 3,200 3,21176 80 3,200 3,259 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 30.0 3,300 3,29879 85 6,600 6,539 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 30.0 5,000 4,999119 135 15,000 14,907 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-8 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 30.0 5,500 5,510131 155 22,000 22,133 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-9 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 30.0 5,000 7,699183 217 25,000 31,371 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-10 30# Hybor G Spacer and Ball Drop 15.0 1,000 561 13 13 1.00 0.50 1.000.40 30.00 0.15 2.00 0.255-11 30# Hybor G Flush 30.0 1,000 2,175 52 52 1.00 0.50 1.00 0.40 30.00 0.152.00 0.25Interval 1Kuparuk Sands@ 20246 - 20249 ft 155.9 °FInterval 2Kuparuk Sands@ 19508 - 19511 ft 155.7 °FInterval 3Kuparuk Sands@ 19020 - 19023 ft 155.6 °FInterval 4Kuparuk Sands@ 18542 - 18545 ft 155.6 °FInterval 5Kuparuk Sands@ 18048 - 18051 ft 155.7 °FLiquid AdditivesDry Additives50-103-208220906757288Conoco Phillips - 3H-37Actual Design5
CUSTOMERConoco PhillipsAPIBFD (lb/gal)8.48LAT 70.41205042LEASE3H-37SALES ORDERBHST (°F)156LONG-150.0109514FORMATIONKuparuk A-SandDATE Max Pressure (psi)9000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated SlurryDesign Prop Calculated Prop LoSurf-300D CL-31 CL-22 UC MO-67 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SPTreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalSurfactant Crosslinker Crosslinker Buffer Freeze Protect Gel Biocide Breaker BreakerBreakerInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-2082209067572886-1 Shut-In Shut-In-6-2 30# Hybor G Establish Stable Fluid 15.0 4,200 2,957 70 70 1.00 0.501.00 0.40 30.00 0.15 1.50 0.256-3 30# Hybor G Spacer and Ball Drop 15.0 1,000 1,218 29 29 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.256-4 30# Hybor G Pad 23.0 25,000 25,003 595 595 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.256-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23.0 13,200 13,197 314 327 13,200 12,455 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.256-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23.0 8,000 7,998190 207 16,000 16,047 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.256-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23.0 8,000 8,492202 229 24,000 24,930 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.25- 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.256-8 30# Hybor G Spacer and Ball Drop 15.0 1,000 2,181 52 52 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.257-1 30# Hybor G Pad 23.0 25,000 25,011 596 596 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.257-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23.0 13,200 13,215 315 328 13,200 12,577 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.257-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23.0 12,000 12,007 286 312 24,000 24,275 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.257-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23.0 12,000 12,007 286 326 36,000 37,647 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.257-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 23.0 6,700 7,453177 205 26,800 26,180 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.257-6 30# Hybor G Spacer and Ball Drop 15.0 1,000 770 18 18 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-1 30# Hybor G Pad 23.0 22,350 22,357 532 532 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23.0 3,200 3,21276 80 3,200 3,158 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23.0 3,300 3,30179 85 6,600 6,497 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23.0 5,000 5,005119 135 15,000 14,925 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 23.0 5,500 5,499131 154 22,000 21,729 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 23.0 5,000 5,007119 145 25,000 24,179 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 23.0 4,700 5,981142 174 28,200 29,685 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-8 30# Hybor G Spacer and Ball Drop 15.0 1,000 650 15 15 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.259-1 30# Hybor G Pad 23.0 22,350 22,383 533 533 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.259-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23.0 3,200 3,21076 80 3,200 3,133 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.259-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23.0 3,300 3,30679 86 6,600 6,788 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.259-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23.0 5,000 5,163123 140 15,000 15,804 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.259-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 23.0 5,500 5,507131 154 22,000 21,986 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.259-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 23.0 5,000 5,008119 146 25,000 25,048 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.250.259-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 23.0 4,700 5,126122 149 28,200 24,983 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.250.259-8 30# Waterfrac G Flush 23.0 5,227 5,277 126 126 1.00 30.00 0.15 1.50 0.250.509-9 Freeze Protect Freeze Protect 15.0 1,050 1,281 31 311000.00Interval 6Kuparuk Sands@ 17593 - 17596 ft 155.7 °FInterval 7Kuparuk Sands@ 16621 - 16624 ft 155.8 °FInterval 8Kuparuk Sands@ 16209 - 16212 ft 155.8 °FInterval 9Kuparuk Sands@ 15755 - 15758 ft 155.8 °FConoco Phillips - 3H-37Actual Design6
CUSTOMERConoco PhillipsAPIBFD (lb/gal)8.48LAT 70.41205042LEASE3H-37SALES ORDERBHST (°F)156LONG-150.0109514FORMATIONKuparuk A-SandDATE Max Pressure (psi)9000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated SlurryDesign Prop Calculated Prop LoSurf-300D CL-31 CL-22 UC MO-67 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SPTreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalSurfactant Crosslinker Crosslinker Buffer Freeze Protect Gel Biocide Breaker BreakerBreakerInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-20822090675728810-1 Shut-In Shut-In-10-2 30# Hybor G Spacer and Ball Drop 15.0 1,000 1,573 37 37 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-3 30# Hybor G Establish Stable Fluid 15.0 4,200 3,939 94 94 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-4 30# Hybor G Pad 24.0 26,550 26,562 632 632 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 24.0 3,200 3,210 76 80 3,200 3,228 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 24.0 3,300 3,314 79 86 6,600 6,699 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 24.0 5,000 4,998 119 135 15,000 15,363 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-8 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 24.0 5,500 5,500 131 155 22,000 22,775 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-9 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 24.0 5,000 4,995 119 146 25,000 25,823 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-10 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 24.0 4,700 5,514 131 160 28,200 27,424 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-11 30# Hybor G Spacer and Ball Drop 15.0 1,000 828 20 20 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-1 30# Hybor G Pad 24.0 22,350 21,942 522 522 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 24.0 3,200 3,200 76 80 3,200 3,789 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 24.0 3,300 3,311 79 86 6,600 6,622 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 24.0 5,000 5,005 119 135 15,000 15,126 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 24.0 5,500 5,505 131 155 22,000 22,856 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 24.0 5,000 5,005 119 147 25,000 26,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 24.0 4,700 5,485 131 161 28,200 28,228 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-8 30# Hybor G Spacer and Ball Drop 15.0 1,000 802 19 19 1.00 0.50 1.000.40 30.00 0.15 1.50 0.2512-1 30# Hybor G Pad 23.0 22,350 22,346 532 532 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2512-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23.0 3,200 3,193 76 79 3,200 2,930 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2512-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23.0 3,300 3,274 78 85 6,600 6,719 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2512-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23.0 5,000 5,004 119 134 15,000 13,869 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2512-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 23.0 5,500 5,502 131 156 22,000 23,667 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2512-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 23.0 5,000 8,728 208 248 25,000 38,194 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.250.2530# Hybor G- 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.250.2512-7 30# Waterfrac G Flush 23.0 5,208 4,184 100 100 1.00 30.00 0.15 1.50 0.250.5012-8 Freeze Protect Freeze Protect 15.0 1,050 1,055 25 251000.00732,545 751,154 17,885 19,077 1,096,800 1,125,109Design Total (gal)Actual Total (gal)Design Total (lbs)Calculated Total (lbs)Ticket Total (lbs)LoSurf-300D CL-31 CL-22 UC MO-67 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP1,180,000 1,125,109 1,200,000(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)(lbs)710,750 720,029 - - - Initial Design Material Volume 739.5 355.4 710.8 284.3 4,620.0 22,183.7 110.9 1,277.9 184.917.028,705 25,819 - - - Actual Design Material Volume 745.8 360.0 720.0 288.0 5,306.0 22,375.4 111.9 1,291.5 186.515.94,620 5,306 - - - Physical Material Volume Pumped 770 380 730 290 6720 20753 119 1,250 189.66 17- - - - - Physical Material Volume Deviance 3% 6% 1% 1% 27% -7% 6% -3% 2% 7%--** IFS numbers for proppant are taken from software calculations based on multiple variablesMicroMotion Volume Pumped 759 353 709 280 - 20,259 105 1,258 192 11--** Proppant is billed from Weight Ticket volumesMicroMotion Volume Deviance 2% -2% -2% -3% - -9% -6% -3% 3% -31%--Interval 10Kuparuk Sands@ 15302 - 15305 ft 155.8 °FInterval 11Kuparuk Sands@ 14666 - 14669 ft 155.6 °FInterval 12Kuparuk Sands@ 14115 - 14118 ft 155.3 °F----Fluid TypeSeawater30# Hybor G30# Waterfrac GFreeze Protect-Proppant Type20/40 Wanli---Conoco Phillips - 3H-37Actual Design7
10/16/20 10:12
10/16/20 12:51
159 min
6.3 bpm
6,414 psi
8,557 psi
28.4 bpm
7,150 psi
6,569 psi
24.7 bpm
6,119 psi
6,020 psi
5,515 psi
3,704 hhp
383 psi
893 psi
4.47 ppg
26.6 cP
73.7 F
9.48
100,277 lbs
100,277 lbs
100,277 lbs
0 gal 0 bbls
96,557 gal 2,299 bbls
9,224 gal 220 bbls
1,260 gal 30 bbls
24,972 gal 595 bbls
43,442 gal 1,034 bbls
1,639 gal 39 bbls
9,224 gal 220 bbls
1,260 gal 30 bbls
13,735 gal 327 bbls
12,769 gal 304 bbls
1,260 gal 30 bbls
Completed
Proppant in Formation:
Seawater Volume:
30# Hybor G Volume:
30# Waterfrac G Volume:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Flush Volume:
Max OA Pressure:
Average Visc:
Average Temp:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Interval Summary
3H-37 - Kuparuk A-Sand - Interval 1
Interval Summary
Start Date/Time:
End Date/Time:
Pump Time:
Initial OA Pressure:
Average Surface Pressure:
Max Proppant Concentration:
Average Rate:
Average Missile Pressure:
Average Missile HHP:
Initial BH Pressure (Breakdown):
Average BH Pressure:
Minifrac Volume:
Freeze Protect Volume:
Freeze Protect Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Establish Stable Fluid Volume:
20/40 Wanli Pumped:
Proppant Summary
Freeze Protect Volume:
Interval Status:
Average pH:
Total Proppant Pumped* :
Pad Volume:
Conoco Phillips - 3H-37 Interval Summary 8
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Dan Faur
Chad Burkett
Scott Pessetto
Paul Bessette
Keegan LambeThe well was opened at 10:12. Minifrac was pumped from 10:12 to 10:59 and pressure was
analyzed up to 11:29. Max rate during the minifrac was 28.57bpm, max downhole pressure was
5775psi and max surface pressure was 7095psi. Average rate was 18.85bpm, average surface
pressure was 4654psi, average downhole pressure was 5121psi. Average horsepower was
2154HHP. One pump kicked out during the stage and was reset. Stage was pumped per proppant
design.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Conoco Phillips - 3H-37 Interval Summary 9
10/16/20 12:51
10/16/20 14:03
72 min
14.8 bpm
7,224 psi
8,378 psi
28.9 bpm
6,834 psi
5,884 psi
25.2 bpm
6,013 psi
5,903 psi
5,255 psi
3,709 hhp
893 psi
907 psi
4.09 ppg
26.8 cP
76.8 F
9.36
100,745 lbs
100,745 lbs
100,745 lbs
72,229 gal 1,720 bbls
0 gal 0 bbls
0 gal 0 bbls
25,010 gal 595 bbls
45,975 gal 1,095 bbls
1,244 gal 30 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Keegan Lambe
Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
30# Hybor G Volume:
30# Waterfrac G Volume:
Freeze Protect Volume:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
20/40 Wanli Pumped:
Total Proppant Pumped* :
Proppant in Formation:
Average Missile HHP:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
Average Temp:
Average pH:
3H-37 - Kuparuk A-Sand - Interval 2
Interval Summary
Start Date/Time:
End Date/Time:
Pump Time:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Average Surface Pressure:
Average BH Pressure:
Interval Status:
Caught air during the 1ppg stage. Pumped 1ppg to fluid volume. All missed proppant was added to
the 4ppg stage. Had to shift rate around due to a pump being stuck in converter. Ball audio was
not heard. Ball hit for next stage. Dan Faur
Chad Burkett
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Scott Pessetto
Paul Bessette
Conoco Phillips - 3H-37 Interval Summary 10
10/16/20 14:03
10/16/20 15:10
67 min
12.9 bpm
6,762 psi
7,618 psi
29.6 bpm
6,643 psi
5,430 psi
27.1 bpm
6,152 psi
6,039 psi
5,095 psi
4,083 hhp
890 psi
933 psi
4.24 ppg
25 cP
77.5 F
9.44
102,792 lbs
102,792 lbs
102,792 lbs
0 gal 0 bbls
70,385 gal 1,676 bbls
0 gal 0 bbls
0 gal 0 bbls
25,000 gal 595 bbls
44,609 gal 1,062 bbls
776 gal 18 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Initial OA Pressure:
Max Proppant Concentration:
Average Temp:
Average pH:
Average BH Pressure:
Start Date/Time:
End Date/Time:
Average Missile HHP:
Max OA Pressure:
Spacer and Ball Drop Volume:
Interval Status:
Interval pumped to design.
Seawater Volume:
Fluid Summary (by stage description)
Total Proppant Pumped* :
Proppant in Formation:
Proppant Laden Fluid Volume:
30# Hybor G Volume:
Pad Volume:
3H-37 - Kuparuk A-Sand - Interval 3
Interval Summary
Pump Time:
Average Missile Pressure:
Average Surface Pressure:
Initial Rate (Breakdown):
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Average Visc:
Proppant Summary
20/40 Wanli Pumped:
Fluid Summary (by fluid description)
30# Waterfrac G Volume:
Freeze Protect Volume:
Keegan Lambe
Dan Faur
Chad Burkett
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Scott Pessetto
Paul Bessette
Conoco Phillips - 3H-37 Interval Summary 11
10/16/20 15:10
10/16/20 15:59
49 min
15.1 bpm
7,087 psi
7,478 psi
28.9 bpm
6,623 psi
5,510 psi
24.6 bpm
6,023 psi
5,916 psi
5,222 psi
3,633 hhp
916 psi
925 psi
5.86 ppg
27.7 cP
78.8 F
9.51
4524 psi
0.757 psi/ft
4394 psi
4330 psi
4283 psi
101,748 lbs
101,748 lbs
101,748 lbs
0 gal 0 bbls
43,782 gal 1,042 bbls
7,134 gal 170 bbls
1,710 gal 41 bbls
15,014 gal 357 bbls
28,768 gal 685 bbls
7,134 gal 170 bbls
1,710 gal 41 bbls
1,710 gal 41 bbls
Completed
Max Proppant Concentration:
Average Temp:
Average pH:
Fluid Summary (by fluid description)
Pad Volume:
Proppant Laden Fluid Volume:
Average Missile Pressure:
Max Surface Pressure:
Initial Surface Pressure (Breakdown):
Initial 15 min:
End Date/Time:
Initial Rate (Breakdown):
30# Hybor G Volume:
30# Waterfrac G Volume:
Average Surface Pressure:
Max Rate:
Freeze Protect Volume:
Max BH Pressure:
Average Rate:
ISIP:
Initial Fracture Gradient:
Freeze Protect Volume:
Average Missile HHP:
Average Visc:
Initial OA Pressure:
Max OA Pressure:
Proppant in Formation:
20/40 Wanli Pumped:
Total Proppant Pumped* :
Seawater Volume:
Initial BH Pressure (Breakdown):
Pump Time:
Average BH Pressure:
Start Date/Time:
3H-37 - Kuparuk A-Sand - Interval 4
Interval Summary
Initial 5 min:
Initial 10 min:
Proppant Summary
Fluid Summary (by stage description)
Freeze Protect Volume:
Flush Volume:
Interval Status:
Conoco Phillips - 3H-37 Interval Summary 12
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Dropped rate as pressure required to prevent kicking out trucks. Interval pumped to proppant
design. Freeze protected at 10bpm to complete flush. Pushed 25bbl of LVT into the well.
Keegan Lambe
Dan Faur
Chad Burkett
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Scott Pessetto
Paul Bessette
Conoco Phillips - 3H-37 Interval Summary 13
10/18/20 10:04
10/18/20 11:00
56 min
14.7 bpm
7,007 psi
7,373 psi
32.3 bpm
7,815 psi
9,718 psi
22.4 bpm
5,812 psi
5,728 psi
5,203 psi
3,185 hhp
340 psi
716 psi
5.35 ppg
NA cP
84.3 F
9.2
78,209 lbs
78,209 lbs
62,405 lbs
0 gal 0 bbls
46,117 gal 1,098 bbls
0 gal 0 bbls
0 gal 0 bbls
15,320 gal 365 bbls
24,717 gal 589 bbls
1,250 gal 30 bbls
2,175 gal 52 bbls
2,655 gal 63 bbls
Screened Out
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Max Proppant Concentration:
Proppant Laden Fluid Volume:
Interval Status:
Initial Surface Pressure (Breakdown):
Max BH Pressure:
Average Rate:
Spacer and Ball Drop Volume:
20/40 Wanli Pumped:
Seawater Volume:
Max Rate:
Average Visc:
Average BH Pressure:
Initial OA Pressure:
Max OA Pressure:
Average Surface Pressure:
Establish Stable Fluid Volume:
Wellhead opened at 10:04 at a pressure of 566psi. Ball seat was observed. Cut sand during 5ppg
due to a increase in downhole pressure. Screened out with 15,804lbs in the wellbore. Little Red
pumped LVT behind the wellbore to attempt to move fluid. After failing to establish injection coil
was called. Rigged down front yard in preparation for coil.
Interval Summary
Average pH:
3H-37 - Kuparuk A-Sand - Interval 5
Pump Time:
Initial BH Pressure (Breakdown):
Initial Rate (Breakdown):
Max Surface Pressure:
Average Missile Pressure:
Average Temp:
End Date/Time:
Start Date/Time:
Freeze Protect Volume:
Keegan Lambe
Dan Faur
Average Missile HHP:
30# Hybor G Volume:
30# Waterfrac G Volume:
Total Proppant Pumped* :
Proppant in Formation:
Chad Burkett
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Scott Pessetto
Paul Bessette
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Pad Volume:
Flush Volume:
Conoco Phillips - 3H-37 Interval Summary 14
10/23/20 8:45
10/23/20 10:03
78 min
14.6 bpm
7,370 psi
7,729 psi
27.5 bpm
5,835 psi
5,330 psi
21.6 bpm
4,578 psi
4,560 psi
4,852 psi
2,419 hhp
437 psi
743 psi
3.36 ppg
29.6 cP
83.7 F
9.3
53,432 lbs
53,432 lbs
53,432 lbs
0 gal 0 bbls
61,046 gal 1,453 bbls
0 gal 0 bbls
0 gal 0 bbls
25,003 gal 595 bbls
29,687 gal 707 bbls
3,399 gal 81 bbls
2,957 gal 70 bbls
Cut Short
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Average Missile Pressure:
Max Surface Pressure:
Max Rate:
Initial Rate (Breakdown):
Establish Stable Fluid Volume:
Proppant in Formation:
Average pH:
Start Date/Time:
End Date/Time:
Max BH Pressure:
Average Rate:
Proppant Laden Fluid Volume:
Total Proppant Pumped* :
Max OA Pressure:
Initial Surface Pressure (Breakdown):
Average BH Pressure:
Average Missile HHP:
Initial BH Pressure (Breakdown):
Spacer and Ball Drop Volume:
Max Proppant Concentration:
Average Visc:
Average Temp:
The well was opened at 08:45 to a wellhead pressure of 835psi. The ball for stage 6 was dropped.
Cut proppant due to the downhole pressure trend. Well was successfully flushed.
3H-37 - Kuparuk A-Sand - Interval 6
Interval Summary
Average Surface Pressure:
Initial OA Pressure:
Pump Time:
Keegan Lambe
Dan Faur
Chad Burkett
Interval Status:
Seawater Volume:
30# Hybor G Volume:
30# Waterfrac G Volume:
Freeze Protect Volume:
Proppant Summary
20/40 Wanli Pumped:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Pad Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Scott Pessetto
Paul Bessette
Conoco Phillips - 3H-37 Interval Summary 15
10/23/20 10:03
10/23/20 11:21
78 min
14.9 bpm
7,419 psi
7,435 psi
27.8 bpm
5,971 psi
5,040 psi
23.0 bpm
4,357 psi
4,331 psi
4,544 psi
2,451 hhp
744 psi
816 psi
4.02 ppg
29.4 cP
84.4 F
9.34
100,679 lbs
100,679 lbs
100,679 lbs
0 gal 0 bbls
70,463 gal 1,678 bbls
0 gal 0 bbls
0 gal 0 bbls
25,011 gal 596 bbls
44,682 gal 1,064 bbls
770 gal 18 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
30# Waterfrac G Volume:
Freeze Protect Volume:
30# Hybor G Volume:
Average pH:
20/40 Wanli Pumped:
Total Proppant Pumped* :
Proppant in Formation:
Max Rate:
Proppant Laden Fluid Volume:
Interval pumped to design.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Spacer and Ball Drop Volume:
Pad Volume:
Average Visc:
Proppant Summary
Fluid Summary (by fluid description)
Seawater Volume:
Fluid Summary (by stage description)
Average Temp:
Interval Summary
Initial Rate (Breakdown):
Max Proppant Concentration:
Initial BH Pressure (Breakdown):
Start Date/Time:
End Date/Time:
Average Surface Pressure:
Average BH Pressure:
Average Missile Pressure:
Max Surface Pressure:
Initial Surface Pressure (Breakdown):
3H-37 - Kuparuk A-Sand - Interval 7
Average Missile HHP:
Initial OA Pressure:
Max OA Pressure:
Max BH Pressure:
Average Rate:
Pump Time:
Interval Status:
Keegan Lambe
Dan Faur
Chad Burkett
Scott Pessetto
Paul Bessette
Conoco Phillips - 3H-37 Interval Summary 16
10/23/20 11:21
10/23/20 12:20
59 min
14.7 bpm
7,057 psi
7,523 psi
27.1 bpm
6,486 psi
4,881 psi
22.2 bpm
4,547 psi
4,520 psi
4,569 psi
2,469 hhp
812 psi
847 psi
6.06 ppg
27 cP
88.4 F
9.57
100,173 lbs
100,173 lbs
100,173 lbs
0 gal 0 bbls
51,012 gal 1,215 bbls
0 gal 0 bbls
0 gal 0 bbls
22,357 gal 532 bbls
28,005 gal 667 bbls
650 gal 15 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Volume:
Proppant Laden Fluid Volume:
30# Hybor G Volume:
Max BH Pressure:
Average Missile Pressure:
Freeze Protect Volume:
Average pH:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Average Temp:
Max Proppant Concentration:
Average Visc:
Average Rate:
Average Surface Pressure:
Start Date/Time:
End Date/Time:
Pump Time:
Max Rate:
Max Surface Pressure:
Proppant Summary
Fluid Summary (by stage description)
Total Proppant Pumped* :
Proppant in Formation:
Interval Summary
3H-37 - Kuparuk A-Sand - Interval 8
Initial OA Pressure:
Initial Rate (Breakdown):
Average BH Pressure:
Average Missile HHP:
20/40 Wanli Pumped:
Max OA Pressure:
Fluid Summary (by fluid description)
30# Waterfrac G Volume:
Keegan Lambe
Seawater Volume:
Spacer and Ball Drop Volume:
Interval pumped to design.
Dan Faur
Chad Burkett
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Scott Pessetto
Paul Bessette
Interval Status:
Conoco Phillips - 3H-37 Interval Summary 17
10/23/20 12:20
10/23/20 13:16
56 min
14.9 bpm
6,779 psi
7,390 psi
24.9 bpm
6,493 psi
4,611 psi
23.4 bpm
4,719 psi
4,691 psi
4,380 psi
2,710 hhp
828 psi
858 psi
6.10 ppg
28 cP
88.6 F
9.47
4273 psi
0.714 psi/ft
4148 psi
4102 psi
4060 psi
97,742 lbs
97,742 lbs
97,742 lbs
49,703 gal 1,183 bbls
5,277 gal 126 bbls
1,281 gal 31 bbls
22,383 gal 533 bbls
27,320 gal 650 bbls
0 gal 0 bbls
5,277 gal 126 bbls
1,281 gal 31 bbls
Completed
Max Proppant Concentration:
Final 5 min:
Final 10 min:
Average Missile HHP:
Max Surface Pressure:
Max BH Pressure:
Average Visc:
Spacer and Ball Drop Volume:
Average Temp:
Average pH:
3H-37 - Kuparuk A-Sand - Interval 9
Interval Summary
Start Date/Time:
End Date/Time:
Pump Time:
Average Surface Pressure:
Average BH Pressure:
Initial OA Pressure:
Max OA Pressure:
Average Rate:
Average Missile Pressure:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Max Rate:
Initial Rate (Breakdown):
Proppant Summary
Total Proppant Pumped* :
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Proppant in Formation:
Freeze Protect Volume:
30# Hybor G Volume:
20/40 Wanli Pumped:
30# Waterfrac G Volume:
Final Fracture Gradient:
Final 15 min:
ISDP:
Pad Volume:
Proppant Laden Fluid Volume:
Flush Volume:
Interval Status:
Freeze Protect Volume:
Conoco Phillips - 3H-37 Interval Summary 18
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval pumped to design. Keegan Lambe
Dan Faur
Chad Burkett
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Scott Pessetto
Paul Bessette
Conoco Phillips - 3H-37 Interval Summary 19
10/24/20 9:27
10/24/20 10:45
78 min
14.8 bpm
6,746 psi
6,905 psi
24.6 bpm
6,444 psi
4,514 psi
22.3 bpm
4,667 psi
4,611 psi
4,303 psi
2,545 hhp
506 psi
758 psi
6.24 ppg
29.5 cP
84.6 F
9.38
101,312 lbs
101,312 lbs
101,312 lbs
0 gal 0 bbls
60,433 gal 1,439 bbls
0 gal 0 bbls
0 gal 0 bbls
26,562 gal 632 bbls
27,531 gal 656 bbls
2,401 gal 57 bbls
0 gal 0 bbls
3,939 gal 94 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Average Visc:
Total Proppant Pumped* :
Proppant in Formation:
30# Hybor G Volume:
Pad Volume:
Establish Stable Fluid Volume:
Initial Rate (Breakdown):
Average Surface Pressure:
Spacer and Ball Drop Volume:
3H-37 - Kuparuk A-Sand - Interval 10
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Dan Faur
Chad Burkett
Keegan Lambe
Initial BH Pressure (Breakdown):
Freeze Protect Volume:
Proppant Laden Fluid Volume:
Average Rate:
Average Missile Pressure:
Initial OA Pressure:
20/40 Wanli Pumped:
Average BH Pressure:
Seawater Volume:
Scott Pessetto
Paul Bessette
Interval Status:
Wellhead was opened at 09:27 to 645psi. Interval pumped to design.
Interval Summary
Max Surface Pressure:
Max BH Pressure:
Max OA Pressure:
Max Proppant Concentration:
Proppant Summary
Fluid Summary (by fluid description)
30# Waterfrac G Volume:
Fluid Summary (by stage description)
Average Temp:
Average Missile HHP:
Average pH:
Start Date/Time:
End Date/Time:
Pump Time:
Max Rate:
Initial Surface Pressure (Breakdown):
Freeze Protect Volume:
Conoco Phillips - 3H-37 Interval Summary 20
10/24/20 10:45
10/24/20 11:40
55 min
15.5 bpm
4,729 psi
5,081 psi
27.6 bpm
6,380 psi
4,939 psi
23.6 bpm
4,756 psi
4,704 psi
4,625 psi
2,746 hhp
759 psi
808 psi
6.32 ppg
29 cP
79.6 F
9.37
102,621 lbs
102,621 lbs
102,621 lbs
0 gal 0 bbls
50,255 gal 1,197 bbls
0 gal 0 bbls
0 gal 0 bbls
21,942 gal 522 bbls
27,511 gal 655 bbls
802 gal 19 bbls
0 gal 0 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Keegan Lambe
Dan Faur
Average pH:
Average Temp:
Max Proppant Concentration:
Max BH Pressure:
Initial OA Pressure:
Max OA Pressure:
Max Surface Pressure:
Average Rate:
Fluid Summary (by stage description)
Proppant Laden Fluid Volume:
Seawater Volume:
Start Date/Time:
End Date/Time:
3H-37 - Kuparuk A-Sand - Interval 11
Pump Time:
Max Rate:
Chad Burkett
Average Missile Pressure:
Average Surface Pressure:
Freeze Protect Volume:
Freeze Protect Volume:
30# Hybor G Volume:
Pad Volume:
Spacer and Ball Drop Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Scott Pessetto
Paul Bessette
Interval Status:
Ball hit was observed at volume, but the shifting pressure was significantly lower than previous
stages. Interval pumped to design
Interval Summary
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Average BH Pressure:
Average Missile HHP:
Average Visc:
Proppant Summary
Fluid Summary (by fluid description)
30# Waterfrac G Volume:
Total Proppant Pumped* :
Proppant in Formation:
20/40 Wanli Pumped:
Initial BH Pressure (Breakdown):
Conoco Phillips - 3H-37 Interval Summary 21
10/24/20 11:40
10/24/20 12:32
52 min
15.0 bpm
7,481 psi
6,964 psi
25.7 bpm
6,720 psi
5,178 psi
24.1 bpm
5,264 psi
5,217 psi
4,766 psi
3,112 hhp
804 psi
830 psi
5.26 ppg
29.6 cP
79.3 F
9.45
5030 psi
0.844 psi/ft
4396 psi
4119 psi
4066 psi
85,379 lbs
85,379 lbs
85,379 lbs
48,047 gal 1,144 bbls
4,184 gal 100 bbls
1,055 gal 25 bbls
22,346 gal 532 bbls
25,701 gal 612 bbls
4,184 gal 100 bbls
1,055 gal 25 bbls
Cut Short
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Fluid Summary (by fluid description)
30# Hybor G Volume:
Keegan Lambe
Dan Faur
Proppant Laden Fluid Volume:
Interval Status:
Ball hit observed at volume. Truck kicked out due to ball seat. Held 5ppg long due to downhole
pressure trend. Cut sand early due to the downhole pressure trend. Well was successfully flushed
and freeze protected.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Final Fracture Gradient:
Proppant in Formation:
20/40 Wanli Pumped:
Chad Burkett
Total Proppant Pumped* :
Final 10 min:
Average Visc:
Average Temp:
Average pH:
Scott Pessetto
Paul Bessette
Pad Volume:
Freeze Protect Volume:
Average Missile Pressure:
3H-37 - Kuparuk A-Sand - Interval 12
Final 15 min:
ISDP:
Max Surface Pressure:
Fluid Summary (by stage description)
Flush Volume:
Freeze Protect Volume:
30# Waterfrac G Volume:
Interval Summary
Start Date/Time:
End Date/Time:
Max BH Pressure:
Average Rate:
Proppant Summary
Average Missile HHP:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Pump Time:
Max OA Pressure:
Initial OA Pressure:
Max Rate:
Average Surface Pressure:
Average BH Pressure:
Final 5 min:
Max Proppant Concentration:
Conoco Phillips - 3H-37 Interval Summary 22
CustomerFormationLeaseAPIDateWell Summary20/40 WanliTotal Proppantrface PressRate Visc Temp pHrface PressRate gal bbl gal bbl gal bbl gal bbl lbs lbs16020 24.7 26.6 73.7 9.5 7150 28.4 96,557 2,299 9,224 220 1,260 30 107,041 2,549 100,277 100,277 25903 25.2 27 77 9.4 6834 28.9 72,229 1,720 72,229 1,720 100,745 100,745 36039 27.1 25 78 9.4 6643 29.6 70,385 1,676 70,385 1,676 102,792 102,792 45916 24.6 28 79 9.5 6623 28.9 43,782 1,042 7,134 170 1,710 41 52,626 1,253 101,748 101,748 55728 22.4 NA 84 9.2 7815 32.3 46,117 1,098 46,117 1,098 78,209 78,209 64560 21.6 30 84 9.3 5835 27.5 61,046 1,453 61,046 1,453 53,432 53,432 74331 23.0 29 84 9.3 5971 27.8 70,463 1,678 70,463 1,678 100,679 100,679 84520 22.2 27 88 9.6 6486 27.1 51,012 1,215 51,012 1,215 100,173 100,173 94691 23.4 28 89 9.5 6493 24.9 49,703 1,183 5,277 126 1,281 31 56,261 1,340 97,742 97,742 104611 22.3 30 85 9.4 6444 24.6 60,433 1,439 60,433 1,439 101,312 101,312 114704 23.6 29 80 9.4 6380 27.6 50,255 1,197 50,255 1,197 102,621 102,621 125217 24.1 30 79 9.5 6720 25.7 48,047 1,144 4,184 100 1,055 25 53,286 1,269 85,379 85,379 Minimum43782 1042 4184 100 1055 25 46117 1098 53432 53432 Average60002 1429 6455 154 1327 32 62596 1490 93759 93759 Maximum96557 2299 9224 220 1710 41 107041 2549 102792 102792 20/40 Wanli Total ProppantPressure Rate Visc Temp pH Pressure Rate gal bbl gal bbl gal bbl gal bbl lbs TotalPlanned710,750 16,923 28,705 683 4,620 110 744,075 17,716 1,096,800 1,180,000Recorded5187 23.7 28 82 9.41 7815 32.3 720,029 17,144 25,819 615 5,306 126 751,154 17,885 1,125,109 1,125,109Weight Tickets1,200,000 1,200,000** Proppant is billed from Weight Ticket volumesOctober 16, 202050-103-208223H-37Kuparuk A-SandConoco PhillipsIntervalAverage Max30# Waterfrac GAverage Max30# Waterfrac G30# Hybor G30# Hybor G** IFS numbers for proppant are taken from software Total FluidFluidsProppantsFluidsProppantsTotal FluidFreeze ProtectFreeze ProtectConoco Phillips - 3H-37 Fluid System-Proppant Summary23
<-Paste Interval 1 Plots HerePressure Test - Day 0110/16/202008:3508:4008:4510/16/202008:50Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P1 Kickout Pressure (psi)43424140393837363534Global Event Log34353637383940414243Pressure Test - Globals Pressure Test - Locals Check Pop-OffPop-off good Test Reset Pop-Off Pop-Off TestPressure Test Pressure Test - Max (9459psi) Good Test, bleed downPre-Job Safety Meeting 08:34:08 08:35:05 08:35:5608:36:17 08:38:46 08:40:4908:43:03 08:49:00 08:52:0008:53:57Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 1 Plots24
<-Paste Interval 1 Plots HereBlender Chemical Plot - Bucket Tests Day 0110/16/202009:1709:1809:1909:2009:2110/16/202009:22Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA2 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBBCustomer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 1 Plots25
<-Paste Interval 1 Plots HereADP Chemical Plot - Bucket Tests Day 0110/16/202006:2006:2510/16/202006:30Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AABCustomer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 1 Plots26
<-Paste Interval 1 Plots HereTreatment Plot - Minifrac10/16/202010:1010:2010:3010:4010:5010/16/202011:00Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD7654Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 1 Plots27
Blender Chemical Plot - Minifrac10/16/202010:2510:3010:3510:4010:4510:5010:5510/16/202011:00Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA2 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB765Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 1 Plots28
ADP Chemical Plot - Minifrac10/16/202010:2510:3010:3510:4010:4510:5010:5510/16/202011:00Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB765Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 1 Plots29
Net Pressure Plot - Minifrac2345678923456789234560.1110Time (min)23456789234567892345678923456789110100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3200 psi 0 Time = 10/16/20 10:24:25 1Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 1 Plots30
Treatment Plot - Interval 0110/16/202011:4012:0012:2010/16/202012:40Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD11413121110982Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 1 Plots31
Blender Chemical Plot - Interval 0110/16/202011:3011:4011:5012:0012:1012:2012:3012:4010/16/202012:50Time0.00.51.01.52.02.53.0A012345BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA2 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB11413121110982Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 1 Plots32
ADP Chemical Plot - Interval 0110/16/202011:3011:4011:5012:0012:1012:2012:3012:4010/16/202012:50Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB11413121110982Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 1 Plots33
Net Pressure Plot - Interval 0145678Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/16/20 11:26:52 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 1 Plots34
<-Paste Interval 2 Plots HereTreatment Plot - Interval 0210/16/202012:4013:0013:2013:4010/16/202014:00Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD16543211432Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 2 Plots35
<-Paste Interval 2 Plots HereBlender Chemical Plot - Interval 0210/16/202012:4012:5013:0013:1013:2013:3013:4013:5010/16/202014:00Time0.00.51.01.52.02.53.0A012345BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA2 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB16543211432Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 2 Plots36
<-Paste Interval 2 Plots HereADP Chemical Plot - Interval 0210/16/202012:5013:0013:1013:2013:3013:4013:5010/16/202014:00Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB165432132Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 2 Plots37
<-Paste Interval 2 Plots HereNet Pressure Plot - Interval 0223456710Time (min)23456789234567892345678923456789110100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/16/20 13:05:30 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 2 Plots38
<-Paste Interval 3 Plots HereTreatment Plot - Interval 0310/16/202014:0014:2014:4010/16/202015:00Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD1654321643Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 3 Plots39
<-Paste Interval 3 Plots HereBlender Chemical Plot - Interval 0310/16/202014:0014:1014:2014:3014:4014:5015:0010/16/202015:10Time0.00.51.01.52.02.53.0A012345BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA2 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB165432143Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 3 Plots40
<-Paste Interval 3 Plots HereADP Chemical Plot - Interval 0310/16/202014:0014:1014:2014:3014:4014:5015:0010/16/202015:10Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB165432143Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 3 Plots41
<-Paste Interval 3 Plots HereNet Pressure Plot - Interval 0356789234510Time (min)23456789234567892345678923456789110100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/16/20 14:19:37 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 3 Plots42
<-Paste Interval 4 Plots HereTreatment Plot - Interval 0410/16/202015:1015:2015:3015:4015:5010/16/202016:00Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD98765432164Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 4 Plots43
<-Paste Interval 4 Plots HereBlender Chemical Plot - Interval 0410/16/202015:1015:2015:3015:4010/16/202015:50Time0.00.51.01.52.02.53.0A012345BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA2 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB98765432164Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 4 Plots44
<-Paste Interval 4 Plots HereADP Chemical Plot - Interval 0410/16/202015:1015:2015:3015:4010/16/202015:50Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB98765432164Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 4 Plots45
<-Paste Interval 4 Plots HereNet Pressure Plot - Interval 0423456789234110Time (min)23456789234567892345678923456789110100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/16/20 15:22:28 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 15-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 4 Plots46
<-Paste Interval 5 Plots HerePressure Test - Day 210/18/202008:5108:5208:5308:5408:5508:5608:5710/18/202008:58Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P1 Kickout Pressure (psi)7654Global Event Log4567Pressure Test - Globals Pressure Test - LocalsPressure Test - Max Pressure Test - Good Test08:50:32 08:51:5708:55:16 08:57:04Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 18-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 5 Plots47
<-Paste Interval 5 Plots HereBlender Chemical Plot - Bucket Tests Day 0210/18/202006:4206:4406:4606:4806:5006:5210/18/202006:54Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA2 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBBCustomer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 18-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 5 Plots48
<-Paste Interval 5 Plots HereADP Chemical Plot - Bucket Tests Day 0210/18/202007:3007:3107:3207:3307:3407:3510/18/202007:36Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AABCustomer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 18-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 5 Plots49
<-Paste Interval 5 Plots HereTreatment Plot - Interval 0510/18/202010:0010:2010:4011:0010/18/202011:20Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD111987654326Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 18-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 5 Plots50
Blender Chemical Plot - Interval 0510/18/202010:1010:2010:3010:4010:5010/18/202011:00Time0.00.51.01.52.02.53.0A012345BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA3 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB111987654326Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 18-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 5 Plots51
ADP Chemical Plot - Interval 0510/18/202010:1010:2010:3010:4010:5010/18/202011:00Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB111987654326Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 18-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 5 Plots52
Net Pressure Plot - Interval 052345678923456710Time (min)2345678923456789100100010000A0123456BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/18/20 10:23:43 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 18-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 5 Plots53
<-Paste Interval 6 Plots HerePressure Test - Day 0310/23/202006:2006:4007:0007:2007:4008:0010/23/202008:20Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P1 Kickout Pressure (psi)151413121110Global Event Log101112131415Pressure Test - Globals Pressure Test - LocalsPop-Off Test Pressure Test - Reset Pop-OffPressure Test - Low Pressure Pressure Test - High Pressure Test06:25:54 06:26:3206:27:28 06:28:1006:29:39 08:23:49Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 6 Plots54
<-Paste Interval 6 Plots HereBlender Chemical Plot - Bucket Tests Day 0310/23/202006:0506:1006:1510/23/202006:20Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA3 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBBCustomer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 6 Plots55
<-Paste Interval 6 Plots HereADP Chemical Plot - Bucket Tests Day 0310/23/202006:3006:3506:4006:4506:5010/23/202006:55Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AABCustomer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 6 Plots56
<-Paste Interval 6 Plots HereTreatment Plot - Interval 0610/23/202008:4009:0009:2009:4010/23/202010:00Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD197654327Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 6 Plots57
Conoco Phillips - 3H-37 Interval 6 Plots58
ADP Chemical Plot - Interval 0610/23/202008:5009:0009:1009:2009:3009:4009:5010/23/202010:00Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB197654327Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 6 Plots59
Net Pressure Plot - Interval 062345678923456110Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/23/20 09:05:38 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 6 Plots60
<-Paste Interval 7 Plots HereTreatment Plot - Interval 0710/23/202010:0010:2010:4011:0010/23/202011:20Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD1654321987Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 7 Plots61
<-Paste Interval 7 Plots HereBlender Chemical Plot - Interval 0710/23/202010:0010:1010:2010:3010:4010:5011:0011:1010/23/202011:20Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA3 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB165432187Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 7 Plots62
<-Paste Interval 7 Plots HereADP Chemical Plot - Interval 0710/23/202010:0010:1010:2010:3010:4010:5011:0011:1010/23/202011:20Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB165432187Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 7 Plots63
<-Paste Interval 7 Plots HereNet Pressure Plot - Interval 079234567892345678110Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/23/20 10:05:53 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 7 Plots64
<-Paste Interval 8 Plots HereTreatment Plot - Interval 0810/23/202011:2011:3011:4011:5012:0012:1010/23/202012:20Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD18765432198Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 8 Plots65
<-Paste Interval 8 Plots HereBlender Chemical Plot - Interval 0810/23/202011:2011:3011:4011:5012:0012:1010/23/202012:20Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA3 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB187654321698Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 8 Plots66
<-Paste Interval 8 Plots HereADP Chemical Plot - Interval 0810/23/202011:2011:3011:4011:5012:0012:1010/23/202012:20Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB187654321698Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 8 Plots67
<-Paste Interval 8 Plots HereNet Pressure Plot - Interval 089234567892345110Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/23/20 11:26:26 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 8 Plots68
<-Paste Interval 9 Plots HereTreatment Plot - Interval 0910/23/202012:2012:3012:4012:5013:0013:1013:2010/23/202013:30Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD98765432189Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 9 Plots69
<-Paste Interval 9 Plots HereBlender Chemical Plot - Interval 0910/23/202012:2012:3012:4012:5013:0010/23/202013:10Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA3 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB98765432189Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 9 Plots70
<-Paste Interval 9 Plots HereADP Chemical Plot - Interval 0910/23/202012:2012:3012:4012:5013:0010/23/202013:10Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB98765432189Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 9 Plots71
<-Paste Interval 9 Plots HereNet Pressure Plot - Interval 09234567892345110Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/23/20 12:23:01 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 22-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 9 Plots72
<-Paste Interval 10 Plots HerePressure Test - Day 410/24/202008:1008:2008:3008:4008:5010/24/202009:00Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P1 Kickout Pressure (psi)987654Global Event Log456789Pressure Test - Globals Pressure Test - LocalsTest Pop-Off Pressure TestPressure Test - Max Pressure Test Good Test08:04:42 08:05:5308:06:22 08:07:4409:01:40 09:06:50Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 10 Plots73
<-Paste Interval 10 Plots HereBlender Chemical Plot - Bucket Tests Day 0410/24/202007:4907:5007:5107:5207:5307:5407:5507:5610/24/202007:57Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA3 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBBCustomer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 10 Plots74
<-Paste Interval 10 Plots HereADP Chemical Plot - Bucket Tests Day 0410/24/202008:3308:3408:3508:3608:3710/24/202008:38Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AABCustomer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 10 Plots75
<-Paste Interval 10 Plots HereTreatment Plot - Interval 1010/24/202009:4010:0010:2010/24/202010:40Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD111109876543211Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 10 Plots76
Blender Chemical Plot - Intrval 1010/24/202009:3009:4009:5010:0010:1010:2010:3010/24/202010:40Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA3 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB111109876543211Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 10 Plots77
ADP Chemical Plot - Intrval 1010/24/202009:3009:4009:5010:0010:1010:2010:3010:4010/24/202010:50Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB11Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 10 Plots78
Net Pressure Plot - Interval 1023456789234567110Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/24/20 09:43:54 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 10 Plots79
<-Paste Interval 11 Plots HereTreatment Plot - Interval 1110/24/202010:5011:0011:1011:2011:3010/24/202011:40Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD1876543211211Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 11 Plots80
<-Paste Interval 11 Plots HereBlender Chemical Plot - Intrval 1110/24/202010:4010:5011:0011:1011:2011:3010/24/202011:40Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA3 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB1876543211211Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 11 Plots81
<-Paste Interval 11 Plots HereADP Chemical Plot - Intrval 1110/24/202010:4010:5011:0011:1011:2011:3010/24/202011:40Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB1876543211211Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 11 Plots82
<-Paste Interval 11 Plots HereNet Pressure Plot - Interval 11234567892345110Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/24/20 10:49:42 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 11 Plots83
<-Paste Interval 12 Plots HereTreatment Plot - Interval 1210/24/202011:4011:5012:0012:1012:2010/24/202012:30Time010002000300040005000600070008000900010000A0102030405060708090100B012345678910C0255075100125150175DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD9865432Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 12 Plots84
<-Paste Interval 12 Plots HereBlender Chemical Plot - Intrval 1210/24/202011:4011:5012:0012:1012:2010/24/202012:30Time0.00.51.01.52.02.53.0A0123456BB1 CL-31 Conc -LA1 (gal/Mgal)B1 CL-22 UC Conc -LA3 (gal/Mgal)B1 Optiflo-III Conc -DA1 (lb/Mgal)B1 Optiflo-II Conc -DA2 (lb/Mgal)SP Breaker Conc (lb/Mgal)AABBB98654321812Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 12 Plots85
<-Paste Interval 12 Plots HereADP Chemical Plot - Intrval 1210/24/202011:4011:5012:0012:1012:2010/24/202012:30Time0.00.20.40.60.81.01.21.4A0102030405060708090100BB2 Losurf-300D Conc -LA3 (gal/Mgal)B2 MO-67 Conc -LA4 (gal/Mgal)B2 WG-36 Conc -DA1 (lb/Mgal)AAB9865432112Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 12 Plots86
<-Paste Interval 12 Plots HereNet Pressure Plot - Interval 1289234567892345110Time (min)2345678923456789100100010000A012345678910BNet Gauge BH Pres (psi)BH Proppant Conc (lb/gal)AB Closure Pressure = 3350 psi 0 Time = 10/24/20 11:45:22 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 24-Oct-2020Sales Order #: 0906757288Well Description: 3H-37UWI: 50-103-20822Conoco Phillips - 3H-37 Interval 12 Plots87
Sales Order#
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Prepared for: Scott Pessetto
October 24, 2020
County, AK
0906757288
Conoco Phillips
3H-37
Intervals 1-12
Kuparuk A-Sand Formation
API: 50-103-20822
Wellbore Information
Chemical Summary
Stimulation Treatment
Appendix
Planned Design
Water Straps
Water Analysis
Real-Time QC
Event Log
Lab Testing
Fann 15 Minute
Field Break Test
Conoco Phillips - 3H-37 Appendix 88
Interval Date
Designed
Proppant
(lbs)
Proppant in
Formation (lbs)
Vol Clean
(bbl)
Vol Slurry
(bbl)
Top Perf
(ft)
Bottom
Perf (ft)
Fluid
System
1 10/16/2020 100000 100,277 2519 2,625 20,246 20,249 Hybor G
2 10/16/2020 100000 100,745 1720 1,826 19,508 19,511 Hybor G
3 10/16/2020 100000 102,792 1676 1785 19,050 19,023 Hybor G
4 10/16/2020 100000 101,748 1253 1361 18,542 18,545 Hybor G
5 10/18/2020 100000 62,405 1098 1181 18,048 18,051 Hybor G
6 10/23/2020 80000 53,432 1453 1510 17,593 17,596 Hybor G
7 10/23/2020 100000 100,679 1678 1784 16,621 16,624 Hybor G
8 10/23/2020 100000 100,173 1215 1321 16,209 16,212 Hybor G
9 10/23/2020 100000 97,742 1340 1443 15,755 15,758 Hybor G
10 10/24/2020 100000 101,312 1439 1546 15,302 15,305 Hybor G
11 10/24/2020 100000 102,621 1197 1305 14,666 14,669 Hybor G
12 10/24/2020 100000 85,379 1269 1359 14,115 14,118 Hybor G
3H-37 Interval Highlights
Conoco Phillips - 3H-37 Well Summary 89
CustomerConoco PhillipsFormationKuparuk A-SandLease3H-37API50-103-20822DateInterval Summary - Chemicals LoSurf-300D CL-31 CL-22 UC MO-67 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs) (lbs)Prime Up00000000001106 48 93 35 0 2990 16 202 27 0271 35 71 28 0 1833 11 142 18 0369 34 69 28 0 1948 11 138 18 0454 33 47 24 4200 1245 13 69 13 6560 35 50 19 - 1250 7 90 13 0660 30 61 24 0 1898 9 90 15 0769 34 69 28 0 1889 11 104 17 0850 25 50 20 0 1391 8 75 14 0961 26 60 24 1470 1406 8 91 14 51061 30 60 24 - 2025 9 91 15 01148 24 48 19 - 1483 8 72 13 01262 26 52 17 1050 1395 8 88 12 6Total 770 380 730 290 6720 20753 119 1250 190 17w/o Prime Up770 380 730 290 6720 20753 119 1250 190 17Interval10/16/2020Dry AdditivesLiquid AdditivesConoco Phillips - 3H-37 Chemical Summary90
CUSTOMERConoco PhillipsFALSEAPIBFD (lb/gal)8.48LEASE3H-37SALES ORDERBHST (°F)156FORMATIONKuparuk A-SandDATE Max Pressure (psi)9000*Exceeds 80% of bProp Slurry Design Clean Design Clean Design Slurry Design Prop LoSurf-300D CL-31 CL-22 UC MO-67 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SPTreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume TotalSurfactant Crosslinker Crosslinker Buffer Freeze Protect Gel Biocide Breaker BreakerBreakerInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In1-2 Freeze Protect Freeze Protect 2 2,100 50 50 1000.001-3 Shut-In Shut-In1-4 30# Hybor G Establish Stable Fluid 15 4,200 100 100 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-5 30# Hybor G Minifrac 30 12,600 300 300 1.00 0.50 1.00 0.40 30.00 0.152.00 0.251-6 30# Waterfrac G Flush 30 9,156 218 218 1.00 30.00 0.15 2.00 0.251-7 Shut-In Shut-In1-8 30# Hybor G Establish Stable Fluid 30 4,200 100 100 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-9 30# Hybor G Pad 30 25,000 595 595 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-10 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 30 13,200 314 328 13,200 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-11 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 30 12,000 286 311 24,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-12 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 30 12,000 286 324 36,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-13 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 30 6,700 160 188 26,800 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.251-14 30# Hybor G Spacer and Ball Drop 15 1,000 24 24 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-1 30# Hybor G Pad 30 25,000 595 595 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 30 13,200 314 328 13,200 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 30 12,000 286 311 24,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 30 12,000 286 324 36,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 30 6,700 160 188 26,800 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.252-6 30# Hybor G Spacer and Ball Drop 15 1,000 24 24 1.00 0.50 1.00 0.4030.00 0.15 2.00 0.253-1 30# Hybor G Pad 30 25,000 595 595 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.253-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 30 13,200 314 328 13,200 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.253-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 30 12,000 286 311 24,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.253-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 30 12,000 286 324 36,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.253-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 30 6,700 160 188 26,800 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.253-6 30# Hybor G Spacer and Ball Drop 15 1,000 24 24 1.00 0.50 1.00 0.4030.00 0.15 2.00 0.254-1 30# Hybor G Pad 30 15,000 357 357 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.254-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 30 3,200 76 80 3,200 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.254-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 30 3,300 79 86 6,600 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.254-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 30 5,000 119 135 15,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.254-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 30 5,500 131 154 22,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.254-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 30 5,000 119 146 25,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.250.254-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 30 4,700 112 142 28,200 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.250.254-8 30# Waterfrac G Flush 30 8,064 192 192 1.00 30.00 0.15 2.00 0.250.504-9 Freeze Protect Freeze Protect 15 840 20 20 1000.005-1 Shut-In Shut-In5-2 30# Hybor G Establish Stable Fluid 30 4,200 100 100 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-3 30# Hybor G Spacer and Ball Drop 15 1,000 24 24 1.00 0.50 1.00 0.4030.00 0.15 2.00 0.255-4 30# Hybor G Pad 30 15,000 357 357 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 30 3,200 76 80 3,200 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 30 3,300 79 86 6,600 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 30 5,000 119 135 15,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-8 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 30 5,500 131 154 22,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-9 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 30 5,000 119 146 25,000 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-10 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 30 4,700 112 142 28,200 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.255-11 30# Hybor G Spacer and Ball Drop 30 1,000 24 24 1.00 0.50 1.00 0.40 30.00 0.15 2.00 0.25Interval 1Kuparuk Sands@ 20246 - 20249 ft 155.9 °FInterval 2Kuparuk Sands@ 19508 - 19511 ft 155.7 °FInterval 3Kuparuk Sands@ 19020 - 19023 ft 155.6 °FInterval 4Kuparuk Sands@ 18542 - 18545 ft 155.6 °FInterval 5Kuparuk Sands@ 18048 - 18051 ft 155.7 °F10/16/20Liquid AdditivesDry Additives50-103-208220906757288Conoco Phillips - 3H-37Planned Design91
CUSTOMERConoco PhillipsFALSEAPIBFD (lb/gal)8.48LEASE3H-37SALES ORDERBHST (°F)156FORMATIONKuparuk A-SandDATE Max Pressure (psi)9000*Exceeds 80% of bProp Slurry Design Clean Design Clean Design Slurry Design Prop LoSurf-300D CL-31 CL-22 UC MO-67 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SPTreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume TotalSurfactant Crosslinker Crosslinker Buffer Freeze Protect Gel Biocide Breaker BreakerBreakerInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) (ppt)10/16/20Liquid AdditivesDry Additives50-103-2082209067572886-1 Shut-In Shut-In6-2 30# Hybor G Establish Stable Fluid 15 4,200 100 100 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.256-3 30# Hybor G Spacer and Ball Drop 15 1,000 24 24 1.00 0.50 1.00 0.4030.00 0.15 1.50 0.256-4 30# Hybor G Pad 23 25,000 595 595 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.256-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23 13,200 314 328 13,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.256-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23 8,000 190 207 16,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.256-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23 8,000 190 216 24,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.256-8 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 23 6,700 160 188 26,800 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.256-9 30# Hybor G Spacer and Ball Drop 15 1,000 24 24 1.00 0.50 1.00 0.4030.00 0.15 1.50 0.257-1 30# Hybor G Pad 23 25,000 595 595 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.257-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23 13,200 314 328 13,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.257-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23 12,000 286 311 24,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.257-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23 12,000 286 324 36,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.257-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 23 6,700 160 188 26,800 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.257-6 30# Hybor G Spacer and Ball Drop 15 1,000 24 24 1.00 0.50 1.00 0.4030.00 0.15 1.50 0.258-1 30# Hybor G Pad 23 22,350 532 532 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23 3,200 76 80 3,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23 3,300 79 86 6,600 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23 5,000 119 135 15,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 23 5,500 131 154 22,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 23 5,000 119 146 25,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 23 4,700 112 142 28,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.258-8 30# Hybor G Spacer and Ball Drop 15 1,000 24 24 1.00 0.50 1.00 0.4030.00 0.15 1.50 0.259-1 30# Hybor G Pad 23 22,350 532 532 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.259-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23 3,200 76 80 3,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.259-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23 3,300 79 86 6,600 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.259-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23 5,000 119 135 15,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.259-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 23 5,500 131 154 22,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.259-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 23 5,000 119 146 25,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.250.259-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 23 4,700 112 142 28,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.250.259-8 30# Waterfrac G Flush 23 6,277 149 149 1.00 30.00 0.15 1.50 0.250.509-9 Freeze Protect Freeze Protect 15 840 20 20 1000.0010-1 Shut-In Shut-In10-2 30# Hybor G Establish Stable Fluid 15 4,200 100 100 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-3 30# Hybor G Spacer and Ball Drop 15 1,000 24 24 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-4 30# Hybor G Pad 23 22,350 532 532 1.00 0.50 1.00 0.40 30.00 0.15 1.500.2510-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23 3,200 76 80 3,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23 3,300 79 86 6,600 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23 5,000 119 135 15,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-8 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 23 5,500 131 154 22,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-9 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 23 5,000 119 146 25,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-10 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 23 4,700 112 142 28,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2510-11 30# Hybor G Spacer and Ball Drop 15 1,000 24 24 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-1 30# Hybor G Pad 23 22,350 532 532 1.00 0.50 1.00 0.40 30.00 0.15 1.500.2511-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23 3,200 76 80 3,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23 3,300 79 86 6,600 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23 5,000 119 135 15,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 23 5,500 131 154 22,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 23 5,000 119 146 25,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 23 4,700 112 142 28,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2511-8 30# Hybor G Spacer and Ball Drop 15 1,000 24 24 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2512-1 30# Hybor G Pad 23 22,350 532 532 1.00 0.50 1.00 0.40 30.00 0.15 1.500.2512-2 30# Hybor G Proppant Laden Fluid 20/40 Wanli 1.00 23 3,200 76 80 3,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2512-3 30# Hybor G Proppant Laden Fluid 20/40 Wanli 2.00 23 3,300 79 86 6,600 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2512-4 30# Hybor G Proppant Laden Fluid 20/40 Wanli 3.00 23 5,000 119 135 15,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2512-5 30# Hybor G Proppant Laden Fluid 20/40 Wanli 4.00 23 5,500 131 154 22,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.2512-6 30# Hybor G Proppant Laden Fluid 20/40 Wanli 5.00 23 5,000 119 146 25,000 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.250.2512-7 30# Hybor G Proppant Laden Fluid 20/40 Wanli 6.00 23 4,700 112 142 28,200 1.00 0.50 1.00 0.40 30.00 0.15 1.50 0.250.2512-8 30# Waterfrac G Flush 23 5,208 124 124 1.00 30.00 0.15 1.50 0.250.5012-9 Freeze Protect Freeze Protect 15 840 20 20 1000.00744,075 17,716 18,966 1,180,000Design Total (gal)Design Total (lbs)LoSurf-300D CL-31 CL-22 UC MO-67 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP1,180,000(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs) (lbs)710,750- 739.5 355.4 710.8 284.3 4,620.0 22,183.7 110.9 1,277.9 184.9 17.028,705-4,620--- LoSurf-300D CL-31 CL-22 UC MO-67 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP-(gpm) (gpm) (gpm) (gpm) (gpm) ppm ppm ppm ppm ppm-1.3 0.6 1.3 0.5 1,260.0 37.8 0.2 2.5 0.3 0.6-Interval 9Kuparuk Sands@ 15755 - 15758 ft 155.8 °FInterval 10Kuparuk Sands@ 15302 - 15305 ft 155.8 °FInterval 11Kuparuk Sands@ 14666 - 14669 ft 155.6 °FInterval 6Kuparuk Sands@ 17593 - 17596 ft 155.7 °FInterval 7Kuparuk Sands@ 16621 - 16624 ft 155.8 °FInterval 8Kuparuk Sands@ 16209 - 16212 ft 155.8 °FInterval 12Kuparuk Sands@ 14115 - 14118 ft 155.3 °FProppant Type20/40 Wanli----Fluid TypeSeawater30# Hybor G30# Waterfrac GFreeze Protect----Conoco Phillips - 3H-37Planned Design92
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons BarrelsTemperature (°F)Inches Gallons Barrels1 Atigan CPF3 106 20,142 480 98 9 1,444 342 Atigan CPF3 105 19,949 475 101 9 1,444 343 Atigan CPF3 105 19,949 475 105 9 1,444 344 Atigan CPF3 105 19,949 475 101 9 1,444 345 Atigan CPF3 105 19,949 475 103 9 1,444 346 Atigan CPF3 104 19,755 470 97 9 1,444 347 Atigan CPF3 105 19,949 475 2 10 1,627 398 Atigan CPF3 105 19,949 475 94 105 19,949 4759 Atigan CPF3 100 18,981 452 109 58 10,784 25710 Wichita CPF3 100 20,160 480 109 9 1,722 4111 Wichita CPF3 100 20,160 480 110 9 1,722 4112 Wichita CPF3 100 20,160 480 111 9 1,722 4113 Wichita CPF3 100 20,160 480 110 9 1,722 4114 Wichita CPF3 105 0 0 109 9 1,722 4115 Wichita CPF3 100 20,160 480 110 9 1,722 4116 Wichita CPF3 100 20,160 480 102 9 1,722 4117 Wichita CPF3 100 20,160 480 102 0 0 018 0 019 0 020 0 021 0 022 0 023 0 024 0 025 0 0Gallons Barrels Gallons Barrels Gallons Barrels319,691 7,612 53,080 1,264 266,611 6,348Zones: 1Volume Needed for X Intervals (BBL):Number of Tanks Needed:000 0Tank Bottoms (BBL):476 476 476 476Conoco Phillips3H-3710/16/2020Kuparuk A-Sand0906757288Pre-Job Barrel BottomsGeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips - 3H-37Water Straps Day 193
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons BarrelsTemperature (°F)Inches Gallons Barrels1 Atigan CPF3 105 19,755 470 110 10 1,444 342 Atigan CPF3 105 19,755 470 107 10 1,444 343 Atigan CPF3 105 19,755 470 107 70 12,985 3094 Atigan CPF3 105 19,755 470 107 70 12,985 3095 Atigan CPF3 105 19,755 470 108 105 19,755 4706 Atigan CPF3 105 19,755 470 106 105 19,755 4707 Atigan CPF3 105 19,755 470 106 105 19,755 4708 Atigan CPF3 105 19,755 470 86 105 19,755 4709 Atigan CPF3 105 19,755 470 106 105 19,755 47010 Wichita CPF3 100 20,160 480 110 100 20,160 48011 Wichita CPF3 100 20,160 480 109 100 20,160 48012 Wichita CPF3 100 20,160 480 109 100 20,160 48013 Wichita CPF3 100 20,160 480 107 100 20,160 48014 Wichita CPF3 100 20,160 480 107 100 20,160 48015 Wichita CPF3 100 20,160 480 107 100 20,160 48016 Wichita CPF3 100 20,160 480 105 100 20,160 48017 Wichita CPF3 100 20,160 480 106 80 15,960 38018 0 019 0 020 0 021 0 022 0 023 0 024 0 025 0 0Gallons Barrels Gallons Barrels Gallons Barrels339,076 8,073 284,715 6,779 54,361 1,294Zones: 1Volume Needed for X Intervals (BBL):Number of Tanks Needed:000 0Tank Bottoms (BBL):475 475 475 475Pre-Job Barrel BottomsGeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips3H-3710/16/2020Kuparuk A-Sand0906757288Conoco Phillips - 3H-37Water Straps Day 294
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons BarrelsTemperature (°F)Inches Gallons Barrels1 Atigan CPF3 105 19,755 470 106 9 1,262 302 Atigan CPF3 106 19,949 475 109 9 1,262 303 Atigan CPF3 106 19,949 475 112 9 1,262 304 Atigan CPF3 105 19,755 470 110 12 1,809 435 Atigan CPF3 106 19,949 475 111 9 1,262 306 Atigan CPF3 104 19,562 466 102 9 1,262 307 Atigan CPF3 101 18,981 452 106 24 4,182 1008 Atigan CPF3 102 19,175 457 106 105 19,755 4709 Atigan CPF3 100 18,788 447 111 100 18,788 44710 Wichita CPF3 101 20,370 485 110 100 20,160 48011 Wichita CPF3 100 20,160 480 108 87 17,430 41512 Wichita CPF3 101 20,370 485 108 48 9,240 22013 Wichita CPF3 100 20,160 480 107 9 1,722 4114 Wichita CPF3 100 20,160 480 108 9 1,722 4115 Wichita CPF3 100 20,160 480 110 9 1,722 4116 Wichita CPF3 95 19,110 455 108 9 1,722 4117 Wichita CPF3 99 19,950 475 104 20 3,780 9018 0 019 0 020 0 021 0 022 0 023 0 024 0 025 0 0Gallons Barrels Gallons Barrels Gallons Barrels336,302 8,007 108,343 2,580 227,959 5,428Zones: 1Volume Needed for X Intervals (BBL):Number of Tanks Needed:000 0Tank Bottoms (BBL):471 471 471 471Pre-Job Barrel BottomsGeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips3H-3710/16/2020Kuparuk A-Sand0906757288Conoco Phillips - 3H-37Water Straps Day 395
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons BarrelsTemperature (°F)Inches Gallons Barrels1 Atigan CPF3 105 19,755 470 106 9 1,262 302 Atigan CPF3 105 19,755 470 107 12 1,809 433 Atigan CPF3 105 19,755 470 107 9 1,262 304 Atigan CPF3 105 19,755 470 106 9 1,262 305 Atigan CPF3 105 19,755 470 106 9 1,262 306 Atigan CPF3 105 19,755 470 106 9 1,262 307 Atigan CPF3 71 13,178 314 106 36 6,190 1478 Atigan CPF3 105 19,755 470 101 105 19,755 4709 Atigan CPF3 100 18,788 447 108 80 14,919 35510 Wichita CPF3 100 20,160 480 107 56 10,920 26011 Wichita CPF3 87 17,430 415 102 9 1,722 4112 Wichita CPF3 48 9,240 220 85 9 1,722 4113 Wichita CPF3 9 1,722 41 9 1,722 4114 Wichita CPF3 9 1,722 41 9 1,722 4115 Wichita CPF3 9 1,722 41 9 1,722 4116 Wichita CPF3 9 1,722 41 9 1,722 4117 Wichita CPF3 9 1,722 41 20 3,780 9018 0 019 0 020 0 021 0 022 0 023 0 024 0 025 0 0Gallons Barrels Gallons Barrels Gallons Barrels225,692 5,374 74,016 1,762 151,676 3,611Zones: 1Volume Needed for X Intervals (BBL):Number of Tanks Needed:000 0Tank Bottoms (BBL):448 448 448 448Pre-Job Barrel BottomsGeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips3H-3710/16/2020Kuparuk A-Sand0906757288Conoco Phillips - 3H-37Water Straps Day 496
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO4
2-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-Crosslink
pH Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank # Hydrometer
Digital
Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
1 1.014 78.1 0 12,040 800 1,480 720 2,200 23.0 7.20 7.20 9.80 Y 8,520
2 1.012 79.5 0 11,180 800 1,320 560 1,880 24.0 7.30 7.30 9.70 Y 1,257
3 1.012 83.2 0 12,040 800 1,400 400 1,800 25.0 7.30 7.30 9.90 Y 690
4 1.014 80.1 0 14,050 1,200 1,400 440 1,840 24.0 7.30 7.40 9.90 Y 348
5 1.014 75.5 0 13,010 800 1,520 440 1,960 23.0 7.30 7.40 9.80 Y 4,646
6 1.012 79.8 5 15,150 800 1,480 280 1,760 24.0 7.30 7.40 9.70 Y 5,827
7 1.012 73.4 0 16,320 800 1,360 720 2,080 25.0 7.30 7.40 9.90 Y 6,792
8 1.014 74.6 0 17,580 800 1,280 640 1,920 23.0 7.30 7.40 9.80 Y 6,574
9 1.014 77.7 0 16,320 1,200 1,440 560 2,000 24.0 7.30 7.30 9.70 Y 4,438
10 1.014 72.5 0 16,320 800 1,320 760 2,080 25.0 7.20 7.30 9.70 Y 6,879
11 1.014 73.9 5 15,150 800 1,480 520 2,000 23.0 7.20 7.30 9.70 Y 718
12 1.014 73.4 0 15,150 1,200 1,400 520 1,920 24.0 7.20 7.20 9.80 Y 329
13 1.014 75.1 0 16,320 800 1,320 720 2,040 24.0 7.20 7.40 9.70 Y 1,197
14 1.016 72.9 0 18,930 800 1,400 600 2,000 23.0 7.20 7.30 9.70 Y 1,742
15 1.016 74.6 0 18,930 800 1,440 520 1,960 24.0 7.20 7.40 9.80 Y 1,035
16 1.016 77.8 0 16,320 800 1,480 520 2,000 24.0 7.30 7.40 9.80 Y 2,271
17 1.016 79.2 0 16,320 1,200 1,400 640 2,040 23.0 7.30 7.40 9.70 Y 30,426
Average 1.014 76.5 1 15,361 894 1,407 562 1,969 23.8 7.26 7.34 9.77 - 4,923
Maximum 1.016 83.2 5 18,930 1,200 1,520 760 2,200 25.0 7.30 7.40 9.90 - 30,426
Minimum 1.012 72.5 0 11,180 800 1,280 280 1,760 23.0 7.20 7.20 9.70 - 329
Range 0.004 10.7 5 7,750 400 240 480 440 2.0 0.10 0.20 0.20 - 30,097
Alaska District Field QC
Prejob Water Analysis on Location
Company:
Conoco Phillips
Well Name:3H-37
Water Source:
Conoco Phillips - 3H-37 Water Analysis Interval 01-04 97
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO4
2-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-Crosslink
pH Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank # Hydrometer
Digital
Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
1 1.018 94.7 5 17,580 1,200 1,680 1,080 2,760 24.0 7.20 7.40 9.50 Y 1,808
2 1.020 90.1 0 17,580 800 1,400 1,160 2,560 24.0 7.10 7.40 9.50 Y 1,162
3 1.018 87.4 5 21,960 1,200 1,680 920 2,600 25.0 7.30 7.50 9.60 Y 1,012
4 1.018 82.0 5 17,580 800 1,720 1,000 2,720 26.0 7.30 7.40 9.80 Y 2,706
5 1.020 81.2 0 20,380 800 1,760 680 2,440 25.0 7.20 7.40 9.70 Y 1,159
6 1.018 81.6 0 23,680 800 1,600 1,120 2,720 26.0 7.10 7.40 9.80 Y 1,904
7 1.018 83.1 0 21,960 1,200 1,560 1,040 2,600 25.0 7.00 7.50 9.60 Y 3,095
8 1.020 80.4 0 23,680 800 1,520 1,040 2,560 25.0 7.10 7.40 9.70 Y 794
9 1.018 79.8 5 20,380 800 1,480 1,040 2,520 24.0 7.00 7.40 9.60 Y 3,630
10 1.014 75.8 0 16,320 800 1,320 760 2,080 25.0 7.20 7.30 9.70 Y 7,612
11 1.018 81.6 5 21,960 800 1,560 1,120 2,680 25.0 6.90 7.40 9.70 Y 2,561
12 1.018 74.9 0 21,960 1,200 1,640 800 2,440 26.0 7.00 7.30 9.80 Y 1,351
13 1.020 83.9 0 23,680 800 1,520 1,000 2,520 24.0 6.90 7.50 9.70 Y 4,261
14 1.018 84.6 0 17,580 800 1,440 920 2,360 25.0 6.90 7.40 9.80 Y 1,869
15 1.018 81.2 0 21,960 1,200 1,520 1,000 2,520 26.0 6.90 7.50 9.80 Y 3,457
16 1.018 77.6 5 20,380 800 1,520 880 2,400 24.0 7.00 7.40 9.60 Y 17,918
17 1.020 74.1 0 23,680 800 1,720 880 2,600 25.0 6.90 7.50 9.70 Y 13,424
Average 1.018 82.0 2 20,724 918 1,567 967 2,534 24.9 7.06 7.42 9.68 - 4,101
Maximum 1.020 94.7 5 23,680 1,200 1,760 1,160 2,760 26.0 7.30 7.50 9.80 - 17,918
Minimum 1.014 74.1 0 16,320 800 1,320 680 2,080 24.0 6.90 7.30 9.50 - 794
Range 0.006 20.6 5 7,360 400 440 480 680 2.0 0.40 0.20 0.30 - 17,125
Well Name:3H-37
Water Source:CPF3
Alaska District Field QC
Prejob Water Analysis on Location
Company:
Conoco Phillips
Conoco Phillips - 3H-37 Water Analysis Intervals 05-05 98
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO4
2-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-Crosslink
pH Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank # Hydrometer
Digital
Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
1 1.018 89.9 0 16,320 800 1,800 1,200 3,000 26.0 6.90 7.00 9.70 Y 14,941
2 1.020 89.9 5 16,320 800 1,920 1,040 2,960 25.0 6.80 7.20 9.60 Y 6,679
3 1.200 87.8 0 16,320 800 1,400 1,800 3,200 26.0 6.80 7.20 9.70 Y 4,984
4 1.200 79.8 5 18,930 800 1,920 1,280 3,200 25.0 6.80 7.10 9.60 Y 5,499
5 1.020 81.2 0 20,380 800 1,760 680 2,440 25.0 7.20 7.40 9.70 Y 1,159
6 1.018 81.6 0 23,680 800 1,600 1,120 2,720 26.0 7.10 7.40 9.80 Y 1,904
7 1.018 83.1 0 21,960 1,200 1,560 1,040 2,600 25.0 7.00 7.50 9.60 Y 3,095
8 1.020 80.4 0 23,680 800 1,520 1,040 2,560 25.0 7.10 7.40 9.70 Y 794
9 1.018 79.8 5 20,380 800 1,480 1,040 2,520 24.0 7.00 7.40 9.60 Y 3,630
10 1.014 75.8 0 16,320 800 1,320 760 2,080 25.0 7.20 7.30 9.70 Y 7,612
11 1.018 81.6 5 21,960 800 1,560 1,120 2,680 25.0 6.90 7.40 9.70 Y 2,561
12 1.018 74.9 0 21,960 1,200 1,640 800 2,440 26.0 7.00 7.30 9.80 Y 1,351
13 1.020 83.9 0 23,680 800 1,520 1,000 2,520 24.0 6.90 7.50 9.70 Y 4,261
14 1.018 84.6 0 17,580 800 1,440 920 2,360 25.0 6.90 7.40 9.80 Y 1,869
15 1.018 81.2 0 21,960 1,200 1,520 1,000 2,520 26.0 6.90 7.50 9.80 Y 3,457
16 1.018 77.6 5 20,380 800 1,520 880 2,400 24.0 7.00 7.40 9.60 Y 17,918
17 1.018 73.6 0 16,320 800 1,480 1,520 3,000 25.0 6.80 7.30 9.80 Y 2,298
Average 1.040 81.6 1 19,890 871 1,586 1073 2,659 25.1 6.96 7.34 9.70 - 4,942
Maximum 1.200 89.9 5 23,680 1,200 1,920 1,800 3,200 26.0 7.20 7.50 9.80 - 17,918
Minimum 1.014 73.6 0 16,320 800 1,320 680 2,080 24.0 6.80 7.00 9.60 - 794
Range 0.186 16.3 5 7,360 400 600 1,120 1,120 2.0 0.40 0.50 0.20 - 17,125
Well Name:3H-37
Water Source:CPF3
Alaska District Field QC
Prejob Water Analysis on Location
Company:
Conoco Phillips
Conoco Phillips - 3H-37 Water Analysis Intervals 06-09 99
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO4
2-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-Crosslink
pH Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank # Hydrometer
Digital
Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
1 1.020 68.8 0 17,580 1,200 1,240 1,120 2,360 25.0 7.00 7.20 9.60 Y 4,650
2 1.018 69.7 5 21,960 800 1,400 1,440 2,840 26.0 6.90 7.50 9.70 Y 2,153
3 1.018 68.4 0 18,930 800 1,360 1,240 2,600 26.0 6.90 7.30 9.60 Y 3,873
4 1.020 73.4 0 21,960 800 1,520 1,000 2,520 25.0 6.90 7.40 9.60 Y 2,095
5 1.018 71.4 5 1,893 1,200 1,360 1,480 2,840 26.0 6.80 7.30 9.50 Y 2,707
6 1.020 69.7 5 21,960 800 1,480 1,120 2,600 25.0 6.80 7.40 9.70 Y 2,078
7 1.020 68.5 0 20,380 800 1,600 1,120 2,720 26.0 6.80 7.20 9.00 Y 12,463
8 1.020 80.4 0 23,680 800 1,520 1,040 2,560 25.0 7.10 7.40 9.70 Y 794
9 1.018 79.8 5 20,380 800 1,480 1,040 2,520 24.0 7.00 7.40 9.60 Y 3,630
10 1.014 75.8 0 16,320 800 1,320 760 2,080 25.0 7.20 7.30 9.70 Y 7,612
11 1.018 81.6 5 21,960 800 1,560 1,120 2,680 25.0 6.90 7.40 9.70 Y 2,561
12 1.018 74.9 0 21,960 1,200 1,640 800 2,440 26.0 7.00 7.30 9.80 Y 1,351
Average 1.019 73.5 2 19,080 900 1,457 1107 2,563 25.3 6.94 7.34 9.60 - 3,831
Maximum 1.020 81.6 5 23,680 1,200 1,640 1,480 2,840 26.0 7.20 7.50 9.80 - 12,463
Minimum 1.014 68.4 0 1,893 800 1,240 760 2,080 24.0 6.80 7.20 9.00 - 794
Range 0.006 13.2 5 21,787 400 400 720 760 2.0 0.40 0.30 0.80 - 11,669
Well Name:3H-37
Water Source:CPF3
Alaska District Field QC
Prejob Water Analysis on Location
Company:
Conoco Phillips
Conoco Phillips - 3H-37 Water Analysis Intervals 10-12 100
Linear XL Linear XL Comments
Interval Stage Visc pH Temp °F pH Interval Stage Visc pH Temp °F pH
1 Minifrac 20 8.7 75.6 9.3 7
Pad 33 9.2 74.5 9.4 Pad 27 9.1 87.9 9.4
1# 28 9.1 72.3 9.7 1#27 8.9 86.4 9.3
2# 27 9.2 72.1 9.5 2#31 9.1 78.6 9.4
.3# 27 9.5 72.1 9.5 3#31 9.1 84.3 9.3
4# 25 9.7 75.3 9.5 4#31 9.2 84.9 9.3
2 Pad 28 9.9 80.2 9.4 8 Pad 25 9.2 86.4 9.5
1# 28 9.7 78.3 9.5 1# 28 9.2 88.5 9.6
2# 27 9.5 75.3 9.2 2# 30 9.4 84.5 9.5
3# 25 9.5 77.6 9.3 3# 27 9.4 90.8 9.6
4# 26 9.5 72.5 9.4 4# 27 9.2 91 9.6
5# 27 9.1 91.3 9.6
6# 25 9.2 86.5 9.6
3 Pad 26 9.6 75.2 9.4 9 Pad 25 9.2 87 9.5
1# 25 9.4 73.9 9.3 1# 25 9.2 84.5 9.5
2# 24 9.4 75.9 9.4 2# 29 9.1 92.9 9.4
3# 23 9.4 86 9.5 3# 30 9.3 94.7 9.4
4# 27 9.4 76.6 9.6 4# 30 9.3 92.1 9.5
5# 28 9.3 82.5 9.5
6# 30 9.5 86.7 9.5
4 Pad 29 9.4 78.9 9.5 10 Pad 26 9 78 9.6
1# 30 9.4 89.2 9.6 1# 30 9.2 93 9.4
2# 27 9.4 78.6 9.5 2# 30 9 88 9.5
3# 27 9.4 77.4 9.4 3# 30 9.2 92.3 9.4
4# 28 9.4 77.3 9.5 4# 31 9.3 81.1 9.4
5# 26 9.3 76.1 9.5 5# 30 9.2 81.6 9.3
6# 25 9.5 74.4 9.6 6# 30 9.2 78.8 9.1
5 Pad 22 9.1 80.4 9.3 11 Pad 26 9.3 81.3 9.4
1# 20 1# 32 9 79.1 9.3
2# 20 9.2 81.4 9.2 2# 30 9.1 78.4 9.3
3# 20 9.2 81.6 9 3# 30 8.9 80.4 9.4
4# 20 9 82.3 9.1 4# 30 9.2 80.7 9.4
5# 20 9.2 85 9.2 5# 27 8.8 80.7 9.4
6# 28 9.4 78 9.4
6 Pad 29 9.3 74.6 9.2 12 Pad 28 9.2 79.3 9.4
1# 31 8.8 87.8 9.3 1# 30 9 75.3 9.4
2# 27 8.6 85.1 9.4 2# 31 9.3 80 9.5
3# 30 9.1 86.3 9.4 3# 30 9.1 87.1 9.5
4# 31 9.2 84.9 9.3 4# 31 9.2 78.8 9.6
5# 28 8.9 75.3 9.3 Skipped 6ppg due to pressure
6#
Customer:ConocoPhillips Alaska, Inc.
Wellname & #:3H-37
Date:
Comments
Fann Issues fluid in good shape
Screened out
Conoco Phillips - 3H-37 Real-Time QC 101
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Pad1 ppg2 ppg 3 ppg4 ppg5 ppg6 ppgStage(s):1Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:ConocoPhillipsProject No:Hydration Visc:Fann tests were run on the 1ppg and the 6ppg stage due to the rapid samples. All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Hydration pH:Temp 0FPHLOSURF-300DCL-31CAT-3SP0000011111102:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg6 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann 15 Zone 1102
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Break Test3H-37Stage(s):Break Test155Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/14/2020ConocoPhillipsProject No:KK.LambeHydration Visc:2570.4All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:7.20Hydration pH:7.40Temp 0FPHLOSURF-300DCL-22 UCCL-31MO-67Optiflo-IIIOptiFlo-II749.701.001.000.500.302.000.25050010001500200025003000350000:00 02:00 04:00 10:00 20:00 30:00 1:00 30:00 00:0030:00Viscosity (cp)Time (min:sec)Prejob Crosslink Break TestsBreak Test 1Break Test 2Break Test 3Fluid is broken at 200cpConoco Phillips - 3H-37Prejob Break Test Day 1103
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Break Test3H-37Stage(s):Break Test155Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/17/2020ConocoPhillipsProject No:KK.LambeHydration Visc:2476.4All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:7.00Hydration pH:7.20Temp 0FPHLOSURF-300DCL-22 UCCL-31MO-67Optiflo-IIIOptiFlo-II809.601.001.000.500.402.000.25020040060080010001200140000:00 02:00 04:00 10:00 20:00 30:00 1:00 30:00 00:0030:00Viscosity (cp)Time (min:sec)Prejob Crosslink Break TestsBreak Test 1Break Test 2Break Test 3Fluid is broken at 200cpConoco Phillips - 3H-37Prejob Break Test Day 2104
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Break Test3H-37Stage(s):Break Test155Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/22/2020ConocoPhillipsProject No:CC.BurkettHydration Visc:2674.3All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:6.90Hydration pH:7.20Temp 0FPHLOSURF-300DCL-22 UCCL-31MO-67Optiflo-IIIOptiFlo-II74.39.601.001.000.500.401.500.2505001000150020002500300000:00 02:00 04:00 10:00 20:00 30:00 1:00 30:00 00:0030:00Viscosity (cp)Time (min:sec)Prejob Crosslink Break TestsBreak Test 1Break Test 2Break Test 3Fluid is broken at 200cpConoco Phillips - 3H-37Prejob Break Test Day 3105
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Break Test3H-37Stage(s):Break Test155Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/24/2020ConocoPhillipsProject No:KK.LambeHydration Visc:2571.2All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:6.90Hydration pH:7.20Temp 0FPHLOSURF-300DCL-22 UCCL-31MO-67Optiflo-IIIOptiFlo-II71.29.501.001.000.500.401.500.250500100015002000250000:00 02:00 04:00 10:00 20:00 30:00 1:00 30:00 00:0030:00Viscosity (cp)Time (min:sec)Prejob Crosslink Break TestsBreak Test 1Break Test 2Break Test 3Fluid is broken at 200cpConoco Phillips - 3H-37Prejob Break Test Day 4106
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):1155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/16/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:05001000150020002500300000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 1107
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):2155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/16/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:050010001500200025003000350000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 2 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 2108
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):3155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/16/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:05001000150020002500300000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 3 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 3109
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):4155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/16/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:0500100015002000250030003500400000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 4 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 4110
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):5155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/18/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:05001000150020002500300035004000450000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 5 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 5111
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):6155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/23/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:0500100015002000250030003500400000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 6 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 6112
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):7155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/23/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:010002000300040005000600000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 7 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 7113
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):8155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/23/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:010002000300040005000600000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 8 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 8114
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):9155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/23/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:0500100015002000250030003500400000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 9 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 9115
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):10155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/24/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:05001000150020002500300035004000450000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 10 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 10 116
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):11155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/24/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:050010001500200025003000350000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 10 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 11117
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @3H-37Stage(s):12155Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:10/24/2020ConocoPhillipsProject No:Hydration Visc:Water pH:Hydration pH:010002000300040005000600000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:0015:00Viscosity (cp)Time (min:sec)Zone 10 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3H-37Fann Test Interval 12118
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 06:28:02 (10/15/20) Start Job Starting Job 0 0 0 0 01 06:28:02 (10/15/20) Next Treatment Treatment Interval 1 0 0 0.01 0 1.031 6:42:00 Next Stage Shut-In 0 14.28 15.97 0 2890.322 9:54:41 Prime Pumps Prime Pumps 0 53.47 60.66 0 2891.833 10:14:55 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 186.77 56.44 0 2890.454 10:47:11 Pressure Test Pressure Test 0 5.13 1.36 0 2890.355 10:49:20 Pressure Test Pressure Test - Globals 0 94.33 86.33 0 2890.346 10:50:10 Pressure Test Pressure Test - Locals 0 350.76 355.39 0 2890.347 10:51:13 Pressure Test Pressure Test - Pop-off Test 0 993.3 1031.870 2890.358 10:55:01 Pressure Test Adjust Pop-Off 0 444.22 417.75 0 2890.349 11:02:48 Drop Ball Pop-off needle Valve 0 1373.71 1412.96 0 2890.3210 11:06:46 Pressure Test Reset Pop-off 0 263.81 245.79 0 2890.311 11:09:24 Pressure Test Check Van connection 0 1445.51 1446.33 0 2890.3112 12:02:59 Pressure Test Simulated Pressure via offset 0 13.09 7.38 02890.2413 12:26:11 Pressure Test Testing ePRV 0 63.53 76.18 0 2890.2314 12:27:09 Pressure Test Pressure Test - Good Pop 0 627.26 571.82 0 2890.2315 12:32:37 Pressure Test Pressure Test - Test Pop 0 1980.49 2000.08 02890.2216 12:35:17 Pressure Test Pressure Test - Pop-off 0 3944.97 3983.97 02890.2217 12:38:21 Pressure Test Backside Pop-off Test 0 2101.91 2153.82 0 2890.2218 12:40:00 Other Kill Equipment 0 98.42 109.41 0 2890.2119 13:43:25 Pause Suspending Job 0 0 0 0 020 05:40:41 (10/16/20) Resume Resuming Job 0 -12.81 5.09 0 2890.1421 6:22:54 Prime Pumps Prime Pumps 0 13.34 37.38 0 2889.5622 6:35:55 Pressure Test Pop-off Test 0 27.27 67.62 0 2889.5423 6:38:24 Pressure Test Pressure Test - Globals 0 118.56 137.39 0 2889.5424 6:39:10 Pressure Test Pressure Test - Locals 0 130.67 149.66 0 2889.5425 6:44:17 Prime Pumps Prime Truck 1 & 2 0 0.44 5.52 0 2889.5326 6:47:29 Prime Pumps Swapping Ports 0 36.73 48.64 0 2889.5427 6:55:13 Prime Pumps Prime Pumps 0 -17.26 -5.64 0 2889.5428 7:09:56 Other Frozen Pump, Check Valves 0 -16.5 41.73 0 2889.4929 8:03:45 Other Pump Repaired 0 -0.06 -6.26 0 2889.4330 8:08:46 Prime Pumps Prime Pumps 0 0.85 -1.53 0 2889.4331 8:15:13 Pressure Test Testing PRV 0 -11.25 35.42 0 2889.4332 8:23:55 Other Pressure Not Building 0 69.28 68.3 0 2889.4233 8:29:45 Prime Pumps RE-Prime Pumps 0 20.58 39.56 0 2889.3934 8:34:07 Pressure Test Pressure Test - Globals 0 66.91 66.54 0 2889.3835 8:35:05 Pressure Test Pressure Test - Locals 0 1040.78 994.5 0 2889.436 8:35:55 Pressure Test Check Pop-Off 0 898.8 875.02 0 2889.437 8:36:17 Pressure Test Pop-off good Test 0 1417.15 932.59 0 2889.438 8:38:46 Pressure Test Reset Pop-Off 0 143.72 72.49 0 2889.3739 8:40:48 Pressure Test Pop-Off Test 0 1326.31 860.72 0 2889.3840 8:43:03 Pressure Test Pressure Test 0 39.07 23.64 0 2889.3841 8:48:59 Pressure Test Pressure Test - Max (9459psi) 0 9459.17 9541.83 0 2889.3742 8:51:59 Pressure Test Good Test, Bleed Down 0 9272.01 9297.61 0 2889.3743 8:53:57 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 46.26 11.7 0 2888.844 9:14:56 Pressure Test Little Red Pressure Test 0 33.73 -3.09 0 2888.8645 9:24:59 Other Load Balls 0 17.62 -7.17 02888.7946 9:34:53 Other Build gel tub 0 13.26 -11.86 02888.8447 10:04:26 Other Good Gel 0 6.01 5.8 02889.548 10:12:31 Open Well Open Well 0 543.43 513.02 02889.714 10:18:56 Next Stage Establish Stable Fluid 3.14 2481.79 2350.91 2.54988.4949 10:24:07 Other Shift Alpha Sleeve 19.49 6413.56 6512.6 6.48556.5350 10:33:10 Other Back to blender Rate 161.32 2938.62 2986.8 8.74386.1351 10:33:51 Other CL-31 injection issue 169.56 4975.98 5097.27 16.7 4961.85 10:39:23 Next Stage Minifrac 261.04 3631.21 3691.37 15.5 4833.016 10:50:57 Next Stage Flush 565.07 6600.53 6710.08 27.1 5519.147 10:59:26 Next Stage Shut-In for FET Analysis 784.69 1766.69 217.76 04295.738 11:29:19 Next Stage Establish Stable Fluid 784.69 471.01 108.23 0 3057.9352 11:29:59 Other Other 784.69 464.8 125.08 0 3051.949 11:33:21 Next Stage Pad 853.81 5574.32 5661.58 27.7 5372.8553 11:40:37 Other Pump Died 1053.8 5016.5 5102.36 21.4 5128.8454 11:49:18 Other Pump Internal Issue 1265.37 6113.24 6249.92 26.4 5447.1110 11:56:10 Next Stage 1.00ppg 20/40 Wanli 1448.39 6468.76 6605.62 27.8 5494.6711 12:08:15 Next Stage 2.00ppg 20/40 Wanli 1776.9 6252.7 6314.08 27.1 5519.8212 12:19:49 Next Stage 3.00ppg 20/40 Wanli 2089.64 6655.35 6825.52 27 5649.5713 12:32:17 Next Stage 4.00ppg 20/40 Wanli 2415.73 6696.73 6791.82 24.9 5709.2555 12:36:09 Other Pump DMP 2512.05 5919.27 6074.34 24.7 5797.2456 12:39:19 Other ball Loaded 2574.45 5490.24 5697 20.5 5664.3714 12:40:02 Next Stage Spacer and Ball Drop 2588.89 5312.23 5391.08 20.7 5684.6557 12:40:43 Drop Ball Drop Ball 2599.96 4362.99 4416.51 15.2 5466.962 12:42:35 (10/16/20) Next Treatment Treatment Interval 2 2627.93 4605.99 4650.88 15 5610.031 12:42:35 Next Stage Pad 2628.18 4564.47 4610.2 15 561058 12:51:15 Ball on Seat Ball on Seat 2804.32 4112.56 4175.54 14.8 6285.959 12:51:22 Break Formation Break Formation 2806.05 7144.04 7218.64 14.8 8378.432 0.546400463 Next Stage 1.00ppg 20/40 Wanli 3223.92 6048.54 6142.03 28.1 5106.1660 13:11:46 Other Caught Air from tanks 3360.82 2059.89 2235.16 15.8 4553.033 13:19:44 Next Stage 2.00ppg 20/40 Wanli 3548.52 6302.81 6412.7 28.5 5169.8761 13:28:49 Other Shifting Rate around 3804.3 6458.07 6541 27.4 5295.264 13:30:48 Next Stage 3.00ppg 20/40 Wanli 3860.45 6799.8 6882.01 28.2 5391.4562 13:31:19 Other Pump Kicked out 3875.01 5606.82 5987.96 28 5389.5563 13:35:28 Other Drop rate for pressure 3982.63 6722.34 6847.17 26.9 5385.775 13:43:34 Next Stage 4.00ppg 20/40 Wanli 4184.56 6247.07 6427.24 24.95497.6864 13:52:04 Other Ball Loaded 4392.75 6429.9 6541.15 23.9 5553.165 13:53:12 Other Pump kicked bad trip amp 4419.81 5160.5 5339.05 20.35303.56 13:53:27 Next Stage Spacer and Ball Drop 4424.75 5165.1 5298.51 19.65377.566 13:54:07 Drop Ball Drop Ball 4434.69 3696.89 3781.51 13.4 5146.193 13:55:37 (10/16/20) Next Treatment Treatment Interval 3 4454.44 4393.63 4474.64 13.2 5253.851 13:55:37 Next Stage Pad 4454.66 4390.62 4474.26 13.2 5251.7567 14:04:12 Drop Ball Drop Ball 4629.32 3478.83 3544.45 12.9 5145.868 14:04:19 Break Formation Break Formation 4631.04 6308.21 6333.75 12.9 7618.352 14:19:21 Next Stage 1.00ppg 20/40 Wanli 5049.72 6220.91 6320.09 29.55019.783 14:30:34 Next Stage 2.00ppg 20/40 Wanli 5378.85 6298.87 6427.85 29.25090.54 14:41:22 Next Stage 3.00ppg 20/40 Wanli 5691.84 6207.25 6383.31 27.55131.155 14:53:29 Next Stage 4.00ppg 20/40 Wanli 6016.94 5904.52 5996.8 25.7 5197.469 14:59:34 Other Load Ball 6174.35 6321.86 6446.57 24.5 5200.786 15:01:28 Next Stage Spacer and Ball Drop 6221.09 6283.64 6406.42 24.8 5227.0470 15:02:27 Drop Ball Drop Ball 6236.93 4561.56 4651.99 15.3 5033.674 15:02:36 (10/16/20) Next Treatment Treatment Interval 4 6239.22 4533.91 4595.75 15.3 5058.521 15:02:36 Next Stage Pad 6239.48 4535.03 4594.4 15.3 5058.4871 15:10:46 Other Ball on Seat 6426.25 3746.71 3801.8 15.1 4876.9772 15:10:53 Break Formation Break Formation 6428.01 6775.77 6803.03 15.1 7478.372 15:17:05 Next Stage 1.00ppg 20/40 Wanli 6596.96 6245.97 6411.23 28.95148.33 15:19:52 Next Stage 2.00ppg 20/40 Wanli 6676.43 6142.42 6227.51 28.65092.664 15:22:51 Next Stage 3.00ppg 20/40 Wanli 6762.49 6038.97 6192.95 28.75082.235 15:27:39 Next Stage 4.00ppg 20/40 Wanli 6897.45 6419.2 6550.32 27.6 5229.236 15:33:34 Next Stage 5.00ppg 20/40 Wanli 7051.16 6167.28 6280.11 24.65325.147 15:39:36 Next Stage 6.00ppg 20/40 Wanli 7195.73 6256.41 6414.49 23.65415.88 15:48:01 Next Stage Flush 7390.05 6593.67 6677.32 23 5336.879 0.663645833 Next Stage Freeze Protect 7559.6 2750.92 2797.52 9.4 4770.2473 0.665717593 ISIP ISIP 7600.32 1523.07 1503.58 0 4523.8974 0.666585648 Shut In Well Shut In Well 7600.32 2087.83 2115.36 0 4477.7975 0.669189815 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes7600.32 25.43 24.31 0 4394.4676 0.672662037 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 7600.32 29.46 27.44 0 4329.9977 0.676111111 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 7600.32 29.43 30.68 0 4282.9778 0.734618056 Pause Suspending Job 7600.32 0 0 0 079 08:00:50 (10/18/20) End Job Ending Job 7600.32 0 0 0 0Event Log Intervals 01-04Conoco Phillips - 3H-37 Event Log Day 1 119
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 08:24:18 (10/18/20) Start Job Starting Job 0 0 0 0 01 08:24:18 (10/18/20) Next Treatment Treatment Interval 1 0 0 0 0 05 08:24:31 (10/18/20) Next Treatment Treatment Interval 5 0 18.24 15.28 0 01 8:24:32 Next Stage Shut-In 0 18.24 15.25 0 02 8:43:27 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 18.02 14.9 0 2852.613 8:50:03 Pressure Test Pressure Test 0 18.11 27.19 0 2852.614 8:50:32 Pressure Test Pressure Test - Globals 0 50.44 85.9 0 2852.615 8:51:57 Pressure Test Pressure Test - Locals 0 407.7 428.17 0 2852.66 8:55:15 Pressure Test Pressure Test - Max 0 9507.04 9633.29 0 2852.67 8:57:03 Pressure Test Pressure Test - Good Test 0 9394.24 9449.15 0 2852.68 8:58:22 Other Mix Gel 0 47.19 27.25 0 2852.599 9:02:06 Other Load Balls 0 38.73 13.29 0 2852.5910 9:12:09 Other Checking 22 chem line 0 37.79 13.48 0 2852.5811 10:04:27 Open Well Open Well 0 566.08 541.94 0 2861.332 10:08:31 Next Stage Establish Stable Fluid 0.26 829.61 883.41 1.3 3264.093 10:13:18 Next Stage Spacer and Ball Drop 63.72 4485.95 4550.56 15 4697.9112 10:14:04 Drop Ball Drop Ball 75.44 5179.9 5266.5 14.9 4746.524 10:14:23 Next Stage Pad 79.9 5227.4 5309.08 14.8 4744.6513 10:22:56 Ball on Seat Ball on Seat 254.82 3707.4 3787.17 14.8 4765.9714 10:23:04 Break Formation Break Formation 256.54 6714.33 6737.69 14.7 7373.415 10:23:27 Other Pump 043 DPM Trip 263.03 4888.94 5001.4 21.5 4649.9916 10:28:00 Other Pump 4 Internal Issue 383.5 5519.71 5790.78 28.4 4707.185 10:30:04 Next Stage 1.00ppg 20/40 Wanli 444.66 6100.61 6179.22 29.8 4815.166 10:32:46 Next Stage 2.00ppg 20/40 Wanli 524.56 6114.95 6212.94 29.6 4797.817 10:35:39 Next Stage 3.00ppg 20/40 Wanli 610.02 6214.18 6300.41 29.6 4877.698 10:40:19 Next Stage 4.00ppg 20/40 Wanli 745.27 6457.17 6549.67 27.7 4987.089 10:46:14 Next Stage 5.00ppg 20/40 Wanli 899.43 6278.18 6348.93 24.5 5300.2717 10:53:17 Other Cut Sand bad gel 1064.09 6445.51 6512.28 21.9 5937.8211 10:55:46 Next Stage Spacer and Ball Drop 1115.96 6853.26 6930.23 20.5 6601.3418 10:55:58 Drop Ball Drop Ball 1120.31 6686.63 6782.31 19.7 6634.236 10:56:28 (10/18/20) Next Treatment Treatment Interval 6 1129.31 6055.71 6096.31 18 6656.061 10:56:28 Next Stage Pad 1129.61 6040.4 6077.85 18 6617.9719 10:57:51 Other Pressure Out 1153.84 6546.52 6607.12 16.3 7728.3720 10:58:00 Other Pressure Release 1156.16 3098.95 3153.55 14.5 4445.7321 10:59:41 Other Screen Out 1178.57 7622.41 7739.37 10.1 8730.0822 11:17:45 Other Bleed off 1180.58 5929.52 5941.47 0 8176.223 11:27:01 Other Flow well back 1180.58 18.15 28.6 0 8139.8824 12:03:47 Other Pump off surface lines 1180.58 12.51 63.51 0 4224.0225 12:25:28 Open Well Open Well 1181.1 579.94 16.02 0 4270.6226 12:27:12 Other Little Red Pump moving fluid 1181.1 866.45 13.26 0 427327 12:43:39 Other Little Red Offline 1181.1 8802.23 27.12 0 8743.4228 13:26:17 Other Bleed Down 1181.1 0.07 14.01 0 8400.7629 13:29:53 Other Blow Down Front Yard 1181.1 0.01 10.47 0 8306.2230 13:56:01 Other Rig down Front Yard for Coil 1181.1 15.44 26.34 0 7549.331 7:23:13 Pause Suspending Job 1181.1 0 0 0 032 7:23:50 End Job Ending Job 1181.1 0 0 0 0Event Log Interval 5Conoco Phillips - 3H-37 Event Log Day 2120
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 13:49:39 (10/22/20) Start Job Starting Job 0 0 0 0 01 13:49:39 (10/22/20) Next Treatment Treatment Interval 1 0 -0.01 -0.01 0 06 13:56:22 (10/22/20) Next Treatment Treatment Interval 6 0 -54.38 -53.03 0 2879.731 13:56:23 Next Stage Shut-In 0 -54.38 -52.97 0 2879.732 14:28:34 Prime Pumps Prime Pumps 0 -47.8 -35.91 0 2879.873 14:47:46 Pressure Test Pressure Test - globals 0 39.14 87.54 0 2879.954 14:48:37 Pressure Test Pressure Test - Local 0 188.61 215.8 0 2879.965 14:49:53 Pressure Test Pressure Test - Pop-Off 0 2315.69 2190.21 0 2879.966 14:51:59 Pressure Test Pressure Test - Low Test 0 5084.68 5066.14 0 2879.977 15:23:09 Pause Suspending Job 0 0 0 0 08 05:19:02 (10/23/20) Resume Resuming Job 0 -0.41 -0.44 0 09 5:53:56 Prime Pumps Prime Pumps 0 0.64 30.42 0 2883.9910 6:25:54 Pressure Test Pressure Test - Globals 0 29.91 65.64 0 2884.1311 6:26:31 Pressure Test Pressure Test - Locals 0 321.42 345.18 0 2884.1412 6:27:27 Pressure Test Pop-Off Test 0 2776.67 2700.34 0 2884.1413 6:28:10 Pressure Test Pressure Test - Reset Pop-Off 0 3176.49 81.94 0 2884.1414 6:29:38 Pressure Test Pressure Test - Low Pressure 0 5284.77 5278.28 0 2884.1515 8:23:49 Pressure Test Pressure Test - High Pressure Test 0 25.95 24.54 0 2884.6616 8:34:47 Other Load Balls 0 13.25 -47.44 0 2884.717 8:45:01 Open Well Open Well 0 835.04 797.53 0 2886.512 8:46:26 Next Stage Establish Stable Fluid 0.65 1023.47 1081.05 3.1 3021.343 8:51:35 Next Stage Spacer and Ball Drop 71.07 4824.41 4815.51 15 5157.1418 8:53:13 Drop Ball Drop Ball 95.55 5153.31 5163.35 15.1 5294.034 8:53:30 Next Stage Pad 100.06 4762.95 4730.67 15 5279.0919 9:02:16 Ball on Seat Ball on Seat 271.51 3842.94 3873.46 14.6 5315.4420 9:02:23 Break Formation Break Formation 273.22 7006.15 6931.6 14.6 7728.925 9:21:00 Next Stage 1.00ppg 20/40 Wanli 694.98 4598.22 4620.62 23 4669.266 9:35:08 Next Stage 2.00ppg 20/40 Wanli 1022.77 4397.81 4426.89 23.4 4740.167 9:44:06 Next Stage 3.00ppg 20/40 Wanli 1230.23 4432.97 4466.07 23.1 4828.6521 9:52:51 Other Customer called stage 1431.64 4688.22 4714.66 23 5086.419 9:53:58 Next Stage Spacer and Ball Drop 1459.2 5267.45 5298.91 25.4 5145.5822 9:56:26 Drop Ball Drop Ball 1509.48 3974.18 3987.32 14.8 5043.527 09:56:33 (10/23/20) Next Treatment Treatment Interval 7 1511.21 3656.96 3655.18 14.8 5031.071 9:56:33 Next Stage Pad 1511.45 3641.29 3640.09 14.8 5030.8723 10:03:44 Ball on Seat Ball on Seat 1671.29 3652.57 3692.35 14.9 5095.5724 10:03:52 Break Formation Break Formation 1673.03 7323.61 7273.39 14.9 7434.852 10:22:47 Next Stage 1.00ppg 20/40 Wanli 2106.78 4187.03 4213.57 23.14408.623 10:37:02 Next Stage 2.00ppg 20/40 Wanli 2434.74 4281.2 4313.16 23.1 4458.044 10:50:28 Next Stage 3.00ppg 20/40 Wanli 2746.32 4250.87 4276.53 23.34515.775 11:04:27 Next Stage 4.00ppg 20/40 Wanli 3071.97 4315.39 4353.08 23.24513.5225 11:11:19 Other ball loaded 3232.16 4915.08 4944.31 23.3 4652.036 11:13:16 Next Stage Spacer and Ball Drop 3277.52 5159.47 5199.39 23.2 4747.2226 11:14:15 Drop Ball Drop Ball 3293.19 3901.57 3917.3 15.4 4666.168 11:14:24 (10/23/20) Next Treatment Treatment Interval 8 3295.5 3594.38 3584.8 15.4 4668.271 11:14:24 Next Stage Pad 3295.76 3586.78 3578.31 15.4 4668.2127 11:21:27 Ball on Seat Ball on Seat 3449.01 3360.62 3373.03 14.7 5026.3828 11:21:33 Break Formation Break Formation 3450.47 6876.27 6819.31 14.77523.332 11:38:32 Next Stage 1.00ppg 20/40 Wanli 3827.91 4301.05 4323.48 22.54474.883 11:42:07 Next Stage 2.00ppg 20/40 Wanli 3907.73 4189.35 4214.67 22.14472.044 11:45:59 Next Stage 3.00ppg 20/40 Wanli 3993.21 4082.99 4109.51 22.24464.5429 11:50:13 Other Pump Bobble 4086.56 4028.63 4143.04 22.24480.315 11:52:06 Next Stage 4.00ppg 20/40 Wanli 4128.17 4176.53 4200.68 22.34525.446 11:59:00 Next Stage 5.00ppg 20/40 Wanli 4282.11 4524.28 4553.47 22.44645.3730 12:00:22 Other Castle Swap 4312.67 4537.3 4572.42 22.5 4647.967 12:05:28 Next Stage 6.00ppg 20/40 Wanli 4426.93 5178.44 5211.36 22.44654.8131 12:07:40 Other Ball loaded 4476.05 5214.38 5245.95 22.4 4685.1132 12:10:24 Other Ice Chunk 4536.96 5647.06 5674.08 22.3 4682.078 12:13:15 Next Stage Spacer and Ball Drop 4600.76 5774.18 5801.59 22.1 4731.9933 12:14:09 Drop Ball Drop Ball 4615.06 4122.51 4131.88 14.7 4606.489 12:14:14 (10/23/20) Next Treatment Treatment Interval 9 4616.3 3966.04 4007.59 14.7 4605.151 12:14:15 Next Stage Pad 4616.54 3868.64 3888.52 14.7 4606.9634 12:20:58 Ball on Seat Ball on Seat 4763.23 3124.12 3150.67 14.9 4525.9435 12:21:07 Break Formation Break Formation 4765.21 6778.74 6764.16 14.8 7389.722 12:37:08 Next Stage 1.00ppg 20/40 Wanli 5149.52 4431.08 4456.29 24.34306.63 12:40:26 Next Stage 2.00ppg 20/40 Wanli 5229.26 4319.43 4349.83 24 4316.754 12:44:00 Next Stage 3.00ppg 20/40 Wanli 5315.16 4205.9 4234.45 24 4328.25 12:49:47 Next Stage 4.00ppg 20/40 Wanli 5454.83 4656.06 4692.65 24 4370.916 12:56:13 Next Stage 5.00ppg 20/40 Wanli 5609.24 5193.68 5226.65 23.94472.987 13:02:18 Next Stage 6.00ppg 20/40 Wanli 5755.01 5930.8 5963.62 24 4511.4836 13:07:57 Other Tuck 01 Died 5889.84 5702.1 5775.72 23.9 4544.898 13:08:42 Next Stage Flush 5903.51 4367.81 4378.63 17.8 4450.219 13:14:13 Next Stage Freeze Protect 6029.39 2485.68 2526.15 13.7 4382.3337 13:16:30 ISIP ISIP 6059.9 1042.28 1071.51 0 4288.9338 13:18:07 Shut In Well Shut In Well 6059.9 1689.15 840.23 0 4187.5139 0.556597222 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 6059.9 -77.42 -38.79 0 4147.840 13:26:29 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 6059.9 -80.4 -30.4 0 4101.9241 13:31:29 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 6059.9 -81.25 -39.58 0 4060.14Event Log Intervals 06-09Conoco Phillips - 3H-37 Event Log Day 3121
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 05:24:06 (10/24/20) Start Job Starting Job 0 0 0 0 01 05:24:06 (10/24/20) Next Treatment Treatment Interval 1 0 -0.01 0 0 02 7:06:40 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 -77.25 3.76 0 02 07:39:54 (10/24/20) Next Treatment Treatment Interval 2 0 -80.6 1.89001 7:40:00 Next Stage Pad 0 -80.69 1.83 0 02 7:40:07 Next Stage 1.00ppg 20/40 Wanli 0 -81.89 2.12 0 03 7:40:10 Next Stage 2.00ppg 20/40 Wanli 0 -80.77 2.19 0 04 7:40:14 Next Stage 3.00ppg 20/40 Wanli 0 -81.19 2.28 0 05 7:40:17 Next Stage 4.00ppg 20/40 Wanli 0 -80.42 2.19 0 06 7:40:19 Next Stage Spacer and Ball Drop 0 -79.19 2.01 0 03 07:40:33 (10/24/20) Next Treatment Treatment Interval 3 0 -81.29 1.98 0 01 7:40:44 Next Stage Pad 0 -80.59 2 0 04 07:41:10 (10/24/20) Next Treatment Treatment Interval 4 0 -80.65 1.96 0 01 7:41:10 Next Stage Pad 0 -80.24 1.95 0 05 07:43:19 (10/24/20) Next Treatment Treatment Interval 5 0 -80.56 1.96 0 01 7:43:36 Next Stage Shut-In 0 -79.96 1.7 0 06 07:44:41 (10/24/20) Next Treatment Treatment Interval 6 0 -81.35 2.07 0 01 7:44:46 Next Stage Shut-In 0 -79.68 2.13 0 010 07:46:30 (10/24/20) Next Treatment Treatment Interval 10 0 -80.841.87 0 01 7:46:30 Next Stage Shut-In 0 -80.65 1.87 0 03 7:47:27 Prime Pumps Prime Pumps 0 -56.28 18.69 0 04 8:04:41 Pressure Test Pressure Test - Globals 0 1.21 65.44 0 05 8:05:52 Pressure Test Pressure Test - Locals 0 2181.27 2191.98 0 06 8:06:22 Pressure Test Test Pop-Off 0 2138.13 2167.58 0 07 8:07:44 Pressure Test Pressure Test 0 2969.69 87.68 0 08 9:01:39 Pressure Test Pressure Test - Max Pressure Test 0 120.08 144.66 0 2892.689 9:06:50 Pressure Test Good Test 0 9250.33 9217.31 0 2892.5910 9:27:10 Open Well Open Well 0 644.77 644.9 0 2894.562 9:29:37 Next Stage Spacer and Ball Drop 0.02 520.1 613.55 0.9 2895.5211 9:32:40 Drop Ball Drop Ball 35.8 5211.06 5249.53 14.3 4057.353 9:32:47 Next Stage Establish Stable Fluid 37.46 4716.01 4756.68 14.34092.824 9:39:12 Next Stage Pad 131.5 4076.96 4123.6 14.7 4390.1912 9:41:48 Ball on Seat Ball on Seat 169.78 3282.78 3319.47 14.8 4366.7713 9:41:55 Break Formation Break Formation 171.5 6746.24 6734.31 14.7 6904.565 10:06:35 Next Stage 1.00ppg 20/40 Wanli 763.73 4537.33 4595.06 24.5 4278.866 10:09:51 Next Stage 2.00ppg 20/40 Wanli 843.58 4434.38 4484.26 24.5 4301.457 10:13:23 Next Stage 3.00ppg 20/40 Wanli 929.58 4251.3 4310.06 24.4 4317.728 10:18:57 Next Stage 4.00ppg 20/40 Wanli 1064.84 4516.74 4576.25 24.34366.049 10:25:20 Next Stage 5.00ppg 20/40 Wanli 1219.9 4876.68 4941.09 24.3 4406.8810 10:31:23 Next Stage 6.00ppg 20/40 Wanli 1366.16 5621.5 5682.87 24.34441.3911 10:38:04 Next Stage Spacer and Ball Drop 1526.5 6273.72 6335.63 22.8 4475.414 10:39:05 Drop Ball Drop Ball 1542.16 4377.21 4431.08 15.1 4409.9611 10:41:13 (10/24/20) Next Treatment Treatment Interval 11 1584.275280.01 5339.1 24.2 4492.461 10:41:13 Next Stage Pad 1584.68 5280.39 5340.12 24.2 4492.615 10:45:23 Ball on Seat Ball on Seat 1671.76 3173.54 3233.44 15.5 4375.7116 10:45:24 Break Formation Break Formation 1671.76 3174.89 3234.57 15.5 5080.532 11:02:08 Next Stage 1.00ppg 20/40 Wanli 2068.73 4440.5 4498.89 24.44568.23 11:05:26 Next Stage 2.00ppg 20/40 Wanli 2147.86 4443.51 4495.47 24.14580.284 11:08:59 Next Stage 3.00ppg 20/40 Wanli 2233.7 4299.88 4357.6 244599.365 11:14:38 Next Stage 4.00ppg 20/40 Wanli 2368.88 4324.6 4380.58 244638.836 11:21:05 Next Stage 5.00ppg 20/40 Wanli 2524.16 4702.65 4756.22 23.94676.737 11:27:14 Next Stage 6.00ppg 20/40 Wanli 2671.26 5408.95 5459.73 244709.828 11:33:57 Next Stage Spacer and Ball Drop 2831.34 6380.06 6422.87 23.94755.6117 11:34:56 Drop Ball Drop Ball 2847.65 4485.26 4531.72 15.4 4696.5712 11:35:08 (10/24/20) Next Treatment Treatment Interval 12 2850.483587.8 3605.28 15.4 4667.021 11:35:08 Next Stage Pad 2850.74 3583.86 3592.02 15.4 4667.0118 11:40:35 Ball on Seat Ball on Seat 2969.72 3410.53 3472.67 15 4752.1919 11:40:40 Break Formation Break Formation 2970.96 7018.44 6998.61 14.9 6963.782 11:57:28 Next Stage 1.00ppg 20/40 Wanli 3382.55 5003.84 5056.33 25 4602.373 12:00:34 Next Stage 2.00ppg 20/40 Wanli 3461.66 4824.47 4869.86 25.44549.684 12:03:56 Next Stage 3.00ppg 20/40 Wanli 3546.72 4769.3 4819.84 25 4559.3620 12:06:29 Other Castle Swap 3610.86 4834.3 4891.27 25 4559.7521 12:07:29 Other Frozen sand chunks 3636.02 4931.52 4985.81 25 4587.345 12:09:15 Next Stage 4.00ppg 20/40 Wanli 3680.55 5038.56 5088.2 25.1 4623.36 12:15:28 Next Stage 5.00ppg 20/40 Wanli 3836.61 5827 5869.22 25.1 4784.0722 12:23:53 Other Customer Called Flush 4043.48 6198.52 6254.08 24 5043.738 12:25:37 Next Stage Flush 4084.87 6006.25 6050.04 24.1 5112.69 12:30:20 Next Stage Freeze Protect 4184.48 3642.04 3693.55 13.5 5098.4723 12:32:20 ISIP ISIP 4209.6 2175.74 1723.63 0 5029.8624 12:34:00 Shut In Well Shut In Well 4209.6 2384.48 1877.47 0 4754.9125 12:37:19 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 4209.6 -71.25 -7.16 0 4396.3426 12:42:19 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 4209.6 -66.1 -5.47 0 4119.4427 12:47:20 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 4209.6 -70.17 -5.03 0 4066.29Event Log Intervals 10-12Conoco Phillips - 3H-37 Event Log Day 4122
Hydraulic Fracturing Fluid Product Component Information Disclosure
10/24/2020
Alaska
Harrison Bay
5010320822
CONOCOPHILLIPS
NORTH SLOPE -
EBUS
3H-37
-150.0109514
70.41205042
NAD27
none
Oil
5,992
745,848
Hydraulic Fracturing Fluid Composition:
Trade Name Supplier Purpose Ingredients
Chemical
Abstract
Service
Number (CAS
#)
Maximum Ingredient
Concentration in Additive
(% by mass)**
Maximum
Ingredient
Concentration in
HF Fluid (% by
mass)**
Ingredient Mass
lbs Comments Company First Name Last Name Email Phone
Sea Water Operator Base Fluid Water 7732-18-5 96.00% 80.52779% 6071780 Density = 8.480
CL-22 UC Halliburton Crosslinker Listed Below Listed Below 0 NA
CL-31
CROSSLINKER Halliburton Crosslinker Listed Below Listed Below 0 NA
LOSURF-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0 NA
MO-67 Halliburton pH Control Additive Listed Below Listed Below 0 NA
OPTIFLO-II
DELAYED
RELEASE
BREAKER
Halliburton Breaker Listed Below Listed Below 0 NA
OPTIFLO-III
DELAYED
RELEASE
BREAKER
Halliburton Breaker Listed Below Listed Below 0 NA
SP BREAKER Halliburton Breaker Listed Below Listed Below 0 NA
WG-36 GELLING
AGENT Halliburton Gelling Agent Listed Below Listed Below 0 NA
LVT 200 Pencro Freeze Protect Listed Below Listed Below 0 NA
Wanli 20/40
Wanli
Proppant
Company
Proppant Listed Below Listed Below 0 NA
Ingredients Listed Above Listed Above 1,2,4 Trimethylbenzene 95-63-6
1.00% 0.00077% 58
Acrylate polymer Proprietary
1.00% 0.00114% 86
Denise Tuck,
Halliburton, 3000 N.
Sam Houston Pkwy
E., Houston, TX
77032, 281-871-
6226
Halliburton Denise Tuck
Denise.Tuck@
Halliburton.co
m
281-871-6226
Ammonium persulfate 7727-54-0
100.00% 0.01816% 1369
Borate salts Proprietary
60.00% 0.06826% 5147 Halliburton Denise Tuck
Denise.Tuck@
Halliburton.co
m
281-871-6226
Corundum 1302-74-5 65.00% 9.69924% 731321
Crystalline silica, quartz 14808-60-7 30.00% 0.00525% 396
Cured acrylic resin Proprietary
30.00% 0.00545% 411 Halliburton Denise Tuck
Denise.Tuck@
Halliburton.co
m
281-871-6226
Ethanol 64-17-5
60.00% 0.04608% 3475
Guar gum 9000-30-0
100.00% 0.27524% 20753
Heavy aromatic petroleum naphtha 64742-94-5
30.00% 0.02304% 1738
Hydrotreated Distillate, light 64742-47-8
100.00% 0.61496% 46368
Mullite 1302-93-8 45.00% 6.71486% 506300
Naphthalene 91-20-3
5.00% 0.00384% 290
Oxylated phenolic resin Proprietary
30.00% 0.03072% 2318 Halliburton Denise Tuck
Denise.Tuck@
Halliburton.co
m
281-871-6226
Poly(oxy-1,2-ethanediyl), alpha-(4-
nonylphenyl)-omega-hydroxy-,
branched
127087-87-0 5.00% 0.00384% 290
Potassium formate 590-29-4
60.00% 0.06826% 5147
Potassium hydroxide 1310-58-3
5.00% 0.00275% 208
Potassium metaborate 13709-94-9
60.00% 0.03299% 2488
Sodium carboxymethyl cellulose 9004-32-4
1.00% 0.00114% 86
Sodium chloride 7647-14-5
4.00% 3.35687% 253108
Sodium glycollate 2836-32-0
1.00% 0.00114% 86
Sodium hydroxide 1310-73-2
30.00% 0.01225% 924
Sodium persulfate 7775-27-1
100.00% 0.00023% 17
Sodium sulfate 7757-82-6
0.10% 0.00000% 1
Water 7732-18-5
100.00% 0.10796% 8142
* Total Water Volume sources may include fresh water, produced water, and/or recycled water _
** Information is based on the maximum potential for concentration and thus the total may be over 100%
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.
v3.3
Fracture Date
State:
County:
API Number:
Operator Name:
Well Name and Number:
Total Water Volume (gal)*:
MSDS and Non-MSDS Ingredients are listed below the green line
All component information listed was obtained from the supplier’s Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier
who provided it. The Occupational Safety and Health Administration’s (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how
this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D.
Longitude:
Latitude:
Long/Lat Projection:
Indian/Federal:
Production Type:
True Vertical Depth (TVD):
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By Samantha Carlisle at 10:52 am, Aug 27, 2020
320-359
Digitally signed by Scott Pessetto
DN: C=US, OU=Drilling and Wells, O=ConocoPhillips, CN=Scott Pessetto, E=scott.t.pessetto@conocophillips.com
Reason: I am the author of this document
Location: Anchorage
Date: 2020-08-17 14:10:16
Foxit PhantomPDF Version: 10.0.0
Scott Pessetto
DSR-8/27/2020
x
DLB 09/01/2020
CDW 9/1/2020
X 10-404
VTL 9/3/20
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9/3/2020
dts 9/3/2020 JLC 9/3/2020
RBDMS HEW 9/8/2020
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CUSTOMERConoco Phillips AlaskaFALSEAPIBFD (lb/gal)8.54LAT 70.3136LEASE3H-37SALES ORDERBHST (°F)LONG-151.223FORMATIONKuparuk A-SandDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval LoSurf-300D MO-67 CL-22 UC CL-31 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeSurfactant Buffer Crosslinker Crosslinker Freeze Protect Gel Biocide Breaker Breaker BreakerInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In2:14:25 1-2 Freeze Protect Prime Pumps 2 2,100 50 50 0:25:00 2:14:25 1000.001-3 Shut-In Shut-In1:49:25 1-4 #30 HyborG Establish Stable Fluid 5 4,200 100 100 0:20:00 1:49:25 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.251-5 #30 HyborG Minifrac 30 21,000 500 500 0:16:40 1:29:25 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.251-6 #30 WaterFrac G Flush 30 12,000 286 286 0:09:31 1:12:45 1.00 30.00 0.15 2.00 0.251-7 Shut-In Shut-In1:03:13 1-8 #30 HyborG Establish Stable Fluid 30 4,200 100 100 0:03:20 1:03:13 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.251-9 #30 HyborG Pad 30 25,000 595 595 0:19:50 0:59:53 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.251-10 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 13,200 314 329 13,200 0:10:57 0:40:03 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.251-11 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 12,000 286 312 24,000 0:10:24 0:29:06 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.251-12 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 12,000 286 325 36,000 0:10:50 0:18:42 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.251-13 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 6,700 160 189 26,800 0:06:17 0:07:52 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.251-14 #30 HyborG Spacer and Ball Drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.252-1 #30 HyborG Pad 30 24,000 571 571 0:19:03 0:59:06 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.252-2 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 13,200 314 329 13,200 0:10:57 0:40:03 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.252-3 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 12,000 286 312 24,000 0:10:24 0:29:06 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.252-4 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 12,000 286 325 36,000 0:10:50 0:18:42 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.252-5 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 6,700 160 189 26,800 0:06:17 0:07:52 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.252-6 #30 HyborG Spacer and Ball Drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.253-1 #30 HyborG Pad 30 25,000 595 595 0:19:50 0:59:53 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.253-2 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 13,200 314 329 13,200 0:10:57 0:40:03 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.253-3 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 12,000 286 312 24,000 0:10:24 0:29:06 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.253-4 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 12,000 286 325 36,000 0:10:50 0:18:42 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.253-5 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 6,700 160 189 26,800 0:06:17 0:07:52 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.253-6 #30 HyborG Spacer and Ball Drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.254-1 #30 HyborG Pad 30 15,000 357 357 0:11:54 0:38:18 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.254-2 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 3,200 76 80 3,200 0:02:39 0:26:24 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.254-3 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 3,300 79 86 6,600 0:02:51 0:23:44 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.254-4 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 5,000 119 135 15,000 0:04:31 0:20:53 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.254-5 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 5,500 131 155 22,000 0:05:10 0:16:22 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.254-6 #30 HyborG Proppant Laden Fluid Wanli 20/40 5.00 30 5,000 119 146 25,000 0:04:52 0:11:13 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.254-7 #30 HyborG Proppant Laden Fluid Wanli 20/40 6.00 30 4,700 112 143 28,200 0:04:45 0:06:20 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.254-8 #30 HyborG Spacer 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.255-1 #30 HyborG Pad 30 15,000 357 357 0:11:54 0:38:18 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.255-2 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 3,200 76 80 3,200 0:02:39 0:26:24 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.255-3 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 3,300 79 86 6,600 0:02:51 0:23:44 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.255-4 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 5,000 119 135 15,000 0:04:31 0:20:53 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.255-5 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 5,500 131 155 22,000 0:05:10 0:16:22 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.255-6 #30 HyborG Proppant Laden Fluid Wanli 20/40 5.00 30 5,000 119 146 25,000 0:04:52 0:11:13 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.255-7 #30 HyborG Proppant Laden Fluid Wanli 20/40 6.00 30 4,700 112 143 28,200 0:04:45 0:06:20 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.255-8 #30 HyborG Spacer 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.256-1 #30 HyborG Pad 30 15,000 357 357 0:11:54 1:02:33 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.256-2 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 3,200 76 80 3,200 0:02:39 0:50:39 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.256-3 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 3,300 79 86 6,600 0:02:51 0:47:59 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.256-4 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 5,000 119 135 15,000 0:04:31 0:45:08 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.256-5 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 5,500 131 155 22,000 0:05:10 0:40:37 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.256-6 #30 HyborG Proppant Laden Fluid Wanli 20/40 5.00 30 5,000 119 146 25,000 0:04:52 0:35:27 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.25 0.256-7 #30 HyborG Proppant Laden Fluid Wanli 20/40 6.00 30 4,700 112 143 28,200 0:04:45 0:30:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.25 0.256-8 #30 HyborG Flush 30 10,500 250 250 0:08:20 0:25:50 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.25 0.506-9 Freeze Protect Freeze Protect 2 1,470 35 35 0:17:30 0:17:30 1000.006-10 Shut-In Shut-In-Liquid AdditivesDry AdditivesInterval 1@ - ft - °FInterval 2@ - ft - °FInterval 3@ - ft - °FInterval 4@ - ft - °FInterval 5@ - ft - °FInterval 6@ - ft - °FConoco Phillips Alaska - 3H-37Planned Design1
CUSTOMERConoco Phillips AlaskaFALSEAPIBFD (lb/gal)8.54LAT 70.3136LEASE3H-37SALES ORDERBHST (°F)LONG-151.223FORMATIONKuparuk A-SandDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval LoSurf-300D MO-67 CL-22 UC CL-31 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeSurfactant Buffer Crosslinker Crosslinker Freeze Protect Gel Biocide Breaker Breaker BreakerInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) (ppt)-Liquid AdditivesDry Additives7-1 Shut-In Shut-In0:42:26 7-2 #30 HyborG Establish Stable Fluid 30 4,200 100 100 0:03:20 0:42:26 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.257-3 #30 HyborG Spacer and Ball Drop 30 1,000 24 24 0:00:48 0:39:06 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.257-4 #30 HyborG Pad 30 15,000 357 357 0:11:54 0:38:18 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.257-5 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 3,200 76 80 3,200 0:02:39 0:26:24 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.257-6 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 3,300 79 86 6,600 0:02:51 0:23:44 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.257-7 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 5,000 119 135 15,000 0:04:31 0:20:53 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.257-8 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 5,500 131 155 22,000 0:05:10 0:16:22 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.257-9 #30 HyborG Proppant Laden Fluid Wanli 20/40 5.00 30 5,000 119 146 25,000 0:04:52 0:11:13 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.257-10 #30 HyborG Proppant Laden Fluid Wanli 20/40 6.00 30 4,700 112 143 28,200 0:04:45 0:06:20 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.257-11 #30 HyborG Spacer and Ball Drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.258-1 #30 HyborG Pad 30 15,000 357 357 0:11:54 0:38:18 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.258-2 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 3,200 76 80 3,200 0:02:39 0:26:24 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.258-3 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 3,300 79 86 6,600 0:02:51 0:23:44 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.258-4 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 5,000 119 135 15,000 0:04:31 0:20:53 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.258-5 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 5,500 131 155 22,000 0:05:10 0:16:22 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.258-6 #30 HyborG Proppant Laden Fluid Wanli 20/40 5.00 30 5,000 119 146 25,000 0:04:52 0:11:13 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.258-7 #30 HyborG Proppant Laden Fluid Wanli 20/40 6.00 30 4,700 112 143 28,200 0:04:45 0:06:20 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.258-8 #30 HyborG Spacer and Ball Drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.259-1 #30 HyborG Pad 30 15,000 357 357 0:11:54 0:38:18 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.259-2 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 3,200 76 80 3,200 0:02:39 0:26:24 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.259-3 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 3,300 79 86 6,600 0:02:51 0:23:44 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.259-4 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 5,000 119 135 15,000 0:04:31 0:20:53 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.259-5 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 5,500 131 155 22,000 0:05:10 0:16:22 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.259-6 #30 HyborG Proppant Laden Fluid Wanli 20/40 5.00 30 5,000 119 146 25,000 0:04:52 0:11:13 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.259-7 #30 HyborG Proppant Laden Fluid Wanli 20/40 6.00 30 4,700 112 143 28,200 0:04:45 0:06:20 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.259-8 #30 HyborG Spacer and Ball Drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2510-1 #30 HyborG Pad 30 15,000 357 357 0:11:54 0:38:18 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2510-2 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 3,200 76 80 3,200 0:02:39 0:26:24 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2510-3 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 3,300 79 86 6,600 0:02:51 0:23:44 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2510-4 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 5,000 119 135 15,000 0:04:31 0:20:53 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2510-5 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 5,500 131 155 22,000 0:05:10 0:16:22 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2510-6 #30 HyborG Proppant Laden Fluid Wanli 20/40 5.00 30 5,000 119 146 25,000 0:04:52 0:11:13 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2510-7 #30 HyborG Proppant Laden Fluid Wanli 20/40 6.00 30 4,700 112 143 28,200 0:04:45 0:06:20 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2510-8 #30 HyborG Spacer and Ball Drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2511-1 #30 HyborG Pad 30 15,000 357 357 0:11:54 0:38:18 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2511-2 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 3,200 76 80 3,200 0:02:39 0:26:24 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2511-3 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 3,300 79 86 6,600 0:02:51 0:23:44 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2511-4 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 5,000 119 135 15,000 0:04:31 0:20:53 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2511-5 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 5,500 131 155 22,000 0:05:10 0:16:22 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2511-6 #30 HyborG Proppant Laden Fluid Wanli 20/40 5.00 30 5,000 119 146 25,000 0:04:52 0:11:13 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2511-7 #30 HyborG Proppant Laden Fluid Wanli 20/40 6.00 30 4,700 112 143 28,200 0:04:45 0:06:20 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2511-8 #30 HyborG Spacer and Ball Drop 15 1,000 24 24 0:01:35 0:01:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2512-1 #30 HyborG Pad 30 15,000 357 357 0:11:54 1:02:33 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2512-2 #30 HyborG Proppant Laden Fluid Wanli 20/40 1.00 30 3,200 76 80 3,200 0:02:39 0:50:39 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2512-3 #30 HyborG Proppant Laden Fluid Wanli 20/40 2.00 30 3,300 79 86 6,600 0:02:51 0:47:59 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2512-4 #30 HyborG Proppant Laden Fluid Wanli 20/40 3.00 30 5,000 119 135 15,000 0:04:31 0:45:08 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2512-5 #30 HyborG Proppant Laden Fluid Wanli 20/40 4.00 30 5,500 131 155 22,000 0:05:10 0:40:37 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.2512-6 #30 HyborG Proppant Laden Fluid Wanli 20/40 5.00 30 5,000 119 146 25,000 0:04:52 0:35:27 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.25 0.2512-7 #30 HyborG Proppant Laden Fluid Wanli 20/40 6.00 30 4,700 112 143 28,200 0:04:45 0:30:35 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.25 0.2512-8 #30 HyborG Flush 30 10,500 250 250 0:08:20 0:25:50 1.00 1.00 1.00 0.50 30.00 0.15 2.00 0.25 0.5012-9 Freeze Protect Freeze Protect 2 1,470 35 35 0:17:30 0:17:30 1000.0012-10 Shut-In Shut-In663,640 15,801 17,104 1,200,000Design Total (gal)Design Total (lbs)LoSurf-300D MO-67 CL-22 UC CL-31 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP 1,200,000(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs) (lbs)- Initial Design Material Volume 658.6 646.6 646.6 323.3 5,040.0 19,758.0 98.8 1,317.2 164.7 15.4646,600-Add 30% 856.18 840.58 840.58 420.29 6552 25685.4 128.427 1712.36 214.04519.95512,000-5,040-LoSurf-300D MO-67 CL-22 UC CL-31 LVT-200 WG-36 BE-6 OptiFlo-III OptiFlo-II SP -(gpm) (gpm) (gpm) (gpm) (gpm) ppm ppm ppm ppm ppm-Max Additive Rate 1.3 1.3 1.3 0.6 1,260.0 37.8 0.2 2.5 0.3 0.6-Min Additive Rate-Fluid TypeSea WaterTreated Water#30 HyborG#30 WaterFrac GFreeze Protect----Proppant TypeWanli 20/40----Interval 12@ - ft - °FInterval 9@ - ft - °FInterval 10@ - ft - °FInterval 11@ - ft - °FInterval 7@ - ft - °FInterval 8@ - ft - °F10:50:44 Conoco Phillips Alaska - 3H-37Planned Design2
Hydraulic Fracturing Fluid Product Component Information Disclosure
Alaska
Harrison Bay
CONOCOPHILLIPS
NORTH SLOPE -
EBUS
NAD27
none
Oil
5,900
Hydraulic Fracturing Fluid Composition:
Trade Name Supplier Purpose Ingredients
Chemical
Abstract
Service
Number (CAS
#)
Maximum Ingredient
Concentration in Additive
(% by mass)**
Maximum
Ingredient
Concentration in
HF Fluid (% by
mass)**
Ingredient Mass
lbs Comments Company First Name Last Name Email Phone
Sea Water Operator Base Fluid Water 7732-18-5
96.00% 78.51406% 7321203 Density = 8.490
BE-6
MICROBIOCIDE Halliburton Biocide Listed Below Listed Below 0 NA
CL-22 UC Halliburton Crosslinker Listed Below Listed Below 0 NA
CL-31
CROSSLINKER Halliburton Crosslinker Listed Below Listed Below 0 NA
LOSURF-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0 NA
MO-67 Halliburton pH Control Additive Listed Below Listed Below 0 NA
OPTIFLO-II
DELAYED
RELEASE
BREAKER
Halliburton Breaker Listed Below Listed Below 0 NA
OPTIFLO-III
DELAYED
RELEASE
BREAKER
Halliburton Breaker Listed Below Listed Below 0 NA
SP BREAKER Halliburton Breaker Listed Below Listed Below 0 NA
WG-36 GELLING
AGENT Halliburton Gelling Agent Listed Below Listed Below 0 NA
LVT-200 Penreco Freeze Protect Listed Below Listed Below 0 NA
Wanli 20/40
Wanli
Proppant
Company
Additive Listed Below Listed Below 0 NA
Ingredients Listed Above Listed Above 1,2,4 Trimethylbenzene 95-63-6 1.00% 0.00072% 68
2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00% 0.00145% 135
Acrylate polymer Proprietary 1.00% 0.00109% 102
Denise Tuck,
Halliburton, 3000
N. Sam Houston
Pkwy E., Houston,
TX 77032, 281-
871-6226
Halliburton Denise Tuck
Denise.Tuck@
Halliburton.co
m
281-871-6226
Ammonium persulfate 7727-54-0 100.00% 0.02168% 2022
Borate salts Proprietary
60.00% 0.06563% 6120 Halliburton Denise Tuck
Denise.Tuck@
Halliburton.co
m
281-871-6226
Corundum 1302-74-5
65.00% 11.15317% 1040000
Crystalline silica, quartz 14808-60-7
30.00% 0.00613% 574
Cured acrylic resin Proprietary
30.00% 0.00651% 608 Halliburton Denise Tuck
Denise.Tuck@
Halliburton.co
m
281-871-6226
Ethanol 64-17-5 60.00% 0.04345% 4052
Guar gum 9000-30-0 100.00% 0.28900% 26948
Heavy aromatic petroleum naphtha 64742-94-5 30.00% 0.02173% 2026
Hydrotreated Distillate, light 64742-47-8 100.00% 0.46145% 43029
Mullite 1302-93-8 45.00% 7.72143% 720000
Naphthalene 91-20-3 5.00% 0.00362% 338
Oxylated phenolic resin Proprietary
30.00% 0.02897% 2702 Halliburton Denise Tuck
Denise.Tuck@
Halliburton.co
m
281-871-6226
Poly(oxy-1,2-ethanediyl), alpha-(4-
nonylphenyl)-omega-hydroxy-,
branched
127087-87-0 5.00% 0.00362% 338
Potassium formate 590-29-4 60.00% 0.06563% 6120
Potassium hydroxide 1310-58-3 5.00% 0.00254% 237
Potassium metaborate 13709-94-9 60.00% 0.03047% 2841
Sodium carboxymethyl cellulose 9004-32-4 1.00% 0.00109% 102
Sodium chloride 7647-14-5 4.00% 3.27301% 305200
Sodium glycollate 2836-32-0 1.00% 0.00109% 102
Sodium hydroxide 1310-73-2 30.00% 0.01483% 1383
Sodium persulfate 7775-27-1 100.00% 0.00021% 20
Sodium sulfate 7757-82-6 0.10% 0.00000% 1
Water 7732-18-5 100.00% 0.11271% 10511
* Total Water Volume sources may include fresh water, produced water, and/or recycled water _
** Information is based on the maximum potential for concentration and thus the total may be over 100%
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.
v3.3
Fracture Date
State:
County:
API Number:
Operator Name:
Well Name and Number:
Total Water Volume (gal)*:
MSDS and Non-MSDS Ingredients are listed below the green line
All component information listed was obtained from the supplier’s Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier
who provided it. The Occupational Safety and Health Administration’s (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how
this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D.
Longitude:
Latitude:
Long/Lat Projection:
Indian/Federal:
Production Type:
True Vertical Depth (TVD):
658,600
3H-37
70.31
-151.2
5010320822
2020-09-15
658,600
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DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20822-00-00Well Name/No. KUPARUK RIV UNIT 3H-37Completion Status1-OILCompletion Date4/18/2020Permit to Drill2191940Operator ConocoPhillips Alaska, Inc.MD20296TVD5992Current Status1-OIL8/13/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/ResNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF4/30/2020 Electronic File: 3H-37 EOW - NAD27.pdf32980EDDigital DataDF4/30/2020 Electronic File: 3H-37 EOW - NAD27.txt32980EDDigital DataDF4/30/2020 Electronic File: 3H-37 EOW - NAD83.pdf32980EDDigital DataDF4/30/2020 Electronic File: 3H-37 EOW - NAD83.txt32980EDDigital Data0 0 2191940 KUPARUK RIV UNIT 3H-37 LOG HEADERS32980LogLog Header ScansLog5/8/2020148 20296 Electronic Data Set, Filename: 3H-37 Drilling Mechanics Depth Data.las33001EDDigital DataDF5/8/2020119 3629 Electronic Data Set, Filename: 3H-37 13.5 Inch Section OTK Memory FE Drilling Data.las33001EDDigital DataDF5/8/202013981 20296 Electronic Data Set, Filename: 3H-37 6.75 Inch Section OTK Memory FE Drilling Data.las33001EDDigital DataDF5/8/20203620 14043 Electronic Data Set, Filename: 3H-37 9.875 Inch Section OTK Memory FE Drilling Data.las33001EDDigital DataDF5/8/2020147 20296 Electronic Data Set, Filename: 3H-37 Memory FE Drilling Data.las33001EDDigital DataDF5/8/2020145 3629 Electronic Data Set, Filename: 3H-37 13.5 Inch Section OTK Realtime FE Drilling Data.las33001EDDigital DataDF5/8/202013982 20296 Electronic Data Set, Filename: 3H-37 6.75 Inch Section OTK Realtime FE Drilling Data.las33001EDDigital DataDF5/8/20203584 14044 Electronic Data Set, Filename: 3H-37 9.875 Inch Section OTK Realtime FE Drilling Data.las33001EDDigital DataDF5/8/2020148 20296 Electronic Data Set, Filename: 3H-37 Composite Realtime FE Drilling Data.las33001EDDigital DataThursday, August 13, 2020AOGCCPage 1 of 53H-37 Memory FE Drilling Data.las
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20822-00-00Well Name/No. KUPARUK RIV UNIT 3H-37Completion Status1-OILCompletion Date4/18/2020Permit to Drill2191940Operator ConocoPhillips Alaska, Inc.MD20296TVD5992Current Status1-OIL8/13/2020UICNoDF5/8/2020 Electronic File: VSS_DEPTH_MEM_ConocoPhillips_3H-37.cgm33001EDDigital DataDF5/8/2020 Electronic File: FE_LTK_MD2MEM_ConocoPhillips_3H-37.cgm33001EDDigital DataDF5/8/2020 Electronic File: FE_LTK_MD5MEM_ConocoPhillips_3H-37.cgm33001EDDigital DataDF5/8/2020 Electronic File: FE_LTK_TVD2MEM_ConocoPhillips_3H-37.cgm33001EDDigital DataDF5/8/2020 Electronic File: FE_LTK_TVD5MEM_ConocoPhillips_3H-37.cgm33001EDDigital DataDF5/8/2020 Electronic File: FE_OTK_MD2MEM_ConocoPhillips_3H-37.cgm33001EDDigital DataDF5/8/2020 Electronic File: FE_OTK_MD5MEM_ConocoPhillips_3H-37.cgm33001EDDigital DataDF5/8/2020 Electronic File: FE_OTK_TVD2MEM_ConocoPhillips_3H-37.cgm33001EDDigital DataDF5/8/2020 Electronic File: FE_OTK_TVD5MEM_ConocoPhillips_3H-37.cgm33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_2MD_RLT Log 146-20296.cgm33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_2TVD_RLT Log 146-5992.cgm33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_5MD_RLT Log 146-20296.cgm33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_5TVD_RLT Log 146-5992.cgm33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_VSS_RLT_Time Log_Run 1.cgm33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_VSS_RLT_Time Log_Run 2.cgm33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_VSS_RLT_Time Log_Run 3.cgm33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_VSS_RLT_Time Log_Run 4.cgm33001EDDigital DataDF5/8/2020 Electronic File: VSS_TIME_MEM_ConocoPhillips_3H-37.cgm33001EDDigital DataThursday, August 13, 2020AOGCCPage 2 of 5
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20822-00-00Well Name/No. KUPARUK RIV UNIT 3H-37Completion Status1-OILCompletion Date4/18/2020Permit to Drill2191940Operator ConocoPhillips Alaska, Inc.MD20296TVD5992Current Status1-OIL8/13/2020UICNoDF5/8/2020 Electronic File: 3H-37 13.5 Inch Section OTK Memory FE Drilling Data.dls33001EDDigital DataDF5/8/2020 Electronic File: 3H-37 6.75 Inch Section OTK Memory FE Drilling Data.dls33001EDDigital DataDF5/8/2020 Electronic File: 3H-37 9.875 Inch Section OTK Memory FE Drilling Data.dls33001EDDigital DataDF5/8/2020 Electronic File: 3H-37 OTK Memory FE Drilling Data.dls33001EDDigital DataDF5/8/2020 Electronic File: 3H-37 13.5 Inch Section OTK Realtime FE Drilling Data.dls33001EDDigital DataDF5/8/2020 Electronic File: 3H-37 6.75 Inch Section OTK Realtime FE Drilling Dat.dls33001EDDigital DataDF5/8/2020 Electronic File: 3H-37 9.875 Inch Section OTK Realtime FE Drilling Data.dls33001EDDigital DataDF5/8/2020 Electronic File: 3H-37 Composite Realtime FE Drilling Data.dls33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_BH_EOW_Letter.pdf33001EDDigital DataDF5/8/2020 Electronic File: VSS_DEPTH_MEM_ConocoPhillips_3H-37.pdf33001EDDigital DataDF5/8/2020 Electronic File: FE_LTK_MD2MEM_ConocoPhillips_3H-37.pdf33001EDDigital DataDF5/8/2020 Electronic File: FE_LTK_MD5MEM_ConocoPhillips_3H-37.pdf33001EDDigital DataDF5/8/2020 Electronic File: FE_LTK_TVD2MEM_ConocoPhillips_3H-37.pdf33001EDDigital DataDF5/8/2020 Electronic File: FE_LTK_TVD5MEM_ConocoPhillips_3H-37.pdf33001EDDigital DataDF5/8/2020 Electronic File: FE_OTK_MD2MEM_ConocoPhillips_3H-37.pdf33001EDDigital DataDF5/8/2020 Electronic File: FE_OTK_MD5MEM_ConocoPhillips_3H-37.pdf33001EDDigital DataDF5/8/2020 Electronic File: FE_OTK_TVD2MEM_ConocoPhillips_3H-37.pdf33001EDDigital DataDF5/8/2020 Electronic File: FE_OTK_TVD5MEM_ConocoPhillips_3H-37.pdf33001EDDigital DataThursday, August 13, 2020AOGCCPage 3 of 5
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20822-00-00Well Name/No. KUPARUK RIV UNIT 3H-37Completion Status1-OILCompletion Date4/18/2020Permit to Drill2191940Operator ConocoPhillips Alaska, Inc.MD20296TVD5992Current Status1-OIL8/13/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NADF5/8/2020 Electronic File: 3H-37_2MD_RLT Log 147-20296.pdf33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_2TVD_RLT Log 147-5992.pdf33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_5MD_RLT Log 147-20296.pdf33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_5TVD_RLT Log 147-5992.pdf33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_VSS_RLT_Time Log_Run 1.pdf33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_VSS_RLT_Time Log_Run 2.pdf33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_VSS_RLT_Time Log_Run 3.pdf33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_VSS_RLT_Time Log_Run 4.pdf33001EDDigital DataDF5/8/2020 Electronic File: VSS_TIME_MEM_ConocoPhillips_3H-37.pdf33001EDDigital DataDF5/8/2020 Electronic File: 3H-37 Final Survey Listing.pdf33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_Final DDO.xls33001EDDigital DataDF5/8/2020 Electronic File: 3H-37_FinalSurveys.txt33001EDDigital Data0 0 2191940 KUPARUK RIV UNIT 3H-37 LOG HEADERS33001LogLog Header ScansThursday, August 13, 2020AOGCCPage 4 of 5
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20822-00-00Well Name/No. KUPARUK RIV UNIT 3H-37Completion Status1-OILCompletion Date4/18/2020Permit to Drill2191940Operator ConocoPhillips Alaska, Inc.MD20296TVD5992Current Status1-OIL8/13/2020UICNoComments:Compliance Reviewed By:Date:COMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:4/18/2020Release Date:2/21/2020Thursday, August 13, 2020AOGCCPage 5 of 5M. Guhl 8/13/2020
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section):16. Well Name and Number:
Surface:
Top of Productive Interval:9. Ref Elevations: KB:73.7 17. Field / Pool(s):
GL:35.8 BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD:19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22.Logs Obtained:
23.
BOTTOM
20 H-40 156
10 3/4 L-80 2946
7 5/8 L-80 5948
4 1/2 L-80 5992
24.Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press:Calculated Gas-MCF:Oil Gravity - API (corr):
Press.24-Hour Rate
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Gas
WAG
ConocoPhillips Alaska, Inc.4/18/2020
Permit to Drill Number / Sundry:
P.O. Box 100360 Anchorage, AK 99510-0360 3/9/2020 50-103-20822-00-00
1359' FNL, 281' FWL, Sec 12, T12N, R08E, UM
8.Date TD Reached:
KRU 3H-37
1316' FNL, 2179' FWL, Sec 34, T13N, R8E, UM Kuparuk River Field/Kuparuk Oil Pool
2181' FNL, 3147' FWL, Sec 28, T13N, R8E, UM N/A ADL 25531, ADL 25524, ADL 365501
498655 6000298 20296/5992
494214 6010902
489898 6015321 N/A 1701/1675
N/A
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
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
CASING, LINER AND CEMENTING RECORD
CASING WT. PER
FT.GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD
AMOUNT
PULLEDTOP BOTTOM TOP
94 37 156 37 42 Installed
45.5 37 3620 37 13 1/2 1185sx 10.7ppg Class G,
275sx 15.8ppg Class G
29.7 34 14039 34 9 7/8x11 730sx 14.0ppg C Class G
220sx 15.8ppg Class G
12.6 13796 20274 5893 6 3/4 Uncemented Liner
TUBING RECORD
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date Perfd):
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
3 1/2 13852 13684/5862
FRAC SLEEVE@:
14114-14117 MD and 5959 -5960 TVD…......4/14/2020
14666-14668 MD and 5975-5975 TVD…......4/14/2020
15302-15304 MD and 5987-5987 TVD…......4/14/2020
15755-15757 MD and 5988 -5988 TVD…......4/14/2020
16209-16212 MD and 5990-5990 TVD…......4/14/2020
17592-17595 MD and 5981-5981 TVD…......4/14/2020
18048-18050 MD and 5979 -5979 TVD…......4/14/2020
18542-18544 MD and 5976 -5976 TVD…......4/14/2020
19020-19022 MD and 5977-5977 TVD…......4/14/2020
19508-19510 MD and 5981 -5981 TVD…......4/14/2020
20255-20258 MD and 5992-5992 TVD…......4/14/2020
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Per 20 AAC 25.283 (i)(2) attach electronic information
PRODUCTION TEST
N/A WAITING FOR HOOKUP
Date of Test: Oil-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio:
Sr Pet Eng Sr Pet Geo Sr Res Eng
932060000, 932059000, 931866000,
Flow Tubing Oil-Bbl:Water-Bbl:
WINJ
SPLUG Other Abandoned Suspended
Stratigraphic Test
No
(((attached) No
No
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By Samantha Carlisle at 2:09 pm, May 19, 2020
Completion Date
4/18/2020
HEW
RBDMS HEW 5/26/2020
GDLB 05/27/2020 DSR-5/27/2020
SFD 6/10/2020
VTL 8/12/20
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1701 1675
Top of Productive Interval 14038 5948
Kuparuk A
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Mark Vanderhorst Contact Name:Marti Titus
Kup Drilling Manager Contact Email:marti.n.titus@cop.com
Authorized Contact Phone:265-1192
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
28. CORE DATA Yes 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.
29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS
NAME Well tested? Yes No
Permafrost - Top If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
Permafrost - Base
Formation @ TPI -Kuparuk C
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
Formation at total depth:
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
TPI (Top of Producing Interval).
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
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.
Authorized Name:
Authorized Title:
Signature w/Date:
INSTRUCTIONS
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.
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.
Daily Operations Summary, Definitive Survey, Cement Report, Schematic
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment, whichever occurs first.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals 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.
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.
No Sidewall Cores:Yes No
No
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
Digitally signed by mark.j.vanderhorst@conocophillips.com
DN: CN=mark.j.vanderhorst@conocophillips.com
Reason: I am the author of this document
Location: your signing location here
Date: 2020-05-19 11:20:53
Foxit PhantomPDF Version: 9.7.0
mark.j.vanderhorst@conocop
hillips.com
Top W Sak @ 2675' MD / 2470' TVD
Base W Sak @ 3310' MD / 2836' TVD
Top Moraine @ 12023' MD / 5405' TVD
Base Moraine @ 12261' MD / 5472' TVD
Base Permafrost @ 1670' MD / 1632' TVD
Top Kalubik @ 13149' MD / 5717' TVD
Top HRZ @ 12895' MD / 55645' TVD
Top K1 @ 13642' MD / 5857' TVD
3H-37 Horizontal Kuparuk A-Sand Producer
Proposed Wellbore Schematic
Surface Casing: 10-3/4" 45.5# L-80 Hydril 563
@ 3,601’ MD / 2,970' TVD, 65° deg Inc
Conductor: 20" driven to +/-119'
Production Liner: 4-1/2" 12.6# L-80 Hydril 563 w/ frac sleeves
@ 20,321' MD / 5,966' TVD, 90° Inc
Tubing: 3-1/2” 9.3# L-80 EUE 8RD-MOD
9-7/8" x 11" Intermediate Hole
6-3/4" Production Hole
FloPro (WBM)13-1/2" Surface Hole
Intermediate Casing: 7-5/8" 29.7#, L80, Hydril 563
@ 13,964' MD / 5,943' TVD, 78° Inc
5-3/4" x 4-1/2” Swell Packer for fault isolation
GLGL
GLGL
LSNDSpud Mud3-½”, 2.75" XN Nipple
5-1/2” x 7-5/8" Baker HRD-E ZXP Packer / Flex Lock Liner Hanger
@ 13,814' MD
TOC @ 11143' MD / 5155' TVD (250' TVD above top of Moraine)
Top Kuparuk @ 13918' MD / 5933' TVD
TOC @ Surface
Well plan: wp07
2.813" X
Ball Actuated Frac Sleeves
Wellbore Isolation Valve + Alpha Sleeve
3-½” x 7-5/8" Premier Packer
Halliburton DHG
GLGL
X
GLGL
GLGL
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
LAST TAG:3H-37 jennalt
Last Rev Reason
Annotation End Date Wellbore Last Mod By
REV REASON: NEW WELL 5/18/2020 3H-37 jennalt
Casing Strings
Casing Description
CONDUCTOR
OD (in)
20
ID (in)
19.12
Top (ftKB)
37.5
Set Depth (ftKB)
156.5
Set Depth (TVD) …
156.5
Wt/Len (l…
94.00
Grade
H-40
Top Thread
Casing Description
SURFACE
OD (in)
10 3/4
ID (in)
9.95
Top (ftKB)
37.5
Set Depth (ftKB)
3,620.5
Set Depth (TVD) …
2,946.5
Wt/Len (l…
45.50
Grade
L-80
Top Thread
Hyd563
Casing Description
INTERMEDIATE
OD (in)
7 5/8
ID (in)
6.88
Top (ftKB)
34.4
Set Depth (ftKB)
14,038.6
Set Depth (TVD) …
5,947.9
Wt/Len (l…
29.70
Grade
L-80
Top Thread
HYD563
Casing Description
LINER
OD (in)
4.55
ID (in)
3.91
Top (ftKB)
13,795.8
Set Depth (ftKB)
20,274.0
Set Depth (TVD) …
5,992.5
Wt/Len (l…
12.60
Grade
L-80
Top Thread
HYD 563
Liner Details
Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com
Nominal ID
(in)
13,795.8 5,892.8 74.66 PACKER 5" X 7" Baker " HRDE" ZXP Liner top packer w/11.31'
Tie-back
4.810
13,815.5 5,897.9 75.00 NIPPLE 5 1/2" RS Packoff seal Nipple - 5 1/2" HYD 563 box
by box
4.250
13,817.8 5,898.5 75.04 HANGER Flex Lock DG liner hanger - 5.50" X 7.625" Q125 - 5
1/2" 17# Hyd 563 pin x pin - H294-24-0002
4.800
13,827.1 5,900.9 75.20 XO
REDUCING
Crossover 5-1/2" H 563 X 5" H 561 4.400
13,838.5 5,903.8 75.39 SBE 80-40- seal bore extension - 5" hyd 521 pin X 4.5"
Hyd 521 box - H024747203
4.000
14,114.5 5,959.4 82.30 FRAC SLEEVE Baker Frac Sleeve #11 W/ 2.595" Ball OD (Seat ID
= 2.555")
2.555
14,213.4 5,970.1 85.32 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "N" 3.910
14,396.3 5,975.4 90.24 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "M" 3.910
14,666.2 5,975.2 90.08 FRAC SLEEVE Baker Frac Sleeve #10 W/ 2.545" Ball OD (Seat ID
= 2.545")
2.545
14,764.9 5,975.4 89.90 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "L" 3.910
15,032.5 5,977.3 88.18 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "K" 3.910
15,301.8 5,986.7 88.34 FRAC SLEEVE Baker Frac Sleeve #9 W/ 2.495" Ball OD (Seat ID =
2.465")
2.465
15,523.2 5,989.8 90.03 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "J" 3.910
15,754.6 5,987.6 90.63 FRAC SLEEVE Baker Frac Sleeve #8 W/ 2.455" Ball OD (Seat ID =
2.425")
2.425
15,977.8 5,986.9 89.45 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "I" 3.910
16,209.2 5,989.7 90.03 FRAC SLEEVE Baker Frac Sleeve #7 W/ 2.415" Ball OD (Seat ID =
2.385")
2.385
16,391.3 5,988.7 90.23 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "H" 3.910
16,621.3 5,987.8 91.04 FRAC SLEEVE Baker Frac Sleeve #6 W/ 2.375" Ball OD (Seat ID =
2.345")
2.345
16,885.4 5,985.3 90.08 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "G" 3.910
17,319.0 5,982.2 90.25 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "F" 3.910
17,592.5 5,981.5 90.83 FRAC SLEEVE Baker Frac Sleeve #5 W/ 2.335" Ball OD (Seat ID =
2.305")
2.305
17,816.5 5,979.9 89.27 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "E" 3.910
18,048.1 5,979.2 90.70 FRAC SLEEVE Baker Frac Sleeve #4 W/ 2.295" Ball OD (Seat ID =
2.265")
2.265
18,270.6 5,977.1 90.43 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "D" 3.910
18,541.7 5,976.2 90.08 FRAC SLEEVE Baker Frac Sleeve #3 W/ 2.255" Ball OD (Seat ID =
2.225")
2.225
18,757.8 5,976.5 90.09 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "C" 3.910
19,019.7 5,977.2 89.77 FRAC SLEEVE Baker Frac Sleeve #2 W/ 2.215" Ball OD (Seat ID =
2.185")
2.185
19,239.3 5,977.7 89.83 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "B" 3.910
19,507.7 5,981.3 89.10 FRAC SLEEVE Baker Frac Sleeve #1 W/ 2.175" Ball OD (Seat ID =
2.145")
2.145
19,731.5 5,986.0 89.58 SWELL
PACKER
Baker swell Packer, 4-1/2"x5.6", HYD 563, "A" 3.910
20,246.0 5,992.4 89.66 BAFFLE Alpha Pressure Sleeve W/#16 Rupture disk - Hyd
563
3.000
20,255.5 5,992.5 89.81 FRAC SLEEVE 4.5" Baker WIV 12.6# P110 - Ball OD 1.25"-1.75" - 2
pins @ 990 PSI
1.125
Tubing Strings
Tubing Description
3 1/2" COMPLETION
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
33.5
Set Depth (ft…
13,851.9
Set Depth (TVD) (…
5,907.2
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
33.5 33.5 0.00 HANGER Cameron 4-1/2" Tubing Hanger, H563 3.900
158.7 158.7 0.35 XO REDUCING XO, 2', 4-1/2" 12.6# L-80 H563 box x 3-1/2" 9.3# EUE 2.990
HORIZONTAL, 3H-37, 5/18/2020 12:38:21 PM
Vertical schematic (actual)
LINER; 13,795.8-20,274.0
Annular Fluid - Mud; 13,795.8-
20,296.0; 4/14/2020
INTERMEDIATE; 34.4-14,038.6
MULE SHOE; 13,849.7
XO Threads; 13,848.3
SUB; 13,792.4
DUEL FLAPPER VALVE;
13,742.9
NIPPLE; 13,742.7
PACKER; 13,684.4
GAUGE; 13,627.0
GAS LIFT; 12,719.5
GAS LIFT; 11,318.1
GAS LIFT; 9,213.4
Annular Fluid - Saltwater/Brine;
2,107.0-13,795.0; 4/15/2020
GAS LIFT; 6,016.1
SURFACE; 37.5-3,620.5
SHEAR OUT SUB; 2,744.5
NIPPLE; 1,997.2
Annular Fluid - Diesel; 33.4-
2,107.0; 4/17/2020
XO REDUCING; 158.7
CONDUCTOR; 37.5-156.5
HANGER; 33.5
H BPV; 33.0
KUP PROD
KB-Grd (ft)
37.87
Rig Release Date
4/18/2020
3H-37
...
TD
Act Btm (ftKB)
20,296.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032082200
Wellbore Status
PROD
Max Angle & MD
Incl (°)
91.58
MD (ftKB)
17,670.13
WELLNAME WELLBORE3H-37
Annotation
LAST WO:
End DateH2S (ppm) DateComment
SSSV: None
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
1,997.2 1,949.8 28.59 NIPPLE NIPPLE,LANDING,3 1/2", X, 2.81" min ID, 2.81 packing bore
S/N=4277509-04
2.813
2,744.5 2,510.0 53.94 SHEAR OUT
SUB
"3-1/2"" x 1"" Camco KBMG GLM #1 w/ SOV, S/N - 21894-03SOV
pinned to 2000psi (IA to TBG)"
2.920
13,627.0 5,846.6 73.99 GAUGE Halliburton Gauge Mandrel, EUE S/N = 19-575 2.957
13,684.4 5,862.4 74.04 PACKER Baker Premier Production Packer 3.5"x7.63" 2.890
13,742.7 5,878.4 74.09 NIPPLE NIPPLE,LANDING,3 1/2",XN, 2.813", min ID 2.75", EUE BXP w/
dual flapper valve installed S/N=C2763026
2.750
13,792.5 5,891.9 74.61 SUB Baker Fluted NO GO sub 2.990
13,849.7 5,906.6 75.58 MULE SHOE Baker Indexing Mule shoe - Material # H444-08-005 2.980
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°) Des Com Run Date ID (in) SN
33.0 33.0 0.00 H BPV 4/18/2020 0.000
13,742.
9
5,878.4 74.09 DUEL FLAPPER
VALVE
4/17/2020 0.000
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 2,744.5 2,510.0 Camco KBMG 1 GAS LIFT SOV BEK 4/17/2020 SOV
shear
IA x
tubin
g
com
muni
catio
n.2 6,016.1 3,698.1 Camco KBMG 1 GAS LIFT DMY BK 4/17/2020
3 9,213.4 4,603.3 Camco KBMG 1 GAS LIFT DMY BK 4/17/2020
4 11,318.1 5,200.7 Camco KBMG 1 GAS LIFT DMY BK 4/17/2020
5 12,719.5 5,596.0 Camco KBMG 1 GAS LIFT DMY BK 4/17/2020
Notes: General & Safety
End Date Annotation
NOTE:
HORIZONTAL, 3H-37, 5/18/2020 12:38:22 PM
Vertical schematic (actual)
LINER; 13,795.8-20,274.0
Annular Fluid - Mud; 13,795.8-
20,296.0; 4/14/2020
INTERMEDIATE; 34.4-14,038.6
MULE SHOE; 13,849.7
XO Threads; 13,848.3
SUB; 13,792.4
DUEL FLAPPER VALVE;
13,742.9
NIPPLE; 13,742.7
PACKER; 13,684.4
GAUGE; 13,627.0
GAS LIFT; 12,719.5
GAS LIFT; 11,318.1
GAS LIFT; 9,213.4
Annular Fluid - Saltwater/Brine;
2,107.0-13,795.0; 4/15/2020
GAS LIFT; 6,016.1
SURFACE; 37.5-3,620.5
SHEAR OUT SUB; 2,744.5
NIPPLE; 1,997.2
Annular Fluid - Diesel; 33.4-
2,107.0; 4/17/2020
XO REDUCING; 158.7
CONDUCTOR; 37.5-156.5
HANGER; 33.5
H BPV; 33.0
KUP PROD 3H-37
...
WELLNAME WELLBORE3H-37
Page 1/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/7/2020
04:00
3/7/2020
08:00
4.00 MIRU MOVE MOB P Clean and clear cellar area on 3H35.
Prepare pipeshed/motor module for
move. Move matting boards into
position for move and around 3H-37
well location.
119.0 119.0
3/7/2020
08:00
3/7/2020
12:00
4.00 MIRU MOVE MOB P PJSM for rig move. Move Pipe shed
to 3H-37. Break services lines
between rig sub and motor module.
Move motor module away from rig
sub. Continue to shuffle matting
boards.
119.0 119.0
3/7/2020
12:00
3/7/2020
17:00
5.00 MIRU MOVE MOB P PJSM. Prepare rig sub. Skid rig floor
to move position. Raise back windwall
and stompers. Move off 3H35 well.
(Witnessed by pad operator). Stage
MPD and Cameron equipment into 37
cellar area.
119.0 119.0
3/7/2020
17:00
3/7/2020
22:00
5.00 MIRU MOVE MOB P Turn tires and move Rig sub to 3H37
well. Move out to clear and remove
wind walls. Install herculite in place of
wind walls. Move to 3H-37 and spot
over well with Pad operator present for
move in and spotting operations.
Continue to shuffle matting boards.
119.0 119.0
3/7/2020
22:00
3/8/2020
00:00
2.00 MIRU MOVE MOB P Shim rear end of rig sub and set Rig
sub down. Prep to skid rig floor.
Clean up 3H-35 cellar area.
119.0 119.0
3/8/2020
00:00
3/8/2020
06:00
6.00 MIRU MOVE MOB P Spot pipe shed in place. Spot
pit/motor complex in place. Connect
service lines between pits and rig sub.
156.0 156.0
3/8/2020
06:00
3/8/2020
09:00
3.00 MIRU MOVE RURD P Level pipe shed/ Start up boilers. One
boiler not working. Troubleshoot and
repair. (Line leaking to nozzle). Offload
surface casing. Build berm and spot
cuttings tank.
156.0 156.0
3/8/2020
09:00
3/8/2020
10:00
1.00 MIRU MOVE RURD P Continue on boiler. (Repaired leak but
will not fire (electrical)). Spot heater
for pipeshed and RU.
156.0 156.0
3/8/2020
10:00
3/8/2020
13:00
3.00 MIRU MOVE RURD P Continue on boiler (waiting on part).
Install dump line from drag chain to
cutting tanks. NU riser adapter. Spot
MWD connex and move MPD connex
close for crane pick. Offload surface
casing.
156.0 156.0
3/8/2020
13:00
3/8/2020
16:30
3.50 MIRU MOVE RURD P Continue on boiler. Spot MPD connex
in place. NU surface riser. Install 4"
valves on conductor.
156.0 156.0
3/8/2020
16:30
3/9/2020
00:00
7.50 MIRU MOVE RURD P Continue on boiler. Start taking on
spud mud. Installing riser. Load casing
in pipeshed. Welder replaced pillow
block bearing on pipe skate,
completed 23:45 hrs. Boiler #1 back
on line 23:30 hrs.
156.0 156.0
3/9/2020
00:00
3/9/2020
03:15
3.25 MIRU MOVE RURD P Work on pre spud check list - Trouble
shoot boiler # 1 - Finish replacing
pillow block bearing on pipe skate
156.0 156.0
3/9/2020
03:15
3/9/2020
05:00
1.75 MIRU MOVE RURD P PU and stand back 2 stds HWDP and
jar std.
156.0 156.0
3/9/2020
05:00
3/9/2020
07:30
2.50 MIRU MOVE SLPC P Pre-job safety meeting on Slip & cut
drill line - Slip & cut 13 wraps - Service
TD, brake bands, and drawworks.
156.0 156.0
3/9/2020
07:30
3/9/2020
10:00
2.50 MIRU MOVE BHAH P RU Baker bypass actuator - MU motor
and bit. RIH and tag at 43'.
156.0 156.0
Rig: DOYON 19
Page 2/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/9/2020
10:00
3/9/2020
10:30
0.50 MIRU MOVE SFTY P Hold Pre-Spud meeting with crew,
Baker DD and MWD, Gyro hand and
CP reps. Discussed well and surface
section hazards and mitigations,
156.0 156.0
3/9/2020
10:30
3/9/2020
11:45
1.25 MIRU MOVE PRTS P Fill conductor and repair leak on fill-up
line. Pump and check for leaks. Test
lines back to pump to 3500psi. Good.
156.0 156.0
3/9/2020
11:45
3/9/2020
13:00
1.25 MIRU MOVE WASH P Tag @ 43' Wash clean out conductor
to 156'
156.0 156.0
3/9/2020
13:00
3/9/2020
13:30
0.50 SURFAC DRILL DDRL P Drill 13.5in surface hole f/ 156' to 200'
MD 200' TDV
ADT - .3 hrs.
WOB 2/5 k RPM 40 GPM 450 @ 400
psi
Torque 2 k/ft lbs.
156.0 200.0
3/9/2020
13:30
3/9/2020
14:00
0.50 SURFAC DRILL TRIP P POOH to Stabilizer to PU rest of BHA.
Blow down TD.
200.0 200.0
3/9/2020
14:00
3/9/2020
15:45
1.75 SURFAC DRILL BHAH P PJSM. MU Cont. MU BHA # 1 - 13
1/2" motore assembly w/ Gyro
200.0 200.0
3/9/2020
15:45
3/9/2020
16:30
0.75 SURFAC DRILL BHAH P Plug into MWD and Gyro to
synchronize highside orientation of the
tools.
200.0 200.0
3/9/2020
16:30
3/9/2020
17:15
0.75 SURFAC DRILL BHAH P Continue to MU BHA # 1 - orient
UBHO to motor
200.0 200.0
3/9/2020
17:15
3/9/2020
18:00
0.75 SURFAC DRILL BHAH P Shallow pulse test MWD & gyro
survey @ 170' MD
200.0 200.0
3/9/2020
18:00
3/10/2020
00:00
6.00 SURFAC DRILL DDRL P Drilled 13 1/2" hole from 200' to 632'
MD, 630' TVD
WOB 5-15K - GPM 550, SPP - 1200
psi - RPM 50
Torque on/off btm - 3K/5K
String wt. - PU 95K ROT 85K
ADT - 1.5 hrs, AST - 0.7 hrs, Jars hrs.
1.1 hrs. Bit hrs. 2.5 hrs
200.0 632.0
3/10/2020
00:00
3/10/2020
06:00
6.00 SURFAC DRILL DDRL P Drilled 13 1/2" 632' to 1225' (593' @
98.8 FPH)
WOB 5-15K - GPM 550, SPP - 1200
psi - RPM 50
TORQUE ON / OFF 3K / 5K, MUD IN /
OUT 9.7 / 9.7 ppg
PU 95K ROT 85K
ART - 1.7 hrs, AST - 2.1 hrs, Jars hrs.
5.9 hrs. Bit hrs. 6.3 hrs
632.0 1,225.0
3/10/2020
06:00
3/10/2020
12:00
6.00 SURFAC DRILL DDRL P Drilled 13 1/2" hole f/ 1225' to
1864' (639' @ 106.5 FPH)
WOB 5-15K - GPM 550, SPP - 1250
psi - RPM 50
TORQUE ON / OFF 5K / 3K, MUD IN /
OUT 9.2 / 9.2 ppg
PU 106K ROT 122K
ART - 1.9 hrs, AST - 2.4 hrs, Jars hrs.
10.2 hrs. Bit hrs. 10.6 hrs
1,225.0 1,864.0
Rig: DOYON 19
DRILL DDRL
Page 3/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/10/2020
12:00
3/10/2020
18:00
6.00 SURFAC DRILL DDRL P Drill 13 1/2" Surface Hole F/ 1864' to
2290' MD, 2199 TVD
650 GPM = 1810 psi, 50 RPM = 7K
TQ on bottom, 4K TQ off bottom
PUWT = 125K, SOWT = 120K, ROTW
= 122K @ 20 RPM = 4.5K TQ off
bottom.
MW = 9.3 ppg in/out, VIS = 170
ART = 1.3 hrs, AST = 3.0 hrs, Jars hrs
= 13.5 hrs. Bit hrs = 14.9 hrs
1,864.0 2,290.0
3/10/2020
18:00
3/11/2020
00:00
6.00 SURFAC DRILL DDRL P Drill 13 1/2" Surface Hole F/ 2290' to
2905' MD, 2597' TVD
650 GPM = 2050 psi
50 RPM = 5.5K TQ on bottom, 4.5k
TQ off bottom
PUWT = 131K, SOWT = 120K, ROTW
= 125K @ 20 RPM = 4.5K TQ off
bottom.
MW = 9.5 ppg in/out, VIS = 170
Pump nut plug sweep at 2775' MD
ART = 2.00 hrs, AST = 2.1 hrs, Jars
hrs = 17.6 hrs. Bit hrs = 19.0 hrs
2,290.0 2,905.0
3/11/2020
00:00
3/11/2020
06:00
6.00 SURFAC DRILL DDRL P Drill 13 1/2" Surface Hole F/ 2905' to
3307' MD, 2807' TVD
650 GPM = 1890 psi
55 RPM = 7K TQ on bottom
PUWT = 132K, SOWT = 120K, ROTW
= 125K @ 20 RPM = 4.5K TQ off
bottom.
MW = 9.7 ppg in/out, VIS = 130
ART = 3.9 hrs, AST = 1.1 hrs, Jars hrs
= 22.6 hrs. Bit hrs = 23.0 hrs
2,905.0 3,307.0
3/11/2020
06:00
3/11/2020
10:30
4.50 SURFAC DRILL DDRL P Drill 13 1/2" Surface Hole F/ 3307' to
TD @ 3628' MD, 2950' TVD
650 GPM = 2120 psi
60 RPM = 9K TQ on bottom
PUWT = 135K, SOWT = 115K, ROTW
= 120K @ 20 RPM = 6K TQ off
bottom.
MW = 9.7 ppg in/out, VIS = 152
ART = 3.1 hrs, AST = .6 hrs, Jars hrs
= 26.3 hrs, bit hrs = 26.7 hrs
3,307.0 3,628.0
3/11/2020
10:30
3/11/2020
12:00
1.50 SURFAC CASING CIRC P CBU 2X while back-reaming 1 stand
per bottoms up, F/ 628' to 3478' with
650 GPM = 1800 psi, 60RPM = 5.5K
TQ
PUWT = 130K, SOWT = 115K, ROTW
= 120K
3,628.0 3,628.0
3/11/2020
12:00
3/11/2020
12:15
0.25 SURFAC CASING OWFF P Observe Well for Flow = Static
B/D Top Drive
3,628.0 3,628.0
3/11/2020
12:15
3/11/2020
19:00
6.75 SURFAC CASING REAM P BROOH F/ 3478' to 1980' MD, 650
GPM = 1955 psi
Pump nut plug sweep at 3460 MD
3,628.0 3,628.0
3/11/2020
19:00
3/11/2020
20:15
1.25 SURFAC CASING COND T B/D Top Drive, Flow check well =
Static
Lost prime on both pumps due to High
Viscosity mud.
Clean suction screens, blow down all
lines to Mud pumps.
Condition mud.
3,628.0 3,628.0
Rig: DOYON 19
Page 4/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/11/2020
20:15
3/11/2020
22:30
2.25 SURFAC CASING BKRM P BROOH from 1980' to 1583' with 680
GPM, 1680 psi, 60 RPM with 4K
torque.
3,628.0 3,628.0
3/11/2020
22:30
3/11/2020
22:45
0.25 SURFAC CASING OWFF P Monitor well; Static
B/D Top Drive
3,628.0 3,628.0
3/11/2020
22:45
3/12/2020
00:00
1.25 SURFAC CASING TRIP P POOH on elevators from 1583' to 920'
with proper fill.
PUWT = 100K, SOWT = 95K
3,628.0 3,628.0
3/12/2020
00:00
3/12/2020
00:30
0.50 SURFAC CASING TRIP P Continue to pull on elevators from 920'
to 546' (Top of BHA) with proper fill.
920.0 546.0
3/12/2020
00:30
3/12/2020
00:45
0.25 SURFAC CASING OWFF P Monitor well static. 546.0 174.0
3/12/2020
00:45
3/12/2020
01:30
0.75 SURFAC CASING TRIP P POOH from 546' to 174'
Stand back HWDP and jars.
0.0 0.0
3/12/2020
01:30
3/12/2020
02:15
0.75 SURFAC CASING BHAH P Lay down Surface BHA #1 as per
Baker rep.
0.0 0.0
3/12/2020
02:15
3/12/2020
02:45
0.50 SURFAC CASING BHAH P Baker MWD plug into Gyro to verify
Data integrity. Check battery
operation.
0.0 0.0
3/12/2020
02:45
3/12/2020
04:45
2.00 SURFAC CASING BHAH P Continue to LD BHA components.
Drain Mud Motor and Break Bit.
Observe moderate amounts of clay on
stabilizers and bit.
0.0 0.0
3/12/2020
04:45
3/12/2020
06:15
1.50 SURFAC CASING CLEN P Clean and clear rig floor and stage
casing equipment and Volant to rig
floor
0.0 0.0
3/12/2020
06:15
3/12/2020
08:00
1.75 SURFAC CASING RURD P PJSM. RU to run 10 3/4" surface
casing.
0.0 0.0
3/12/2020
08:00
3/12/2020
09:30
1.50 SURFAC CASING PUTB P PJSM. MU and RIH w/ 10 3/4" shoe
track to 86' MD. (FS+2 joints+FC).
Install 2 Bow-spring centralizers on
Shoe joint and FC joint.
2 hydra-form centralizers on joint in
between Shoe jt and FC jt.
Thread lock all connections and pin
end of joint #1.
MU torque 16,200 ft/lbs.
Pump through shoe track and check
floats. Good.
0.0 86.0
3/12/2020
09:30
3/12/2020
12:00
2.50 SURFAC CASING PUTB P RIH w/ 10 3/4" 45.5# L-80 Hydril 563
Surface Casing F/ 86' to 1007' MD
Install 1 Hydra-form centralizer on
each joint F/ joint #1 thru #86
MU torque 16,200 ft/lbs.Break
circulation and CBU.
Fill on the fly, top off every 5 joints
86.0 1,007.0
3/12/2020
12:00
3/12/2020
14:00
2.00 SURFAC CASING PUTB P RIH w/ 10 3/4" 45.5# L-80 casing F/
1007' to 1875' MD
MU torque 16,200 ft/lbs.
3,628.0 3,628.0
3/12/2020
14:00
3/12/2020
14:45
0.75 SURFAC CASING CIRC P Circulate BU. 210 GPM = 220 psi,
PUWT = 130K, SOWT = 90K
3,628.0 3,628.0
3/12/2020
14:45
3/12/2020
17:00
2.25 SURFAC CASING PUTB P RIH w/ 10 3/4" 45.5# L-80 casing F/
1875' to 2787' MD
MU torque 16,200 ft/lbs, SOWT =
118K
3,628.0 3,628.0
3/12/2020
17:00
3/12/2020
18:00
1.00 SURFAC CASING CIRC P CBU 1X. 250 GPM = 300 psi,
PUWT = 160K, SOWT = 100K
3,628.0 3,628.0
3/12/2020
18:00
3/12/2020
20:00
2.00 SURFAC CASING PUTB P RIH w/ 10 3/4" 45.5# L-80 casing F/
1800'' to 3578' MD
3,628.0 3,628.0
Rig: DOYON 19
Page 5/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/12/2020
20:00
3/12/2020
20:45
0.75 SURFAC CASING PUTB P M/U Cameron Hanger and landing
joint.
Land 10 3/4" Surface Hanger on
Landing ring.
F/ 3578 to 3620.50' MD
PUWT = 185K, SOWT = 120K
3,628.0 3,628.0
3/12/2020
20:45
3/13/2020
00:00
3.25 SURFAC CEMENT CIRC P Circulate and condition Mud for
cement job
Stage pumps up to 6 bpm/258 gpm =
230 psi
Reciprocate 15' strokes
PJSM for Cement job with Haliburton,
Truck pusher, Mud Man and Doyon
personnel
3,628.0 3,628.0
3/13/2020
00:00
3/13/2020
06:00
6.00 SURFAC CEMENT CMNT P Perform 10-3/4" Surface casing
cement job. Reciprocate casing while
cementing. PUWT = 200K, SOWT =
130K.
Fill lines with 5 bbls 8.34 ppg fresh
water. Test lines to 3800 psi.
Pump 60 bbls 10.0 ppgTuned spacer.
3.5 bpm = 300 psi.
Drop bottom plug.
Pump 619 bbls Lead Cement, 1185
sks, 10.7 ppg, 2.9 cu-ft/sk yield, 14.97
gal/sk, 5 bpm = 550 psi, Added 5# Pol-
E-Flake and 4# Red Dye to first 10
bbls pumped. (Observed cement to
surface). Pump 57 bbls Tail Cement,
275 sks, 15.8 ppg, 1.16 cu-ft/sk yield,
5.05 gal/sk.
Drop top plug.
HES Pump 20 bbls 8.34 ppg fresh
water.
Displace plug with rig pumps. Pump
240 bbls of 9.6 ppg mud. Pumps
locked up - unable to pump fluid
Continue to displace Top Plug with 85
bbls of fresh water from HES pump
truck.
Total of 345 bbls pumped on top of
plug. Did not bump plug.
Check floats = good, Cement in place
at 05:00, 3/13/20
Total liquid returns = 402 bbls, plus
and estimated 75 bbls of solid cement
out of pits.
3,628.0 3,628.0
3/13/2020
06:00
3/13/2020
10:30
4.50 SURFAC CEMENT CMNT P Rig down GBR 10 3/4" casing tools
and equipment. Clear and clean rig
floor. Blow down mud pumps and all
charge lines.
Clean out surface cement lines and
cement valves. Begin pit cleaning
operations.
3,628.0 3,628.0
3/13/2020
10:30
3/13/2020
16:00
5.50 SURFAC WHDBOP NUND P Clean out and nipple down surface
riser and flow line. N/D 20" diverter
adapter.
N/U BOP, Choke and kill lines
Simops - load 4" drill pipe in pipe
shed.
Note: Had to wait on loader for snow
removal around beaver slide and
cement trucks for them to RD and
move.
3,628.0 3,628.0
Rig: DOYON 19
Page 6/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/13/2020
16:00
3/13/2020
18:00
2.00 SURFAC WHDBOP NUND P N/U Cameron well head. Orientate
wellhead (Witnessed by pad operator).
Test to 5000 psi, 10 min = Good.
Observe cement top at 44" below
ground level in conductor
3,628.0 3,628.0
3/13/2020
18:00
3/13/2020
21:00
3.00 SURFAC WHDBOP NUND P Continue to NU BOP stack, Perform
"Between Well Maintenance" on rams
and Annular. Continue to clean pits.
Phase 3 declared at 21:00.
3,628.0 3,628.0
3/13/2020
21:00
3/14/2020
00:00
3.00 SURFAC WHDBOP WAIT T Clean pits . (Phase 3 conditions) 3,628.0 3,628.0
3/14/2020
00:00
3/14/2020
06:00
6.00 SURFAC WHDBOP WAIT T Cleaning pits. (Phase 3 conditions) 3,628.0 3,628.0
3/14/2020
06:00
3/14/2020
10:30
4.50 SURFAC WHDBOP NUND P Perform BWM on BOPE. NU flow
box/MPD RCD spool/orbit valve/
Continue cleaning pits.
Load and strap 4" DP
3,628.0 3,628.0
3/14/2020
10:30
3/14/2020
19:00
8.50 SURFAC WHDBOP WAIT T Cleaning pits. (Phase 3 conditions). 3,628.0 3,628.0
3/14/2020
19:00
3/14/2020
22:00
3.00 SURFAC WHDBOP NUND P N/U MPD and equipment, Install trip
nipple riser and MPD choke lines and
drip pans. Tighten Ram doors on BOP
Continue pit cleaning operations.
Load pipe shed with DP and Casing
3,628.0 3,628.0
3/14/2020
22:00
3/15/2020
00:00
2.00 SURFAC WHDBOP NUND P Rig up Flow line. Install mouse hole.
M/U 5" test joint and set Cameron Test
Plug. R/U BOP test equipment.
3,628.0 3,628.0
3/15/2020
00:00
3/15/2020
03:00
3.00 SURFAC WHDBOP NUND P Continue to N/U BOPE and test
equipment.
Fill stack and choke manifold with
water and purge air from system.
3,628.0 3,628.0
3/15/2020
03:00
3/15/2020
07:45
4.75 SURFAC WHDBOP BOPE P Test BOPE. Test 13 3/8" annular,
Upper pipe 3 1/2" X 5" VBR's, Choke
manifold valves, floor valves and Top
Drive valves per Doyon procedure
steps 1 and 2. Test all rams and
valves - 250 psi low, 3500 psi high, 5
min each. Test Annular to 250 / 2500
psi. Use 5" test joint. Chart all tests.
AOGCC Austin McLeod waived States
right of witness to BOP test. 21:50,
3/14/2020
3,628.0 3,628.0
3/15/2020
07:45
3/15/2020
09:45
2.00 SURFAC WHDBOP BOPE P 2 tests complete. Unable to test
further. Chase leaks.
Pull trip nipple. Pull test plug to verify
good seal.
Replace upper Ram VBR packer
element
3,628.0 3,628.0
3/15/2020
09:45
3/15/2020
11:45
2.00 SURFAC WHDBOP BOPE P Flood BOP and lines. Attempt to test =
unsuccessful.
Lower ram door leaking
3,628.0 3,628.0
3/15/2020
11:45
3/15/2020
13:00
1.25 SURFAC WHDBOP BOPE T Tighten lower door, re-test = no test.
Open doors and C/O door seal
3,628.0 3,628.0
3/15/2020
13:00
3/15/2020
14:30
1.50 SURFAC WHDBOP BOPE T Continue to attempt to test and
troubleshoot leaks.
3,628.0 3,628.0
3/15/2020
14:30
3/15/2020
18:00
3.50 SURFAC WHDBOP BOPE T Install trip nipple. C/O upper ram door
seals.
Attempt to test = unsuccessful
Pull Cameron test plug and C/O seal
Attempt to test = unsuccessful
3,620.5 3,620.5
Rig: DOYON 19
Page 7/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/15/2020
18:00
3/15/2020
22:45
4.75 SURFAC WHDBOP BOPE T Continue troubleshoot BOPE system.
Re-Torque mud cross flange studs.
Cycle all associated valves on well
head.
Check and tighten Ram door bolts.
Re-install test joint and R/U test
equipment.
3,628.0 3,628.0
3/15/2020
22:45
3/16/2020
00:00
1.25 SURFAC WHDBOP BOPE P Continue Test BOPE. Test lower pipe
rams and blind rams, Test all
remaining choke manifold valves, floor
valves and Top Drive valves. Test all
rams and valves - 250 psi low, 3500
psi high, 5 min each. Use 5" test joint.
Chart all tests.
Test gas alarms.
AOGCC Austin McLeod waived States
right of witness to BOP test. 21:50,
3/14/2020
3,628.0 3,628.0
3/16/2020
00:00
3/16/2020
02:15
2.25 SURFAC WHDBOP BOPE P Continue to test BOPE. Test lower
pipe rams and blind rams, Test all
remaining choke manifold valves, floor
valves and Top Drive valves. Test all
rams and valves - 250 psi low, 3500
psi high, 5 min each. Use 5" test joint.
Chart all tests.
Test gas alarms.
AOGCC Austin McLeod waived States
right of witness to BOP test. 21:50,
3/14/2020
3,628.0 3,628.0
3/16/2020
02:15
3/16/2020
03:00
0.75 SURFAC WHDBOP MPDA P Pull trip nipple. Install test cap and test
MPD RCD to 1200 psi for 10 min,
charted
3,628.0 3,628.0
3/16/2020
03:00
3/16/2020
06:00
3.00 SURFAC WHDBOP BOPE P RD MPD test equipment. Install trip
nipple. Pull test plug. Install 10" ID
wear bushing.
Blow down choke and kill line.
Continue to clean cement from pits.
Load 5" DP in pipe shed and process
same.
Mobilize BHA to rig floor
3,628.0 3,628.0
3/16/2020
06:00
3/16/2020
07:00
1.00 SURFAC DRILLOUT BHAH P PJSM to M/U BHA. R/U handling tools
and equipment to rig floor.
3,628.0 3,628.0
3/16/2020
07:00
3/16/2020
11:00
4.00 SURFAC DRILLOUT BHAH P M/U 9 7/8" x 11" Intermediate BHA
Run #2 per Baker Rep.
PDC Bit, Auto-track, MWD, Rhino-
Reamer, HWDP, Jar. T/ 560' MD
Plug in and test MWD connections.
3,628.0 3,628.0
3/16/2020
11:00
3/16/2020
13:15
2.25 SURFAC DRILLOUT PULD P RIH w/ BHA on 5" DP F/ 560' to 2400'
MD.
Single in DP from pipe shed. Fill pipe
every 20 stands.
3,628.0 3,628.0
3/16/2020
13:15
3/16/2020
14:15
1.00 SURFAC DRILLOUT CIRC T Prepare pits and circulate across top
of hole checking lines for
contamination from surface cement
job.
Load pits with 9.7 ppg mud
3,628.0 3,628.0
3/16/2020
14:15
3/16/2020
16:30
2.25 SURFAC DRILLOUT CIRC T Circulating hole. Contaminated mud
from cement job back to surface.
Pumping at slow rates (overloading
shakers/flowline)
3,628.0 3,628.0
Rig: DOYON 19
Page 8/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/16/2020
16:30
3/16/2020
17:30
1.00 SURFAC DRILLOUT CIRC P Circulate and perform shallow test for
MWD tools. 650 GPM = 2200 psi,
Good
Function under reamer at ICP @ 650
GPM = 2250 psi, FCP @ 650 GPM =
1750 psi, Good
3,628.0 3,628.0
3/16/2020
17:30
3/16/2020
21:00
3.50 SURFAC DRILLOUT WASH P Wash down F/ 2400' to 3500' MD. 600
GPM = 1950 psi.
Wash and rotate on stringers F/ 3500'
to hard tag at 3520' MD
600 GPM = 1890 psi, 10K WOB, 5K
TQ, 50 RPM
PUWT = 145K, SOWT = 108K ROTW
= 122K
3,628.0 3,628.0
3/16/2020
21:00
3/16/2020
22:15
1.25 SURFAC DRILLOUT CIRC P CBU 3X, Reciprocate DP. Circulate
and condition mud to 9.0 ppg. 600
GPM = 1890 psi
3,628.0 3,628.0
3/16/2020
22:15
3/17/2020
00:00
1.75 SURFAC DRILLOUT PRTS P R/U Casing test equipment. Circulate
and flood lines.
Test 10 3/4" 45.5#, L80, Hydril 563,
Surface casing to 3500 psi, 30
minutes. Charted. Good test.
R/D testing equipment and blow down
lines.
3,628.0 3,628.0
3/17/2020
00:00
3/17/2020
00:15
0.25 SURFAC DRILLOUT RURD P Finish RD casing test equipment. BD
lines.
3,628.0 3,628.0
3/17/2020
00:15
3/17/2020
02:15
2.00 SURFAC DRILLOUT DRLG P Drill out cement/plugs/FC/ shoetrack
F/ 3520' to 3610'. (10' above FS).
Hard cement @ 3520'
600 gpm/1890 psi
65 rpm/ 7-11k tq
WOB= 5-15k
Rot wt= 124k
3,628.0 3,628.0
3/17/2020
02:15
3/17/2020
03:45
1.50 SURFAC CEMENT CIRC P Circulate while preparing pits f/
displacement. Displace hole to 9.0
ppg LSND mud.
3,628.0 3,628.0
3/17/2020
03:45
3/17/2020
04:30
0.75 SURFAC DRILLOUT DRLG P Drill out shoetrack/FS. Clean out RH
and drill 20' of new hole to 3648' MD.
600 gpm/1560 psi
65 rpm/ 7-9k tq
WOB= 5-15k
Rot wt= 124k
3,628.0 3,648.0
3/17/2020
04:30
3/17/2020
05:30
1.00 SURFAC CEMENT CIRC P Circulate and condition mud f/ LOT.
600 gpm/ 1560 psi.
50 rpm/ 6k tq
Rot wt=124k
MW 9.1ppg in/out
3,648.0 3,648.0
3/17/2020
05:30
3/17/2020
06:30
1.00 SURFAC CEMENT LOT P R/U F/ LOT. Performed LOT to 14.5
ppg EMW - Pumped @ 1/2 bbl/min
and observed break over at 820 psi.
Pumped 1/2 bbl more.
Shut in and observe pressure for 10
minutes. Bleed off pressure. RD test
equipment and Blow down lines.
1.75 bbls pumped/ 1.0 bbls returned.
Current MW 9.1 ppg. TVD 2946'.
3,648.0 3,648.0
3/17/2020
06:30
3/17/2020
12:00
5.50 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" section F/ 3648'
MD/3150' TVD to 4148' MD. (500' at
91 ft/hr w/ connection)
725 gpm/1820 psi.
120 rpm/ 8k tq/ 6.5k off bttm tq
WOB= 13-15k
ECD=10.3 ppg
PU wt 150/ SO wt 110k/ Rot wt 125k
ADT'4.3 hrs/ Jars 30.8 hrs
3,648.0 4,148.0
Rig: DOYON 19
Page 9/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/17/2020
12:00
3/17/2020
18:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 4148' to 4780' MD, 3339' TVD.
(632' at 105 ft/hr w/ connections)
725 GPM = 2060 psi
120 RPM = 9.5K TQ
WOB = 15K
ECD = 10.57 ppg
PUWT = 150K, SOWT = 110K, ROTW
= 125K, Off bottom TQ = 6.5K
SPR@ 4622 MD, 3293 TVD, 9.2 ppg
MW
#1 MP - 25/35 SPM = 180 / 230 psi
#2 MP - 25/35 SPM = 190 / 240 psi
ADT = 4.5 hrs, Jars = 35.3 hrs
4,148.0 4,780.0
3/17/2020
18:00
3/18/2020
00:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 4780' to 5565' MD, 3567' TVD.
(785' at 131 ft/hr w/ connections)
725 GPM = 2420 psi
120-140 RPM = 11K TQ
WOB = 15-25K
ECD = 10.98 ppg
PUWT = 162K, SOWT = 113K, ROTW
= 132K, Off bottom TQ = 7K @ 20
RPM
SPR@ 4622 MD, 3293 TVD, 9.2 ppg
MW
#1 MP - 25/35 SPM = 190 / 260 psi
#2 MP - 25/35 SPM = 190 / 250 psi
ADT = 4.3 hrs, Jars = 39.6 hrs
4,780.0 5,565.0
3/18/2020
00:00
3/18/2020
06:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 5565' to 6139' MD, 3732' TVD.
(574ft @ 95ft/hr w/ connections)
725 GPM = 2390 psi
120-140 RPM = 10-13K TQ
WOB = 15-25K
ECD = 11.21 ppg
PUWT = 170K, SOWT = 113K, ROTW
= 135K, Off bottom TQ = 8.5 @ 20
RPM
ADT = 4.8 hrs, Jars = 44.4 hrs
5,565.0 6,139.0
3/18/2020
06:00
3/18/2020
12:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 6139' to 6608' MD, 3865' TVD.
(469' @ 78ft/hr)
725 GPM = 2920 psi
120 RPM = 11.5K TQ
WOB = 20-25K
ECD = 11.75 ppg
PUWT = 172K, SOWT = 112K, ROTW
= 135K, Off bottom TQ = 9.5 @ 20
RPM
SPR@ 3512 MD, 3838 TVD, MW =
9.7 ppg
#1 MP - 25/35 SPM = 330 / 390 psi
#2 MP - 25/35 SPM = 330 / 400 psi
ADT = 5.3 hrs, Jars = 49.7 hrs
6,139.0 6,608.0
Rig: DOYON 19
Page 10/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/18/2020
12:00
3/18/2020
18:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 6608' to 7076' MD, 3998' TVD.
(468' @ 78ft/hr)
725 GPM = 2920 psi
120 RPM = 11.5K TQ
WOB = 20-25K
ECD = 11.75 ppg
PUWT = 172K, SOWT = 112K, ROTW
= 135K, Off bottom TQ = 9.5 @ 20
RPM
ADT = 5.3 hrs, Jars = 49.7 hrs
6,608.0 7,076.0
3/18/2020
18:00
3/19/2020
00:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 7076' to 7739' MD, 4189' TVD.
(663' @ 110 ft/hr)
725 GPM = 2850 psi
120 RPM = 12.5K TQ
WOB = 15-28K
ECD = 11.30 ppg
PUWT = 190K, SOWT = 118K, ROTW
= 143K, Off bottom TQ = 10 @ 20
RPM
SPR@ 7551' MD, 4133' TVD, MW =
9.6 ppg
#1 MP - 25/35 SPM = 300/400 psi
#2 MP - 25/35 SPM = 300/400 psi
ADT = 4.8 hrs, Jars = 59.5 hrs
7,076.0 7,739.0
3/19/2020
00:00
3/19/2020
06:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 7739' to 8404' MD, 4376' TVD.
(665' @ 110 ft/hr)
725 GPM = 3050 psi
120 RPM = 10-15K TQ
WOB = 20-28K
ECD = 11.58 ppg
PUWT = 187K, SOWT = 120K, ROTW
= 148K, Off bottom TQ = 10.5 @ 20
RPM
ADT = 4.6 hrs, Jars = 64.1 hrs
7,739.0 8,404.0
3/19/2020
06:00
3/19/2020
12:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 8404' to 9018' MD, 4562' TVD.
(614' @ 102 ft/hr)
725 GPM = 3340 psi
120 RPM = 14.5K TQ
WOB = 20-28K
ECD = 11.87 ppg
PUWT = 195K, SOWT = 122K, ROTW
= 147K, Off bottom TQ = 11.5K @ 20
RPM
ADT = 5.0 hrs, Jars = 69.1 hrs
8,404.0 9,018.0
3/19/2020
12:00
3/19/2020
16:15
4.25 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 9018' to 9465' MD, 4675' TVD.
(447' @ 105 ft/hr)
725 GPM = 3250 psi
120 RPM = 16K TQ
WOB = 20-28K
ECD = 11.78 ppg
PUWT = 200K, SOWT = 123K, ROTW
= 150K, Off bottom TQ = 12K @ 20
RPM
ADT = 3.5 hrs, Jars = 72.6 hrs
9,018.0 9,465.0
3/19/2020
16:15
3/19/2020
17:15
1.00 INTRM1 DRILL RGRP T Change out mud line o-ring.
Verify Rhino Reamer open. ICP @
725 GPM = 3490 psi, FCP @ 725
GPM = 3150 psi
9,465.0 9,465.0
Rig: DOYON 19
Page 11/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/19/2020
17:15
3/19/2020
18:00
0.75 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 9465' to 9537' MD, 4695' TVD.
725 GPM = 3100 psi
120 RPM = 14K TQ
WOB = 20-28K
ECD = 11.78 ppg
PUWT = 205K, SOWT = 125K, ROTW
= 155K, Off bottom TQ = 12K @ 20
RPM
ADT = .5 hrs, Jars = 73.1 hrs
9,465.0 9,537.0
3/19/2020
18:00
3/19/2020
21:45
3.75 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 9537' to 10009 MD, 4828' TVD.
(472' @ 125 ft/hr)
725 GPM = 3350 psi
120 RPM = 19K TQ
WOB = 25-28K
ECD = 11.42 ppg
PUWT = 216K, SOWT = 123K, ROTW
= 159K, Off bottom TQ = 13.5K @ 20
RPM
ADT = 3 hrs, Jars = 76.1 hrs
SPR@ 10102' MD, 4855 TVD, MW =
9.8 ppg
#1 MP - 25/35 SPM = 300/400 psi
#2 MP - 25/35 SPM = 290/ 400 psi
9,537.0 10,009.0
3/19/2020
21:45
3/19/2020
22:15
0.50 INTRM1 DRILL SVRG P Replace swab on Pump #2, Service
rig
R&R DP AT 60 RPM. 160 GPM = 510
PSI
10,009.0 10,009.0
3/19/2020
22:15
3/20/2020
00:00
1.75 INTRM1 DRILL DRLG P Drill 9 7/8" x 11" Intermediate section
F/10009' to 10195' MD, 4828' TVD.
(186' @106 ft/hr)
725 GPM = 3350 psi
120 RPM = 19K TQ
WOB = 25-28K
ECD = 11.42 ppg
PUWT = 216K, SOWT = 123K, ROTW
= 159K, Off bottom TQ = 13.5K @ 20
RPM
ADT = 1.3 hrs, Jars = 77.4 hrs
10,009.0 10,195.0
3/20/2020
00:00
3/20/2020
06:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/10195' to 10842' MD, 5066' TVD.
(647' @107 ft/hr)
725 GPM = 3020 psi
120 RPM = 19K TQ
WOB = 25-28K
ECD = 11.02 ppg
Max gas = 28 units
PUWT = 235K, SOWT = 126K, ROTW
= 167K, Off bottom TQ = 15K @ 20
RPM
ADT = 4.9 hrs, Jars = 82.3 hrs
10,195.0 10,842.0
Rig: DOYON 19
Page 12/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/20/2020
06:00
3/20/2020
12:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 10842' to 11239 MD, 5178' TVD.
(387' @ 65 ft/hr)
725 GPM = 3220 psi
120 RPM = 17K TQ
WOB = 25K
ECD = 11.11 ppg
Max gas = 97 units
PUWT = 220K, SOWT = 130K, ROTW
= 162K, Off bottom TQ = 14K @ 20
RPM
ADT = 4.9 hrs, Jars = 87.2 hrs
SPR@ 11045' MD, 5125' TVD, MW =
9.8+ ppg
#1 MP - 25/35 SPM = 200/280 psi
#2 MP - 25/35 SPM = 210/ 290 psi
10,842.0 11,239.0
3/20/2020
12:00
3/20/2020
18:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 11239' to 11685 MD, 5304' TVD.
(446' @ 74 ft/hr)
725 GPM = 3240 psi
140 RPM = 18K TQ
WOB = 25K
ECD = 11.26 ppg
Max gas = 139 units
PUWT = 225K, SOWT = 130K, ROTW
= 162K, Off bottom TQ = 15K @ 20
RPM
ADT = 5.0 hrs, Jars = 92.2 hrs
11,239.0 11,685.0
3/20/2020
18:00
3/21/2020
00:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 11685' to 12183' MD, 5447' TVD.
(498' @ 83 ft/hr)
725 GPM = 3260 psi
120 RPM = 15K TQ
WOB = 22K
ECD = 11.23 ppg
Max gas = 100 units
PUWT = 211K, SOWT = 141K, ROTW
= 172K, Off bottom TQ = 11K @ 20
RPM
ADT = 5.2 hrs, Jars = 97.4 hrs
SPR@ 12183' MD, 5447' TVD, MW =
9.9 ppg
#1 MP - 25/35 SPM = 280/390 psi
#2 MP - 25/35 SPM = 310/ 400 psi
11,685.0 12,183.0
3/21/2020
00:00
3/21/2020
00:15
0.25 INTRM1 DRILL SVRG P Change swab and liner on pump #2 -
Circ cond mud @ 150 GPM 500 PSI -
Rot @ 60 RPM 9.5k TQ - 167k Rot
WT
12,183.0 12,183.0
3/21/2020
00:15
3/21/2020
01:30
1.25 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 12183' to 12277' MD, 5474' TVD.
(94' @ 75 ft/hr)
750 GPM = 3240 psi
140 RPM = 17K TQ
WOB = 22-25K
ECD = 11.30 ppg
Max gas = 100 units
PUWT = 211K, SOWT = 141K, ROTW
= 171K, Off bottom TQ = 11K @ 20
RPM
ADT = .7 hrs, Jars = 98.1 hrs
12,183.0 12,277.0
3/21/2020
01:30
3/21/2020
03:00
1.50 INTRM1 DRILL CIRC P Circ 2 B/U @ 750 GPM 3310 PSI ROt
@ 140 RPM 9K TQ 160K ROT WT -
PJSM for MPD Bearing install
12,277.0 12,277.0
Rig: DOYON 19
Page 13/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/21/2020
03:00
3/21/2020
03:45
0.75 INTRM1 DRILL SEQP P Flow Check static - Install MPD
bearing - Circ thru MPD System -
Break Circ break in RCD with 200
GPM 350 PSI - Rot @ 20 RPM 11K
TQ 163k Rot Wt - Verify system
function properly
12,277.0 12,277.0
3/21/2020
03:45
3/21/2020
05:45
2.00 INTRM1 DRILL DRLG P Drill 9 7/8" x 11" Intermediate section
F/12277' to 12430' MD, 5516' TVD.
(153' @ 76 ft/hr)
750 GPM = 3240 psi
140 RPM = 16K TQ
WOB = 20-24K
ECD = 11.23 ppg
Max gas = 194 units
PUWT = 210K, SOWT = 143K, ROTW
= 173K, Off bottom TQ = 11K @ 20
RPM
ADT = 1.6 hrs, Jars = 99.7 hrs
12,277.0 12,430.0
3/21/2020
05:45
3/21/2020
06:30
0.75 INTRM1 DRILL CIRC T Change swab and liner on pump #2 -
Circ cond mud @ 150 GPM 540 PSI
450 GPM 1510 PSI - Rot @ 20-80
RPM 9.5k TQ - 165k Rot WT
12,430.0 12,430.0
3/21/2020
06:30
3/21/2020
08:00
1.50 INTRM1 DRILL DRLG P Drill 9 7/8" x 11" Intermediate section
F/12430' to 12562' MD, 5553' TVD.
(132 @ 88 ft/hr)
750 GPM = 3450 psi
140 RPM = 18K TQ
WOB = 20-24K
ECD = 11.45 ppg
Max gas = 75 units
PUWT = 210K, SOWT = 143K, ROTW
= 173K, Off bottom TQ = 11K @ 20
RPM
ADT = 1.1 hrs, Jars = 100.8 hrs
12,430.0 12,562.0
3/21/2020
08:00
3/21/2020
10:00
2.00 INTRM1 DRILL RGRP T Change swab and liner on pump #2
and change liner nut on pump #2 -
Repair valve cover gasket on MP #1 -
Circ cond mud @ 150 GPM 540 PSI
450 GPM 1510 PSI - Rot @ 20-80
RPM 9.5K TQ - 165K ROTW
12,562.0 12,562.0
3/21/2020
10:00
3/21/2020
12:00
2.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 12562' to 12751' MD, 5605' TVD.
(189' @ 95 ft/hr)
750 GPM = 3630 psi
140 RPM = 20.5K TQ
WOB = 20K
ECD = 11.83 ppg
Max gas = 75 units
PUWT = 215K, SOWT = 127K, ROTW
= 162K, Off bottom TQ = 18K @ 20
RPM
ADT = 1.6 hrs, Jars = 102.4 hrs
12,562.0 12,751.0
3/21/2020
12:00
3/21/2020
13:00
1.00 INTRM1 DRILL CIRC T Change swab and liner on pump #1
Circulate and condition mud @ 460
GPM = 1610 psi, 50 RPM = 16K TQ,
ROTW = 162K
12,751.0 12,751.0
Rig: DOYON 19
Page 14/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/21/2020
13:00
3/21/2020
17:30
4.50 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 12751' to 13062' MD, 5690' TVD.
(311' @ 69 ft/hr)
750 GPM = 3580 psi
140 RPM = 21K TQ
WOB = 25K
ECD = 11.91 ppg
Max gas = 393 units
PUWT = 215K, SOWT = 120K, ROTW
= 162K, Off bottom TQ = 20K @ 20
RPM
ADT = 3.0 hrs, Jars = 105.4 hrs
12,751.0 13,062.0
3/21/2020
17:30
3/21/2020
18:00
0.50 INTRM1 DRILL CIRC T Change swab and liner on pump #1
Circulate and condition mud @ 460
GPM = 1660 psi, 50 RPM = 13.5K TQ,
ROTW = 162K
13,062.0 13,062.0
3/21/2020
18:00
3/22/2020
00:00
6.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/ 13062' to 13518' MD, 5818' TVD.
(456' @ 76 ft/hr)
700 GPM = 3590 psi
140 RPM = 20K TQ
WOB = 30K
ECD = 12.16 ppg
Max gas = 303 units
PUWT = 240K, SOWT = 135K, ROTW
= 165K, Off bottom TQ = 20K @ 20
RPM
SPR@ 13512' MD, 5840' TVD, MW =
10.3+ ppg
#1 MP - 25/35 SPM = 520/610 psi,
MPD 200/250 BP
#2 MP - 25/35 SPM = 520/610 psi,
MPD 200/250 BP
ADT = 4.9 hrs, Jars = 110.3 hrs
13,062.0 13,518.0
3/22/2020
00:00
3/22/2020
03:00
3.00 INTRM1 DRILL DRLG P Drill 9 7/8" x 11" Intermediate section
F/ 13518' to 13749' MD, 5880' TVD.
(231' @ 77 ft/hr)
700 GPM = 3650 psi
140 RPM = 21K TQ
WOB = 20K
ECD = 12.24 ppg
Max gas = 302 units
PUWT = 255K, SOWT = 130K, ROTW
= 175K, Off bottom TQ = 19K @ 20
RPM
ADT = 2.2 hrs, Jars = 112.5 hrs
13,518.0 13,749.0
3/22/2020
03:00
3/22/2020
03:30
0.50 INTRM1 DRILL SVRG P Service rig while changing swab on
mud pump #1 - Circ @ 150 GPM 640
PSI - Rot 50 RPM 173K Rot Wt -
14.5K TQ - 240k UP - 138k DN
13,749.0 13,749.0
3/22/2020
03:30
3/22/2020
06:00
2.50 INTRM1 DRILL DRLG P Drill 9 7/8" x 11" Intermediate section
F/13749' to 13833' MD, 5903' TVD.
(84' @ 33 ft/hr)
700 GPM = 3650 psi
140 RPM = 21K TQ
WOB = 20K
ECD = 12.24 ppg
Max gas = 302 units
PUWT = 255K, SOWT = 130K, ROTW
= 175K, Off bottom TQ = 19K @ 20
RPM
ADT = 2.1 hrs, Jars = 114.6 hrs
13,749.0 13,833.0
Rig: DOYON 19
Page 15/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/22/2020
06:00
3/22/2020
11:00
5.00 INTRM1 DRILL DDRL P Drill 9 7/8" x 11" Intermediate section
F/13833' to 14043' MD, 5950' TVD.
(210' @ 42 ft/hr)
740 GPM = 3750 psi
140 RPM = 21K TQ
WOB = 28K
ECD = 11.92 ppg
Max gas = 377 units
PUWT = 255K, SOWT = 130K, ROTW
= 175K, Off bottom TQ = 19K @ 20
RPM
ADT = 4.2 hrs, Jars = 116.7 hrs
13,833.0 14,043.0
3/22/2020
11:00
3/22/2020
13:15
2.25 INTRM1 DRILL CIRC T Observed Mud and Pressure loss.
Loss rate = 180BPH
Continue to monitor G/L,
Pump at 450 GPM = 1670 psi
14,043.0 14,043.0
3/22/2020
13:15
3/22/2020
14:00
0.75 INTRM1 DRILL CIRC T Pump LCM pill #1 at 14035' MD.
Pump 30 BBL - 35 PPB LCM Pill loose
48 total BBLS
Hold BP with MPD, CBU, 250 GPM =
1670 psi,
Max gas = 2019 units
Experiencing mud losses.
Adjusted Pump rate and MPD
pressure to stabilize G/L
14,043.0 14,043.0
3/22/2020
14:00
3/22/2020
18:00
4.00 INTRM1 DRILL CIRC T Observe Pit gain
Shut well in and line up on choke
manifold and Gas Buster.
SIDPP = 630 psi, SICP = 510 psi
Discuss options with town engineers
Pump at 40 spm, DPP = 710 psi, CP =
630 psi
Pump at 20 spm, DDP = 630 psi, CP =
660 psi
14,043.0 14,043.0
3/22/2020
18:00
3/22/2020
19:30
1.50 INTRM1 DRILL CIRC T Cont Circ thru choke manifold @ 23
SPM 660 PSI Shut in on DP Casing
pressure = 610 PSI - Monitor returns
for loss rate @ 144-180 bph loss rate.
Attempt to improve returns
14,043.0 14,043.0
3/22/2020
19:30
3/23/2020
00:00
4.50 INTRM1 DRILL CIRC T Line up pump #1 on MPD equalize
pressure @ 625 PSI - open rams -
Est. and mantain circ @ 740 psi -
pumping thru string and MPD system -
P/U attempt to break string over @
277k - no good - Rot @ 10 RPM -
break free - Rot @ 10 RPM 185k Rot
Wt TQ = 21-26K - Cont Circ out gas
thru MPD choke system thru the gas
buster @ 130 GPM 850 PSI with 93
GPM on pump 1 on MPD - Monitor
returns and loss rate - Loss rate of 20-
40%
14,043.0 14,043.0
3/23/2020
00:00
3/23/2020
03:45
3.75 INTRM1 DRILL CIRC T Continue to circulate thru MPD choke.
135 GPM = 850 psi. MPD 518 psi BP
10 RPM = 26K TQ, ROTW = 173K
Take returns thru gas buster. Observe
gas breaking out in mud.
Monitor G/L, ~30% loss rate
14,043.0 14,043.0
Rig: DOYON 19
Page 16/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/23/2020
03:45
3/23/2020
06:00
2.25 INTRM1 DRILL CIRC T Pump LCM pill #2
31 bbl 10.2 ppg, 15 ppb Walnut Plug
Med and 20 ppb Mix2 Fine.
168 GPM = 950 psi, Squeeze away 30
BBLS LCM into formation with MPD @
620 psi BP.
Cont circulate taking returns thru gas
buster holding BP with MPD @ 504
psi.
ROWT = 174K = 26K TQ, 10 RPM
Monitor loss rates
14,043.0 14,043.0
3/23/2020
06:00
3/23/2020
08:00
2.00 INTRM1 DRILL CIRC T Remove MP#1 F/ MPD annulus line.
Stage pump up to 550 GPM = 2430
psi.
Hold 321 psi on MPD, Rot at 13 RPM
= 23.5K TQ
ECD = 11.97 ppg
14,043.0 14,043.0
3/23/2020
08:00
3/23/2020
08:30
0.50 INTRM1 DRILL CIRC T Attempt to move Drill string =
unsuccessful
Rotate at 60 RPM = 25K TQ, Pipe
began stalling out at 30K.
Reduce flow rate to 400 GPM = 1750
psi, MPD @ 400 psi and work pipe
free.
Current loss of 68 bbl
14,043.0 14,043.0
3/23/2020
08:30
3/23/2020
10:45
2.25 INTRM1 DRILL CIRC T Stage pumps up to 575 GPM = 2590
psi. MPD @ 300 psi. ECD = 12.12
ppg.
60 RPM = 22K TQ,
Observed flow increase. Line up
returns to Gas Buster, Cont Circ.
14,043.0 14,043.0
3/23/2020
10:45
3/23/2020
12:00
1.25 INTRM1 DRILL CIRC T Dynamic pore pressure test with MPD
Reduce BP in 30 psi in stages
monitoring ECDs.
Began with 300 psi on MPD, Stepped
down in 30 psi increments to 90 psi
Pore pressure equal to 11.55 ppg
ECD
14,043.0 14,043.0
3/23/2020
12:00
3/23/2020
14:45
2.75 INTRM1 DRILL CIRC T R&R DP and Circulate. 585 GPM =
2520 psi, MPD @ 200 psi.
100 RPM = 25K TQ, ECD = 11.89 ppg
Stage pumps up to 720 GPM = 3480
psi, MPD @130 psi.
90 RPM = 20K TQ
Obtain final survey at TD of 14043'
MD, 5950' TVD
14,043.0 14,043.0
3/23/2020
14:45
3/23/2020
15:45
1.00 INTRM1 DRILL CIRC T Pump LCM pill #3
Squeeze 30 bbl 10.2 ppg LCM pill - 15
ppb Walnut Plug Med and 20 ppb
Mix2 Fine. Squeeze away 28 BBLS
MPD attempting to hold 600 psi -
Unable to hold due to irratic return.
Adjust mud pumps and MPD to regain
balnced flow in/out.
175 GPM = 950 PSI - MPD BP = 450
PSI - 10 RPM 24K TQ
Loss all returns - pump 45 BBLS total
- Stand back stand T/ 13980' MD
14,043.0 14,043.0
3/23/2020
15:45
3/23/2020
18:00
2.25 INTRM1 DRILL CIRC T Establish Circ - Stage pumps up to
575 GPM = 2440 psi
MPD BP @ 145 psi, 11.83 ppg ECD,
80 RPM = 24KTQ.
Attempt to BROOH F/13908' - Stall
Rot @ 30K TQ - Experiencing Pack off
Close Rhino Reamer for Circulating
and pumping LCM
14,043.0 14,043.0
Rig: DOYON 19
Page 17/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/23/2020
18:00
3/23/2020
19:15
1.25 INTRM1 DRILL CIRC T Establish circ @ 570 GPM 2760 PSI -
ROT 50 RPM - 175k ROT WT - 22k
TQ - Circ establish loss rate - MPD @
120 BP
14,043.0 14,043.0
3/23/2020
19:15
3/24/2020
00:00
4.75 INTRM1 DRILL CIRC T Pump LCM Pill #4
30 BBL LCM pill - 80 ppb 10.4 PPG -
Mix 2 med 10 ppb - WNF 20 ppb -
WNM 50 ppb. Squeeze away 28
BBLS
Pump at169 GPM 660-740 PSI - ROT
@ 15 RPM 22k TQ 180k Rot WT -
Squeeze away @ 300 PSI on MPD
Release MPD back pressure - Monitor
flow out - stage pumps to 570 GPM
2790 PSI.
Cont circ. R&R DP- Maintain 11.8
PPG ECD with MPD
Pump LCM Pill #5
27 BBL - 80 PPB 10.4 PPG - Mix 2
med 10 ppb - WNF 20 PPB - WNM 50
PPB Squeeze away 25 BBLS
169 GPM 660-740 psi - Rot @ 15
RPM 21K TQ - Squeeze away with
300 PSI MPD until pill clears the bit
then release BP
Monitor flow out with MPD
system.Maintain 11.8 PPG ECD with
MPD
Stage pumps up to 570 GPM = 2800
PSI - Cont work pipe and monitor loss
rate and flow out.
14,043.0 14,043.0
Rig: DOYON 19
Page 18/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/24/2020
00:00
3/24/2020
06:00
6.00 INTRM1 DRILL CIRC T Pump LCM Pill #6
50 BBL LCM pill - 80 ppb 10.4 PPG -
Mix 2 med 10 ppb - WNF 20 ppb -
WNM 50 ppb.
Pump at169 GPM 660-740 PSI - ROT
@ 18 RPM 19k TQ 180k Rot WT -
Squeeze away @ 310 PSI on MPD
mantain a 11.8PPG ECD
Release MPD back pressure -
Squeeze away 50 BBLS total
Monitor flow out - stage pumps to 570
GPM 2830 PSI.
Cont circ. R&R DP
Pump LCM Pill #7
30 BBL - 80 PPB 10.4 PPG - Mix 2
med 10 ppb - WNF 20 PPB - WNM 50
PPB
218 GPM 920 psi - Rot @ 15 RPM
21K TQ - Squeeze @ 78 GPM 650
PSI with 310 PSI MPD until pill clears
the bit then release BP
Squeeze away a total of 44 BBLS total
Monitor flow out with MPD system.
Maintain a 11.8 PPG ECD
Stage pumps up to 570 GPM = 2750
PSI - Cont work pipe and monitor loss
rate and flow out.
Pump LCM Pill #8
61 BBL - 80 PPB 10.4 PPG - Mix 2
med 10 ppb - WNF 20 PPB - WNM 50
PPB
218 GPM 960 psi - Rot @ 18 RPM
18K TQ - Squeeze @ 78 GPM 680
PSI with 375 PSI MPD until pill clears
the bit then release BP
squeeze away a total of 63 BBLS
Monitor flow out with MPD system.
Maintain a 11.8 PPG ECD
Stage pumps up to 570 GPM = 2750
PSI - Cont work pipe and monitor loss
rate and flow out.
14,043.0 14,043.0
3/24/2020
06:00
3/24/2020
08:30
2.50 INTRM1 DRILL CIRC T Cont Circ @ 575 GPM 2860 PSI - Rot
@ 40 RPM 18K TQ 162K Rot Wt -
MPD @ 220 psi to maintain 11.8PPG
ECD
14,043.0 14,043.0
3/24/2020
08:30
3/24/2020
12:00
3.50 INTRM1 DRILL CIRC T Pump LCM Pill #9
This is Form A Block pill #1
Pump 20 BBLS Form-a-Block 35 PPB
Pill @ 4 BPM 800 PSI MPD @ 310
PSi to maintain a 11.8 PPG ECD - @
2100 STKS slow to 2 BPM 610 PSi
Bring MPD to 370 PSI to squeeze
away 37 BBLS total
Stage pumps up to 5 BPM 900 PSI -
MPD @ 300 PSI to Maintain a 11.8
PPG ECD
14,043.0 14,043.0
3/24/2020
12:00
3/24/2020
18:00
6.00 INTRM1 DRILL CIRC T Pump LCM Pill #10
This is Form A Block pill #2
Pump 45 BBLS Form-a-Block Pill, 35
PPB @ 5 BPM 870 PSI MPD @ 285
PSI - @ 2230 STKS slow to 2 BPM
310 PSI Bring MPD to 388 PSI to
squeeze away 45 BBLS total
Stage pumps up to 13 BPM/570 GPM
= 2770 PSI - MPD @ 224 PSI, ECD =
11.83 PPG
14,043.0 14,043.0
Rig: DOYON 19
Page 19/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/24/2020
18:00
3/24/2020
22:15
4.25 INTRM1 DRILL CIRC T Cont circ and R&R DP @ 13908' -
Stage pumps to 570 GPM 2800 PSI -
Hold 220 PSI with MPD to maintain a
11.9 PPG ECD -
40 RPM = 19K TQ 165K Rot WT -
Monitor loss rate, gains, and bottoms
up,
Mix Form-A-Block LCM pill in pit 6
14,043.0 14,043.0
3/24/2020
22:15
3/25/2020
00:00
1.75 INTRM1 DRILL CIRC T Pump LCM pill #11
This is Form A Block pill #3
Pump 68 BBL Form a Block Pill , 35
PPB @ 5 BPM 880 PSI - Holding 11.9
ECD with MPD @ 305 PSI
Stg #1 = Hold BP with MPD at 393 -
398 psi, and attempt to squeeze LCM
at 13975' MD. Observe no indication
of squeeze. 70 BBLS
Stg #2 = Hold BP with MPD at 374 -
385 psi, and attempt to squeeze LCM
at 12100' MD. Observe no indication
of squeeze. 70 BBLS
Continue Sqeeze stages after
midnight.
14,043.0 14,043.0
3/25/2020
00:00
3/25/2020
04:00
4.00 INTRM1 DRILL CIRC T Cont to Pump LCM pill #11
This is Form A Block pill #3
35 PPB At 219 GPM 880 PSI - while
holding MPD back pressure @ 305
PSI
Squeeze LCM @ 85 GPM 570 PSI -
MPD at 380-390 PSI no returns
Squeeze 70 BBLS away @ 11400'
Squeeze 70 BBLS away @ 8400'
Squeeze 70 BBLS away @ 4300'
Total squeezed away is 348 BBLS
14,043.0 14,043.0
3/25/2020
04:00
3/25/2020
07:30
3.50 INTRM1 DRILL CIRC T Circ and R&R DP @ 13908' MD
Stage pumps to 570 GPM 2740PSI -
Hold 225 PSI with MPD to maintain a
11.8 PPG ECD -
40 RPM = 19K TQ 165K Rot WT -
Monitor loss rate, gains, and bottoms
up,
Mix #4 Form-A-Block LCM pill in pit 6
14,043.0 14,043.0
3/25/2020
07:30
3/25/2020
09:00
1.50 INTRM1 DRILL CIRC T Pump 38 BBL 50 PPB nut plug sweep
to gauge hole
17.5 PPB NPF
32.5 PPB NPM
At 570 GPM 2750 PSI
Sweep back @ 11,800 STKS
Calc STKS = 14504 - 270 BBLS early
Lost communication with LWD tools.
14,043.0 14,043.0
3/25/2020
09:00
3/25/2020
09:45
0.75 INTRM1 DRILL CIRC T Circ and R&R DP @ 13908' MD
Stage pumps to 570 GPM 2740PSI -
Hold 225 PSI with MPD to maintain a
11.8 PPG ECD -
40 RPM = 19K TQ 165K Rot WT -
Monitor Gain / loss
14,043.0 14,043.0
3/25/2020
09:45
3/25/2020
11:00
1.25 INTRM1 DRILL CIRC T Pump LCM pill #12,
This is Form-a-Block pill #4
Pump 70 bbls 35 PPB pill, Squeeze
into formation plus 56 BBLS mud, 210
GPM = 930 psi, Hold 386 psi BP with
MPD.
20 RPM = 20K TQ, Total squeeze =
126 bbls
14,043.0 14,043.0
Rig: DOYON 19
Page 20/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/25/2020
11:00
3/25/2020
14:00
3.00 INTRM1 DRILL CIRC T Circulate and R&R DP. 385 GPM =
1580 psi, ROWT = 162K, 40 RPM =
18K TQ, Hold 265 psi BP with MPD.
At BU from pumping squeeze
observed pill across shakers.
14,043.0 14,043.0
3/25/2020
14:00
3/25/2020
14:15
0.25 INTRM1 DRILL CIRC T Open Rhino-reamer per SLB Rep.
ICP = 2860 psi @ 580 GPM, MPD =
221 psi BP, 40 RPM = 18K.
FCP = 2560 psi @ 580 GPM, MPD =
223 psi BP
Verify opened W/ 300 psi Diff pressure
Stand back STD #142 - T/13890'
14,043.0 14,043.0
3/25/2020
14:15
3/25/2020
15:15
1.00 INTRM1 DRILL BKRM T Attempt to back ream out of hole F/
13890' to 13860' MD
Noticed pressure loss of 420 psi
Troubleshoot pressure loss. Wash out
seems to be above floats.
Unable to close Reamer due to loss of
pressure/
14,043.0 14,043.0
3/25/2020
15:15
3/25/2020
16:00
0.75 INTRM1 DRILL STRP T Attempt to strip out of hole F/ 13860'
to 13791' MD. 250 GPM = 740 psi,
MPD = 307psi
Observed pressure on DP after
bleeding off.
14,043.0 14,043.0
3/25/2020
16:00
3/25/2020
17:45
1.75 INTRM1 DRILL CIRC T Circ at 315 GPM = 500 psi, Hold 315
psi BP
14,043.0 14,043.0
3/25/2020
17:45
3/25/2020
18:00
0.25 INTRM1 DRILL CIRC T Attempt to close floats. Observe
pressure equalization of annulus and
drill pipe, indicating wash out above
floats.
14,043.0 14,043.0
3/25/2020
18:00
3/26/2020
00:00
6.00 INTRM1 DRILL CIRC T Discuss options with Town; Plan to
weight up hole volume with 11.8 ppg
LSND
Continue to Circulate @ 80 GPM =
510 psi. MPD = 315 psi BP
Weight up active system to 11.8 ppg
mud. Order 11.8 ppg from mud plant.
14,043.0 14,043.0
3/26/2020
00:00
3/26/2020
04:00
4.00 INTRM1 DRILL CIRC T Cont to circ @ 80 GPM 510 PSI while
holding 315 PSI with MPD to maintain
a 11.8 PPG ECD
Weight up active system to 11.8 ppg
mud. Order 11.8 ppg from mud plant
and transport to location.
14,043.0 14,043.0
3/26/2020
04:00
3/26/2020
13:45
9.75 INTRM1 CASING CIRC P PJSM, Displace well to 11.8 ppg
KWM.
Stage pumps up to 5 BPM. ICP @ 210
GPM = 580 PSI, FCP = 300 PSI, FCP
@ 130 GPM = 300 PSI
Hold BP with MPD per schedule. Final
MPD = 67 PSI
Build mud and add to active system as
needed.
Pump total of 1840 BBLS 11.8 ppg
KWF
14,043.0 14,043.0
3/26/2020
13:45
3/26/2020
14:45
1.00 INTRM1 CASING OWFF P OWFF W/ MPD Static test. Pump @
130 GPM = 130 PSI. Static
14,043.0 14,043.0
3/26/2020
14:45
3/26/2020
19:30
4.75 INTRM1 CASING PMPO P Pump OOH F/ 13855' to 12853' MD,
above HRZ,
90 GPM = 190 PSI, Hold BP W/ MPD
@ 50 PSI with MP#1 @ 125 GPM
PUWT = 250 - 290K SOWT = 125 -
100K
Pulled tight/worked thru at 13197' MD
14,043.0 14,043.0
3/26/2020
19:30
3/26/2020
20:00
0.50 INTRM1 CASING OWFF P OWFF - Monitor returns at Trip Tank
and MPD return meter = Good
14,043.0 14,043.0
Rig: DOYON 19
Page 21/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/26/2020
20:00
3/27/2020
00:00
4.00 INTRM1 CASING PMPO P Pump OOH F/12853' to 11455' MD, 90
GPM = 170 PSI, Hold BP W/ MPD @
50 psi w MP#1
Worked pipe thru tight spots at 11675',
11607', 11614' MD
PUWT = 235 - 280K, SOWT = 132 -
102K
Found wash-out below box end tool
joint in bottom single of stand #116.
from a depth of ~2518' MD
L/D wash out joint.
14,043.0 14,043.0
3/27/2020
00:00
3/27/2020
04:30
4.50 INTRM1 CASING PMPO P Pump OOH F/11455' T/9542' - @ 90
GPM = 390 PSI - Hold 50 PSI on MPD
- PUWT = 218K, SOWT = 117K
14,043.0 14,043.0
3/27/2020
04:30
3/27/2020
05:15
0.75 INTRM1 CASING TRIP P SOOH on Elev F/9542' T/8755' - with
70 PSI on MPD - 215K up113K DN -
Pulling 30-40K over @ 8800'
14,043.0 14,043.0
3/27/2020
05:15
3/27/2020
08:45
3.50 INTRM1 CASING PMPO P Pump OOH F/8755' T/ 7935' -
pumping 90 GPM 320 PSI - with 25
PSI on MPD - 195k UP 110K DN.
Observed LCM material and
formabloc material coming over
shakers.Start taking losses @ 35 BPH
- decide to spot a pill
14,043.0 14,043.0
3/27/2020
08:45
3/27/2020
12:00
3.25 INTRM1 CASING CIRC P Circ @ 2 BPM @ 300 PSI - while
building LCM pill - work pipe F/7935'
T/7840' - 185K UP 120K dn - pull 45-
55K over @ 7895'
14,043.0 14,043.0
3/27/2020
12:00
3/27/2020
13:30
1.50 INTRM1 CASING CIRC P CIrc @ 7935' - spot LCM pill #13
85 BBLS @ 2.7 BPM 510 PSI w/ 125-
102 PSI on MPD
Squeeze a total of 88 BBL's - 180K
UP 120K DN
100 PPB Pill
WPM - 62.5 PPB
WPF - 25 PPB
Mix 2 fine 12.5 PPB
14,043.0 14,043.0
3/27/2020
13:30
3/27/2020
16:00
2.50 INTRM1 CASING PMPO P Pump OOH F/7935' T/7363' - W/84
GPM 300 PSI with 30 PSI on MPD -
work thru tight spot @ 7840' - 30K
over pull - decide to rotate W/20 RPM
10-20K TQ - clean up
14,043.0 14,043.0
3/27/2020
16:00
3/27/2020
21:30
5.50 INTRM1 CASING TRIP P SOOH F/7363' T/3580' - W/ MPD
holding 100 PSI while pulling and 30
PSI in slips -
175K UP 120K DN
14,043.0 14,043.0
3/27/2020
21:30
3/27/2020
23:00
1.50 INTRM1 CASING CIRC P CBU at surface casing shoe.
Stage pumps up to 190 GPM 400 PSI
- Rot @ 20 RPM w/4K TQ
125K Rot Wt - Monitor loss rate, Circ
until shakers clean
14,043.0 14,043.0
3/27/2020
23:00
3/28/2020
00:00
1.00 INTRM1 CASING OWFF P OWFF @ Trip Tank. Start at 9 BPH
returns thru MPD flow meter, falling off
at steady rate to 1.9 BPH
Note: Continue flow check after
midnight till well static.
14,043.0 14,043.0
3/28/2020
00:00
3/28/2020
01:15
1.25 INTRM1 CASING OWFF P OWFF - At trip tank - then thru outlet
valve on MPD - slow down from 1.9
BPH to static
14,043.0 14,043.0
Rig: DOYON 19
Page 22/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/28/2020
01:15
3/28/2020
04:15
3.00 INTRM1 CASING SMPD P SOOH F/ 3580' T/ 1593' MD. Hold
MPD @ 30 PSI while in slips and 45
while pulling pipe.
PUWT = 125K - Notice improper hole
fill
14,043.0 14,043.0
3/28/2020
04:15
3/28/2020
04:45
0.50 INTRM1 CASING OWFF P OWFF - Flow check well = static 14,043.0 14,043.0
3/28/2020
04:45
3/28/2020
05:00
0.25 INTRM1 CASING CIRC P Circ @ 88 GPM = 120 PSI - Rot @ 25
RPM = 2K TQ, ROTW = 107K
Attempt to clear balled up BHA
14,043.0 14,043.0
3/28/2020
05:00
3/28/2020
06:45
1.75 INTRM1 CASING SMPD P SOOH F/1593' T/647' - Hold MPD @
30 PSI while in slips and 60 PSI while
tripping
14,043.0 14,043.0
3/28/2020
06:45
3/28/2020
07:30
0.75 INTRM1 CASING OWFF P Flow check - Static
PJSM, Pull RCD bearing, install trip
nipple, Blow down MPD lines.
14,043.0 14,043.0
3/28/2020
07:30
3/28/2020
08:00
0.50 INTRM1 CASING SVRG P Service TD and Draw works, SIMOPS
= change out leaking 20" air boot on
stack.
14,043.0 14,043.0
3/28/2020
08:00
3/28/2020
08:30
0.50 INTRM1 CASING TRIP P Stand back HWDP and jars
PJSM to L/D Baker BHA
14,043.0 14,043.0
3/28/2020
08:30
3/28/2020
11:15
2.75 INTRM1 CASING BHAH P L/D 9 7/8" X 11" Intermediate BHA #2
and beak bit as per Baker DD
Note:Reamer and Bit packed off w/
cuttings.and clay
14,043.0 14,043.0
3/28/2020
11:15
3/28/2020
12:15
1.00 INTRM1 CASING WWWH P M/U stack washer. Jet WH and stack
Pull wear bushing.
14,043.0 14,043.0
3/28/2020
12:15
3/28/2020
14:15
2.00 INTRM1 CASING BOPE P C/O upper pipe rams to 7 5/8" casing
rams.
SIMOPS, Clean and clear rig floor of
BHA tools and equipment.
14,043.0 14,043.0
3/28/2020
14:15
3/28/2020
15:00
0.75 INTRM1 CASING BOPE P R/U test equipment. Install test plug
and 7 5/8" test joint, Flood lines, C/O
seal on test plug and re-install
14,043.0 14,043.0
3/28/2020
15:00
3/28/2020
16:30
1.50 INTRM1 CASING BOPE P Test 7 5/8" upper pipe rams to 250 /
3500 psi, 5 min each.
Test annular 250 / 2500 psi, 5 min
each, charted.
R/D test joint and equipment. BD
lines.
14,043.0 14,043.0
3/28/2020
16:30
3/28/2020
18:30
2.00 INTRM1 CASING RURD P Mobilize GBR casing tools to rig floor.
R/U Volant CRT, bales, slips etc. M/U
safety valve,
14,043.0 14,043.0
3/28/2020
18:30
3/28/2020
19:15
0.75 INTRM1 CASING PUTB P PJSM, M/U 7 5/8", 29.7#, L80, Hydril
563, casing Shoe track,
Bakerlok all connections thru pin on jt
#4. Check floats = Good
14,043.0 14,043.0
3/28/2020
19:15
3/29/2020
00:00
4.75 INTRM1 CASING PUTB P Run 7 5/8" casing T/ 1600'
HydroForm centralizers on every
other joint thru joint #36
Torque connections to 10,300 ft/lbs,
Fill on the fly, Top off every 10 jts.
Break circulation every 20 joints and
pump 50 bbls @ 2-4 BPM
Monitor loss rate
14,043.0 14,043.0
3/29/2020
00:00
3/29/2020
05:00
5.00 INTRM1 CASING PUTB P RIH w/ 7 5/8" casing F/1600' T/3599' -
circ 50 BBLS every 20 JTS - stage up
to 4 BPM 120 PSI - 125K UP
14,043.0 14,043.0
3/29/2020
05:00
3/29/2020
06:15
1.25 INTRM1 CASING CIRC P Circ B/U stage pump up to 4 BPM 160
PSI - 135K UP 127K DN - monitor loss
rate - zero losses
14,043.0 14,043.0
3/29/2020
06:15
3/29/2020
09:15
3.00 INTRM1 CASING PUTB P RIH w/ 7 5/8" casing F/3599' T/4617' -
150K UP
Cent installed every other JTS to # 87
14,043.0 14,043.0
Rig: DOYON 19
Page 23/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/29/2020
09:15
3/29/2020
09:45
0.50 INTRM1 CASING CIRC P Circ stage pumps up to 2 BPM 210
PSI - Monitor losses 51% loss rate @
2 BPM - 150k UP
14,043.0 14,043.0
3/29/2020
09:45
3/29/2020
13:15
3.50 INTRM1 CASING PUTB P RIH with 7 5/8" casing F/ 4617'' T/
5435' MD
PUWT = 162K, SOWT = 125K
14,043.0 14,043.0
3/29/2020
13:15
3/29/2020
13:45
0.50 INTRM1 CASING CIRC P Circulate & condition mud, 2 BPM =
230 PSI,
Loss rate = 90%
14,043.0 14,043.0
3/29/2020
13:45
3/29/2020
16:45
3.00 INTRM1 CASING PUTB P RIH with 7 5/8" casing F/ 5435'' T/
6249' MD
PUWT = 175K, SOWT = 125K
Maintain 400-500 FPH running speed
14,043.0 14,043.0
3/29/2020
16:45
3/29/2020
17:30
0.75 INTRM1 CASING CIRC P Circulate & condition mud, ICP @ 2
BPM = 210 PSI, FCP @ 2 BPM = 220
PSI
No displacement returns on down
stroke. Partial returns on up stroke
while pumping.
Loss rate = 100%
14,043.0 14,043.0
3/29/2020
17:30
3/29/2020
20:45
3.25 INTRM1 CASING PUTB P RIH with 7 5/8" casing F/ 6249'' T/
7045' MD
PUWT = 180K, SOWT = 125K
14,043.0 14,043.0
3/29/2020
20:45
3/29/2020
21:30
0.75 INTRM1 CASING CIRC P Circulate & condition mud, ICP @ 2
BPM = 310 PSI, FCP @ 2 BPM = 270
PSI
No displacement returns on down
stroke. Partial returns on up stroke
while pumping.
Loss rate = 100%
14,043.0 14,043.0
3/29/2020
21:30
3/30/2020
00:00
2.50 INTRM1 CASING PUTB P RIH with 7 5/8" casing F/7045'' T/7704'
MD
PUWT = 190K, SOWT = 125K
14,043.0 14,043.0
3/30/2020
00:00
3/30/2020
00:30
0.50 INTRM1 CASING PUTB P RIH W/7 5/8" casing F/7704' T/7860' -
127K DN
14,043.0 14,043.0
3/30/2020
00:30
3/30/2020
01:15
0.75 INTRM1 CASING CIRC P CIRC 50 BBLS @ 2 BPM on the up
stroke, pumps off on the down stroke
2 BPM 310 PSI - 194K UP 128K DN -
100% losses
14,043.0 14,043.0
3/30/2020
01:15
3/30/2020
04:15
3.00 INTRM1 CASING PUTB P RIH W/7 5/8" casing F/7860' T/8665' -
127K DN
14,043.0 14,043.0
3/30/2020
04:15
3/30/2020
05:00
0.75 INTRM1 CASING CIRC P CIRC 50 BBLS @ 2 BPM on the up
stroke, pumps off on the down stroke
2 BPM 350 PSI - 210K UP 126K DN -
100% losses
14,043.0 14,043.0
3/30/2020
05:00
3/30/2020
08:00
3.00 INTRM1 CASING PUTB P RIH W/7 5/8" casing F/8665' T/9485' -
127K DN
14,043.0 14,043.0
3/30/2020
08:00
3/30/2020
08:45
0.75 INTRM1 CASING CIRC P CIRC 37 BBLS @ 2 BPM on the up
stroke, pumps off on the down stroke
2 BPM 390 PSI - 215K UP 125K DN -
100% losses
14,043.0 14,043.0
3/30/2020
08:45
3/30/2020
12:00
3.25 INTRM1 CASING PUTB P RIH W/7 5/8" casing F/ 9485' T/10300'
MD -
225K UP, 125K DN
14,043.0 14,043.0
3/30/2020
12:00
3/30/2020
12:30
0.50 INTRM1 CASING CIRC P CIRC 40 BBLS @ 2.5 BPM = 390 PSI
on the up stroke, pumps off on the
down stroke
225K UP 125K DN - 100% losses
14,043.0 14,043.0
3/30/2020
12:30
3/30/2020
15:00
2.50 INTRM1 CASING PUTB P RIH W/7 5/8" casing F/ 10300'
T/11106' MD
230K UP, 127K DN
14,043.0 14,043.0
Rig: DOYON 19
Page 24/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/30/2020
15:00
3/30/2020
15:45
0.75 INTRM1 CASING CIRC P CIRC 40 BBLS @ 2.5 BPM = 430 PSI
on the up stroke, pumps off on the
down stroke
235K UP 127K DN - 100% losses
14,043.0 14,043.0
3/30/2020
15:45
3/30/2020
18:45
3.00 INTRM1 CASING PUTB P RIH W/7 5/8" casing F/ 11106'
T/11911' MD - 129K DN
14,043.0 14,043.0
3/30/2020
18:45
3/30/2020
19:30
0.75 INTRM1 CASING CIRC P CIRC 40 BBLS @ 2.5 BPM = 510 PSI
on the up stroke, pumps off on the
down stroke
250K UP 130K DN - 100% losses
14,043.0 14,043.0
3/30/2020
19:30
3/30/2020
22:15
2.75 INTRM1 CASING PUTB P RIH W/7 5/8" casing F/ 11191' T/
12724' MD - 129K DN
14,043.0 14,043.0
3/30/2020
22:15
3/30/2020
22:45
0.50 INTRM1 CASING CIRC P CIRC 40 BBLS @ 2.5 BPM = 600 PSI
on the up stroke, pumps off on the
down stroke
262K UP 124K DN - 100% losses
14,043.0 14,043.0
3/30/2020
22:45
3/31/2020
00:00
1.25 INTRM1 CASING PUTB P RIH W/7 5/8" casing F/ 12724' T/
13063' MD - 130K DN
14,043.0 14,043.0
3/31/2020
00:00
3/31/2020
01:45
1.75 INTRM1 CASING PUTB P RIH with 7 5/8" casing F/13063'
T/13535' - 128K DN
14,043.0 14,043.0
3/31/2020
01:45
3/31/2020
02:00
0.25 INTRM1 CASING CIRC P Circ @ 2.5 BPM 670 PSI on up
stroke , no pumps on down stroke -
100% loss rate - 285k UP 127K DN
14,043.0 14,043.0
3/31/2020
02:00
3/31/2020
04:00
2.00 INTRM1 CASING PUTB P RIH with 7 5/8" casing F/13535'
T/14004' - 312K UP 126K DN
14,043.0 14,043.0
3/31/2020
04:00
3/31/2020
04:30
0.50 INTRM1 CASING PUTB P M/U 7 5/8" hanger and landing joint as
per Cameron - RIH T/14038' land out
in wellhead
14,043.0 14,043.0
3/31/2020
04:30
3/31/2020
11:00
6.50 INTRM1 CASING CIRC P Circ @ 1 BPM - 600 PSI ICP- 470 PSI
FCP - P/U 300K - 125K DN - work
pipe twice - PSI up 50 pounds - take
35K over on the up stroke and 35K
DN on the down stroke - land casing
in wellhead @ 14038' shoe depth
while waiting on cementers to get on
location
Rig up cementers and blow air thru
the lines - L/D xx STDs 5" DP - clean
clear rig floor
Loss rate = 100%
Cementers on location 09:30.
Cement on location 10:20.
14,043.0 14,043.0
3/31/2020
11:00
3/31/2020
12:00
1.00 INTRM1 CEMENT RURD P RU cement lines to Baker swivel and
continue to circulate.
Cementers and equipment on location
- Stage pumps up to 1 BPM 450 PSI.
RU cement equipment and lines.
14,043.0 14,043.0
Rig: DOYON 19
Page 25/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
3/31/2020
12:00
3/31/2020
16:45
4.75 INTRM1 CEMENT CMNT P Pressure test cement lines 1000 /3500
low/high psi. Pump 57 bbls of 12.0
ppg tuned spacer at 4 BPM with 740
psi. Drop bottom plug and pumped
187 bbl of 14.0 ppg lead cement at 4
BPM with 830 psi. Pump 45 bbl of
15.8 ppg tail cement at 3.2 BPM with
600 psi. Drop top plug with 10 bbl of
water, then chased with 632.4 bbl of
11.8 ppg LSND. ICP= 570 psi at 6
BPM. FCP= 970 psi at 4 BPM. Did
not bump plug (using 96% efficiency
on pumps) with no returns throughout
job. Held 500 psi for 5 minutes, bled
back 1.5 bbl and floats held. CIP at
16:45 3/30/20.
SIMOPS: Laid down 30 stands of 5"
DP.
14,043.0 14,043.0
3/31/2020
16:45
3/31/2020
18:15
1.50 INTRM1 CEMENT RURD P Blow down and rig down cement
equipment and Volant with GBR.
Install 7.625" elevators.
14,043.0 14,043.0
3/31/2020
18:15
3/31/2020
19:15
1.00 INTRM1 CEMENT WWSP P Install pack-off per Cameron rep. PT
pack-off to 5000 psi for 10 minutes,
witnessed Coman. RD well head
equipment.
14,043.0 14,043.0
3/31/2020
19:15
3/31/2020
21:30
2.25 INTRM1 CEMENT RURD P Change out top rams to 3.5"x6"
variable rams. Change save sub and
continue to prep for BOP testing.
14,043.0 14,043.0
3/31/2020
21:30
3/31/2020
23:00
1.50 INTRM1 WHDBOP BOPE P Set test plug with 3.5" test joint as per
Cameron rep.
RU and test BOPE. Fill all lines and
stack with H2O.
14,043.0 14,043.0
3/31/2020
23:00
4/1/2020
00:00
1.00 INTRM1 WHDBOP BOPE P Test BOP; with 4.5" test joint,
250/3500 psi, 2500 on annular
preventor for 5 minutes each, good.
14,043.0 14,043.0
4/1/2020
00:00
4/1/2020
05:00
5.00 INTRM1 WHDBOP BOPE P Continue test BOPs with 3.5" and 4.5"
test joints. 250/2500 psi low/high test
on annular and 250/3500 psi test on
all other BOP elements, 5 minutes
each charted test. Test 4" DEMCO
kill, choke valves 1 through 14,
manual kill, manual choke, HCR
choke and HCR kill. Test auto IBOP,
manual IBOP, outer bleeder valve,
floor FOSV and dart valves. Manual
and Super chokes, Blinds.
Perform Koomey drawdown test;
good. System - 3050 psi, PAC - 1350
psi, Int. - 200 psi recovery in 21
seconds, FSP - 153 seconds with an
average bottle of 2050 psi.
**Test Gas alarms**
AOGCC rep Austin McLeod witnessed
test.
14,043.0 14,043.0
4/1/2020
05:00
4/1/2020
05:30
0.50 INTRM1 WHDBOP RURD P RD testing equipment, blow down all
lines and pull test plug. Install 10"
wear ring as per Cameron.
14,043.0 14,043.0
4/1/2020
05:30
4/1/2020
06:00
0.50 INTRM1 CEMENT RURD P RD, clean and clear rig floor. Ready
pipeshed to LD 5" DP.
14,043.0 14,043.0
4/1/2020
06:00
4/1/2020
12:00
6.00 INTRM1 CEMENT PULD P LD 5" DP to pipe shed.
SIMOPS; Freeze Protect annulus with
LRS. Inject 85 bbl diesel in 10.75: x
7.625" at 2 BPM with 1130 psi.
14,043.0 14,043.0
Rig: DOYON 19
Page 26/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/1/2020
12:00
4/1/2020
17:30
5.50 INTRM1 CEMENT PULD P LD 5" DP from derrick. 14,043.0 14,043.0
4/1/2020
17:30
4/1/2020
18:00
0.50 INTRM1 CEMENT SVRG P Rig service; Grease top drive, pipe
skate, service IRN.
14,043.0 14,043.0
4/1/2020
18:00
4/2/2020
00:00
6.00 INTRM1 CEMENT PULD P Continue to LD 5" DP. Encounter tight
connections and RU 100's for break-
out assist. Continue to LD 5" DP.
14,043.0 14,043.0
4/2/2020
00:00
4/2/2020
00:45
0.75 INTRM1 CEMENT PULD P Continue to LD 5" DP with tight
connections. Breaking as needed with
100's tongs.
0.0 0.0
4/2/2020
00:45
4/2/2020
02:00
1.25 INTRM1 CEMENT BHAH P Clean and clear rigfloor and stage
tools and BHA components to floor.
change elevators 5" to 4" and check
per ID/OD procedure.
0.0 0.0
4/2/2020
02:00
4/2/2020
02:30
0.50 INTRM1 CEMENT SFTY P Safety Stand Down for spill AAR.
Discussed with the crew the need to
follow procedure and make the
concentrated effort to make all transfer
a success with out spill.
0.0 0.0
4/2/2020
02:30
4/2/2020
07:00
4.50 INTRM1 CEMENT BHAH P PU and MU Lateral BHA per Baker
and SLB DD, MWD. Verify
programming with good comm's.
Loaded nuclear sources and installed
Well Commander tool.
0.0 186.0
4/2/2020
07:00
4/2/2020
07:30
0.50 INTRM1 CEMENT PULD P Single in from the pipe shed with 4"
DP from 186' to 751'
186.0 751.0
4/2/2020
07:30
4/2/2020
08:00
0.50 INTRM1 DRILLOUT SVRG P Service rig, grease top drive and
service top drive and IRN,
751.0 751.0
4/2/2020
08:00
4/2/2020
11:30
3.50 INTRM1 DRILLOUT PULD P Single in from the pipe shed with 4"
DP from 751' to 3700'.
751.0 3,700.0
4/2/2020
11:30
4/2/2020
12:00
0.50 INTRM1 DRILLOUT BHAH P Shallow pulse test MWD tools; good.
300 GPM with 1800 psi.
3,700.0 3,700.0
4/2/2020
12:00
4/2/2020
12:45
0.75 INTRM1 DRILLOUT DLOG P MADD pass with Memory-Only Sonic
tool for free pipe comparison log. Log
from 3700' to 4000' at 900 FPH.
3,700.0 4,000.0
4/2/2020
12:45
4/2/2020
18:00
5.25 INTRM1 DRILLOUT PULD P Single in from the pipe shed with 4"
DP from 4000' to 8500'.
4,000.0 8,500.0
4/2/2020
18:00
4/3/2020
00:00
6.00 INTRM1 DRILLOUT DLOG P MADD pass with Memory-Only Sonic
tool for CBT log. Log from 8500' to
11,187' at 900 FPH. 92K DN
8,500.0 11,187.0
4/3/2020
00:00
4/3/2020
06:00
6.00 INTRM1 DRILLOUT DLOG P RIH w/ 4" DP from shed F/11187'
T/13615' @ 900' HR max for cement
logs with sonic tool - 92K DN
11,187.0 13,615.0
4/3/2020
06:00
4/3/2020
06:45
0.75 INTRM1 DRILLOUT DLOG P RIH w/ 4" DP from shed F/13615'
T/13805' @ 900' HR max for cement
logs with sonic tool - 92K DN
13,615.0 13,805.0
4/3/2020
06:45
4/3/2020
08:30
1.75 INTRM1 DRILLOUT SLPC P Slip and cut 13 (98') wraps of drilling
line - service rig - Circ @ 4.5 BPM
@1650 PSI for casing test.
13,805.0 13,805.0
4/3/2020
08:30
4/3/2020
09:15
0.75 INTRM1 DRILLOUT CIRC P Circulate and condition mud for
FIT/LOT. 300 gpm with 2740 psi.
13,805.0 13,805.0
4/3/2020
09:15
4/3/2020
11:00
1.75 INTRM1 DRILLOUT PRTS P RU and test casing to 3500 psi for 30
minutes to chart.
13,805.0 13,805.0
4/3/2020
11:00
4/3/2020
11:30
0.50 INTRM1 DRILLOUT REAM P Kelly up and wash down from 13,805'
to 13,957' and tag with 84 gpm and
890 psi. Tag 13,957'.
13,805.0 13,957.0
4/3/2020
11:30
4/3/2020
13:00
1.50 INTRM1 DRILLOUT DRLG P Drill shoe track from 13,957' to 14,043'
with 250 gpm and 2330 psi, 50 RPM
with 11K torque.
13,957.0 14,043.0
Rig: DOYON 19
Page 27/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/3/2020
13:00
4/3/2020
13:30
0.50 INTRM1 DRILLOUT DDRL P Drill 6 3/4" production section from
14,043' to 14,063' MD, 5973' TVD.
(107' @ 47.5 fph)
280 GPM = 2640 psi, 80 RPM = 10.5K
Torque
WOB = 15K, ECD = 11.4 ppg, Bgrd
gas = 45 units
14,043.0 14,063.0
4/3/2020
13:30
4/3/2020
14:30
1.00 INTRM1 DRILL CIRC P Circulate and condition mud for MW in
= MW out.
14,063.0 14,063.0
4/3/2020
14:30
4/3/2020
14:45
0.25 INTRM1 DRILL LOT P RU testing equipment for LOT. 14,063.0 14,063.0
4/3/2020
14:45
4/3/2020
15:45
1.00 INTRM1 DRILL LOT P Observe well for flow; slowly flowing,
tapered off with time to static.
14,063.0 14,063.0
4/3/2020
15:45
4/3/2020
16:45
1.00 INTRM1 DRILL LOT P Perform LOT to 14.0 ppg EMW with
11.8 ppg mud at 5953' TVD.
14,063.0 14,063.0
4/3/2020
16:45
4/3/2020
17:00
0.25 INTRM1 DRILL LOT P RD all test lines and blow down as
needed.
14,063.0 14,063.0
4/3/2020
17:00
4/3/2020
17:45
0.75 INTRM1 DRILL CIRC P PJSM with Beyond MPD. Install RCD
as per Beyond rep. Perform break-in
bearing procedure. Verify all MPD
circulating lines, good.
14,063.0 14,063.0
4/3/2020
17:45
4/3/2020
19:00
1.25 INTRM1 DRILL CIRC P Circulate and condition mud while
preparing to displace.
14,063.0 14,063.0
4/3/2020
19:00
4/3/2020
19:30
0.50 INTRM1 DRILL SFTY P Perform PJSM for displacement
19:00 - 19:30 on rigfloor.
14,063.0 14,063.0
4/3/2020
19:30
4/3/2020
21:45
2.25 INTRM1 DRILL DISP P Perform FloPro displacement.
Displace 11.8 ppg LSND with 10.3 ppg
FloPro mud system at 280 GPM with
3100 psi.
14,063.0 14,063.0
4/3/2020
21:45
4/4/2020
00:00
2.25 PROD1 DRILL DDRL P Drill 6 3/4" production section from
14,063' to 14,170' MD, 5973' TVD.
(107' @ 47.5 fph)
280 GPM = 2410 psi, 100 RPM =
10.5K Torque
WOB = 10K, ECD = 11.78 ppg, Bgrd
gas = 150 units
PUWT = 210K, SOWT = 107K, ROTW
= 126K, Off bottom TQ = 10K @ 20
RPM
ADT = 2.2 hrs, Jars = 2.2 hrs
14,063.0 14,170.0
4/4/2020
00:00
4/4/2020
06:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
14,170' to 14,558' MD, 5973' TVD,
(388' @ 64.6 fph).
280 GPM = 2240 psi, 110 RPM =
14.5K Torque
WOB = 15-19K, ECD = 11.76 ppg,
Bgrd gas = 257 units
MPD @ 175 PSI while drilling and 475
PSI on connections for a 11.8PPG
ECD
PUWT = 210K, SOWT = 80K, ROTW
= 135K, Off bottom TQ = 10K @ 20
RPM
ADT = 4.8 hrs, Jars = 7.0 hrs
14,170.0 14,558.0
Rig: DOYON 19
Page 28/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/4/2020
06:00
4/4/2020
12:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
14,558' to 14,797' MD, 5973' TVD,
(239' @ 39.8 fph).
270 GPM = 2240 psi, 110 RPM =
14.5K Torque
WOB = 15-19K, ECD = 11.83 ppg,
Bgrd gas = 257 units
MPD @ 175 PSI while drilling and 475
PSI on connections for a 11.8 PPG
ECD
PUWT = 210K, SOWT = 85K, ROTW
= 138K, Off bottom TQ = 12K @ 20
RPM
ADT = 4 hrs, Jars = 11 hrs
14,558.0 14,797.0
4/4/2020
12:00
4/4/2020
16:30
4.50 PROD1 DRILL DDRL P Drill 6 3/4" production section from
14,797' to 14,935' MD, 5975' TVD,
(138' @ 39.8 fph).
240 GPM = 1930 psi, 140 RPM = 14.K
Torque
WOB = 15-19K, ECD = 11.60 ppg,
Bgrd gas = 303 units
MPD @ 175 PSI while drilling and 475
PSI on connections for a 11.8 PPG
ECD
PUWT = 210K, SOWT = 85K, ROTW
= 138K, Off bottom TQ = 12K @ 20
RPM
ADT = 4 hrs, Jars = 11 hrs
14,797.0 14,935.0
4/4/2020
16:30
4/4/2020
18:00
1.50 PROD1 DRILL CIRC T When drilling through 14,866', losses
were realized, but manageable. At
14,918' another fault was crossed and
losses were 105 BPH. An LCM pill
was mixed with 35 PPB, 35 BBL was
pumped at an EMW of 11.8 ppg and
was squeezed at an EMW of 12.5
ppg. Losses decreased to 8-12 BPH.
14,935.0 14,935.0
4/4/2020
18:00
4/4/2020
21:15
3.25 PROD1 DRILL DDRL P Drill 6 3/4" production section from
14,935' to 15,125' MD, 5975' TVD,
(190' @ 58.5 fph).
240 GPM = 1930 psi, 140 RPM = 14.K
Torque
WOB = 15-20K, ECD = 11.80 ppg,
Bgrd gas =85 units
MPD @ 175 PSI while drilling and 475
PSI on connections for a 11.8 PPG
ECD
14,935.0 15,125.0
4/4/2020
21:15
4/5/2020
00:00
2.75 PROD1 DRILL CIRC T While making connection at 14,125'
the drill string floats would not hold.
Made multiple attempts at surging and
shut-in flows to set float valves without
success. Varied RPM and flow rates,
also pressure dumps without success.
Mixed and pumped High VIS pill
15,125.0 15,125.0
4/5/2020
00:00
4/5/2020
06:00
6.00 PROD1 DRILL CIRC T Circulate and condition hole at 230
GPM with 2130 psi, 80-140 RPM with
9-11K torque. Pumped 42 BBL high
VIS sweep (150 cp). Pumped 39 BBL
of Low VIS sweep (31cp). Employed
high flow and high RPM without
success trying to get the float valves
to close. Ordered out KWM, 11.8
NaBr for trip out of hole. Took final
survey on bottom for DD and
downlinked to put AUTOTRAK tool in
neutral.
15,125.0 15,125.0
Rig: DOYON 19
Page 29/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/5/2020
06:00
4/5/2020
12:00
6.00 PROD1 DRILL CIRC T Continue to circulate at 105 GPM with
990 psi. Maintaining 11.8 EMW with
MPD on bottom hole.
15,125.0 15,125.0
4/5/2020
12:00
4/5/2020
13:45
1.75 PROD1 DRILL CIRC T Continue to circulate at 105 GPM with
990 psi. Maintaining 11.8 EMW with
MPD on bottom hole.
15,125.0 15,125.0
4/5/2020
13:45
4/5/2020
16:45
3.00 PROD1 DRILL DISP T Displace well from 10.3 ppg Flo-Pro to
11.8 NaBr kill weight brine. Using
MPD for pressure step-down schedule
to hold BHP constant. ICP= 1000 psi
at 105 GPM. FCP= 380 psi at 105
GPM. 25 RPM with 13K torque and
130K Rot wieght.
15,125.0 15,125.0
4/5/2020
16:45
4/5/2020
17:30
0.75 PROD1 DRILL OWFF T Monitor well on slight vacuum.
Decision made for more circulation.
15,125.0 15,125.0
4/5/2020
17:30
4/5/2020
18:30
1.00 PROD1 DRILL CIRC T Continued to circulate at 95 GPM with
430 GPM for 0.5 BU with 2145
strokes.
15,125.0 15,125.0
4/5/2020
18:30
4/5/2020
19:00
0.50 PROD1 DRILL OWFF T Monitor well static. Service rig while
OWFF.
15,125.0 15,125.0
4/5/2020
19:00
4/5/2020
21:30
2.50 PROD1 DRILL PMPO T Pump out of the hole from 15,125' to
13,994' with 2 BPM.
15,125.0 13,994.0
4/5/2020
21:30
4/5/2020
22:45
1.25 PROD1 DRILL RURD T Pull RCD and install trip nipple. 13,994.0 13,994.0
4/5/2020
22:45
4/6/2020
00:00
1.25 PROD1 DRILL TRIP T Pull out of the hole on elevaotrs from
13,994' to 12,529'.
13,994.0
4/6/2020
00:00
4/6/2020
04:15
4.25 PROD1 DRILL TRIP T POOH F/12529' T/4339' on Trip Tank -
120k UP
12,529.0 4,339.0
4/6/2020
04:15
4/6/2020
04:30
0.25 PROD1 DRILL OWFF T Monitor well on trip tank to establish a
loss rate = 17 BPH
4,339.0 4,339.0
4/6/2020
04:30
4/6/2020
07:00
2.50 PROD1 DRILL TRIP T Cont. POOH on trip tank F/4339'
T/372' - 70K UP
4,339.0 372.0
4/6/2020
07:00
4/6/2020
11:00
4.00 PROD1 DRILL BHAH T PJSM - L/D BHA #3 as per Baker DD -
Remove nuclear sources , L/D Sonic
Tool , C/O floats (looked good) - plug
into MWD to check tool configuration -
Bit looked good.
372.0 0.0
4/6/2020
11:00
4/6/2020
12:30
1.50 PROD1 DRILL BHAH T PJSM for MU BHA per baker. Plug in
and verify MWD connections. MU
6.75" production BHA per Baker DD.
Load nuclear sources and RIH.
0.0 345.0
4/6/2020
12:30
4/6/2020
13:45
1.25 PROD1 DRILL TRIP T RIH with 4" DP from derrick from 345'
to 2233'.
345.0 2,233.0
4/6/2020
13:45
4/6/2020
14:15
0.50 PROD1 DRILL BHAH T Shallow pulse test MWD tools; good
with 300 GPM and 1500 psi.
2,233.0 2,233.0
4/6/2020
14:15
4/6/2020
23:00
8.75 PROD1 DRILL TRIP T Trip in from 2233' to 13,871'. 2,233.0 13,871.0
4/6/2020
23:00
4/6/2020
23:30
0.50 PROD1 DRILL RURD T Pull trip nipple and install RCD per
Beyond rep. Break circulation through
lines, good. Fill hole and meter loss at
13 BPH static.
13,871.0 13,871.0
4/6/2020
23:30
4/7/2020
00:00
0.50 PROD1 DRILL TRIP T Trip in from 13,871' to 14,512' with 4"
DP.
13,871.0 14,512.0
4/7/2020
00:00
4/7/2020
01:00
1.00 PROD1 DRILL TRIP T RIH F/14515' T/15098' - 225K UP 92K
DN
14,512.0 15,098.0
4/7/2020
01:00
4/7/2020
02:00
1.00 PROD1 DRILL CIRC T Circ @54 GPM 130 Psi Rot @ 20
RPM 13K TQ - 132K Rot Wt - ready
pits for displacement
15,098.0 15,098.0
Rig: DOYON 19
Page 30/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/7/2020
02:00
4/7/2020
04:45
2.75 PROD1 DRILL DISP T Displace F/11.8 KWB T/10.2 PPG Flo
Pro - Pump 41 BBL HI Vis spacer -
stage rates f/125 GPM T/250 GPM
2050 FCP - ROt @ 40 RPM 137K Rot
WT - Holding 11.8 PPG ECD with
MPD
15,098.0 15,098.0
4/7/2020
04:45
4/7/2020
10:00
5.25 PROD1 DRILL CIRC T Circ @ 250 GPM 1940 PSi - 137K Rot
WT - Monitor Loss rate = 18 BPH -
while waiting on mud trucks due to
Phase weather conditions.
15,098.0 15,125.0
4/7/2020
10:00
4/7/2020
12:00
2.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
15,125' to 15,288'' MD, 5986' TVD,
(163' @ 81.5 fph).
240 GPM = 2100 psi, 120 RPM = 15K
Torque
WOB = 15-19K, ECD = 11.94 ppg,
Bgrd gas = 75 units
MPD @ 175 PSI while drilling and 475
PSI on connections for a 11.8 PPG
ECD
PUWT = 210K, SOWT = 80K, ROTW
= 135K, Off bottom TQ = 13K @ 20
RPM
ADT = 1.6 hrs, Jars = 18.2 hrs
15,125.0 15,288.0
4/7/2020
12:00
4/7/2020
17:00
5.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
15,288' to 15,572' MD, 5989' TVD,
(284' @ 56.5 fph).
270 GPM = 2420 psi, 120 RPM = 15K
Torque
WOB = 15-19K, ECD = 11.94 ppg,
Bgrd gas = 75 units
MPD @ 175 PSI while drilling and 505
PSI on connections for a 11.8 PPG
ECD
PUWT = 225K, SOWT = 70K, ROTW
= 135K, Off bottom TQ = 12K @ 20
RPM
ADT = 3.1 hrs, Jars = 21.3 hrs
15,288.0 15,572.0
4/7/2020
17:00
4/7/2020
17:45
0.75 PROD1 DRILL CIRC T Could not get floats to close. Pumped
22 bbl low VIS sweep to clear floats.
pump 350 GPM with 3560 psi, 140
RPM with 14K torque to clear subs.
Got floats to close.
15,572.0 15,572.0
4/7/2020
17:45
4/7/2020
18:45
1.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
15,572' to 15,660' MD, 5987' TVD, (88'
@ 88 fph).
270 GPM = 2420 psi, 120 RPM = 15K
Torque
WOB = 15-19K, ECD = 11.99 ppg,
Bgrd gas = 353 units
MPD @ 175 PSI while drilling and 505
PSI on connections for a 11.8 PPG
ECD
PUWT = 225K, SOWT = 70K, ROTW
= 135K, Off bottom TQ = 12K @ 20
RPM
ADT = 2.4 hrs, Jars = 23.7 hrs
15,572.0 15,660.0
4/7/2020
18:45
4/7/2020
20:45
2.00 PROD1 DRILL CIRC T Could not get floats to close. Pumped
40 bbl low VIS sweep to clear floats.
Pumped at 350 GPM with 3560 psi,
140 RPM with 14K torque to clear
subs without success. After multiple
attempts while surging string floats
closed.
15,660.0 15,660.0
Rig: DOYON 19
Page 31/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/7/2020
20:45
4/8/2020
00:00
3.25 PROD1 DRILL DDRL P Drill 6 3/4" production section from
15,660' to 15,910' MD, 5986' TVD,
(250' @ 83 fph).
275 GPM = 2560 psi, 120 RPM = 16K
Torque
WOB = 15-20K, ECD = 12.09 ppg,
Bgrd gas = 178 units
MPD @ 175 PSI while drilling and 505
PSI on connections for a 11.8 PPG
ECD
PUWT = 215K, SOWT = 70K, ROTW
= 132K, Off bottom TQ = 13K @ 20
RPM
ADT = 2.4 hrs, Jar = 26.1 hrs
15,660.0 15,910.0
4/8/2020
00:00
4/8/2020
06:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
15910' to 16320' MD, 5989' TVD, (410'
@ 68 fph).
275 GPM = 2730 psi, 140 RPM = 16K
Torque
WOB = 15K, ECD = 12.32 ppg, Bgrd
gas = 280 units
MPD @ 175 PSI while drilling and 505
PSI on connections for a 11.8 PPG
ECD
PUWT = 215K, SOWT = 75K, ROTW
= 130K, Off bottom TQ = 13K @ 20
RPM
ADT = 4.1 hrs, Jar = 28.6 hrs
Loss rate = About 14 BPH
15,910.0 16,320.0
4/8/2020
06:00
4/8/2020
12:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
16,320' to 16,798' MD, 5985' TVD,
(478' @ 79.7 fph).
300 GPM = 3000 psi, 140 RPM = 16K
Torque
WOB = 17K, ECD = 12.14 ppg, Bgrd
gas = 300 units
MPD @ 175 PSI while drilling and 505
PSI on connections for a 11.8 PPG
ECD
PUWT = 215K, SOWT = 0K, ROTW =
130K, Off bottom TQ = 13K @ 20
RPM
ADT = 4.5 hrs, Jar = 33.1 hrs
Loss rate = About 12 BPH
16,320.0 16,798.0
4/8/2020
12:00
4/8/2020
18:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
16,798' to 17,073' MD, 5984' TVD,
(275' @ 45.8 fph).
300 GPM = 3000 psi, 140 RPM = 16K
Torque
WOB = 17K, ECD = 12.12 ppg, Bgrd
gas = 280 units
MPD @ 175 PSI while drilling and 505
PSI on connections for a 11.8 PPG
ECD
PUWT = 230K, SOWT = 85K, ROTW
= 148K, Off bottom TQ = 13K @ 20
RPM
ADT = 5.0 hrs, Jar = 38.0 hrs
Loss rate = About 13 BPH
16,798.0 17,073.0
Rig: DOYON 19
Page 32/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/8/2020
18:00
4/9/2020
00:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
17,073' to 17,502' MD, 5982' TVD,
(429' @ 71.5 fph).
300 GPM = 3370 psi, 140 RPM = 14K
Torque
WOB = 14K, ECD = 12.17 ppg, Bgrd
gas = 185 units
MPD @ 175 PSI while drilling and 505
PSI on connections for a 11.8 PPG
ECD
PUWT = 222K, SOWT = N/A, ROTW
= 149K, Off bottom TQ = 12K @ 20
RPM
ADT = 4.5 hrs, Jar = 42.6 hrs
Loss rate = About 24 BPH
17,073.0 17,502.0
4/9/2020
00:00
4/9/2020
06:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
17,502' to 17,853' MD, 5980' TVD,
(351' @ 58.5 fph).
300 GPM = 3210 psi, 140 RPM = 12K
Torque
WOB = 7K, ECD = 12.36 ppg, Bgrd
gas = 187 units
MPD @ 175 PSI while drilling and 505
PSI on connections for a 11.8 PPG
ECD at 7 5/8" shoe
PUWT = 210K, SOWT = N/A, ROTW
= 140K, Off bottom TQ = 12K @ 20
RPM
ADT = 4.7 hrs, Jar = 47.3 hrs
Loss rate = About 12 BPH
17,502.0 17,853.0
4/9/2020
06:00
4/9/2020
12:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
17,853' to 18,135' MD, 5980' TVD,
(282' @ 47.0 fph).
300 GPM = 3320 psi, 140 RPM =
13.5K Torque
WOB = 7K, ECD = 12.18 ppg, Bgrd
gas = 166 units
MPD @ 175 PSI while drilling and 500
PSI on connections for an 11.8 PPG
ECD at 7 5/8" shoe.
PUWT = 210K, SOWT = 95, ROTW =
150K, Off bottom TQ = 12K @ 20
RPM
ADT = 5.1 hrs, Jar = 52.4 hrs
Loss rate = 32 BPH
17,853.0 18,135.0
Rig: DOYON 19
Page 33/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/9/2020
12:00
4/9/2020
18:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
18,135' to 18,485' MD, 5977' TVD,
(350' @ 58.3 fph).
300 GPM = 3350 psi, 140 RPM =
14.5K Torque
WOB = 8K, ECD = 12.18 ppg, Bgrd
gas = 100 units
MPD @ 175 PSI while drilling and 500
PSI on connections for an 11.8 PPG
ECD at 7 5/8" shoe.
PUWT = 210K, SOWT = 90, ROTW =
152K, Off bottom TQ = 12K @ 20
RPM
ADT = 5.0 hrs, Jar = 57.4 hrs
Loss rate = 26 BPH
18,135.0 18,485.0
4/9/2020
18:00
4/10/2020
00:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
18,485'to 18,877' MD, 5976' TVD,
(392' @ 65.3 fph).
300 GPM = 3320 psi, 140 RPM = 15K
Torque
WOB = 17K, ECD = 12.25 ppg, Bgrd
gas = 70 units
MPD @ 175 PSI while drilling and 500
PSI on connections for an 11.8 PPG
ECD at 7 5/8" shoe.
PUWT = 218K, SOWT = 75, ROTW =
158K, Off bottom TQ = 12K @ 20
RPM
ADT = 5.1 hrs, Jar = 62.5 hrs
Loss rate = 23 BPH
18,485.0 18,877.0
4/10/2020
00:00
4/10/2020
06:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
18,877 'to 19,172' MD, 5977' TVD,
(295' @ 49.1 fph).
300 GPM = 3450 psi, 140 RPM = 17K
Torque
WOB = 17K, ECD = 12.35 ppg, Bgrd
gas = 120 units
MPD @ 175 PSI while drilling and 500
PSI on connections for an 11.8 PPG
ECD at 7 5/8" shoe.
PUWT = 218K, SOWT = 75, ROTW =
158K, Off bottom TQ = 12K @ 20
RPM
ADT = 4.3 hrs, Jar = 66.8 hrs
Loss rate = 40 BPH
18,877.0 19,172.0
Rig: DOYON 19
Page 34/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/10/2020
06:00
4/10/2020
10:45
4.75 PROD1 DRILL DDRL P Drill 6 3/4" production section from
19172' to19429' MD, 5979' TVD, (257'
@ 42.8 fph).
300 GPM = 3450 psi, 140 RPM = 17K
Torque
WOB = 15K, ECD = 12.33 ppg, Bgrd
gas = 416 units
MPD @ 175 PSI while drilling and 500
PSI on connections for an 11.8 PPG
ECD at 7 5/8" shoe.
PUWT = 225K, SOWT = N/A, ROTW
= 148K, Off bottom TQ = 12.5K @ 20
RPM
ADT = 4.1 hrs, Jar = 70.9 hrs
Loss rate = 45 BPH
19,172.0 19,429.0
4/10/2020
10:45
4/10/2020
14:30
3.75 PROD1 DRILL DDRL T Trouble shoot MWD - staging pump
rates and RPM - 225-340 GPM 2430 -
4210 PSI , 80 -100 RPM 12-15.5k TQ
control drill @ 25 FPH
T/19429'
19,429.0 19,562.0
4/10/2020
14:30
4/10/2020
18:00
3.50 PROD1 DRILL DDRL P Drill 6 3/4" production section from
19562' to19600' MD, 5979' TVD, (38'
@ 10 fph).
300 GPM = 3470 psi, 140 RPM = 13K
Torque
WOB = 15K, ECD = 12.22 ppg, Bgrd
gas = 25 units
MPD @ 175 PSI while drilling and 500
PSI on connections for an 11.8 PPG
ECD at 7 5/8" shoe.
PUWT = 225K, SOWT = N/A, ROTW
= 148K, Off bottom TQ = 12.5K @ 20
RPM
ADT = 5.1 hrs, Jar = 75 hrs
Loss rate = 35 BPH
19,562.0 19,600.0
4/10/2020
18:00
4/11/2020
00:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
19600' to19782' MD, 5986' TVD, (182'
@ 30.3 fph).
300 GPM = 3250 psi, 100 RPM = 13K
Torque
WOB = 10K, ECD = 12.16 ppg, Bgrd
gas = 53 units
MPD @ 175 PSI while drilling and 500
PSI on connections for an 11.8 PPG
ECD at 7 5/8" shoe.
PUWT = 220K, SOWT = N/A, ROTW
= 152K, Off bottom TQ = 10K @ 20
RPM
ADT = 5.2 hrs, Jar = 80.2 hrs
Loss rate = 30 BPH
19,600.0 19,782.0
Rig: DOYON 19
Page 35/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/11/2020
00:00
4/11/2020
06:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
19,782' to20,010' MD, 5989' TVD,
(228' @ 38 fph).
300 GPM = 3380 psi, 100 RPM =
13.5K Torque
WOB = 8K, ECD = 12.14 ppg, Bgrd
gas = 50 units
MPD @ 175 PSI while drilling and 500
PSI on connections for an 11.8 PPG
ECD at 7 5/8" shoe.
PUWT = 220K, SOWT = N/A, ROTW
= 154K, Off bottom TQ = 10.5K @ 20
RPM
ADT = 5.5 hrs, Jar = 85.7 hrs
Loss rate = 39 BPH
19,782.0 20,010.0
4/11/2020
06:00
4/11/2020
12:00
6.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
20,010' to 20,200' MD, 5991' TVD, (90'
@ 15 fph).
300 GPM = 3450 psi, 100 RPM =
13.5K Torque
WOB = 8K, ECD = 12.34 ppg, Bgrd
gas = 26 units
MPD @ 175 PSI while drilling and 500
PSI on connections for an 11.8 PPG
ECD at 7 5/8" shoe.
PUWT = 220K, SOWT = N/A, ROTW
= 148K, Off bottom TQ = 10.5K @ 20
RPM
ADT = 5.0 hrs, Jar = 90.7 hrs
Loss rate = 36 BPH
20,010.0 20,200.0
4/11/2020
12:00
4/11/2020
15:00
3.00 PROD1 DRILL DDRL P Drill 6 3/4" production section from
20,200' to 20,296' MD, 5992' TVD, (96'
@ 32 fph).
300 GPM = 3450 psi, 100 RPM =
14.0K Torque
WOB = 8K, ECD = 12.34 ppg, Bgrd
gas = 22 units
MPD @ 175 PSI while drilling and 500
PSI on connections for an 11.8 PPG
ECD at 7 5/8" shoe.
PUWT = 220K, SOWT = N/A, ROTW
= 148K, Off bottom TQ = 10.5K @ 20
RPM
ADT = 2.6 hrs, Jar = 93.3 hrs
Loss rate = 36.5 BPH
20,200.0 20,296.0
4/11/2020
15:00
4/11/2020
18:45
3.75 PROD1 CASING CIRC P Circulate reciprocate and rotate for
2.5X BU at 300 GPM with 3450 psi.
120 RPM with 13.5K torque. Rot=
147K
20,296.0 20,296.0
4/11/2020
18:45
4/11/2020
21:00
2.25 PROD1 CASING CIRC P Draw-down Test; Performed Static DD
test closing chokes and recording
bleed-down to 190 PSI. Bleeding to 0
psi four times to record pressure
increase and each time the pressure
would build to 176-177 psi for an
equivalent of 10.7 (10.66) ppg.
20,296.0 20,296.0
4/11/2020
21:00
4/12/2020
00:00
3.00 PROD1 CASING CIRC P Circulate reciprocate and rotate for
2.5X BU at 300 GPM with 3450 psi.
120 RPM with 13.5K torque. Rot=
147K
20,296.0 20,296.0
Rig: DOYON 19
20,296.020,200.0
Page 36/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/12/2020
00:00
4/12/2020
02:15
2.25 PROD1 CASING CIRC P CIrc cond mud @ 310 GPM 3380 PSI
- Holding 150 PSI with MPD for a 11.5
PPG ECD - Circ 1.5 times B/U - 120
RPM 13K TQ 144k Rot Wt
20,296.0 20,293.0
4/12/2020
02:15
4/12/2020
03:15
1.00 PROD1 CASING SMPD P SOOH from 20,296' to19,944' Holding
550 PSI w/ MPD - Floats not holding -
work pipe get floats to close
20,293.0 19,944.0
4/12/2020
03:15
4/12/2020
12:00
8.75 PROD1 CASING SMPD P SOOH from 19,944' to 13,966' Holding
50 PSI w/ MPD.
19,944.0 13,966.0
4/12/2020
12:00
4/12/2020
16:00
4.00 PROD1 CASING CIRC P Circulate casing clean. 13,966.0 13,966.0
4/12/2020
16:00
4/12/2020
19:15
3.25 PROD1 CASING DISP P Displace well to 11.5 KWM (NaBr) 13,966.0 13,966.0
4/12/2020
19:15
4/12/2020
20:00
0.75 PROD1 CASING OWFF P Observe well for flow, with losses at
16 BPH static.
13,966.0 13,966.0
4/12/2020
20:00
4/12/2020
20:45
0.75 PROD1 CASING SMPD P SOOH from 13,966' to 13,504' Holding
25-50 PSI w/ MPD with losses
increasing.
13,966.0 13,504.0
4/12/2020
20:45
4/12/2020
21:00
0.25 PROD1 CASING CIRC P Pump dry job. 13,504.0 13,504.0
4/12/2020
21:00
4/12/2020
23:00
2.00 PROD1 CASING SMPD P SOOH from 13,504' to 11,358' Holding
25-50 PSI w/ MPD with losses
increasing and RCD element leaking
unable to hold desired back pressure.
13,504.0 11,358.0
4/12/2020
23:00
4/13/2020
00:00
1.00 PROD1 CASING RURD P Pull RCD (leaking) and install trip
nipple. Monitor well while changing to
trip nipple. Loss rate at 14 BPH.
11,358.0 11,358.0
4/13/2020
00:00
4/13/2020
06:00
6.00 PROD1 CASING TRIP P POOH on TT F/11359' T/440'. 11,358.0 440.0
4/13/2020
06:00
4/13/2020
06:15
0.25 PROD1 CASING OWFF P Monitor well for flow, 26 BPH loss. 440.0 440.0
4/13/2020
06:15
4/13/2020
09:00
2.75 PROD1 CASING TRIP P LD jars and HWDP. Remove nuclear
sources.
440.0 205.0
4/13/2020
09:00
4/13/2020
10:00
1.00 PROD1 CASING BHAH P LD BHA per Baker DD and MWD. LD
equipment off rig floor.
Clean and clear floor.
205.0 0.0
4/13/2020
10:00
4/13/2020
10:30
0.50 PROD1 WHDBOP RURD P Pull wear ring and install test plug for
testing.
0.0 0.0
4/13/2020
10:30
4/13/2020
11:30
1.00 PROD1 WHDBOP RURD P RU lines and flood lines with H2O for
tests.
0.0 0.0
4/13/2020
11:30
4/13/2020
12:00
0.50 PROD1 WHDBOP BOPE P Test annular with 3.5" test joint
250/2500 for 5 minutes and chart.
0.0 0.0
4/13/2020
12:00
4/13/2020
17:30
5.50 PROD1 WHDBOP BOPE P With 4.5" test joints. Test annular
250/2500 low/high 5 min ea. Test with
4 1/2" and 3 1/2" - All others elements
were tested to 250/3500 low/high.
Function test PVT's, flow meter, and
Gas alarms. Man & Hydraulic Choke,
1500 psi drawdown. Function remote
control panel in boiler room.
Koomey test; initial- 3050 psi, after
close 1350 psi, 200 psi attained after
22 seconds with full pressure after 144
seconds. Nitrogen bottles (4)
average2000 psi.
Witness waived by Jeff Jones
0.0 0.0
4/13/2020
17:30
4/13/2020
18:30
1.00 PROD1 WHDBOP BOPE P Pull test plug - R/D BOP test
equipment - clean clear rig floor of
excess tools
0.0 0.0
4/13/2020
18:30
4/13/2020
19:00
0.50 PROD1 WHDBOP RURD P Install 10" Wear ring 0.0 0.0
Rig: DOYON 19
Page 37/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/13/2020
19:00
4/13/2020
20:30
1.50 COMPZN CASING RURD P Rig to run 4 1/2" Hyd 563 liner 0.0 0.0
4/13/2020
20:30
4/14/2020
00:00
3.50 COMPZN CASING PUTB P PJSM - Run 4 1/2" liner 12.6# Hyd
563 liner - M/u Float shoe assy RIH 2
JTS - circ 6 BBLS @ 2 BPM 70 PSI -
RIH T/1501'
0.0 1,501.0
4/14/2020
00:00
4/14/2020
06:00
6.00 COMPZN CASING RCST P RIH F/1501' T/5371' - with 4 1/2" Hyd
563 liner - Fill every 20 JTS
DN WT = 90K, KWB loss = 140 BBLS
116.0 5,371.0
4/14/2020
06:00
4/14/2020
07:30
1.50 COMPZN CASING RCST P RIH F/5371' T/6415' - with 4 1/2" Hyd
563 liner - Fill every 20 JTS -
DN WT = 90K KWB loss = 23 BPH
5,371.0 6,415.0
4/14/2020
07:30
4/14/2020
08:15
0.75 COMPZN CASING RUNL P C/O Elevators to 3 1/2" - P/U Slick
Bore Extension and Liner Top Packer
Assy.
PU = 110K, SO = 90K
6,415.0 6,415.0
4/14/2020
08:15
4/14/2020
08:30
0.25 COMPZN CASING RUNL P C/O Elevators to 4" RIH 1 STD 4" DP
T/6578'
RD casing equipment and clear floor.
6,415.0 6,415.0
4/14/2020
08:30
4/14/2020
08:45
0.25 COMPZN CASING RUNL P Continue to RIH from 6415' to 6578'
with 4" DP.
6,415.0 6,578.0
4/14/2020
08:45
4/14/2020
09:30
0.75 COMPZN CASING CIRC P Pump liner volume (100 BBLS) 85
GPM with 80 psi. 13 RPM with 3K
torque. Clear flow path verified. PU=
110K, SO= 95K, Rot= 100K.
Loss rate at 24 BPH.
6,578.0 6,578.0
4/14/2020
09:30
4/14/2020
10:45
1.25 COMPZN CASING RUNL P RIH with liner from 6578' to 7905' with
4" DP.
6,578.0 7,905.0
4/14/2020
10:45
4/14/2020
11:15
0.50 COMPZN CASING SVRG P Rig service; Grease top drive, IRN,
drawworks, auto IBOP, washpipe.
7,905.0 7,905.0
4/14/2020
11:15
4/14/2020
12:00
0.75 COMPZN CASING RUNL P RIH with liner from 7905' to 8750' with
4" DP.
7,905.0 8,750.0
4/14/2020
12:00
4/14/2020
16:30
4.50 COMPZN CASING RUNL P RIH with liner from 8750' to 13,958'
with 4" DP.
8,750.0 13,958.0
4/14/2020
16:30
4/14/2020
16:45
0.25 COMPZN CASING OWFF P Monitor well with 23 BPH loss.
PU= 168K, SO= 110K, ROT= 132K
with 6.2K torque
13,958.0 13,958.0
4/14/2020
16:45
4/14/2020
17:15
0.50 COMPZN CASING RURD P Pull trip nipple and install RCD 13,958.0 13,958.0
4/14/2020
17:15
4/14/2020
23:30
6.25 COMPZN CASING RUNL P RIH with liner from 13,958' to 20,296
with 4" DP and tagged bottom.
Measured space out.
13,958.0 20,274.0
4/14/2020
23:30
4/15/2020
00:00
0.50 COMPZN CASING CIRC P Circulate string volume at 126 GPM
with 575 psi. Drop ball and circulate
down with high Vis pill.
20,274.0 20,274.0
4/15/2020
00:00
4/15/2020
00:45
0.75 COMPZN CASING CIRC P Circ liner and DP volume @ 120 GPM
600 PSI - loss rate = 36-42 BPH
20,274.0 20,274.0
4/15/2020
00:45
4/15/2020
03:15
2.50 COMPZN CASING RUNL P Set liner hanger as per Baker Rep -
pump 10 BBLS Hi vis Brine - Drop
1.25" ball - Chase with 10 BBLS hi vis
brine - followed by 203 BBLS 11.5
KWB - Ball on seat @ 2019 STKS -
PSI up T/2300 - S/O T/55K down on
hanger - PSI up T/3500 Bleed off - P/U
T/250K on hook - not released - S/O
T/60K on hook - PSI up T/3800 PSI
Bleed off - P/U confirmed released @
205K up - Loss of 40k - P/U 6' expose
dog sub - S/O set ZXP W/70K DN -
P/U confirm set with Rot. @ 10 RPM
7K TQ 165K ROt Wt - S/O T/95K - P/U
For tool joint space out to test.
20,274.0 20,274.0
Rig: DOYON 19
Page 38/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/15/2020
03:15
4/15/2020
03:45
0.50 COMPZN CASING DHEQ P Test WIV T/2000 PSI F/10 MIN 13,800.0 13,800.0
4/15/2020
03:45
4/15/2020
04:30
0.75 COMPZN CASING DHEQ P Test LTP T/3850 PSI F/10 MIN 13,800.0 13,800.0
4/15/2020
04:30
4/15/2020
07:15
2.75 COMPZN WELLPR CIRC P Displace to 8.5 PPG Seawater @ 210
GPM 1210 PSI ICP - 950 PSI FCP
13,800.0 13,800.0
4/15/2020
07:15
4/15/2020
07:45
0.50 COMPZN WELLPR OWFF P Flow Check - observed slight flow with
fluids out of balance.
13,800.0 13,800.0
4/15/2020
07:45
4/15/2020
09:00
1.25 COMPZN WELLPR CIRC P Circ B/U @ 6 BPM 1230 PSI 13,800.0 13,800.0
4/15/2020
09:00
4/15/2020
09:30
0.50 COMPZN WELLPR CIRC P Observe well for flow; static 13,800.0 13,800.0
4/15/2020
09:30
4/15/2020
10:00
0.50 COMPZN WELLPR RURD P Install RCD (BD MPD, MP #1) 13,800.0 13,796.0
4/15/2020
10:00
4/15/2020
11:15
1.25 COMPZN WELLPR CIRC P Circulate Sea H2) to surface with 5600
strokes. 425 GPM with 3100 psi.
13,796.0 13,796.0
4/15/2020
11:15
4/15/2020
11:30
0.25 COMPZN WELLPR OWFF P Observe well for flow; static 13,796.0 13,796.0
4/15/2020
11:30
4/15/2020
12:00
0.50 COMPZN WELLPR CIRC P Pump 30 BBL dry job, 13,796.0 13,796.0
4/15/2020
12:00
4/15/2020
16:45
4.75 COMPZN WELLPR TRIP P TOH from 13,796' to 7660' with proper
fill.
13,796.0 7,660.0
4/15/2020
16:45
4/15/2020
17:45
1.00 COMPZN WELLPR SLPC P Slip and cut 13 wraps, 86' of drill line. 7,660.0 7,660.0
4/15/2020
17:45
4/15/2020
18:15
0.50 COMPZN WELLPR SVRG P Rig service; grease top drive, swivel
packing, drawworks, check all fluid
levels.
7,660.0 7,660.0
4/15/2020
18:15
4/16/2020
00:00
5.75 COMPZN WELLPR TRIP P TOH F/7660' T/541' with proper fill. 7,660.0 541.0
4/16/2020
00:00
4/16/2020
00:30
0.50 COMPZN WELLPR TRIP P Lay down 4" DP to pipe shed. 541.0 53.0
4/16/2020
00:30
4/16/2020
01:15
0.75 COMPZN WELLPR PULD P Inspect and lay down liner running
tools - Dog sub was sheared and all
parts accounted for at the surface.
53.0 0.0
4/16/2020
01:15
4/16/2020
02:30
1.25 COMPZN RPCOMP RURD P Clean clear floor - pull wear ring - flush
stack again - lay down stack washing
tool
0.0 0.0
4/16/2020
02:30
4/16/2020
04:15
1.75 COMPZN RPCOMP RURD P RIg to run 3 1/2" completion with GBR
and Halliburton - Prep Tech wire -
Make up safety valve - rig up power
tongs - bring clamps to floor
0.0 0.0
4/16/2020
04:15
4/16/2020
06:15
2.00 COMPZN RPCOMP PUTB P PJSM - run tubing - Run 3 1/2" 9.3# L-
80 TBG as per detail to 218' - Rig up
and test tech wire to Gauge mandrel.
0.0 218.0
4/16/2020
06:15
4/16/2020
06:30
0.25 COMPZN RPCOMP PUTB P Run 3 1/2" tubing as per detail from
218' to 330'.
218.0 330.0
4/16/2020
06:30
4/16/2020
09:30
3.00 COMPZN RPCOMP DHEQ T TOH from 330' to 218' and trouble-
shoot HES TEC wire and gauge.
Change out gauge and test; good.
SIMOPS: Remove Baker transducer
for stand pipe.
330.0 218.0
4/16/2020
09:30
4/16/2020
12:00
2.50 COMPZN RPCOMP PUTB P Run 3 1/2" tubing as per detail from
330' to 1740'. Gauge good.
SO= 75K
218.0 1,740.0
4/16/2020
12:00
4/16/2020
18:00
6.00 COMPZN RPCOMP PUTB P Run 3 1/2" tubing as per detail from
1740' to 5925'. Gauge good.
SO= 80K
1,740.0 5,925.0
4/16/2020
18:00
4/17/2020
00:00
6.00 COMPZN RPCOMP PUTB P Run 3 1/2" tubing as per detail from
5925' to 9921'. Gauge good.
SO= 87K.
5,925.0 9,921.0
Rig: DOYON 19
Page 39/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/17/2020
00:00
4/17/2020
06:00
6.00 COMPZN RPCOMP RCST P Run 3 1/2" tubing as per detail from
9921' to 13,692'. Gauge good.
PU= 128K, SO= 89K.
Ran 432ea 3 1/2" Full Cannon clamps
11ea 3 1/2" Half Cannon clamps
2ea 4 1/2" Full Cannon clamps
2ea 4 1/2" Half Cannon clamps
881 pins
9,921.0 13,692.0
4/17/2020
06:00
4/17/2020
08:45
2.75 COMPZN RPCOMP HOSO P PU XO to 4 1/2" tubing for space out,
tag TOL at 13,795.14'. Shear pins
with 5K, Final TD at 13,851.87'. MU
hanger, feed TEC wire and test wire
port to 5000 psi for 10 minutes.
PU= 128K, SO= 89K
13,692.0 13,795.0
4/17/2020
08:45
4/17/2020
09:15
0.50 COMPZN RPCOMP THGR P Land tubing and hanger, RILDS and
test seals to 5000 psi for 10 minutes.
PU= 130K, SO= 90K
13,795.0 13,795.0
4/17/2020
09:15
4/17/2020
12:00
2.75 COMPZN RPCOMP PACK P RU test 3 1/2" tubing to 4500 psi for
30 minutes (Baker Packer set at 2050
psi). Bleed tubing to 2500 psi. Test IA
and tubing hanger to 3900 psi for 15
minutes. Sheared the SOV with 2500
psi on IA. Circulate to verify full open
with 84 GPM with 340 psi.
13,795.0 13,795.0
4/17/2020
12:00
4/17/2020
13:00
1.00 COMPZN RPCOMP RURD P RD testing equipment and surface
lines. LD landing joint.
13,795.0 0.0
4/17/2020
13:00
4/17/2020
13:45
0.75 COMPZN WHDBOP RURD P Set BPV per Cameron rep, test to
2500 psi for 10 minutes; good.
0.0 0.0
4/17/2020
13:45
4/17/2020
15:00
1.25 COMPZN WHDBOP RURD P RD casing and TEC wire equipment
via beaver slide. RD sheaves and
tubing test manifold.
0.0 0.0
4/17/2020
15:00
4/17/2020
16:30
1.50 COMPZN WHDBOP WWWH P Flush stack, choke manifold, gas
buster, kill and choke lines, mud
pumps with deep clean pill.
0.0 0.0
4/17/2020
16:30
4/17/2020
18:00
1.50 COMPZN WHDBOP NUND P ND trip nipple, MPD orbit valve, flow
box and flowline.
0.0 0.0
4/17/2020
18:00
4/18/2020
00:00
6.00 COMPZN WHDBOP NUND P LD mouse hole to pipeshed, remove
choke/kill line from BOP. Remove
rams from stack. Clean bodies for
stack out. RD control lines to rack
BOP's on pedestal.
SIMOPS; LD excess tools and
equipment from rigfloor. Clean pits.
0.0 0.0
4/18/2020
00:00
4/18/2020
02:45
2.75 COMPZN WHDBOP NUND P Continue to ND BOP's, break adapter
flange connections, PU and rack back
BOP stack on pedestal and secured.
0.0 0.0
4/18/2020
02:45
4/18/2020
06:00
3.25 COMPZN WHDBOP NUND P Prepare hanger, install Production
SBMS per Cameron rep. Test TEC
wire per Halliburton rep. Good. Install
5K - 10K adapter and tree onto well
head as per Cameron rep. 3H DSO
verified orientation and TEC wire
alignment.
SIMOPS; Disconnect choke/flare lines
from sub to pits. Disconnect service
lines from sub to rigfloor. Prep mud
pumps for Demob, clean pits, #2 boiler
prep'd for Demob. Grease choke
manifold for Demob.
0.0 0.0
Rig: DOYON 19
Page 40/40
3H-37
Report Printed: 5/1/2020
Operations Summary (with Timelog Depths)
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)
4/18/2020
06:00
4/18/2020
09:30
3.50 COMPZN WHDBOP NUND P Continue NU adapter spool, tested low
250/5000 psi high for 10 minutes. NU
FMC tree and tested tree low
250/5000 psi high for low 5/15 minutes
per Cameron rep.
SIMOPS; LD 4" DP from derrick.
Final down hole pressure reading
2835 PSI. Temp 140. F/ HES gauge
mandrel
0.0 0.0
4/18/2020
09:30
4/18/2020
10:00
0.50 COMPZN WHDBOP RURD P Remove dart and BPV with dry rod. 0.0 0.0
4/18/2020
10:00
4/18/2020
10:45
0.75 COMPZN WHDBOP FRZP P RU annulus and tubing to freeze
protect with LRS.
SIMOPS; LD 4" DP from derrick.
0.0 0.0
4/18/2020
10:45
4/18/2020
12:00
1.25 COMPZN WHDBOP FRZP P Freeze protect IA with 90 BBL of
diesel. Total 93 BBL, ICP @ 2 BPM
with 0 psi, FCP @ 2 BPM with 480 psi.
0.0 0.0
4/18/2020
12:00
4/18/2020
16:15
4.25 COMPZN WHDBOP FRZP P Line up to U-tube Starting psi, IA= 200
psi, Tubing= 250 psi, Final IA= 250
psi, Tubing= 275 psi.
SIMOPS; LD 45 stands of 4" DP from
derrick.
0.0 0.0
4/18/2020
16:15
4/18/2020
17:00
0.75 COMPZN WHDBOP RURD P RD IA and Tubing surface lines. 0.0 0.0
4/18/2020
17:00
4/18/2020
18:30
1.50 COMPZN WHDBOP NUND P MU blind flanges to IA and FMC tree,
install blank flanges choke and kill
line. Prep cellar area for rig move.
Continue to prep pits for Demob.
Continue to pickle pumps.
0.0 0.0
4/18/2020
18:30
4/18/2020
21:45
3.25 COMPZN WHDBOP NUND P Prep tree to install lubricator, set up
test equpiment for lubricator pressure
test. Pressure test lubricator to 1860
psi for 10 minutes; good. Install H
BPV via lubricator per Cameron. RD
test equipment. Close all valves on
tree and plug.
Well secured*** Tubing= 500 psi, IA=
200 psi, OA= 740 psi.
0.0 0.0
4/18/2020
21:45
4/19/2020
00:00
2.25 DEMOB MOVE DMOB P Demob checklist: Clean rigfloor with P
-washer, grease all valves/ store in
open position. Wash piperack, pull
plug from centrifuge pumps, continue
to pickle pumps and store all parts for
move.
Rig released @ 23:59 Hrs
0.0 0.0
Rig: DOYON 19
Page 1/1
3H-37
Report Printed: 5/1/2020
Cement Detail Report
Cement Details
Description
Surface Casing Cement
Cementing Start Date
3/13/2020 02:00
Cementing End Date
3/13/2020 03:00
Wellbore Name
3H-37
Comment
Cement Stages
Stage # 1
Description
Surface Casing Cement
Objective
Casing integrity
Top Depth (ftKB)
37.5
Bottom Depth (ftKB)
3,628.0
Full Return?
No
Vol Cement …Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
8
Q Pump Avg (bbl/…
7
P Pump Final (psi)
600.0
P Plug Bump (psi) Recip?
Yes
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Perform 10-3/4" Surface casing cement job. Reciprocate casing while cementing. PUWT = 200K, SOWT = 130K.
Fill lines with 5 bbls 8.34 ppg fresh water. Test lines to 3800 psi.
Pump 60 bbls 10.0 ppgTuned spacer. 3.5 bpm = 300 psi.
Drop bottom plug.
Pump 619 bbls Lead Cement, 1185 sks, 10.7 ppg, 2.9 cu-ft/sk yield, 14.97 gal/sk, 5 bpm = 550 psi, Added 5# Pol-E-Flake and 4# Red Dye to first 10 bbls
pumped.
Pump 57 bbls Tail Cement, 275 sks, 15.8 ppg, 1.16 cu-ft/sk yield, 5.05 gal/sk.
Drop top plug.
HES Pump 20 bbls 8.34 ppg fresh water.
Chase plug with rig pumps. Pump 240 bls of 9.6 ppg mud. Pumps locked up - unable to pump fluid
Continue to chase Top Plug with 85 bbls of fresh water from HES pump truck.
Total of 325 bbls pumped on top of plug. Did not bump plug.
Check floats = good, Cement in place at 05:00, 3/13/20
Observed cement to surface 44" below GL
Cement Fluids & Additives
Fluid
Fluid Type
Spacer
Fluid Description Estimated Top (ftKB)
0.0
Est Btm (ftKB)
0.0
Amount (sacks) Class
gel
Volume Pumped (bbl)
60.0
Yield (ft³/sack)
8.81
Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal)
10.00
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
37.9
Est Btm (ftKB)
3,311.0
Amount (sacks)
1,185
Class
G
Volume Pumped (bbl)
619.0
Yield (ft³/sack)
2.94
Mix H20 Ratio (gal/sa…
14.97
Free Water (%) Density (lb/gal)
10.70
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
3,311.0
Est Btm (ftKB)
3,628.0
Amount (sacks)
275
Class
G
Volume Pumped (bbl)
57.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sa…
5.05
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Displacement
Fluid Description Estimated Top (ftKB)
3,628.0
Est Btm (ftKB)
3,628.0
Amount (sacks) Class
LSND
Volume Pumped (bbl)
315.0
Yield (ft³/sack)
9.60
Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Surface Casing Cement
Job: DRILLING ORIGINAL, 3/7/2020 04:00
Page 1/1
3H-37
Report Printed: 5/1/2020
Cement Detail Report
Cement Details
Description
Intermediate Casing Cement
Cementing Start Date
3/31/2020 14:00
Cementing End Date
3/31/2020 16:45
Wellbore Name
3H-37
Comment
Pump 57 bbls of 12.0 ppg tuned spacer at 4 BPM with 740 psi. Drop bottom plug and pumped 187 bbl of 14.0 ppg lead cement at 4 BPM with 830 psi. Pump 45
bbl of 15.8 ppg tail cement at 3.2 BPM with 600 psi. Drop top plug with 10 bbl of water, then chased with 632.4 bbl of 11.8 ppg LSND. ICP= 570 psi at 6 BPM.
FCP= 970 psi at 4 BPM. Did not bump plug (using 96% efficiency on pumps) with no returns throughout job. Held 500 psi over for 5 minutes, bled back 1.5 bbl
and floats held. CIP at 16:45 3/30/20.
Cement Stages
Stage # 1
Description
Intermediate Casing
Cement
Objective
casing and shoe integrity
Top Depth (ftKB)
10,212.0
Bottom Depth (ftKB)
14,043.0
Full Return?
No
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
4
Q Pump Avg (bbl/…
4
P Pump Final (psi)
970.0
P Plug Bump (psi) Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Pump 6280 Stks - did not bump - no returns - good lift pressure
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
10,212.0
Est Btm (ftKB)
13,548.0
Amount (sacks)
730
Class
G
Volume Pumped (bbl)
187.0
Yield (ft³/sack)
1.52
Mix H20 Ratio (gal/sa…
7.73
Free Water (%) Density (lb/gal)
14.00
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
13,548.0
Est Btm (ftKB)
14,043.0
Amount (sacks)
220
Class
G
Volume Pumped (bbl)
45.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sa…
4.97
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Intermediate Casing Cement
Job: DRILLING ORIGINAL, 3/7/2020 04:00
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Transmittal #1272 Detail
Date: 5/4/2020
To (External Party):From (CPAI Contact):
Email*: abby.bell@alaska.gov Email*: richard.e.elgarico@conocophillips.com
First
Name*:Abby First Name*: Ricky
Last Name*: Bell Last Name*: Elgarico
Phone
Number:(907) 793-1225 Phone Number: (907) 265-6580
Company: AOGCC Company: ConocoPhillips
Address: 333 West 7th Ave.Address: 700 G Street
City: Anchorage City: Anchorage
State: AK State: AK
Zip Code: 99501 Zip Code: 99501
Transmittal Info
Sent Via: FTP Tracking #:
Justification:
Data Detail
Quantity*:Description*:Type*:
1
3H-35 LWD Data. CGM, EOW
Letter, DLIS, LAS, PDF, Survey
Data
Digital
1
3H-37 LWD Data. CGM, EOW
Letter, DLIS, LAS, PDF, Survey
Data
Digital
Attachments:
Received By:
___________________________
Signature:
___________________________
Date:
_________________
Approver:
___________________________
Signature:
___________________________
Date:
_________________
Abby Bell Abby Bell 05/08/2020
RESUBMITTAL from 05/04/2020, original data received 05/04/2020
PTD: 2191940
E-Set: 33001
ConocoPhillips
To (External Party):
Email*: abby.bell@alaska.gov
First Abby
Name*:
Last Name*: Bell
Phone (907) 793-1225
Number:
Company: AOGCC
Address: 333 West 7th Ave.
City: Anchorage
State: AK
Zip Code: 99501
Sent Via: FTP
I Justification:
Transmittal #1272 Detail
Date: 5/4/2020
From (CPAI Contact):
Email*: richard.e.elgarico@conocophillips.com
First Name*: Ricky
Last Name*: Elgarico
Phone Number: (907) 265-6580
Company:
ConocoPhillips
Address:
700 G Street
City:
Anchorage
State:
AK
Zip Code:
99501
Transmittal Info
Tracking #:
Data Detail
Quantity*: Description*
31-1-35 LWD Data. CGM, EOW
1 Letter, DLIS, IAS, PDF, Survey
Data
31-1-37 LWD Data. CGM, EOW
1 Letter, DLIS, LAS, PDF, Survey
Data
Attachments:
ire
I
Type*:
Digital
Digital
D te:
0�120Z°
Date:
2l q- lqq
3zq�r
Baker Hughes Date:
S
April 30, 2020
To: - —
Abby Bell
AOGCC
333 West 7`h Ave, Suite 100
Anchorage, Alaska 99501
21 91 94
3298®
Letter of Transmittal
- (From:
Michael Soper
I Baker Hughes
795 East 94`h Avenue
Anchorage, Alaska 99515
I
i
Please find enclosed the directional survey data for the following well(s):
3H-37
RECEIVED
APR 3 0 2020
A®GCC
(1) Total print
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Michael Soper
Baker Hughes
Applications Engineer
Michael.Soper(@bakerhughes.com
21 91 14
52960
ConocoPhilli s
p
ConocoPhillips Alaska Inc—Kuparuk
Kuparuk River Unit
Kuparuk 3H Pad
3H-37
50-103-20822-00
Baker Hughes INTEQ BakerHughes 23
Definitive Survey Report
30 April, 2020
ConocoPhillip
ConocoPhillips
BakerHughes g
5Report
Survey
Company:
ConocoPhillips Alaska Inc—Kuparuk
Local Coordinate Reference:
Well 31-1-37
Project:
Kuparuk River Unit
TVD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Site:
Kuparuk 3H Pad
MD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Well:
31-1-37
North Reference:
True
Wellbore:
31-1-37
Survey Calculation Method:
Minimum Curvature
Design:
31-1-37
Database:
EDT 15 Alaska Prod
Project
Kuparuk River Unit, North Slope Alaska, United States
Map System:
US State Plane 1927 (Exact solution)
System Datum: Mean Sea Level
Geo Datum:
NAD 1927 (NADCON CONUS)
Using Well Reference Point
Map Zone:
Alaska Zone 04
Using geodetic scale factor
Well
3H-37
Well Position
+N/ -S 0.00 usft
Northing: 6,000,297.70usft
Latitude:
700 24'43.370 N
+E/ -W 0.00 usft
Easting: 498,655.44usft
Longitude:
150" 0'39.417 W
Position Uncertainty
0.00 usft
Wellhead Elevation: usft
Ground Level:
35.80 usft
Wellbore
3H-37
Magnetics
Model Name Sample Date
Declination
Dip Angle
Field Strength
(1)
(1
(nT)
B G G M 2019 3/15/2020
16.06
80.80
57, 366.07
Design
3H-37
Audit Notes:
Version:
1.0 Phase: ACTUAL
Tie On Depth: 37.87
Vertical Section:
Depth From (TVD)
+N/ -S
+E/ -W Direction
(usft)
(usft)
(usft) (1)
37.87
0.00
0.00 330.01
4/30/2020 2:10:49PM Page 2 COMPASS 5000.15 Build 91 E
"I ConocoPhillips
Report sckerHughes 20
ConocoPhillips Survey
Company:
ConocoPhillips Alaska Inc-Kuparuk
Local Co-ordinate Reference:
Well 3H-37
Project:
Kuparuk River Unit
TVD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Site:
Kuparuk 3H
Pad
MD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Well:
3H-37
North Reference:
True
Wellbore:
3H-37
Survey Calculation Method:
Minimum Curvature
Design:
3H-37
Database:
EDT 15 Alaska Prod
Survey Program
Date 4/20/2020
From
To
Survey
Survey
(usft)
(usft)
Survey (Wellbore)
Tool Name
Description
Start Date
End Date
94.16
744.61
3H-37 Srvy 1 - 13-1/2"
SDI Gyro MWD (3
GYD-GC-SS
Gyrodata gyro single shots
3/9/2020
3/10/2020
760.94
3,563.94
3H-37 Srvy 2 - 13-1/2"
OnTrak MWD (3H
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag + Multi -Station Correctior 3/10/2020
3/11/2020
3,662.79
13,950.89
3H-37 Srvy 3 - 9-7/8 x 11" OnTrak MWD
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag + Multi -Station Correctior 3/17/2020
3/22/2020
14,049.31
14,049.31
3H-37 Srvy 4 - 6-3/4" AutoTrak eXact (3H
MWD-INC_ONLY
MWD-INC_ONLY_FILLER
4/4/2020
4/4/2020
14,147.80
20,268.66
3H-37 Srvy 5 - 6-3/4" AutoTrak eXact (3H
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag + Multi -Station Correctior 4/4/2020
4/11/2020
Survey
Map
Map
Vertical
MD
Inc
Azi TVD
TVDSS +N/ -S
*Elft►
DLS
(usft)
(")
(°) (usft)
(usft) (usft)
(usft )
Northing
Easting
(°/100')
Section
Survey Tool Name
y
Annotation
(ft)
(ft)
(ft)
37.87
0.00
0.00 37.87
-35.80
0.00
0.00
6,000,297.70
498,655.44 0.00
0.00
UNDEFINED
94.16
0.18
163.83 94.16
20.49
-0.08
0.02
6,000,297.61
498,655.46 0.32
-0.09
GYD-GC-SS (1)
155.30
0.35
170.16 155.30
81.63
-0.36
0.08
6,000,297.33
498,655.52 0.28
-0.35
GYD-GC-SS (1)
186.76
0.35
174.02 186.76
113.09
-0.55
0.11
6,000,297.14
498,655.55 0.07
-0.53
GYD-GC-SS (1)
274.51
1.67
255.94 274.50
200.83
-1.13
-1.10
6,000,296.57
498,654.33 1.89
-0.43
GYD-GC-SS (1)
367.90
3.16
256.64 367.80
294.13
-2.05
4.93
6,000,295.64
498,650.51 1.60
0.68
GYD-GC-SS(1)
460.90
5.45
268.95 460.53
386.86
-2.73
-11.84
6,000,294.97
498,643.60 2.64
3.56
GYD-GC-SS (1)
555.42
6.77
285.12 554.52
480.85
-1.36
-21.71
6,000,296.34
498,633.73 2.28
9.67
GYD-GC-SS (1)
650.35
8.17
293.20 648.65
574.98
2.76
-33.31
6,000,300.46
498,622.13 1.84
19.04
GYD-GC-SS (1)
744.61
8.96
298.13 741.85
668.18
8.86
-45.94
6,000,306.56
498,609.51 1.14
30.64
GYD-GC-SS (1)
760.94
8.79
299.98 757.99
684.32
10.08
-48.14
6,000,307.79
498,607.30 2.03
32.80
MWD+IFR2+SAG+MS (2)
855.07
9.83
303.95 850.88
777.21
18.16
-61.04
6,000,315.87
498,594.41 1.30
46.24
MWD+IFR2+SAG+MS (2)
949.73
8.70
305.08 944.30
870.63
26.79
-73.60
6,000,324.50
498,581.85 1.21
59.99
MWD+IFR2+SAG+MS (2)
1,046.48
9.70
312.52 1,039.81
966.14
36.51
-85.59
6,000,334.21
498,569.86 1.60
74.40
MWD+IFR2+SAG+MS (2)
1,140.43
11.76
318.65 1,132.12
1,058.45
49.05
-97.75
6,000,346.75
498,557.70 2.50
91.34
MWD+IFR2+SAG+MS (2)
1,236.71
14.10
324.59 1,225.95
1,152.28
65.97
-111.03
6,000,363.68
498,544.43 2.79
112.64
MWD+IFR2+SAG+MS (2)
1,330.66
13.25
326.20 1,317.24
1,243.57
84.25
-123.65
6,000,381.96
498,531.81 0.99
134.78
MWD+IFR2+SAG+MS (2)
1,424.85
12.67
327.88 1,409.03
1,335.36
101.96
-135.15
6,000,399.67
498,520.32 0.73
155.87
MWD+IFR2+SAG+MS (2)
1,518.72
13.46
327.70 1,500.47
1,426.80
119.92
-146.46
6,000,417.63
498,509.01 0.84
177.07
MWD+IFR2+SAG+MS (2)
4/3012020 2:10:49PM
Page 3
COMPASS 5000.15 Build 91E
ConocoPhillips
ConocoPhillips BakerHughes $
p Definitive Survey Report
Company:
ConocoPhillips Alaska Inc-Kuparuk
Local Co-ordinate Reference:
Well 31-1-37
Project:
Kuparuk River Unit
TVD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Site:
Kuparuk 3H Pad
MD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Well:
31-1-37
North Reference:
True
Wellbore:
31-1-37
Survey Calculation Method:
Minimum Curvature
Design:
31-1-37
Database:
EDT 15 Alaska Prod
Survey
Map
Map
Vertical
MID
Inc
AN
TVD
TVDSS
+E/ -W
RLS
(usft)
(°)
(°)
(ustt)
(usft)
(usft)
usft)
(usft)
Northing
Easting
(°/100')
Section
Survey Tool Name
Annotation
(ft)
(ft)
(ft)
1,614.72
16.04
328.33
1,593.30
1,519.63
140.65
-159.40
6,000,438.36
498,496.08
2.69
201.50
MWD+IFR2+SAG+MS (2)
1,708.29
17.11
329.05
1,682.98
1,609.31
163.46
-173.27
6,000,461.17
498,482.22
1.16
228.18
MWD+IFR2+SAG+MS (2)
1,801.67
19.92
329.32
1,771.52
1,697.85
188.93
-188.45
6,000,486.64
498,467.04
3.01
257.83
MWD+IFR2+SAG+MS (2)
1,897.93
23.98
326.48
1,860.78
1,787.11
219.35
-207.63
6,000,517.06
498,447.87
4.36
293.77
MWD+IFR2+SAG+MS (2)
1,992.38
28.40
325.34
1,945.51
1,871.84
253.85
-231.01
6,000,551.56
498,424.49
4.71
335.33
MWD+IFR2+SAG+MS (2)
2,086.67
32.15
326.69
2,026.93
1,953.26
293.27
-257.55
6,000,590.98
498,397.97
4.04
382.74
MWD+IFR2+SAG+MS (2)
2,182.17
34.53
328.51
2,106.71
2,033.04
337.59
-285.65
6,000,635.31
498,369.88
2.70
435.18
MWD+IFR2+SAG+MS (2)
2,277.02
37.23
331.03
2,183.56
2,109.89
385.63
-313.59
6,000,683.34
498,341.94
3.24
490.75
MWD+IFR2+SAG+MS (2)
2,371.54
39.91
331.10
2,257.45
2,183.78
437.20
-342.10
6,000,734.91
498,313.45
2.84
549.66
MWD+IFR2+SAG+MS (2)
2,466.16
44.47
330.81
2,327.54
2,253.87
492.74
-372.95
6,000,790.45
498,282.61
4.82
613.19
MWD+IFR2+SAG+MS (2)
2,561.15
47.40
331.07
2,393.60
2,319.93
552.40
-406.10
6,000,850.11
498,249.48
3.09
681.42
MWD+IFR2+SAG+MS (2)
2,655.77
50.57
332.44
2,455.69
2,382.02
615.29
-439.86
6,000,913.00
498,215.73
3.52
752.77
MWD+IFR2+SAG+MS (2)
2,749.10
54.11
333.19
2,512.70
2,439.03
681.00
473.60
6,000,978.72
498,182.01
3.85
826.56
MWD+IFR2+SAG+MS (2)
2,843.76
55.68
333.64
2,567.13
2,493.46
750.26
-508.25
6,001,047.97
498,147.37
1.70
903.86
MWD+IFR2+SAG+MS (2)
2,938.98
57.34
333.36
2,619.67
2,546.00
821.32
-543.69
6,001,119.03
498,111.95
1.76
983.12
MWD+IFR2+SAG+MS (2)
3,033.87
58.91
333.16
2,669.78
2,596.11
893.28
-579.94
6,001,190.99
498,075.71
1.66
1,063.57
MWD+IFR2+SAG+MS (2)
3,127.96
60.05
333.30
2,717.56
2,643.89
965.65
-616.45
6,001,263.36
498,039.22
1.22
1,144.49
MWD+IFR2+SAG+MS (2)
3,222.97
59.72
332.04
2,765.23
2,691.56
1,038.66
-654.18
6,001,336.37
498,001.51
1.20
1,226.59
MWD+IFR2+SAG+MS (2)
3,315.71
61.86
332.38
2,810.49
2,736.82
1,110.27
-691.92
6,001,407.97
497,963.79
2.33
1,307.47
MWD+IFR2+SAG+MS (2)
3,408.61
62.92
333.71
2,853.55
2,779.88
1,183.64
-729.23
6,001,481.35
497,926.50
1.71
1,389.67
MWD+IFR2+SAG+MS (2)
3,505.66
64.40
334,59
2,896.61
2,822.94
1,261.91
-767.14
6,001,559.62
497,888.60
1.73
1,476.41
MWD+IFR2+SAG+MS (2)
3,563.94
64.19
334.28
2,921.88
2,848.21
1,309.28
-789.80
6,001,606.99
497,865.95
0.60
1,528.77
MWD+IFR2+SAG+MS (2)
3,620.00
64.12
333.93
2,946.32
2,872.65
1,354.67
-811.84
6,001,652.38
497,843.93
0.58
1,579.09
MWD+IFR2+SAG+MS (3)
13-1/2" x 10-3/4"
3,662.79
64.07
333.66
2,965.02
2,891.35
1,389.20
-828.83
6,001,686.91
497,826.94
0.58
1,617.50
MWD+IFR2+SAG+MS (3)
3,738.66
65.80
334.82
2,997.16
2,923.49
1,451.10
-858.70
6,001,748.80
497,797.09
2.67
1,686.03
MWD+IFR2+SAG+MS (3)
3,834.32
66.82
335.43
3,035.59
2,961.92
1,530.57
-895.54
6,001,828.27
497,760.26
1.22
1,773.28
MWD+IFR2+SAG+MS (3)
3,928.29
67.39
336.79
3,072.15
2,998.48
1,609.72
-930.60
6,001,907,42
497,725.22
1.46
1,859.36
MWD+IFR2+SAG+MS (3)
4,023.31
68.95
338.98
3,107.49
3,033.82
1,691.43
-963.79
6,001,989.13
497,692.05
2.70
1,946.72
MWD+IFR2+SAG+MS (3)
4,118.05
70.46
339.75
3,140.35
3,066.68
1,774.59
-995.10
6,002,072.28
497,660.75
1.77
2,034.39
MWD+IFR2+SAG+MS (3)
4,212.66
71.55
339.86
3,171.14
3,097.47
1,858.54
-1,025.98
6,002,156.24
497,629.89
1.16
2,122.54
MWD+IFR2+SAG+MS (3)
4,307.15
72.76
339.44
3,200.10
3,126.43
1,942.87
-1,057.26
6,002,240.56
497,598.63
1.35
2,211.22
MWD+IFR2+SAG+MS (3)
4/30/2020 2:10.,49PM
Page 4
COMPASS 5000.15 Build 91E
10-1 ConocoPhillips
ConocoMilli S BakerHughes 21
1'11 p Definitive Survey Report
Company:
ConocoPhillips Alaska Inc-Kuparuk
Local Co-ordinate Reference:
Well 31-1-37
Project:
Kuparuk River Unit
TVD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Site:
Kuparuk 3H Pad
MD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Well:
31-1-37
North Reference:
True
Wellbore:
31-1-37
Survey Calculation Method:
Minimum Curvature
Design:
31-1-37
Database:
EDT 15 Alaska Prod
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/ -S
+E/ -W
DLS
(usft)
0
(°)
(usft)
(usft)
(usft)
(usft)
Northing
East)
(°/100')
Section
Survey Tool Name Annotation
(ft)
(ft)
(ft)
4,402.01
72.82
338.19
3,228.17
3,154.50
2,027.36
-1,090.01
6,002,325.05
497,565.90
1.26
2,300.76
MWD+IFR2+SAG+MS (3)
4,497.58
72.81
336.43
3,256.40
3,182.73
2,111.59
-1,125.23
6,002,409.28
497,530.70
1.76
2,391.32
MWD+IFR2+SAG+MS (3)
4,592.38
72.81
336.47
3,284.42
3,210.75
2,194.61
-1,161.41
6,002,492.30
497,494.54
0.04
2,481.31
MWD+IFR2+SAG+MS (3)
4,686.44
72.75
336.95
3,312.27
3,238.60
2,277.14
-1,196.93
6,002,574.82
497,459.03
0.49
2,570.54
MWD+IFR2+SAG+MS (3)
4,780.75
72.81
336.90
3,340.19
3,266.52
2,360.01
-1,232.24
6,002,657.69
497,423.75
0.08
2,659.97
MWD+IFR2+SAG+MS (3)
4,876.39
72.80
336.26
3,368.46
3,294.79
2,443.85
-1,268.55
6,002,741.53
497,387.45
0.64
2,750.73
MWD+IFR2+SAG+MS (3)
4,968.93
72.62
337.32
3,395.96
3,322.29
2,525.05
-1,303.38
6,002,822.73
497,352.65
1.11
2,838.47
MWD+IFR2+SAG+MS (3)
5,064.86
72.80
337.44
3,424.48
3,350.81
2,609.60
-1,338.61
6,002,907.28
497,317.44
0.22
2,929.31
MWD+IFR2+SAG+MS (3)
5,159.43
72.81
336.72
3,452.43
3,378.76
2,692.81
-1,373.79
6,002,990.49
497,282.27
0.73
3,018.97
MWD+IFR2+SAG+MS (3)
5,254.00
72.76
335.51
3,480.42
3,406.75
2,775.41
-1,410.36
6,003,073.08
497,245.71
1.22
3,108.79
MWD+IFR2+SAG+MS (3)
5,349.15
72.87
334.26
3,508.54
3,434.87
2,857.72
-1,448.95
6,003,155.39
497,207.15
1.26
3,199.36
MWD+IFR2+SAG+MS (3)
5,443.17
73.40
335.44
3,535.81
3,462.14
2,939.16
-1,487.18
6,003,236.83
497,168.93
1.33
3,289.01
MWD+IFR2+SAG+MS (3)
5,537.82
73.54
335.85
3,562.74
3,489.07
3,021.82
-1,524.60
6,003,319.49
497,131.53
0.44
3,379.31
MWD+IFR2+SAG+MS (3)
5,632.42
73.49
335.90
3,589.59
3,515.92
3,104.61
-1,561.68
6,003,402.28
497,094.47
0.07
3,469.55
MWD+IFR2+SAG+MS (3)
5,726.30
73.55
335.54
3,616.22
3,542.55
3,186.67
-1,598.70
6,003,484.34
497,057.48
0.37
3,559.12
MWD+IFR2+SAG+MS (3)
5,821.23
73.61
335.09
3,643.06
3,569.39
3,269.41
-1,636.72
6,003,567.07
497,019.47
0.46
3,649.79
MWD+IFR2+SAG+MS (3)
5,914.84
73.58
333.87
3,669.49
3,595.82
3,350.44
-1,675.41
6,003,648.11
496,980.80
1.25
3,739.31
MWD+IFR2+SAG+MS (3)
6,009.55
73.62
333.22
3,696.23
3,622.56
3,431.79
-1,715.89
6,003,729.45
496,940.34
0.66
3,830.00
MWD+IFR2+SAG+MS (3)
6,104.28
73.62
334.29
3,722.95
3,649.28
3,513.30
-1,756.08
6,003,810.96
496,900.17
1.08
3,920.69
MWD+IFR2+SAG+MS (3)
6,197.30
73.58
335.73
3,749.21
3,675.54
3,594.18
-1,793.77
6,003,891.84
496,862.49
1.49
4,009.58
MWD+IFR2+SAG+MS (3)
6,291.35
73.58
336.72
3,775.80
3,702.13
3,676.74
-1,830.14
6,003,974.39
496,826.14
1.01
4,099.26
MWD+IFR2+SAG+MS (3)
6,387.72
73.55
337.29
3,803.07
3,729.40
3,761.82
-1,866.25
6,004,059.48
496,790.05
0.57
4,191.01
MWD+IFR2+SAG+MS (3)
6,481.99
73.59
337.43
3,829.73
3,756.06
3,845.28
-1,901.06
6,004,142.93
496,755.26
0.15
4,280.69
MWD+IFR2+SAG+MS (3)
6,576.99
73.64
338.20
3,856.53
3,782.86
3,929.67
-1,935.47
6,004,227.32
496,720.87
0.78
4,370.98
MWD+IFR2+SAG+MS (3)
6,670.15
73.64
337.91
3,882.77
3,809.10
4,012.58
-1,968.88
6,004,310.23
496,687.48
0.30
4,459.49
MWD+IFR2+SAG+MS (3)
6,765.12
73.64
336.79
3,909.52
3,835.85
4,096.68
-2,003.97
6,004,394.32
496,652.41
1.13
4,549.87
MWD+IFR2+SAG+MS (3)
6,860.56
73.57
335.90
3,936.46
3,862.79
4,180.54
-2,040.71
6,004,478.19
496,615.69
0.90
4,640.87
MWD+IFR2+SAG+MS (3)
6,954.62
73.64
335.86
3,963.01
3,889.34
4,262.90
-2,077.58
6,004,560.54
496,578.83
0.08
4,730.63
MWD+IFR2+SAG+MS (3)
7,048.51
73.70
336.11
3,989.41
3,915.74
4,345.20
-2,114.25
6,004,642.84
496,542.18
0.26
4,820.24
MWD+IFR2+SAG+MS (3)
7,144.12
73.58
336.00
4,016.34
3,942.67
4,429.05
-2,151.48
6,004,726.69
496,504.97
0.17
4,911.47
MWD+IFR2+SAG+MS (3)
7,238.98
73.11
336.41
4,043.53
3,969.86
4,512.20
-2,188.15
6,004,809.84
496,468.32
0.65
5,001.82
MWD+IFR2+SAG+MS (3)
4/30/2020 2:10:49PM
Page 5
COMPASS 5000.15 Build 91E
ConocoPhillips
ConocoPhillips
BakerHughes $
Definitive Survey Report
Company: ConocoPhillips Alaska Inc-Kuparuk
Local Co-ordinate Reference:
Well 31-1-37
Project: Kuparuk River Unit
TVD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Site: Kuparuk 3H Pad
MD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Well: 31-1-37
North Reference:
True
Wellbore: 31-1-37
Survey Calculation Method:
Minimum Curvature
Design: 31-1-37
Database:
EDT 15 Alaska Prod
Survey
4/30/2020 2:10:49PM Page 6 COMPASS 5000.15 Build 91E
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/ -S
+E/ -W
DLS
(usft)
(°)
(°)
(-ft)
(-ft)
(usft)
(usft)
Northing
Northing
Ea(t)
(°/100')
Section
Survey Tool Name Annotation
(ft)
(ft)
(ft)
7,333.59
73.28
337.11
4,070.88
3,997.21
4,595.42
-2,223.89
6,004,893.06
496,432.60
0.73
5,091.76
MWD+IFR2+SAG+MS (3)
7,428.25
73.37
336.97
4,098.04
4,024.37
4,678.92
-2,259.26
6,004,976.55
496,397.25
0.17
5,181.76
MWD+IFR2+SAG+MS (3)
7,522.44
73.48
337.21
4,124.91
4,051.24
4,762.07
-2,294.40
6,005,059.70
496,362.12
0.27
5,271.34
MWD+IFR2+SAG+MS (3)
7,617.30
73.34
336.96
4,152.00
4,078.33
4,845.81
-2,329.80
6,005,143.44
496,326.74
0.29
5,361.56
MWD+IFR2+SAG+MS (3)
7,711.90
73.43
336.80
4,179.05
4,105.38
4,929.18
-2,365.40
6,005,226.81
496,291.17
0.19
5,451.56
MWD+IFR2+SAG+MS (3)
7,807.22
73.49
336.51
4,206.18
4,132.51
5,013.07
-2,401.60
6,005,310.70
496,254.98
0.30
5,542.32
MWD+IFR2+SAG+MS (3)
7,901.77
73.51
335.97
4,233.04
4,159.37
5,096.04
-2,438.13
6,005,393.67
496,218.47
0.55
5,632.45
MWD+IFR2+SAG+MS (3)
7,996.09
73.39
335.73
4,259.90
4,186.23
5,178.54
-2,475.12
6,005,476.17
496,181.50
0.28
5,722.39
MWD+IFR2+SAG+MS (3)
8,090.31
73.64
336.04
4,286.64
4,212.97
5,261.01
-2,512.03
6,005,558.63
496,144.60
0.41
5,812.26
MWD+IFR2+SAG+MS (3)
8,185.50
73.68
335.96
4,313.42
4,239.75
5,344.45
-2,549.19
6,005,642.07
496,107.47
0.09
5,903.11
MWD+IFR2+SAG+MS (3)
8,285.13
73.51
336.90
4,341.56
4,267.89.
5,432.05
-2,587.40
6,005,729.67
496,069.27
0.92
5,998.08
MWD+IFR2+SAG+MS (3)
8,374.31
73.59
336.29
4,366.81
4,293.14
5,510.54
-2,621.38
6,005,808.16
496,035.31
0.66
6,083.05
MWD+IFR2+SAG+MS (3)
8,468.26
73.64
335.82
4,393.32
4,319.65
5,592.92
-2,657.96
6,005,890.54
495,998.75
0.48
6,172.68
MWD+IFR2+SAG+MS (3)
8,563.11
73.59
336.14
4,420.07
4,346.40
5,676.04
-2,695.00
6,005,973.65
495,961.73
0.33
6,263.18
MWD+IFR2+SAG+MS (3)
8,657.17
73.61
335.89
4,446.63
4,372.96
5,758.48
-2,731.68
6,006,056.09
495,925.07
0.26
6,352.92
MWD+IFR2+SAG+MS (3)
8,751.74
73.64
336.01
4,473.29
4,399.62
5,841.34
-2,768.66
6,006,138.95
495,888.11
0.13
6,443.17
MWD+IFR2+SAG+MS(3)
8,845.79
73.68
336.09
4,499.75
4,426.08
5,923.82
-2,805.29
6,006,221.43
495,851.49
0.09
6,532.92
MWD+IFR2+SAG+MS (3)
8,941.58
73.65
335.77
4,526.69
4,453.02
6,007.75
-2,842.79
6,006,305.36
495,814.02
0.32
6,624.35
MWD+IFR2+SAG+MS (3)
9,035.27
73.65
335.96
4,553.07
4,479.40
6,089.79
-2,879.54
6,006,387.40
495,777.28
0.19
6,713.78
MWD+IFR2+SAG+MS (3)
9,129.71
73.59
336.39
4,579.70
4,506.03
6,172.68
-2,916.15
6,006,470.28
495,740.70
0.44
6,803.87
MWD+IFR2+SAG+MS (3)
9,224.89
73.61
336.72
4,606.57
4,532.90
6,256.45
-2,952.47
6,006,554.05
495,704.39
0.33
6,894.58
MWD+IFR2+SAG+MS (3)
9,318.72
73.61
336.87
4,633.05
4,559.38
6,339.18
-2,987.94
6,006,636.78
495,668.94
0.15
6,983.96
MWD+IFR2+SAG+MS (3)
9,413.94
73.62
336.69
4,659.91
4,586.24
6,423.13
-3,023.96
6,006,720.73
495,632.94
0.18
7,074.68
MWD+IFR2+SAG+MS (3)
9,506.99
73.62
337.09
4,686.15
4,612.48
6,505.24
-3,059.00
6,006,802.84
495,597.92
0.41
7,163.31
MWD+IFR2+SAG+MS (3)
9,602.88
73.64
337.71
4,713.18
4,639.51
6,590.18
-3,094.35
6,006,887.77
495,562.58
0.62
7,254.55
MWD+IFR2+SAG+MS (3)
9,696.50
73.61
338.32
4,739.57
4,665.90
6,673.47
-3,127.98
6,006,971.06
495,528.97
0.63
7,343.50
MWD+IFR2+SAG+MS (3)
9,791.71
73.55
338.32
4,766.48
4,692.81
6,758.34
-3,161.72
6,007,055.93
495,495.25
0.06
7,433.86
MWD+IFR2+SAG+MS (3)
9,886.71
73.63
338.19
4,793.32
4,719.65
6,842.98
-3,195.48
6,007,140.57
495,461.51
0.16
7,524.05
MWD+IFR2+SAG+MS (3)
9,980.95
73.49
338.18
4,819.99
4,746.32
6,926.90
-3,229.07
6,007,224.48
495,427.94
0.15
7,613.52
MWD+IFR2+SAG+MS (3)
10,074.21
73.49
337.99
4,846.50
4,772.83
7,009.85
-3,262.44
6,007,307.43
495,394.58
0.20
7,702.05
MWD+IFR2+SAG+MS (3)
10,169.65
73.46
337.94
4,873.64
4,799.97
7,094.67
-3,296.77
6,007,392.24
495,360.28
0.06
7,792.67
MWD+IFR2+SAG+MS (3)
4/30/2020 2:10:49PM Page 6 COMPASS 5000.15 Build 91E
ConocoPhillips
21
ConocoPhillips Definitive Survey Report 8akerHughes
Company:
ConocoPhillips Alaska Inc-Kuparuk
Local Co-ordinate Reference:
Well 31-1-37
Project:
Kuparuk River Unit
TVD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Site:
Kuparuk 3H Pad
MD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Well:
31-1-37
North Reference:
True
Wellbore:
31-1-37
Survey Calculation Method:
Minimum Curvature
Design:
31-1-37
Database:
EDT 15 Alaska Prod
Survey
4/30/2020 2:10:49PM Page 7 COMPASS 5000.15 Build 91E
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+NlS
VII +El.
Northing
Easting
DLS
Section
(usft)
(`)
(')
(usft)
(usft)
(usft)
(usft)
(°l100-)
Survey Tool Name Annotation
(ft)
(ft)
(ft)
10,265.30
73.41
338.35
4,900.91
4,827.24
7,179.76
-3,330.90
6,007,477.33
495,326.17
0.41
7,883.42
MWD+IFR2+SAG+MS (3)
10,358.24
73.40
338.21
4,927.46
4,853.79
7,262.50
-3,363.86
6,007,560.08
495,293.22
0.14
7,971.57
MWD+IFR2+SAG+MS (3)
10,453.55
73.49
337.57
4,954.61
4,880.94
7,347.14
-3,398.25
6,007,644.71
495,258.85
0.65
8,062.06
MWD+IFR2+SAG+MS (3)
10,548.60
73.39
337.07
4,981.70
4,908.03
7,431.20
-3,433.38
6,007,728.77
495,223.74
0.52
8,152.43
MWD+IFR2+SAG+MS (3)
10,642.32
73.43
337.08
5,008.46
4,934.79
7,513.93
-3,468.36
6,007,811.50
495,188.78
0.04
8,241.57
MWD+IFR2+SAG+MS (3)
10,737.08
73.45
335.59
5,035.47
4,961.80
7,597.12
-3,504.82
6,007,894.68
495,152.34
1.51
8,331.84
MWD+IFR2+SAG+MS (3)
10,831.00
73.53
334.79
5,062.16
4,988.49
7,678.85
-3,542.60
6,007,976.42
495,114.57
0.82
8,421.52
MWD+IFR2+SAG+MS (3)
10,924.54
73.47
334.67
5,088.73
5,015.06
7,759.96
-3,580.89
6,008,057.52
495,076.30
0.14
8,510.90
MWD+IFR2+SAG+MS (3)
11,017.96
73.45
334.82
5,115.33
5,041.66
7,840.95
-3,619.10
6,008,138.52
495,038.11
0.16
8,600.15
MWD+IFR2+SAG+MS (3)
11,113.70
73.52
334.97
5,142.54
5,068.87
7,924.07
-3,658.04
6,008,221.63
494,999.19
0.17
8,691.61
MWD+IFR2+SAG+MS (3)
11,208.81
73.45
335.60
5,169.58
5,095.91
8,006.90
-3,696.17
6,008,304.46
494,961.08
0.64
8,782.41
MWD+IFR2+SAG+MS (3)
11,300.86
73.49
335.78
5,195.77
5,122.10
8,087.33
-3,732.50
6,008,384.88
494,924.77
0.19
8,870.22
MWD+IFR2+SAG+MS (3)
11,396.70
73.36
335.85
5,223.11
5,149.44
8,171.12
-3,770.13
6,008,468.68
494,887.16
0.15
8,961.61
MWD+IFR2+SAG+MS (3)
11,490.98
73.33
335.77
5,250.13
5,176.46
8,253.51
-3,807.14
6,008,551.07
494,850.16
0.09
9,051.47
MWD+IFR2+SAG+MS (3)
11,585.51
73.47
336.25
5,277.14
5,203.47
8,336.28
-3,843.97
6,008,633.83
494,813.35
0.51
9,141.56
MWD+IFR2+SAG+MS (3)
11,680.88
73.43
336.56
5,304.30
5,230.63
8,420.05
-3,880.56
6,008,717.61
494,776.78
0.31
9,232.41
MWD+IFR2+SAG+MS (3)
11,776.68
73.50
336.53
5,331.57
5,257.90
8,504.30
-3,917.12
6,008,801.85
494,740.24
0.08
9,323.65
MWD+IFR2+SAG+MS (3)
11,870.88
73.44
336.41
5,358.37
5,284.70
8,587.10
-3,953.17
6,008,884.65
494,704.21
0.14
9,413.39
MWD+IFR2+SAG+MS (3)
11,964.93
73.39
336.62
5,385.21
5,311.54
8,669.77
-3,989.09
6,008,967.32
494,668.31
0.22
9,502.94
MWD+IFR2+SAG+MS (3)
12,059.99
73.45
336.81
5,412.34
5,338.67
8,753.46
-4,025.11
6,009,051.00
494,632.31
0.20
9,593.43
MWD+IFR2+SAG+MS (3)
12,154.26
73.45
336.79
5,439.19
5,365.52
8,836.52
-4,060.71
6,009,134.06
494,596.73
0.02
9,683.16
MWD+IFR2+SAG+MS (3)
12,246.16
73.74
337.70
5,465.15
5,391.48
8,917.81
-4,094.80
6,009,215.35
494,562.65
1.00
9,770.61
MWD+IFR2+SAG+MS (3)
12,343.29
73.96
340.10
5,492.17
5,418.50
9,004.85
-4,128.39
6,009,302.39
494,529.09
2.38
9,862.78
MWD+IFR2+SAG+MS (3)
12,436.56
73.93
341.74
5,517.97
5,444.30
9,089.55
4,157.69
6,009,387.09
494,499.80
1.69
9,950.79
MWD+IFR2+SAG+MS (3)
12,530.99
74.00
343.10
5,544.05
5,470.38
9,176.07
-4,185.10
6,009,473.60
494,472.41
1.39
10,039.42
MWD+IFR2+SAG+MS (3)
12,625.37
74.01
344.92
5,570.06
5,496.39
9,263.28
-4,210.09
6,009,560.81
494,447.44
1.85
10,127.45
MWD+IFR2+SAG+MS (3)
12,720.05
74.03
346.75
5,596.13
5,522.46
9,351.53
-4,232.36
6,009,649.05
494,425.18
1.86
10,215.02
MWD+IFR2+SAG+MS (3)
12,813.65
73.98
348.59
5,621.92
5,548.25
9,439.43
-4,251.57
6,009,736.94
494,405.99
1.89
10,300.75
MWD+IFR2+SAG+MS (3)
12,907.30
73.94
350.07
5,647.80
5,574.13
9,527.87
4,268.24
6,009,825.38
494,389.34
1.52
10,385.68
MWD+IFR2+SAG+MS (3)
13,003.59
73.98
350.63
5,674.40
5,600.73
9,619.10
4,283.75
6,009,916.61
494,373.85
0.56
10,472.45
MWD+IFR2+SAG+MS (3)
13,098.55
73.93
350.42
5,700.65
5,626.98
9,709.12
4,298.77
6,010,006.62
494,358.84
0.22
10,557.93
MWD+IFR2+SAG+MS (3)
4/30/2020 2:10:49PM Page 7 COMPASS 5000.15 Build 91E
l '-
Survey
ConocoPhillips
�.
ConocoPhillips
BakerHughes
i�
Definitive Survey Repoli
Map
Company: ConocoPhillips Alaska Inc-Kuparuk
Local Co-ordinate Reference:
Well 31-1-37
Project: Kuparuk River Unit
TVD Reference:
Actual 37.87+35.80@73.67usft (1319) @ 73.67usft (Doy
Site: Kuparuk 3H Pad
MD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Well: 31-1-37
North Reference:
True
Wellbore: 31-1-37
Survey Calculation Method:
Minimum Curvature
Design: 31-1-37
Database:
EDT 15 Alaska Prod
Survey
4/30/2020 2:10:49PM
Page 8
COMPASS 5000.15 Build 91E
Map
Map
Vertical
MD
Inc
AzI
TVD
TVDSS
+N1 -S
+E/ -W
DUS
(usft)
(')
0
(usft)
(usft)
(usft)
(usft)
Northing
Easting
(°/100')
Section
Survey Tool Name
Annotation
(ft)
(ft)
(ft)
13,194.26
74.06
350.75
5,727.04
5,653.37
9,799.88
-4,313.82
6,010,097.37
494,343.81
0.36
10,644.06
MWD+IFR2+SAG+MS (3)
13,287.85
73.98
351.32
5,752.81
5,679.14
9,888.75
-4,327.84
6,010,186.24
494,329.81
0.59
10,728.04
MWD+IFR2+SAG+MS (3)
13,383.07
73.98
351.63
5,779.08
5,705.41
9,979.26
-4,341.41
6,010,276.74
494,316.26
0.31
10,813.22
MWD+IFR2+SAG+MS (3)
13,478.32
73.91
351.54
5,805.43
5,731.76
10,069.81
-4,354.81
6,010,367.28
494,302.88
0.12
10,898.34
MWD+IFR2+SAG+MS (3)
13,572.96
73.94
351.09
5,831.63
5,757.96
10,159.71
-4,368.54
6,010,457.17
494,289.17
0.46
10,983.06
MWD+IFR2+SAG+MS (3)
13,668.33
74,03
351.45
5,857.94
5,784.27
10,250.32
-4,382.45
6,010,547.77
494,275.27
0.37
11,068.49
MWD+IFR2+SAG+MS (3)
13,762.57
74.10
351.45
5,883.82
5,810.15
10,339.93
-4,395.92
6,010,637.38
494,261.82
0.07
11,152.84
MWD+IFR2+SAG+MS (3)
13,856.30
75.69
350.49
5,908.24
5,834.57
10,429.29
-4,410.13
6,010,726.74
494,247.63
1.96
11,237.34
MWD+IFR2+SAG+MS (3)
13.950.89
77.05
349.33
5,930.53
5,856.86
10,519.79
-4,426.24
6,010,817.23
494,231.54
1.87
11,323.77
MWD+IFR2+SAG+MS (3)
14,038.00
80.14
347.60
5,947.76
5,874.09
10,603.44
-4,443.31
6,010,900.88
494,214.48
4.04
11,404.76
MWD -INC _ONLY (4)
9-7/8" x 7-5/8"
14,049.31
80.54
347.38
5,949.66
5,875.99
10,614.33
4,445.73
6,010,911.76
494,212.06
4.04
11,415.40
MWD-INC_ONLY (4)
Interpolated Azimuth
14,147.80
83.20
345.47
5,963.58
5,889.91
10,709.09
-4,468.62
6,011,006.52
494,189.20
3.31
11,508.91
MWD+IFR2+SAG+MS (5)
14,243.72
86.31
343.35
5,972.35
5,898.68
10,801.08
-4,494.29
6,011,098.50
494,163.55
3.92
11,601.41
MWD+IFR2+SAG+MS (5)
14,339.80
89.92
341.40
5,975.51
5,901.84
10,892.58
-0,523.36
6,011,190.00
494,134.49
4.27
11,695.19
MWD+IFR2+SAG+MS (5)
14,434.49
90.46
338.54
5,975.20
5,901.53
10,981.53
-4,555.79
6,011,278.95
494,102.08
3.07
11,788.45
MWD+IFR2+SAG+MS (5)
14,529.15
89.55
331.27
5,975.19
5,901.52
11,067.20
-4,595.91
6,011,364.61
494,061.98
7.74
11,882.70
MWD+IFR2+SAG+MS (5)
14,623.87
90.29
327.12
5,975.32
5,901.65
11,148.53
-4,644.40
6,011,445.95
494,013.51
4.45
11,977.39
MWD+IFR2+SAG+MS (5)
14,719.32
89.81
324.52
5,975.24
5,901.57
11,227.49
-4,698.02
6,011,524.91
493,959.91
2.77
12,072.57
MWD+IFR2+SAG+MS (5)
14,811.87
90.00
325.26
5,975.39
5,901.72
11,303.20
-4,751.25
6,011,600.62
493,906.70
0.83
12,164.75
MWD+IFR2+SAG+MS (5)
14,905.56
90.40
327.32
5,975.07
5,901.40
11,381.13
4,803.24
6,011,678.55
493,854.72
2.24
12,258.24
MWD+IFR2+SAG+MS (5)
15,000.91
88.17
321.03
5,976.26
5,902.59
11,458.39
4,859.02
6,011,755.82
493,798.97
7.00
12,353.03
MWD+IFR2+SAG+MS (5)
15,095.17
88.21
315.16
5,979.24
5,905.57
11,528.48
4,921.91
6,011,825.91
493,736.09
6.22
12,445.18
MWD+IFR2+SAG+MS (5)
15,163.52
87.81
313.55
5,981.61
5,907.94
11,576.23
-4,970.75
6,011,873.67
493,687.26
2.43
12,510.95
MWD+IFR2+SAG+MS (5)
15,259.08
87.81
312.54
5,985.26
5,911.59
11,641.41
-5,040.54
6,011,938.85
493,617.50
1.06
12,602.28
MWD+IFR2+SAG+MS (5)
15,353.04
88.97
312.10
5,987.90
5,914.23
11,704.65
5,109.98
6,012,002.09
493,548.07
1.32
12,691.76
MWD+IFR2+SAG+MS (5)
15,447.56
89.26
314.34
5,989.36
5,915.69
11,769.36
-5,178.85
6,012,066.81
493,479.22
2.39
12,782.24
MWD+IFR2+SAG+MS (5)
15,542.83
90.23
313.98
5,989.79
5,916.12
11,835.73
-5,247.20
6,012,133.19
493,410.90
1.09
12,873.88
MWD+IFR2+SAG+MS (5)
15,636.14
90.68
312.68
5,989.05
5,915.38
11,899.76
-5,315.07
6,012,197.22
493,343.04
1.47
12,963.26
MWD+IFR2+SAG+MS (5)
15,731.72
90.70
312.87
5,987.89
5,914.22
11,964.66
-5,385.22
6,012,262.13
493,272.91
0.20
13,054.54
MWD+IFR2+SAG+MS (5)
15,827.02
90.42
310.17
5,986.96
5,913.29
12,027.83
-5,456.56
6,012,325.30
493,201.59
2.85
13,144.91
MWD+IFR2+SAG+MS (5)
15,921.44
89.96
308.81
5,986.65
5,912.98
12,087.87
-5,529.43
6,012,385.35
493,128.74
1.52
13,233.34
MWD+IFR2+SAG+MS (5)
4/30/2020 2:10:49PM
Page 8
COMPASS 5000.15 Build 91E
*-
ConocoPhillips
ConocoPhillips
Baker Hughes
p
Definitive Survey Report
Company: ConocoPhillips Alaska Inc-Kuparuk
Local Co-ordinate Reference:
Well 31-1-37
Project: Kuparuk River Unit
TVD Reference:
Actual 37.87+35.80@73.67usft (1319) @ 73.67usft (Doy
Site: Kuparuk 3H Pad
MD Reference:
Actual 37.87+35.80@73.67usft (D19) @ 73.67usft (Doy
Well: 31-1-37
North Reference:
True
Wellbore: 31-1-37
Survey Calculation Method:
Minimum Curvature
Design: 31-1-37
Database:
EDT 15 Alaska Prod
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/ -S
+E/ -W
DLS
(usft)
(°)
(°)
(usft)
(usft)
(waft
(usft)
Northing
Easting
(°l100')
Section
Survey Tool Name Annotation
(ft)
(ft)
(ft)
16,013.70
89.12
309.55
5,987.39
5,913.72
12,146.15
-5,600.94
6,012,443.64
493,057.24
1.21
13,319.56
MWD+IFR2+SAG+MS(5)
16,106.91
89.04
310.85
5,988.89
5,915.22
12,206.31
-5,672.12
6,012,503.80
492,986.08
1.40
13,407.24
MWD+IFR2+SAG+MS (5)
16,198.77
89.98
309.88
5,989.67
5,916.00
12,265.80
5,742.11
6,012,563.30
492,916.11
1.47
13,493.75
MWD+IFR2+SAG+MS (5)
16,290.87
90.46
310.00
5,989.32
5,915.65
12,324.92
-5,812.73
6,012,622.43
492,845.51
0.54
13,580.26
MWD+IFR2+SAG+MS (5)
16,383.08
90.27
313.60
5,988.73
5,915.06
12,386.37
-5,881.45
6,012,683.89
492,776.80
3.91
13,667.83
MWD+IFR2+SAG+MS (5)
16,475.23
89.84
315.60
5,988.64
5,914.97
12,451.07
-5,947.06
6,012,748.59
492,711.21
2.22
13756.67
MWD+IFR2+SAG+MS (5)
16,566.25
90.37
314.39
5,988.48
5,914.81
12,515.43
-6,011.43
6,012,812.95
492,646.86
1.45
13,844.58
MWD+IFR2+SAG+MS (5)
16,658.06
91.48
315.73
5,986.99
5,913.32
12,580.40
-6,076.27
6,012,877.93
492,582.04
1.90
13,933.26
MWD+IFR2+SAG+MS (5)
16,750.26
90.26
311.93
5,985.59
5,911.92
12,644.23
-6,142.76
6,012,941.77
492,515.57
4.33
14,021.78
MWD+IFR2+SAG+MS (5)
16,843.99
90.09
314.73
5,985.31
5,911.64
12,708.54
-6,210.93
6,013,006.09
492,447.41
2.99
14,111.56
MWD+IFR2+SAG+MS (5)
16,934.22
90.06
316.06
5,985.19
5,911.52
12,772.78
-6,274.29
6,013,070.33
492,384.07
1.47
14,198.87
MWD+IFR2+SAG+MS (5)
17,026.94
90.43
313.76
5,984.79
5,911.12
12,838.24
-6,339.95
6,013,135.79
492,318.43
2.51
14,288.38
MWD+IFR2+SAG+MS (5)
17,120.11
90.65
316.11
5,983.91
5,910.24
12,904.04
-6,405.90
6,013,201.59
492,252.50
2.53
14,378.33
MWD+IFR2+SAG+MS (5)
17,212.35
90.52
312.18
5,982.97
5,909.30
12,968.26
-6,472.08
6,013,265.83
492,186.34
4.26
14,467.04
MWD+IFR2+SAG+MS (5)
17,303.83
90.31
311.62
5,982.31
5,908.64
13,029.36
-6,540.16
6,013,326.92
492,118.27
0.65
14,553.98
MWD+IFR2+SAG+MS (5) -
17,395.39
89.96
314.38
5,982.09
5,908.42
13,091.79
-6,607.12
6,013,389.37
492,051.34
3.04
14,641.53
MWD+IFR2+SAG+MS (5)
17,486.71
89.94
313.53
5,982.17
5,908.50
13,155.18
-6,672.86
6,013,452.76
491,985.62
0.93
14,729.29
MWD+IFR2+SAG+MS (5)
17,579.64
90.71
316.22
5,981.65
5,907.98
13,220.74
-6,738.71
6,013,518.32
491,919.79
3.01
14,818.98
MWD+IFR2+SAG+MS (5)
17,670.13
91.58
319.74
5,979.84
5,906.17
13,287.94
-6,799.26
6,013,585.53
491,859.25
4.01
14,907.45
MWD+IFR2+SAG+MS (5)
17,760.71
89.23
319.43
5,979.20
5,905.53
13,356.90
-6,857.98
6,013,654.49
491.,800.55
2.62
14,996.53
MWD+IFR2+SAG+MS (5)
17,850.69
89.29
320.29
5,980.36
5,906.69
13,425.68
-6,915.98
6,013,723.27
491,742.57
0.96
15,085.09
MWD+IFR2+SAG+MS (5)
17,942.25
90.59
317.70
5,980.45
5,906.78
13,494.77
-6,976.05
6,013,792.37
491,682.52
3.17
15,174.96
MWD+IFR2+SAG+MS (5)
18,034.82
90.71
314.02
5,979.40
5,905.73
13,561.18
-7,040.50
6,013,858.79
491,618.09
3.98
15,264.70
MWD+IFR2+SAG+MS (5)
18,126.65
90.61
315.12
5,978.35
5,904.68
13,625.62
-7,105.91
6,013,923.23
491,552.69
1.20
15,353.20
MWD+IFR2+SAG+MS (5)
18,217.86
90.46
310.64
5,977.49
5,903.82
13,687.67
-7,172.73
6,013,985.29
491,485.89
4.91
15,440.34
MWD+IFR2+SAG+MS (5)
18,310.29
90.40
314.56
5,976.80
5,903.13
13,750.22
-7,240.75
6,014,047.84
491,417.89
4.24
15,528.52
MWD+IFR2+SAG+MS (5)
18,402.95
89.78
315.64
5,976.66
5,902.99
13,815.85
-7,306.15
6,014,113.48
491,352.50
1.34
15,618.06
MWD+IFR2+SAG+MS (5)
18,494.70
90.47
316.89
5,976.45
5,902.78
13,882.14
-7,369.58
6,014,179.78
491,289.09
1.56
15,707.18
MWD+IFR2+SAG+MS (5)
18,586.42
89.71
313.98
5,976.31
5,902.64
13,947.48
-7,433.94
6,014,245.12
491,224.76
3.28
15,795.93
MWD+IFR2+SAG+MS (5)
18,679.17
89.97
311.70
5,976.57
5,902.90
14,010.54
-7,501.94
6,014,308.19
491,156.77
2.47
15,884.54
MWD+IFR2+SAG+MS (5)
18,773.86
90.12
311.37
5,976.50
5,902.83
14,073.33
-7,572.82
6,014,370.98
491,085.91
0.38
15,974.35
MWD+IFR2+SAG+MS (5)
4/30/2020 2:10:49PM
Page 9
COMPASS 5000.15 Build 91E
ConocoPhillips
ConocoPhillips BakerHughes
p Definitive Survey Report
Company:
ConocoPhillips Alaska Inc_Kuparuk
Local Co-ordinate Reference:
Well 31-1-37
Project:
Kuparuk River Unit
TVD Reference:
Actual 37.87+35.80@73.67usft
(D19) @ 73.67usft (Doy
Site:
Kuparuk 3H Pad
MD Reference:
Actual 37.87+35.80@73.67usft
(D19) @ 73.67usft (Doy
Well:
31-1-37
North Reference:
True
Wellbore:
31-1-37
Survey Calculation Method:
Minimum Curvature
Design:
31-1-37
Database:
EDT 15
Alaska Prod
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/,S
+E/ -W
Northing
Easting
DLS
Section
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°1100')
Survey Tool Name
(ft)
(ft)
(ft)
18,867.75
89.84
309.41
5,976.53
5,902.86
14,134.17
-7,644.33
6,014,431.82
491,014.42
2.11
16,062.79
MWD+IFR2+SAG+MS (5)
18,963.12
89.66
307.84
5,976.94
5,903.27
14,193.70
-7,718.83
6,014,491.36
490,939.93
1.66
16,151.59
MWD+IFR2+SAG+MS (5)
19,058.53
89.85
304.58
5,977.35
5,903.68
14,250.05
-7,795.80
6,014,547.72
490,862.98
3.42
16,238.87
MWD+IFR2+SAG+MS (5)
19,153.24
89.97
305.05
5,977.50
5,903.83
14,304.12
-7,873.56
6,014,601.80
490,785.24
0.51
16,324.57
MWD+IFR2+SAG+MS (5)
19,248.77
89.81
309.49
5,977.68
5,904.01
14,361.96
-7,949.56
6,014,659.65
490,709.25
4.65
16,412.65
MWD+IFR2+SAG+MS (5)
19,344.08
88.38
309.67
5,979.19
5,905,52
14,422.68
-8,023.01
6,014,720.37
490,635.83
1.51
16,501.96
MWD+IFR2+SAG+MS (5)
19,438.95
89.86
308.78
5,980.65
5,906.98
14,482.66
-8,096.49
6,014,780.36
490,562.36
1.82
16,590.64
MWD+IFR2+SAG+MS (5)
19,533.34
88.82
309.83
5,981.73
5,908.06
14,542.45
-8,169.52
6,014,840.16
490,489.35
1.57
16,678.92
MWD+IFR2+SAG+MS (5)
19,627.46
87.96
307.63
5,984.38
5,910.71
14,601.30
-8,242.91
6,014,899.02
490,415.98
2.51
16766.58
MWD+IFR2+SAG+MS (5)
19,654.59
88.99
308.26
5,985.10
5,911.43
14,617.98
-8,264.30
6,014,915.70
490,394.60
4.45
16,791.72
MWD+IFR2+SAG+MS (5)
19,722.87
89.55
308.06
5,985.97
5,912.30
14,660.16
-8,317.98
6,014,957.89
490,340.93
0.87
16,855.09
MWD+IFR2+SAG+MS (5)
19,817.51
89.88
308.54
5,986.44
5,912.77
14,718.82
-8,392.25
6,015,016,55
490,266.67
0.62
16,943.01
MWD+IFR2+SAG+MS (5)
19,847.00
89.68
309.77
5,986.55
5,912.88
14,737.44
-8,415.12
6,015,035,18
490,243.81
4.23
16,970.57
MWD+IFR2+SAG+MS (5)
19,912.61
88.91
308.88
5,987.36
5,913.69
14,779.01
-8,465.87
6,015,076.75
490,193.08
1.79
17,031.95
MWD+IFR2+SAG+MS (5)
19,967.06
89.33
311.25
5,988.20
5,914.53
14,814.05
-8,507.53
6,015,111.80
490,151.42
4.42
17,083.12
MWD+IFR2+SAG+MS (5)
20,006.96
90.44
312.42
5,988.28
5,914.61
14,840.67
-8,537.26
6,015,138.41
490,121.70
4.04
17,121.03
MWD+IFR2+SAG+MS (5)
20,101.72
88.22
308.69
5,989.39
5,915.72
14,902.26
-8,609.23
6,015,200.01
490,049.75
4.58
17,210.35
MWD+IFR2+SAG+MS (5)
20,197.23
88.90
308.27
5,991.79
5,918.12
14,961.67
-8,683.98
6,015,259.43
489,975.02
0.84
17,299.17
MWD+IFR2+SAG+MS (5)
20,268.66
90.01
309.26
5,992.47
5,918.80
15,006.39
-8,739.67
6,015,304.16
489,919.35
2.08
17,365.74
MWD+IFR2+SAG+MS (5)
20,274.00
90.01
309.26
5,992.47
5,918:80
15,009.77
-8,743.80
6,015,307.54
489,915.21
0.00
17,370.73
PROJECTED to TO
20,296.00
90.01
309.26
5,992.46
5,918.79
15,023.69
-8,760.84
6,015,321.46
489,898.18
0.00
17,391.30
PROJECTED to TD
Annotation
6-3/4" x 4-1/2"
4/30/2020 2:10:49PM Page 10 COMPASS 5000.15 Build 91E
STATE OF ALASKA Reviewed By: Jr�
OIL AND GAS CONSERVATION COMMISSION P.I. Supry 1+ z3 tom;
BOPE Test Report for: KUPARUK RIV UNIT 3H-37 ✓ Comm
Contractor/Rig No.: Doyon 19 PTD#: 2191940 ' DATE: 4/l/2020 ' Inspector Austin McLeod ' Insp Source
Operator: ConocoPhillips Alaska, Inc. Operator Rep: Shirley/Pickworth Rig Rep: Williams/Sam Inspector
Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopSAM200401125255
Rams: Annular: Valves: MASP:
Type Test: BIWKLY 250/3500 - 250/2500 ' 250/3500 - 3260 - Related Insp No:
TEST DATA
MISC. INSPECTIONS:
MUD SYSTEM:
ACCUMULATOR SYSTEM:
Upper Kelly
- l
P/F
Lower Kelly
Visual
Alarm
Time/Pressure P/F
Location Gen.:
P -
Trip Tank
P
P
System Pressure - - 3050 _--
P -_
Housekeeping:
P
Pit Level Indicators
P
P
Pressure After Closure 1.350 _
P
PTD On Location
P
Flow Indicator
P
P
200 PSI Attained 21
P
Standing Order Posted
P
Meth Gas Detector
P "_
P
Full Pressure Attained 153- -
P "
Well Sign
P-'
H2S Gas Detector
P_
P
Blind Switch Covers: All stations "
P "
Drl. Rig
P_-
MS Misc
NA
NA_
Nitgn. Bottles (avg): 4�a�2050
P -
Hazard Sec.
P
FP /
Inside Reel Valves - 0
-NA
ACC Mise 0
NA
Misc
NA
Check Valve
0
NA
FLOOR SAFTY VALVES:
BOP STACK:
Quantity
P/F
Upper Kelly
- l
P "
Lower Kelly
1
P '
Ball Type
I
--P
Inside BOP
I
P
FSV Misc
0
NA
BOP STACK:
CHOKE MANIFOLD:
Quantity Size
P/F
Quantity
P/F
Stripper
0_ _ _
NA
No. Valves 14- -
P --
"Annular
Annular Preventer
1 ' 13-5/8"
P
Manual Chokes I
P
#1 Rams
1 " 3-1/2"x6" "
P
Hydraulic Chokes I __
_P _
#2 Rams
1 " Blinds
P
CH Misc 0
NA
#3 Rams
1 3-1/2"x6"-
P '
#4 Rams
0
NA
#5 Rams
0
NA
INSIDE REEL VALVES:
#6 Rams
0
NA
(Valid for Coil Rigs Only)
Choke Ln. Valves
1 3-1/8" -
P
Quantity
P/F
HCR Valves
'�
2 3-118
FP /
Inside Reel Valves - 0
-NA
Kill Line Valves
2 3-1/8"
P
Check Valve
0
NA
BOP Misc
0
NA
Number of Failures: 1 Test Results Test Time 6.5
Remarks: 3-1/2" & 4-1/2" joints. Annular on both. HCR kill needed grease. assed retest. Test due 3/30/20. An AOGCC extension was
granted until casing was cemented. -
Regg, James B (CED)
From:
Sent:
To:
Subject:
Attachments:
FYI
Sent from my iPhone
Begin forwarded message:
15 :f -Lk 314-37
NO zlci mo
Loepp, Victoria T (CED) �Cl '�IZi�Zz�ic
Monday, March 23, 2020 9:52 AM l
Regg, James B (CED)
Fwd: 31-1-37 - Notification of BOP use
31-1-37 BOPE Use Notification 22Mar2020.pdf; ATT00001.htm
From: "Titus, Marti N" <Marti.N.Titus@conocophillips.com>
Date: March 23, 2020 at 9:47:51 AM AKDT
To: "Loepp, Victoria T (CED)" <victoria.loepp@alaska.gov>
Subject: 311-11-37 - Notification of BOP use
Hi Victoria
Please find attached the notification of BOP use on 31-1-37. We had to shut the well in last night due to
an observed pit gain. We have since opened the rams and are circulating with our MPD system.
We have decided to set our casing at our current depth; therefore, we will not need to test the pipe
rams when we come out as they will be changed and tested prior to us running casing as per the drilling
program.
Please let me know if you have any questions.
Thanks,
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
1
ConocoPh i 1 I i ps
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
March 23, 2020
AOGCC Industry Guidance Bulletin No. 10-003
Reporting BOPE Use to Prevent the Flow of Fluids from a Well
Dear Commissioner:
As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Doyon 19 with a written
report.
Time of BOPE Use: 3/22/2020 at 14:00 hours
Well Location: 3H-37 -
API Number: 50-103-20822-00-00 -
PTD Number: 219-194
Rig Name: Doyon 19
Operator Contact: Marti Titus (office) 907-265-1192 (mobile) 713-494-8198 (email) marti.n.titus@conocophillips.com
Operations Summary: Drilled 9-7/8" x 11" intermediate hole to 14043' MD (5950' TVD). Observed mud and pressure loss.
Loss rate 180 bph. Pumped LCM pill at 14035' MD. Circulated bottoms up at 250 gpm. Max gas 2019 units at bottoms up.
Experienced m ulosses. Adjusted pump rate to stabilize gain/loss. Observed pit gain. Shut well in on pipe rams and lined up
on choke manifold and gas buster. SIDPP = 630 psi. SICP = 510 psi. Pumped at 40 spm, DPP = 710 psi, CP = 630 psi. Pumped at
20 spm, DPP = 630 psi, CP = 660 psi. Continued to circulate through choke manifold at 23 spm. Monitored returns for loss rate
(144-180 bph loss rate). Attempted to improve returns. Lined up pump #1 on MPD. Equalized pressure at 625 psi. Opened
rams. Established and maintained circulation at 740 psi. Pumped through string and MPD system. Picked up and attempted to
break string over at 277 klbs. No good. Rotated at 10 rpm. Broke free. Rotated at 10 rpm, 185 klbs rotating weight, torque 21-
26k ft -lbs. Continued circulating out gas through MPD choke s4tstPm through the gas buster at 130 gpm, 850 psi with 93 gpm
on pump #1 on MPD.
BOPE Used: Pipe rams
Reason for BOPE Use: The pipe rams were closed to contain a fluid imbalance in the wellbore.
Actions To Be Taken: The decision was made to set intermediate casing at our current depth. The pipe rams will be changed
out and tested as per the program before we run casing.
If you have any questions or require any further information, please contact me at 713-494-8198.
Sincerely,
Marti Titus
Staff Drilling Engineer
CPAI Drilling and Wells
PTD a /q -P94-
Loepp, Victoria T (CED)
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Tuesday, March 3, 2020 2:36 PM
To: Loepp, Victoria T (CED)
Subject: KRU 3H-37 (PTD 219-194) Anti -collision revision approvala
Follow Up Flag: Follow up
Flag Status: Flagged
Thank you, Victoria.
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Tuesday, March 03, 2020 2:26 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Subject: [EXTERNAL]KRU 3H-37 (PTD 219-194) Anti -collision revision approval
Marti,
The changes to the subject approved PTD are approved and include the following:
1. Revised anti -collision summary provided below
2. Revised directional survey provided below
3. Deletion of the requirement to set a deep plug in well 3H-24 offset injector.
This approval and the revised documents must be included with your approved copy of the PTD in your files and
available for the State Inspector on rig.
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loepp(d.)alaska.gov
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 Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.gov
From: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Sent: Tuesday, March 3, 2020 9:47 AM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 219-194) Anti -collision with 3H-24
Thank you Marti. Directional data in digital format definitely saves time for us.
I appreciate your help with this.
Cheers,
Steve Davies
AOGCC
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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov.
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Tuesday, March 3, 2020 9:44 AM
To: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 219-194) Anti -collision with 3H-24
Hi Steve
Here is the file. Let me know if you need anything else.
Thanks
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Sent: Tuesday, March 03, 2020 9:16 AM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 219-194) Anti -collision with 3H-24
Marti,
Could CPAI also provide the revised directional data for KRU 3H-37 in the form of an Excel spreadsheet or an ASCII
table? That will allow me to update AOGCC's geoscience workstations without a lot of page scanning and optical
character recognition processing.
Thank you for your help,
Steve Davies
Senior Petroleum Geologist
Alaska Oil and Gas Conservation Commission (AOGCC)
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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov.
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Tuesday, March 3, 2020 8:54 AM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 219-194) Anti -collision with 31-1-24
Hi Victoria,
Here are the updated files for the new directional plan. I believe they are all in NAD 83.
Thanks
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Tuesday, March 03, 2020 8:13 AM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>
Subject: [EXTERNAL]KRU 3H-37 (PTD 219-194) Anti -collision with 31-1-24
Has the directional survey changed? If so, please submit as well as any other information that has changed in the
approved PTD.
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Monday, March 2, 2020 4:38 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 219-194) Anti -collision with 3H-24
Hi Victoria
We were able to work with our subsurface team and move the well so that it no longer fails our anti -collision rule for
minimum separation factor. All SF's are now above 1.5. Please see the attached anti -collision summary. This should
eliminate the need to set a deep plug on 3H-24.
Thanks
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Monday, March 02, 2020 3:04 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>
Subject: [EXTERNAL]KRU 3H-37 (PTD 219-194) Anti -collision with 3H-24
Marti,
In KRU 3H-24, the potential collision point is over 700' TVD above the reservoir that is assumed to be at 12.5 ppg(5928'
TVD). The collision point in KRU 3H-37 is in the intermediate section at 5217' TVD that is being drilled with 10 ppg mud.
The LOT required at the surface shoe in the event of a collision is much greater than the 14.3 ppg specified in the
PTD(closer to >15 ppg). When there is an anti -collision major risk failure or close to one, setting a deep plug is a
reasonable mitigation measure. In your February 12, 2020 email your comment that "we completed our risk
assessment yesterday and agreed that we do not need to set a deep plug in 31-1-24" is insufficient. The AOGCC may at
any time require a deep set plug as a risk mitigation measure and will not be performing the analysis to justify this
requirement. The deep set plug is required in KRU 3H-24.
G reg,
At one time we received risk analysis and a more detail traveling cylinder report from CPAI. In addition, our traveling
cylinder report identified major risk failures. We reviewed anti -collision with Ty Senden a couple of years ago as CPAI
was changing the calculation of the separation factor as well as other criteria and the AOGCC is now receiving less
definitive information. We have not asked for mitigation measures since the review with Ty Senden and question
whether the information we are receiving will even indicate a major risk failure. It is likely the time to have another
review of what CPAI is actually providing and what constitutes a major risk failure. We would like to know what changes
were made in the calculation of the separation factor and in your internal risk analysis.
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. LoeppC�alaska.4ov
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 Victoria Loepp at (907)793-1247 or Victoria.Loepp@aloska.gov
Sent from my iPhone
On Mar 2, 2020, at 9:42 AM, Titus, Marti N <Marti.N.Titus@conocophillips.com> wrote:
Hi Victoria
I was just reading through the 3H-37 approved permit and noticed that it says that a deep set plug in 3H-
24 is required. Can you please let me know why? I thought you were satisfied with all of the
information that I sent regarding the anti -collision risk. I wasn't aware that you still wanted us to set a
deep plug in 31-1-24.
Thanks
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
Loepp, Victoria T (CED)
From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Sent: Tuesday, March 3, 2020 5:00 PM
To: Titus, Marti N; Loepp, Victoria T (CED)
Cc: Livingston, Erica J
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 219-194) Anti -collision with 3H-24
Follow Up Flag: Follow up
Flag Status: Flagged
Thanks Marti -
Victoria,
I will schedule the review requested below. ConocoPhillips has gone to a Global Methodology for anti -collision that has
removed most of the custom features from Compass that were in more detailed past AC plots for Alaska that you
mention below.
More conservative tool codes and separation factors were also added with a new global risk matrix. Where a separation
factor of 1.0 used to create a major risk, a separation factor of 1.5 now does.
I will come over and walk you through it. Philip Hayden is now in Malaysia and I was not aware that there was a loose
end here.
Greg
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Monday, March 2, 2020 4:38 PM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 219-194) Anti -collision with 3H-24
Hi Victoria
We were able to work with our subsurface team and move the well so that it no longer fails our anti -collision rule for
minimum separation factor. All SF's are now above 1.5. Please see the attached anti -collision summary. This should
eliminate the need to set a deep plug on 3H-24.
Thanks
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
ConocoPs
philli
ConocoPhillips Alaska
Inc _Kuparuk
Kuparuk River Unit _2
Kuparuk 3H Pad
Plan: 31-1-37
3H-37
3H-37_wp07
Anticollision Report
02 March, 2020
BakerHughes 5�1
I&- ConocoPhillips
ConocoPhillips Anticollision Report BakerHughes S
Company:
ConocoPhillips Alaska Inc-Kuparuk
Project:
Kuparuk River Unit -2
Reference Site:
Kuparuk 3H Pad
Site Error:
0.00 usft
Reference Well:
Plan: 3H-37
Well Error:
0.00 usft
Reference Wellbore
3H-37
Reference Design:
3H-37_wp07
Reference 3H-37_wp07
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Filter type:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method:
MD Interval 25.00usft Error Model:
Depth Range:
Unlimited Scan Method:
Results Limited by:
Maximum ellipse separation of 1,000.00 usft Error Surface:
Warning Levels Evaluated at: 2.79 Sigma
Casing Method
Well Plan: 3H-37
Plan: 36.79+35.8 @ 72.59usft (D019)
Plan: 36.79+35.8 @ 72.59usft (D019)
True
Minimum Curvature
2.00 sigma
EDT 15 Alaska Prod
Offset Datum
ISCWSA
Tray. Cylinder North
Combined Pedal Curve
Added to Error Values
Survey Tool Program Date 3/2/2020
From To
(usft) (usft) Survey (Wellbore) Tool Name Description
36.79
1,200.00 3H-37_wp07 (31-1-37)
GYD-GC-SS
Gyrodata gyro single shots
1,200.00
1,350.00 3H-37_wp07 (31-1-37)
MWD OWSG
OWSG MWD - Standard
1,200.00
3,601.00 3H-37_wp07 (31-1-37)
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag + Multi -Station Correction
3,601.00
5,101.00 3H-37_wp07 (31-1-37)
MWD OWSG
OWSG MWD - Standard
3,601.00
13,963.00 3H-37_wp07 (31-1-37)
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag + Multi -Station Correction
13,963.00
15,463.00 3H-37_wp07 (31-1-37)
MWD OWSG
OWSG MWD - Standard
13,963.00
20,321.07 3H-37_wp07 (31-1-37)
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag + Multi -Station Correction
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
Kuparuk 3H Pad
3H-01 - 3H-01 - 3H-01
72.59
76.00
186.99
185.72
147.263 CC, ES
3H-01 - 3H-01 - 3H-01
755.28
775.00
253.29
247.10
40.881 SF
3H-01 - 3H -01A- 3H -01A
72.59
76.00
186.99
186.18
231.935 CC, ES
3H-01 - 31-1-01 A - 3H -01A
800.00
825.00
268.71
262.61
44.030 SF
3H-01 - 3H-01AL1 - 3H-01AL1
72.59
76.00
186.99
186.18
231.935 CC, ES
3H -01-3H-01 AL1 -3H-01 AL1
800.00
825.00
268.71
262.61
44.030 SF
3H-01 - 3H-01AL1PB1 - 3H-01AL1PB1
72.59
76.00
186.99
186.18
231.935 CC, ES
3H-01-3H-01AL1PB1-3H-01AL1PB1
800.00
825.00
268.71
262.61
44.030 SF
3H-02 - 3H-02 - 3H-02
423.33
425.00
158.87
155.19
43.166 CC
3H-02 - 3H-02 - 3H-02
448.67
450.00
158.99
155.15
41.342 ES
3H-02 - 3H-02 - 3H-02
713.11
725.00
186.32
180.57
32.379 SF
3H-03 - 3H-03 - 3H-03
473.39
475.00
135.82
132.74
44.031 CC
3H-03 - 3H-03 - 3H-03
498.58
500.00
135.84
132.65
42.612 ES
3H-03 - 3H-03 - 3H-03
668.27
675.00
147.11
143.17
37.376 SF
3H-04 - 3H-04 - 3H-04
622.82
625.00
105.93
100.87
20.946 CC
3H-04 - 3H-04 - 3H-04
646.44
650.00
105.98
100.74
20.230 ES
3H-04 - 3H-04 - 3H-04
763.37
775.00
114.88
108.73
18.686 SF
3H-05 - 3H-05 - 3H-05
622.33
625.00
83.44
78.44
16.682 CC
3H-05 - 3H-05 - 3H-05
646.23
650.00
83.57
78.39
16.123 ES
3H-05 - 3H-05 - 3H-05
765.29
775.00
90.53
84.44
14.851 SF
3H-06 - 3H-06 - 3H-06
621.90
625.00
59.39
54.34
11.747 CC, ES
3H-06 - 3H-06 - 3H-06
742.47
750.00
64.48
58.52
10.806 SF
3H-07 - 3H-07 - 3H-07
621.51
625.00
31.26
26.20
6.183 CC, ES
3H-07 - 3H-07 - 3H-07
670.51
675.00
32.49
27.08
5.997 SF
3H-08 - 3H-08 - 3H-08
496.64
500.00
8.13
5.17
2.745 Normal Operations, CC, ES
3H-08 - 3H-08 - 3H-08
546.52
550.00
8.43
5.27
2.671 Normal Operations, SF
3H-09 - 3H-09 - 3H-09
271.59
275.00
12.52
9.88
4.739 CC
3H-09 - 3H-09 - 3H-09
396.50
400.00
12.91
9.39
3.673 ES
3H-09 - 3H-09 - 3H-09
471.39
475.00
13.92
9.91
3.471 SF
31-1-10 - 3H-10 - 3H-10
371.36
375.00
36.83
33.95
12.801 CC
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
3/2/2020 5:24:09PM Page 2 COMPASS 5000.15 Build 91E
Summary
ConocoPhillips
.-'
ConocoPhillips
Anticollision Report
BakerHughes S
Company: ConocoPhillips Alaska Inc-Kuparuk
Local Co-ordinate Reference:
Well Plan: 3H-37
Project: Kuparuk River Unit -2
TVD Reference:
Plan: 36.79+35.8 @ 72.59usft (D019)
Reference Site: Kuparuk 3H Pad
MD Reference:
Plan: 36.79+35.8 @ 72.59usft (D019)
Site Error: 0.00 usft
North Reference:
True
Reference Well: Plan: 31-1-37
Survey Calculation Method:
Minimum Curvature
Well Error: 0.00 usft
Output errors are at
2.00 sigma
Reference Wellbore 31-1-37
Database:
EDT 15 Alaska Prod
Reference Design: 31-1-37_wp07
Offset TVD Reference:
Offset Datum
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
Kuparuk 3H Pad
31-1-10 - 31-1-10 - 31-1-10
421.19
425.00
36.93
33.77
11.710 ES
31-1-10 - 31-1-10 - 31-1-10
896.64
900.00
48.27
42.25
8.023 SF
31-1-10 - 31-1-10B - 31-1-106
380.73
375.00
36.83
33.90
12.570 CC
31-1-10 - 31-1-10B - 31-1-106
430.55
425.00
36.98
33.78
11.543 ES
31-1-10 - 3H-1013 - 3H -10B
881.23
875.00
47.47
41.55
8.021 SF
31-1-10 - 31-1-10C - 31-1-10C
380.73
375.00
36.83
33.90
12.571 CC
31-1-10 - 31-1-10C - 31-1-10C
430.55
425.00
36.98
33.78
11.543 ES
31-1-10 - 31-1-10C - 31-1-10C
881.23
875.00
47.47
41.55
8.021 SF
3H-10 - 31-1-10CL1 - 31-1-10CL1
380.73
375.00
36.83
33.90
12.571 CC
31-1-10 - 31-1-10CL1 - 31-1-10CL1
430.55
425.00
36.98
33.78
11.543 ES
3H-10 - 31-1-10CL1 - 3H-10CL1
881.23
875.00
47.47
41.55
8.021 SF
31-1-10 - 3H-10CL2 - 3H-10CL2
380.73
375.00
36.83
33.90
12.571 CC
31-1-10 - 3H-10CL2 - 3H-10CL2
430.55
425.00
36.98
33.78
11.543 ES
31-1-10 - 3H-10CL2 - 3H-10CL2
881.23
875.00
47.47
41.55
8.021 SF
31-1-10 - 31-1-10CL2-01 - 3H-10CL2-01
380.73
375.00
36.83
33.90
12.571 CC
31-1-10 - 31-1-10CL2-01 - 3H-10CL2-01
430.55
425.00
36.98
33.78
11.543 ES
31-1-10 - 3H-10CL2-01 - 31-1-10CL2-01
881.23
875.00
47.47
41.55
8.021 SF
31-1-10 - 3H-10CL2-02 - 31-1-10CL2-02
380.73
375.00
36.83
33.90
12.571 CC
31-1-10 - 31-1-10CL2-02 - 3H-10CL2-02
430.55
425.00
36.98
33.78
11.543 ES
3H-10 - 31-1-10CL2-02 - 31-1-10CL2-02
881.23
875.00
47.47
41.55
8.021 SF
311-10 - 31-1-10CPB1 - 3H-10CP131
380.73
375.00
36.83
33.90
12.571 CC
31-1-10 - 31-1-10CPB1 - 31-1-10CPB1
430.55
425.00
36.98
33.78
11.543 ES
31-1-10 - 31-1-10CPB1 - 31-1-10CPB1
881.23
875.00
47.47
41.55
8.021 SF
31-1-11 - 31-1-11 - 31-1-11
346.05
350.00
127.20
122.48
26.939 CC
3H-11 - 31-1-11 - 31-1-11
469.31
475.00
127.80
121.50
20.273 ES
3H-11 - 31-1-11 - 31-1-11
813.58
825.00
157.34
146.53
14.551 SF
3H-11 - 3H -11A- 3H -11A
352.38
350.00
127.20
122.39
26.481 CC
31-1-11 - 3H -11A- 311-11A
475.59
475.00
127.89
121.51
20.031 ES
31-1-11 - 3H -11A- 31-1-11A
819.66
825.00
158.55
147.65
14.552 SF
31-1-11-3H-11AL1-3H-11AL1
352.38
350.00
127.20
122.39
26.481 CC
3H-11 - 3H-11AL1 - 3H-11AL1
475.59
475.00
127.89
121.51
20.031 ES
31-1-11 - 3H-11AL1 - 3H-11AL1
819.66
825.00
158.55
147.65
14.552 SF
31-1-11 - 3H-11AL1-01 - 3H-11AL1-01
352.38
350.00
127.20
122.39
26.481 CC
31-1-11 - 3H-11AL1-01 - 3H-11AL1-01
475.59
475.00
127.89
121.51
20.031 ES
31-1-11 - 3H-11AL1-01 - 3H-11AL1-01
819.66
825.00
158.55
147.65
14.552 SF
31-1-12 - 31-1-12 - 3H-12
1,234.87
1,225.00
125.77
110.08
8.016 CC, ES
31-1-12 - 31-1-12 - 31-1-12
1,330.18
1,325.00
129.75
112.89
7.692 SF
311-12 - 3H -12A- 31-1-12A
1,234.87
1,225.00
125.77
110.08
8.016 CC, ES
3H -12 -3H -12A -3H -12A
1,330.18
1,325.00
129.75
112.89
7.692 SF
31-1-12 - 31-1-12AL1 - 3H-12AL1
1,234.87
1,225.00
125.77
110.08
8.016 CC, ES
31-1-12 - 3H-12AL1 - 3H-12AL1
1,330.18
1,325.00
129.75
112.89
7.692 SF
31-1-12 - 3H-12AL2 - 3H-12AL2
1,234.87
1,225.00
125.77
110.08
8.016 CC, ES
31-1-12 - 3H-12AL2 - 3H-12AL2
1,330.18
1,325.00
129.75
112.89
7.692 SF
31-1-12 - 3H-12AL3 - 3H-12AL3
1,234.87
1,225.00
125.77
110.08
8.016 CC, ES
31-1-12 - 3H-12AL3 - 3H-12AL3
1,330.18
1,325.00
129.75
112.89
7.692 SF
31-1-12 - 31-1-12APB1 - 3H-12APB1
1,234.87
1,225.00
125.77
110.08
8.016 CC, ES
31-1-12 - 31-1-12APB1 - 31-1-12APB1
1,330.18
1,325.00
129.75
112.89
7.692 SF
31-1-13 - 31-1-13 - 31-1-13
1,340.98
1,325.00
135.56
118.25
7.833 CC
31-1-13 - 31-1-13 - 31-1-13
1,364.80
1,350.00
135.60
118.01
7.707 ES
31-1-13 - 31-1-13 - 31-1-13
1,459.21
1,450.00
140.67
121.96
7.520 SF
31-1-13 - 3H -13A- 3H -13A
1,345.75
1,325.00
135.53
118.16
7.805 CC
3H -13 -3H -13A -3H -13A
1,369.55
1,350.00
135.67
118.01
7.686 ES
31-1-13 - 3H -13A- 3H -13A
1,440.44
1,425.00
139.02
120.53
7.518 SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
3/2/2020 5:24:09PM Page 3 COMPASS 5000.15 Build 91E
BakerHughesCC�t
Well Plan: 31-1-37
Plan: 36.79+35.8 @ 72.59usft (DO 19)
Plan: 36.79+35.8 @ 72.59usft (D019)
True
Minimum Curvature
2.00 sigma
EDT 15 Alaska Prod
Offset Datum
Summary
ConocoPhillips
ConocoPhillips
Anticollision Report
Company:
ConocoPhillips Alaska Inc_Kuparuk
Local Co-ordinate Reference:
Project:
Kuparuk River Unit -2
TVD Reference:
Reference Site:
Kuparuk 3H Pad
MD Reference:
Site Error:
0.00 usft
North Reference:
Reference Well:
Plan: 31-1-37
Survey Calculation Method:
Well Error:
0.00 usft
Output errors are at
Reference Wellbore
3H-37
Database:
Reference Design:
3H-37_wp07
Offset TVD Reference:
BakerHughesCC�t
Well Plan: 31-1-37
Plan: 36.79+35.8 @ 72.59usft (DO 19)
Plan: 36.79+35.8 @ 72.59usft (D019)
True
Minimum Curvature
2.00 sigma
EDT 15 Alaska Prod
Offset Datum
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
Kuparuk 3H Pad
31-1-13 - 3H-13AL1 - 3H-13AL1
1,345.75
1,325.00
135.53
118.63
8.019 CC
3H-13 - 31-1-13AL1 - 3H-13AL1
1,369.55
1,350.00
135.67
118.48
7.893 ES
31-1-13 - 31-1-13AL1 - 3H-13AL1
1,440.44
1,425.00
139.02
120.99
7.712 SF
31-1-13-31-1-13AL1-01P131-31-1-13A1-1-01P131
1,345.75
1,325.00
135.53
118.63
8.019 CC
31-1-13-31-1-13ALl-01PB1-31-1-13A1-1-01P131
1,369.55
1,350.00
135.67
118.48
7.893 ES
3H-13-3H-13ALl-01PBI -3H-13ALl-01PB1
1,440.44
1,425.00
139.02
120.99
7.712 SF
31-1-13 - 3H-13ALl-02 - 31-1-13ALl-02
1,345.75
1,325.00
135.53
118.63
8.019 CC
31-1-13 - 3H-13AL1-02 - 31-1-13AL1-02
1,369.55
1,350.00
135.67
118.48
7.893 ES
31-1-13 - 3H-13AL1-02 - 31-1-13ALl-02
1,440.44
1,425.00
139.02
120.99
7.712 SF
311-13 - 31-1-13AL1-03 - 31-1-13ALl-03
1,345.75
1,325.00
135.53
118.63
8.019 CC
31-1-13 - 3H-13AL1-03 - 3H-13ALl-03
1,369.55
1,350.00
135.67
118.48
7.893 ES
31-1-13 - 31-1-13AL1-03 - 31-1-13A1-1-03
1,440.44
1,425.00
139.02
120.99
7.712 SF
3H-13-31-1-13AL1P131-3H-13AL1PB1
1,345.75
1,325.00
135.53
118.63
8.019 CC
3H-13-3H-13AL1P131-3H-13AL1PBI
1,369.55
1,350.00
135.67
118.48
7.893 ES
3H-13-3H-13AL1PBI -3H-13AL1PB1
1,440.44
1,425.00
139.02
120.99
7.712 SF
3H-13 - 31-1-13AL1 PB2 - 3H-13AL1 P132
1,345.75
1,325.00
135.53
118.63
8.019 CC
3H-13-3H-13AL1PB2-31-1-13AL1PB2
1,369.55
1,350.00
135.67
118.48
7.893 ES
311-13-31-1-13AL1PB2-31-1-13AL1P62
1,440.44
1,425.00
139.02
120.99
7.712 SF
31-1-13-31-1-13AL1P133-31-1-13AL1P133
1,345.75
1,325.00
135.53
118.63
8.019 CC
31-1-13-31-1-13AL1PB3-31-1-13AL1PB3
1,369.55
1,350.00
135.67
118.48
7.893 ES
31-1-13 - 31-1-13AL1P83 - 31-1-13AL1P133
1,440.44
1,425.00
139.02
120.99
7.712 SF
3H-14 - 31-1-14 - 31-1-14
1,244.39
1,225.00
166.67
150.44
10.270 CC
31-1-14 - 31-1-14 - 31-1-14
1,268.31
1,250.00
166.76
150.21
10.074 ES
31-1-14 - 31-1-14 - 3H-14
1,339.20
1,325.00
171.96
154.49
9.842 SF
3H -14 -3H -14A -3H -14A
1,244.39
1,225.00
166.67
150.44
10.270 CC
3H-14- 3H -14A- 31-1-14A
1,268.31
1,250.00
166.76
150.21
10.074 ES
311-14 - 3H -14A- 31-1-14A
1,339.20
1,325.00
171.96
154.49
9.842 SF
3H-14 - 31-1-14AP131 - 3H-14APB1
1,244.39
1,225.00
166.67
150.44
10.270 CC
31-1-14 - 3H-14APB1 - 3H-14APB1
1,268.31
1,250.00
166.76
150.21
10.074 ES
31-1-14 - 3H-14APB1 - 3H-14APB1
1,339.20
1,325.00
171.96
154.49
9.842 SF
31-1-14 - 3H-1413- 31-1-14B
1,264.88
1,250.00
166.70
150.46
10.267 CC, ES
3H-14 - 3H-1413- 31-1-14B
1,335.83
1,325.00
171.54
154.38
9.996 SF
31-1-14 - 3H-1461-1 - 3H-14BL1
1,264.88
1,250.00
166.70
150.46
10.267 CC, ES
31-1-14 - 3H-14BL1 - 3H-14131-1
1,335.83
1,325.00
171.54
154.38
9.996 SF
31-1-14 - 3H-14BL2 - 31-1-1461-2
1,264.88
1,250.00
166.70
150.46
10.267 CC, ES
31-1-14 - 3H-1461-2 - 3H-14BL2
1,335.83
1,325.00
171.54
154.38
9.996 SF
3H-14 - 3H-14BL3 - 3H-14BL3
1,264.88
1,250.00
166.70
150.46
10.267 CC, ES
31-1-14 - 3H-14BL3 - 31-1-1461-3
1,335.83
1,325.00
171.54
154.38
9.996 SF
31-1-14 - 3H-14BL4 - 3H-14BL4
1,264.88
1,250.00
166.70
150.46
10.267 CC, ES
31-1-14 - 31-1-14131-4 - 3H-1461-4
1,335.83
1,325.00
171.54
154.38
9.996 SF
31-1-15 - 31-1-15 - 3H-15
1,587.87
1,550.00
175.92
156.20
8.920 CC
31-1-15 - 31-1-15 - 31-1-15
1,613.31
1,575.00
176.02
155.99
8.787 ES
31-1-15 - 31-1-15 - 31-1-15
3,093.46
3,025.00
296.49
254.50
7.061 SF
31-1-16 - 31-1-16 - 31-1-16
1,186.65
1,150.00
229.38
214.11
15.025 CC
31-1-16 - 31-1-16 - 31-1-16
1,211.00
1,175.00
229.67
214.07
14.726 ES
31-1-16 - 31-1-16 - 31-1-16
1,378.74
1,350.00
246.10
228.30
13.826 SF
3H -16 -3H -16A -3H -16A
1,193.75
1,150.00
229.41
214.49
15.374 CC,ES
3H -16 -3H -16A -3H -16A
1,385.60
1,350.00
247.34
229.90
14.177 SF
3H-16 - 3H-16APB1 - 3H-16APB1
1,193.75
1,150.00
229.41
214.05
14.931 CC, ES
3H-16 - 3H-16APB1 - 3H-16APB1
1,385.60
1,350.00
247.34
229.45
13.826 SF
31-1-17 - 31-1-17 - 31-1-17
246.59
250.00
277.55
274.24
83.776 CC
31-1-17 - 31-1-17 - 31-1-17
418.54
425.00
278.51
272.97
50.243 ES
31-1-17 - 31-1-17 - 31-1-17
1,288.88
1,250.00
341.67
325.49
21.115 SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
3/2/2020 5.24:09PM Page 4 COMPASS 5000.15 Build 91E
BakerHughes S
Well Plan: 31-1-37
Plan: 36.79+35.8 @ 72.59usft (DO 19)
Plan: 36.79+35.8 @ 72.59usft (D019)
True
Minimum Curvature
2.00 sigma
EDT 15 Alaska Prod
Offset Datum
Summary
ConocoPhillips
ConocoPhillips
Anticollision Report
Company:
ConocoPhillips Alaska Inc_Kuparuk
Local Co-ordinate Reference:
Project:
Kuparuk River Unit -2
TVD Reference:
Reference Site:
Kuparuk 3H Pad
MD Reference:
Site Error:
0.00 usft
North Reference:
Reference Well:
Plan: 31-1-37
Survey Calculation Method:
Well Error:
0.00 usft
Output errors are at
Reference Wellbore
31-1-37
Database:
Reference Design:
3H-37_wp07
Offset TVD Reference:
BakerHughes S
Well Plan: 31-1-37
Plan: 36.79+35.8 @ 72.59usft (DO 19)
Plan: 36.79+35.8 @ 72.59usft (D019)
True
Minimum Curvature
2.00 sigma
EDT 15 Alaska Prod
Offset Datum
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
Kuparuk 3H Pad
31-1-23 - 31-1-23 - 3H-23
1,833.92
1,725.00
336.90
315.18
15.510 CC
31-1-23 - 31-1-23 - 31-1-23
4,131.00
3,800.00
356.71
292.58
5.562 ES
31-1-23 - 31-1-23 - 31-1-23
4,564.03
4,275.00
431.08
337.40
4.602 SF
3H -23 -3H -23A -3H -23A
1,843.80
1,725.00
336.88
315.03
15.413 CC
3H-23 - 3H -23A- 31-1-23A
4,116.50
3,775.00
355.74
292.59
5.633 ES
31-1-23 - 3H -23A- 31-1-23A
4,572.85
4,275.00
433.55
339.44
4.607 SF
31-1-23 - 3H-23AL1 - 3H-23AL1
1,843.80
1,725.00
336.88
315.03
15.413 CC
31-1-23 - 3H-23AL1 - 3H-23AL1
4,116.50
3,775.00
355.74
292.59
5.633 ES
31-1-23 - 3H-23AL1 - 3H-23AL1
4,572.85
4,275.00
433.55
339.48
4.609 SF
31-1-24 - 31-1-24 - 31-1-24
72.59
79.00
365.22
363.84
265.822 CC
31-1-24 - 31-1-24 - 31-1-24
9,632.16
9,125.00
681.34
236.95
1.533 Caution Monitor Closely, ES
3H-24 - 31-1-24 - 31-1-24
10,050.38
9,550.00
716.79
243.99
1.516 Caution Monitor Closely, SF
31-1-25 - 3H-25 - 31-1-25
267.59
275.00
138.97
135.31
37.936 CC
31-1-25 - 3H-25 - 31-1-25
317.36
325.00
139.14
134.85
32.412 ES
31-1-25 - 31-1-25 - 31-1-25
1,787.14
1,750.00
226.90
204.30
10.038 SF
31-1-25 - 3H -25A- 31-1-25A
287.09
275.00
138.96
135.05
35.523 CC
31-1-25 - 31-1-25A - 3H -25A
311.93
300.00
139.08
134.86
32.918 ES
3H -25 -3H -25A -3H -25A
1,781.64
1,725.00
226.12
203.59
10.038 SF
31-1-25 - 3H-25APB1 - 3H-25APB1
287.09
275.00
138.96
135.05
35.523 CC
3H-25 - 3H-25APB1 - 3H-25APB1
311.93
300.00
139.08
134.86
32.918 ES
31-1-25 - 3H-25APB1 - 3H-25APB1
1,781.64
1,725.00
226.12
203.59
10.038 SF
31-1-25 - 3H-25APB2 - 3H-25AP62
287.09
275.00
138.96
135.05
35.523 CC
31-1-25 - 3H-25APB2 - 3H-25APB2
311.93
300.00
139.08
134.86
32.918 ES
31-1-25 - 3H-25APB2 - 3H-25APB2
1,781.64
1,725.00
226.12
203.59
10.038 SF
31-1-26 - 31-1-26 - 31-1-26
492.68
500.00
23.22
19.80
6.780 CC
31-1-26 - 31-1-26 - 31-1-26
517.61
525.00
23.24
19.67
6.515 ES
3H-26 - 31-1-26 - 31-1-26
641.58
650.00
25.65
21.36
5.977 SF
31-1-26 - 3H-261-1 - 31-1-261-1
492.68
500.00
23.22
19.80
6.779 CC
31-1-26 - 31-1-261-1 - 31-1-261-1
517.61
525.00
23.24
19.67
6.514 ES
31-1-26 - 31-1-261-1 - 31-1-261-1
641.58
650.00
25.65
21.36
5.976 SF
31-1-26 - 3H-261-1-01 - 31-1-261-1-01
492.68
500.00
23.22
19.80
6.779 CC
31-1-26 - 31-1-261-1-01 - 31-1-261-1-01
517.61
525.00
23.24
19.67
6.514 ES
31-1-26 - 31-1-261-1-01 - 31-1-261-1-01
641.58
650.00
25.65
21.36
5.976 SF
31-1-26 - 31-1-261-1-02 - 31,1-261-1-02
492.68
500.00
23.22
19.80
6.779 CC
3H-26 - 31-1-261-1-02 - 31-1-261-1-02
517.61
525.00
23.24
19.67
6.514 ES
3H -26 -3H -261-1-02-3H-261-1-02
641.58
650.00
25.65
21.36
5.976 SF
31-1-28 - 31-1-28 - 31-1-28
72.59
79.00
240.25
238.88
174.867 CC
31-1-28 - 3H-28 - 3H-28
93.59
100.00
240.27
238.80
164.042 ES
31-1-28 - 31-1-28 - 3H-28
4,876.99
5,250.00
2,218.50
2,024.57
11.440 SF
31-1-28 - 31-1-28A - 31-1-28A
72.59
79.00
240.25
238.88
174.867 CC
31-1-28 - 31-1-28A - 3H -28A
93.59
100.00
240.27
238.80
164.042 ES
31-1-28 - 3H -28A- 3H -28A
4,876.99
5,250.00
2,218.50
2,024.57
11.440 SF
31-1-28 - 3H-28APB1 - 3H-28APB1
72.59
79.00
240.25
238.88
174.867 CC
31-1-28 - 3H-28APB1 - 3H-28APB1
93.59
100.00
240.27
238.80
164.042 ES
31-1-28 - 3H-28APB1 - 3H-28AP61
4,876.99
5,250.00
2,218.50
2,024.57
11.440 SF
31-1-32 - 31-1-32 - 31-1-32
1,856.82
1,800.00
133.50
118.87
9.124 CC, ES, SF
31-1-32 - 3H-32PB1 - 3H-32PB1
1,856.82
1,800.00
133.50
118.87
9.124 CC, ES, SF
3H -32 -Prelim: 31-1-32A-3H-32Awp01
1,856.82
1,800.00
133.50
118.65
8.991 CC, ES, SF
Plan: 31-1-35 - 31-1-35 - 31-1-35
718.24
725.00
193.36
189.05
44.783 CC, ES
Plan: 31-1-35 - 31-1-35 - 31-1-35
12,222.83
12,775.00
1,052.67
745.31
3.425 SF
Plan: 3H -3613C - 3H-36 - 3H-36wp05
621.34
625.00
90.10
86.34
23.937 CC, ES
Plan: 3H -36 -BC - 31-1-36 - 3H-36wp05
5,094.60
5,425.00
1,097.93
990.50
10.220 SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
3/212020 5:24.09PM Page 5 COMPASS 5000.15 Build 91E
10�. ConocoPhillips
ConocoPhillips Anticollision Report BakerHughes cq-�
Company:
ConocoPhillips Alaska Inc—Kuparuk
Local Co-ordinate Reference:
Well Plan: 31-1-37
Project:
Kuparuk River Unit -2
ND Reference:
Plan: 36.79+35.8 @ 72.59usft (DO 19)
Reference Site:
Kuparuk 3H Pad
MD Reference:
Plan: 36.79+35.8 @ 72.59usft (D019)
Site Error:
0.00 usft
North Reference:
True
Reference Well:
Plan: 3H-37
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00 usft
Output errors are at
2.00 sigma
Reference Wellbore
31-1-37
Database:
EDT 15 Alaska Prod
Reference Design:
3H-37_wp07
Offset TVD Reference:
Offset Datum
Reference Depths are relative to Plan: 36.79+35.8 @ 72.59usft (D019) Coordinates are relative to: Plan: 31-1-37
Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1983, Alaska Zone 4
Central Meridian is 150° 0'0.000 W Grid Convergence at Surface is: -0.01 °
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
3/2/2020 5:24:09PM Page 6 COMPASS 5000.15 Build 91E
Ladder
Plot
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0 3500 7000 10500 14000 17500 21000
Measured Depth
LEGEND
S,L,, 3H21, SIO1 V1 JH -t i, 3112. 91-,I V,V,
3HOtA VO JH-13.3H-,IA,3H-,IA VB -,9 3H-,BF.3H-,G V.
V0
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]HLi, 311, 3112 V 1 }I-13. JH-tIAIJ. 3141U 13 V0� 3H23, JH2J, 9123 v,
JHdl.--. 12]V3 31-13.91-iJAP8,, 3H-t0APB1 Vo 91Y3, 111,30]H✓11, 91U1, 312. VI $ —3.-3..1-2—. —1, 311-YWL1 VO
3105, 9,25, 3H05 V1 a— JH -,3,91-,>A, 91-1]A V1 312.,3H24.912.VI
3106, 3106, 3108 V, 7N-13, 31-13AL,, SN— V0 Si25 V 1
01102, —7, 3H0i V1 31-13,91-13AL101PB,, 31-,AL—B, VO 3125. JH25N,JHXA V.
3108, 9108, ]HOB Vt 9,-13, JH-13AL103.3H-13AL181 V0 3125, 91—P8,.9105APB, V0
91-08, 9108, 91� Vt 91-,3, 3H-,3AL1-0J, --l. V0 3H25, SH25APBI, 9,25.APBi V1
31-10,91-,0,31-OOV2 9113, 3H-i]AL1PB1, 91-1 ]AHPBl VO 3128, 91.28, 9,28 V1
-10,]H-108, JH -10B V0 —3. —1-1-2. VO + 9128, 3H2BL1, 9, 28 L, V0
JH-10,JH-10C.—VO � � 9,-13, 3H-,3RL,PH3. —U—VO A 3126. 3128L1a1. 3126L,O1W
9410, 91-,OLLI.9N I VO + 9,-1..3H-11. 31-,1VJ �� 3H28, 3H28L102, 9128,@ W
OH -10, 3H-tOCLi, 9410L12 V. + >•-1.,.1-. 3H -1M Vi m ]H2B, 9138, 9128V0
t 91-10, OH-10GLI01. 3H-10CLI01 V0 -14,31-1MPBt. 91 -,.APB, VI —B. 912M,3H28A V0
3H -,0,91 -10G13 -0I. 91-10CLIOI V0 31-1., JH -1.8,—V3 i� ]H2B, 912BAPB,,—.P. VO
31-,0,31-M-1, 3H-tO —VO A 9114,91-1.BL1, 9N.BL, V1 ]H2I, 91JI,9WI Vo
31-,., 91-,.8L2, ]H-NBLI V1 SIJI. 31JIP81. 91JIP81 b
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THE STATE
GOVERNOR MIKE DUNLEAVY
G. Alvord
Alaska Drilling Manager
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 31-1-37
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-194
Surface Location: 1359' FNL, 281' FWL, Sec. 12, T12N, R08E, UM
Bottomhole Location: 2074' FNL, 3176' FWL, Sec. 28, TUN, R08E, UM
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 service well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run
must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this
well.
This permit to drill does not exempt you from obtaining additional permits or an approval required by
law from other governmental agencies and does not authorize conducting drilling operations until all
other required permits and approvals have been issued. In addition, the AOGCC reserves the right to
withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an
applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an
AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension
of the permit.
Sincerely,
re Price
Chair
DATED this a 1 day of ary, 2020.
��At offial
STATE OF ALASKA
AKA OIL AND GAS CONSERVATION COMMISSICIP
PERMIT TO DRILL
20 AAC 25.005
RECEIVED
DEC 2 0 2019
A f"1r_il
1a. Type of Work:
1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp E]
1c. Specify if we is proposed for:
Drill ❑� • Lateral ❑
Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone ❑� •
Coalbed Gas ❑ Gas Hydrates ❑
Redrill ❑ Reentry ❑
Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond: Blanket Q • Single Well ❑
11. Well Name and Number:
ConocoPhillips
Bond No. 59-52-180
KRU 3H-37 •
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 20661 TVD: 5930
Kuparuk River Field
Kuparuk Oil Pool
4a. Location of Well (Governmental Section):
7. Property Designation:
Surface: 1359' FNL, 281' FWL, Sec 12, T 12N, R 08E, UM
ADL025531, ADL025524, ADL365501
Top of Productive Horizon:
8. DNR Approval Number:
13. Approximate pud Date:
1294' FNL, 2340' FWL, Sec 34, T 13N, R 08E, UM
932060000, 932059000, 931866000
21Y262'0 3I F / Z4 r r- -
Total Depth:
9. Acres in Propertv:
14. Dis ante to Nearest Propertv:
2074' FNL, 3176' FWL, Sec 28, T 13N, R 08E, UM
2560, 1920, 640 /,,4-61622-
to ADL355032
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 7Z, J ,36.9'
15. Distance to Nearest Well Open
Surface: x: 498655.44 y: 6000297.70 • Zone -4 •
GL / BF Elevation above MSL (ft): 35.8'
to Same Pool: 1622' to 3H-31AL1
16. Deviated wells: Kickoff depth: 300 feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 91 degrees
Downhole: 3,853 psi ' Surface: 3,260 psi
18. Casing Program: Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Hole Casing Weight Grade Coupling I Length
MD TVD MD TVD (including stage data)
42" 20" 94# H-40 Welded 80
Surface Surface 119 119 To be installed
13-1/2" 10-3/4" 45.5# L-80 Hyd 563 3360
Surface Surface 3360 2970 1178 sx 11.0 Lead, 272 sx 15.8 Tail
9-7/8" x 11" 7-5/8" 29.7# L-80 Hyd 563 14371
Surface Surface 14371 5937 1282 sx 15.8 Class G
6-3/4" 4-1/2" 12.6# L-80 Hyd 563 6440
14221 5913 20661 5930 N/A: Un -cemented liner
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 ❑✓ BOP Sketch Q Drilling Program ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑
Diverter Sketch ❑� Seabed Report ❑ Drilling Fluid Program ❑� 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 deviated from
without prior written approval.
Contact Name: Marti Titus"
Authorized Name: G. Alvord Contact Email: marti.n.titus@cop.com
Authorized Title: Alaska Drilling Manager Contact Phone: 907-265-1192
I
12
Authorized Signature: -�. V` �\ Date: -
Commission Use Only
Permit to Drill / /�
_`
API Number:
L"e
Permit Approval
h02J
See cover letter for other
Number: �L `
50- (j��-Z
Date:X1
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: 30P f. 71CI 3500 Samples req'd: Yes ❑ No� Mud log req'd: Yes ❑ No
41-1�/Q �il (/l �'1 l�� jr�� 7Lrj 7 !� QD� H25 measures: Yes No❑ Directional svy req'd: Yes [�No ❑
Subm�� w���rcz' L°a5�✓� L d 7��/� Spacing exception req'd: Yes❑No�/ Inclination -only svyreq'd:Yes ❑No[✓]
Post initial injectioq MIT req'd: Yes ❑ No
r o ✓ a J / vC/fl/ W / IAZf{- rct ✓r C�
o � 11
,$CC �t}ache�l C'oc�clitio-n-s t-.�. W Crd2v���?5. O3��h�i2�
P 7-0 �raCryr //rvtv�� dry`/lr of ��� lu !h f/
DF{S '✓ 3H " 4 3 - / 3N -/S fo rr'<r" a •`. Ss" �h Jc r�v,Y�GF� 9 3
APPROVED d
-I IVD
Approved by: COMMISSIONER THE COMMISSION Date: o�
Submif Form aAd
Form 10-40(1is 5/ 017 This permit is valid for 24mo a f p v I per 20 AAC 25.005( Attach m nts in Duplicate
KRU 3H-37(PTD 219-194)
Conditions of Approval:
Approval is granted to run the LWD-Sonic on upcoming well KRU 31-1-37 with the following provisions:
1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as
soon as they become available. The evaluation is to include/highlight the intervals of competent
cement (and lengths) that CPAI is using to meet the objective requirements for annular
isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an
evaluation/interpretation is not acceptable.
2. LWD sonic logs must show free pipe and Top of Cement, just as the a -line log does. CPAI must
start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC.
Starting the log below the actual TOC based on calculations predicting a different TOC will not
be acceptable.
3. CPAI will provide a cement job summary report and evaluation along with the cement log and
evaluation to the AOGCC when they become available
4. CPAI will provide the results of the FIT when available.
5. Depending on the cement job results indicated by the cement job report, the logs and the FIT,
remedial measures or additional logging may be required.
Application for Permit to Drill, Well 3H-37
Saved: 19 -Dec -19
Conoco Phillips
December 19, 2019
Alaska Oil and Gas Conservation Commission
333 West 7t" Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill, Kuparuk Producer, 3H-37
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grass roots producer, a single -lateral horizontal well in
the Kuparuk formation. The potential spud date for this well is February 6, 2020. It is planned to use rig Doyon 19. .
A 13-1/2" surface hole will be drilled on diverter & 10-3/4" surface casing run to total depth and cemented to surface.
The remaining intervals will utilize Doyon 19's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on
a 14 -day cycle in accordance with COP and AOGCC policy. The intermediate hole section will consist of a 9-7/8" x 11"
hole with 7-5/8" casing run to total depth & cemented in place. The production lateral will include a 6-3/4" production
hole geo-steered in the Kuparuk formation and lined with 4-1/2" liner with swell packers. The upper completion will be
run with 3-1/2" tubing.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent
information attached to this application includes the following:
1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a).
2. Pressure information as required by 20 ACC 25.035 (d) (2).
3. Casing and Cementing program.
4. A drilling fluids program summary.
5. A proposed drilling program.
6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b).
7. A proposed completion diagram.
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by
20 ACC 25.035 (a) and (b).
2. A description of the drilling fluids handling system.
3. Diagram of riser set up.
If you have any questions or require further information, please contact Marti Titus at 907-265-1192
(marti.n.titus@cop.com) or Chip Alvord at 907-265-6120.
Sincere) ,
Chip Alvord
Drilling Manager
Loepp, Victoria T (CED)
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Wednesday, February 19 2020_2.57-PM-
To:
020257 PMTo: Loepp, Victoria T (CED)
Subject: 3H-37 PTD - Diverter Waiver Request
Hi Victoria,
We stated in the 3H-37 permit that we would have the diverter rigged up when we drill the surface hole. Our field
drilling supervisor contacted me on Monday and said that after looking at the pad layout on 3H, he thinks that it would
be very difficult to rig up the diverter on 37 as they would have to extend the diverter line out to get past the flowlines
so that it's not pointing directly at them. This would be very challenging as they appear to about the same level as the
conductor. In addition, extending the diverter line would put the production facilities within the 75' radius of no ignition
sources. Given that we just drilled the 3H-35 surface hole and didn't encounter any shallow hazards, would it be
possible to get a waiver for the diverter on 3H-37?
Thanks,
Marti ,7icy , ,. r L-�- r
Marti Titus
Staff Drilling Engineer 3;7
Office: 907-265-1192 kr�l l`�v� fc- /L
Cell: 713-494-8198
1
Application for Permit to Drill Document
Kuparuk Well 31-1-37
Well Name
Requirements of 20 AAC 25.005 (f)
The well for which this application is submitted will be designated as KRU 3H-37
Location Summary
Requirements of 20 AAC 25.O05(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 property'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 of the top of each objective formation and at total depth;
Location at Surface 1359' FNL, 281' FWL, Sec 12, T12N, R08E, UM
'
NGS Coordinates
Northings: 6000297.70' Eastings: 498655.44'
RKB Elevation i , "% 36:9' AMSL "'
1Pad Elevation 35.8' AMSL ,
Location at Surface Casing 701' FNL, 4629' FWL, Sec 11, T12N, R08E, UM
NGS Coordinates
Northings: 6000956.61' Eastings: 497723.10'
Measured Depth, RKB: 3,360'
Total Vertical Depth, RKB: 2,970'
Total Vertical Depth, SS: 1 2,897'
Location at Intermediate Casing 1236' FNL, 2315' FWL, Sec 34, T13N, R08E, UM
NGS Coordinates
Northings: 6010982.31' Eastings: 494349.56'
Measured Depth, RKB: 14,371'
Total Vertical Depth, RKB: 5,937'
Total Vertical Depth, SS: 5,864'
Location at Total Depth 2074' FNL, 3176' FWL, Sec 28, T13N, R08E, UM
NGS Coordinates
Northings: 6015428.92' Eastings: 489926.93'
Measured Depth, RKB: 20,662'
Total Vertical Depth, RKB: 5,930'
Total Vertical Depth, SS: 5,857'
and
(D) other information required by 20 AAC 25.050(b);
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;
Please see Attachment: 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.
The Applicant is the only affected owner.
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 on item already on file with the
commission and identified in the application:
(3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC
25.037, as applicable,
Please reference BOP schematics on file for Doyon 19.
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 hazards, 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;
The maximum potential surface pressure (MPSP) while drilling 3H-37 is 3,260 psi; estimate from a max estimated
reservoir pressure (based on offset well injection/pressure data and reservoir simulator), a gas gradient of 0.10
psi/ft, and the estimated formation depth: 1
Kuparuk Sand Estimated BHP = 3853 psi
Kuparuk Sand estimated depth = 5,928' TVD 7
Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) I2
Hydrostatic of full gas column = 593 psi (5,928' TVD * 0.10 psi/ft) \
MPSP = BHP — gas column = 3260 psi 1 (3,853 psi — 593 psi) /� ��yy)
(B) data on potential gas zones; 35 0 " v
The wellbore is not expected to penetrate any shallow gas zones.
And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones
that have a propensity for differential sticking;
See attached Drilling Hazards Summary
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 on 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);
A procedure is on file with the commission for performing FIT's/LOT'S.
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 Cement Program
Casing and Cementing Program
Hole
Casing
Weight
Grade
Coupling
Length
Top MD
Top
Bottom
Bottom
Cement Details
TVD
MD
TVD
42"
20"
94#
H-40
Welded
80
Surface
Surface
119
119
To be installed
13
10-3/4"
45.S#
L-80
Hyd 563
3,360 '
Surface
Surface
3,360
2,970
1178 sx 11.0 Lead, 272 sx
1/2"
15.8 Tail
9-7/8"
7-5/8"
29.7#
L-80
Hyd 563
14,371
Surface
Surface
14,371 '
5,937
1282 sx 15.8 Class G
X 11"
6-3/4"
1 4-1/2"
1 12.6#
1L-80
IHyd 563
1 6,440 '
14,221
15,913
20,661
5,930
N/A: Un -cemented liner
10-3/4" Surface casing run to 3,360' MD / 2,970' TVD
Cement surface casing back to surface. Pump a 11.0 ppg lead slurry from 2,860 to surface and 500'of 15.8 ppg tail
slurry from 3,360' MD to 2,860'. Assume 300% excess open hole annular volume from conductor to base permafrost
and 50% from base permafrost to shoe.
7-5/8" Production casing run to 14,371' MD / 5,937' TVD
Single stage slurry is designed to be placed from TD to 11,203' MD / 5141' TVD (250' TVD above top of the Moraine
which is the predicted top of hydrocarbons) with 35% excess open hole annular volume.
7-5/8" Intermediate Casing
10-3/4" Surface Casing
Design: Single stage 15.8 ppg Class G slurry with 35% excess in OH
Design: 11.0 ppg lead slurry from 2860' to surface and 500' of 15.8 ppg tail slurry
Cement yield
Lead Cementyield =
2.61 ft3/sk Tail Ce mentyield =F
1.16 ft3/sk
11.0 ppg LiteCRETE Lead Slurry
261.1 bbls
Shoetrack 80'x 0.0.04592 bbl/ft x 1 (0% excess)
Conductor
119'x 0.2477 bbl/ft x 1.0 (0% excess)
29.5 bbls
Base permafrost to conductor
(1675'- 119') x 0.06478 bbl/ft x 4 (300% excess)
403.2 bbls
Btm of lead to base permafrost
(2860' - 1675) x 0.06478 bbl/ft x 1.5 (50% excess)
115.2 bbls
Total Lead Cement
547.8 bbls
3075.9 ft3
1178 sx
12.0 ppg DeepCRETE Tail Slurry
Shoe to Top of Tail
500'x 0.06478 bbl/ft x 1.5 (50% excess)
48.6 bbls
Shoetrack
80'x 0.09598 bbl/ft x 1 (0% excess)
7.7 bbls
Total Tail Cement
56.3 bbls
315.9 ft3
272 sx
7-5/8" Production casing run to 14,371' MD / 5,937' TVD
Single stage slurry is designed to be placed from TD to 11,203' MD / 5141' TVD (250' TVD above top of the Moraine
which is the predicted top of hydrocarbons) with 35% excess open hole annular volume.
7-5/8" Intermediate Casing
Design: Single stage 15.8 ppg Class G slurry with 35% excess in OH
Cement yield
1.16 ft3/sk
15.8 ppg Class G Slurry
Shoe to TOC (14371'- 11203') x 0.06106 bbl/ft x 1.35 (35% excess)
261.1 bbls
Shoetrack 80'x 0.0.04592 bbl/ft x 1 (0% excess)
3.7 bbls
Total Tail Cement
264.8 bbls
1486.9 ft3
1282 sx
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 on 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
under 20 AAC 25.035(h)(2);
Please reference attachment for diverter schematic.
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;
Mud Program Summary
Diagram of Doyon 19 Mud System is on file with AOGCC.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
N/A - Application is not for an exploratory or stratigraphic test well.
Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
N/A - Application is not for an exploratory or stratigraphic test well.
Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
N/A - Application is not for an offshore well.
Evidence of Bonding
_Requirements of 20 AAC 25.005 (c)(12)
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
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 follows. Please refer to attachment for proposed well schematic. 01 j' f'���'r
1. Move in / rig up Doyon Rig 19. est. -f
2. Spud and directionally drill 13-1/2" hole to casing point as per directional plan. Survey/log with MWUD/LWD
(Gamma Ray, Resistivity) and gyro (as required).
3. Run and cement 10-3/4", 45.5#, L80, Hydril 563 casing to surface. Displace cement with mud & check floats
upon bumping plug. Perform top job if required after notifying AOGCC. Evacuate top 2 feet of cement from
annulus for sealant job (post rig).
Surface
Intermediate
Production
13-1/2" Hole
9-7/8" x 11" Hole
6-3/4" Hole
10-3/4" Casing
7-5/8" Casing
4-1/2" Liner
Mud System
Spud
(WBM)
LSND
(WBM)
Flo -Pro NT
(WBM)
Density (ppg)
8.8-9.5
9.0-10.2
10.2-12.7
PV (CP)
ALAP
ALAP
ALAP
YP (Ib/100ft2)
30-80
18-30
15-25
Funnel Viscosity
200-300
Base Permafrost
100-150 to TD
N/A
N/A
Gel Strengths (10s/10m)
30-50 / 30-50
8-15 / <20
5-10/6-12
API Fluid Loss (cc/30min)
NC
< 10 shoe to HRZ<
< 6 HRZ to TD
6
HTHP Fluid Loss (cc/min at 160 °F
N/A
< 10
< 10
pH
9.5-10.0
9.5-10.0
9.0-10.0
Diagram of Doyon 19 Mud System is on file with AOGCC.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
N/A - Application is not for an exploratory or stratigraphic test well.
Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
N/A - Application is not for an exploratory or stratigraphic test well.
Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
N/A - Application is not for an offshore well.
Evidence of Bonding
_Requirements of 20 AAC 25.005 (c)(12)
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
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 follows. Please refer to attachment for proposed well schematic. 01 j' f'���'r
1. Move in / rig up Doyon Rig 19. est. -f
2. Spud and directionally drill 13-1/2" hole to casing point as per directional plan. Survey/log with MWUD/LWD
(Gamma Ray, Resistivity) and gyro (as required).
3. Run and cement 10-3/4", 45.5#, L80, Hydril 563 casing to surface. Displace cement with mud & check floats
upon bumping plug. Perform top job if required after notifying AOGCC. Evacuate top 2 feet of cement from
annulus for sealant job (post rig).
4. Remove diverter system, install and test wellhead, and install and test 13-5/8" x 5,000 psi BOPS to 3500 psi
high and 250 psi low. Notify AOGCC 24 hrs before test.
5. PU 9-7/8" PDC bit and directional drilling assembly with underreamer, MWD, Gamma Ray, Resistivity, and
PWD. RIH and clean out to 100' above shoe. Test surface casing to 3,500 psi for 30 minutes.
6. Drill out shoe track and 20' of new formation. Perform LOT/FIT (to a minimum of 1 . ppg), record results. a
7. Directionally drill to intermediate hole TD.
8. BROOH to base permafrost, circulate well clean, and then POOH on elevators.
9. Laydown intermediate BHA. 4' 3��r'
10. Run 7-5/8", 29.7#, L80, Hydril 563 casing from surface to TD. 'TL -
11. Pump cement job as per Halliburton proposal. Top cement to be placed @ +/- 250' TVD above top
hydrocarbon bearing zone (Moraine).
12. If plugs bump, pressure test casing to 3,500 psi for 30 minutes.
13. Install 7-5/8" packoff & test to 5000 psi.
14. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel to freeze protect.
15. PU 6-3/4" bit, and drilling assembly with MWD, Gamma Ray, Resistivity, Density, Neutron, SonicScope and
PWD. Shallow test BHA.
16. Perform "MAD pass" across at least 300' to establish free pipe baseline for cement evaluation.
17. Continue RIH on drill pipe to 7-5/8" estimated TOC.
18. Continue TIH to log cement down to 1-2 stands above float collar. Cement log results will be provided to
AOGCC as soon as available.
19. Clean out any residual cement to top of float equipment. If not previously tested, test intermediate casing
to 3,500 psi for 30 minutes.
20. Drill out shoe track and 20' of new formation. Perform FIT/LOT and record results.
21. Directionally drill 6-3/4" hole, geo-steering through the Kuparuk formation per directional plan.
22. Circulate 1 BU after TD and BROOH to 7-5/8" shoe. CBU to clean casing and POOH on elevators.
23. Lay down production BHA.
24. PU and run 4-1/2", 12.6# L-80, Hydril 563 liner with liner hanger/packer. The top of liner will be placed at
14,221' (150' overlap in the 7-5/8" casing).
25. Set liner hanger & packer. Test liner top packer.
26. Flow check well.
27. POOH with liner running tools and lay down.
28. Run 3-1/2" 9.3#, L-80, Hydril 563 upper completion and land tubing.
29. Nipple down BOPE and nipple up tree. Test tree and freeze protect well. Install BPV.
30. RDMO.
Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application for a Permit to Drill mustc be accompanied by each of the following items, except for on item already on file with 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 authorization under 20 AAC 25.080 for on annular disposal operation in the well.;
Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU
Class II disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe
Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved
disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and
roads in the Kuparuk area in accordance with a permit from the State of Alaska.
6
Attachments:
Attachment 1— Well Schematic
Attachment 2 — Diverter Layout Diagram
Attachment 3 — Directional Plan
Attachment 4 — Drilling Hazards Summary
Attachment 5 — Wellhead / Tree Diagram
Attachment 6 — Plat
Attachment 1- Well Schematic
3H-37 Horizontal Kuparuk A -Sand Producer
ConocoPhillips
Proposed Wellbore
Schematic
Well plan: wp06
Updated: 12/19/19
by M. Titus
Conductor: 20" driven to +/-119' -
Base Permafrost @ 1675' MD (1632' ND
TOC @ Surface
13-1/2" Surface Hole
Top WSak @ 2637' M D/ 2470' ND
eL
GLM #4 @ ^'2700' MD / 2500' TVD
Base WSak @3144'MD/2836'ND
Surface Casin¢: 10-3/4" 45.5# L-80 Hydril 563
@ 3,360' MD / 2,970' TVD, 54• deg Inc
Tubing: 3-1/2" 9.3# L-80 EUE 8RD-MOD
DIAL Smart Gas Lift System @ 5,200' MD / 3,600' TVD
os
• 3-Y,", 2.813" DS Nipple
• DIAL Smart Gas Lift Mandrel
J
Polished Bore
Po
• Conventional GLM
9-7/8" x 11" Intermediate Hole
x
DIAL Smart Gas Lift System @ 9,100' MD / 4,600' TVD
GL
• 3-YZ', 2.813" X Nipple
DIAL Smart Gas Lift Mandrel
Pa
Polished Bore
J
: Conventional GLM
TOC @ 11203' MD / 5141' TVD (250' TVD above top of Moraine)
Top Moraine L)12175' MD/5391' TVD
Base Moraine @ 12501'MD/ 5475'TVD
GLM #1 @ "12,600' M D / 5500' TVD, "'75°
Top HRZ @ 13333' M D/ 5687' TVD
DIAL DHG, 13,960' MD
Top Kalubik @ 13788' MD / 5806' TVD
3-%" x 7-5/8" Premier Packer @ 14,000' MD, 75°
Fault 1 @ 13811' MD / 5812' ND
3-R", 2.813" XN Nipple @ ^'14,040' MD / 5871' TVD, -75'
Top K1 @ 14021' M D / 5866' TVD %tt
Intermediate Casine: 7-5/8" 29.7#, L80, Hydril 563
@ 14,371' MD / 5,937' TVD, 83• Inc
Top Kuparuk . @ 14307' MD / 5928' TVD
6-3/4" Production Hole
I----
7-5/8" x 5-1/2" BakerZXP Packer / Flex Lock Liner
Wellbore Isolation Valve + Alpha Sleeve
Hanger @ 14,221' MD / 5913' ND, "79°
Ball Actuated Frac Sleeves
5-3/4" x 4-1/2" Swell Packer for fault isolation
Production Liner: 4-1/2" 12.6# L-80 Hydril 563 w/ pert joints
@ 20,661' MD / 5,930' ND, 90• Inc
Attachment 2 - Diverter LayM
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ConocoPhilli s
p
ConocoPhillips Alaska
Inc—Kuparuk
Kuparuk River Unit 2
Kuparuk 3H Pad
Plan: 31-1-37
50103xxxxx00
3H-37 -
3H-37_wp06
Anticollision Report
18 December, 2019
BakerHughes C
ConocoPhillips
ConocoPhillips Anticollision Report BakerHughes
Company:
ConocoPhillips Alaska Inc-Kuparuk
Project:
Kuparuk River Unit -2
Reference Site:
Kuparuk 3H Pad
Site Error:
0.00 usft
Reference Well:
Plan: 3H-37
Well Error:
0.00 usft
Reference Wellbore
3H-37
Reference Design:
3H-37_wp06
Reference 3H-37_wp06
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method: MD Interval 25.00usft Error Model:
Depth Range: Unlimited Scan Method:
Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface:
Warning Levels Evaluated at: 2.79 Sigma Casing Method:
Survey Tool Program
From
(usft)
36.90
1,200.00
1,200.00
3,359.86
3,359.86
14,370.61
14,370.61
Date 12/18/2019
To
(usft) Survey (Wellbore)
1,200.00 3H-37_wp06 (31-1-37)
2,200.00 3H-37_wp06 (31-1-37)
3,359.86 3H-37_wp06 (31-1-37)
4,859.86 3H-37_wp06 (31-1-37)
14,370.61 3H-37_wp06 (31-1-37)
15,870.61 3H-37_wp06 (31-1-37)
20,661.80 3H-37_wp06 (31-1-37)
Well Plan: 3H-37
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
True
Minimum Curvature
2.00 sigma
OAKEDMPI
Offset Datum
ISCWSA
Tray. Cylinder North
Combined Pedal Curve
Added to Error Values
Tool Name Description
GYD-GC-SS
Gyrodata gyro single shots
MWD OWSG
OWSG MWD - Standard
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag + Multi -Station Correction
MWD OWSG
OWSG MWD - Standard
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag + Multi -Station Correction
MWD OWSG
OWSG MWD - Standard
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag + Multi -Station Correction
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
lusft)
Kuparuk 3H Pad
3H-01 - 3H-01 - 3H-01
72.70
76.00
186.99
185.79
156.156 CC, ES
3H-01 - 3H-01 - 3H-01
1,251.48
1,250.00
359.43
348.92
34.198 SF
3H-01 - 3H -01A- 3H-01A_wp04 (Draft B)
72.70
76.00
186.99
186.25
254.788 CC, ES
3H-01 - 3H -01A- 3H-01A_wp04 (Draft B)
1,331.65
1,350.00
395.11
384.05
35.721 SF
3H-01 - 3H-01AL1 - 3H-01AL1_wp02 (DraftA)
72.70
76.00
186.99
186.25
254.788 CC, ES
3H-01 - 3H-01AL1 - 3H-01AL1_wp02 (DraftA)
1,331.65
1,350.00
395.11
384.05
35.721 SF
3H-02 - 3H-02 - 3H-02
423.44
425.00
158.87
155.25
43.958 CC
3H-02 - 3H-02 - 3H-02
448.78
450.00
158.99
155.21
42.041 ES
3H-02 - 3H-02 - 3H-02
824.27
825.00
201.66
195.20
31.185 SF
3H-03 - 3H-03 - 3H-03
473.50
475.00
135.82
132.82
45.277 CC
3H-03 - 3H-03 - 3H-03
498.69
500.00
135.84
132.74
43.748 ES
3H-03 - 3H-03 - 3H-03
796.98
800.00
164.64
160.17
36.785 SF
3H-04 - 3H-04 - 3H-04
674.59
675.00
104.86
99.49
19.530 CC
3H-04 - 3H-04 - 3H-04
699.46
700.00
104.87
99.32
18.893 ES
3H-04 - 3H-04 - 3H-04
821.52
825.00
111.48
104.99
17.187 SF
3H-05 - 3H-05 - 3H-05
723.40
725.00
82.25
76.57
14.471 CC, ES
3H-05 - 3H-05 - 3H-05
896.17
900.00
90.69
83.68
12.941 SF
3H-06 - 3H-06 - 3H-06
1,825.17
1,850.00
44.84
24.89
2.247 Caution Monitor Closely, CC
3H-07 - 3H-07 - 3H-07
621.94
625.00
31.17
26.17
6.231 CC
3H-07 - 3H-07 - 3H-07
646.77
650.00
31.24
26.06
6.026 ES
3H-07 - 3H-07 - 3H-07
720.97
725.00
33.23
27.50
5.799 SF
3H-08 - 3H-08 - 3H-08
496.75
500.00
8.13
5.26
2.834 Normal Operations, CC, ES
3H-08 - 3H-08 - 3H-08
546.62
550.00
8.47
5.40
2.761 Normal Operations, SF
3H-09 - 3H-09 - 3H-09
271.70
275.00
12.52
9.96
4.880 CC
3H-09 - 3H-09 - 3H-09
396.61
400.00
12.91
9.46
3.747 ES
3H-09 - 3H-09 - 3H-09
496.44
500.00
14.51
10.39
3.525 SF
3H-10 - 3H-10 - 3H-10
371.47
375.00
36.83
34.04
13.175 CC
3H-10 - 3H-10 - 3H-10
421.30
425.00
36.93
33.85
12.005 ES
3H-10 - 3H-10 - 3H-10
644.46
650.00
43.64
39.26
9.973 SF
3H-10 - 3H -10B - 3H -10B
380.84
375.00
36.83
33.98
12.928 CC
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/18/2019 9.14:56AM Page 2 COMPASS 5000.14 Build 85G
BakerHughes
Well Plan: 31-1-37
Plan: 36.9+35.8 @ 72.70usft (Doyon 1'9)
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
True
Minimum Curvature
2.00 sigma
OAKEDMP1
Offset Datum
Summary
ConocoPhillips
ConocoPhillips
Anticollision Report
Company:
ConocoPhillips Alaska Inc-Kuparuk
Local Co-ordinate Reference:
Project:
Kuparuk River Unit -2
TVD Reference:
Reference Site:
Kuparuk 3H Pad
MD Reference:
Site Error:
0.00 usft
North Reference:
Reference Well:
Plan: 31-1-37
Survey Calculation Method:
Well Error:
0.00 usft
Output errors are at
Reference Wellbore
31-1-37
Database:
Reference Design:
3H-37_wp06
Offset TVD Reference:
BakerHughes
Well Plan: 31-1-37
Plan: 36.9+35.8 @ 72.70usft (Doyon 1'9)
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
True
Minimum Curvature
2.00 sigma
OAKEDMP1
Offset Datum
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
lusft)
(usit)
(usft)
(usft)
Kuparuk 3H Pad
31-1-10 - 3H -10B - 3H -10B
430.66
425.00
36.98
33.86
11.826 ES
31-1-10 - 3H -10B - 3H -10B
629.08
625.00
42.70
38.42
9.976 SF
31-1-10 - 3H -10C - 3H -10C
380.84
375.00
36.83
33.98
12.928 CC
31-1-10 - 3H -10C - 31-1-10C
430.66
425.00
36.98
33.86
11.826 ES
31-1-10 - 31-1-10C - 31-1-10C
629.08
625.00
42.70
38.42
9.976 SF
31-1-10 - 31-1-10CL1 - 31-1-10CL1
380.84
375.00
36.83
33.98
12.928 CC
3H-10 - 31-1-10CL1 - 31-1-10CL1
430.66
425.00
36.98
33.86
11.826 ES
3H-10 - 31-1-10CL1 - 31-1-10CL1
629.08
625.00
42.70
38.42
9.976 SF
31-1-10 - 31-1-10CL2 - 31-1-10CL2
380.84
375.00
36.83
33.98
12.928 CC
31-1-10 - 31-1-10CL2 - 31-1-10CL2
430.66
425.00
36.98
33.86
11.826 ES
31-1-10 - 31-1-10CL2 - 31-1-10CL2
629.08
625.00
42.70
38.42
9.976 SF
31-1-10 - 31-1-10CL2-01 - 31-1-10CL2-01
380.84
375.00
36.83
33.98
12.928 CC
31-1-10 - 31-1-10CL2-01 - 31-1-10CL2-01
430.66
425.00
36.98
33.86
11.826 ES
31-1-10 - 31-1-10CL2-01 - 31-1-10CL2-01
629.08
625.00
42.70
38.42
9.976 SF
31-1-10 - 31-1-10CL2-02 - 31-1-10CL2-02
380.84
375.00
36.83
33.98
12.928 CC
31-1-10 - 31-1-10CL2-02 - 31-1-10CL2-02
430.66
425.00
36.98
33.86
11.826 ES
31-1-10 - 31-1-10CL2-02 - 31-1-10CL2-02
629.08
625.00
42.70
38.42
9.976 SF
31-1-10 - 31-1-10CPB1 - 31-1-10CPB1
380.84
375.00
36.83
33.98
12.928 CC
31-1-10 - 31-1-10CPB1 - 31-1-10CPB1
430.66
425.00
36.98
33.86
11.826 ES
31-1-10 - 31-1-10CPB1 - 31-1-10CPB1
629.08
625.00
42.70
38.42
9.976 SF
31-1-11 - 31-1-11 - 31-1-11
346.16
350.00
127.20
122.52
27.163 CC
31-1-11 - 31-1-11 - 31-1-11
469.42
475.00
127.80
121.53
20.381 ES
31-1-11 -31-1-11 -31-1-11
706.03
725.00
147.11
137.67
15.587 SF
31 -1 -11 -3H -11A -3H -11A
352.48
350.00
127.20
122.43
26.696 CC
31 -1 -11 -3H -11A -3H -11A
475.70
475.00
127.89
121.54
20.135 ES
3H -11 -3H -11A -3H -11A
711.74
725.00
148.32
138.80
15.584 SF
31-1-11 - 31-1-11AL1 - 3H-11AL1
352.48
350.00
127.20
122.43
26.696 CC
31-1-11-3H-11AL1-3H-11AL1
475.70
475.00
127.89
121.54
20.135 ES
31-1-11-3H-11AL1-3H-11AL1
711.74
725.00
148.32
138.80
15.584 SF
31-1-11-31-1-11AL1-01 - 3H-11AL1-01
352.48
350.00
127.20
122.43
26.696 CC
31-1-11-31-1-11AL1-01 - 3H-11AL1-01
475.70
475.00
127.89
121.54
20.135 ES
31-1-11-31-1-11AL1-01-3H-11AL1-01
711.74
725.00
148.32
138.80
15.584 SF
31-1-12 - 31-1-12 - 3H-12
370.73
375.00
151.95
147.23
32.208 CC
31-1-12 - 31-1-12 - 31-1-12
469.28
475.00
152.56
146.57
25.490 ES
31-1-12 - 31-1-12 - 31-1-12
994.93
1,025.00
194.11
181.25
15.098 SF
31-1-12 - 3H -12A- 31-1-12A
370.73
375.00
151.95
147.23
32.208 CC
3H -12 -3H -12A -3H -12A
469.28
475.00
152.56
146.57
25.490 ES
3H -12 -3H -12A -3H -12A
994.93
1,025.00
194.11
181.25
15.098 SF
31-1-12 - 3H-12AL1 - 3H-12AL1
370.73
375.00
151.95
147.23
32.208 CC
31-1-12 - 3H-12AL1 - 3H-12AL1
469.28
475.00
152.56
146.57
25.490 ES
31-1-12 - 3H-12AL1 - 3H-12AL1
994.93
1,025.00
194.11
181.25
15.098 SF
31-1-12 - 3H-12AL2 - 3H-12AL2
370.73
375.00
151.95
147.23
32.208 CC
31-1-12 - 3H-12AL2 - 3H-12AL2
469.28
475.00
152.56
146.57
25.490 ES
31-1-12 - 3H-12AL2 - 31-1-12AL2
994.93
1,025.00
194.11
181.25
15.098 SF
31-1-12 - 3H-12AL3 - 3H-12AL3
370.73
375.00
151.95
147.23
32.208 CC
31-1-12 - 3H-12AL3 - 3H-12AL3
469.28
475.00
152.56
146.57
25.490 ES
31-1-12 - 31-1-12AL3 - 3H-12AL3
994.93
1,025.00
194.11
181.25
15.098 SF
31-1-12 - 3H-12APB1 - 3H-12APB1
370.73
375.00
151.95
147.23
32.208 CC
31-1-12 - 3H-12AP61 - 3H-12APB1
469.28
475.00
152.56
146.57
25.490 ES
31-1-12 - 3H-12APB1 - 3H-12APB1
994.93
1,025.00
194.11
181.25
15.098 SF
31-1-13 - 31-1-13 - 31-1-13
72.70
76.00
177.78
176.59
148.472 CC
31-1-13 - 31-1-13 - 31-1-13
395.22
400.00
179.05
173.84
34.392 ES
31-1-13 - 31-1-13 - 31-1-13
3,883.03
3,950.00
745.07
689.37
13.376 SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/18/2019 9:14:56AM Page 3 COMPASS 5000.14 Build 85G
BakerHughes
Well Plan: 31-1-37
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
True
Minimum Curvature
2.00 sigma
OAKEDMPI
Offset Datum
Summary
ConocoPhillips
ConocoPhillips
Anticollision Report
Company: ConocoPhillips Alaska Inc-Kuparuk
Local Co-ordinate Reference:
Project: Kuparuk River Unit -2
ND Reference:
Reference Site: Kuparuk 3H Pad
MD Reference:
Site Error: 0.00 usft
North Reference:
Reference Well: Plan: 3H-37
Survey Calculation Method:
Well Error: 0.00 usft
Output errors are at
Reference Wellbore 3H-37
Database:
Reference Design: 3H-37_wp06
Offset ND Reference:
BakerHughes
Well Plan: 31-1-37
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
True
Minimum Curvature
2.00 sigma
OAKEDMPI
Offset Datum
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
lusft)
fusft)
lusft)
(usft)
Kuparuk 3H Pad
31-1-13 - 31-1-13A - 3H -13A
72.70
71.00
177.78
176.59
148.472 CC
311-13 - 3H -13A- 3H -13A
400.00
400.00
179.10
173.83
33.988 ES
31-1-13 - 3H -13A- 3H -13A
3,887.13
3,950.00
745.84
690.08
13.375 SF
31-1-13 - 3H-13AL1 - 31-1-13AL1
72.70
71.00
177.78
177.05
242.249 CC
3H-13 - 31-1-13AL1 - 31-1-13AL1
400.00
400.00
179.10
174.30
37.266 ES
31-1-13 - 31-1-13AL1 - 3H-13AL1
3,907.52
3,975.00
749.83
694.08
13.450 SF
314-13 - 31-1-13AL1-01 PB1 - 31-1-13AL1-01 PB1
72.70
71.00
177.78
177.05
242.249 CC
31-1-13 - 31-1-13AL1-01 PB1 - 31-1-13AL1-01 PB1
400.00
400.00
179.10
174.30
37.266 ES
31-1-13 - 3H-13AL1-01 PB1 - 31-1-13AL1-01 PB1
3,907.52
3,975.00
749.83
694.08
13.450 SF
31-1-13 - 3H-13AL1-02 - 3H-13AL1-02
72.70
71.00
177.78
177.05
242.249 CC
3H-13 - 31-1-13AL1-02 - 31-1-13AL1-02
400.00
400.00
179.10
174.30
37.266 ES
31-1-13 - 31-1-13AL1-02 - 31-1-13AL1-02
3,907.52
3,975.00
749.83
694.08
13.450 SF
31-1-13 - 31-1-13AL1-03 - 31-1-13AL1-03
72.70
71.00
177.78
177.05
242.249 CC
31-1-13 - 31-1-13AL1-03 - 31-1-13AL1-03
400.00
400.00
179.10
174.30
37.266 ES
3H-13 - 3H-13AL1-03 - 3H-13AL1-03
3,907.52
3,975.00
749.83
694.08
13.450 SF
3H-13 - 3H-13AL1 PB1 - 31-1-13AL1 PB1
72.70
71.00
177.78
177.05
242.249 CC
31-1-13 - 31-1-13AL1 PB1 - 31-1-13AL1 PB1
400.00
400.00
179.10
174.30
37.266 ES
31-1-13 - 31-1-13AL1 PB1 - 31-1-13AL1 PB1
3,907.52
3,975.00
749.83
694.08
13.450 SF
31-1-13 - 31-1-13AL1 PB2 - 31-1-13AL1 PB2
72.70
71.00
177.78
177.05
242.249 CC
31-1-13 - 3H-13AL1 PB2 - 31-1-13AL1 PB2
400.00
400.00
179.10
174.30
37.266 ES
3H-13 - 3H-13AL1 PB2 - 31-1-13AL1 PB2
3,907.52
3,975.00
749.83
694.08
13.450 SF
31-1-13 - 31-1-13AL1 P63 - 31-1-13AL1 PB3
72.70
71.00
177.78
177.05
242.249 CC
31-1-13 - 31-1-13AL1 PB3 - 3H-13AL1 P63
400.00
400.00
179.10
174.30
37.266 ES
31-1-13 - 31-1-13AL1 PB3 - 3H-13AL1 PB3
3,907.52
3,975.00
749.83
694.08
13.450 SF
31-1-14 - 31-1-14 - 31-1-14
345.87
350.00
201.80
197.00
42.095 CC
3H-14 - 3H-14 - 31-1-14
468.52
475.00
202.49
196.11
31.748 ES
31-1-14 - 3H-14 - 3H-14
1,079.23
1,125.00
259.59
245.05
17.852 SF
31-1-14 - 3H -14A- 31-1-14A
345.87
350.00
201.80
197.00
42.095 CC
31-1-14 - 3H -14A- 31-1-14A
468.52
475.00
202.49
196.11
31.748 ES
3H -14 -3H -14A -3H -14A
1,079.23
1,125.00
259.59
245.05
17.852 SF
31-1-14 - 31-1-14APB1 - 31-1-14APB1
345.87
350.00
201.80
197.00
42.095 CC
3H-14 - 3H-14APB1 - 3H-14APB1
468.52
475.00
202.49
196.11
31.748 ES
3H-14 - 3H-14APB1 - 3H-14APB1
1,079.23
1,125.00
259.59
245.05
17.852 SF
31-1-14 - 31-1-14B - 31-1-14B
342.33
350.00
201.80
197.32
45.073 CC
31-1-14 - 31-1-14B - 3H -14B
489.49
500.00
202.76
196.38
31.794 ES
3H -14 -3H -14B -3H -14B
1,100.00
1,150.00
264.16
249.62
18.168 SF
31-1-14 - 3H-14BL1 - 3H-14BL1
342.33
350.00
201.80
197.32
45.073 CC
31-1-14 - 3H-14BL1 - 3H-14BL1
489.49
500.00
202.76
196.38
31.794 ES
3H-14 - 3H-14BL1 - 3H-14BL1
1,100.00
1,150.00
264.16
249.62
18.168 SF
31-1-14 - 3H-14BL2 - 3H-14BL2
342.33
350.00
201.80
197.32
45.073 CC
31-1-14 - 3H-14BL2 - 3H-14BL2
489.49
500.00
202.76
196.38
31.794 ES
31-1-14-3H-14BL2-3H-14BL2
1,100.00
1,150.00
264.16
249.62
18.168 SF
31-1-14 - 3H-14BL3 - 3H-14BL3
342.33
350.00
201.80
197.32
45.073 CC
31-1-14 - 3H-14BL3 - 3H-14BL3
489.49
500.00
202.76
196.38
31.794 ES
3H-1 4 - 3H-14BL3 - 3H-14BL3
1,100.00
1,150.00
264.16
249.62
18.168 SF
3H-14 - 3H-14BL4 - 3H-14BL4
342.33
350.00
201.80
197.32
45.073 CC
31-1-14 - 3H-14BL4 - 3H-14BL4
489.49
500.00
202.76
196.38
31.794 ES
31-1-14-3H-14BL4-3H-14BL4
1,100.00
1,150.00
264.16
249.62
18.168 SF
31-1-15 - 31-1-15 - 31-1-15
246.70
250.00
227.53
224.27
69.840 CC
31-1-15 - 31-1-15 - 31-1-15
394.73
400.00
228.26
223.09
44.195 ES
31-1-15 - 31-1-15 - 31-1-15
4,261.39
4,050.00
350.41
276.54
4.744 SF
3H-16 - 3H-16 - 31-1-16
516.61
525.00
251.65
244.63
35.866 CC
3H-16 - 3H-16 - 31-1-16
589.41
600.00
252.10
244.11
31.573 ES
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12118/2019 9:14:56AM Page 4 COMPASS 5000.14 Build 85G
Summary
ConocoPhillips
ConocoPhillips
Anticollision Report
BakerHughes C,'$
Company: ConocoPhillips Alaska Inc_Kuparuk
Local Co-ordinate Reference:
Well Plan: 31-1-37
Project: Kuparuk River Unit -2
TVD Reference:
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
Reference Site: Kuparuk 3H Pad
MD Reference:
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
Site Error: 0.00 usft
North Reference:
True
Reference Well: Plan: 31-1-37
Survey Calculation Method:
Minimum Curvature
Well Error: 0.00 usft
Output errors are at
2.00 sigma
Reference Wellbore 3H-37
Database:
OAKEDMPI
Reference Design: 3H-37_wp06
Offset TVD Reference:
Offset Datum
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
lusft)
(usft)
(usft)
Kuparuk 3H Pad
31-1-16 - 3H-16 - 31-1-16
1,748.58
1,725.00
388.43
364.24
16.058 SF
31-1-16 - 31-1-16A - 3H -16A
523.67
525.00
251.65
244.99
37.743 CC
31-1-16 - 31-1-16A - 3H -16A
596.48
600.00
252.19
244.55
33.024 ES
3H -16 -3H -16A -3H -16A
1,756.20
1,725.00
389.94
366.10
16.357 SF
31-1-16 - 3H-16APB1 - 3H-16APB1
523.67
525.00
251.65
244.54
35.393 CC
3H-16 - 3H-16APB1 - 31-1-16APB1
596.48
600.00
252.19
244.11
31.214 ES
31-1-16 - 3H-16APB1 - 31-1-16APB1
1,756.20
1,725.00
389.94
365.65
16.059 SF
31-1-23 - 31-1-23 - 31-1-23
5,083.57
4,500.00
316.06
248.32
4.666 CC
31-1-23 - 31-1-23 - 31-1-23
5,169.87
4,600.00
319.00
244.21
4.266 ES
31-1-23 - 31-1-23 - 31-1-23
5,344.27
4,800.00
345.84
259.34
3.998 SF
3H-23 - 31-1-23A - 3H -23A
5,092.06
4,500.00
316.00
247.65
4.623 CC
31-1-23 - 3H -23A- 31-1-23A
5,178.48
4,600.00
319.68
244.34
4.243 ES
31-1-23 - 3H -23A- 31-1-23A
5,352.91
4,800.00
347.84
260.95
4.004 SF
31-1-23 - 3H-23AL1 - 3H-23AL1
5,092.06
4,500.00
316.00
247.69
4.626 CC
31-1-23 - 3H-23AL1 - 3H-23AL1
5,178.48
4,600.00
319.68
244.38
4.245 ES
31-1-23 - 3H-23AL1 - 31-1-23AL1
5,352.91
4,800.00
347.84
260.99
4.005 SF
31-1-24 - 31-1-24 - 31-1-24
72.70
79.00
365.22
363.91
280
3H-24 - 3H-24 - 3H-24
11,506.92
10,625.00
542.44
11.99
1.023Take I�diaion, ES,
31-1-25 - 3H-25 - 31-1-25
267.70
275.00
138.97
135.35
31-1-25 - 3H-25 - 31-1-25
317.47
325.00
139.14
134.89
32.719 ES
31-1-25 - 31-1-25 - 31-1-25
2,201.70
2,100.00
365.83
335.10
11.906 SF
31-1-25 - 31-1-25A - 3H -25A
287.20
275.00
138.96
135.09
35.901 CC
3H-25 - 31-1-25A - 31-1-25A
312.04
300.00
139.08
134.90
33.237 ES
31-1-25 - 3H -25A- 31-1-25A
2,195.53
2,075.00
365.60
334.87
11.898 SF
31-1-25 - 3H-25APB1 - 3H-25APB1
287.20
275.00
138.96
135.09
35.901 CC
31-1-25 - 3H-25APB1 - 3H-25APB1
312.04
300.00
139.08
134.90
33.237 ES
31-1-25 - 3H-25APB1 - 3H-25APB7
2,195.53
2,075.00
365.60
334.87
11.898 SF
31-1-25 - 3H-25APB2 - 3H-25APB2
287.20
275.00
138.96
135.09
35.901 CC
3H-25 - 3H-25APB2 - 3H-25APB2
312.04
300.00
139.08
134.90
33.237 ES
3H-25 - 3H-25APB2 - 3H-25APB2
2,195.53
2,075.00
365.60
334.87
11.898 SF
31-1-26 - 31-1-26 - 31-1-26
492.79
500.00
23.22
19.87
6.925 CC
31-1-26 - 31-1-26 - 31-1-26
517.71
525.00
23.24
19.74
6.645 ES
31-1-26 - 311-26 - 31-1-26
641.91
650.00
25.76
21.53
6.095 SF
31-1-26 - 3H-261-1 - 31-1-261-1
492.79
500.00
23.22
19.87
6.923 CC
31-1-26 - 31-1-261-1 - 31-1-261-1
517.71
525.00
23.24
19.74
6.644 ES
3H-26 - 3H -26L1 - 3H -26L1
641.91
650.00
25.76
21.53
6.094 SF
31-1-26 - 31-1-261-1-01 - 3H -26L1-01
492.79
500.00
23.22
19.87
6.923 CC
31-1-26 - 31-1-261-1-01 - 31-1-261-1-01
517.71
525.00
23.24
19.74
6.644 ES
31-1-26 - 31-1-261-1-01 - 31-1-261-1-01
641.91
650.00
25.76
21.53
6.094 SF
31-1-26 - 3H-261-1-02 - 31-1-261-1-02
492.79
500.00
23.22
19.87
6.923 CC
31-1-26 - 31-1-261-1-02 - 3H-261-1-02
517.71
525.00
23.24
19.74
6.644 ES
3H-26 - 3H-261-1-02 - 31-1-261-1-02
641.91
650.00
25.76
21.53
6.094 SF
314-31 - 3H-31AL1 - 3H-31AL1
72.70
80.00
390.26
388.96
299.831 CC
31-1-31 - 3H-31AL1 - 31-1-31AL1
242.70
250.00
391.01
387.86
124.132 ES
31-1-31 - 3H-31AL1 - 3H-31AL1
14,631.16
14,648.00
1,627.81
1,251.91
4.331 SF
31-1-32 - 31-1-32 - 31-1-32
49.60
50.00
315.28
314.01
247.401 CC
31-1-32 - 31-1-32 - 31-1-32
99.60
100.00
315.33
313.85
212.995 ES
31-1-32 - 31-1-32 - 31-1-32
2,189.52
2,100.00
347.83
316.45
11.084 SF
31-1-32 - 3H-32PB1 - 3H-32PB1
49.60
50.00
315.28
314.01
247.401 CC
3H-32 - 3H-32PB1 - 3H-32PB1
99.60
100.00
315.33
313.85
212.995 ES
31-1-32 - 3H-32PB1 - 3H-32PB1
2,189.52
2,100.00
347.83
316.45
11.084 SF
31-1-32 - Prelim: 31-1-32A - 31-1-32A wp01
49.60
50.00
315.28
314.01
247.403 CC
3H-32- Prelim: 3H-32A-3H-32Aw 01
99.60
100.00
315.33
313.85
213.002 ES
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12118/2019 9:14.56AM Page 5 COMPASS 5000.14 Build 85G
ConocoPhillips
ConocoPhillips Anticollision Report BakerHughes 11?i�
Company:
ConocoPhillips Alaska Inc—Kuparuk
Project:
Kuparuk River Unit -2
Reference Site:
Kuparuk 3H Pad
Site Error:
0.00 usft
Reference Well:
Plan: 31-1-37
Well Error:
0 00 usft
Reference Wellbore
31-1-37
Reference Design:
3H-37_wp06
Summary
Site Name
Offset Well - Wellbore - Design
Kuparuk 3H Pad
31-1-32 - Prelim: 3H -32A - 31-1-32A wp01
Plan: 31-1-35 - 31-1-35 - 31-1-35 wp04
Plan: 3H-35 - 31-1-35 - 31-1-35 wp04
Plan: 31-1-36_13C - 31-1-36 - 3H-36wp05
Plan: 3H-36—BC - 31-1-36 - 3H-36wp05
Plan: 3H-36—BC - 3H-36 - 3H-36wp05
Local Co-ordinate Reference:
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset ND Reference:
Well Plan: 31-1-37
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
True
Minimum Curvature
2.00 sigma
OAKEDMP1
Offset Datum
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Depth
Depth
Centres
Ellipses
Factor
(usft)
(usft)
(usft)
(usft)
2,189.52
2,100.00
347.83
315.80
10.860 SF
1,458.48
1,475.00
73.13
65.43
9.499 CC, ES
7,601.39
7,800.00
495.94
355.32
3.527 SF
1,692.73
1,700.00
50.94
39.68
4.525 CC
1,717.26
1,725.00
51.06
39.66
4.481 ES
1,741.80
1,750.00
51.36
39.84
4.461 SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/18/2019 9:14:56AM Page 6 COMPASS 5000.14 Build 85G
ConocoPhillips
ConocoPhillips Anticollision Report BakerHughes 5�t
Company:
ConocoPhillips Alaska Inc—Kuparuk
Project:
Kuparuk River Unit -2
Reference Site:
Kuparuk 3H Pad
Site Error:
0.00 usft
Reference Well:
Plan: 3H-37
Well Error:
0.00 usft
Reference Wellbore
3H-37
Reference Design:
3H-37_wp06
Local Co-ordinate Reference:
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset ND Reference:
Well Plan: 31-1-37
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
Plan: 36.9+35.8 @ 72.70usft (Doyon 19)
True
Minimum Curvature
2.00 sigma
OAKEDMP1
Offset Datum
Reference Depths are relative to Plan: 36.9+35.8 @ 72.70usft (Doyon 1 Coordinates are relative to: Plan: 3H-37
Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4
Central Meridian is 150° 0' 0.000 W Grid Convergence at Surface is: -0.01 °
i
�� P6n3H�8C.JK363K3&gOSW
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/18/2019 9:14 56AM Page 7 COMPASS 5000.14 Build 85G
Separation
Factor PloffJt
'...
9.00
I
I I
I I
I I I
I I
I
I
I
I
I
I
I
1 I
I I
I I
_ _ _ _
I I I
I
I
1 I
( I I
v 6.00
LL -
l0
0
I
I
I I
I I
N
I �
I i I
I '
___
_
_'�
_) _
U)
I I
( I I
I
I
I I I
Normal Operatons '
3.00
Caution Mondor Closely
I I
I I
I
Take Immediate Action
I
I
I I
STOP Drilling
0.00
I
I
1 I (
1
I I
I I
0 3500 7000 10500 14000 17500 21000
Measured Depth
LEGEND
3H013K013K01 V1 � 3K12.3K12.3K13V1 �� 3K15,3K15,3K15V1
3H013Hufn,3H01A_rg0l �atBlW 3K12,3K12A.3H-12AV0 � 3N16.3K16,3Kt6V1
3H01,3H01PL1,3HOIALI_vg02 (Ga1A)W 3K123K12AL1,3K12PL1W -
y
3K@3Ha2,3Ha2V1123K12AL2.3K12P12W T� 3K16,3K16APB1'3K16VPB1 V0
Km3H033Ha3V2 3K123K12PL3,3K _. 3123:311,3-311
3HC4,3H04,3K04Vt 3K13iPB1W
3K1]3K13.3K13V2 3K23.3K211L1.3K9AL1 VO
HO' V1 3K13.3K13A.3H--V1 —,-4.3-
3-7,3H07,31-11 K133K13AL1?K13x1 W
3K133K111L1-01PB13H-1JNL1L1F01W 3K25.3K25A.3H354VI
3K133K13lLL1JQ3Kf3n1f4BW 3K25.3K25PP01.3K254PB1W
J4103K10,3410V2 3K133K13K1¢13Kt3N1Q1W 31—,3K25i1P82,3H]51PB2V1
K103K10B,3K10BW —3.-3—PBI —P-0 3—.3K26,3K26V1
3K103K10C.3K10CW 3K133K13K1P6;3i1—Pw V0 � 3K26,3K26L13K�L1W
3K1B3H160.1,3KIDQ1W 3K13K1PB3,3113P11PB3V0 3K263K26L1-013K26L1a1W
3K103K1 L23K10q.2W 111:3 14.31111 3K263K26L1-02,3K26L112W
3---l'—Vo
3K103K100.2O13Kt0Q2-01 W KtM,3K
3K103K100.2�,3K10Q1-02W K14,3K14HPB1'3K14CPB1 V2 3H323H323H32W
K103H-10CPB13K1QP81W 31414,3-13 ]Iit4BW 31-3K32PB1,3H3 —
31411,31+11,33-11 3 a2A3H32FwpO1 W
3-31+11A.31+11—
i
�� P6n3H�8C.JK363K3&gOSW
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/18/2019 9:14 56AM Page 7 COMPASS 5000.14 Build 85G
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§
Attachment 4 — Drilling Hazards Summary
3H-37 Drilling Hazards Summary
13-1/2" Open Hole / 10-3/4" Casing Interval
Hazard
Risk Level
Mitigation Strategy
Broach of Conductor
Low
Monitor cellar continuously during interval.
Washouts / Hole Sloughing
Low
Cool mud temperatures, minimize circulating times when possible
Anti -Collision
Low
Follow real time surveys very closely, gyro survey as needed to
ensure survey accuracy.
Running Sands and Gravels
Low
Maintain planned mud parameters, increase mud weight /
viscosity, pump high viscosity sweeps.
Gas Hydrates
Low
Reduce pump rates, reduce drilling fluid temperatures, additions
of lecithin.
Hole swabbing /tight hole on trips
Moderate
Circulate hole clean prior to trip, manage trip speeds, proper hole
filling (use of trip sheets), pump out of hole as needed
Lost Circulation
Moderate
Keep hole clean. If losses occur, reduce pump rates and mud
rheology. Use LCM.
9-7/8" Open Hole / 7-5/8" Casing Interval
Hazard
Risk Level
Mitigation Strategy
Abnormal pressure
High -
Follow mud weight schedule. Adjust mud weight as needed.
weights required
Ensure adequate kick tolerance prior to drilling pay interval. Utilize
Stuck Pipe
Low
MPD to contain any pressure and prevent allowing an influx in the
even pressure is higher than expected.
Stuck Pipe
Low
Good hole cleaning, pre-treatment with lost circulation material,
stabilized BHA, proper mud weight.
Hole swabbing on trips
Moderate
Maintain appropriate trip speeds, proper hole filling (use of trip
sheets), pump out if required. Strip out with MPD.
Shale instability
Moderate
For the unstable HRZ and Kalubik shales, mitigate with higher mud
weight and proper tripping practices to avoid surging or swabbing.
Minimize pressure cycling by stripping out using MPD.
Lost circulation
Moderate
Reduce pump rates, adjust mud rheology, add LCM as required.
Manage ECD using MPD.
Hole swabbing on trips
Moderate
Manage trip speeds, proper hole filling (use of trip sheets), pump
out of hole.
6-3/4" Open Hole / 4-1/2" Liner Interval
Hazard
Risk Level
Mitigation Strategy
High ECD and swabbing with higher mud
Moderate
Condition mud prior to trips. Monitor ECD with PWD tool. Strip out
weights required
with MPD to mitigate swab.
Stuck Pipe
Low
Good hole cleaning, stabilized BHA, proper mud weight to
minimize differential sticking. Use PWD to monitor ECD.
Lost Circulation
Moderate
Use PWD to monitor hole cleaning. Reduce pump rates, adjust
mud rheology, and add LCM as required.
Hole Swabbing on Trips
Moderate
Manage trip speeds, proper hole filling (use of trip sheets), pump
out of hole. Use MPD to strip out of hole.
Abnormal Reservoir Pressure
High
Follow mud weight schedule. Adjust mud weight as required.
Ensure adequate kick tolerance prior to drilling pay interval. Utilize
MPD to contain any pressure and prevent allowing an influx in the
even pressure is higher than expected.
Attachment 5 - Wellhead and ' e
Kuparuk 11" MBS
3H-37
Note: Dimensional information reflected
on this drawing are estimated
measurements only
118.04"
10.19"
5.5f
T
13.62"
14.27"
Top Of Conductor
4-1/16" 5M RX -39
4-1/16" 5M
Hydraulic Act.
4-1/16" 5M RX -39
4-1/16" 10M BX -155,
CAMERON
t
N
A Schlumberger Company
28.31
12.00"
41.65"
99.96"
50.31"
8.00"
16.09"
11" 5M RX -54
26.39" �� 2.1/16" 5M R-24
15.75"
11" 5M RX -54
59.73"
24.81'=—� 2-1/16" 5M R-24
21.25"
171.69'
Surface Mandrel 6.64"
Load Ring 3.30"
20" Top Of Conductor
Surface On Emergency Slips 14.09"
F,0-3/4"
7-5/8"
4-1/z"
Schlumberger -Private
- Plat
27 26
AD665\501
ADL025524
IN
Well Pad
Well Trajectory
Open Interval
Active
Suspended
Plugged and Abandoned
CPAI Lease
ConocoPhillips
Naska
31-1-37 N
PTD Plat
0
12/12/2019
2
' 3I;p
0.2 0.4 0.6 08
--Wiles
1$1
9
OA 3H -10
1A
REV DATE I BY CK APP I DDESCRIPTIONIREVI
DATE BY CK APP DESCRIPTION
4 5/19/19 KDR I LGM I Updated Per K190005ACS 1 3 10/28/1 DHS I BGM I Per K11008811ACS
N
22 2 3�f�4) 19 ti 20'j 21`4 ,
3 b
27 26 25 rn 0� 293N 2$
w�
U)
Q
4 PROJECT 6 3t � 32
2 1
LOCATION Ti 3N
3 v T1 2N
—+
2 1 C 4 3J
11 12
•22
11 12 7 8 9
3124 *21
3 3 J'—� 'oi�falil
23:20
•19�
14 G'o rn 18 1 16 3
t3
27118
t5
3B
•17
0:16
VICINITY MAP
28:15
1"= 2 MILES
•14
•13
•12
25e11
DS3H
9810
-------
9
2607
569
3604
NOTES:
03
1. BASIS OF LOCATION AND ELEVATION IS DS3H
MONUMENTATION PER LOUNSBURY & ASSOC.
02
2. ALASKA STATE PLANE AND GEODETIC COORDINATES
•1
ARE, ZONE 4, N.A.D. 27.
0—�— 35
3. ELEVATION ARE B.P.M.S.L.
4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED
SECTIONS 12, TOWNSHIP 12 NORTH, RANGE 8 EAST,
UMIAT MERIDIAN, ALASKA.
5. DATE OF SURVEY 3/15/19, 5/7/19 & 5/18/19
STAKED IN FIELD BOOK L19-19—P020 L19-19—PG51
L19-20—PG61.
6. ALL DISTANCES SHOWN ARE GROUND.
LEGEND
O• ASBUILT CONDUCTOR LOCATION
• EXISTING CONDUCTOR LOCATION
GRAPHIC SCALE
)( ABANDONED CONDUCTOR LOCATION
o 75 iso
soo
�-- _
LOUNSBURY
1 inch = 150 ft.
& ASSOCIATES, INC.
SURVEYORS ENGINEERS PLANNERS
AREA: 3H MODULE: XXXX UNIT: D3
ConocoPhilli SDS3H
WELL CONDUCTORS
Alaska, Inc.
ASBUILT LOCATION
CADD FILE N0.
LK6308d40 4/26/ 08
DRAWING N0.
CEA—D3HX-6308D40
PART:
1,, of 3 ,
REV:
4,
14 15/19/191 KDR I LGM I I Updated Per K190005ACS 13 110/28/11I DHS I BGM I jPer K110081ACS
CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 12,
T. 12 N., R. 8 E., UMIAT MERIDIAN
* CONDUCTOR ASBUILT THIS SURVEY
** PLUGGED AND ABANDON
10 LOUNSBURY
& ASSOCIATES, INC.
SURVEYORS ENGINEERS PLANNERS
44
AREA: 3H MODULE: XXXX UNIT: D3
ConocoPhilli S DS31-1
WELL CONDUCTORS
Alaska, Inc. ASBUILT LOCATION
CADD FILE N0.NG N0. PART: REV:
LK6308d4O 4/26/08 CEA-D3HX-6308D40 2 of 3 4
DRAWI
NAD 27
ASP Coordinates
NAD 27
Geographic Coordinates
Section
Offset
Elev.
Well
No.
Y
X
Lot.
Long.
F.N.L
F.W.L.
O.G.
PAD
0
6000562.90
498655.23
N 70' 24' 45.979"
W 150' 00' 39.425"
1094
281
33.8
37.8
1
6000110.73
498655.44
N 70' 24' 41.531"
W 150' 00' 39.416"
1546
281
34.0
38.8
2
6000135.51
498655.43
N 70' 24' 41.775"
W 150' 00' 39.416"
1522
281
34.0
38.8
3
6000160.57
498655.39
N 70' 24' 42.022"
W 150' 00' 39.418"
1497
281
33.9
38.7
4
6000185.28
498655.43
N 70' 24' 42.265"
W 150' 00' 39.417"
1472
281
33.8
38.7
**5
6000210.66
498655.47
N 70' 24' 42.514"
W 150' 00' 39.416"
1446
281
33.7
38.8
6
6000235.50
498655.40
N 70' 24' 42.759"
W 150' 00' 39.418"
1422
281
33.7
38.8
7
6000260.34
498655.41
N 70' 24' 43.003"
W 150' 00' 39.418"
1397
281
33.6
38.9
8
6000285.82
498655.44
N 70' 24' 43.253"
W 150' 00' 39.417"
1371
281
33.6
38.7
9
6000310.30
498655.45
N 70' 24' 43.494"
W 150' 00' 39.417"
1347
281
33.6
38.6
10 1
6000335.43
498655.44
N 70' 24' 43.741"
W 150' 00' 39.417"
1322
281
33.6
38.6
11
6000425.37
498655.44
N 70' 24' 44.626"
W 150' 00' 39.418"
1232
281
33.7
38.7
12
6000450.51
498655.38
N 70' 24' 44.873"
W 150' 00' 39.420"
1207
281
33.8
38.8
13
6000475.46
498655.42
N 70' 24' 45.119"
W 150' 00' 39.419"
1182
281
33.8
38.8
14
6000500.41
498655.43
N 70' 24' 45.364"
W 150' 00' 39.418"
1157
281
33.8
38.7
15
6000525.44
498655.41
N 70' 24' 45.610"
W 150' 00' 39.419"
1132
281
33.8
38.7
16
6000550.46
498655.47
N 70' 24' 45.856"
W 150' 00' 39.418"
1107
281
33.8
38.7
17
6000575.45
498655.55
N 70' 24' 46.102"
W 150' 00' 39.415"
1082
282
33.8
38.8
18
6000600.44
498655.59
N 70' 24' 46.348"
W 150' 00' 39.414"
1057
282
33.8
38.9
19
6000625.20
498655.52
N 70' 24' 46.592"
W 150' 00' 39.416"
1032
282
33.8
38.7
20
6000650.45
498655.49
N 70' 24' 46.840" 1
W 150' 00' 39.417"
1007
282
33.9
38.7
* CONDUCTOR ASBUILT THIS SURVEY
** PLUGGED AND ABANDON
10 LOUNSBURY
& ASSOCIATES, INC.
SURVEYORS ENGINEERS PLANNERS
44
AREA: 3H MODULE: XXXX UNIT: D3
ConocoPhilli S DS31-1
WELL CONDUCTORS
Alaska, Inc. ASBUILT LOCATION
CADD FILE N0.NG N0. PART: REV:
LK6308d4O 4/26/08 CEA-D3HX-6308D40 2 of 3 4
DRAWI
4 15/19/191 KDR I LGM I jUpdated Per K190005ACS 13 110/28/11I DHS I BGM I IPer K110081ACS
CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 12,
T. 12 N., R. 8 E., UMIAT MERIDIAN
* CONDUCTOR ASBUILT THIS SURVEY
** PLUGGED AND ABANDON
SURVEYOR'S CERTIFICATE
1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND
LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF
ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY
DONE BY ME OR UNDER MY DIRECT SUPERVISION AND
THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION
ARE CORRECT AS OF MAY 19, 2019.
LOUNSBURY
& ASSOCIATES, INC.
SURVEYORS ENGINEERS PLANNERS
10 ,,U
AREA: 3H MODULE: XXXX UNIT: D3
ConocoPhillips DS3H
WELL CONDUCTORS
Alaska, Inc. ASBUILT LOCATION
CADD FILE N0. DRAWING NO. PART: REV:
LK6308d40 4/26/08 CEA-D3HX-6308D40 3 OF 3 4
NAD 27
ASP Coordinates
NAD 27
Geographic Coordinates
Section
Offset
Elev.
Well
No.
Y
X
Lat.
Long.
F.N.L.
F.W.L.
O.G.
PAD
21
6000675.40
498655.63
N 70' 24' 47.085"
W 150' 00' 39.413"
982'
282'
33.9'
38.6'
22
6000700.42
498655.73
N 70' 24' 47.331"
W 150' 00' 39.411"
957'
282'
33.9'
38.6'
23
6000637.79
498655.28
N 70' 24' 46.715"
W 150' 00' 39.424"
1019'
281'
33.9'
38.4'
24
6000662.87
498655.38
N 70' 24' 46.962"
W 150' 00' 39.421"
994'
281'
33.9'
38.0'
25
6000437.54
498655.50
N 70' 24' 44.746"
W 150' 00' 39.416"
1220'
281'
33.7'
37.7'
26
6000272.70
498654.81
N 70' 24' 43.124"
W 150' 00' 39.435"
1384'
281'
33.6'
38.2'
28
6000537.92
498655.52
N 70' 24' 45.733"
W 150' 00' 39.416"
1119'
282'
33.8'
37.9'
31
6000687.91
498655.24
N 70' 24' 47.208"
W 150' 00' 39.425"
969'
282'
33.9'
38.5'
32
6000612.94
498655.63
N 70' 24' 46.471 "
W 150' 00' 39.413"
1044'
282'
33.8'
37.8'
33
6000588.21
498655.30
N 70' 24' 46.228"
W 150' 00' 39.423"
1069'
281'
33.8'
36.1'
34
6000725.46
498655.48
N 70' 24' 47.578"
W 150' 00' 39.418"
932'
282'
33.9'
36.4'
*35
6000095.70
498655.28
N 70' 24' 41.383"
W 150' 00' 39.421"
1561'
281'
34.0'
36.6'
*36
6000206.27
498655.61
N 70' 24' 42.471"
W 150' 00' 39.412"
1451'
281'
33.7'
36.2'
*37
6000297.70
498655.44
N 70' 24' 43.370"
W 150' 00' 39.416"
1359'
281'
33.6'
35.8'
98
6000322.88
498655.48
N 70' 24' 43.618"
W 150' 00' 39.416"
1334'
281'
33.6'
38.4'
99
6000223.16
498654.90
N 70' 24' 42.637"
W 150' 00' 39.432"
1434'
281'
33.7'
38.2'
* CONDUCTOR ASBUILT THIS SURVEY
** PLUGGED AND ABANDON
SURVEYOR'S CERTIFICATE
1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND
LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF
ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY
DONE BY ME OR UNDER MY DIRECT SUPERVISION AND
THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION
ARE CORRECT AS OF MAY 19, 2019.
LOUNSBURY
& ASSOCIATES, INC.
SURVEYORS ENGINEERS PLANNERS
10 ,,U
AREA: 3H MODULE: XXXX UNIT: D3
ConocoPhillips DS3H
WELL CONDUCTORS
Alaska, Inc. ASBUILT LOCATION
CADD FILE N0. DRAWING NO. PART: REV:
LK6308d40 4/26/08 CEA-D3HX-6308D40 3 OF 3 4
PCL XL error
Error: ILLegaLOperatorSequence
Operator: ReadImage
Position: 307
Loepp, Victoria T (CED)
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Wednesday, February 19, 2020 4:11 PM
To: Loepp, Victoria T (CED)
Cc: Rixse, Melvin G (CED)
Subject: RE: [EXTERNAL]KRU 3H-37(PTD 219-194) Anti -collision 3H-24
Attachments: 31-1-37_Intermediate section -Min LOT.pdf, 3H-37_lntermediate section_14.7ppg
LOT -Kick Tolerance.pdf, 3H -37 -Intermediate section_13.9ppg LOT -Kick Tolerance.pdf
Follow Up Flag: Follow up
Flag Status: Flagged
Hi Victoria,
Please see the attached kick tolerance calculations. The absolute minimum LOT is 13.6 ppg EMW (assumes we take a
kick from 3H-24 at the 11507' MD/5219' TVD with a pore pressure of 12.1 ppg EMW). This only gives a kick tolerance of
2.2 bbis so realistically, we would be looking for at least a 13.9 ppg EMW which yields a kick tolerance of 13.4 bbls (see
attached). I also calculated the kick tolerance using the LOT from 3H-37 which was 14.7 ppg EMW. In this case, the kick
tolerance would be 45.7 bbls.
Thanks,
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Wednesday, February 19, 2020 2:56 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>
Subject: [EXTERNAL]KRU 3H-37(PTD 219-194) Anti -collision 31
Marti,
Please provide calculations for the minimum SC shoe FIT requ
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loepp(a)alaska.gov
1
071191- 0
CONFIDENTIALITY NOTICE: This e-mail messo,.;, including any attachments, contains informatio , m 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 Victoria Loepp at (907)793-1247 or Victoria.Loepo@alaska.aov
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Tuesday, February 18, 2020 11:02 AM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.Eoy>
Subject: RE: [EXTERNAL]KRU 3H-37(PTD 219-194) Anti -collision 3H-24
Hi Victoria,
We no longer have a TCR sheet like we used to. Our risk assessments consist of a discussion between the engineer,
engineering supervisor, engineering manager and chief engineer where we go through the risks and mitigations and
agree our path forward. Below are the main points we discussed for 3H-37:
Our plan is to TD the intermediate section on 3H-37 in the Kuparuk A sand which we expect is likely
overpressured; therefore, setting a plug in 3H-24 will not eliminate the risk of taking a kick while drilling the
intermediate section. We've designed the well plan to account for the scenario where we drill into elevated
pressure in the Kuparuk so the anti -collision risk does not impact how we plan to drill this interval. We will have
MPD so that we maintain constant bottom hole pressure and to manage any elevated pressure. In the event we
take a kick, we will shut-in on the annular and weight up as required as we did on 3G-27. Our plan would be to
weight up as required so that we can drill to TD on MPD and then preform a drawdown test at TD to confirm the
pore pressure and determine our kill weight. We would carry -out the same steps if we took a kick from
penetrating 31-1-24.
I don't think that there would be any difficulty in setting a plug in 31-1-24. We just don't think that we gain
anything as it does not eliminate the risk of taking a kick from the potentially overpressured Kuparuk reservoir
while drilling the intermediate section on 3H-37.
• We will manage our distance from 3H-24 through regular surveys (we can increase the frequency if
required). We would expect to see magnetic interference on our tools before we got close enough to hit 3H-24.
• 3H-24 is still shut-in and the pressure has decreased since January (12.4 ppg on 01/29/20). The latest SBHP was
12.1 ppg EMW (taken on 02/15/20). We anticipate that it will continue to decrease and will be even lower when
we drill the intermediate section on 3H-37.
Please let me know if you still have any questions. I don't think I did a great job explaining everything in my last
email. I'm still waiting on the AOR plot you requested. I'll send it to you as soon as I receive it from Baker.
On a totally different note, we stated in the 3H-37 permit that we would have the diverter rigged up when we drill the
surface hole. Our field drilling supervisor contacted me yesterday and said that after looking at the pad layout on 3H, he
thinks that it would be very difficult to rig up the diverter on 37 as they would have to extend the diverter line out to get
past the flowlines so that it's not pointing directly at them. This would be very challenging as they appear to about the
same level as the conductor. In addition, extending the diverter line would put the production facilities within the 75'
radius of no ignition sources. Given that we just drilled the 3H-35 surface hole and didn't encounter any shallow
hazards, would it be possible to get a waiver for the diverter on 3H-37?
Thanks,
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Thursday, February 13, 2020 2:53 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Subject: [EXTERNAL]KRU 3H-37(PTD 219-194) Anti -collision 3H-24
Marti,
Please provide the following information related to the collision risk between KRU 3H-37 and KRU 3H-24:
1. TCR analysis/risk analysis.
2. Outline the sequence of events if collision did occur and a 2.2-2.5 ppg kick were to occur
3. Outline the difficulty with setting a deep plug in KRU 31-1-24.
Thanx,
Victoria
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Wednesday, February 12, 2020 9:48 AM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gou>
Subject: KRU 3H-37(PTD 219-194) Anti -collision - PTD Status
Hi Victoria,
We completed our risk assessment yesterday and agreed that we do not need to set a deep plug in 3H-24. Our
mitigation against the anti -collision risk is to use field referencing (IFR) and multi station analysis (MSA) for improved
wellbore positioning. It is extremely unlikely that we would ever penetrate the 3H-24 wellbore; however, if we did, we
would have to penetrate the 7" production casing and the 3-1/2" tubing before we were exposed to the pressure in the
well. The inner and outer annuli on 3H-24 are continuously monitored. Current pressures are 200 and 250 psi,
respectively. The well is currently shut-in and has been since October 2019. In addition, the anti -collision risk does not
increase the risk of encountering high pressure in the intermediate section on 3H-35 as we are already planning to drill
into the reservoir in this section (which is potentially overpressured as a result of offset injection, including 31-1-24). We
plan to utilize MPD to manage the pressure while drilling this interval.
Thanks,
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Tuesday, February 11, 2020 3:11 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>; Haggerty -Sherrod, Ann (Northland Staffing Services)
<Ann.Haggerty-Sherrod @contractor.conocophillips.com>
Subject: [EXTERNAL]KRU 3H-37(PTD 219-194) Anti -collision - PTD Status
Marti,
What is the current status of this information?
Victoria
From: Loepp, Victoria T (CED)
Sent: Wednesday, February 5, 2020 1:22 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>; Haggerty -Sherrod, Ann (Northland Staffing Services)
(Ann.Haggerty-Sherrod@contractor.conocophillips.co ) <A,)n.Haggerty-Sherrod@contractor.conocophillips.com>
Subject: KRU 3H-37(PTD 219-194) Anti -collision - PTD Status
Ann,
In response to your inquiry about the status of this PTD, I am waiting on information as outlined below before the PTD is
submitted for approval.
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loepp a()alaska.gov
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 Victoria Loepp, at (907)793-1247 or Victoria. Loeppi alaska.gov
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Tuesday, February 4, 2020 8:51 AM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Subject: KRU 3H-37(PTD 219-194) Anti -collision
Hi Victoria
I'm still waiting on my supervisor to review it. I'll let you know as soon as it's complete.
Thanks
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Tuesday, February 04, 2020 8:41 AM
To: Titus, Marti N -phillips.com>
Subject: [EXTERNAL]KRU 3H-37(PTD 219-194) Anti -collision
Marti,
Let me know the status of this assessment.
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loepp(dialaska.goy
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 Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska_gov
From: Titus, Marti N <Marti.N.Titus conocophillips.com>
Sent: Wednesday, January 29, 2020 9:43 AM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Subject: RE: [EXTERNAL]KRU 3H-37(PTD 219-194) Anti -collision
Hi Victoria,
Our mitigation will be based on the outcome of our risk assessment. If we're able to minor risk the well, then we will
not need to set a deep plug. The depth of concern (11507 ft MD) is in the intermediate section on both wells (10625' MD
on 31-1-24). The 7" intermediate casing on 3H-24 had good cement across this interval (confirmed with CBL) and we are
-540 ft away (center -to -center) at this depth.
I'll let you know the outcome of our risk assessment. I'm hoping to complete it today and have an answer by early next
week.
Thanks
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Tuesday, January 28, 2020 11:28 AM
To: Titus, Marti N <N" 'Hct), ,.;c .;)hillips.com>
Subject: [EXTERNAL]KRU 3H-37(PTD 219-194) Anti -collision
Marti,
Well KRU 3H-24 appears to fail major risk with the drilling KRU 31-1-37. Will a deep plug be set in this injector? What
mitigation measures will be in place?
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loepp aa)alaska.gov
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 Victoria Loepp at (907)793-1247 or
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Tuesday, January 28, 2020 9:26 AM
To: Loepp, Victoria T (CED) < ;c u of@@alas_ka.gov>
Subject: RE: [EXTERNAL]Re: 3H-37 Permit to Drill
Thanks Victoria.
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Tuesday, January 28, 2020 9:20 AM
To: Titus, Marti N <Marti.N.Titus conocophillips.com>
Subject: [EXTERNAL]Re: 3H-37 Permit to Drill
Next few days -
Sent from my iPhone
On Jan 28, 2020, at 8:39 AM, Titus, Marti N <Marti.N.Titus@conocophillips.com> wrote:
Hi Victoria,
Happy New Year. I hope you iiad a great holiday. I wanted to check on tht status of the 3H-37 Permit to
Drill application that I submitted before Christmas. Could you please send me an update?
Thanks
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
Kick Tolererance.As
Well: 1 31-1-37 Intermediate Hole <== Data Input
Name: I / Titus . / I — Data Input
Mud Weiaht'h=) / 1 10.20
Weak point or LOT - Measured depth (ft)
Weak point or LOT True vertical depth (ft)
Weak point or LOT - Hole angle (deg)
Weak point or LOT - Hole size (in)
Weak point pressure or LOT - EMW (ppg)
3,360'
2,970'
54.00
11.000"
13.90
Weak Pt to Zone of Interest distance (MD ft):
Zone of interest - Measured depth (ft)
Zone of interest - True vertical depth (ft)
Zone of interest - Hole angle (deg)
Zone of interest - Hole size (in)
Zone of interest - Pore pressure EMW (ppg)
11,507'
5,219'
75.00
1 .000"
t 12.10 1
V1bha
V1 dp
V1
Gas gradient (psi/ft) 0.10
VWp
Bottom hole assembly OD (in) 6.750"
Bottom hole assembly length (ft) 200'
Drill pipe OD (in) 5.000"
V2
BHA annular vol. @ zone of interest (bbl/ft)
DP annular vol. @ zone of interest (bbl/ft)
DP annular vol. @ weak point bbl/ft
0.0733
0.0933
0.0933
Additional safetv marain (psi) 0.00
Weak point pressure (psi):
Weak point pressure - Safety margin:
PIO
Pmax
Pmax EMW
Max anticipated formation pressure (psi):
Pf
Weak Pt to Zone of Interest distance (TVD ft):
OH (TVD)
Weak Pt to Zone of Interest distance (MD ft):
OH (MD)
Maximum influx height at the bit (TVD ft):
H (TVD)
Maximum influx height at the bit (MD ft):
H (MD)
Calc. volume of (H) around BHA:
Caic. volume of {H) around drill pipe:
Calc. volume that H equals @ initial shut in:
V1bha
V1 dp
V1
Calc. vol. that H equals @ weak point (MD ft):
VWp
Calc. volume of Vwp 0 initial shut in:
V2
Kick Tolerance: V2
TE:
2/19/2020 4:08 PM
— Data Input
— Data Input
— Data Input
— Data Input
— Data Input
— Data Input
— Data Input
— Data Input
— Data Input
— Data Input
— Data Input
— Data Input
<== Data Input
— Data Input
— Data Input
2,147 psi
2,147 psi
13.90 ppg
3,284 psi
2,249'
8,147'—'
130'
501'
94.7 bbl
28.1 bbl
42.7 bbl
20.6 bbl
13.4 bbl
13.4 bbl
revised
M
FA
W` 31-f –Z+
)� ) PP9
-/�i5 ii for 3o-3-4
S2 19 7✓x�
Kick Tolererance.xls
Well:
Name:
31-1-37 Intermediate Hole
— Data Input
2,100 psi
Titus
— Data Input
2,100 psi
13.60 ppg
Mud Weight (ppg)
10.20
<_= Data input
Weak point or LOT - Measured depth (ft)
3,360'
<_= Data Input
Weak point or LOT True vertical depth (ft)
2,970'
<_= Data Input
Weak point or LOT - Hole angle (deg)
54.00
<_= Data Input
Weak point or LOT - Hole size (in)
11.0001,
<_= Data Input
Weak point pressure or LOT - EMW (ppg)
13.60
<_= Data Input
Zone of interest - Measured depth (ft)
11,507'
<_= Data Input
Zone of interest - True vertical depth (ft)
5,219'
<_= Data Input
Zone of interest - Hole angle (deg)
75.00
<_= Data Input
Zone of interest - Hole size (in)
11.0001,
<_= Data Input
Zone of interest - Pore pressure EMW (ppg)
12.10
<_= Data Input
Gas gradient (psi/ft)
0.10
<_= Data Input
Bottom hole assembly OD (in)
6.750"
<_= Data Input
Bottom hole assembly length (ft)
200'
<_= Data Input
Drill pipe OD (in)
5.0001.
<_= Data Input
BHA annular vol. @ zone of interest (bbl/ft)
0.0733
DP annular vol. @ zone of interest (bbl/ft)
0.0933
DP annular vol. weak point bbl/ft
0.0933
Additional safety margin (psi)
0.00
<_= Data Input
2/19/2020 3:58 PM
Weak point pressure (psi):
PIO
2,100 psi
Weak point pressure - Safety margin:
Pmax
Pmax EMW
2,100 psi
13.60 ppg
Max anticipated formation pressure (psi):
Pf
3,284 psi
Weak Pt to Zone of Interest distance (ND ft):
OH (TVD)
2,249'
Weak Pt to Zone of Interest distance (MD ft):
OH {MD)
8,147'
Maximum influx height at the bit (TVD ft):
H (TVD)
22'
Maximum influx height at the bit (MD ft):
H {MD)
85'
Calc. volume of (H) around BHA:
Calc. volume of (H) around drill pipe:
Calc. volume that H equals @ initial shut in:
V1bha
V1 dp
V1
6.2 bbl
0.0 bbl
6.2 bbi
Calc. vol. that H equals @ weak point (MD ft):
VWp
3.5 bbi
Calc. volume of Vwp @ initial shut in:
V2
2.2 bbi
I Kick Tolerance: V2 2.2 bbl
revised by. G. S. Walz
Kick Tolererance.xis
Well: 31-1-37 Intermediate Hole
<== Data Input
— Data Input
Name: Titus
<_= Data Input
2,270 psi
Mud Weight (ppg)
10.20
<_= Data Input
Weak point or LOT - Measured depth (ft)
3,360'
<_= Data Input
Weak point or LOT True vertical depth (ft)
2,970'
<_= Data Input
Weak point or LOT - Hole angle (deg)
54.00
<== Data Input
Weak point or LOT - Hole size (in)
11.000"
— Data Input
Weak point pressure or LOT - EMW (ppg)
14.70
— Data Input
Calc. volume of {H) around BHA:
Calc. volume of (H) around drill pipe:
Calc. volume that H equals @ initial shut in:
V1 bha
V1 dp
V1
14.7 bb(
131.5 bbl
146.1 bbl
Calc. vol. that H equals @ weak point (MD ft):
VWp
Zone of interest - Measured depth (ft)
11,507'
— Data Input
45.7 bbl
Zone of interest - True vertical depth (ft)
5,219'
— Data Input
Zone of interest - Hole angle (deg)
75.00
<== Data Input
Zone of interest - Hole size (in)
11.000"
— Data Input
Zone of interest - Pore pressure EMW (ppg)
12.10
— Data Input
=gradientsi/ft)
0.10
<_= Data Input
Bottom hole assembly OD (in)
6.750"
<_= Data Input
Bottom hole assembly length (ft)
200'
<_= Data Input
Drill pipe OD (in)
5.0001,
<_= Data Input
2/19/2020 4:00 PM
BHA annular vol. @ zone of interest (bbl/ft)
DP annular vol. @ zone of interest (bbl/ft)
DP annular vol. @ weak point bbl/ft
Additional safety margin (psi)
0.0733
0.0933
0.0933
0.00
— Data Input
Weak point pressure (psi):
PIO
2,270 psi
Weak point pressure - Safety margin:
Pmax
Pmax EMW
2,270 psi
14.70 ppg
Max anticipated formation pressure (psi):
Pf
3,284 psi
Weak Pt to Zone of Interest distance (TVD ft):
OH (TVD)
2,249'
Weak Pt to Zone of Interest distance (MD ft):
OH {MD)
8,147'
Maximum influx height at the bit (TVD ft):
H (TVD)
417'
Maximum influx height at the bit (MD ft):
H {MD)
1,610'
Calc. volume of {H) around BHA:
Calc. volume of (H) around drill pipe:
Calc. volume that H equals @ initial shut in:
V1 bha
V1 dp
V1
14.7 bb(
131.5 bbl
146.1 bbl
Calc. vol. that H equals @ weak point (MD ft):
VWp
66.1 bbi
Calc. volume of Vwp @ initial shut in:
V2
45.7 bbl
Kick Tolerance: V2 45.7 bbl
revised by. G. S. Walz
Well:
Name:
KRU 3H-37
Mud Weight (ppg)
Weak point or LOT - Measured depth (ft)
Weak point or LOT True vertical depth (ft)
Weak point or LOT - Hole angle (deg)
Weak point or LOT - Hole size (in)
Weak point pressure or LOT - EMW (ppg)
nc vi 111tV3=*L - —FL11 JILY
ne of interest - True vertical depth (ft)
ne of interest - Hole angle (deg)
ne of interest - Hole size (in)
ne of interest - Pore pressure EMW (a
— Data Input
— Data
1
1
12.
<== Data Input
— Data Input
<== Data Input
<== Data In
<----15a-ta Input
<_= Data Input
<== Data Input
— Data Input
— Data Input
— Data Input
— Data Input
Bottom hole assembly OD (in)6.8"
<== Data Input
Bottom hole assembly length (ft)
200' <_= Data Input
Drill pipe OD (in)
5.000" <== Data Input
Max anticipated formation pressure (psi):
Pf
BHA annular vol. @ zone of interest (bbl/ft)
0.0733
OH {TVD}
DP annular vol. @ zone of interest (bbl/ft)
0.0933
OH {MD)
DP annular vol. 0 weak point (bbl/ft)
0.0933
H (TVD)
— Data Input
Weak point pressure (psi):
PIO
2,147 psi
Weak point pressure - Safety margin:
Pmax
Pmax EMW
2,147 psi
13.90 ppg
Max anticipated formation pressure (psi):
Pf
3,283 ps°
Weak Pt to Zone of Interest distance (TVD ft):
OH {TVD}
2,247'
Weak Pt to Zone of Interest distance (MD ft):
OH {MD)
8,146'
Maximum influx height at the bit (TVD ft):
H (TVD)
130'
Maximum influx height at the bit (MD ft):
H {MD)
503'
Calc. volume of (H) around BHA:
Calc. volume of (H) around drill pipe:
Calc. volume that H equals @ initial shut in:
Vlbha
V1dp
V1
14.7 bbl
28.2 bbl
42.9 bbl
Calc. vol. that H equals @ weak point (MD ft):
VWp
20.6 bbl
Calc. volume of Vwp @ initial shut in:
V2
13.5 bbl
Kick Tolerance: V2 13.5 bbl
Collision with 3H-24 at 11506' MD
Boyer, David L (CED)
From: Loepp, Victoria T (CED)
Sent: Wednesday, February 19, 2020 8:36 AM
To: Boyer, David L (CED)
Subject: KRU 3H-37(PTD 219-194) Diverter waiver?
G
1!e
�� — y n u 1/Y1
David,
ct / u
b6 o w k 'its 3 K- 3
Please see the highlighted area below where CPAI is asking for a diverter waiver. I have not sent this PTD for approval
yet. Could you please take a look and see if we would consider granting a diverter waiver? In the past, we have looked
at wells with SC shoes within a 500' radius and whether or not there were gas shows while drilling the surface hole.
Thanx,
Victoria
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Tuesday, February 18, 2020 11:02 AM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Subject: RE: [EXTERNAL]KRU 3H-37(PTD 219-194) Anti -collision 3H-24
Hi Victoria,
We no longer have a TCR sheet like we used to. Our risk assessments consist of a discussion between the engineer,
engineering supervisor, engineering manager and chief engineer where we go through the risks and mitigations and
agree our path forward. Below are the main points we discussed for 3H-37:
Our plan is to TD the intermediate section on 3H-37 in the Kuparuk A sand which we expect is likely
overpressured; therefore, setting a plug in 3H-24 will not eliminate the risk of taking a kick while drilling the
intermediate section. We've designed the well plan to account for the scenario where we drill into elevated
pressure in the Kuparuk so the anti -collision risk does not impact how we plan to drill this interval. We will have
MPD so that we maintain constant bottom hole pressure and to manage any elevated pressure. In the event we
take a kick, we will shut-in on the annular and weight up as required as we did on 3G-27. Our plan would be to
weight up as required so that we can drill to TD on MPD and then preform a drawdown test at TD to confirm the
pore pressure and determine our kill weight. We would carry -out the same steps if we took a kick from
penetrating 31-1-24.
I don't think that there would be any difficulty in setting a plug in 31-1-24. We just don't think that we gain
anything as it does not eliminate the risk of taking a kick from the potentially overpressured Kuparuk reservoir
while drilling the intermediate section on 31-1-37.
We will manage our distance from 3H-24 through regular surveys (we can increase the frequency if
required). We would expect to see magnetic interference on our tools before we got close enough to hit 31-1-24.
• 3H-24 is still shut-in and the pressure has decreased since January (12.4 ppg on 01/29/20). The latest SBHP was
12.1 ppg EMW (taken on 02/15/20). We anticipate that it will continue to decrease and will be even lower when
we drill the intermediate section on 31-1-37.
Please let me know if you still have any questions. I don't think I did a great job explaining everything in my last
email. I'm still waiting on the AOR plot you requested. I'll send it to you as soon as I receive it from Baker.
On a totally different note, we statea in the 3H-37 permit that we would have the aiverter rigged up when we drill the
surface hole. Our field drilling supervisor contacted me yesterday and said that after looking at the pad layout on 3H, he
thinks that it would be very difficult to rig up the diverter on 37 as they would have to extend the diverter line out to get
past the flowlines so that it's not pointing directly at them. This would be very challenging as they appear to about the
same level as the conductor. In addition, extending the diverter line would put the production facilities within the 75'
radius of no ignition sources. Given that we just drilled the 3H-35 surface hole and didn't encounter any shallow
hazards, would it be possible to get a waiver for the diverter on 3H-37?
Thanks,
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Thursday, February 13, 2020 2:53 PM
To: Titus, Marti N <Marti.N.Titus@conocop�com>
Subject: [EXTERNAL]KRU 3H-37(PTD 219-194) Anti -collision 3H-24
Marti,
Please provide the following information related to the collision risk between KRU 3H-37 and KRU 3H-24:
1. TCR analysis/risk analysis.
2. Outline the sequence of events if collision did occur and a 2.2-2.5 ppg kick were to occur
3. Outline the difficulty with setting a deep plug in KRU 3H-24.
Thanx,
Victoria
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Wednesday, February 12, 2020 9:48 AM
To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Subject: KRU 3H-37(PTD 219-194) Anti -collision - PTD Status
Hi Victoria,
We completed our risk assessment yesterday and agreed that we do not need to set a deep plug in 3H-24. Our
mitigation against the anti -collision risk is to use field referencing (IFR) and multi station analysis (MSA) for improved
wellbore positioning. It is extremely unlikely that we would ever penetrate the 3H-24 wellbore; however, if we did, we
would have to penetrate the 7" production casing and the 3-1/2" tubing before we were exposed to the pressure in the
well. The inner and outer annuli on 3H-24 are continuously monitored. Current pressures are 200 and 250 psi,
respectively. The well is currently shut-in and has been since October 2019. In addition, the anti -collision risk does not
increase the risk of encountering high pressure in the intermediate section on 3H-35 as we are already planning to drill
into the reservoir in this section (which is potentially overpressured as a result of offset injection, including 31-1-24). We
plan to utilize MPD to manage the pressure while drilling this interval.
Thanks,
Marti
Davies, Stephen F (CED)
From: Titus, Marti N <Marti.N.Titus@conocophilIips.com>
Sent: Monday, December 30, 2019 7:39 AM
To: Davies, Stephen F (CED)
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Attachments: 3H-35 Quick Look_FINAL_18Dec19.pdf
Hi Steve
The reason for the abnormal reservoir pressure is injection on offset wells. The wells have been shut in since October
161h as we prepare to drill 3H-35 (planned spud is mid January). We anticipate that the pressure will continue to decline
as we're still producing from the other 3H wells and the injectors remain shut-in. However, I wanted to include the
"worst case" scenario in the permit since we're not positive exactly what the pressure will level off at prior to drilling 3H-
37. Below is a summary of the latest shut-in bottom hole pressures from the offset injectors.
We plan to utilize MPD to manage wellbore stability and reservoir ressure (if required). We will have all necessary mud
products available to weight up as required. e drilled two similar wells on the 3G pad this past summer and were able
to manage the abnormal pressure without any issues. I've attached a copy of the one page summary for 3H-35 which
includes the estimated pore pressures and frac gradients for the entire well. 3H-37 should look pretty much the
same. It will be updated prior to drilling to reflect the actual pressures we see on 3H-35. This will at least give you an
idea of our planned mud program based on what we think the reservoir pressure is today.
The risk of H2S is minimal. We will have the appropriate alarms and sensors on the rig though as we have on previous
wells. Again, these are very similar to the 3G wells we drilled earlier in 2019 and everyone was required to where
sensors when they went outside on the rig. .
Yes, the well will be hydraulically fractured and the Sundry Application will be submitted as required
Please let me know if you have any other questions. I'll be in and out of the office today and then out for the rest of the
week so I may be a little slow to respond but will get back to you as soon as I can.
Thanks
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Sent: Friday, December 20, 2019 2:31 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Shut-in Pressure (EMW)
Injectorrr
August 2019
10/31/19 12/05/19
12/16/19
3H-24
14.6
13.3 11.6*
12.2
3H-18
13.3
12.5 11.7
11.6
3H-15
11.6
12.1 11.8
11.3
We plan to utilize MPD to manage wellbore stability and reservoir ressure (if required). We will have all necessary mud
products available to weight up as required. e drilled two similar wells on the 3G pad this past summer and were able
to manage the abnormal pressure without any issues. I've attached a copy of the one page summary for 3H-35 which
includes the estimated pore pressures and frac gradients for the entire well. 3H-37 should look pretty much the
same. It will be updated prior to drilling to reflect the actual pressures we see on 3H-35. This will at least give you an
idea of our planned mud program based on what we think the reservoir pressure is today.
The risk of H2S is minimal. We will have the appropriate alarms and sensors on the rig though as we have on previous
wells. Again, these are very similar to the 3G wells we drilled earlier in 2019 and everyone was required to where
sensors when they went outside on the rig. .
Yes, the well will be hydraulically fractured and the Sundry Application will be submitted as required
Please let me know if you have any other questions. I'll be in and out of the office today and then out for the rest of the
week so I may be a little slow to respond but will get back to you as soon as I can.
Thanks
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Sent: Friday, December 20, 2019 2:31 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
3H-35 (wp04) Kuparuk A-Sand Injector
Plan
MD/TVD
Geo Tops
Casing/Cement
Hole/Casing Size
Mud
Pore Pressure / Frac
Pressure
BHAs
Notes
0 Inc 90
MD/TVD
5 7 9 11 13 15
KOP
20" Conductor
'
13-1/2" Mill
300' MD
1 5"/l0oft
8.6-9.6 ppg
(
(Hughes Hu hes
VM-3) +.8°
Cameron 11"
MBS Wellhead
119'
13-1/2" hole
19° Inc
1670/1635
Base Perm
TOC @ surface
Spud Mud
8.7 12.5 '
Xtreme Motor
+MWD+LWD
331' azi
500' of tail
ppg ppg
I
(GR/Res) +
DS
3.5"2.813 DS
I
GWD
FMC SkTree
3'/100ft
Nipple-2000' MD
2554/2468
GLM@^'2600' MD
(2500' TVD)
West Sak
Surface CsR
37°inc
3004/2857
30-3/4" 45.5# L-80
I
5" DP
331' azi
Hydril S63
Trip Wt. 9.6
3'/1006
3379/3134
---
3157/2976
----------------
ppg
---------------------------�
• ----•-------------
I
------------
Camp SS
9-7/8" x 11"
75° inc
hole
i
9-7/8" PDC
Casing will be
GLM@-4800'MD
I
(Hughes
set in top of
(3700'TVD) -75°
I
D505TX) +
reservoir
5882/3982
C-50
3-1/2" 9.3# L-80
Hydril 563Tbg
I
13.0- 1
AutoTrak RSS +
11" Rhino
underreamer+
14.5 I
MWD +LWD
GLM@-8200'MD
9.6-10.2 ppg
PPg I
(GR/Res)+
7407/4383
(4600' TVD) `75°
LSND WBM
I
PWD
C-35
11174/5374
TOC @ 10223' MD
(5124' TVD)
8.7
11581/5481
Moraine119
G
(250'TVD above
top Moraine)
ppg
12345/5682
nti
Top HRZ
1
5" DP
12444/5708
Fault
14.0-14.SI
Upper Kalubik
D
3.5",2.75" D Nipple
12600' MD (5750'
TVD), -75-
PPB I
12497/5722
12960/5832
75° inc
KS - Lower
Liner hanger @
331' azi
Kalubik
"13407' MD
3'/100ff
13254/5871
Fu
Int Cs
13292/5874
Kuparuk
7-5/8" 29.7# L-80
Hydril 563
Trip Wt. -11.7
J
10.0 - 12.2 I 113.0
90° inc
--13557/5883 --
----PPg-----
-- Ppg--- -- L_tPP9
314° azi
I I
Start at 10.2
10.0-12.2 I 113.0
0 2'/100ft
1 1
6-3/4" hole
ppg
ppg 1 1 PPB
6-3/4" PDC
SonicScope
5-3/4" x 4-1/2"
Swell Packer for
fault isolation
10.2-10.8 ppg
FloPro WBM
I I
I I
I I
I I
(Hughes
DD405T) +
AutoTrak eXact
RSS + MWD +
LWD
will be run in
memory to log
7-5/8" cement
I I
(GR/Res/Den/N
eu)+PWD +
SonicScope
Prod Liner
1 I
4-1/2" 12.6# L-80
89° inc
317' azi
1 1
Hydril 563
20156/5954
Trip Wt. TBD
1 I
4" DP
Davies, Stephen F (CED)
From: Davies, Stephen F (CED)
Sent: Friday, December 20, 2019 2:31 PM
To: Titus, Marti N
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Marti,
I notice that the estimated BHP in the Kuparuk is 3853 psi at 5928' TVD = 0.65 psi/ft = about 12.5 ppg EMW, and I notice
that the abnormal reservoir pressure risk is listed as "High" for the production hole interval. This is a bit concerning as
this well will be drilled one-half to 1 mile or more away from existing well control. What is the cause of this abnormally
high pressure? It appears that a PWD tool will be utilized, and the Drilling Hazards Summary mentions using MPD.
Correct? Will CPAI have mud components on hand at the drill site to increase the mud weight beyond the maximum
expected pressure? How far beyond? Could you also please provide expected pressures (in ppg EMW) for the various
formations that KRU 3H-37 will transect as CPAI drills down to the Kuparuk reservoir so that I can verify the planned mud
program for the entire well?
H2S is not mentioned in the Drilling Hazards Summary, but I notice that CPAI has measured from 90 to 500 ppm on
samples from 3H -Pad wells during 2018 and 2019. Is H2S anticipated? If not, why not? Will the rig have automatic
sensors and alarms? What mitigation measures will be taken?
And, from below: I notice that on the Permit to Drill form you have checked the "Yes" box next to "Hydraulic Fracture
planned?" If CPAI plans to frac this well, you'll have to request AOGCC's approval by submitting a separate Sundry
Application for that proposed frac'ing operation and providing all of the information specified within Regulation 20 AAC
Thanks,
Steve Davies
AOGCC
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 Steve Davies at 907-793-1224 or steve..davies alask�.�v.
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Friday, December 20, 2019 1:36 PM
To: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Subject: Re: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Thanks Steve. I have no idea what happened with the body of the permit. So strange. I'll email you the conductor
installation report which I think has exactly what you're looking for.
Thanks
Marti
Get Outlook for iOS
From: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Sent: Friday, December 20, 2019 1:32:07 PM
To: Titus, Marti N <Marti. N.Titus@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Hi Marti,
No, all that I have are a one-page cover letter signed by Chip, a Permit to Drill form (AOGCC Form 10-401), and six
attachments. No discussions or information regarding pressures (formation pressures, maximum downhole pressure, or
maximum potential surface pressure, abnormal pressures), and no casing and cementing, drilling, drilling fluids, or well
logging programs.
There is a land plat that shows the affected leases (thank you), but I'm also looking for a detailed surveyor's plat that
lists the Slot names / numbers and provides the ASP, Lat/Long, and Metes and Bounds coordinates (footages from
section lines) for each slot. Similar to the screen capture below.
Also, I notice that on the Permit to Drill form you have checked the "Yes" box next to "Hydraulic Fracture planned?" If
CPAI plans to frac this well, you'll have to request AOGCC's approval by submitting a separate Sundry Application for
that proposed frac'ing operation and providing all of the information specified within Regulation 20 AAC 25.283.
Thanks,
Steve Davies
AOGCC
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 Steve Davies at 907-793-1224 orsteve.davies(aalaska.Eov.
Davies, Stephen F (CED)
From: Titus, Marti N <Marti.N.Titus@conocophiIIips.com>
Sent: Friday, December 20, 2019 1:39 PM
To: Davies, Stephen F (CED)
Subject: Fwd: DS31-1 Asbuilt Conductors 35, 36 & 37
Attachments: LK6308d40-Signed.pdf
Get Outlook for iOS
From: NSK Survey Office Tech 3 <n1660@conocophillips.com>
Sent: Monday, May 20, 2019 8:14:53 AM
To: 2L Pad Co -Man <21padcm@conocophillips.com>; aka-dec@slb.com <aka-dec@slb.com>; Haggerty -Sherrod, Ann
(Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com>; Lehman, Nick R
<Nick.R.Lehman@conocophillips.com>; Lemke, Sandra D <Sandra.D.Lemke@conocophillips.com>; NSK AES Drlg Gen
Frmn <n2425@conocophillips.com>; NSK Fld Drlg Supv <n1335@conocophillips.com>; NSK Survey Office Tech 2
<n1336@conocophillips.com>; NSK Survey Office Tech 3 <n1660@conocophillips.com>; NSK Survey Prj Mgr
<nl305@conocophillips.com>; Ragbirsingh, Yosha M <Yosha.Ragbirsingh@bakerhughes.com>; Rohlfing, Jenaya J
<Jenaya.J.Rohlfing@conocophillips.com>; Soper, Michael K <Michael.Soper@bakerhughes.com>; Tai Sturdivant
<tai.sturdivant@bake rhughes.com>; Titus, Marti N <Marti.N.Titus@conocophillips.com>; Tolman, Ben V
<Ben.V.Tolman@conocophillips.com>; Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com>
Subject: DS31-1 Asbuilt Conductors 35, 36 & 37
To All,
Attached is the signed asbuilt for DS31-1 Conductors 35, 36 and 37.
Leon Moline
Lounsbury & Associates, Kuparuk
907-659-7276
907-659-7313
N1660@conocophillips.com
Davies, Stephen F (CED)
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Friday, December 20, 2019 1:19 PM
To: Davies, Stephen F (CED)
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Attachments: 3H-37 Permit to Drill.pdf
Hi Steve
Here is the main body of the permit. My apologies that it wasn't in the package that was submitted.
Thanks,
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Sent: Friday, December 20, 2019 12:07 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Thanks Marti.
The main body of the supporting documentation for this application was not submitted. All I have is a cover letter, the
Permit to Drill form (Form 10-401), and Attachments 1 through 6. There is no pressure information (formation
pressures, maximum downhole pressure, or maximum potential surface pressure), and no casing and cementing,
drilling, drilling fluids, or well logging programs in either copy. Could you please provide these items?
Thanks,
Steve Davies
AOGCC
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 Steve Davies at 907-793-1224 or steve.davies@alaska.&ov.
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Friday, December 20, 2019 11:52 AM
To: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Hi Steve,
Here is the text file. Please let me know if you need anything else.
Thanks
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Sent: Friday, December 20, 2019 2:24 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Subject: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Marti,
I'm reviewing CPAI's Permit to Drill Application for KRU 3H-37. It would speed my portion of AOGCC's review if CPAI
could provide the proposed directional survey data in either Excel spreadsheet or ASCII table format. Otherwise to load
the well into my geoscience workstation, I must scan the printed survey pages, process them with Optical Character
Recognition software, troubleshoot the results, and load the data.
Thank you.
Regards,
Steve Davies
Senior Petroleum Geologist
Alaska Oil and Gas Conservation Commission (AOGCC)
333 West 7 1 Avenue, Suite 100
Anchorage, Alaska 99501
907-793-1224
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 Steve Davies at 907-793-1224 or steve.davies(@alaska.gov
Davies, Stephen F (CED)
From: Davies, Stephen F (CED)
Sent: Friday, December 20, 2019 12:27 PM
To: 'Titus, Marti N'
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Marti,
In addition to the missing items below, could you also provide a surveyor's plat for the 3H -Pad (referencing NAD 27 if
available) that will allow me to confirm the surface location coordinate footages from section lines?
Thanks,
Steve Davies
AOGCC
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 Steve Davies at 907-793-1224 or steve.davie.s@alaska.pov.
From: Davies, Stephen F (CED)
Sent: Friday, December 20, 2019 12:07 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Thanks Marti.
The main body of the supporting documentation for this application was not submitted. All I have is a cover letter, the
Permit to Drill form (Form 10-401), and Attachments 1 through 6. There is no pressure information (formation
pressures, maximum downhole pressure, or maximum potential surface pressure), and no casing and cementing,
drilling, drilling fluids, or well logging programs in either copy. Could you please provide these items?
Thanks,
Steve Davies
AOGCC
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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov.
From: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Sent: Friday, December 20, 2019 11:52 AM
To: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Subject: RE: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Hi Steve,
Here is the text file. Please let me know if you need anything else.
Marti
Marti Titus
Staff Drilling Engineer
Office: 907-265-1192
Cell: 713-494-8198
From: Davies, Stephen F (CED) <steve.davies@alaska. >
Sent: Friday, December 20, 2019 2:24 PM
To: Titus, Marti N <Marti.N.Titus@conocophillips.com>
Subject: [EXTERNAL]KRU 3H-37 (PTD 2191940) - Request
Marti,
I'm reviewing CPAI's Permit to Drill Application for KRU 3H-37. It would speed my portion of AOGCC's review if CPAI
could provide the proposed directional survey data in either Excel spreadsheet or ASCII table format. Otherwise to load
the well into my geoscience workstation, I must scan the printed survey pages, process them with Optical Character
Recognition software, troubleshoot the results, and load the data.
Thank you.
Regards,
Steve Davies
Senior Petroleum Geologist
Alaska Oil and Gas Conservation Commission (AOGCC)
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
907-793-1224
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 Steve Davies at 907-793-1224 or steve.davies(aalaska.gov.
Remark:
AOGCC
PTD No. 219-193 Coordinate Check
20 December 2019
INPUT
Geographic, NAD27
OUTPUT
State Plane, NAD27
5004 - Alaska 4, U.S. Feet
MPU M-34 1/1
Latitude: 70 29 12.78500 Northing/Y: 6027765.651
Longitude: 149 43 25.94400 Easting/X: 533783.867
Convergence: 0 15 36.96326
Scale Factor: 0.999901297
Corpscon v6.0.1, U.S. Army Corps of Engineers
Conochillips
AWSka lmn
RANGER, 37 -
CONDUCTOR,
42-121
NIPPLE. 518
GAS LIFT,
2.130
j1 O SLEEVE -C,
V 11.588
PACKER,
11,635
NIPPLE, 11.651
SOS. 11
PRODUCTION.
2512,025
TD. 1
2.044
KUP 3H-24
all Attributes
Imax An le & MD VID
ihore APWWI
Fietd Name
Well Status
Incl l°) MO(RKB) AG B)
501032023500
KUPARUK RIVER UNIT
INJ
71.89 4,269.78 12,044.0
omen!
N23 (ppm) Dab
Annotation KB -Ord (R) Rig Rates- Data
3V: NIPPLE
jEftdDate
Last WO: 45.11 2!6/1996
rotation Depth ()t)(01 jEndDate Annobtlon
Last Mod _. End Data
1 Tag: R)(B 1 11,917.0 1 4/5/2009 Rev Reason: WELL REVIEW osbod 3/5/2012
ising Stain s
Ing
StringDescription String 0... String W... Top (ftKB)
Set Depth (t_. Set Depth (TVD) ... Siring WL.. SMng ._ String Top Thrd
NDUCTOR
16 15.062 42.0
121.0 121.0 62.58 H-40 WELDED
Ing Description
String O... String... Top(RKB)
Set Depth(f... Set Depth(TVD)... String Wt.. String._ String Top Thrd
RFACE
9518 8.835 41.0
4,989.4 '3,134.9 40.00 L-80 BTC
Ing Descrlption
String O._ String 10._ Top (111(8)
Set Dapth (f... Set Depth (TVD) _. String Wt.. Strl _. String Top Thrd
DDUCTION
7 6.276 24.8
12,025.4 6,252.6 26.00 L-80 BTC -MOD
bino Strings
Mg Description
ShMg 0... Strirg 10... Top (RKB/
Sat Depth (f... Set E)5. t (TVD) _. Strirg WL.. String ... String Top Thrd
31NG
31/2 2.992 37.0
11,660.9 5,960.0 9.30 L-80 ABM-EUE
impletion Details
Top Depth
()
Top incl
I tftKBI (ftKB)
P) Imes Descriptor
Comment ID (In)
Comment
S�P ✓l5S v�'C � �^" " J
�°/3119 � 3 • 3
ISMITmlf"ll OVID)(RKB) I IrI I Make I ModN I IMI l t3ery I Type Type Type Va. Latch I Onl liRO"Q I Run Dam /Com...'
TRANSMITTAL LETTER CHECKLIST
WELL NAME: 3 7
PTD:
Development — Service _ Exploratory _ Stratigraphic Test Non -Conventional
FIELD: lC L n ��r ►,-tom 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 cau ht and 10' sam le 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
v1
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 da s after com letion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100
_ Well Name: KUPARUK RIV UNIT 31-1-37 _ _Program DEV Well bore seg ❑
PTD#: 2191940 Company ConocoPhillips Alaska, Inc. _ _ Initial Class/Type DEV /_PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑
Administration 1 Permit fee attached NA
i2
Lease number appropriate
Yes
Surface Location lies within AD_L0025531; Top Productive Interval lies -in ADL0025524;
13
Unique well name and number
Yes
TD lies in ADL0365501.
4
Well located in a defined pool
Yes
Kuparuk River Oil Pool_, governed by Conservation Order No. 432D
5
Well located proper distance from drilling unit boundary
Yes
CO 432D Rule 3: There shall be no restrictions as to well spacing except that no pay shall be opened in
6
Well located proper distance from other wells
Yes
a well closer than 500 feet to an external property line where ownership or landownership changes.
7
Sufficient acreage available in drilling unit
Yes
As planned, well conforms with_spacing_requirements.
8
If deviated, is wellbore plat included
Yes
Adequate tankage or reserve pit
9
Operator only affected party
Yes
25
10
Operator has appropriate bond in force
Yes
11
Permit can be issued without conservation order
Yes
Anti -collision fails major risk with 31-1-24 WI_both _in int section;will use MPD; 31-1-24 Sl w/ deep plug
Appr Date 112
Permit can be issued without administrative approval
Yes
Yes
,13
Can permit be approved before 15 -day wait
Yes
Drilling fluid program schematic & equip list adequate
SFD 12/20/2019 1
Max formation pressure is 3853 psig(12_.5 ppg EMW); will drill w/ 12.7 ppg EMW & use MPD to manage overpr_ess
VTL 2/20/2020
'29
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
MPSP is 3260 psig; will test BOPs to 3500 psig
16
Pre -produced injector: duration of pre -production less than 3 months (For service well only)
NA
Yes
17
Nonconven. gas conforms to AS31.05.0300.1_.A),(j_.2.A-D)
NA
Work will occur without operation shutdown
18
Conductor string provided _ _ _ _ _
Yes _ _ _
80' conductor set
Engineering
1
19
Surface casing protects all known USDWs
Yes
Surface casing set to 3360' MD
I20
CMT vol adequate to circulate on conductor & surf csg
Yes
178% excess
I21
CMT vol adequate to tie-in long string to surf csg
No
I22
CMT will cover -all known -productive horizons
No
Productive interval will be completed with uncemented liner w/ swell packers and frac sleeves
23
Casing designs adequate for C, T, B &_permafr_ost
Yes
I24
Adequate tankage or reserve pit
Yes
Rig has steel tanks; all waste to approved disposal wells
25
If a re -drill, has a 10-403 for abandonment been approved
NA
26
Adequate wellbore separation proposed
Yes
Anti -collision fails major risk with 31-1-24 WI_both _in int section;will use MPD; 31-1-24 Sl w/ deep plug
127
If-diverter required, does it meet regulations -
Yes
Diverter waiver granted per 20 AAC 25.035_(h)(2)
Appr Date
28
Drilling fluid program schematic & equip list adequate
Yes
Max formation pressure is 3853 psig(12_.5 ppg EMW); will drill w/ 12.7 ppg EMW & use MPD to manage overpr_ess
VTL 2/20/2020
'29
BOPEs,_do they meet regulation
Yes
30
BOPE press rating appropriate; test to (put psig in comments) -
Yes
MPSP is 3260 psig; will test BOPs to 3500 psig
31
Choke manifold complies w/API RP -53 (May 84)
Yes
32
Work will occur without operation shutdown
Yes
33
Is presence of H2S gas probable
Yes
H2S measures required
34
Mechanical condition of wells within AOR verified (For service well only)
NA_ -
35
Permit can be issued w/o hydrogen sulfide measures
No
3H -Pad_ wells are H2S-bearing. H2S measures are required. Rig has sensors and alarms.
Geology
36
Data presented on potential overpressure zones
Yes
Potential for overpressure due to nearby injection. MPD will be used to manage reservoir pressure
Appr Date
37
Seismic analysis of shallow gas zones
NA
and maintain wellbore stability. Components will be available to increase mud weight if needed.
SFD 12/30/2019
38
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Seabed condition survey if off -shore
NA
39
Contact name/phone for weekly progress reports [exploratory only]
NA_
Geologic Engineering Public
Commissioner: Date: Commissioner: Date mmissio Date
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