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HomeMy WebLinkAbout218-076DATA SUBMITTAL COMPLIANCE REPORT
1/9/2019
Permit to Drill
2180760 Well Name/No. KUPARUK RIV UNIT 3H-31AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20205-60-00
MD
14648
TVD 6101 Completion Date
8/17/2018 Completion Status 1-0I1-
Current Status 1 -OIL UIC No
REQUIRED
INFORMATION
Mud Log No ✓
Samples No
Directional Survey Yes
DATA
INFORMATION---------�
List of Logs Obtained: Gr/ Res
(from Master Well Data/Logs)
Well Log
Information:
Log/
Electr
Data
Digital
Dataset
Log Log Run Interval OH I
Type
Med/Frmt
Number Name
Scale Media No Start Stop CH
Received
Comments
j ED
C
29659 Digital Data
10320 14648
8/31/2018
Electronic Data Set, Filename: 31-1-31AL1
GAMMA RES.Ias
ED
C
29659 Digital Data
8/31/2018
Electronic File: 31-1-31AL1 21VID Final Log.cgm
ED
C
29659 Digital Data
8/31/2018
Electronic File: 3H-31AL1 51VID Final Log.cgm
ED
C
29659 Digital Data
8/31/2018
Electronic File: 31-1-31AL1 5TVDSS Final
ED
C
29659 Digital Data
8/31/2018
Electronic File: 31-1-31AL1 21VID Final Log.pdf
ED
C
29659 Digital Data
8/31/2018
Electronic File: 3H-31AL1 51VID Final Log.pdf
ED
C
29659 Digital Data
8/31/2018
Electronic File: 31-1-31AL1 5TVDSS Final Log.pdf
ED
C
29659 Digital Data
8/31/2018
Electronic File: 3H-31AL1 EOW - NAD27.pdf
ED
C
29659 Digital Data
8/31/2018
Electronic File: 31-1-31AL1 EOW - NAD27.bd
ED
C
29659 Digital Data
8/31/2018
Electronic File: 31-1-31AL1 Final Surveys TO
14648.csv
ED
C
29659 Digital Data
8/31/2018
Electronic File: 3H-31AL1 Final Surveys TO
14648.xlsx
ED
C
29659 Digital Data
8/31/2018
Electronic File: 31-1-31AL1 Survey Listing.bd
ED
C
29659 Digital Data
8/31/2018
Electronic File: 3H-31AL1 Surveys.txt
ED
C
29659 Digital Data
8/31/2018
Electronic File: 31-1-
31 AL1_25_tapescan_B H I_CTK.txt
ED
C
29659 Digital Data
8/31/2018
Electronic File: 31-1-
31 AL1 _5_tapescan_BHI_CTK.txt
ED
C
29659 Digital Data
8/31/2018
Electronic File: 31-1-31AL1_output.tap
ED
C
29659 Digital Data
8/31/2018
Electronic File: 31-1-31AL1 2MD Final Log.tif
ED
C
29659 Digital Data
8/31/2018
Electronic File: 3H-31AL1 SMO Final Log.tif
AOGCC
Pagel of 3
Wednesday, January 9, 2019
DATA SUBMITTAL COMPLIANCE REPORT
1/9/2019
Permit to Drill 2180760 Well Name/No. KUPARUK RIV UNIT 3H-31AL1
Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20205-60-00
MD 14648 TVD 6101 Completion Date 8/17/2018
Completion Status 1 -OIL Current Status 1 -OIL UIC No
[ED C 29659 Digital Data
8/31/2018 Electronic File: 3H-31AL1 5TVDSS Final 1-090—
-09 fLog
LogC 29659 Log Header Scans
0 0 2180760 KUPARUK RIV UNIT 3H-31AL1 LOG
HEADERS
ED C 29784 Digital Data
10/12/2018 Electronic File: 3H-31AL1 EOW - NAD27.pdf
ED C 29784 Digital Data
10/12/2018 Electronic File: 3H-31AL1 EOW - NAD27.txt
ED C 29784 Digital Data
10/12/2018 Electronic File: 3H-31AL1 EOW - NAD83.pdf
ED C 29784 Digital Data
10/12/2018 Electronic File: 3H-31AL1 EOW - NAD83.txt
Log C 29784 Log Header Scans
0 0 2180760 KUPARUK RIV UNIT 3H-31AL1 LOG
HEADERS
Well Cores/Samples Information:
Sample
Interval
Set
Name Start Stop
Sent Received Number Comments
INFORMATION RECEIVED
Completion Report ® Directional / Inclination Data
Mud Logs, Image Files, Digital Data Y /�A Core Chips Y /&
Production Test Informatid YY NA Mechanical Integrity Test Information Y / NA
Composite Logs, Image, Data Files (9 Core Photographs Y/10
Geologic Markers/Tops (' Y 1 Daily Operations Summary
0
Cuttings Samples Y/ 10 Laboratory Analyses Y / I�A�
COMPLIANCE HISTORY
Completion Date: 8/17/2018
Release Date: 7/5/2018
Description
Comments:
Date Comments
AOGCC Page 2 of 3 Wednesday, January 9, 2019
DATA SUBMITTAL COMPLIANCE REPORT
1/9/2019
Permit to Drill 2180760 Well Name/No. KUPARUK RIV UNIT 3H-31AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20205-60-00
MD 14648 TVD 6101 Coqpletion Date 8/17/2018 Completion Status 1-0I1- Current Status 1-0I1- c1 / UIC No
Compliance Reviewed B�'///�(/1�n ( Date:
AOGCC Page 3 of 3 Wednesday, January 9, 2019
B FUGHES
a GF company
To:
2 180 76
29784
Letter of Transmittal
Date: — — – ----
October 11, 2018
Meredith Guhl
AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska 99501
From:
Michael Soper/Yosha Ragbirsingh
Baker Hughes, a GE Company
795 East 94'h Avenue
Anchorage, Alaska 99515
Please find enclosed the directional survey data for the following well(s):
KUPARUK RIVER UNIT GREATER MOOSES TOOTH UNIT
3H -31A MT6-03PH
3H-31AL1 MT6-03
1H -21A MT6-05PB1 Gl \Q�
1H-21AL1 MT6-05PB2
1H-21AL2 I MT6-05 rr
IH-21AL2-01 MT6-05L1 POv�
MT6-08PB1 r`
MT6-08
(14) Total prints
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Note: Please feel free to send us an email in place of return mail.
Michael Soper, Baker Hughes, Project Engineer
Michael.Soper@BHGE.com
Yosha Ragbirsingh, Baker Hughes, Survey Manager
Yosha.Ragbirsingh@BHGE.com
ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kup2
Kuparuk River Unit
Kuparuk 3H Pad
3H-31AL1
50-103-20205-60
Baker Hughes INTEQ
Definitive Survey Report
20 August, 2018
BA ER
I UGHES
a GE company
21 8076
29784
ConocoPhillips
Baker Hughes INTEQ
Definitive Survey Report
Latitude:
Company: Conocc Phillips (Alaska) Inc.-Kup2-� _
Local Coordinate Reference:
Well 3H-31 �J
Project Kuparuk River Unit
TVD Reference:
31-1-31 @ 80.00usft (31-1-31)
Site: Kuparuk 3H Pad
MD Reference:
31-1-31 @ 80.00usft(3H-31)
Well: 31-1-31
North Reference:
True
Wellbore: 31-1-31
Survey Calculation Method:
Minimum Curvature
Design: 31-1-31
Database:
OAKEDMP2
Project
Kuparuk River Unit, North Slope Alaska, United States
Latitude:
70° 24'47.208 N
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-31
Well Position
-NI-S 0 00 usft
Northing:
6,000,687.91 usft
+El -W 0.00 usft
Easting:
498,655.24usft
Position Uncertainty
0.00 usft
Wellhead Elevation:
usft
Wellbore 3H-31AL1
Magnetics Model Name Sample Date
Design
Audit Notes:
Version:
Vertical Section:
BGGM2018 911/2018
3H-31AL1
1.0 Phase: ACTUAL
Depth From (TVD)
(usft)
80.00
Declination
(°)
16.92
Tie On Depth: 12,221.68
+WS +El -W
(usft) (usft)
0.00 0.00
BATWIs
HES
Direction
(°)
330.00
8202018 12.31:O1PM Page 2 COMPASS 5000.14 Build 85
f
4
Latitude:
70° 24'47.208 N
Longitude:
150° 0'39.425 W
Ground Level:
0.00 usft
Dip Angle
i
Field Strength
(nT)
i
80.91
57,441
Direction
(°)
330.00
8202018 12.31:O1PM Page 2 COMPASS 5000.14 Build 85
Baker Hughes INTEQ BA ER
ConocoPhilli s Definitive Survey Report ut
!!S
Company:
ConowPhillips (Alaska) Inc -Kup2
Local Co-ordinate Reference:
Well 31-1-31
Project:
Kuparuk River Unit
Map
TVD Reference:
31-1-31 @ 80.00usft (3H-31)
MD
Site:
Kuparuk 3H Pad
TVD
MD Reference:
31-1-31 @ 80.00usft (3H-31)
+E/ -W
Well:
31-1-31
North Reference:
True
Wellbore:
31-1-31
Survey Calculation Method:
Minimum Curvature
Easting
Design:
31-1-31
(usft)
(us
Database:
OAKEDMP2
(usft)
(usft)
Survey Program
Date
(ft)
(01100' )
(R)
I From
To
34741
6,082.95
6,002.95
Survey
Survey
(usft)
(usft)
Survey (Wellbore)
Tool Name
Description
Start Date
End Date
88.20
10,409.00
3H-31 (31-1-31)
GCT -MS
Schlumberger GCT multishot
1/12/2001
497,129.25
10,435.00
10,520.11
3H-31AMWD-INC(3H-31A)
MWD -INC ONLY
MWD -INC ONLY_FILLER
7/31/2018
8/1/2018
10,550.81
12,221.68
3H -31A MWD (31-1-31 A)
MWD
MWD -Standard
8/1/2018
8/7/2018
12,243.00
12,327.08
3H-31AL1 MWD -INC (3H-31AL1)
MWD -INC ONLY
MWD -INC -ONLY -FILLER
8/8/2018
8/8/2018
12,356.87
14,596.58
3H-31AL1 (3H-31ALi)
MWD
MWD -Standard
8/8/2018
8/15/2018
Survey
341.00
6,082.36
6,002.36
9,607.80
-1,551.05
6,010,295.03
8/20/2018 12:31:01PM
Page 3
Annotation
TIP
KOP
Interpolated Azimuth
Interpolated Azimuth
Interpolated Azimuth
COMPASS 5000.14 Build 85
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N1 -S
+E/ -W
DLS
Northing
Easting
Section
Survey Tool Name
(usft)
(us
(1)
(')
(usft)
(usft)
(usft)
(usft)
(ft)
(ft)
(01100' )
(R)
12,221.68
88.19
34741
6,082.95
6,002.95
9,506.36
-1,522.82
6,010,193.59
497,134.29
648
8,994.15
MWO(3)
12,243.00
87.34
345.22
6,083.78
6,003.78
9,527.05
-1,527.86
6,010,214.29
497,129.25
11.01
9,014.60
MWD -INC -ONLY (4)
12,270.48
90.40
34580
6,084.32
6,004.32
9,553.60
-1,534.92
6,010,240.83
497,122.20
11.16
9,041.12
MWD -INC -ONLY (4)
12,296.58
92.64
344.00
6,083.63
6,003.63
9,578.74
-1,54189
6,010,265.97
497,115.23
9.40
9,066.38
MWD-INC_ONLY(4)
12,327.08
92.12
341.00
6,082.36
6,002.36
9,607.80
-1,551.05
6,010,295.03
497,106.07
9.97
9,096.13
MWD -INC ONLY(4)
12,356.87
92.12
338.73
6,081.26
6,00126
9,635.75
-1,561.30
6,010,322.98
497,095.83
7.61
9,12545
MWD(5)
12,387.19
9064
335.10
6,080.53
6,000.53
9,663.63
-1,573.18
6,010,350.86
497,083.96
12.93
9,155.54
MWD (5)
12,417.15
88.56
33187
6,080.74
6,000.74
9,690.43
-1,586.55
6,010,377.66
497,070.59
12.82
9,18544
MWD (5)
12,456.03
90.34
331.52
6,081.11
6,001.11
9,724.65
-1,604.99
6,010,411.89
497,052.17
4.67
9,224.30
MWD (5)
12,506.10
89.33
32656
6,081.26
6,001.26
9,767.58
-1,630]4
6,010.454.81
497,026.43
10.11
9,274.34
MWD (5)
12,53906
89.91
32267
6,08148
6,00148
9,794.45
-1649.82
6,010,481,68
497,007.35
11.93
9,307.15
MWD (5)
12,570.43
89.66
319.11
6,081.59
6,001.59
9,818.79
-1,669.60
6,010,506.01
496,987.57
11.38
9,338.12
MWD (5)
12,600.10
87,08
313.79
6,082.44
6.002.44
9,840.27
-1,690.03
6,010,527.50
496,967.15
19.92
9,366.94
MWD l5)
12,631.31
88.44
316.26
6,08366
6,003.66
9,862.33
-1,712.07
6,010,54956
496,945.12
9.03
9,397.06
MWD(5)
12,665.93
88.16
316.37
6,08469
6,00469
9,887.36
-1,735.97
6,010,57459
496,921.23
0.87
9,430.69
MWO(5)
12,696.17
8600
320.87
6,085.70
6,005.70
9,910.03
-1,755.94
6,010,597.26
496,90126
14.88
9,460.31
MWD(5)
12,730.57
89.39
327.19
6,086.48
6,00648
9,937.85
-1776.13
6,010,625.08
496,881.08
18.81
9,494.49
MWD(5)
12,760.35
89.75
328.10
6,086.71
6,006.71
9,96380
-1,79287
6,010,650.24
496,865.15
3.29
9,524.25
MWD (5)
12,785.75
90.65
332.32
6.08662
6,60662
9,98504
-1,804.68
6,010,672.28
496,65253
16.99
9,54964
MWD (5)
8/20/2018 12:31:01PM
Page 3
Annotation
TIP
KOP
Interpolated Azimuth
Interpolated Azimuth
Interpolated Azimuth
COMPASS 5000.14 Build 85
Baker HughesINTEQF %E ER
COnocoPhillips Definitive Survey Report EE
Company:
Protect:
I Site
Well:
Wellbore
Design
survey
ConocoPhillips (Alaska) Inc. -Kup2
Kuparuk River Unit
Kuparuk 3H Pad
3H-31
3H-31
3H-31
Local Co-ordinate Reference:
TVD Reference:
MO Reference:
North Reference:
Survey Calculation Method:
Database:
Well 3H-31
3H-31 @ 80.00usft (3H-31)
3H-31 @ 80.00usft (3H-31)
True
Minimum Curvature
OAKEDMP2
Annotation I
820/2018 12:31:01PM Page 4 COMPASS 5000.14 Build 85
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/ -S
+E/ -W
Northing
Easting
DLS
Section
(usft)
( '1
(°)
(usft)
(usft)
1
usft
( )
(usft)
usft
(°1100')
Survey Tool Name
(ft)
(ft)
(ft)
12,810.74
91.69
335.51
6,085.11
6,006.11
10,007.48
-1,815.67
6,010,69471
496,841.56
1342
9,574.56
MWD(5)
12,658.07
92.37
332.97
6,084.43
6,004.43
10,050.07
-1,836.22
6,010,737.31
496,821.01
5.55
9,62173
MWD (5)
12,885.57
9163
329.93
6,08347
6,003.47
10,074.21
-1,849.36
6,010,761.45
496,807.88
11.37
9,64920
MWD (5)
12,92055
9191
32686
6,08239
6,002.39
10,103.99
-1,867.68
6,010,791.22
496,789.57
8.81
9,684.15
MWD(5)
12,958.05
90.37
324.78
6,081.64
6,001.65
10,135.00
-1,888.74
6,010,822.24
496,768.52
6.90
9,721.54
MWD (5)
12,987.84
88.95
323.76
6,081.82
6,001.82
10,159.18
-1,906.13
6,010,846.42
496,751.13
5.87
9,751.18
MWD (5)
13,019.09
87.91
317.73
6,082.68
6,002.68
10,183.36
-1,925.89
6,010,870.60
496,731.38
19.57
9,781.99
MWD (5)
13,049.98
87.02
313.07
6,084.05
6,004.05
10,205.33
-1,947.55
6,010,892.57
496,709.72
15.34
9,811.85
MWD (5)
13,08045
8767
313.44
6,065.46
6,005.46
10,226.18
-1,969.72
6,010,913.42
496,687.56
2.45
9,840.99
MWD (5)
13,110.37
88.53
310.83
6,086.45
6,006.45
10,246.24
-1,991.89
6,010,933.49
496,665.39
9.18
9,869.45
MWD (5)
13,139.97
88.93
312.14
6,087.09
6,007.09
10,265.85
-2,014.06
6,010,953.09
496,643.23
4.69
9,897.51
MM (5)
13,170.52
88.31
314.80
6,087.81
6,007.81
10,288.86
-2,036.22
6,010,974.10
496,621.07
8.96
9,926.79
MW (5)
13,199.90
87.39
314.10
6,088.91
6,008.91
10,307.41
-2,057.18
6,010,994.66
496,600.12
3.93
9,955.07
MWD (5)
13,229.85
87.94
318.86
6,090.13
6,010.13
10,329.11
-2,077.78
6,011,016.36
496,579.52
15.99
9,984.16
MWD (5)
13,259.96
88.07
320.66
6,091.18
6,011.18
10,352.08
-2,097.22
6,011,039.33
496,560.09
5.99
10,013.77
MWD (5)
13,290.12
88.37
321.80
6,092.12
6,012.12
10,375.58
-2,116.10
6,011,062.83
496,591.22
3.91
10,043.57
WO (5)
13,321.52
89.88
323.17
6,092.60
6,012.60
10,400.48
-2,135.22
6,011,087.74
496,522.11
6.49
10,074.69
MWD (5)
13,350.45
91.38
327.29
6,092.28
6,012.28
10,424.24
-2,151.71
6,011,11149
496,505.62
15.15
10,103.51
MWD (5)
13,382.28
90.55
325.74
6,091.74
6,011.74
10,450.78
-2,169.27
6,011.138.04
496,488.07
5.52
10,135.28
MWD (5)
13,409.94
91.41
325.36
6,091.27
6,011.27
10,473.59
-2,184.91
6,011,160.84
496,472.43
3.40
10,162.85
MWD(5)
13,442.91
90.64
320.76
6,09068
6,01068
10,499.93
-2,204.72
6,011,187.18
49645263
14.14
10,195.56
MN/D(5)
13,470.75
89.39
320.60
6,090.67
6,010.67
10,52147
-2,222.36
6,011,208.72
496,43560
4.53
10,223.04
MWD(5)
13,500]5
89.60
317.10
6,09094
6,01094
10,544.05
-2,242.10
6,011,231.31
496415.27
11,69
10,252.46
MWD (5)
13,529.76
91.41
31931
6,09068
6,01068
10,565.68
-2,261.43
6,011,25294
496395.94
9.85
10,280.86
MWD (5)
13,560.44
91.10
311.75
6,090.01
6,01061
10,587.55
-2,282.90
6,011,274.81
496374.48
24.66
10,310.53
MWD (5)
13,591.76
90.18
30998
6,089.66
6,009.66
10,608.04
-2,306.58
6,011,295.30
496,350.80
6.37
10,340.12
MWD (5)
13,61924
89.79
308.18
6,08967
600967
10,62536
-2,32791
6,011,312.63
496,329.47
6.70
10,365.79
MWD (5)
13,651,67
90.28
307.81
6,089.65
6,009.65
10,645.32
-2,353.47
6,011,332.59
49630392
1.89
10,395.86
MM (5)
13,680.90
8969
306.51
6,089.65
6,009.65
10,662.98
-2,376.76
6,011,350.25
496280.63
4.88
10,422.79
MWD (5)
13,725.38
88.31
299.25
6,09043
6,010.43
10,687.11
-2,414.09
6,011,374.38
496243.32
16.61
10,462.35
MWD(5)
13,745.58
87.45
301.34
6091.18
6.011.18
10,69729
-2,431.52
6,011,384.57
495,225.89
11.18
10479.88
MWD (5)
Annotation I
820/2018 12:31:01PM Page 4 COMPASS 5000.14 Build 85
Baker Hughes INTEQNEs
ConocoPhillips Definitive Survey Report ^
Company:
ConocoPhillips(Alaska) Inc.-Kup2
Project:
Kuparuk River Unit
Site:
Kupamk 3H Pad
Well:
31-1-31
Wellbore:
31-1-31
Design:
31-1-31
Survey
Local Co-ordinate Reference
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well 3H-31
31-1-31 @ 80.00usft (3H-31)
3H-31 @ 80.00usft (31-1-31)
True
Minimum Curvature
OAKEDMP2
DLS
(11100')
0.87
11.88
7,16
8.11
326
1004
1]25
1.07
11.86
1033
175
14.20
12,15
9,00
3,43
12,99
2.06
8.40
5.94
11.65
12.45
12.41
8.04
4.37
2.73
8,39
9.10
4,05
000
Vertical
Section Survey Tool Name
(ft)
10.506,81 MWD (5)
10,532.27 MWD (5)
10,561.47 MWD (5)
10,586.83 MWD (5)
10,614,03 MWD (5)
10,641.73 MWD (5)
10,669.76 MWD (5)
10,703.19 MWD (5)
10,734.62 MWD (5)
10,764.95 MWD (5)
10,795,92 MWD (5)
10,831.25 MWD (5)
10,850.79 MWD (5)
10,891.47 MWD (5)
10,920.62 MWD (5)
10,944.89
MWD (5)
10,975.40 MWD (5)
11,008.63 MWD (5)
11,034.90 MWD (5)
11,065.12 MAD (5)
11,094.59 VIM (5)
11,124.25 VIM (5)
11,153.79 MAD (5)
11,18631 MWD (5)
11,217.21 VIM (5)
11,247.21 VIM (5)
11,274.07 MWD(5)
11301.86 MWD(5)
11,351.02 PROJEC'
Annotation
8202018 12:31:01PM Page 5 COMPASS 5000.14 Build 85
Map
Map
MD
IncAzl
ND
NDSS
-NI-S
+E/ -W
Northing
Easting
(usft)
(1)
(1
(usft)
(usft)
(usft)
(usft)
(ft)
(ft)
13,77626
87.39
301.60
6,092.56
6,012.56
10,71329
-2,457.66
6011400.57
496,199.76
13,804.80
8721
30499
6,093.90
6,013,90
10,728.94
-2,48148
6,011,416.22
496,175.94
13,836.78
8825
307.03
6,095,17
6,015.17
10,74772
-2,507.33
6,011,435.01
496,150.10
13,864.58
88,59
304,80
6,095.94
6,01594
10,764,02
-2,52963
6,011,451.31
496,12760
13,894.64
89.57
304.83
6,09642
6,016.42
10,781.18
-2,554,51
6,011,46847
496,10293
13,924.90
88,77
307,76
6,096,86
6,016,86
10,799.09
-2,578.89
6,01148638
496,07855
13,954]1
89.69
312.82
6,09726
6,01726
10,818.36
-2,60162
6,011,50566
496,055,83
13,989.71
89,51
312,49
6,097.50
6,017.50
10,842.07
-2,62736
6,011,529.37
496,03009
14,022.34
89.79
316,35
6,097,70
6,017,70
10,864.91
-2,65066
6,011,55221
496,006.80
14,053.36
90,89
319.49
6,09752
6,017.52
10,887.93
-2,671.45
6,011,57523
495,98602
14,084.93
90.61
318.34
6,097,11
6,017.11
10,911.72
-2,692,19
6,011,599.02
495,96528
14,120.73
9135
323.37
6,096.49
6,016,49
10,939,47
-2,71418
6,011,626,78
495,942.70
14,150.40
92,58
326.76
6,09548
6,015.48
10,963.78
-2,731,76
6.011.651.08
495,925,73
14,181.12
91.69
329.38
6,094.33
6,014.33
10,98963
-2,747.99
6,011,677,13
495,909,50
14,210.28
91A1
330.34
6,093,54
6,01354
11,015,04
-2,762.63
6,011,70234
495,894,87
14,234,58
92.64
327.43
6,092.68
6,012.68
11,035,82
-2,775.18
6,011,723,13
495,882.33
14,265.15
9230
326.90
6,091,37
6,011,37
11,061,49
@,791.74
6,011,748,79
495,865,77
14,298.42
90.00
328.49
6,090.70
6.010.70
11,089.60
-2,809.51
6,011,776,90
495,848,00
14,324.71
89.91
326,93
6,090.72
6,010.72
11,111,82
-2,823.56
6,011,799,13
495,833.97
14,35504
89.02
323.51
6,031.00
6,011.00
11,136.73
-2,840.85
6,011,824.04
495,816,67
14,38484
87.97
31995
6,091.79
6,011.79
11,160.11
-2,859.30
6,011,847,42
495,79923
14,41462
88.83
32357
6,092.62
6,012.62
11,183.65
-2,877.85
6,011870,96
495,779,69
14,444,64
88.22
321.25
6,033.39
6,013.39
11,207.27
-2,896.03
6,011,894.58
495,76152
14,477.62
88.56
319.85
6,09432
6,014.32
11,232.72
-2,916.98
6,011,920,03
495,740.58
14,50906
8834
319.02
6,095.17
6,015,17
11,256.60
-2,937.42
6,011,943.91
495,720.15
14,539.78
87.45
316.60
6,096.30
6,016.30
11,279.34
-2,958,03
6,011,96666
495,699.54
14,56758
87,11
314.09
6,097.62
6,017.62
11,299.09
-2,977.55
6,011,986.41
495,680.03
14,596.58
87.73
313.03
6,038.92
6,018,92
11,319.07
-2,99853
6,012.00638
495,659,05
14,648.00
87.73
31309
6,100,96
6,020.96
11,354.17
-3,03605
6,012,041.49
495,621.54
DLS
(11100')
0.87
11.88
7,16
8.11
326
1004
1]25
1.07
11.86
1033
175
14.20
12,15
9,00
3,43
12,99
2.06
8.40
5.94
11.65
12.45
12.41
8.04
4.37
2.73
8,39
9.10
4,05
000
Vertical
Section Survey Tool Name
(ft)
10.506,81 MWD (5)
10,532.27 MWD (5)
10,561.47 MWD (5)
10,586.83 MWD (5)
10,614,03 MWD (5)
10,641.73 MWD (5)
10,669.76 MWD (5)
10,703.19 MWD (5)
10,734.62 MWD (5)
10,764.95 MWD (5)
10,795,92 MWD (5)
10,831.25 MWD (5)
10,850.79 MWD (5)
10,891.47 MWD (5)
10,920.62 MWD (5)
10,944.89
MWD (5)
10,975.40 MWD (5)
11,008.63 MWD (5)
11,034.90 MWD (5)
11,065.12 MAD (5)
11,094.59 VIM (5)
11,124.25 VIM (5)
11,153.79 MAD (5)
11,18631 MWD (5)
11,217.21 VIM (5)
11,247.21 VIM (5)
11,274.07 MWD(5)
11301.86 MWD(5)
11,351.02 PROJEC'
Annotation
8202018 12:31:01PM Page 5 COMPASS 5000.14 Build 85
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
a far �uO E.Y V Y.o�
SFP 14 2018
W
WELL COMPLETION OR RECOMPLETION REPORT AND LOG -'
1a. Well Status: OiI Q Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑
20AAC 25.105 20AAC 25.110
GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: i
1b. Well Class:
Development Q Exploratory ❑
Service ❑ Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Abend.: 8/17/2018
14. Permit to Drill Number/ Sundry:
218.076
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded:
8/10/2018
15, API Number: ,
50-103-20205-60-00
4a. Location of Well (Governmental Section):
Surface: 970' FNL, 282' FWL, Sec 12, T12N, RBE, UM
Top of Productive Interval:
1976' FNL, 186' FEL, Sec 34, T13N, RBE, UM
Total Depth:
176' FNL, 1693' FEL, Sec 34, T13N, RBE, UM
8. Date TO Reached:
8/14/2018
16. Well Name and Number:
KRU 3H-31AL1
9. Ref Elevations: KB:80
GL:39 BF:
17. Field / Pool(s):
Kuparuk River Field/Kuparuk River Oil Pool
10. Plug Back Depth MD/TVD:
N/A
18. Property Designation:
ADL 25524, ADL 25531
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 498666 y- 6000687 Zone- 4
TPI: x- 497129 y- 6010241 Zone- 4
Total Depth: x- 495621 y- 6012041 Zone- 4
11. Total Depth MD/rVD:
1464816101
19, DNR Approval Number:
LONS 84-134, LIONS 84149
12. SSSV Depth MD/rVD:
N/A
20. Thickness of Permafrost MOM D:
1746/1638
5. Directional or Inclination Survey: Yes Q (attached) No ❑
Submit electronic and printed information per 20 AAC 25.050
13. Water Depth, if Offshore:
1 N/A (ft MSL)
21. Re-drill/Lateral Top Window MD/TVD:
12243/6084
22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days
of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential,
gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and
perforation record. Acronyms may be used. Attach a separate page if necessary
GR./Res
23. CASING, LINER AND CEMENTING RECORD
WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT
CASING FT TOP BOTTOM TOP BOTTOM PULLED
SIZE CEMENTING RECORD PULLED
16 62.5 H40 Surface 121 Surface 121 24 200 sx AS 1
9.625 36 J-55 Surface 5023 Surface 3262 12.25 1100 sx AS III, 600 sx Class G
7 26 L-80 Surface 10712 Surface 6228 8.5 250 sx Class G
23/8 4.6 L-80 10317 14648 5925 6101 3 Slotted Liner
24. Open to production or injection? Yes Q No ❑
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):3
SLOTTED LINER @:
11245-14648 MD and 6075-6101 TVD GOIVIPLE i iUP,
/1,Was
APer
KIF DD
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD/rVD)
112 10337 1031115921
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
hydraulic fracturing used during completion? Yes EJNo ❑Q•
20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27. PRODUCTION PRODUCTION TEST
Date First Production:
8/20/2016
Method of Operation (Flowing, gas lift, etc.):
FLOWING
Date of Test:
8/24/2018
Hours Tested:
24hrs
Production for
Test Period
Oil -Bbl:
323
Gas -MCF:
159
Water -Bbl:
2146
Choke Size:
176
Gas -Oil Ratio:
0.49 MCF/bbl
Flow Tubing
Press. 208
JCasinq Press:
1 1,100
Calculated
124 -Hour Rate
Oil -Bbl:
Gas -MCF:
Water -Bbl:
21
Oil Gravity- API (corr):
1 24
Form 10-407 Revised 5/2017 ABDMS.4V`MP 14 201&ONTINUED ON PAGE 2 V7-1- ill?llcrl
Submit ORIGINAL on[
28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No [D
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): 30. FORMATION TESTS
NAME
MD
TVD Well tested? Yes ❑ No El
Surface If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Permafrost - Base
1746
1636 Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
12243
6084 information, including reports, per 20 AAC 25.071.
Formation @ TPI -Kuparuk A
TD
14648
6101
Formation at total depth:
Ku aruk A
31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontolooical report production or well test results. r 20 AAC 25.070.
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
_
Authorized Name: James Ohlin er Contact Name: Keith Herrin
Authorized Title: ff CTD In ineer Contact Email: Kekh.E.Herrin O co .com
Authorized /8 Contact Phone: 263-4321
Signature: Date: �3
INSTRUCTIONS
General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Form 10-407 Revised 5/2017 Submit ORIGINAL Only
31-1-31 Final CTD Schematic
16" 62# H40 shoe
Q 121' MD
36# J-55 shoe
KOP Q 10,435' MD
A -sand perfs squeezed
10,452'-10,494' MD
7" 26# L-80 shoe Q
10,712' MD
Upper Completion
3-12" 9 3M LA0 EUE 8rd Tubing to surface
3-12" DS nipple @ 488' RKB (2.812" min ID)
3-12" Carrico gas lift mandrels @ 10223' RKB
312" W-1 nipple @ 1027D RKB, 10286' PDC (2.81T' min ID)
Lower Completion
Baker KSH-22 Anchor Seal
Baker SAB -3 Permanent Paker @ 10311' RKB, 10307' PDC
3-12" D nipple @ 10327' RKB, 10323' PDC (2.80" ID)
Baker Shear Out Sub @ 10336 RKB, 10332' PDC
3H-31AL1 TD = 14648' MD
2-3/8" slotted/blank liner w/ 6' sealbore deployment sleeve
TOL = 10316' MD, BOL = 14648' MD
Blank liner 10316'- 11245'MD
3H
-31A TD = 14304' MD
�I72-3/8" slotted liner w/ aluminum billet
OL = 12243' MD, BOL = 14304' MD
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC
O vRILL11Y11 JIUC 1 RXi.rt�
End
Dur (hr)
2.50
Phase
MIRU
OP Cede
MOVE
Code
Tuna PJA
01 sfi0n
sled Depth
M)
End Deplh(ftKB)
p -
Attach Jeeps, prep for departure.
0.0
0.0
1.00
MIRU
MOVE
!MOB
P
Crew change, PJSM w Peak and
0.0
0.0
6.00
MIRU
MOVE
P
incoming crew, start move
Move rig from 1C-24 to the entrance
of 3H patl 15.5 miles, 6 hrs - 2.58 mph
0.0
0.0
7/15/2018
13:00
0.50
MIRU
MOVE
P
Drop jeeps, spot rig mat in front of
0.0
0.0
well, dbl check Vee valves, close
master. spot sills for backing in, meet
with pad op.
7/1512018
14'30
1.50
MIRU
MOVE
MOB
P
Spot sub over well. Very narrow pad,
0.0
0.0
trucks having a hard time pulling
forward very far. D8 dozer assist, set
mats, on jack, drop trucks. Tight
vertical clearance in the cellar.
7/15/2018
16:00
1.50
MIRU
MOVE
MOB
P
Spot service module. - trucks returned
0.0
0.0
to 1C for shop and 1/2 way house.
Tiger tank on location
7/15/2018
0.10
MIRU
MOVE
MOB
P
8pottiger-tank
0.0
16:06
"Note DTH crew called out, night
.0
0
crew, after 6:30 pm.
?/15/2018
16:36
2.50
MIRU
MOVE
RURD
P
Work RU check list, safe out
0.0
0.0
walkways. Cellar spill containment
1/16/2018
10:00
5.40
MIRU
WHDBOP
RURD
P
Nipple up BOPE, tighten flowcross
0.0
0.0
flanges, WU MP line. R/U tiger tank
line and air test, rig up putt, R/U
steam. Center stack. Install / prep reel
iron for circulating, install well name
sign on side of dg.
"' Check tree bolts (2 loose bottom of
master)
/16/2018
5:00
5.00
MIRU
WHDBOP
KURD
P
Continue installing CTC, re -head BHI
0.0
0.0
upper quick, pull test 35 k, install
lubricators w/new o -rings, connect
wash pipe, reconfigure test joint.
install mouse holes, retrieve RKB's
(16/2018
7:30
2.50
MIRU
WHDBOP
NUND
P
Crew change, grease valves, prep to
0.0
0.0
flood up.
"`Rig accept 05:00
'16/2018
3:48
2.30
MIRU
WHDBOP
BOPE
P
Flood up and shell test to 250/4200
0.0
0.0
psi, low high
Tests 1-7 - good
16/2018
).48
1.00
MIRU
WHDBOP
BOPE
P
09:50 - Test 8 - Pass fail - C7 leaking,
0.0
0.0
greased, rebuilt -
16/2018
i:30
4.70
MIRU
WHDBOP
BOPE
P
complete BOPE testing
0.0
0.0
'"' Swap to highline @ 14:18
16/2018
':30
2.00
MIRU
WHDBOP
RURD
P
PT ODS PDL and tiger tank line to
0.0
0.0
1600 psi -good.
16/2018
:30
1.00
PROD1
RPEQPT
OWFF
P
Check for pressure under master,
0.0
0.0
1,330 psi. IA 0, OA D psi. Bleed
wellhead to the tiger tank. Crew
change, Pressure remained at zero
with no flow, Open up to the stack,
obsery for flow - none
16/2018
:36
1.10
PROD1
RPEQPT
PULD
P
PJSM, PU BHA#1, straight motor with
0.0
99.0
ridge
set D331. Skid carl,stab on
6/2018
18
0.70 PROD1
RPEQPT
CTOP
P Inspect
and adjust goose neck post
99.0
99,0
swap
to 2" coil.
6/2018
30
1.20 PROD1
RPEQPT
TRIP
P
RIH
displacing well to seawater taking
99.0
5,096.0
retums
of the tiger tank.
Page 1129 Report Printed: 8I22I2018
Operations Summary (with Timelog Depths)
3H-31
NRINEW
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
sten Depth
Start Time
End Time
D. (W)
Phase
Op Coda
AcdNty Code
lime P -T -X
Common
(BKB)
End DepN(PoCB)
7/16/2018
7/16/2018
1.50
PROD1
RPEQPT
SVRG
P
Park, lock out reel, inspect injector
5,096.0
5,096.0
21:30
23:00
goose neck alignment, inspect reel
hubs, saddle clamps, torqe and
hammer up inner reel iron.
7/16/2016
7/17/2018
1.00
PROD1
RPEQPT
TRIP
P
Continue to RIH
5,096.0
9,551.0
23:00
00:00
7/17/2018
7/17/2018
0.20
PROD1
RPEQPT
DLOG
P
log formation correction (plus 127),
9,551.0
9,568.0
00:00
00:12
1
1
1 PUW 47 k
7/17/2018
7/17/2018
1.00
PROD1
RPEQPT
TRIP
P
Continue IH, tag possibly cement
9,568.0
10,207.0
00:12
01:12
Node @ 10,207' DHWOB=3 k, PUW
48 k (no -pump)
7/17/2018
7/1712018
2.00
PRODt
RPEQPT
TRIP
P
Bring pump up to 1.77 bpm at 4,409
10,207.0
10,327.6
01:12
03:12
psi, continue IH slowly to 10,220',
PUW 40 k, work down towards bottom
50' at a time, PUH circulating BU,
RBIH and continue 50' at a time.
7/1712018
7/17/2018
0.50
PROD1
RPEQPT
TRIP
P
PUH, while pumping BU, log gamma
10,327.6
9,515.0
03:12
03:42
1
1 for depth conlrot.
7/17/2016
7/17/2018
0.30
PROD1
RPEQPT
DLOG
P
Log gamma correction of plus 2.0'
9,515.0
9,575.0
03:42
04:00
7/17/2018
7/17/2018
0.30
PROD1
RPEQPT
TRIP
P
RIH
9,575.0
10,000.0
04:00
04:18
7/17/2018
7117/2018
0.30
PROD1
RPEQPT
DLOG
P
Log CCL, upload data to s:drive
10,000.0
10,320.0
04:18
04:36
7117/2018
7/17/2018
0.45
PROD1
RPEQPT
TRIP
P
PUH to log HRZ
10,320.0
9,875.0
04:36
05:03
7/17/2018
7/17/2018
0.30
PROD1
RPEQPT
DLOG
P
Log HRZ correction of minus 2.5'
9,875.0
10,053.0
05:03
05:21
7/1712018
7/17/2018
0.50
PROD1
RPEQPT
TRIP
P
PUH to log CCL
10,053.0
9,950.0
05:21
05:51
7/17/2016
7/17/2018
1.00
PROD1
RPEQPT
DLOG
P
Log CCL, upload data to s:drive
9,950.0
10,320.0
05:51
06:51
7/17/2018
7/1712018
0.25
PROD1
RPEQPT
TRIP
P
PUH, adjust gooseneck, bring pump
10,320.0
10,300.0
06:51
07:06
up 1.8 bpm at 4428 psi
7117/2018
7/17/2018
0.20
PROW
RPEQPT
TRIP
P
RBIH, tag at 10,327', DHWOB=7.2 k,
10,300.0
10,327.0
07:06
07:18
PUH tag second time DHWOB=3.2 k,
PUH
7/17/2018
7/17/2018
0.30
PROD1
RPEQPT
MILL
P
Mill ahead 1.8 bpm at 4,428 psi,
10,327.0
10,332.0
07:18
07:36
CTSW=15 k, DHWOB=0.7-1.3 k
7/17/2018
7117/2018
1.00
PROD1
RPEQPT
TRIP
P
POOH
10,332.0
2,611.0
07:36
08:36
7/17/2018
7/17/2016
0.56
PROD1
RPEQPT
SVRG
P
Inspect reel, tighten hub bolts
2,611.0
2,611.0
08:36
09:10
7/17/2016
7/1712018
0.30
PROW
RPEQPT
TRIP
P
POOH
2,611.0
1,014.0
09:10
09:28
7/17/2018
7/17/2018
0.80
PROW
RPEQPT
SVRG
P
Inspect reel again, tighten hub bolts
1,014.0
1,014.0
0928
10:16
again
7/17/2018
7/17/2018
0.25
PROD1
RPEQPT
TRIP
P
POOH
1,014.0
62.5
10:16
10:31
7/17/2018
7/17/2018
0.50
PROD1
RPEQPT
SFTY
P
At surface, check well for flow (no-
62.5
62.4
10:31
11:01
flow)
7/17/2018
7/17/2018
0.40
PROD1
RPEQPT
PULD
P
LD motor and mill, millling BHA #1
62.4
0.0
11:01
11:25
7/17/2018
7/17/2018
0.50
PROD1
RPEQPT
PULD
P
PU 0.9 ako motor and D331 slick
0.0
65.5
11:25
11:55
gauge mill, surface test Coiltrak tools
(good -test)
7/17/2018
7/17/2018
2.00
PROD1
RPEQPT
TRIP
P
Tag up reset counters, RIH w/Milling
65.5
9,550.0
11:55
13:55
BHA#2
7/17/2018
7117/2018
0.30
PROD1
RPEQPT
DLOG
P
Log the HRZ correction of plus 10'
9,550.0
9,996.0
13:55
14:13
Page 2129 ReportPrinted: 8122/2018
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
Dur (W)
Phaae
Op Code
Ac Ay Cade
Time P -T -K
operation
(PKB)
EM Depth (W13).
7/17/2018
7/17/2018
0.25
PROD1
RPEQPT
TRIP
P
Continue IH, dry tagging cement @
9,996.0
10,332.0
14:13
14:28
10,332', PUW 42 k
7/17/2018
7/17/2018
0.50
PROD1
RPEQPT
MILL
P
Bring pump up 1.77 bpm @ 4,375 psi,
10,332.0
10,365.0
14:28
14:58
mill ahead @ 82 fph, DHWOB=2.5 k
7117/2018
7/1712018
1.00
PROD1
RPEQPT
WPRT
P
Perform 3 cleanup passes from TT
10,365.0
10,365.0
14:58
15:58
down to TO 10,365'
7117/2018
7/17/2018
1.80
PROD1
RPEQPT
TRIP
T
POOH, w/closed EDC
10,365.0
55.0
15:58
17:46
7/17/2018
7/1712018
1.50
PROD1
RPEQPT
PULD
T
At surface, flow check well - Dead.
55.0
0.0
17:46
19:16
PJSM. Lay down BHA #2 pilot hole
mill with .9' AKO mill. Reconfigure
BHA
7/17/2018
7/17/2018
1.50
PROD1
RPEQPT
PULD
T
PJSM, PIU BHA#3 with Reeves 2 3/8"
0.0
77.7
19:16
20:46
under reamer, 2 118" WFT Motor and
pup joints. Make up to coil and surface
test - Good. Adjust gooseneck. Tag up
and set counters
7/17/2018
7117/2018
1.80
PRODI
RPEQPT
TRIP
T
Trip in hole BHA 93
77.7
9,515.0
20:46
22:34
7/17/2018
7117/2018
0.30
PRODi
RPEQPT
DLOG
T
Log gamma tie in for +6'correction
9,515.0
9,577.0
22:34
22:52
7/17/2018
7/17/2018
0.40
PROD1
RPEQPT
TRIP
T
Continue in well, Close EDC @
9,577.0
10,345.0
22:52
23:16
1
10000, PUW=41 K. Continue in hole
7/17/2018
7/1812018
0.72
PROD1
RPEQPT
UREM
T
Get to 10345. Bring on pumps 1.38
10,345.0
10,356.0
23:16
00:00
BPM @ 4035 PSI FS. Recip
underreamer to open blades. Under
ream up to below TT. Ream down
hole. No vibration on meter. few stalls
7/18/2018
7/1812018
0.10
PROD1
RPEQPT
UREM
T
Under reaming, 1.4 BPM @ 3985 PSI
10,356.0
10,367.0
00:00
00:06
FS, BHP=3615
7/18/2018
7/18/2018
3.50
PROD1
RPEQPT
UREM
T
Stall and restart @ 10367, 10,371,
10,367.0
10,370.0
00:06
03:36
PUW=48K, Slow going after end of
pilot hole with stalls, Try light
WOB <700 LBS
7/18/2018
7/18/2018
2.50
PROD1
RPEQPT
UREM
T
Able to work WOB up to 1.5K and
10,370.0
10,373.0
03:36
06:06
maintain, 1.4 BPM @ 3990 PSI FS,
continue to stall at 10,373', PUH, tool
rep recommended we pull to inspect
BHA
7/18/2018
7/18/2018
2.00
PROD1
RPEQPT
UREM
T
POOH, w/open EDC
10,373.0
98.0
06:06
08:06
7/18/2018
7/18/2018
0.50
PROD1
RPEQPT
UREM
T
At surface, check well for flow (no-
98.8
0.0
08:06
08:36
flow)
7/18/2018
7/1812018
0.30
PROD1
RPEQPT
UREM
T
LD BHA #3, upon inspection found
0.0
0.0
08:36
08:54
blades to be 5.0" OD, considable
amount of wear on the reamer body
and reamers.upload pictures to the
s:ddve.
7/18/2018
7/18/2018
5.80
PROD1
RPEQPT
WAIT
T
WOO, PJSM, wrap service loop,
0.0
0.0
08:54
14:42
perform various rig maintenance
operations
7/18/2018
7/18/2018
0.25
PROD1
RPEQPT
SFTY
T
BOT on location, load equipment onto
0.0
0.0
14:42
14:57
rig, PJSM
7/18/2018
7/18/2018
1.00
PROD1
RPEQPT
PULD
T
PU1MU Under reaming BHA, stab
0.0
77.1
14:57
15:57
UQS, surface lest BHI Coiltrak tools
(good -test), check pac-offs (good -
condition)
7/18/2018
7/18/2018
1.80
PROD1
RPEQPT
TRIP
T
Tag up, reset coutners, RIH w/ under
77.1
9,515.0
15:57
17:45
1
1
1
reaming -BHA #2,
7/18/2018
7/18/2018
0.30
PROD1
RPEQPT
DLOG
T
Gamma tie in for+7.5
9,515.0
9,580.0
17:45
18:03
Page 3/29 ReportPrinted: 812 212 01 8
y ZZI Operations Summary (with Timelog Depths)
3H-31
...
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
scan Depth
Start Time I
End Tima
Dur (hr)
Phew
Op Code
Activdy Cods
Tire P -T -X
Opemfion
(III®)
End Depth(IIKB)
7/18/2018
7118/2018
0.50
PROW
RPEQPT
TRIP
T
Continue in well, Wt check @ 10300
9,580.0
10,346.0
18:03
18:33
4K, Shut EDC
7/18/2018
7118/2018
3.20
PROD1
RPEQPT
UREM
T
Bring on pumps 1.8 BPM and stall,
10,346.0
10,337.0
18:33
21:45
PUH bring on pumps 1.5 BPM @
4200 PSI FS. Start reciping 10345 to
10335 working reamer open. Unable
to ream lack down past 10343. Shut
down pump and pick up into tubing to
close blades. Run dry to get into pilot
hole stack out 10343. Make several
attemps to ease into 10343 with rapid
stalls
7/18/2018
7/1812018
0.80
PROM
RPEQPT
UREM
T
Consult town, go to 10337 with pumps
10,337.0
10,343.0
21:45
22:33
on @ 1.7 BPM @ 4730 PSI free spin
for 30 minutes. Ream down slowly.
Stall @ 10343
7/1812018
7/19/2018
1.45
PROD1
RPEQPT
UREM
T
PUH to tubing. RBIH dry to 10374,
10,343.0
10,344.0
22:33
00:00
1
PUH to 10350. Start working reamer
blades open
7/19/2018
711912018
0.40
PROD1
RPEQPT
UREM
T
Reaming, 1.77 BPM @ 4872 PSI FS,
10,344.0
10,346.0
00:00
00:24
BHP=3670
7/19/2018
7/1912018
1.60
PRODt
RPEQPT
UREM
T
Stall / Restart 1.77 BPM @ 4873. Still
10,346.0
10,347.0
00:24
02:00
having stalling problems @ 10343'
7119/2018
7/19/2018
1.80
PROD1
RPEQPT
UREM
T
Recip 10339 to 10347 Stalls
10,347.0
10,347.0
02:00
03:48
7119/2018
7/19/2018
0.70
PROD1
RPEQPT
UREM
T
10347 Ream down 1.6 BPM @ 4260
10,347.0
10,360.0
03:48
04:30
PSI FS - not going. Run in pilot hole
and back ream up
7/19/2018
7/19/2018
1.50
PROD?
RPEQPT
UREM
T
Back ream up past bad spot, stalling
10,360.0
10,337.0
04:30
06:00
7/1912018
7119/2018
0.25
PROD1
RPEQPT
UREM
T
Ream down slowlly 1.8 bpm at 5,031
1
10,337.0
10,341.0
06:00
06:15
psi
7/19/2018
7119/2018
1.80
PROD1
RPEQPT
UREM
T
Notice high vibration on BHA, POOH
10,341.0
77.1
06:15
08:03
to inspect BHA, open EDC
-A#
7/19/2018
7/1912018
1.00
PRODt
RPEQPT
UREM
T
Check well for flow, LD reaming UH
77.1
0.0
08:03
09:03
4
7/192018
71192018
0.25
PRODt
RPEOPT
UREM
T
Upload photo's of lost blade and under
0.0
0.0
09:03
09:18
reamer to s:drive
7/192018
7119/2018
2.70
PROM
RPEQPT
UREM
T
Stand by for orders
0.0
0.0
09:18
12:00
7/192018
7/19/2018
0.50
PROD1
RPEQPT
UREM
T
Tools on location, load into pipeshed,
0.0
0.0
12:00
12:30
PJSM, check well for flow (no -flow)
7/192018
7/19/2018
0.50
PROD1
RPEQPT
UREM
T
MU Venturi BHA# 5, stab INJH,
0.0
55.2
12:30
13:00
surface test BHI tools (good -test)
7/19/2018
7/19/2018
1.50
PROD1
RPEQPT
UREM
T
RIH, w/ventud and G -force up/down
55.2
9,550.0
1300
14:30
jars, BHA#5
7/19/2018
7/19/2018
0.20
PROD1
RPEQPT
UREM
T
Log the formation for depth control
9,550.0
9,537.0
14:30
14:42
1 correction of plus 7.5'
7/19/2018
7/19/2018
0.30
PRODi
RPEQPT
UREM
T
Continue IH
9,537.0
10,335.0
14:42
15:00
7/19/2018
7/19/2018
0.50
PROD1
RPEQPT
UREM
T
Perform 4 passes (10,335'-103766)
10,335.0
10,375.0
15:00
15:30
7/192018
7/19/2018
1.70
PROD1
RPEQPT
UREM
T
POOH, pumping 1.08 bpm at 2,720
10,370.0
55.2
15:30
17:12
psi
7/19/2018
7/19/2018
0.30
PROD1
RPEQPT
UREM
T
PJSM, check well for flow, Lay down
55.2
0.0
17:12
17:30
BHA#5. Venturi full of metal and some
cement sheath. No under reamer
pieces
7/19/2018
7119/2018
1.00
PROD1
RPEQPT
UREM
T
Reconfg BHA, Crew change
0.0
0.0-
17:30
18:30
Page 4/29 Report Printed: 8/2212018
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
stet Tme
End Time
Dwav)
Phase
Op Code
Acting Code
Time P -T -X
Operation
(ftKB)
End Depth(W(B)
7/19/2018
7/19/2018
0.30
PROD1
RPEQPT
UREM
T
PJSM. BHA#6 Re run venturi. Make
0.0
55.2
18:30
18:48
up to coil and surface test. Tag up and
set counters
7/19/2018
7/19/2018
1.70
PROD1
RPEQPT
UREM
T
Trip in venturi BHA #6 with EDC open
55.2
9,500.0
18:48
20:30
7/19/2018
7/19/2018
0.30
PROD1
RPEQPT
UREM
T
Log Gamma lie in for +7' correction,
9,500.0
9,555.0
20:30
20:48
Close EDC
7/19/2018
7/19/2018
0.30
PRODt
RPEQPT
UREM
T
Continue in hole to bottom
9,555.0
10,374.0
20:48
21:06
7/19/2018
7/19/2018
0.50
PROD1
RPEQPT
UREM
T
Tag bottom, Bring pumps online 2
10,374.0
10,374.0
21:06
21:36
BPM @ 4885 PSI, Recip-40'4 times
7/19/2018
7/19/2018
1.80
PROD1
RPEQPT
UREM
T
Trip out of well
10,374.0
55.0
21:36
23:24
7/19/2018
7/20/2018
0.60
PROD1
RPEQPT
UREM
T
At surface, PJSM stand back BHA #6.
55.0
0.0
23:24
00:00
Have 2 keeper pins and finger hinge
pin in full venturi
7/20/2018
7/20/2018
0.60
PROD1
RPEQPT
UREM
T
Continue clean and inspect venturi
0.0
55.0
00:00
00:36
basxet. Make up to coil trak. Make up
Ito coil and surface test
7/20/2018
7/20/2018
1.60
PROD1
RPEQPT
UREM
T
Trip in well BHA#7 Venturi basket,
55.0
9,500.0
00:36
02:12
EDC open
7/20/2018
7/2012018
0.30
PROD1
RPEQPT
UREM
T
Log Gamma tie in for +7'correction
9,500.0
9,554.0
02:12
02:30
720/2018
7/20/2018
0.40
PROD1
RPEQPT
UREM
T
Continue in hole, Stop @ 10059 and
9,554.0
10,375.0
02:30
02:54
close EDC, Weight check @ 10290 @
44K
7/20/2018
7/202018
0.60
PROD1
RPEQPT
UREM
T
Tag bottom, Bring pumps online 2
10,375.0
10,375.0
02:54
03:30
BPM @ 4890 PSI Recip 4 times up to
10330
7/202018
7/20/2018
1.60
PROD1
RPEQPT
UREM
T
POOH
10,375.0
79.0
03:30
05:06
7120/2018
7202018
0.75
PROD1
RPEQPT
UREM
T
At surface, PJSM, Lay down BHA#7,
79.0
0.0
05:06
05:51
Under reamer blade recovered in
venturi alomg with much less debris
7/202018
720/2018
1.00
PROD1
RPEQPT
UREM
T
Inspect tools, MU Ventrui run 05,
0.0
55.2
05:51
06:51
BHA# 8
7/202018
720/2018
1.75
PROD1
RPEQPT
UREM
T
RIH
55.2
9,500.0
06:51
08:36
720/2018
720/2018
0.20
PRODi
RPEQPT
UREM
T
Log formation correction of plus 6.0'
9,500.0
9,540.0
08:36
08:48
7/20/2018
7/20/2016
0.20
PRODi
RPEQPT
UREM
T
Continue IH, PUW @ 10,300'(46 k)
9,540.0
10,375.0
08:48
09:00
720/2018
7/2012018
0.50
PROD1
RPEQPT
UREM
T
Tag bottom, bring pumps online 2.0
10,375.0
10,330.0
09:00
09:30
bpm at 4,890 psi, Recip 4 times up to
10,330'
7/202018
7/20/2018
1.50
PROD1
RPEQPT
UREM
T
POOH
10,330.0
55.2
09:30
11:00
7/202018
7/202018
0.30
PROD1
RPEQPT
UREM
T
PJSM, check well for flow (no -flow)
55.2
55.2
11:00
11:18
7/20/2018
7120/2018
0.50
PROD1
RPEQPT
UREM
T
LD, and inspect Venturi basket, found
55.2
0.0
11:18
11:48
hand full of cement cuttings and trace
of metal.
7/20/2018
7/20/2018
3.50
PROD1
RPEQPT
UREM
T
Wait on Caliper from Deadhorse.
0.0
0.0
1148
15:18
7/20/2018
7/20/2018
1.00
PROD1
RPEQPT
UREM
T
PDS, tool hand arrived on location, put
0.0
0.0
15:18
16:18
hand thru CDR3 orientation, PJSM,
program tools.
7/20/2018
7/2012018
0.70
PROD1
RPEQPT
UREM
T
PU/MU caliper BHA, BHA #9
0.0
57.1
16:18
17:00
7/202018
7/20/2018
1.80
PROD`
RPE QPT
UREM
T
RIH, w/PDS Caliper
57.1
9,500.0
17:00
18:48
Page 5129 Report Printed: 8/22/2018
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
StallTne
End Time
Dur(hr)
Phase
Op Code
Actw*Code
Time P -T-%
Operation
(fit®)
End DepN(flKB)
7/20/2018
7/20/2018
0.30
PROD1
RPEQPT
OREM
T
Log gamma tie in for =3'
9,500.0
9,559.0
18:48
19:06
7/20/2018
7/20/2018
1.30
PROD1
RPEQPT
UREM
T
Continue in well. Stop and waft on
9,559.0
10,371.0
19:06
20:24
caliper to open
7/20/2018
7/20/2018
1.20
PROD1
RPEQPT
UREM
T
Log up hole with caliper 50 FPM to
10,371.0
9,830.0
20:24
21:36
9830, Stop and wait for caliper arms to
retract
7/20/2018
7120/2018
0.70
PROW
RPEQPT
UREM
T
POOH with caliper
9,830.0
50.0
21:36
22:18
7/20/2018
7/20/2018
0.20
PROD1
RPEQPT
UREM
T
At surface flow check. PJSM lay down
50.0
0.0
22:18
22:30
BHA on dead well
7120/2018
7/2112018
1.50
PROD1
RPEQPT
UREM
T
Reconfigure BHA, BOT here with
0.0
82.2
22:30
00:00
Haily under reamer. Make up BOT
motor, pup joint, and up down jars.
Make up to coil track. Make up to coil
and surface test
7/21/2018
7/21/2018
0.10
PROD1
RPEQPT
UREM
T
Make up BOT motor, pup joint, and up
82.2
82.2
00:00
00:06
down jars. Make up to coil track. Make
up to coil and surface test
7/21/2018
7/21/2018
1.70
PROD1
RPEQPT
-ITR-EM
T
RIH, EDC open
82.2
9,525.0
00:06
01:48
7/21/2018
7/21/2018
0.30
PROD1
RPEQPT
UREM
T
Log gamma tie in for +7.5'
9,525.0
9,584.0
01:48
02:06
7/21/2018
7/21/2018
0.30
PROD1
RPEQPT
UREM
T
Continue in well, weight check @
9,584.0
10,340.0
02:06
02:24
10,000' for 45K, Close EDC
7/21/2018
7/21/2618
2.00
PRODt
RPEQPT
UREM
T
Get to 10340, Bring pumps on 1.8
10,340.0
10,358.0
02:24
04:24
BPM @ 6000 PSI FS, Stall out, P/U
and restart, ream down
7/21/2018
7/21/2018
2.50
PROD1
RPEQPT
UREM
T
Stall motor, PUH to restart POW 50 k,
10,358.0
10,370.0
04:24
06:54
1.79 bpm @ 5,945 psi,
7/21/2018
7121/2018
5.00
PROD1
RPEQPT
UREM
T
Reaming 1.77 bpm at 5,476 psi, IA
10,370.0
10,426.0
06:54
11:54
920, OA491, stall motor POW 48 k
"' Note: bled IA 921 psi /13 psi
7/21/2018
7/21/2016
3.00
PRODi
RPEQPT
T
Re -start 1.78 bpm 5,500 psi, IA 921,
10,426.0
10,443.0
11:54
14:54
OA 491
7/21/2018
7/21/2018
0.70
PROD?
RPEQPT
T
Stalling in the perfs POW 48 k,
10,443.0
10,443.0
14:54
15:36
countinue reaming @ 1.72 bpm at
rUREEM
5,887 psi, IA 49, OA 439
7/21/2018
7/21/2018
2.90PROD1
RPEQPT
T
Unable to make progress. Multiple
10,443.0
89.0
15:36
18:30
stalls. Tdp to inspect BHA
7/21/2018
7/21/2018
0.70
PROD1
RPEQPT
T
At surface, PJSM, Flow check well.
89.0
0.0
18:30
19:12
Break off injector, Swap BHA. Haily
under reamer out with all blades
missing hinge pin cap plug. Consult
town
"" Note: Under Reamer 1/2" under
gauge.....
7/21/2018
7/21/2018
0.80
PROD1
RPEQPT
UREM
T
P/U BHA#11 Venturi win. Make up to
0.0
49.3
19:12
20:00
coil and surface test. Check packoRs.
Tag up and set counters
7/21/2018
7/21/2018
1.70
PROD1
RPEQPT
UREM
T
Trip in hole BHA#11 @ 9400
49.3
9,500.0
20:00
21:42
observed out density dropping - 8
PPG. BHP=3300
7/21/2018
7/21/2016
0.30
PROD1
RPEQPT
UREM
T
Gamma tie in for +6' correction, Close
9,500.0
9,548.0
21:42
22:00
EDC
7/21/2018
7/21/2018
0.80
PROD1
RPEQPT
UREM
T
Continue in well. Clean down to
9,548.0
10,444.0
22:00
22:48
10444. Pumps on 1.8 BPM @ 6000
PSI. Recip 3 times bottom up to 10300
7/21/2018
7/22/2018
1.20
PROD1
RPEQPT
UREM
T
POOH, Stop at 10099 Bit, Sensor @
10,444.0
5,583.0
22:48
00:00
10079' TVD=5673.29 SS, BHP=3400
and slowly rising, Continue out of well
Page 6129 Report Printed: 8122/2018
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stas Depth
Stat Time
ErM7me
Dur(hr)
Phase
Op Code
Activity Code
Tme P -T -X
Operation
(WB)
End Depth(tlKB)
7/22/2018
7/22/2018
1.10
PRODt
RPEQPT
UREM
T
Continue tripping out
5,583.0
56.9
00:00
01:06
7/22/2018
7/22/2018
1.40
PRODi
RPEQPT
UREM
T
At surface, tag up and space out.
56.9
0.0
01:06
02:30
Bleed well down. Went to 220 PSI.
PJSM to PUD BHA. Pull off venturi.
No whole plug in basket.
7/22/2018
7/22/2018
1.20
PROD?
RPEQPT
UREM
T
Make up under reamer and pressure
0.0
82.2
02:30
03:42
deploy BHA#12, Check packoffs,
Make up to coil and surface test
7/22/2018
7/22/2018
1.70
PROD1
RPEQPT
UREM
T
RIH, with Hailey Under Reamer.
82.2
9,500.0
03:42
05:24
7/22/2018
7/22/2018
0.20
PROD1
RPEQPT
UREM
T
Log formation correction of plus 8.0',
9,500.0
9,540.0
05:24
05:36
PUW 39 k
7/22/2018
7/22/2018
0.50
PROD1
RPEQPT
UREM
T
Continue IH
9,540.0
10,399.0
05:36
06:06
7/22/2018
7/22/2018
2.50
PROD1
RPEQPT
UREM
T
Stall, PUH, restart, 1.8 bpm at 5,500
10,399.0
10,465.0
06:06
08:36
psi
7/22/2018
7/22/2018
0.50
PROD1
RPEQPT
UREM
T
Stall, PUH, re -start, hard spot, Back
10,465.0
10,465.0
08:36
09:06
1
Ream up to 10,420'
7/22/2018
7/22/2018
0.60
PROD1
RPEQPT
UREM
T
Ream back down hole, stall motor
10,465.0
10,465.0
09:06
09:42
again (9 stalls (off 10465'), try and work
down. Discuss w/town team, called TD
10,465'
7/22/2018
7/22/2018
0.30
PROD1
RPEQPT
UREM
T
Back ream up hole to 10,345',
10,465.0
10,345.0
09:42
10:00
"•` Note: Lost 1,000 psi differential at
10,368'
7/22/2018
7/22/2018
0.20
PROD1
RPEQPT
UREM
T
Ream back down, to log the K1
10,345.0
10,368.0
10:00
10:12
7/22/2018
7/22/2018
0.20
PROD1
RPEQPT
UREM
T
Log the K1 marker correction of minus
10,368.0
10,386.0
10:12
10:24
2.0'
7/22/2018
7/22/2018
0.60
PRODt
RPEQPT
UREM
T
Continue IH to tag bottom
10,386.0
10,461.9
10:24
11:00
7/22/2018
7/22/2018
1.50
PROD1
RPEQPT
UREM
T
POOH, w/Hailey Under Reamer
10,461.9
82.1
11:00
12:30
7/22/2018
7/22/2018
1.50
PROD1
RPEQPT
UREM
T
At surface, space out, PUD BHA#12
82.1
0.0
12:30
14:00
••• Norte: Under Reamer upper
Blades gauged 5.5", (6.122")
7/22/2018
7/22/2018
2.30
PROD1
RPEQPT
UREM
T
Inspect BHI Coilraktools, PTtools in
0.0
0.0
14:00
16:18
pipe shed (good -lest), hook up test
cable (good -test), sim-ops inspect and
rebuild Under reamer (BOT).
7/22/2018
7/22/2018
0.70
PROD1
RPEQPT
UREM
T
PJSM, MU tools in well, load upper
0.0
0.0
16:18
17:00
section into PDL. Pressure test CT
CTC, and upper quick connect
7/22/2018
7/22/2018
2.10
PROD1
RPEQPT
UREM
T
PD BHA# 13, Haily under reamer,
0.0
82.2
17:00
19:06
Make up to coil and surface test, Tag
up and set counters
7/22/2018
7/22/2018
1.70
PRODi
RPEQPT
UREM
T
RIH with BHA #13 Under reamer
82.2
9,525.0
19:06
20:48
7/22/2018
7/22/2018
0.30
PROD1
RPEQPT
UREM
T
Gamma tie in for +6.5' correction
9,525.0
9,584.0
20:48
21:06
7/22/2018
7/22/2018
0.80
1 PROD1
RPEQPT
UREM
T
Continue in well, swap out milling
9,584.0
10,370.0
21:06
21:54
fluid, closed EDC
7/22/2018
7/22/2018
0101
10
PROD1
RPEQPT
UREM
T
Log K1 for -2.5'
10,370.0
10,382.0
21:54
22:00
Page 7129 Report Printed: 8/22/2018
Operations Summary (with Timelog Depths)
3H-31
oc( 3ilh I Ih .
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
San Depth
Siert Tim
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(flKB)
End Depth(ftKB)
7/2212018
7/23/2018
2.00
PROD1
RPEQPT
UREM
T
PUH to 10341. Pumps on 1.8 BPM @
10,382.0
10,460.0
22:00
00:00
5990 PSI FS, BHP=4045. Start
reaming down. Stall @ 10,381. P/U
restart and stall again then ream past
down to 10460. Work area multiple
times until no motor work observed
10,410 to 10,460
7/23/2018
7/23/2018
1.10
PROD1
RPEQPT
UREM
T
Continue work 10,410 to 10,460 until
10,460.0
10,460.0
00:00
01:06
no motor work observed. One spot @
10430 unable to get cleared up
7/23/2018
7/23/2018
1.80
PROD1
RPEQPT
UREM
T
POOH, stop at 10116 open EDC
10,460.0
85.0
01:06
02:54
7/23/2018
7/23/2018
1.70
PROD1
RPEQPT
UREM
T
Tag up and space out, PJSM to PUD
85.0
0.0
02:54
04:36
BHA# 13
"` Note: Under Reamer upper blades
1/2" under gauge, Lower blades 1/8"
under gauge, Mill gauged 2.73 no-go
7123/2018
7/23/2018
1.50
PROD1
RPEQPT
UREM
T
RU, Haliburton Caliper, MU BHA # 14
0.0
26.0
04:36
06:06
7/23/2018
7/23/2018
2.20
PROD1
RPEQPT
UREM
T
RIH, w/BHA #114 HES caliper
26.0
10,455.0
06:06
08:18
7123/2018
7/23/2018
0.30
PROD1
RPEQPT
UREM
T
Log up hole at 50 fpm, PUW 42 k
10,455.0
9,970.0
08:18
08:36
7/23/2018
7/23/2018
0.40
PROD1
RPEQPT
UREM
T
Hesliate let fingers close, RBIH
9,970.0
10,459.0
08:36
09:00
7/23/2018
7/23/2018
0.30
PROD1
RPEQPT
UREM
T
Let fingers extend, Log up at 50 fpm
10,459.0
9,970.0
09:00
09:18
7/2312018
7/2312018
2.00
PROD1
RPEQPT
UREM
T
Close fingers, POOH
9,970.0
20.0'1
09:18
11:18
7/23/2018
7/23/2018
0.20
PROD?
RPEQPT
UREM
T
Al surface, Lay down BHA#14,
20.0
0.01
11:18
11:30
Caloiper
7/23/2018
71232018
3.50
PROD1
WHDBOP
CTOP
P
Install n=le and jet stack. Flush ng,
0.0
0.011
11:30
15:00
Service valves in prerperation for
BOPE test
7/23/2018
7/23/2018
6.50
PROW
WHDBOP
BOPE
P
Complete full BOPE test, Test witness
0.0
0.0
15:00
21:30
waived by Jeff Jones, AOGCC. Test
PVT and gas monitors and alarms. No
failures
7/23/2018
7/23/2018
1.70
PROD1
RPEQPT
UREM
T
PJSM, M/U and PD BHA#15. D-331
0.0
51.4
21:30
23:12
slick gauge mill, 2.80", and straight
motor to mill more pilot hole. Make up
to coil and surface test, Install checks
in UQC, Check pack offs
7/23/2018
7/24/2018
0.80
PROD1
RPEQPT
UREM
T
Trip in hole BHA#15 to mill more pilot
51.4
3,758.0
23:12
00:00
hole
7/242018
724/2018
1.10
PRODt
RPEQPT
UREM
T
Continue tripping in hole BHA 915 to
3,756.0
10,103.0
00:00
01:06
mill more pilot hole
7124/2018
7/24/2018
0.10
PROD1
RPEQPT
UREM
T
Close EDC, Wt chk @ 40K, Continue
10,103.0
10,330.0
01:06
01:12
in hole
7/24/2018
7/24/2018
0.20
PROD1
RPEQPT
UREM
T
Log K1 for +5' correction
10,330.0
10,355.0
01:12
01:24
7/24/2018
7/2412018
0.10
PROD1
RPEQPT
UREM
T
Continue in well, Dry tag @ 10463'
10,355.0
10,463.0
01:24
01:30
7/2412018
7/24/2018
1.20 j
PROD1
RPEQPT
UREM
T
PUH pumps on 1.8 BPM @ 4765 PSI
10,463.0
10,490.0
01:30
02:42
FS, BHP=4090, AVG ROP=25FPH,
Pump 5 X 5 Sweeps
7/24/2018
7/24/2018
2.30
PRODt
RPEQPT
UREM
T
POOH chasing sweeps, PUW=42K
10,490.0
55.3
02:42
05:00
7/24/2018
7/24/2018
2.50
PROD1
RPEQPT
UREM
T
Atsurface, PJSM, PUD BHA#15
55.3
0.0
05:00
07:30
Page 8129 ReportPrinted: 8/2212018
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Siert Depth
Start Tmre
End Time
our (hr)
Phase
Op Code
Acdvity Code
Time PJA
Operation
(MKS)
End Depth (MKa)
7/24/2018
712412018
3.00
PROD1
RPEQPT
UREM
T
Stand by to P/U WFT 2 1/8" motor and
0.0
0.0
07:30
10:30
Reeves 2 3/8" under reamer with 6"
blades
7/24/2018
7/24/2018
1.20
PROD1
RPEQPT
UREM
T
PJSM, P/U BHA#16 and pressure
0.0
77.8
10:30
11:42
deploy. Make up to coil and surface
test. Check pack offs, Tag up and set
counters
7/24/2018
7/24/2018
1.80
PROD1
RPEQPT
UREM
T
RIH BHA#16 with WFT 2 1/8 motor
77.8
9,525.0
11:42
13:30
and reeved under reamer with 6"
blades
7/24/2018
7/24/2018
0.30
PROD1
RPEQPT
UREM
T
Run gamma tie in for+7' correction
9,525.0
9,571.0
13:30
13:48
7/24/2018
7/24/2018
0.40
PROD1
RPEQPT
UREM
T
Continue in well, close EDC @
9,571.0
10,340.0
13:48
14:12
10,100', PUW=44K
7/24/2018
7/24/2018
4.00
PROD1
RPEQPT
UREM
T
10340 bring pumps online 1.3 BPM @
10,340.0
10,455.0
14:12
18:12
3685 PSI FS. Stall hard multiple times
@ 10370.5. Go past spot pumps down
down to 10,450. Reipt 10450 to 10440
to work reamer open.
Under -ream interval from 10,440'-
10,455' until little to no motorwork
observed, begin to work up 20' interval
to connect (14,420-14,445'), come up
above 10,371' (stalling area), clean up
& no motorwork down through.
Decision made to POOH to inspect
BHA and under -reamer
7/24/2018
7/24/2018
1.60
PRODi
RPEQPT
TRIP
T
POOH to inspect BHA & under -reamer
10,370.0
78.0
18:12
19:48
7/24/2018
7/24/2018
1.20
PROW
RPEQPT
PULD
T
PJSM, PUD BHA #16
78.0
0.0
19:48
21:00
7/24/2018
7/25/2018
3.00
PROD1
RPEQPT
WAIT
T
Reeves under -reamer not re-runable,
0.0
0.0
21:00
00:00
upper blades have -.5" slop in the
open position, broke tool down,
broken seal fell from tool. Confer w/
town, attempt to track down DB UR,
BOT does not have any additonal DB
under -reamers on the slope.
Await the arrival of Hailey under -
reamer to slope, pumping managed
pressure at 11.9 ppg
7125/2018
7/25/2018
6.00
PROW
RPEQPT
WAIT
T
Continue painting rig, await Hailey
0.0
0.0
00:00
06:00
under -reamer delivery to slope
7/25/2018
7/25/2018
0.50
PROD1
RPEQPT
UREM
T
Perform injectivity test. Unable to
0.0
0.0
06:00
06:30
achieve steady rate injection @ 2200
PSI WHP
7/25/2018
7/25/2018
5.70
PROD1
RPEQPT
WAIT
T
Continue painting projects and
0.0
0.0
06:30
12:12
maintenance
7/25/2018
7/25/2018
1.50
PRODi
RPEQPT
UREM
T
PJSM, pressure test GE transducer
0.0
76.3
12:12
13:42
installed by reel swivel. Under reamer
on location. Discuss blade size and
type options with town. M/U under
reamer. M/U to BHA#17 and deploy.
Make up to injector and surface test.
Tag up and set counters
7/25/2018
7/25/2018
2.40
PROD1
RPEQPT
UREM
T
Trip in hole BHA #17 (4.72" & 4.85"
76.3
10,350.0
13:42
16:06
blades), EDC open, Stop @ 10,100'
close EDC. PUW=39K, Continue RIH
7/25/2018
7125!2018
0.20
PRODi
RPEQPT
UREM
T
Log Kt for +5'correction
10,350.0
10,377.0
16:06
16:18
7/25/2018
7/25/2018
0.10
PROD1
RPEQPT
UREM
T
Continue in to 10,345'
10,377.0
10,345.0
16:18
16:24
Page 9129 Report Printed: 8122/2018,
AimOperations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Tlme
End Ttme
O (hr)
Phase
Op Code
mviy Corte
Tinte P -T -X
Operation
(11KB)
End Depth (flKB)
7/25/2018
7/25/2018
1.60
PROD1
RPEQPT
UREM
T
Bring on pumps, 1.78 BPM @ 5950
10,345.0
10,385.0
16:24
18:00
PSI FS, Stay stationary for 10 minutes.
then slowly start reaming down,
significant vibration
7125/2018
7/25/2018
3.00
PROD1
RPEQPT
UREM
T
Continue under -reaming from 10,385',
10,385.0
10,434.0
18:00
21:00
1.78 bpm, vibrations up to 6, stall at
10,386', FS = 1750 psi, pump & bore
pressure dropped beginning at
-10,416(down to -1500 psi
differential from 1800 psi), vibrations
reduced down to 2's
7/25/2018
7125/2018
1.20
PROW
RPEQPT
UREM
T
Continue under -reaming from 10,434'
10,434.0
10,455.0
21:00
22:12
to 10,455', pumping 1.78 bmp, circ
pressure = 5322 psi, dip = 1512 psi
7/25/2018
7/2512018
0.60
PROD1
RPEQPT
UREM
T
Back ream up -hole, PUW = 44K, get
10,455.0
10,350.0
22:12
22:48
parameters at 10,355', circ pressure =
5250 psi, dp = 1460 psi, decision
made to POOH to inspect tools due to
pressure drops
7/25/2018
7/26/2018
1.20
PROD1
RPEQPT
TRIP
T
POOH
10,350.0
4,200.0
22:48
00:00
7/26/2018
726/2018
0.80
PROD1
RPEQPT
TRIP
T
Continue POOH
4,200.0
76.0
00:00
09:48
7/26/2018
7/26/2018
1.10
PROD1
RPEQPT
PULD
T
PJSM, PUD BHA 917
76.0
0.0
00:48
01:54
Note: LD BHI tools due to hour out on
Vibration
7/26/2018
7/26/2018
0.80
PROW
RPEQPT
OTHR
T
Inspect under -reamer, blades look
0.0
0.0
01:54
02:42
good with minimal cutter chips,
retainer pins for blades show a bit of
wear/deformation (2nd run), pistons
look decent & blades show wear as if
they had engagement, set screws are
intact & retaining screws for blades
look good. BOT motor tested good w/
air
Intstall 5.931'& 6.125" blades,
redressed 6.125" blades struggle to fit
in body window, pull & install 6"
blades, hook UR up to air & test,
leaking past seals.
7/262018
7/26/2018
3.60
PROD1
RPEQPT
WAIT
T
Confer w/ town, decision made to run
0.0
0.0
02:42
06:18
HAL caliper, await HAL arrival to dg
726/2018
7262018
0.50
PROD1
RPEQPT
PULD
T
HES on location, Start assembling
0.0
0.0
06:18
06:48
caliper
726/2018
726/2018
2.00
PROD1
RPEQPT
WAIT
T
HES missing go pin connect. Hot Shot
0.0
0.0
06:48
08:48
from deadhorse
71262018
7/26/2018
0.50
PROD1
RPEQPT
PULD
T
Parts on location. M/U BHA#18
0.0
24.5
08:48
09:18
caliper. Make up to coil and surface
test. Check packoffs
7126/2018
7/262018
2.10
PRODII
RPEQPT
TRIP
T
Trip in hole BHA# 18 Caliper, Tie into
24.5
10,455.0
09:18
11:24
k1 for+6'
7/26/2018
726/2018
0.80
PROD1
RPEQPT
DLOG
T
10,455'. Caliper up to 9990 and repeat
10,455.0
9,990.0
11:24
12:12
pass
7/262018
7/26/2018
1.60
PROD1
RPEQPT
TRIP
T
POOH with caliper
9,990.0
23.0
12:12
13:48
7/26/2018
7/26/2018
0.50
PROW
RPEQPT
PULD
T
At surface, PJSM lay down caliper
23.0
0.0
13:48
14:18
7/26/2018
7/26/2018
0.50
PROD1
RPEQPT
SVRG
T
Service reel. Check hubs and saddle
0.0
0.0
14:18
14:48
clamps
Page 10/29 Report Printed: 8/2212018
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Tine
End Time
Dw(M)
phase
Op Code
Activity Code
Time P -T-%
Operation
(fl(a)
End Depth(flKe)
7/26/2018
7/26/2018
1.30
PROD1
RPEQPT
PULD
T
PJSM, M/U BHA#19 with Hailey
0.0
76.3
14:48
16:06
under reamer fitted with 4.72" blades
on bottom 4.85 blades on top. 2.80
mill on nose. PD BHA. M/U to coil and
surface test. Tag up and reset
counters
7/26/2018
7/26/2018
2.20
PROM
RPEQPT
TRIP
T
RIH BHA#19, EDC open, log K1 for
76.3
10,355.0
16:06
18:18
+3' correction
7/26/2018
7/26/2018
0.10
PROD1
RPEQPT
UREM
T
Slop at 10,355', close EDC, begin
10,355.0
10,355.0
18:18
18:24
pumping & get parameters
Depth = 10,355'
Rate = 1.65 bpm
Circ pressure = 5292 psi
Bore = 5326 psi
rip = 1628 psi (FS)
WHIP = 205 psi
BHP = 3700 psi
7/26/2018
7/26/2018
3.90
PRODi
RPEQPT
UREM
T
Begin under -reaming, pumping 1.65
10,355.0
10,455.0
18:24
22:18
bpm, FS = 1628 psi, 18 fph, seeing
little to no motorwork down to 10,385',
increase speed to 0.5 fpm looking for
motorwork, clean down to 10,455',
vibrations up to 4's
7126/2018
7/26/2018
0.40
PROW
RPEQPT
UREM
T
Back ream up -hole @ 5 fpm, pumping
10,455.0
10,350.0
22:18
22:42
1.65 bpm, dip = 1527 psi, circ = 5137
psi
7/26/2018
7/26/2018
1.10
PRODt
RPEQPT
UREM
T
Ream down -hole @ 2 fpm, pumping
10,350.0
10,455.0
22:42
23:48
1.65 bpm, dp = 1489 psi, circ = 5111
psi, saw a bit of molorwork @ 10,430',
stalled at 10,455'
7/26/2018
7/27/2018
0.20
PRODi
RPEQPT
UREM
T
Begin POOH, 5 fpm to TT
10,455.0
10,368.0
23:48
00:00
7/27/2018
7/27/2018
2.10
PROD1
RPEQPT
TRIP
T
Continue back -ream to TT, open EDC
10,368.0
76.0
00:00
02:06
1@ 10,107', POOH, tag up, PJSM
7/27/2018
7/27/2018
0.70
PROM
RPEQPT
PULD
T
PUD BHA#19, mill gauged 2.73",
76.0
0.0
02:06
02:48
blades gauged 4.72" `4.85", pies on
s: drive
7/27/2018
7/27/2018
1.20
PROD1
RPEQPT
PULD
T
PD BHA #20 (Hailey UR redressed
0.0
76.0
02:48
04:00
from BHA#17, w/ 5.93" & 6.125"
blades & 2.74" mill), slide in cart, MU
to coil, tag up, set counters
7/27/2018
7/27/2018
2.00
PROM
RPEQPT
TRIP
T
RIH w/ BHA #20, EDC open. Weight
76.0
10,360.0
04:00
06:00
chk @ 10078 40K. Shut EDC continue
n
7/27/2018
7/27/2018
0.10
PROD1
RPEQPT
DLOG
T
Log K1 for+3' correction. PUH to
10,360.0
10,349.0
06:00
06:06
10349
7/27/2018
7/27/2018
2.00
PROD1
RPEQPT
UREM
T
10349, Pumps on 1.65 BPM @
10,349.0
10,380.0
06:06
08:06
509OPSI FS, 1400 PSI Diff. Start
reaming down
7/27/2018
7/27/2018
0.90
PROM
RPEQPT
UREM
T
10380', Stall and restart, PUW=40K,
10,380.0
10,386.0
08:06
09:00
1
1
1.64 BPM @ 4990 PSI FS
7/27/2018
7/27/2018
4.20
PROD?
RPEQPT
UREM
T
10,386. Stall and restart. Stall a
10,386.0
10,415.0
09:00
13:12
couple of time here and work through,
Stall and restart @ 10393, PUW=40K
7/27/2018
7/2712018
1.90
PROD1
RPEQPT
UREM
T
10415, Stall and restart, PUW=36K,
10,415.0
10,433.0
13:12
15:06
1.72 BPM @ 5310 PSI.
7/27/2018
7/27/2018
1.80
PROM
RPEQPT
UREM
T
10,433 stall and restart, PUW=36K.
10,433.0
10,455.0
15:06
16:54
1.69 BPM @ 5155.
7/27/2018
7/27/2018
3.00
PROD1
RPEQPT
UREM
T
Back ream up, a lot of motorwork @
10,455.0
76.0
16:54
19:54
10,4311,10,425- & 10,422', POOH, tag
up, PJSM
Page 11129 Report Printed: 812 212 01 8
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Sten Depth
Stan Time
End Time
Dur (hr)
Phase
Op Code
Adfty code
Tune P -T -X
Opemlion
We)
End Depth (f KB)
7/27/2018
7/27/2018
1.30
PRODt
RPEQPT
PULD
T
PUD BHA #20, top blades gauged
76.0
0.0
19:54
21:12
5.81" & bottom blades gauged
5.84" (pics on s: drive)
7/27/2018
7/27/2018
0.90
PROD1
RPEQPT
OTHR
T
Make up blades to UR body, run coil
0.0
0.0
21:12
22:06
into pipe -shed, check for flat spots,
none, UT coil at 12' up from CTC
(lowest value .198"), replace return
line in cellar & hammered up
7/27/2018
7/27/2018
1.30
PROD1
RPEQPT
PULD
T
Confer w/town on blades to run, crew
0.0
76.0
2206
23:24
change, PJSM, PD BHA#21 (Hailey
UR, 2.74" mill, 5.93" & 6.1" blades),
pics on s: drive, slid in cart, MU to coil,
tag up, set counters
7127/2018
7/2812018
0.60
PROD1
RPEQPT
TRIP
T
Begin RIH w/ BHA #21, EDC open
76.0
2,500.0
23:24
00:00
7/28/2018
7/28/2018
1.30
PROD1
RPEQPT
TRIP
T
Continue RIH w/ BHA#21, PUW @
2,500.0
10,102.0
00:00
01:18
10,100'=40K
7/28/2018
7128/2018
0.30
PROD1
RPEQPT
DLOG
T
Obtain SBHP, close in choke, shut
10,102.0
10,102.0
01:18
01:36
down pumps:
MID bit = 10,102'
ND sensor= 5738'
Annular = 3688 psi
EMW = 12.4 ppg
7/28/2018
712812018
0.70
PRODt
RPEQPT
UREM
T
Continue RIH, log K1 for+3'
10,102.0
10,396.0
01:36
02:18
correction, under -ream down
beginning at 10,365'
Park @ 10,360', close EDC, & grab
parameters: rate= 1.6 bpm, circ =
5497psi, bore = 5453 psi, dip = 1556
psi
7/28/2018
7/28/2018
2.30
PROD1
RPEQPT
UREM
T
Reaming, multiple stalls from 10,396 -
10,396.0
10,408.0
02:18
04:36
1
1
110,408,
7/28/2018
7/28/2018
0.10
PROD1
RPEQPT
UREM
T
Drop pump, RIH to 10,455'to back
10,408.0
10,455.0
04:36
04:42
1
ream up
7/28/2018
7/28/2018
3.00
PROD1
RPEQPT
UREM
T
Back ream up hole to begin cleaning
10,455.0
10,455.0
04:42
07:42
up WS setting interval, stall bringing
on pumps at 10,454', get blades
cutting at 10,452', work down to
10,455' Recip this area multiple stalls
7/28/2018
712812018
0.10
PRODt
RPEQPT
UREM
T
PUH to 10409 to ream interval down,
10,455.0
10,409.0
07:42
07:48
PUW=40K
7/28/2018
7128/2018
1.10
PROD1
RPEQPT
UREM
T
10409, ream down 1.57 BPM @ 5180
10,409.0
10,455.0
07:48
08:54
PSI FS stall at 10411
7/28/2018
7/28/2018
0.10
PROD1
RPEQPT
UREM
T
10455, Back ream clean up to 10400,
10,455.0
10,400.0
08:54
09:00
Pump 5 X 5 Sweeps
7/28/2018
7/28/2018
1.90
PROD1
RPEQPT
TRIP
T
Open EDC. Trip out
10,400.0
65.0
09:00
10:54
7/28/2018
7/28/2018
1.10
PRODt
RPEQPT
PULD
T
Tag up and space out, PJSM PUD
65.0
0.0
10:54
12:00
BHA# 21. Hailey under reamer out
with blades at 5.91 lioer, 5.95 upper
with small pinhole in body of tool
7/28/2018
7/28/2018
1.00
PROD1
RPEQPT
CTOP
T
Jet stack and flush rig with citric pill to
0.0
0.0
12:00
13:00
tiger tank
7/282018
7/2812018
0.60
PROD1
RPEQPT
PULD
T
PJSM, P/U HES caliper, M/U to coil
0.0
24.5
13:00
13:36
and surface lest
7/28/2018
7282018
2.10
PROD1
RPEQPT
TRIP
T
Trip in well BHA # 22 HES Caliper
24.5
10,222.0
13:36
15:42
7/282018
7/28/2018
0.10
PROD1
RPEQPT
DLOG
T
Start logging gamma tie in for+27
10,222.0
10,350.0
15:42
15:48
7/282018
728/2018
0.20
PROD1
RPEQPT
TRIP
T
Continue in well
10,350.0
10,460.0
15:48
16:00
Page 12129 Report Printed: 812 212 01 8
Operations Summary (with Timelog Depths)
3H-31
•
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
T1me Log
sten Depth
stet Time
Ertl Time
Our (hri
Phase
Op Code
Activity Code
Time P -T -X
Operation
(We)
End Depm(ftKB)
7/28/2018
7/28/2018
0.50
PROD1
RPEQPT
DLOG
T
10460', start calipering casing up to
10,460.0
9,990.0
16:00
16:30
9995'. RBIH and repeat logging pass
7/28/2018
7/28/2018
1.70
PROD1
RPEQPT
TRIP
T
POOH with caliper
9,990.0
25.0
16:30
18:12
7/28/2018
7/28/2018
0.90
PROD1
RPEQPT
PULD
T
PJSM, LD BHA#22 HES Caliper,
25.0
0.0
18:12
19:06
clear floor
7/28/2018
7/28/2018
1.70
PROD1
RPEQPT
WAIT
T
Await arrival of Hailey UR, pre -load
0.0
0.0
19:06
20:48
1
1
1 PDL, 6" & 6.1" blades
7/28/2018
7/28/2018
1.60
PROD1
RPEQPT
PULD
T
PJSM, PD BHA#23 Hailey UR (2.74"
0.0
76.0
20:48
22:24
mill, 6" & 6.1"), slide in cart, check
pack -offs, good, MU to coil, tag up, set
counters
7/28/2018
7/29/2018
1.60
PROD1
RPEQPT
TRIP
T
Begin RIH w/ BHA #23
76.0
9,000.0
22:24
00:00
7/29/2018
7/2912018
0.50
PROD1
RPEQPT
TRIP
T
Continue RIH w/ BHA#23, PUW =
9,000.0
10,405.0
00:00
00:30
40K @ 10,100', close EDC, log K1 for
+4' correction
7/29/2018
7/29/2018
0.90
PROD1
RPEOPT
REAM
T
Under -ream from 10,405', Rate = 1.5
10,405.0
10,405.0
00:30
01:24
bpm, Circ = 5640 psi, Bore = 5486 psi,
FS =1611 psi
'
0.2 fpm, vibrations @ 6, lose annular
& bore on baker screen
Have a drop in circ from 5600 psi to
5300 psi & vibrations dropped at same
time (00:40:40)
7129/2018
7129/2018
2.20
PROD1
RPEQPT
TRIP
T
POOH to TOC, allow MWD to trouble-
10,405.0
76.0
01:24
03:36
shoot baker tools, lost DPS, RBIH to
10,355', bring up rate to 1.5 bpm, circ
= 5600 psi (pressure drop
mysteriously gone),
Confer with town, POOH to replace
BHI tools, unable to open EDC w/ no
dp from BHI tool, pump down MP line,
plan to bench test UR w/ air
7/29/2018
7/29/2018
1.00
PROD1
RPEQPT
PULD
T
PJSM, PUD BHA #23 w/ EDC closed
76.0
0.0
03:36
04:38
7/29/2018
7/29/2018
3.40
PRODt
RPEQPT
OTHR
T
LD tools, PU new BHI tools, bench
0.0
0.0
04:36
08:00
test UR, bottom piston seals are shot,
contact Weatherford & they have a
Reeves UR on the slope, confer w/
town, get the UR coming to rig
" Wait on Reeves UR w/ 6.125"
blades
7/29/2018
7/29/2018
1.30
PROD1
RPEQPT
PULD
T
WFT on location, Load tools into shed,
0.0
77.7
08:00
09:18
PJSM PD BHA#24 with 2 118 WFT
motor, Reeves 2 3/8" under reamer
with 6.125 blades. Make up to coil and
surface test. Tag up and space out
7129/2018
7/29/2018
2.00
PROD1
RPEQPT
TRIP
T
Trip in hole, BHA #24, EDC open,
77.7
10,360.0
09:18
11:18
Close EDC at 10,000', PUW=38K
7129/2018
7/29/2018
0.10
PROW
RPEQPT
DLOG
T
Log K1 for +6'correction
10,360.0
10,376.0
11:18
11:24
7/29/2018
7/29/2018
0.10
PROD1
RPEQPT
TRIP
T
Continue in hole
10,376.0
10,405.0
11:24
11:30
7/29/2018
7/29/2018
3.30
PROD1
RPEQPT
UREM
T
10405 bring pumps on 1.49 BPM,
10,405.0
10,416.0
11:30
14:48
CTC=4743, Diff=872. Start reaming
1
downSlall @ 10413 3 times, stall @
10416 multiple times.
Page 13129 ReportPrinted: 8/22/2018
Operations Summary (with Timelog Depths)
77
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Sart Depth
End Time
our (m)
Phase
Op Code
Aravily Code
Terme P -T -X
Operation
(are)
End Depth (11103)
729/2018
3.20
PROD1
RPEQPT
UREM
T
Hard to get past 10416. Check caliper
10,423.0
10,441.0
18:00
log. go to 10423 at min rate. Bring
pumps online 1.50 BPM and start
working whipstock setting zone, stalls
r9/20MI
at 10,441'
7/29/2018
3.70
PROD1
RPEQPT
UREM
T
Continue under -reaming from 10,441',
10,441.0
10,443.8
21:42
pumping 1.5 bpm, FS = 860 psi, stall
at 10,442', go into auto driller @ ifph,
vibrations in green with occasional
red's, though push on it and stall, stall
@ 10,442.6',10,443.2-
0,442.6',10,443.2'7/29/2018
7129/2018
7/30/2018
2.30
PROD1
RPEQPT
UREM
T
Continue under -reaming from
10,443.8
10,445.7
21:42
00:00
10,443.8', pumping 1.5 bpm, FS = 860
psi, stall @ 10,444.7'& 10,4457,
clean RBIH after stalls at faster
speeds, virbrations in the greens,
yellow, & reds
7/30/2018
7/302018
3.00
PROD1
RPEQPT
UREM
T
Continue under -reaming from
10,445.7
10,449.7
00:00
03:00
10,445.T, FS = 850 psi, vibrations
between 2 - 4, stall again @ 10,447.7',
stall @ 10,448.5'
7/30/2018
7/30/2018
1.00
PROD1
RPEQPT
UREM
T
Continue under -reaming from
10,449.7
10,452.0
03:00
04:00
10,449.7', stall @ 10,451.3', ream to
10,452' (depth discussed if reaming is
difficult)
" Sunday Saftey Meeting held in OPS
Cab
7/3012018
7/30/2018
0.20
PROD1
RPEQPT
UREM
T
Back ream @ 5 fpm, PUW = 45K,
10,452.0
10,420.0
04:00
04:12
clean
7/30/2018
7/30/2018
0.20
PROD1
RPEQPT
UREM
T
Under -ream back in-hole, 3 fpm, dip =
10,420.0
10,452.0
04:12
04:24
1
768 psi, clean
7/30/2018
7/30/2018
1.90
PROD1
RPEOPT
UREM
T
Continue under -reaming from 10,452',
10,452.0
10,454.0
04:24
06:18
-
stall @ 10,452.5'
7/30/2018
7/30/2018
0.30
PROD1
RPEQPT
UREM
T
Back ream up to 10,410 @ 5 FPM
10,454.0
10,410.0
06:18
06:36
71302018
7/30/2018
0.20
PROD1
RPEQPT
UREM
T
Ream down, Clear trip to bottom.
10,410.0
10,454.0
06:36
06:48
7/30/2018
7130/2018
0.20
PROD1
RPEQPT
UREM
T
Back ream up hole to 10360
10,454.0
10,360.0
06:48
07:00
7/30/2018
7/302018
1.70
PRODt
RPEQPT
TRIP
T
Trip out of hole, Stop @ 10095 and
10,360.0
77.0
07:00
08:42
1
1 oipen EDC
7/30/2018
7/30/2018
1.00
PROD1
RPEQPT
PULD
T
Tag up and space out. PJSM PUD
77.0
0.0
08:42
09:42
1 BHA# 24 Reeves under reamer
7/30/2018
7/30/2018
0.80
PROD1
RPEQPT
PULD
T
Reconfigure BHA for caliper run. HES
0.0
0.0
09:42
10:30
here rigging up caliper and computers
7/30/2018
7/30/2018
0.40
PRODi
RPEQPT
PULD
T
PJSM, M/U caliper and surface test
0.0
24.0
10:30
10:54
7/30/2018
7/30/2018
2.00
PROD1
RPEQPT
TRIP
T
RIH BHA # 25 Caliper, Tie in for -2'
24.0
10,458.0
10:54
12:54
7130/2018
7/30/2018
0.70
PROD1
RPEQPT
DLOG
T
10458', Log up with caliper to 9957,
10,458.0
9,940.0.
12:54
13:36
RBIH and repeat logging pass
7/30/2018
7/30/2018
2.40
PROD1
RPEQPT
TRIP
T
POOH after completing caliper interval
9,940.0
23.8
13:36
16:00
7/30/2018
7/30/2018
1.50
PROD1
RPEQPT
PULD
T
PJSM, Lay down caliper, Load out
23.8
0.0
16:00
17:30
7/30/2018
7/30/2018
1.00
PROD1
RPEQPT
CTOP
T
Pull checks out of UQC, Stab on and
0.0
0.0
17:30
18:30
jet stack / Flush rig
7/302018
7/30/2018
2.00
PROD1
RPEQPT
OTHR
T
Prep for BOPE test
0.0
0.0
18:30
20:30
Page 14129 ReportPrinted: 812 212 01 8
Operations Summary (with Timelog Depths)
3H-31
..#
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
StartTons
EndTma
Due(hr)
Phase
op cow
AtlWlty Coes
Tuns P -T -X
Operation
(R)(B)
EM Depth (110)
7/30/2018
7/3112018
3.50
PROD1
RPEQPT
BOPE
P
Start full BOPE test, Test witnessed by
0.0
0.0
20:30
00:00
Matt Herrera, AOGCC, Swab 2 Fail /
Pass, On test 7 Tango 1 fail / fail.
Move on to test 8
7/3112018
7/31/2018
0.70
PROD1
RPEQPT
BOPE
P
Continue w/ BOPE test
0.0
0.0
00:00
00:42
7/31/2018
7/31/2018
2.80
PROD1
RPEQPT
BOPE
T
Fail past Bravo 3 & 7, trouble -shoot,
- 0.0
0.0
00:42
03:30
flush stack, re -grease Tango 1, Bravo
3 & 7, cycle valves, re -test, good
7/31/2018
7/31/2018
3.00
PROD1
RPEQPT
BOPE
P
Continue wl BOP test, draw down,
0.0
0.0
03:30
06:30
inner reel iron & stripper
7/31/2018
7/31/2018
1.70
PROD1
RPEQPT
DISP
P
Clear floor, MU nozzle, displace coil to
0.0
0.0
06:30
08:12
viscosified seawater, load tools, pop
off & break off nozzle, clear floor,
install checks
7/31/2018
7/31/2018
0.70
PROD1
RPEQPT
PULD
P
Bring WS to floor and assemble, put in
0.0
0.0
08:12
08:54
1
hole
7/31/2018
7/31/2018
1.60
PROD1
RPEQPT
PULD
P
PJSM, PD BHA#26 Northern
0.0
74.0
08:54
10:30
Solutions HEW WS
NS rep confers w/ town, shear stud
adjustment bar on WS not threaded
on setting rod sufficiently, LD WS, re-
adjust, continue on with PD, slide in
cart, MU to coil, tag up, set counters
7/31/2018
7/31/2018
2.10
PROD1
RPEQPT
TRIP
P
RIH w/ BHA#26, EDC open, stop at
74.0
10,360.0
10:30
12:36
10,100', close EDC, PUW = 39K,
continue RIH pumps off
7131/2018
7/31/2018
0.10
PROD1
RPEQPT
DLOG
P
Log K1 for +4' correction
10,360.0
10,375.0
12:36
12:42
7/31/2018
7/31/2018
0.20
PROD1
RPEQPT
TRIP
P
Continue RIH, arrive at setting depth,
10,375.0
10,442.8
12:42
12:54
pickup slack, bring up pumps, shear
-
off WS at 4500 psi, TOWS -10,434',
oriented HS, PUW = 39K
-
7/31/2018
7/31/2018
1.70
PROD1
RPEQPT
TRIP
P
POOH, EDC open
10,442.8
76.0
12:54
14:36
7/31/2018
7/31/2018
1.10
PROD1
RPEQPT
PULD
P
PJSM, PUD BHA #26
76.0
0.0
14:36
15:42
7/31/2018
7/31/2018
0.90
PRODt
WHPST
PULD
P
PD BHA #27 Window Milling Assembly
0.0
75.0
15:42
16:36
(1.0 AKO X -creme motor, 2.80" string
reamer, 2.80" window mill), slide in
cart, MU to coil, tag up, set counters
7131/2018
7/31/2018
1.90
PROD1
WHPST
TRIP
P
RIH w/ BHA#27
75.0
10,355.0
16:36
18:30
7/31/2018
7/31/2018
0.20
PROD1
WHPST
DLOG
P
Log the K1 correction of Plus 3.0'
10,355.0
10,390.0
18:30
18:42
7/31/2018
7/31/2018
0.40
PROD1
WHPST
DISP
P
Displace well to milling fluid (8.48 ppg)
10,390.0
10,390.0
18:42
19:06
7/31/2018
7/31/2018
0.20
PROD1
WHPST
TRIP
P
Continue IH, dry tag TOWS 10,438.5'
10,390.0
10,438.0
19:06
19:18
7/31/2018
7/31/2018
2.20
PROD1
WHPST
MILL
P
PUH, and bring pump on line get
10,438.0
10,440.7
19:18
21:30
parameters, begin milling window @ 1
fph, 1.81 bpm at 4,291 psi,
BHP=3,889, WHP=419, IA=26,
OA=364.
7131/2018
7/31/2018
1.75
PROD1
WHPST
MILL
P
Notice DHWOB loss from 2.0k -0.8k,
10,440.7
10,442.2
21:30
23:15
continue milling ahead.
Note: Bottom of window (10,441')
Note: Sample -
g Iauoonite/cement/metal
7/31/2018
8/1/2018
0.75
PROD1
WHPST
MILL
P
Increase to 2 fph as per rep RP
10,442.2
10,444.0
23:15
00:00
I
Page 15129 Report Printed: 8122/2018
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Depth
startTime
EmInme
our(hr)
phase
Op case
Activity Cana
Time P-T-x
Operation
(BI®)
End Depth (WB)
8/1/2018
8/1/2018
3.50
PRODI
WHPST
MILL
P
Continue milling window off of
10,444.0
10,459.0
00:00
03:30
Northern Solutions HEW WS, TD rat
hole 24' down from TOWS.
8/1/2018
8/1/2018
1.80
PROD1
WHPST
REAM
P
Perfrom Reaming passes as per
10,459.0
10,434.0
03:30
05:18
procedure HIS @ 1 fpm, & 15' left &
fight, dry drift window, clean
8/1/2018
8/1/2018
1.90
PROD1
WHPST
TRIP
P
POOH
10,434.0
76.0
05:18
07:12
8/1/2018
8/1/2018
1.00
PRODII
WHPST
PULD
P
PJSM, PUD BHA#27, pumping
76.0
0.0
07:12
08:12
managed pressure
8/1/2018
8/1/2018
3.30
PROD1
DRILL
CTOP
P
Perfrom slack management
0.0
0.0
08:12
11:30
Cut off CTC, protect a-line, stab on,
reverse circlate 5 times up to 2.5 bpm,
cut 72' of coil to find wire, test a-line,
good, cut adddonal 8' for a total of 80',
ream coil, install CTC, pull test to 35K,
good
8/1/2018
8/1/2018
1.80
PROD1
DRILL
CTOP
P
Head up a-line, MWD getting bad lest,
0.0
0.0
11:30
13:18
trouble-shoot, pump and manually pull
e-line out coil, trouble-shoot & resolve,
complete heading up, clear floor
8/1/2018
8/1/2018
1.10
PRODII
DRILL
CIRC
P
MU nozzle, stab on well, circulate
0.0
0.0
13:18
14:24
forward 1 coil volume, load ODS PDL,
pop off, break off nozzle, PJSM
8/1/2018
8/1/2018
1.00
PROD1
DRILL
PULD
P
PD BHA#28 Buildffurn Assembly
0.0
72.0
14:24
15:24
(2.4°+AKO motor, Baker Dynamus
bit), MU to coil, tag up
8/1/2018
8/1/2018
2.00
PROW
DRILL
PULD
T
Tools experiencing power issues,
72.0
72.0
15:24
17:24
trouble shoot, pop off to inspect tools,
shorted a-line, cut & re-head e4ine.
BHA failed testing from surface, PUD
tools, operating w/ single PDL
8/1/2018
8/1/2018
0.60
PRODI
DRILL
PULD
T
Unable to move BHAwith SL, line up
72.0
72.0
17:24
18:00
and pump thru both B valves and 3
Romeo valves, no success
8/1/2018
8/1/2018
0.25
PRODII
DRILL
PULD
T
Crew Change, PJSM for plan forward.
72.0
72.0
18:00
18:15
8/1/2018
8/1/2018
1.25
PROD1
DRILL
PULD
T
Switch to PD failed tools, MU INJH to
72.0
172.0
18:15
19:30
tools BHA# 28, RIH 100' non-issues,
pumping 0.5 bpm with EDC open (no-
comms)
8/1/2018
8/1/2018
1.00
PROD1
DRILL
PULD
T
Re-head SL, pull test to 700 psi
172.0
172.0
19:30
20:30
hydraulic pressure (1,600 ibs)
8/1/2018
8/1/2018
1.00
PRODII
DRILL
PULD
T
Tag up, spaceout, PUD BHA# 28, LD
172.0
0.0
20:30
21:30
tools, check bit condition (good)
8/1/2018
8/1/2018
1.00
PRODII
DRILL
PULD
T
PUIMU second build BHA# 29
0.0
72.0
21:30
22:30
8/1/2018
8/1/2018
0.25
PROW
DRILL
PULD
P
MU INJH to tools, perform surface test
72.0
72.0
22:30
22:45
(good-test)
8/1/2018
8/2/2018
1.25
PROD1
DRILL
TRIP
P
RIH, w/build BHA#29, 2.4+ako motor
72.0
5,849.0
22:45
00:00
8/2/2018
8/2/2018
0.80
PROD1
DRILL
TRIP
P
Continue IH, w/ Build BHA#29
5,849.0
10,345.0
00:00
00:48
8/2/2018
8/2/2018
0.20
PRODI
DRILL
DLOG
P
Log the K1 marker correction of plus
10,345.0
10,365.0
00:48
01:00
2.0'
8/2/2018
8/212018
0.50
PRODII
DRILL
DISP
P
Continue displacing well to drilling fluid
10,365.0
10,365.0
01:00
01:30
6/2/2018
8/212018
0.20
PROD1
DRILL
TRIP
P
Close EDC, continue IH
10,365.0
10,459.0
01:30
01:42
Page 16129 ReportPrinted: 8/22/2018
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start oeptn
Start Time
End Time
Dur(hn
Phase
Op Code
Activity Code
Time P-T.X
Operation
(fiKB)
End Depth (WB)
8/2/2018
812/2018
1.00
PROD1
DRILL
DRLG
P
OBD, 1.8 bpm at 4,413 psi FS,
10,459.0
10,555.0
01:42
02:42
BHP=3,930, WHP=514, IA=O,
OA=133
8/2/2018
8/2/2018
0.20
PROD1
DRILL
TRIP
P
TD Build Section 10,555', PUW 43 k
10,555.0
10,345.0
02:42
02:54
8/2/2018
8/2/2018
0.20
PROD1
DRILL
DLOG
P
Log the Ki marker correction of plus
10,345.0
10,363.0
02:54
03:06
0.5'
8/2/2018
8/2/2018
0.20
PROD1
DRILL
DLOG
P
Log RA marker offcal window depths
10,450.0
10,467.0
03:06
03:18
TOWS=10,435'
TOW =10,438'
BOW & RA=10,442'
8/2/2018
812/2018
1.70
PRODt
DRILL
TRIP
P
POOH, w/open EDC, pumping 1.77
10,467.0
72.0
03:18
05:00
bpm at 3,873 psi, following MP
6/2/2018
8/2/2018
2.10
PROW
DRILL
PULD
P
Tag up, space out, PUD BHA #29,
72.0
0.0
05:00
07:06
againhave difficulty sucking tools into
PDL, close tools in rams, break off
PDL, hook up tools to surface power,
orient HOT additional 90° ROHS,
successfully pull tools into PDL, bit
came out a 1-1
8/2/2018
8/2/2018
1.00
PROD1
DRILL
PULD
P
PJSM, PD BHA #30 (NOV agitator,
0.0
80.0
07:06
08:06
0.5° AKO fixed bend Iron Side motor,
RB C1 3D bit)
Slide in cart, check pack -offs, good,
MU to coil, tag up, set counters
8/2/2018
8/2!2018
1.90
PROD1
DRILL
TRIP
P
RIH w/ BHA #30, stop at 500' & test
80.0
10,360.0
08:06
10:00
tools, good
8/2/2018
8!2/2018
0.10
PROD1
DRILL
DLOG
P
Log K1 for +3
10,360.0
10,272.0
10:00
10:06
8/2/2018
8/212018
0.30
PROD1
DRILL
TRIP
P
Continue RIH
10,372.0
10,555.0
10:06
10:24
8/2/2018
812/2018
1.60
PROD1
DRILL
DRLG
P
OBD, pumping 1.5 bpm, FS = 1800
10,555.0
10,955.0
10:24
12:00
psi, circ = 5842 psi, dp = 2000 psi,
BHP = 4236, PUW = 38K
Bring up rale to 1.8 bpm, FS = 2060
psi, circ = 6783 psi, bore = 7019, CWT
= 12K, pump 5x5 sweeps @ 10,856',
drilling 1 for 1, 12.7 ppg ECD @
10,880'
802018
8/2/2018
2.00
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW = 40K, begin
10,955.0
8,676.0
12:00
14:00
pressuring up on bore from 6000 psi
to -8500 psi @ 10,902, have full
returns, no indication of CWT or WOB
drag, no increase in annular, time 5x5
sweep for EOB,
Observe -800 psi dip increase off
bottom, confer with town, POOH to
inspect tools, pressure returned to
normal once through the window in 7"
casing
8/2/2018
8/2/2018
1.00
PROD1
DRILL
WPRT
P
Confer with town again, decision
8,676.0
10,995.0
14:00
15:00
made to go back to drilling, RIW =
15.51K, perfrom MAD pass for
resistivity
Page 17129 ReportPrinted: 812 212 01 8
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Tine Log
seen Depth
Start Tme
EM Time
Dur (hr)
Passe
op code
Activity Code
Time P-T.X
Operatlon
(WD)
End Depm (rd(B)
812/2018
8/2/2018
0.70
PROD1
DRILL
DRLG
P
BOBD, pumping 1.8 bpm, FS = 1800
10,995.0
11,013.0
15:00
15:42
psi, bore = 5978 psi, circ = 5740 psi,
cip = 1978 psi, BHP = 3934 psi, PUW
= 39K, FS = 1800 psi, pump sweeps
ROP decreased to 0 fph, attempt to
drill off for 5 min, if no progress,
POOH
8/22018
8/2/2018
2.00
PROD1
DRILL
TRIP
T
POOH to inspect tools
11,013.0
80.0
15:42
17:42
8/2/2018
8/2/2018
1.75
PROD1
DRILL
PULD
T
PJSM, PUD BHA#30
80.0
0.0
17:42
19:27
8/2/2018
8/2/2018
0.50
PROD1
DRILL
PULD
T
MU BHI X-treme motor 0.4+° ako
0.0
0.0
19:27
19:57
motor
82/2018
822018
1.00
PROD1
DRILL
PULD
T
PD lateral drilling BHA #31
0.0
78.2
19:57
20:57
8/2/2018
8/2/2018
0.25
PROD1
DRILL
PULD
T
MU INJH, surface test Coiltrak tools
78.2
78.2
20:57
21:12
(good -test), continue PD
81212018
8/2/2018
1.75
PROM
DRILL
PULD
T
RIH w/Lateral BHA #31
78.2
10,350.0
21:12
22:57
82/2018
8/2/2018
0.20
PROW
DRILL
DLOG
T
Log the K1 marker correction of plus
10,350.0
10,363.0
22:57
23:09
4.5', PUW 40 k
8/2/2018
8/2/2018
0.25
PROD1
DRILL
TRIP
T
Continue IH
10,363.0
11,013.0
23:09
23:24
822018
8/3/2018
0.60
PROD1
DRILL
DRLG
P
OBD, 1.79 bpm @ 4,954 psi,
11,013.0
11,045.0
23:24
00:00
WHP=391, BHP=3,996, IA=O,
OA=169,
8/3/2018
8/3/2018
1 .93
PROD1
DRILL
DRLG
P
OBD, 1.78 bpm @ 5,231 psi,
11,045.0
11,410.0
00:00
01:55
WHP=345, BHP=4,014, IA=13,
OA=236
8/3/2018
8/3/2018
0.38
PROD1
DRILL
WPRT
P
Wiper up hole to the EOB, PUW 41 k
11,410.0
10,555.0
01:55
02:18
8/3/2018
8/3/2018
0.38
PROM
DRILL
WPRT
P
Wiper back in hole, RIW 15 k
10,555.0
11,410.0
02:18
02:41
8/3/2018
8/3/2018
2.41
PROM
DRILL
DRLG
P
BOBD, 1.79 bpm at 4,806 psi,
11,410.0
11,810.0
02:41
05:06
WHP=316, BHP=3,950, IA=33,
OA=293
813/2018
813/2018
1.10
PROM
DRILL
WPRT
P
Wiper up -hole, PUW =41K
11,810.0
10,330.0
05:06
06:12
8/32018
8/3/2018
0.70
PROD1
DRILL
WPRT
P
Wiper in-hole, RIW = 11.5K
10,330.0
11,810.0
06:12
06:54
813/2018
8/3/2018
3.50
PRO01
DRILL
DRLG
P
BOBD, pumping 1.8 bpm, FS = 1070
11,810.0
12,222.0
06:54
10:24
psi, CWT = 3K, WOB = 2.3K, BHP =
3981 psi, circ pressure = 5311 psi,
WHP = 400 psi, pump sweeps @
12,000', PUW = 42K, pump sweeps @
12,130', lower ROP beginning at
12,189'
8/32018
8/3/2018
0.30
PROM
DRILL
WPRT
P
Wiper up -hole, PUW =44K
12,222.0
11,389.0
10:24
10:42
8/3/2018
8/3/2018
0.30
PROD1
DRILL
WPRT
P
Wiper in-hole, RIW = 11.5K
11,389.0
12,222.0
10:42
11:00
8/3/2018
8/3/2018
3.00
PROD1
DRILL
DRLG
P
BOBD, pumping 1.8 bpm, FS = 1075
12,222.0
12,348.0
11:00
14:00
psi, CWT = 2K, WOB = 1.8K, circ =
5442 psi, BHP = 4086 psi, WHP = 350
psi, low ROP beginning at 12,277',
-35%Ankedte in sample from 12,335
(down to 3 fph)
8/3/2018
8/312018
2.50
PROD1
DRILL
DRLG
P
Drilling break at 12,348', short lived,
12,348.0
12,403.0
14:00
16:30
drilling with low ROP w/Ankerite in
samples, CWT = 9.5K (up to 300 fph),
WOB = 1 K, BHP = 4109 psi, WHP =
368 psi, PUW = 45K
Page 18129 Report Printed: 812212018
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Depth
Stirtnme
End Time
our (hr)
Phase
Op Code
Acdvey Code
Time P -T -X
operation
tftKB)
End Depth(N(B)
8/3/2018
8/3/2018
3.25
PROD1
DRILL
DRLG
P
Continue drilling w/ low ROP, pointing
12,403.0
12,561.3
16:30
19:45
straight down working to break
through, CWT = -5K, WOB = 3.7K,
BHP = 4075 psi, drilling break at
12,405'
8/3/2018
813/2018
0.30
PROD1
DRILL
WPRT
P
500' wiper up hole, PUW 49 k
12,561.3
12,068.0
19:45
20:03
8/3/2018
8/3/2018
0.25
PROD1
DRILL
WPRT
P
Wiper back IH, RIW 1 k
12,068.0
12,561.3
20:03
20:18
8/3/2018
8/3/2018
2.20
PROD1
DRILL
DRLG
P
BOBD, 1.82 bpm at 4,703 psi,
12,561.3
12,663.0
20:18
22:30
WHP=301, BHP=4,087, IA=374,
OA=638
"` Note: New Mud at the bit @
12,663'
8/312018
8/4/2018
1.50
PROD1
DRILL
DRLG
P
New mud at the bit, OBD 1.82 bpm @
12,663.0
12,722.0
22:30
00:00
5,176 psi, WHP=355, BHP=4,137,
IA=391, OA=648
8/412018
8/412018
3.00
PROD1
DRILL
DRLG
P
OBD, 1.81 bpm @ 5,069 psi,
12,722.0
12,850.0
00:00
03:00
WHP=378, BHP=4,155, IA=343,
OA=565
8/4/2018
814/2018
1.20
PROD1
DRILL
WPRT
P
Wiper up hole, PUW 45 k,(jog the 7"
12,850.0
10,350.0
03:00
04:12
110338'- 10,410'), jog 7" casing
8/4/2018
8/4/2018
0.20
PROD1
DRILL
DLOG
P
Log the K1 marker correction of plus
10,350.0
10,363.0
04:12
04:24
4.5'
8/4/2018
8/4/2018
1.40
PROD1
DRILL
WPRT
P
Continue wiper back in hole, RIW 14
10,363.0
12,850.0
04:24
05:48
k, had to work to bottom from
-12,400', reducing rate to work
through
8/4/2018
814/2018
3.20
PROD1
DRILL
DRLG
P
BOBD, pumping 1.8 bpm, FS = 1080
12,850.0
12,974.0
05:48
09:00
psi, CWT= -5K, WOB=1K, dp=1178
psi, BHP = 4125 psi, WHP = 347 psi
8/4/2018
8/4/2018
0.60
PROD1
DRILL
DRLG
P
Confer wl town, decison made to trip
12,974.0
12,994.0
09:00
09:36
for bit, pump sweeps, additional
sweeps timed for EOB
8/4/2018
8/4/2018
3.50
PROD1
DRILL
WPRT
P
POOH, PUW = 45K, open EDC in 7"
12,994.0
78.0
09:36
13:06
casing & jog, jogs at 5000'& 1000',
add 1 % LoTorq to mud system, tag up
8/4/2018
8/4/2018
1.50
PRODI
DRILL
PULD
P
PJSM, PUD BHA#31, replace quick
78.0
0.0
13:06
14:36
test union o -rings, bit came out a 2-2
wl 1 missing nose cutter & 1 reamer
cutter (2-2), motor missing fill port plug
8/4/2018
8/4/2018
2.00
PROD1
DRILL
PULD
P
Swap lower section of coil track (new
0.0
78.0
14:36
16:36
resistivity tool per geology request)
PD BHA #32 (new agitator, 0.4'+AKO
motor, RS HYC 88 bit), slide in cart,
Check pack -offs, MU to coil, tag up,
set counters
8/4/2018
814/2018
1.91
PROD1
DRILL
TRIP
P
RIH w/ BHA#32, close EDC, test tools
78.0
10,350.0
16:36
18:30
@ 500', good, open EDC, FS = 1000
psi
8/4/2018
814/2018
0.20
PROD?
DRILL
DLOG
P
Log the K1 marker correction of plus
10,350.0
10,363.0
18:30
18:42
4.0', PUW 38 k
8/4/2018
8/4/2018
0.20
PROD1
DRILL
TRIP
P
Continue IH, RIW 14 k
10,363.0
11,160.0
18:42
18:54
8/4/2018
8/4/2018
0.20
PROW
DRILL
DLOG
P
Perfrom Mad Pass
11,160.0
11,026.0
18:54
19:06
814/2018
8/4/2018
0.74
PROD1
DRILL
TRIP
P
Continue IH,. RIW 14
11,026.0
12,994.0
19:06
19:51
814/2018
8/4/2018
1.30
PROD1
DRILL
DRLG
P
BOBD, 1.81 bpm at 5,328 psi,
12,994.0
13,014.0
19:51
21:09
diff --1,180 psi, WHP=298, BHP=4,125,
IA=194, OA=487
Page 19129 Report Printed: 812 212 01 8
Operations Summary (with Timelog Depths)
3H-31
qaftg:
NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stent Time
EWTene
Dur(hr)
Phase
op cDde
Activity Code
Time P.T-x
Operahon
End Depth(NKB)
8/4/2018
8/5/2018
2.85
PROM
DRILL
DRLG
P
BOBD, 1.70 bpm at 4,925 psi,
13,026.0
21:09
00:00
diff -1,180 psi, WHP=298, BHP=4,125,
IA=194, OA=487
P13,026.0
8/5/2018
8/5/2018
PROM
00:00
00:00
8/5/2018
8/5/2018
0.30
PROD1
DRILL
DRLG
P
BOBD, 1.70 bpm at 4,925 psi,
13,039.0
00:00
00:18
diff -1,180 psi, WHP=298, BHP=4,125,
IA=194, OA=487
8/5/2018
8/5/2018
1.50
PRODt
DRILL
DRLG
P
OBD, 1.80 bpm at 5,306 psi,
13,039.0
13,110.0
00:18
01:48
diff -1,180, WHP=324, BHP=4,145,
IA=451, OA=697
8/5/2018
8/5/2018
0.10
PROD1
DRILL
DRLG
P
PUW 38 k,
13,110.0
13,110.0
01:48
01:54
8/5/2018
815/2018
2.20
PROM
DRILL
DRLG
F7_
BOBD, 1.81 bpm @ 5,359 psi,
13,110.0
13,232.0
01:54
04:06
diff --1,180 psi, WHP=323, BHP=4,145,
IA=452, OA=698
8/5/2018
8/5/2018
2.90
PROM
DRILL
DRLG
P
OBD, 1.81 bpm at 5,424 psi,
13,232.0
13,349.0
04:06
07:00
diff -1,180 psi, WHP=324, BHP=4,146,
IA=452, OA=699
8/5/2018
8/5/2018
0.90
PROD1
DRILL
DRLG
P
OBD, 1.82 bpm @ 5461 psi, BHP =
13,349.0
13,395.0
07:00
07:54
4140 psi, WHP = 311 psi, dp = 1267,
CWT =-3K, WOB = .75K
8152018
8/5/2018
0.30
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW = 48K
13,395.0
12,453.0
07:54
08:12
8/52018
8/5/2018
0.50
PR0D1
DRILL
WPRT
P
Wiper in-hole, RIW=6K, worked to
13,395.0
08:12
08:42
gel to bottom from -12,750'
8/512018
8/5/2018
2.00
PROD1
DRILL
DRLG
P
BOBD, FS = 1180 psi @ 1.8 bpm,
13,467.0
08:42
10:42
CWT = -5K WOB = 1.3K BHP = 4077
psi, WHP = 161 psi, begin adding
P12,453.0
additional 0.5% LoTorq to system
8/5/2018
8/5/2018
2.00
PRODt
DRILL
DRLG
P
Drilling, 1.8 bpm, circ pressure = 5427
13,524.0
10:42
12:42
psi, BHP = 4074 psi, CWT = OK, WOB
= 0.8K, dp = 1261 psi, reduce rate to
allow DD to capture survey, PUW =
49K @ 13,510', BHA wiper, grab
survey, work to get to bottom,
stuggling w/ weight transfer
Begin sending bead pills
8/52018
8152018
2.00
PRODt
DRILL
DRLG
P
Drilling, 1.8 bpm, CWT =-3, WOB =
13,524.0
13,621.0
12:42
14:42
1 K, dp = 1315, PUW = 52K @
13,539', experiencing vibrations up to
4's, marginal benefit in weight transfer
8/52018
8/5/2018
1.20
PROM
DRILL
DRLG
P
Drilling, 177 bpm, FS = 1139 psi, rip =
13,621.0
13,660.0
14:42
15:54
1369 psi, CWT = 2.8K, WOB = 0.8K,
BHP = 4096, continue struggling wl
weight transfer
8/52018
8/5/2018
0.40
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW =51K
13,660.0
12,293.0
15:54
16:18
815/2018
8/5/2018
0.60
PROD1
DRILL
WPRT
P
Wiper in-hole, RIW=4K
12,293.0
13,660.0
16:18
16:54
8/5/2018
8/5/2018
3.25
PROD1
DRILL
DRLG
P
BOBD, lubed/beaded pill exiting bit,
13,660.0
13,904.0
16:54
20:09
1.8 bpm, CWT =IK, WOB =0.5K, dp
= 1475 psi
8/5/2018
8/5/2018
0.10
PROD1
DRILL
WPRT
P
PUH, BHA wiper up hole, PUW 37 k
13,904.0
13,904.0
20:09
20:15
8/5/2018
8/5/2018
1.25
PROM
DRILL
DRLG
P
BOBD, 1.81 bpm at 5,673 psi,
13,904.0
13,951.0
20:15
21:30
Diff=1,203, WHP=238, BHP=4,319,
IA=576, OA=625
8/5/2018
8/5/2018
1.75
PROM
DRILLWPRT
P
Motor work fail off, pull heavy, PUW 54
13,951.0
10,350.0
21:30
23:15
k, Wiper up hole, for tie in & jet the 7",
jog 7" w/sweep, pump bottoms up
Page 20129 Report Printed: 8/2212M
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Slant Depth
Stan Time
End Time
Dw(hn
Phase
op Code
Activity Code
Time P -T -x
Operation
Me)
End Depth(11xB)
8/5/2018
8/5/2018
0.20
PROD1
DRILL
CLOG
P
Log K1 marker correction of plus 7.0',
10,350.0
10,367.0
23:15
23:27
PUW 35 k
8/5/2018
8/6/2018
0.55
PRODt
DRILL
WPRT
P
Perform Static Pressure survey --12.61
10,367.0
10,781.0
23:27
00:00
ppg, continue wiper in hole
Sesor Depth TVD=5931.94'
Annular Press.=3,889 psi
Current MW=8.58 ppg
8/6/2018
8/6/2018
1.50
PROD1
DRILL
WPRT
P
Continue wiper back in hole, RIW 15 k
10,781.0
13,730.0
00:00
01:30
8/6/2018
8/6/2018
0.10
PROD1
DRILL
WPRT
P
Set down do to weight transfer, PUH,
13,730.0
13,730.0
01:30
01:36
wait for beads
8/6/2018
8/6/2018
0.50
PROM
DRILL
WPRT
P
Continue IH, 2-4 k positive CTSW with
13,730.0
13,951.0
01:36
02:06
1.0 Ib beaded pill
8/6/2018
8/6/2018
0.10
PROM
DRILL
DRLG
P
Set down 4 k DHWOB, PUH, restart
13,951.0
13,951.0
02:06
02:12
3.8 k
8/6/2018
8/6/2018
1.40
PROM
DRILL
DRLG
P
OBD, 1.81 bpm at 5,580 psi FS,
13,951.0
13,955.0
02:12
03:36
DifF-1,205 psi, WHP=251,
BHP=4,268, IA=521, OA=566
8/612018
8/6/2018
4.00
PROM
DRILL
DRLG
P
Drilling break, 45-50 fph, OBD, 1.81
13,955.0
14,132.0
03:36
07:36
bpm at 5,698 psi, Diff=1,205 psi,
WHP=249, BHP=4,226, IA=532,
OA=574
8/6/2018
8/6/2018
3.40
PROM
DRILL
DRLG
P
Drilling, 1.8 bpm, BHP = 4184 psi,
14,132.0
14,243.0
07:36
11:00
WHP = 125 psi, CWT = -3K, WOB =
2.35K, pumping beaded pills
8/6/2018
8/6/2018
1.00
PROM
DRILL
DRLG
P
Plan from town, point straight up and
14,243.0
14,254.0
11:00
12:00
aquire top of C -Sands
Drilling, 1.8 bpm, CWT= 7K, WOB
_ .2K, BHP = 4096 psi
8/6/2018
816/2018
1.40
PROD1
DRILL
WPRT
P
500' wiper, stacking weight RIH,
14,254.0
14,254.0
12:00
13:24
reduce rate, struggling to get to
bottom
8/6/2018
8/6/2018
4.60
PROD1
DRILL
DRLG
P
Drilling, 1.8 bpm, FS = 1264 psi @ 1.8
14,254.0
14,266.0
13:24
18:00
bpm, CWT = -6.5K, WOB = 3K, BHP =
4170 psi, low ROP (2-4 fph)
8/6/2018
8/6/2018
2.00
PROD1
DRILL
DRLG
P
Continued drilling w/ low ROP, 1.8
14,266.0
14,284.0
18:00
20:00
bpm, CWT= 1.7K, WOB = 3.5K, BHP
= 4300 psi, drilling break at -14,267',
ROP again dropped at 14,281'
8/6/2018
816/2018
2.10
PROD1
DRILL
DRLG
P
Drilling, low ROP, 1.8 bpm, CWT
14,284.0
14,289.0
20:00
22:06
=AK WOB = 3.6K, BHP = 4269 psi,
WHP = 243, dp = 1341 psi, decision
made to wiper up to window & obtain
SBHP, pump 5 x 10 (lo -vis & hi -vis
bead pills)
8/6/2018
8/6/2018
1.28
PROD1
DRILL
WPRT
P
Wiper to window, PUW=42K
14,289.0
10,442.0
22:06
23:22
8/6/2018
8/7/2018
0.62
PROM
DRILL
WPRT
P
PU through window, jog the 7" clean,
10,442.0
10,343.0
23:22
00:00
1
1
pumping bottoms up x 2
8!7/2018
8/72018
0.50
PROD1
DRILL
WPRT
P
Continue jogging 7", circulating
10,343.0
10,350.0
00:00
00:30
bottoms up.
8172018
8/72018
0.20
PROD1
DRILL
DLOG
P
Log the K1 marker correction of plus
10,350.0
10,370.0
00:30
00:42
4.0'
8172018
8/72018
0.90
PROD1
DRILL
WPRT
P
Perform Static Pressure Survey, bleed
10,370.0
10,370.0
00:42
01:36
well down 12.08 ppg (3,726 psi),
monitor well, BHP=3,874 psi/12.565
Ppg
8772018
8/7/2018
1.20
PROM
DRILL
WPRT
P
Wiper back IH, RIW 15 k
10,370.0
14,289.0
01:36
02:48
8/7/2018
8/7/2018
4.20
PROD1
DRILL
DRLG
P
SOBD, 1.8 bpm at 5,825 psi,
14,289.0
14,302.0
02:48
07:00
1
Diff=1,260 psi, WHP=226,
BHP=4,282, IA=395, OA=496
Page 21/29 Report Printed: 8/221 01 6
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start DePM
StanThe
End Time
Dur (hr)
Phase
Op Code
Activity CDde
Time P -T -X
Operation
(fixe)
End Dep1h(fixe)
8/7/2018
8/7/2018
2.50
PRODt
DRILL
WPRT
P
Wiper up to 7" Jog window & 7" csg.
14,302.0
10,369.0
07:00
09:30
8/7/2018
817/2018
1.25
PRODt
DRILL
DLOG
P
Log K-1, Correct +3, RIH, stack at
10,369.0
10,369.0
09:30
10:45
window. Turn TF 30R, go by. RIH. Call
from town, decided to log RA to
ensure WS has not moved. Log RA for
a +1.
8/7/2018
8/7/2018
1.90
PROD1
DRILL
WPRT
P
Trip to bottom in prep for swab wiper.
10,369.0
14,305.0
10:45
12:39
Time out 10 x 10 sweep to bit. Tag TD
@ 14305'
8/7/2018
817/2018
3.30
PROD1
DRILL
WPRT
P
Start wiper to swab, chasing out 10 x
14,305.0
78.2
12:39
15:57
10 sweep w/ beads. 42K off BTM,
pumping @ 1.81 BPM CP 5829, WHIP
134 PSI. At 500', Jog back up to
1000', then pooh to surface. Tag up @
78.19 (78.12 BHA)
8/7/2018
8!7/2018
1.75
PROD1
DRILL
WPRT
P
RIH
78.2
10,350.0
15:57
17:42
817/2018
8/7/2018
0.20
PROD1
DRILL
DLOG
P
Log K1 marker correction of plus 5.0'
10,350.0
10,368.0
17:42
17:54
8/7/2018
8/7/2018
0.10
PROD1
DRILL
WPRT
P
Contiinue IH
10,368.0
10,445.0
17:54
18:00
817/2018
8/7/2018
0.25
PROD1
DRILL
TRIP
T
Set down at the bottom of window @
10,445.0
10,445.0
18:00
18:15
HS, PUH, attempt again @ 30R and
30L. unsuccessful, crew change
8/7/2018
8/7/2018
0.25
PROD1
DRILL
TRIP
T
Attempt to pass through window @
10,445.0
16,445.0
18:15
18:30
HS, unsuccessful, discussed with
town on plan forward. decision was
made to POOH to inspect BHA
877/2018
81712018
2.00
PROD1
DRILL
TRIP
T
POOH, opening the EDC at 5,420'
10,445.0
78.2
18:30
20:30
8/7/2018
8/7/2018
0.10
PROD1
DRILL
PULD
T
PJSM, tag up, space out+ 1.0'
78.2
7F2-
20:30
20:36
817/2018
8/7/2018
1.20
PROD1
DRILL
PULD
T
PUD, drilling BHA#32
78.2
0.0
20:36
21:48
Note: Bit Gauge 5-4
8/7/2018
817/2018
0.20
PROD1
DRILL
PULD
T
LD motor/agitator/FVS
0.0
0.0
21:48
22:00
8/7/2018
817/2018
0.25
PROD1
DRILL
PULD
P
Function test BOPE
0.0
0.0
22:00
22:15
8/7/2018
817/2018
1.25
PROD1
DRILL
PULD
T
PD Redress BHA# 33
0.0
62.7
22:15
23:30
8/7/2018
817/2018
0.25
PROD1
DRILL
PULD
T
Stab UOC, surface test tools (good-
62.7
62.7
23:30
23:45
test)
8/7/2018
8/7/2018
0.10
PROD1
DRILL
PULD
T
Stab INJH, tag up reset counters
62.7
62.7
23:45
23:51
8/7/2018
8/8/2018
0.15
PROD1
DRILL
TRIP
T
RIH
62.7
62.7
23:51
00:00
8/8/2018
8/8/2018
1.80
PROD1
DRILL
TRIP
T
RIH, w/Re-dress BHA# 33 with
62.7
10,350.0
00:00
01:48
crayola mill (2.79 OD no-go)
8/8/2018
8/8/2018
0.20
PROD1
DRILL
DLOG
T
Log the Ki marker correction of plus
10,350.0
10,368.0
01:48
02:00
5.0'
8/8/2018
8/812018
0.10
PROD1
DRILL
TRIP
T
Continue IH
10,368.0
10,407.0
02:00
02:06
8/6/2018
8/8/2016
1.30
PROD1
DRILL
REAM
T
Reaming 1.8 bpm @ 4,789 psi,
10,407.0
10,462.0
02:06
03:24
Diff= -399 psi, WHP=192, BHP=3934,
IA=84, OA=233, HS, 30 LOHS, HS, 30
ROHS, HS, dry drift clean to 10,462'
8/8/2018
8/8/2018
2.35
PROD1
DRILL
TRIP
T
Open EDC, POOH
10,462.0
62.0
03:24
05:45
8/8/2016
8/8/2018
1.00
PROD1
DRILL
PULD
T
PJSM. PUD, Lay down BHA.
62.0
0.0
05:45
06:45
Page 22129 ReportPrinted: 812212018
Operations Summary (with Timelog Depths)
3H-31
Gog:
NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
seen Depth
Start Time
Ertl Time
our (hr)
Phase
Op code
Adlulty Code
Time P-T-X
Operation
((d(B)
End Depth ifil(B)
8/8/2018
8/8/2018
1.75
PROD1
DRILL
PULD
T
PJSM, PD BHA#34
68.0
68.0
WAS
08:30
8/8/2018
8/8/2018
3.25
PROD1
DRILL
TRIP
T
RIH, stop @ pump to test agitator,
68.0
10,438.0
08:30
11:45
good. CRIH. Log K1 for a +2
correction. Drift thru window cleanly.
Stop trouble time.
8/8/2018
8/8/2018
0.50
PROD1
DRILL
TRIP
P
Continue RIH, clean down to BTM &
10,438.0
14,304.0
11:45
12:15
1
1
confirm TD @ 14,304'
8/8/2018
8/8/2018
3.75
PROD1
DRILL
DISP
P
Get 12.8 KWF beaded liner pill lined
14,304.0
68.0
12:15
16:00
up to pump down coil. Move pipe
slowly until liner pill gets to the bit.
Lay in beaded pill in open hole. Pump
12.8 KWF to surface.
8/8/2018
8/8/2018
0.50
PROD1
DRILL
OWFF
P
Tag up. Watch well for flow & perform
68.0
68.0
16:00
16:30
PJSM.
8/8/2018
8/8/2018
1.75
PROD1
DRILL
PULD
P
Inspect !2' of CT above connector.Lay
68.0
0.0
16:30
18:15
down BHA# 34.
8/8/2018
8/812018
0.50
COMPZ1
CASING
PUTB
P
Prep Rig Floor for liner operations
0.0
18:15
18:45
8/8/2018
8/812018
2.00
COMPZ1
CASING
PUTB
P
PJSM, PU/MU Lower liner assembly
0.0
630.1
18:46
20:45
W20 jts of slotted liner & shorty
deployment sleeve
8/8/2018
8/8/2018
0.25
COMPZ1
CASING
PULD
P
PU/MU Coiltrak tools, perform surface
630.1
675.5
20:45
21:00
test (good-test)
8/8/2018
8/8/2018
1.60
COMPZ1
CASING
RUNL
P
Tag up, reset counters, RIH, set down
675.5
10,376.0
21:00
22:36
@ TOW, PUW 41 k
8/8/2018
8/8/2018
0.20
COMPZ1
CASING
RUNL
P
Correct to the EOP flag, minus 3.9'
10,376.0
10,376.0
22:36
22:48
8/8/2018
8/8/2018
0.20
COMPZ1
CASING
RUNL
P
Continue IH through window clean
10,376.0
10,955.0
22:48
23:00
8/812018
8/8/2018
0.20
COMPZ1
CASING
RUNL
P
Log the K1 marker correction of plus
10,955.0
10,982.0
23:00
23:12
4.5'
8/8/2018
8/912018
0.80
COMPZ1
CASING
RUNL
P
Continue IH
10,982.0
13,496.0
23:12
00:00
819/2018
8/9/2018
0.25
COMPZ1
CASING
RUNL
P
Continue RIH with lower liner
13,496.0
14,170.0
00:00
00:15
assembly w120 jts of slotted liner
819/2018
8/9/2018
0.67
COMPZ1
CASING
RUNL
T
Set down 14,170', PUH PUW 50 k,
14,170.0
14,304.0
00:15
00:55
work pipe towards bottom
8/9/2018
8/9/2018
0.20
COMPZ1
CASING
RUNL
P
Liner on bottom, bring pump up to
14,304.0
13,646.0
00:55
01:07
1.44 bpm at 6,000 psi, PUW 38 k, stop
and remove liner length from BHA,
line up across the top
8/9/2018
8/9/2018
2.80
COMPZ1
CASING
TRIP
P
POOH BHA# 35, pumping across the
13,646.0
45.0
01:07
03:55
top
8/9/2018
8/9/2018
0.50
COMPZ1
CASING
PULD
P
PJSM, LD Liner Running Tools
45.0
0.0
03:55
04:25
8/9/2018
8/9/2018
4.00
COMPZ1
CASING
PUTB
P
PU/MU Upper A Lateral Liner -
0.0
1,467.0
04:25
08:25
Assembly
8/9/2018
8/9/2018
2.58
COMPZ1
CASING
RUNL
P
RIH w/ "A" Liner upper section. (44 jts)
1,467.0
13,283.0
08:25
11:00
w/ Liner top billet. Stack out @ 13,283'
8/912018
8/92018
2.75
COMPZ1
CASING
RUNL
T
Work pipe, get by 13,283' after 2
13,283.0
13,283.0
11:00
13:45
cycles. Work it down stacking out in
various depths. Get down to 13,595'.
Cycled pipe & lost ground.
8/9/2018
8/92018
0.75
COMPZ1
CASING
RUNL
T
Decision made to PUH 1000'to
12,300.0
13,283.0
13:45
14:30
12,300'. RBIH, no issues until 13283'.
Cylced pipe several times, no go.
819/2018
8/9/2018
2.25
COMPZ1
CASING
TRIP
T
Decision made to POOH to surface.
13,283.0
1,467.0
14:30
16:45
8/9/2018
8/9/2018
2.09
COMPZ1
CASING
PULD
T
Tag up. Flow check. PJSM. Lay down
1,467.0
724.3
16:46
1850
1
BHA, Billet & 22 jts of liner.
Page 23129 Report Printed: 8/22/2018
Operations Summary (with Timelog Depths)
Iting
3H-31
L�nocoPhilhps
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
sten Depth
SW Time
End Tune
Dur (hr)
Plisse
Op code
AcNly Cede
Tine P-T-k
Operedon
(IIKa)
End Depth (110)
8/9/2018
8/912018
0.42
COMPZt
CASING
PULD
T
PJSM, PU/MU Coiltrak tools, surface
724.3
768.6
18:50
19:15
test (good-test)
8/9/2018
8/912018
1.73
COMPZ1
CASING
RUNL
T
RIH, with Middle A Liner Assembly
768.6
11,045.0
19:15
20:59
w/22 jts of slotted Liner, weight check
above window 42 k
8/9/2018
8/9/2018
0.15
COMPZ1
CASING
RUNL
T
Log K1 marker plus 1.0', did not
11,045.0
11,045.0
20:59
21:08
change depth.
8/9/2018
8/9/2018
0.70
COMPZ1
CASING
RUNL
T
Continue IH w/liner
11,045.0
13,672.0
21:08
21:50
8/912018
8/9/2018
0.20
COMPZ1
CASING
RUNL
P
PUW, 43 k, set back down, bring
13,672.0
12,948.4
21:50
22:02
pump online 1.4 bpm at @ 5,917 psi,
0.78 bpm returns, PUW 40 k
- TOL= 12948.7'
8/912018
8/9/2018
COMPZ1
CASING
RUNL
P
Remove liner length from counters,
12,948.4
12,916.7
22:02
22:02
line up across the top
6/912018
8110/2018
1.96
COMPZ1
CASING
TRIP
P
POOH, BHA#37
12,916.7
4,291.0
22:02
00:00
8/1012018
811012018
0.75
COMPZ1
CASING
TRIP
P
Continue POOH w/ BHA #35
4,291.0
44.5
00:00
00:45
8/10/2018
8110/2018
0.50
COMPZ1
CASING
OWFF
P
PJSM, check well for flow
44.5
44.5
00:45
01:15
811012018
8/10/2018
0.75
COMPZ1
CASING
PULD
P
LD Setting tools BHA # 37
44.5
0.0
01:15
02:00
6/10/2018
8/10/2018
1.75
COMPZ1
CASING
PULD
P
Pick-up liner run #3.
0.0
744.5
02:00
03:45
8/1012018
8/10/2018
3.00
COMPZ1
CASING
RUNL
P
RIH w/ Liner run #3, tie in for+1' corr.
744.5
12,947.0
03:45
06:45
Set @ 12,947'. Pump off.
8/1012018
8/10/2018
2.25
COMPZ1
CASING
TRIP
P
Trip out.
12,947.0
44.5
06:45
09:00
8110/2018
8/1012018
0.80
COMPZ1
CASING
PULD
P
Tag up. Check well for flow. PJSM.
44.5
0.0
09:00
09:48
Break off & lay down tools.
8/10/2018
8/10/2018
1.00
PROD2
STK
PULD
P
PJSM; Pick up drilling BHA. BHA # 39
0.0
78.2
09:48
10:48
8/10/2018
8110/2018
2.75
PROD2
STK
TRIP
P
RIH w/ BHA# 39, Drilling BHA. Test
78.2
12,244.0
10:48
13:33
Agitator @ 500', good. Continue RIH,
tie in for + 1. Dry lag Billet @ 12,244.
Drilling mud @ the bit,
8/10/2018
8/10/2018
1.50
PROD2
STK
DISP
P
Swap hole over to 8.6 used drilling
12,244.0
12,244.0
13:33
15:03
mud, catch formate sample from open
hole.
8/10/2018
8/10/2018
2.60
PROD2
STK
KOST
P
Fluid swap complete, Start kick off of
12,244.0
12,253.0
15:03
17:39
billet. 20L TF. WHP 145 psi, CP 5331,
Rate 1.76 BPM, @ Whir, 27hr, and
107hr,
8/10/2018
8/10/2018
0.20
PROD2
DRILL
DRLG
P
Increase WOB, drill ahead, 1.77 bpm
12,253.0
12,282.0
17:39
17:51
@ 5,233 psi, WHP=139, BHP=4,157,
IA=318, OA=343
8/10/2018
8/10/2018
0.20
PROD2
DRILL
WPRT
P
PUH, PUW 38 k, dry drift kickoff point
12,282.0
12,213.0
17:51
18:03
(Billet) clean.
8/10/2018
8/1012018
0.20
PROD2
DRILL
WPRT
P
RBIH
12,213.0
12,282.0
18:03
18:15
8/1012018
8/10/2018
2.00
PROD2
DRILL
DRLG
P
BOBD, 1.78 bpm @ 5,221 psi,
12,282.0
12,559.0
18:15
20:15
WHP=139, BHP=4,151, IA=319,
OA=344
8/1012018
8/1012018
0.15
PROD2
DRILL
WPRT
P
BHA wiper up hole, PUW 45 k
12,559.0
12,559.0
20:15
2024
8/1012018
8/10/2018
0.75
PROD2
DRILL
DRLG
P
BOBD, 1.78 bpm @ 1.78 bpm @
12,559.0
12,650.0
20:24
21:09
5,221 psi, WHP=145, BHP=4,164,
IA=319,OA=344
8/10/2018
8/10/2018
0.20
PROD2
DRILL
WPRT
P
Wiper up hole PUW 40 k
12,650.0
12,265.0
21:09
21:21
1
1
Page 24129
Report Printed: 812212018
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Simi Depth
stmt Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P -T-%
Opemson
(flKa)
End DePm(NKB)
8/10/2018
8110/2018
0.20
PROM
DRILL
WPRT
P
Wiper back in hole, RIW 7.5 k
12,265.0
12,650.0
21:21
21:33
8110/2018
8/10/2018
1.55
PROM
DRILL
DRLG
P
BOBD, 1.8 bpm @ 5,255 psi,
12,650.0
12,822.0
21:33
23:06
WHP=155, BHP=4,161, IA=320,
OA=345
8/10/2018
8/10/2018
0.20
PROD2
DRILL
WPRT
P
Short BHA Wiper up hole, PUW 39 k
12,822.0
12,822.0
23:06
23:18
8/10/2018
8/11/2018
0.70
PROD2
DRILL
DRLG
P
BOBD, 1.77 @ 5,224 psi, WHP=153,
12,822.0
12,920.0
23:18
00:00
BHP=4,176, IA=322, OA=348
8111/2018
8/11/2018
1.85
PROM
DRILL
DRLG
P
OBD, 1.77 @ 5,224 psi, WHP=153,
12,920.0
13,036.3
00:00
01:51
BHP=4,176, IA=322, OA=348
8/11/2018
8/11/2018
0.88
PROD2
DRILL
WPRT
P
Wiper up hole to the window, PUW 48
13,036.3
10,340.0
01:51
02:43
k
8/11/2018
8/11/2018
0.75
PROD2
DRILL
WPRT
P
Jog the 7" clean wfsweep and bottoms
10,340.0
10,350.0
02:43
03:28
up.
8/11/2018
8/11/2018
0.20
PROD2
DRILL
DLOG
P
Log the K1 marker correction of plus
10,350.0
10,368.0
03:28
03:40
4.5'
8/11/2018
8/11/2018
0.80
PROM
DRILL
WPRT
P
Wiper back in hole, RIW 14 k
10,368.0
13,036.0
03:40
04:28
8/11/2018
8/11/2018
7.50
PROD2
DRILL
DRLG
P
OBD, 1.81 bpm @ 4721 psi,
13,036.0
13,387.0
04:28
11:58
WHP=133, BHP=4,149, IA=276,
OA=352. Pull several BHA wipers
j
along the way. Pull early 800' wiper.
8/11/2018
8/11/2018
0.70
PROD2
DRILL
WPRT
P
Pull 800'wiper.
13,387.0
12,587.0
11:58
12:40
8/11/2018
8/11/2018
0.33
PROD2
DRILL
WPRT
P
Wiper, RBIH
12,587.0
13,387.0
12:40
13:00
8/11/2018
8/11/2018
6.50
PROM
DRILL
DRLG
P
OBD, 1.81 bpm @ 4863 psi,
13,387.0
13,580.0
13:00
19:30
WHP=197, BHP=4,145, IA=420,
OA=440.
8/11/2018
8/11/2018
1.25
PROD2
DRILL
DRLG
P
OBD, 1.77 bpm @ 4,747 psi,
13,580.0
13,650.0
19:30
20:45
WHP=327, BHP=4,226, IA=475,
OA=487
8/11/2018
8/11/2018
1.20
PROD2
DRILL
WPRT
P
PUH, PUW 55 k, Wiper up hole to the
13,650.0
10,350.0
20:45
21:57
1window,
8111/2018
8/11/2018
0.50
PROD2
DRILL
WPRT
P
Jog the 7" clean, w/sweep & bottoms
13,350.0
13,350.0
21:57
22:27
up.
8111/2018
8/11/2018
0.20
PROD2
DRILL
DLOG
P
Log the K1 marker (plus 4.5')
13,350.0
10,368.0
22:27
22:39
8/11/2018
8/11/2018
1.05
PROD2
DRILL
WPRT
P
Wiper back in hole, RIW 15 k
10,368.0
13,650.0
22:39
23:42
8/11/2018
8/12/2018
0.29
PROD2
DRILL
DRLG
P
BOBD, 1.8 bpm @ 4,673 psi FS,
13,650.0
13,677.0
23:42
00:00
WHP=335, BHP=4,234, IA=437,
OA=487
8/12/2018
811212018
2.34
PROD2
DRILL
DRLG
P
OBD, 1.81 bpm @ 4,981 psi,
13,677.0
13,709.0
00:00
02:20
WHP=333, BHP=4,230, IA=476,
OA=509
8/12/2018
8/12/2018
1.50
PROD2
DRILL
DRLG
P
OBD, 1.81 bpm @ 5,201 psi,
13,709.0
13,727.0
02:20
03:50
WHP=333, BHP=4,227, IA=476,
OA=509
8/12/2018
8/1212016
6.75
PROD2
DRILL
DRLG
P
OBD, 1.81 bpm @ 5,277 psi,
13,727.0
13,899.0
03:50
10:35
WHP=322, BHP=4,237, IA=500,
OA=526
8/1212018
8/12/2018
5.25
PROD2
DRILL
DRLG
P
10 bbls pill of beads (1 LB/bbl) @ the
13,899.0
14,015.0
10:35
15:50
bit. Continue drilling, 1.76 bpm @
5,2712 psi, WHP=304, BHP=4,300,
IA=533, OA=557
8/12/2018
8/12/2018
1.00
PROM
DRILL
WPRT
P
PU 48k, Pull window wiper.
14,015.0
10,350.0
15:50
16:50
1
8/1212018
8/12/2018
0.20
PROM
DRILL
DLOG
P
Log the K1 correction of plus 6.0'
10,350.0
10,350.0
16:50
17:02
1
Page 25129 Report Printed: 8122/2018
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Tim
End Time
Dur(ho
Phase
Op code
Ac Ky code
TMPTX
Openadon
(MB)
End Depth(ftKB)
8/12/2018
8/12/2018
0.42
PROD2
DRILL
WPRT
P
Jog the 7" clean w/sweep
10,350.0
10,350.0
17:02
17:27
8/12/2018
8/12/2018
1.55
PROD2
DRILL
WPRT
P
Wiper back in hole,
10,368.0
14,015.0
17:27
19:00
8/12/2018
8/1212018
0.40
PROD2
DRILL
DRLG
P
BOBD, 1.78 bpm @ 5,192 psi,
14,015.0
14,026.0
19:00
19:24
WHP=161, BHP=4,256, IA=569,
OA=582
8/12/2018
8/12/2018
0.40
PROM
DRILL
WPRT
P
PU, heavy PUW 58 k, perform short
14,026.0
14,026.0
19:24
19:48
mini wiper up hole, work coil back to
bottom.
8/12/2018
8/13/2018
4.19
PROD2
DRILL
DRLG
P
BOBO, 1.79 bpm @ 5,062 psi,
14,026.0
14,154.0
19:48
00:00
WHP=158, BHP=4,326, IA=571,
OA=582
8/13/2018
8/13/2018
2.75
PROD2
DRILL
DRLG
P
OBD hard spot, 1.79 bpm at 5,599 psi,
14,154.0
14,207.0
00:00
02:45
WHP=167, BHP=4,343, IA=592,
OA=594
6/13/2018
8/13/2018
1.50
PROD2
DRILL
DRLG
P
Drilling Break, OBD hard spot, 1.79
14,207.0
14,223.0
02:45
04:15
bpm at 5,599 psi, WHP=167,
BHP=4,343, IA=592, OA=594
8/13/2018
8/13/2018
10.40
PROD2
DRILL
DRLG
P
OBD hard spot, 1.77 bpm at 5,521 psi,
14,223.0
14,415.0
04:15
14:39
WHP=175, BHP=4,314, IA=594,_
OA=594
8/132018
8/13/2018
0.60
PROD2
DRILL
WPRT
P
Pick-up 47k. Wiper up for 1000'
14,415.0
13,415.0
14:39
15:15
8/13/2018
8/13/2018
1.25
PROD2
DRILL
WPRT
P
Wiper back down to depth. Had to
13,415.0
14,415.0
15:15
16:30
work back down with beads.
8/13/2018
8/14/2018
7.50
PROD2
DRILL
DRLG
P
OBD 1.76 bpm at 5446 psi,
14,415.0
14,580.0
16:30
00:00
WHP=203, BHP=4,318, IA=492,
OA=523
8/14/2018
8/14/2018
0.30
PROD2
DRILL
DRLG
P
OBD, 1.76 bpm at 5,634 psi,
14,580.0
14,588.0
00:00
00:18
Diff-1090 psi, WHP=169, BHP=4,368,
IA=630, OA=627
8/14/2018
8/142018
0.20
PROD2
DRILL
WPRT
P
Short BHA wiper up hole, PUW 56 k
14,588.0
14,588.0
00:16
00:30
1
1work pipe back to bottom
8/1412018
8/14/2018
2.20
PROD2
DRILL
DRLG
P
BOBD, 1.76 bpm @ 5,378 off bottom,
14,588.0
14,623.0
00:30
02:42
Diff-1,100 psi, WHP=186,
BHP=4,398, IA=661, OA=653
8/14/2018
8/14/2018
0.20
PROD2
DRILL
WPRT
P
BHA Wiper uphole, PUW 55 k, work
14,623.0
14,623.0
02:42
02:54
pipe back to bottom
8/14/2018
8/14/2018
1.50
PROD2
DRILL
DRLG
P
BOBD, 1.76 bpm @ 5,378 off bottom,
14,623.0
14,643.0
02:54
04:24
Diff=1,100 psi, WHP=186,
BHP=4,398, IA=661, OA=653
8/14/2018
8/14/2018
0.20
PROD2
DRILL
WPRT
P
PUH PUW 47 k, circulate beads down
14,643.0
14,643.0
04:24
04:36
1
Ihole
8/14/2018
8/142018
2.40
PROD2
DRILL
DRLG
P
Beads turned comer, BOBD, 1.76 bpm
14,643.0
14,648.5
04:36
07:00
@ 5,378 off bottom. Diff=1,100 psi,
WHP=186, BHP=4,398, IA=661,
OA=653
8/142018
8/142018
0.30
PROD2
DRILL
WPRT
P
TDAL1 lataeral, pump 10x10 sweep
14,648.5
14,648.5
07:00
07:18
followed by beaded pill
8/14/2018
8/14/2018
2.00
PROM
DRILL
WPRT
P
POOH, laying in beaded pill up to
14,648.5
12,500.0
07:18
09:18
12,500'
8/142018
8/14/2018
2.40
PROD2
DRILL
WPRT
P
Continue POOH, pumping 1.8 bpm at
12,500.0
78.2
09:18
11:42
1
14,378 psi
8/14/2018
8/14/2018
1.80
PROD2
DRILL
WPRT
P
Taq up, reset counters, RBIH,
78.2
10,350.0
11:42
13:30
pumping 0.33 bpm @ 2,378 psi
8/14/2018
8/14/2018
0.20
PROD2
DRILL
DLOG
P
Log the K1 correction of plus 4.0'
10,350.0
10,365.0
13:30
13:42
8/14/2018
8/14/2018
0.40
PROD2
DRILL
WPRT
T
Continue IH, set down bottom of
10,365.0
10,443.8
13:42
14:06
window HIS TF, PUW 40 k, Attempt 30
ROHS, 30 LOHS, and 20 LOHS,
Discuss with town plan forward.
Page 26129 Report Printed: 812212018
0 Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
StaM th
Stat Tine
EM Tkne
our (hd
Phaee
Op Cotle
Adiviry Code
Time P -T-%
Operetlon
fi) (De
EM Depth (flKB)
8/14/2018
8/1412018
1.50
PROD2
DRILL
TRIP
T
POOH, pumping 1.8 bpm at 4,858 psi
10,443.8
78.4
14:06.
15:36
8/14/2018
8/14/2018
2.30
PROD2
DRILL
PULD
T
PUD, drilling BHA #39, Blow down and
78.4
0.0
15:36
17:54
lay down tools, Unload uper BHA
section in PDL
8/14/2018
8/14/2018
2.10
PROD2
DRILL
CIRC
P
Install nozzle and jet stack / flush rig.
0.0
0.0
17:54
20:00
Swap coil to water. Prep for BOPE test
8/14/2018
8/15/2018
4.00
PROD2
DRILL
BOPE
P
Perform full biweekly BOPE test. test
0.0
0.0
20:00
00:00
witness waived by Adam Earl,
AOGCC. On test 11. No failures
8/15/2018
8/15/2018
2.00
PROD2
DRILL
BOPE
P
Continue Full BOPE test
0.0
0.0
00:00
02:00
8/15/2018
8/15/2018
2.20
PROD2
DRILL
CTOP
P
Roll CT back to mud, UT coil min
0.0
0.0
02:00
04:12
reading @ .154. Inpect pack offs -
Good. Rehead UQC.
8/15/2018
8/15/2018
1.90
PROW
DRILL
PULD
T
PJSM PD BHA #40. FCO BHA with D-
0.0
68.4
04:12
06:06
331, .6° AKO motor and agitator.
Surface test too
8/15/2018
811512018
1.80
PROD2
DRILL
TRIP
T
RIH, w/cleanout BHA #40
68.4
10,350.0
06:06
07:54
8/15/2018
8/15/2018
0.30
PROD2
DRILL
DLOG
T
Log the K1 marker, discover counters
10,350.0
10,368.0
07:54
08:12
off by 30', reset counters to match
CIES counter, PUW 45 k, re -log Ki
marker, correction of minus 3.0'
8/15/2018
8/15/2018
0.25
PROD2
DRILL
TRIP
T
Continue IH, dry drift window exit
10,368.0
10,472.0
08:12
08:27
clean down to 10,472', PUW 40 k
8/15/2018
8/15/2018
0.20
PROD2
DRILL
TRIP
T
PUH, clean through window @ 1 fpm
10,472.0
10,385.0
08:27
08:39
8/15/2018
8/15/2018
0.15
PROD2
DRILL
TRIP
T
RBIH, @ 1 fph, seen little motor work
10,385.0
10,443.0
08:39
08:48
@ 10,439', continue @ 1 fpm, set
down 3.0 k @ 10,443', PUW 40 k
8/15/2018
8/15/2018
0.15
PROD2
DRILL
TRIP
T
PUH, PUW 40 k clean PU
10,443.0
10,385.0
08:48
08:57
8/15/2018
8/15/2018
0.15
PROD2
DRILL
TRIP
T
RBIH, @ 1.4 bpm @ 3,748 psi, set
10,385.0
10,443.0
08:57
09:06
down 3.5 k DHWOB
8/15/2018
8/15/2018
0.15
PROD2
DRILL
TRIP
T
PUH 42 k PUW,
10,443.0
10,385.0
09:06
09:15
8/15/2018
8/15/2018
0.15
PROD2
DRILL
TRIP
T
RIH through window w/ no pump (dry
10,385.0
10,480.0
09:15
09:24
drift) clean down to 10,480'
8/15/2018
8/15/2018
0.25
PROD2
DRILL
TRIP
T
PUH, pumping 1.8 bpm at 4,837 psi @
10,480.0
10,564.0
09:24
09:39
1 fpm up to 10,385', no motor work
observed, repeat clean, dry drift
window again down to 10,484', come
on line with pump @ 0.48 bpm at
2,336 psi to the EOB
8/15/2018
8/15/2018
0.30
PROD2
DRILL
TRIP
T
PUH, (PUW 40 k) through window HS
10,564.0
10,350.0
09:39
09:57
full rate 1.78 bpm at 4,652 psi, IA=O,
OA=95
8/1512018
8/15/2018
0.30
PROD2
DRILL
TRIP
T
Jetted the 7" (10,408'-10,340') w/
10,350.0
10,350.0
09:57
10:15
bottoms up, sample showing cuttings
and some pipe scale.
8/15/2018
8/15/2018
0.25
PROD2
DRILL
TRIP
T
Changeout INJH counter
10,350.0
10750.0
10:15
10:30
8/15/2018
8/15/2018
0.20
PROM
DRILL
DLOG
T
Log the K1 marker w/ no correction
10,350.0
10,368.0
10:30
10:42
8/15/2018
8/15/2018
1.20
PROD2
DRILL
TRIP
P
Continue through window clean, RIH
10,368.0
14,648.0
10:42
11:54
to confirm TO
8/15/2018
8/15/2018
2.00
PROD2
DRILL
TRIP
P
Confirm TD, send liner running pill,
14,648.0
10,300.0
11:54
13:54
POOH laying in 12.8 ppg beaded liner
pill
Page 27/29 Report Printed: 8/21120-18
Operations Summary (with Timelog Depths)
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
III
Stan Time
End Time
our(hn
Phase
Op Code
Activity Code
Time P -T -X
operation
W13)
End Deptlt(ft
8/15/2018
8/15/2018
1.80
PROD2
DRILL
TRIP
P
Beads are out, continue POOH
10,300.0
68.4
13:54
15:42
displacing well to 12.8 ppg completion
fluid while POOH
8115/2018
8/15/2018
0.50
PROD2
DRILL
TRIP
P
Tagged up, checked well for flow,
68.4
68.4
15:42
16:12
PJSM
8/15/2018
8/15/2018
0.70
PROD2
DRILL
TRIP
P
LD tools on a dead well.
68.4
0.0
16:12
16:54
8/1512018
8/15/2018
0.50
COMPZ2
CASING
PUTS
P
Prep floor to fun Al liner lower
0.0
0.0
16:54
17:24
segment
8/1512018
8/15/2018
1.90
COMPZ2
CASING
PUTB
P
PJSM, WU AL1 lower segment with
0.0
677.7
17:24
19:18
non ported bullnose, 21 Jts slotted
liner, and shorty deployment sleeve.
Make up to coiltrak, Make up to coil
and surface test
8/1512018
8115/2018
2.00
COMPZ2
CASING
RUNL
P
Trip in with BHA #41, tie into window
677.7
10,950.0
19:18
21:18
flag for -3.91, PUW=42K, Clean pass
through window
8/15/2018
8/1512018
0.10
COMPZ2
CASING
DLOG
P
Tie into K1 for+5'
10,950.0
10,974.0
21:18
21:24
8115/2018
8/15/2018
1.40
COMPZ2
CASING
RUNL
P
Continue in hole, One set down @
10,974.0
14,648.0
21:24
22:48
12863. P/U and run past clean. Set
down @ 14371. Pass through after
second pick up
8115/2018
8/16/2018
1.20
COMPZ2
CASING
TRIP
P
14648. PUW=47, Set back down
14,648.0
10,600.0
22:48
00:00
Pump on 1.5 BPM PUW=38K. Trip out
paint EOP flags @ 13319 & 9433,
TOL=14014.73
8/16/2018
8116/2018
2.20
COMPZ2
CASING
TRIP
P
Continue out of well
10,600.0
55.0
00:00
02:12
8/16/2018
8/16/2018
0.50
COMPZ2
CASING
PULD
P
At surface, PJSM, Flow check well,
55.0
0.0
02:12
02:42
Lay down tools on dead well
8/16/2018
8/16/2018
1.80
COMPZ2
CASING
PUTB
P
PJSM, PIU AL1 second liner segment,
0.0
734.4
02:42
04:30
Ported bullnose, 23 Jts slotted liner,
Shorty deployment sleeve. Pick up coil
track and latch into liner. Make up to
coil and surface lest, Inspect packoffs
8/16/2018
8116/2018
1.80
COMPZ2
CASING
RUNL
P
RIH BHA #42
734.4
10,334.0
04:30
06:18
8116/2018
811612018
0.20
COMPZ2
CASING
RUNL
P
Correct to the EDP flag minus 2.3'
10,334.0
10,334.0
06:18
06:30
8116/2018
8/1612018
1.20
COMPZ2
CASING
RUNL
P
Continue IH
10,334.0
14,014.0
06:30
07:42
8/16/2018
8/16/2018
0.20
COMPZ2
CASING
RUNL
P
Tag bottom w/3.0 k DHWOB, PUW 45
14,014.0
14,014.0
07:42
07:54
k
8116/2018
8116/2018
0.10
COMPZ2
CASING
RUNL
P
Set back down 2-3.0 k, bring pump up
14,014.0
14,014.0
07:54
08:00
to 1.4 bpm @ 5,386 psi, 0.79 bpm
returns, PUH PUW 37 k, line up
across the top, remove liner length
from counters
8116/2018
8/16/2018
2.50
COMPZ2
CASING
TRIP
P
POOH, painting EDP flags @
14,014.0
44.2
08:00
10:30
1
1
12,137.6' & 9,300'
8/16/2018
8116/2018
0.30
COMPZ2
CASING
OWFF
P
Tag up, check well for flow, PJSM
44.2
44.2
10:30
10:48
8/16/2018
8116/2018
0.30
COMPZ2
CASING
PULD
P
LD tools on a dead well
44.2
0.0
10:48
11:06
8/16/2018
8/16/2018
0.20
COMPZ2
CASING
PUTB
P
Prep RF for Liner ops, PJSM
0.0
0.0
11:06
11:18
8116/2018
8/16/2018
1.30
COMPZ2
CASING
PUTS
P
PU 33 jts, slotted liner
0.0
1,029.5
11:18
12:36
8/16/2018
8/16/2018
0.20
COMPZ2
CASING
PULD
P
PU/MU Coillrak tools
1,029.5
1,075.0
12:36
12:48
Page 28129 Report Printed: 8/22/2018
Summary (with Timelog Depths)
isOperations
3H-31
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Start Time
I End Time
Write)
Phase
op Code
AcWty Calla
Tmie P -T-%
operetlon
(N(B)
End DepN(fKB)
8/16/2018
8/16/2018
0.50
COMPZ2
CASING
PULD
P
Stab INJH, perform surface test (good
1,075.0
1,075.0
12:48
13:18
-test)
8/16/2018
8/16/2018
2.00
COMPZ2
CASING
RUNL
P
RIH, ALl liner segment#3
1,075.0
10,381.6
13:18
15:18
8/16/2018
8/16/2018
0.20
COMPZ2
CASING
RUNL
P
Correct to the EDP flag, minus 6.6'
10,381.6
10,375.0
15:18
15:30
8/16/2018
8/16/2018
1.00
COMPZ2
CASING
RUNL
P
Continue IH
10,375.0
13,324.0
15:30
16:30
8/16/2018
8/16/2018
0.20
COMPZ2
CASING
RUNL
P
Set down 3.0 k on bottom, PUW 48,
13,324.0
13,324.0
16:30
16:42
set back down 3.0 k, bring pump
online 1.4 bpm, 0.79 bpm returns,
PUW 38'
8/16/2018
8/16/2018
2.70
COMPZ2
CASING
TRIP
P
Liner up across the top, remove liner
13,324.0
50.0
16:42
19:24
length from countes, POOH
8/16/2018
8/16/2018
0.40
COMPZ2
CASING
PULD
P
Tag up, check well for flow, PJSM, LD
50.0
0.0
19:24
19:48
tools on a dead well
8/16/2018
8/162018
0.50
COMPZ2
CASING
PUTS
P
Prep floor for liner ops
0.0
0.0
19:48
20:18
8/16/2018
8/162018
3.60
COMPZ2
CASING
PUTB
P
PJSM, PIU BHA #44, AL1 upper
0.0
2,021.7
20:18
23:54
completion segment #4 with ported
bull nose, 34 Jts slotted, 29 jts blank,
3 pups, and sealbore deployment
sleeve. Make up to coiltrak. M/U to coil
and surface test - Good
8/16/2018
8/17/2018
0.10
COMPZ2
CASING
RUNL
P
Trip in well BHA # 44
2,021.7
2,500.0
23:54
00:00
8/17/2018
8/17/2018
1.60
COMPZ2
CASING
RUNL
P
Continue in well, BHA #4 ALI liner
2,500.0
10,323.4
00:00
01:36
segment #4
8/17/2018
8/17/2018
0.80
COMPZ2
CASING
RUNL
P
Correct to flag -2', PUW=41 K,
10,323.4
10,321.4
01:36
02:24
1
1
1
Continue in We
8/17/2018
8/17/2018
0.10
COMPZ2
CASING
RUNL
P
Tag bottom @ 12293. Pumps on 1.4
10,321.4
12,278.0
02:24
02:30
BPM @ 4900 PSI, PUW=34K, PUH
displace well to seawater. Remove
liner length from counters -1977.46
8/17/2018
8/17/2018
1.50
COMPZ2
CASING
DISP
P
Pump 15 BBIs spacer, Displace well to
12,278.0
10,315.0
02:30
04:00
seawater recovering KFormate
8/17/2018
8/17/2018
1.75
COMPZ2
CASING
TRIP
P
POOH, Freeze protect from 2500" with
10,315.0
44.4
04:00
05:45
diesel
8/17/2018
8/172018
1.75
COMPZ2
CASING
PULD
P
Tag up,space out, PUD setting tools
44.4
0.0
05:45
07:30
8/17/2018
8/17/2018
4.50
DEMOB
WHDBOP
RURD
P
RDMO as per TP, start Rig Move
0.0
0.0
07:30
12:00
Checklist
"• Note: RIG RELEASE 12:00pm
(noon)
Page 29129 Report Printed: 812212018
�/
ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kup2
Kuparuk River Unit
Kuparuk 311 Pad
3H-31AL1
50-103-20205-60
Baker Hughes INTEQ
Definitive Survey Report
20 August, 2018
F UGHES
.GE..,,
�. Baker Hughes INTEq tw116s 4
Conoci3killips Definitive Survey Report
Company.
CorsaoPhllllpr(Alesks) Inc.-KUP2
Project
Kupamk River Unit
she:
Kupamk 3H Pad
Well:
311-31
Wellbnm:
3H31
Design:
311-31
Project
Kupamk RNer Unit,Nodh Slope Alaska.United Sobs
Map System:
US State Pians 1922 (Exact..lution) System Datum
Geo Datum:
NAD 1927(NADC0N C0NUS)
Map Zone:
Alaska Zone 04
Well
3H-31
Local Co-ordinate Reference:
Wall 311-31
TVD Reference:
31131® 80.00ustl (31H31)
MD Reference:
31131® 80.00usft (31131)
North Reference:
Tore
Survey Calculation Method:
Minimum Curvature
Dalabau:
0AKEDMP2
Well Position
Ni.
0.00 inch
Northing:
estimation
1°)
.Ei
0.00 usfl
Fastin:
Position Uncertainty
0.00 usfl
Wellhead Elevation:
Wellbore
3H-31AL1
Mean Sea Level
Using Well Reference Point
Using ge.detic scale factor
6,000,687.91 usfl
498, 65534 usft
usfl
Magnetl.s
Model Name
Sample Data
estimation
1°)
BGGM2018
911/2018
16.92
Design
3H -3f AL1
Audit Notes:
Version:
1.0
Phase: ACTUAL
Its On Depth:
12.221.68
Vertical Semlon:
Depth From (WO)
aNgs
-11141
load)
(ufll
(USM
69 00
0.00
0.00
latitude:
Longitude:
Ground Level:
DIPMgIe
I%
80,91
Dineen
1°I
330 oa
70° 24' 42.208 N
150° D' 39.425 W
0.00 usfl
Feld Strength
Inn
52,441
SRGQ01812:8f:01PM Paye 2 COMPAS 5000.14 asset 85
V,1
Baker Hughes INTEQ
VRIES 4
COnOCOP1Illips
Definitive
Survey Report
Co.,.,
ConacoPhillips(Alaska) Inc.-Kup2
Local Coordlnide Reference:
M11 311411
Pro)ece
Kupamk River Unit
TVD Reference:
31+-31@80.00uER(311-31)
She:
Kupamk 3H
Pad
MD ReMrtnce:
31+41@ 80.00ush(31131)
Well:
311.31
North Reference:
Tree
Wellbore:
31+.31
Survey Calculation Method
Minimum Curvature
Dedi
3H-31
Database:
OAKEDMP2
SurveYProSmm
Dam
From
To
6YMr
Survey
Iti
(insi
Survey (Wa0eom)
Tool Name
Daecdptlon
Sled Doh
End Date
88.20
10,409.00
311-31 (31131)
GCT -MS
Schlumbegar GCT muaishot
1/12/2001
10,435.00
10,520.11
31+4 IA MWD-INC(31141A)
MW0.1NC ONLY
MW INC_ ONLY FILLER
7W12018
8/1/2016
10,550.81
12,221.88
3114 IA MM (311-31A)
MWD
MND-Smndand
8/12018
80/2018
12243.00
12,327.08
3H41AL1 MWD-INC(3H31AL1)
MWDi ONLY
MW INC_ ONLY FILLER
81812018
8/80016
12358.87
14596.58
3H41AL1(31431AL1)
MWD
MIND -5landard
81812018
&15/2018
Survey
Map
Map
Vertical
MD
P.1t)
Inc
(1)
M ND
n (USID
1V055
(usD)
+WS
(oan)
+E/ -W
(..ft)
NorMIn9
Eadin9 OLS
0100)
Section Survey Tool Name
Annotation
(ft)
(e)
(D)
1222168
08.19
347,41 6.092.95
600295
9,60w
-1,522.02
6,010.193.59
487.134.29 646
8,994.15 MOD (31
TIP
12,24300
87.34
34622 6.08378
6,00370
9,527.05
-1.527.65
6,D10,214.29
492129.25 11.01
9,01460 MNDINC ONLY (4)
NOP
12.2]046
00.40
345.00 6,W32
6,0..32
9,563..
4,534.92
6.010.20.83
497,12220 hAii
9.041.12 haND ONLY(4)
IntePaMtedAparmth
12,05.58
9264
344.00 6.03.00
6,00363
9,578.74
.1,541.88
6,010.26597
4911623 SAD
8006.30 MID -INC
Integokted AtlmuN
12,327.09
92,12
34100 6,08236
0,00236
9,600.80
-1,55105
6.010.295.3
49]168.0] 9.97
9.098.13 MW0.1NC ONLY (4)
Interpolated A2imum
12,356.87
92.12
33693 608116
6,0.1..
9,63575
-IMI.30
6,010,3Y2.88
497,095.63 261
9.125.45 MD (5)
12,307.19
9D.&
3361. 6,080.53
6,000.53
9,66163
-1573.18
6.010.3528
49]063.96 1293
8.165.54 apeoph
12,417.15
6656
33157 605.74
6.003.74
8,09043
-1586.55
6.010.3]].5
49]0]0.59 12.02
9,105. MND (5)
12,45603
M.
331.52 6.081.11
6.5111
9.724.66
-160499
0,010411.69
497.052.17 4.00
g22.N indo(5)
12,.510
8933
QS.% 8,08126
6,00126
9,]6]56
-163074
8,010,154.01
497..,. 10.11
9,27434 WD (5)
12,639.00
89.91
322.67 6.81.48
6001.48
9,79445
4,64982
6,010481.60
.7,001 1193
9,3D7,15 MND(5)
12,570,43
69.66
319it 6,001.59
6,00159
9,818.79
-1%9.5
6,01D,5581
421,98]5] 11.30
9,33612 Mb (5)
12,600.10
8706
313.79 6,08244
6,00244
9,&0.27
-1690.03
8.010,527,5
456.967.15 1992
9,3b.e4 "D (5)
12,51.31
W.
31826 6(..
6,00366
9,66233
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6.010,649%
498,945.12 9.03
9,,47.00 MDS)
12,5693
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49'082123 0.67
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9,45.31 MMIC) (5)
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6939
327,19 60Y.46
6.006.46
9,937.85
-1,776.13
6,010.81
496.510 1881
5,42.49 MND(5)
12.760.35
09 ]5
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6,0.'9]1
9983.00
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6,0106524
496.865.15 311
9,52415 MJul3(5)
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9065
33232 6.06862
6,000.62
9,905.04
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4%.05253 1699
9.54964 MW0(5)
8 1812:31VIPM
Papa 3
COMPASS 600014 Si 65
y Baker Hughes INTEQrR O
COnocoPhillips Definitive Survey Report DD s
Company:
Cmwcs illips(Alaska) Inc.-Kup2
Local Conrdlinam Reference:
Well 311-31
Pr4)ecr:
Kupamk River Unit
NO Reference:
3HJl@ 80.00usn(3HJ1)
Sire
Kupamk 311 Pad
MD Reference:
311-31 ® 80.00uen (311-31)
Well:
31H31
NonK Reference:
Tme
WeIIEem:
3H-31
Survey Coddled.. McMnd:
Minimum Curvature
Deali
3H�l
ratesase:
OAKEDMP2
Survey
82M01812:31:01PM Pee 4 COMPASS 5",14 Sued 85
Map
hila,
MO
Ine
Ad
TID
1V088
♦WS
+P/ -W
Northing
E.N.,;
DLS
BWrDpa1 8urvglDol Name Annotator,
11I
(h
loan/
(-amlusnl
lusnl
(n)
In)
(ft)
DII
12.010.14
91.69
33551
6,003.11
6.00311
10007,48
-1.01567
601069471
49681
t3.4z
9,57465 IAMD(5)
12858.03
92,37
=117
6.094.43
6.004,43
10.050.07
-1.835.22
6,010.]3].31
409,821.01
555
9.51 MAD (5)
1268.5.9
91.63
329.83
6,083,47
fi0054]
ID.074.21
-1849.38
6,010]61.45
499.807.88
1137
9,64920 MAD (5)
12920.55
9181
32603
6,00239
6.03239
10,103.99
-196]68
6,010.]8122
496.]03.5]
81
9,684.15 MAD (5)
1295003
80.37
324.78
ismIZI
6,001.65
1AIa500
-1Ma74
6010.02224
49,1.]68.52
030
9;1154 MAD (5)
1298784
00.0
32376
6,00182
6,00182
10,159,18
-1903.13
6,010,846.42
496.]5113
587
9,75118 AM (5)
13,019.09
87.91
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6,08260
8,002.60
10,10338
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19.9
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13,04988
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13.11037
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8.085,45
8.009,45
10,24624
-1,991.89
6,010,933.49
49666539
9.10
9,85945 MAD (6)
13.139.97
80.99
31214
6,09,09
6.007,09
10.255.05
-2,014.0
6,01095309
406643 Y3
469
9,887,51 MAD(5)
13.17052
08,31
314.80
6.0981
6WZ0t
10,255.88
3,003.22
6010.9]4.10
496621.07
S.
A.T. MND(5)
13,10.90
07.39
31410
6.080.91
6,038.91
10.307.41
-2.057.10
6,010.994.03
403.60312
393
8.8559 MID (5)
13229115
07,94
31888
6,09013
601013
10,329.11
-2,9].]8
6,011.016 36
496.99.52
1599
8.884.16 MND(5)
13,259.96
Ili
3.65
6,091.18
6,011.18
10,352.08
3,W]R2
60itIXiB.33
499.560.03
599
10.013.]] WIND (6)
1329012
00.9
321.80
603212
6,01212
10.375.50
Q116.10
6,011.06283
496.54122
391
10,04357 MD (5)
13,3219
e&88
323.17
61091
601260
10,400.48
-21311
6011,08].]4
45 =Al
649
10,94.68 MMD (5)
13.35045
9138
39.29
0,03228
6,01228
10,42924
-2,151.71
601111149
450 ,50.62
15.15
10.10.51 mm (5)
13.38228
90.55
325.74
0,091,74
6,011.74
10,45018
-216927
6,01113604
450,403.9
5.52
10135,28 MAD (5)
13,409.03
9141
Ms..
6091.27
601137
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6.011,16084
4.4] .
3.40
10162.85 Nei
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6,090.68
6,01068
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-2204.1
6.011.19.18
40452M
14,14
10,185.% MWD(5)
13,4]0]5
89.39
320.03
6.09067
0,010.67
10,52147
-2222.36
6,011,208.1
486,435.00
453
10,23304 ~(5)
1350]5
89fi0
317.10
6.09094
6010.94
105440
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6,011,231.31
49641537
11.69
10,25246 MAD(5)
13.529.1
8141
31921
6,00.68
6,01068
t0,%6.60
-226143
6.011,252.94
49639594
9&5
10.20003 MID (5)
13.303.11
91.10
311.75
6.093.01
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6,011,274.81
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24.66
10,31053 AND (5)
13.59116
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603966
10.608.04
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6,011295.69
496.303.03
6.37
10,34012 MND(5)
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Ni
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60099
10.625.38
-2,37.91
6.011.31263
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670
10.36579 MD (5)
13,65167
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6,08332.59
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13,60090
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land 8
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601110
10.01
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6,011,384.57
v. 225.89
11.18
10479.88 MAD(5)
82M01812:31:01PM Pee 4 COMPASS 5",14 Sued 85
Baker Hughes INTEQ
ConocoPhillips Definitive Survey Report
Company:
Canom Phillips(Alaska) Inc.-Kup2
Local Coorkilnate Reference:
Wall 3H-31 �
Project
Kupamk River Unil
TVD Reference:
311.31 80ODusn(31H31)
Sao
Kupamk 311 Pad
MID Reference:
3H3180.00usn(31131)
Well:
31131
North Reference
True
Wellbore:
3H-31
Survey Calculation Method:
Minimum CurvaWre
0es1gn:
311-31
Ditabau:
OAKEOMP2
Survey
MSP
MSR
Venl9al
Mo
luafry
Inc
hl
M
TVD
1,1083
♦034
as.rS
Northing
OLS,
Section Survey Toal Nkme
Annotation
111
Ideal
Ideal
San)
leaft)
MI
Is)
(°1109.1
nl
13.])626
8Z39
307.60
6,09255
601256
10,]1329
-8,457.85
8.01t,4LG.5]
4%,199]6
%,
0.87
1050681 MND(5)
13,80080
6121
30489
609390
6,01360
10.72&94
-2,481.48
6011,41622
468.17564
1185
10,53227 MND(5)
j 13,83678
8&25
307.03
609517
6,015.17
10.]4].72
-2,M7.33
6011113&01
one 15010
T16
10.%147 MND(5)
( 13,854,58
8658
304.82
6.095.94
8,015.94
10,764.02
-2,261183
6.011451.31
496,12280
8.11
10,SP6.83 MWD(5)
13,074.64
89.57
304261
6.096.42
6,01842
10,781.18
-2.55951
6,011,458.4]
496,10293
326
10,614.03 MWD(5)
13,924.93
88.]]
30]]6
6.06.11
6016%
10,799.09
-257689
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4%O7SS5
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8969
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6,097.26
6,01]26
10,018,36
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6,011.50566
496.05583
17P5
10,%9.]8 MW➢(5)
13.909.71
89.51
312.49
6,097M
6,017.50
10.84207
-2,627.36
6,011.50.37
496.033.09
1,07
10.70319 MND(5)
14.02234
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316.35
609]]0
6,01]]0
10,85991
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6,011,55221
45890680
11,%
10,734.62 MD (6)
1405336
9099
319,19
6.09752
6.01752
10,88793
-2.03145
6.011,575 23
495,96602
10.13
10.764.&5 MD (5)
14,084.93
90.61
31634
6.007.11
6017.11
10,911.72
-2,691.19
6.011,599.02
495,9ad.20
3.75
10.795.92 MWD (5)
19120.73
91.35
32337
8.06849
6,01649
10,939.47
3]14]8
8011.826]8
495.942]0
1920
10&.7125 MND(D
141W.40
91.58
3MM
6 95.48
6.015.48
1066378
-2]31.]6
6011,651.09
495.935.73
1215
10,860.79 MWD(5)
1910112
9169
329.36
6,084.11
6,01433
10,90983
4j42W
6,0116]].13
4M,909 SO
9.00
10,891.47 MJrD(5)
14,21020
9141
33.34
6,09354
6,07354
11,01504
-2762.W
8.011,70234
195894.0]
3.43
1092062 MND(6)
14,23458
9264
3243
6,09266
6,07260
11,035.82
8,]]5.10
6,011723.13
4%,08233
12M
10,944.89 MD (5)
14,265.15
9230
32690
6,091.37
6,01137
11,01.49
-279114
6011,]48]9
495.80..]]
208
10.975.40 MD (5)
14,298.42
WOO
32649
6,030.70
8,010.70
11,00960
-28Le,51
6,011,]]690
495.803.03
840
11,03&03 MWD(5)
14.324]1
09.91
SOS,%
6,09dn
6,010.72
11,11112
-2823.%
6011799.13
495.833.97
5.94
110]4.90 MWO(5)
10365.04
89.02
323.51
6,091.00
6.011M
11,136.]3
-2,840,85
6.011,914.04
495,01667
11.65
11,06512 MN0(5)
14.184.84
8].9]
319.95
6091.79
6.01170
11,16011
-2859,30
6,011,84742
495,79623
1245
11,094.59 MND (5)
14.41482
8&B3
323.5]
&09262
601262
11,18365
-2,877.85
6.011,870.%
495,]]&69
1241
11,124.25 Milan (5)
1044964
8022
321.25
609339
SNUG
11,229
-203&03
6,01168450
49676152
004
11,15378 MWD(5)
144862
88.%
31385
6.094.32
6014.32
11,232]2
-2,91&98
&011920.03
495,]4058
437
11,1¢631 "D (6)
t9W9.06
%.34
319.02
6.095.17
6,01517
11,2%.W
-283742
5011,943.91
495,3¢0.15
273
11,21121 MYW(5)
14,539.70
87.45
31660
6.095,3
6.0163
11279,34
-295603
6.011.%8.%
495.W&54
839
11.24731 MD (5)
14.%1%
8211
311.03
6,09762
6,017.62
11,29909
-2077S
6011,985.41
495,680.03
9.10
11]7907 MND(5)
14,596%
87.73
313.09
609092
8,018.92
11,319,07
-2,998.53
6,012.00630
1%6:5.%
4.05
1133105 MJN(5)
14,64600
87.73
31309
5100.%
6,020.%
11,354.17
-3030.05
6,012041.49
49582154
0.03
11.351.02 PROJECTED b TO
BQOrz01812'31.61PM
Pape 5
COMPASS 5000.14 sued 85
BA E,R PRINT DISTRIBUTION LIST
FUGHES
a GE company
COMPANY ConocoPhillips Alaska, Inc.
WELL NAME 3H-31ALI
FIELD Greater Kuparuk Area
COUNTY North Slope Borough
BHI DISTRICT Alaska
218076
29 65 9
se sign and return one copy of this transmittal form to:
DOOPhillips Alaska, Inc.
1 Osterkamp (WNS Petroleum Technician)
G Street.
forage, Alaska 99510
LOG TYPE GR - RES
LOG DATE August 14, 2018
AUTHORIZED BY Patrick Rider
EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE August 29, 2018
Revision
STATUS Final Replacement: No Details:
Rev. Requested by: ---
COMPANY
ADDRESS (FEOEX WILL NOT DELVER TO P.O. BOX)
PERSON ATTENTION
V
I BP North Slope.
EOA. PBOC. PRB-20 (Office 109)
D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill
900 E. Benson Blvd.
Anchorage. Alaska 99508
2 ConocoPhillips Alaska Inc.
Attn: Ricky Hearten
ATO 708
700 G Street
Anchorage, AK 99510
3 Exxon Mobil, Alaska
Attn: Lynda M. Yaskell and/or Leonardo Elias
3201 C Street, Suite 505
.Anchorage, AK 99503
FIELDI
FINAL
CD/DVD
FINAL
PRELIM
LOGS
I
(las, tills, PDF, META,
I
SURVEY
REPORT
LOGS
CGM, Final Surveys)
(Compass)
# OF PRINTS9
Ur rMIN
# OF COPIES
# OF COPIES
# OF COPIES
01 01 0 10 0
0 1 0 1 0 1 0 10
41State of Alaska -AOGCC 0 1 1 0 0
Alm: Natural Resources Technician Il
1333 W. 7th Ave, Suite 100
Anchorage, Alasla 99501
5 DNR - Division ofOil & Gas 1 0 f 0 1 0 1 0
Arco: Resource Evaluation
550 West 7th Avenue. Suite 1100
Anchorage. Alaska 99501
*** Stamp "confidential" on all material deliver to DNR
6 BP Exploration (Alaska) Inc.
Petrotechnical Data Center, LR2-1
900 E. Benson Blvd
Anchorage, Alaska 99508
0 1 0 1 1 1 0 0
TOTALS FOR THIS PAGE: 0 1 3 0 0
Victoria T
From:
Sent: Loepp, Victoria T (DOA)
To: Tuesday, July 10, 2018 1:58 PM
Cr Herring, Keith E (Keith.E.Herrin
Subject: Ohlinger, lames J (James.J.Ohlinng rono nOCO hills s -c
KRU 3H-31AL1(PTD 218-076) prp A croval Modifications Approval Modifications
Keith,
PTO ;?i8_o;;rG
Please make the following modifications to the approved PTD 218-076:
Annular preventer test pressure is 2500 psig
A variance to 20 AAC 25,015(b) is granted to allow the kickoff
Point to be any point along the parent lateral.
Subsequent Form Required: 10-407
Include this approval with the original approved PTD.
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil R, Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
work: (907)793-1247
Victoria.Loeoo(ril_ a
CONFIDENT/q(Iry NOTICE: This e-mail message, including any attachments,
contains State of Alaska and is for the sole use of the intended reciipientformat ay from the Alaska Oil and Gas Conservation
P delete it, without first Savin may violate state or federal low if and
You, contact Victoria Loepp at 907 793_ far Privileged
( 1 1247 or Victoria, oer forwarding if, and so that the AOGCC is aw you are an
@alaska. ov are of the mistake in sendingunintended
itto
THE STATE
°fALASKA
GOVERNOR BILL WALKER
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H-31AL1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 218-076
Surface Location: 970' FNL, 281' FWL, SEC. 12, T12N, R8E, UM
Bottomhole Location: 5066' FNL, 2031' FEL, SEC. 27, T13N, R8E, UM
Dear Mr. Ohlinger:
333 west Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fox: 907276.7542
www.cogcc.alaska.gov
Enclosed is the approved application for the permit to redrill the above referenced development well.
The permit is for a new wellbore segment of existing well Permit No. 218-075, API No. 50-103-20205-
01-00. Production should continue to be reported as a function of the original API number stated
above.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run
must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this
well.
This permit to drill does not exempt you from obtaining additional permits or an approval required by
law from other governmental agencies and does not authorize conducting drilling operations until all
other required permits and approvals have been issued. In addition, the AOGCC reserves the right to
withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an
applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an
AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension
of the permit.
Sincerely,
Hollis S. French
+L Chair
DATED this 5 qday of July, 2018.
STATE OF ALASKA
ALP-- A OIL AND GAS CONSERVATION COMMIS—ON
PERMIT TO DRILL
iL1_T_TrrYbYrUb�
WiN2820118
1a. Type of Work:
Drill ❑ Lateral ❑A
Redrill [:]Reentry ❑
11b. Proposed Well Class: Exploratory - Gas Service - WAG Service- Disp ❑
Stratigraphic Test [__1 Development - Oil ❑✓ -' Service- Winj ❑ Single Zone ❑�
Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
1c. Specify if well is pm0 ed for:
Coalbed Gas El Gas Hydrates ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond: Blanket Q • Single Well ❑
11. Well Name and Number:
ConocoPhillips Alaska, Inc.
Bond No. 5952180 -
KRU 3H-31AL1
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 15200' TVD: 6076'
Kuparuk River Pool /
Kuparuk River Oil Pool
4a. Location of Well (Governmental Section):
7. Properly Designation:
Surface: 970' FNL, 281' FWL, Sec 12, T12N, RSE, UM
OC. SS3 ADL 25524 G • Z� •%
Top of Productive Horizon:
8. DNR Apv Numbe
pror:
13. Approximate Spud Date:
1524' FNL, 330' FEL, Sec 34, T13N, R8E, UM
LONS 84-134 & LONS 84-149
7/9/2018
9. Acres in Property:
14. Distance to Nearest Property:
Total Depth:
5066' FNL, 2031' FEL, Sec 27, T13N, RBE, UM
1920
6820'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 80'
15. Distance to Nearest Well Open
Surface: x- 498655 y- 6000688 , Zone- 4
GL / BF Elevation above MSL (ft): 39'
to Same Pool: 115', 3M-28
116. Deviated wells: Kickoff depth: 12750' ' feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 92 degrees
Downhole: 4056 - Surface: 3455 -
18. Casing Program: Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Hole Casing Weight Grade Coupling Length
MD TVD MD TVD (including stage data)
3" 2-3/8" 4.7# L-80 ST -L 4882'
10318'. 5926' 15200' • 6076' Slotted
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):
10730' 6241' N/A
10623' 6160' N/A
Casing Length Size
Cement Volume MD TVD
Conductor/Structural 79' 16"
200 sx AS 121' 121'
Surface 4981' 9-5/8"
1100 sx ASI 11, 600 sx G 5023' 3262'
Production 10677' 7"
250 sx Class G 10712' 6228'
Perforation Depth MD (ft): 10426'- 10444'
Perforation Depth TVD (ft): 6008'- 6022'
10452'- 10494'
6028'- 6060'
Hydraulic Fracture planned? Yes ❑ No 0
20. Attachments: Property Plat ❑ ch
illing Program Shallow Hazard Analysis
Time v. Depth am
DivertOer Sketch
B
Seabed Report B Drilling Fluid Progr8 20 AAC 25.050 requirements B✓
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: Keith Herring
Authorized Name: James Ohlinger
Contact Email: Keith. E. Herrinclaccip.corn
Authorized Title: Staff CTD Engineer
Contact Phone: 907-263-4321
Authorized Signature:
Date: a/p/d
Commission Use Only
Permit to Drill / /
Number: 2—&-0-7W
API Number* �J �� _ �^v
50 -IL �, �4E-i2Z�S—��-lJ
Permit Approval
Date: '5�
1 11
See cover letter for other
Irequirements.
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methaanne/, gas hydrates, or gas contained in shales:
Other: g. 49�¢ �` bP E'i^$"ST�'� y q51 Samples req'd: Yes ❑ oLd Mud log req'd: Yes E] No fit"
2 y k�L-Y' ,tri r Ce� n �JG 1 HzS measures: Yes [']�No Directional svy req'd: Yes tU/ No
IT Spacing exception req'd: Yes ❑ No[ -fl Inclination -only svy req'd: Yes ❑ NOV
Post initial injection MIT req'd: Yes E3 No[]
Approved by:
APPROVED BY 4 1 'S I(�
COMMISSIONER THE COMMISSION Date:
r Form 10-401 Revised 5/2017
e
46
a i
o
Submit Form and
onths from the data of approval per 20 AAC 25.005(x) ./ AttachrRVs in Dupree
J'VbKc. ;; ..T1D .00ff sir/J - G' -7,sfS
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
June 28, 2018
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 3H-31
(PTD# 194-019) using the coiled tubing drilling rig, Nabors CDR3-AC.
CTD operations are scheduled to begin in early July 2018. The objective will be to drill two laterals KRU 3H -31A
and 3H-31AL1 targeting the Kuparuk A -sand interval.
To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 �'
AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of
being limited to 500' from the original point.
Attached to this application are the following documents:
- Permit to Drill Application Forms (10-401) for 3H -31A and 3H-31AL1
- Detailed Summary of Operations
- Directional Plans for 3H -31A and 3H-31AL1
- Current wellbore schematic
- Proposed CTD schematic
If you have any questions or require additional information, please contact me at 907-263-4321.
Sincerely,
Keith Herring
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Kuparuk CTD Laterals
3H -31A and 3H-31AL1
Application for Permit to Drill Document
1.
Well Name and Classification........................................................................................................ 2
(Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b))...................................................................................................................2
2.
Location Summary.......................................................................................................................... 2
(Requirements of 20 AAC 25.005(c)(2)) ......................................... --.................................................................................................... 2
3.
Blowout Prevention Equipment Information................................................................................. 2
(Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2
4.
Drilling Hazards Information and Reservoir Pressure.................................................................. 2
(Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2
5.
Procedure for Conducting Formation Integrity tests................................................................... 2
(Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2
6.
Casing and Cementing Program.................................................................................................... 3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3
7.
Diverter System Information ..........................................................................................................3
(Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3
8. Drilling Fluids Program.................................................................................................................. 3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3
9. Abnormally Pressured Formation Information.............................................................................4
(Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4
10. Seismic Analysis............................................................................................................................. 4
(Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4
11. Seabed Condition Analysis............................................................................................................ 4
(Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4
12. Evidence of Bonding...................................................................................................................... 4
(Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4
13. Proposed Drilling Program.............................................................................................................4
(Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4
Summaryof Operations...................................................................................................................................................4
LinerRunning...................................................................................................................................................................5
14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6
15. Directional Plans for Intentionally Deviated Wells .....
(Requirements of 20 AAC 25.050(b))..........................................................
....................................... 6
....................................................... 6
16. Attachments....................................................................................................................................6
Attachment 1: Directional Plans for 31-1-31A and 31-1-31AL1 laterals...............................................................................6
Attachment 2: Current Well Schematic for 31-1-31............................................................................................................6
Attachment 3: Proposed Well Schematic for 3H -31A and 3H-31AL1 laterals.................................................................6
Page 1 of 6 June 28, 2018
PTD Application: 3H -31A & 3H-31AL1
Well Name and Classification
(Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))
The proposed lateraydescribed in this document are 3H -31A and 3H-31AL1. The laterals'will be classified as
"Development -Oil" wellsr.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface
and subsurface coordinates of the 3H -31A and 31-1-31 AL1.
3. Blowout Prevention Equipment Information
(Requirements of 20 AAC 25.005 (c)(3))
Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC.
BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations.
— Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,200 psi. Using the
maximum formation pressure in the area of 4,056 psi in 31-1-24 (i.e. 13.0 ppg EMW), the maximum
potential surface pressure in 31-1-31, assuming a gas gradient of 0.1 psi/ft, would be 3,455 psi. See
the "Drilling Hazards Information and Reservoir Pressure" section for more details. -
- The annular preventer will be tested to 250 psi and 2,500 psi.
4. Drilling Hazards Information and Reservoir Pressure
(Requirements of 20 AAC 25.005 (c)(4))
Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a))
The formation pressure in KRU 31-1-31 was measured to be 3,827 psi (12.1 ppg EMW) on 5/13/2018. The
maximum downhole pressure in the 3H-31 vicinity is the 31-1-24 at 4,056 psi (13.0 ppg EMW) measured on
5/18/2018.
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
The offset injection wells to 31-1-31 have injected gas, so there is a possibility of encountering free gas while
drilling the 3H-31 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage
tank away from the rig.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c))
The major expected risk of hole problems in the 31-1-31 laterals will be shale instability across faults. Managed
pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
T 3M 23 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity
tenotrequired.
Page 2 of 6 June 28, 2018
PTD Application: 3H -31A & 3H-31AL1
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
Lateral Name
Liner Top
Liner Btm
Liner Top
Liner Btm
Liner Details
Btm
MD
MD
MD
TVDSS
TVDSS
Conductor
3H -31A
12,750'
15,200'
5,990'
5,987'
2-3/8", 4.7#, L-80, ST -L slotted liner;
0'
121'
1640
670
Surface
aluminum billet on to
3H-31AL1
10,318'
15,200' .
5,846'
5,996'
2-3/8", 4.7#, L-80, ST -L slotted / blank
3262'
3520
2020
Production
7"
liner; with sealbore deployment on to
Existing Casing/Liner Information
Category
OD
Weight
Grade
Connection
Top
MD
Btm
MD
Top
TVD
Btm
TVD
Burst
psi
Collapse
psi
Conductor
16"
62.5
H-40
Welded
0'
121'
0'
121'
1640
670
Surface
9-5/8"
53.5
J-55
BTC
0'
5023'
0'
3262'
3520
2020
Production
7"
26.0
L-80
BTC MOD
0'
10712'
0'
6228'
7240
5410
Tubing
3-1/2"
9.3
L-80
ABM EUE
0'
10336'
0'
5940'
10160
10540
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a
diverter system is not required.
8. Drilling Fluids Program
(Requirements of 20 AAC 25.005(c)(8))
Diagram of Drilling System
A diagram of the Nabors CDR3-AC mud system is on file with the Commission.
Description of Drilling Fluid System
— Window milling operations: Chloride -based PowerVis mud (8.6 ppg)
— Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with 12.2 ppg NaBr completion fluid in order to provide
formation over -balance and shale stability while running completions.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases,
the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke.
BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment
Information".
In the 3H-31 laterals we will target a constant BHP of 12.2 ppg EMW at the window. The constant BHP target
will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if
increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be
employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates
or change in depth of circulation will be offset with back pressure adjustments.
Page 3 of 6 June 28, 2018
PTD Application: 3H -31A & 3H-31AL1
Pressure at the 3H-31 Window (10437' MD. 6017' TVD) Usina MPD
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AAC 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AAC 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AAC 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
Background
Well KRU 3H-31 is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 7" production casing.
The CTD sidetrack will utilize two laterals to target the A sand to the northwest of the 3H-31 parent
wellbore. The laterals will increase recovery and add additional resources.
This project may trial using 2-3/8" coiled tubing inside 3-1/2" production tubing and drilling 3-1/4" hole. If
weight transfer and circulating pressures deem to be problematic, then the project will utilize 2" coiled
tubing and drill 3" hole.
Pre -CTD Work
1. RU Slickline: Drift tubing with dummy whipstock and obtain SBHP.
2. RU E -line: Punch holes in the 3-1/2" tubing tail below production packer.
3. RU Pumping Unit: Perform injectivity test down the tubing.
4. RU Service Coil: Mill out "D" nipple and cement squeeze the A/C -sand perforations up to the holes
in the tubing tail.
5. RU Slickline: Tag top of cement and pressure test cement.
6. Prep site for Nabors CDR3-AC rig.
Page 4 of 6 June 28, 2018
Pumps On 1.8 bpm)
Pumps Off
A -sand Formation Pressure 12.1
3785 psi
3785 psi
Mud Hydrostatic 8.6
2690 psi
2690 psi
Annular friction i.e. ECD, 0.08psi/ft)
834 psi
0 psi
Mud + ECD Combined
no chokepressure)
3524 psi
Underbalanced -261psi)
2690 psi
Underbalanced ^1095psi)
Tar et BHP at Window 12.2
3817 psi
3817 psi
Choke Pressure Required to Maintain
Target BHP
293 psi
1127 psi
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AAC 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AAC 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AAC 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
Background
Well KRU 3H-31 is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 7" production casing.
The CTD sidetrack will utilize two laterals to target the A sand to the northwest of the 3H-31 parent
wellbore. The laterals will increase recovery and add additional resources.
This project may trial using 2-3/8" coiled tubing inside 3-1/2" production tubing and drilling 3-1/4" hole. If
weight transfer and circulating pressures deem to be problematic, then the project will utilize 2" coiled
tubing and drill 3" hole.
Pre -CTD Work
1. RU Slickline: Drift tubing with dummy whipstock and obtain SBHP.
2. RU E -line: Punch holes in the 3-1/2" tubing tail below production packer.
3. RU Pumping Unit: Perform injectivity test down the tubing.
4. RU Service Coil: Mill out "D" nipple and cement squeeze the A/C -sand perforations up to the holes
in the tubing tail.
5. RU Slickline: Tag top of cement and pressure test cement.
6. Prep site for Nabors CDR3-AC rig.
Page 4 of 6 June 28, 2018
PTD Application: 3H -31A & 3H-31AL1
Rig Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. 3H -31A Sidetrack (A1 sand - northwest)
a. Mill 2.80" high -side pilot hole through the cement to 10470' MD.
b. Caliper pilot hole and set top of whipstock at 10437' MD.
c. Mill 2.80" window at 10437' MD.
d. Drill 3" bi-center lateral to TD of 15200' MD.
e. Run 2-3/8" slotted liner with aluminum billet from TD up to 12750' MD.
3. 3H-31AL1 Lateral (Al sand - northwest)
a. Kickoff of the aluminum billet at 12750' MD.
b. Drill 3" bi-center lateral to TD of 15200' MD. '
c. Run 2-3/8" slotted /blank liner with sealbore deployment sleeve from TD up to 10318' MD.
4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Rig Work
1. Install liner top packer onto the 2-3/8" liner.
2. Return well to production.
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on
the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double
swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the
BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two
barriers to reservoir pressure, both internal and external to the BHA, during the deployment process.
During BHA deployment, the following steps are observed.
- Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is
installed on the BOP riser with the BHA inside the lubricator.
- Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and
the BHA is lowered in place via slickline.
- When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate
reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate
reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from
moving when differential pressure is applied. The lubricator is removed once pressure is bled off above
the deployment rams.
- The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the
closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the
double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized,
and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole.
During BHA un -deployment, the steps listed above are observed, only in reverse.
Liner Running
- The 3H-31 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids"
section for more details.
- While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency
deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a
deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide
secondary well control while running 2-3/8" liner.
Page 5 of 6 June 28, 2018
PTD Application: 31-1-31A & 3H-31AL1
14. Disposal of Drilling Mud and Cuttings
(Requirements of 20 AAC 25.005(c)(14))
• No annular injection on this well.
• All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal.
• Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18
or 1B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable.
• All wastes and waste fluids hauled from the pad must be properly documented and manifested. '
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200).
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
- The Applicant is the only affected owner.
- Please see Attachment 1: Directional Plans
- Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
- MWD directional, resistivity, and gamma ray will be run over the entire open hole section.
- Distance to Nearest Property Line (measured to KPA boundary at closest point)
Lateral Name
DZ682O'
3H-31A
3H-31 AL1
Distance to Nearest Well within Pool
Lateral Name Distance well
3H -31A 154' 3M-28
3H-31AL1 115' 3M-28
16. Attachments
Attachment 1: Directional Plans for 3H -31A and 3H-31AL1 laterals
Attachment 2: Current Well Schematic for 3H-31
Attachment 3: Proposed Well Schematic for 3H -31A and 3H-31AL1 laterals
Page 6 of 6 June 28, 2018
ConocoPhillips BAF�UGHES
PmjecC Kuparuk Rivet Unit "9u"y"ew^k n;m,. f �. ?NELLBORE DETAILS: 3H -31A REFERENCE INFORMATION
Site: Kuparuk ]N POC p coawnem lxEl Re@rgrce'. tura 31431. ]rue Nwn
Well: ]X-]7 T/ "M^Rk F1^M Parent WeAbofe: 3H-31 VmllreiiNOi Raiererce: 3Nal�m.aousn�3X31)
su•rae: n++o.�.m Tie 9n MD: 10409.00
Wellbore; ]X -]tit clRarale mal• sxnm Nsl Rekrerte: swl-pmx,RmE1
Plan:
- i IU "i:IM-2 lM�l>r:A;-I] M
sgNdO 2AYlyndl-IS
]Xd1A_wp021SHJ1pH-]tA)
°"' an06i
Mmseex Rralx R 3RJi ll aloqua(3X3p
18]50
CN'I f:
ekvblun McNW. M'msnm CWaNe
ConocoPhillips BAF�UGHES
PmjecC Kuparuk Rivet Unit "9u"y"ew^k n;m,. f �. ?NELLBORE DETAILS: 3H -31A REFERENCE INFORMATION
Site: Kuparuk ]N POC p coawnem lxEl Re@rgrce'. tura 31431. ]rue Nwn
Well: ]X-]7 T/ "M^Rk F1^M Parent WeAbofe: 3H-31 VmllreiiNOi Raiererce: 3Nal�m.aousn�3X31)
su•rae: n++o.�.m Tie 9n MD: 10409.00
Wellbore; ]X -]tit clRarale mal• sxnm Nsl Rekrerte: swl-pmx,RmE1
Plan:
- i IU "i:IM-2 lM�l>r:A;-I] M
sgNdO 2AYlyndl-IS
18]50
18000
T-
vzsp
-
k.l
14250
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12000
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4,750 -6000 -5250 4500 .3750 3000 2;110 -1500 -750 0 "73N 1100 ;250 1NDUP 3750 45
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12ALWest( )/East(+) (750 usft/m➢
1
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ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kup2
Kuparuk River Unit
Kuparuk 3H Pad
3H-31
3H-31AL1
Plan: 3H-31AL1_wp01
Standard Planning Report
27 June, 2018
BER
GHES
TGE company
ConocoPhillips
Database:
EDTAlaska Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup2
Project:
Kuparuk River Unit
Sne:
Kuparuk 3H Pad
Well:
3H-31
Weltbore:
3H-31AL1
Design:
3H-31AL1_wp01
ConocoPhillips
Planning Report
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 3H-31
Mean Sea Level
314-31 @ 80.00usft (3H-31)
True
Minimum Curvature
Project Kupemk 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
BArl1 RHES
a GE cmpany
Site Kuparuk 3H Pad
Build
Tum
Site Position:
Northing:
6,000,110.73usft
Latitude: 70° 24'41.531 N
From: Map
Easting:
498,655.44 usft
Longitude: 150' 0'39.416 W
Position Uncertainty: 0.00 usft
Slot Radius:
0.000 in
Grid Convergence: -0.01 °
Well 3H-31
Well Position +N/ -S 0.00 usft Northing:
+EI -W 0.00 usft Easting:
Position Uncertainty 0.00 usft Wellhead Elevation:
Wellbore 3W31AL1
Magnetics Model Name Sample Date
BGGM2018 9/1/2018
Design
Audit Notes:
Version:
Vertical Section:
3H-31AL1_wp01
6,000,687.91 usft Latitude:
498,655.24 usft Longitude:
usft Ground Level:
Declination
(9
16,92
Dip Angle
P)
Phase: PLAN Tie On Depth:
Depth From (TVD) +N/S +E/ -W
(usft) (usft) (usft)
0.00 0.00 0.00
70° 24'47.208 N
150' 0'39.425 W
0.00 usft
Field Strength
(nn
80.91 57,441
12,750.00
Direction
(')
330.00
Dogleg
Build
Tum
Rate
Rate
Rate
Plan Sections
(•1100ft)
(0/100M
MOM
(q
0.00
Measured
0.00
0.00
TVD Below
6.06
-3.50
330.00
Depth
Inclination
Azimuth
System
•N/.S
+El -W
6.99
(usft)
V)
(I
(usft)
(usft)
(usft)
0.01
12,750 00
87.37
329.64
5,989.95
10,005.17
-1,671.85
7.00
12,820.00
91.62
327.19
5,990.57
10,064.78
-1,708.51
269.00
13,000.00
89.84
314.71
5,988.28
10,204.27
-1,821.67
-6.93
13,200.00
89.12
328.69
5,990.11
10,360.83
-1,945.31
13,500.00
89.18
307.69
5,994.63
10,583.17
-2,144.16
13,700.00
89.20
321.69
5,997.48
10,723.46
-2,285.97
13,950.00
87.74
304.25
6,004.22
10,893.15
-2,468.11
14,250.00
90.39
325.08
6,009.19
11,102.85
-2,680.24
14,550.00
90.00
304.09
6,008.16
11,312.26
-2,892.71
14,750.00
90.00
318.09
6,008.15
11,443.38
-3,043.08
14,950.00
91.93
304.22
6,004.76
11,574.65
-3,193.27
15,200.00
91.84
321.73
5,996.46
11,744.31
-3,375.38
70° 24'47.208 N
150' 0'39.425 W
0.00 usft
Field Strength
(nn
80.91 57,441
12,750.00
Direction
(')
330.00
Dogleg
Build
Tum
Rate
Rate
Rate
TFO
(•1100ft)
(0/100M
MOM
(q
0.00
0.00
0.00
0.00
7.00
6.06
-3.50
330.00
7.00
-0.99
-6.93
262.00
7.00
-0.36
6.99
93.00
7.00
0.02
-7.00
270.00
7.00
0.01
7.00
90.00
7.00
-0.59
18.98
265.00
7.00
0.88
6.95
83.00
7.00
-0.13
-7.00
269.00
7.00
0.00
7.00
90.00
7.00
0.96
-6.93
278.00
7.00
-0.04
7.00
90.00
Target
6/272018 1:57. tOPM Page 2 COMPASS 5000.14 Build 85
I
ConocoPhillips
all
ConocoPhillips Planning Report BA GHES
atiEcompany
Database:
EDT Alaska Sandbox
Local Co-ordinate Reference:
Well 3H-31
Company:
ConocoPhillips (Alaska) Inc -Kup2
TVD Reference:
Mean Sea Level
Project
Kuparuk River Unit
MD Reference:
3H-31 @ 80.00usft (3H-31)
She:
Kuparuk 3H Pad
North Reference:
True
Well:
3H31
Survey Calculation Method:
Minimum Curvature
Wellbore:
3H31AL1
(')
(usft)
Design:
3H31AL1_wp01
(ueft)
Mooft)
, Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination Azimuth
System
+N/S
+E/ -W
Section
Rah
Azimuth
Northing
Eesting
lush)
1")
(')
(usft)
(usft)
(usft)
(ueft)
Mooft)
p)
(usft)
(MR)
12,750.00
87.37
329.64
5,989.95
10,005.17
-1,671.85
9,500.66
0.00
0.00
6,010,692.38
496,985.36
TIPIKOP
12,800.00
90.40
327.89
5,990.92
10,047.90
-1,697.77
9,550.63
7.00
-30.00
6,010,735.11
496,959.44
12,820.00
91.62
327.19
5,990.57
10,064.78
-1,708.51
9,570.60
7.00
-29.97
6,010,751.99
496,948.72
Start 7 dls
12,900.00
90.83
321.64
5,988.86
10,129.79
-1,755.03
9,650.17
7.00
-98.00
6,010,817.01
496,902.21
13,000.00
89.84
314.71
5,988.28
10,204.27
-1,821.67
9,747.99
7.00
-98.12
6,010,891.48
496,835.58
3
13,100.00
89.47
321.70
5,988.88
10,278.77
-1,888.28
9,845.82
7.00
93.00
6,010,965.99
496,769.00
13,200.00
89.12
328.69
5,990.11
10,360.83
-1,945.31
9,945.40
7.00
92.96
6,011,048.05
496,711.99
4
13,300.00
89.12
321.69
5,991.65
10,442.88
-2,002.35
10,044.97
7.00
-90.00
6,011,130.10
496,654.97
13,400.00
89.14
314.69
5,993.16
10,517.36
-2,068.96
10,142.78
7.00
-89.89
6,011,204.59
496,588.38
13,500.00
89.18
307.69
5,994.63
10,583.17
-2,144.16
10,237.37
7.00
-89.79
6,011,270.41
496,513.20
5
13,600.00
89.18
314.69
5,996.07
10,648.98
-2,219.36
10,331.97
7.00
90.00
6,011,336.22
496,438.02
13,700.00
89.20
321.69
5,997.48
10,723.46
-2,285.97
10,429.78
7.00
89.90
6,011,410.71
496,371.43
6
13,800.00
88.60
314.72
5,999.40
10,797.96
4,352.57
10,527.59
7.00
-95.00
6,011,485.21
496,304.85
13,900.00
88.02
307.74
6,002.36
10,863.79
-2,427.69
10,622.17
7.00
-94.87
6,011,551.05
496,229.74
13,950.00
87.74
304.25
6,004.22
10,893.15
-2,468.11
10,667.80
7.00
-94.66
6,011,580.42
496,189.33
7
14,000.00
88.17
307.72
6,006.01
10,922.51
-2,508.54
10,713.44
7.00
83.00
6,011,809.78
496,148.92
14,100.00
89.05
314.67
6,008.44
10,988.31
-2,583.72
10,808.02
7.00
82.88
6,011,675.59
496,073.76
14,200.00
89.94
321.61
6,009.33
11,062.74
-2,650.40
10,905.82
7.00
82.71
6,011,750.02
496,007.09
14,250.00
90.39
325.08
6,009.19
11,102.85
-2,680.24
10,955.47
7.00
82.64
6,011,790.13
495,977.26
8
14,300.00
90.32
321.58
6,008.88 -
11,142.95
-2,710.10
11,005.13
7.00
-91.00
6,011,830.23
495,947.42
14,400.00
90.20
314.59
6,008.42
11,217.32
-2,776.86
11,102.91
7.00
•91.02
6,011,904.61
495,880.68
14,500.00
90.07
307.59
6,008.19
11,283.00
-2,852.18
11,197.45
7.00
-91.05
6,011,970.29
495,805.37
14,550.00
90.00
304.09
6,008.16
11,312.26
-2,892.71
11,243.06
7.00
-91.07
6,011,999.56
495,764.85
9
14,600.00
90.00
307.59
6,008.16
11,341.53
-2,933.24
11,288.68
7.00
90.00
6,012,028.84
495,724,34
14,700.00
90.00
314.59
6,008.15
11,407.21
-3,008.56
11,383.22
7.00
90.00
6,012,094.53
495,649.03
14,750.00
90.00
318.09
6,008.15
11,443.38
-3,043.08
11,431.80
7.00
90.00
6,012,130.69
495,614.53
10
14,800.00
90.49
314.62
6,007.93
11,479.55
-3,077.58
11,480.38
7.00
-82.00
6,012,166.87
495,580.03
14,900.00
91.46
307.69
6,006.23
11,545.31
-3,152.82
11,574.94
7.00
-82.01
6,012,232.64
495,504.82
14,950.00
91.93
304.22
6,004.76
11,574.65
-3,193.27
11,620.58
7.00
-82.13
6,012,261.98
495,464.37
11
15,000.00
91.93
307.72
6,003.07
11,604.00
-3,233.71
11,666.21
7.00
90.00
6,012,291.33
495,423.95
15,100.00
91.90
314.72
5,999.73
11,669.82
-3,308.83
11,760.78
7.00
90.12
6,012,357.16
495,348.84
15,200.00
91.84
321.73
5,996.46 -
11,744.31
-3,375.38
11,858.56
7.00
90.35
6,012,431.65
495,282.32
Planned TD at 16200.00
62712018 1:5710PM Page 3 COMPASS 5000.14 Build 85
ConocoPhillips BA
ConocoPhillips Planning Report UGHES
aUrwpany
Database:
EDT Alaska Sandbox
Company:
ConocoPhillips (Alaska) Ina -Kup2
Project:
Kuparuk River Unit
Site:
Kuparuk 3H Pad
Well:
3H-31
Wellbore:
3H-31AL1
Design:
3H-31AL1_wp01
Targets
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 3H-31
Mean Sea Level
311-31 @ 80.00usft(3H-31)
True
Minimum Curvature
Target Name
-hillmiss target Dip Angle Dip Dir. TVD +NIS +EI -W Northing Basting
-Shape (•) (1) (usR) (usft) (usR) (usft) (usft) Latitude Longitude
311-31A_Fau83 0.00 0.00 5,983.00 9,829.081,138,536.86 6,010,311.00
- plan misses target center by 1140208.73usft at 12750.00usft MD (5989.95 TVD, 10005.17 N, -1671.85 E)
- Polygon
Point 5,983.00 0.00 0.00 6,010,311.00
Point 2 5,983.00 1.00 1.00 6,010,312.00
311-31A_Fault4 0.00 0.00 6,001.00 11,336.961,137,054.44 6,011,819.00
- plan misses target center by 1138727.07usft at 12750.00usft MD (5989.95 TVD, 10005.17 N, -1671.85 E)
- Polygon
Point 1 6,001.00 0.00 0.00 6,011,819.00
Point2 6,001.00 1.00 1.00 6,011,820.00
3H-31A_Fault4_M 0.00 0.00
0.00
11,336.961,137,054.44
6,011,819.00
- plan misses target center by 1138742.83usft at
12750.O0usft MD (5989.95 TVD, 10005.17 N, -1671.85 E)
- Rectangle (sides W1.00 91,000.00 DO.00)
1,637,062.00
- plan misses target center by 1140193.31 usft at 12750.00usft MD (5989.95 TVD, 10005.17 N, -1671.85 E)
311-31 CTD Polygon 0.00 0.00
0.00
7,625.881,138,626.27
6,008,108.00
- plan misses target center by 1140316.33usft at
12750.00usft
MD (5989.95 TVD, 10005.17 N, -1671.85 E)
- Polygon
- plan misses target center by 1139758.65usft at 12750.00usft MD (5989.95 TVD, 10005.17 N, -1671.85 E)
0.00
- Point
Point 1
0.00
0.00 0.00
6,008,108.00
Point 2
0.00
1,313.19 242.72
6,009,421.01
Point
0.00
2,445.25 6.43
6,010,553.00
Point4
0.00
4,312.99 -1,924.19
6,012,420.91
Points
0.00
4,027.91 -2,126.15
6,012,135.89
Point
0.00
2,188.16 -250.53
6,010,295.99
Point
0.00
1,327.11 -118.32
6,009,435.00
Point
0.00
27.92 -354.04
6,008,135.98
Point
0.00
0.00 0.00
6,008,108.00
1,637,080.00
1,637,080.00
1,637,081.00
70° 12'15.058 N 140' 48'
1,635,598.00 70° 12'31.891 N 140° 48'47.525 W
1,635,598.00
1,635,599.00
1,635,598.00
1,637,169.00
1,637,169.00
1,637,411.93
1,637,175.87
1,635,245.78
1,635,043.79
1,636,918,89
1,637,050.93
1,636,815.00
1,637,169.00
311-31A_Fault3_M 0.00 0.00 0.00 9,829.081,138,536.86 6,010,311.00
1,637,080.00
- plan misses target center by 1140224.46uaft at 12750.00usft MD (5989.95 TVD, 10005.17 N, -1671.85 E)
1,636,051.00
- Rectangle (sides W1.00 H1,000.00 DO.00)
140'48'35.988 W
311-31A_Fauftl 0.00 0.00 5,960.00 7,752.871,138,519.23 6,006,235.00
1,637,062.00
- plan misses target center by 1140193.31 usft at 12750.00usft MD (5989.95 TVD, 10005.17 N, -1671.85 E)
-Poygon
Point 1 5,960.00 0.00 0.00 6,008,235.00
1,637,062.00
Point 5,960.00 1.00 1.00 6,008,236.00
1,637,063.00
3HJ1AL1 T01 0.00 0.00 5,993.00 10,464.061,138,086.70 6,010,946.00
1,636,630.00
- plan misses target center by 1139758.65usft at 12750.00usft MD (5989.95 TVD, 10005.17 N, -1671.85 E)
0.00
- Point
1,637,062.00
70° 12'31.891 N 140° 48'4T525 W 1
70° 11' 53.536 N 140'48'18.705 W I
70' 12'15.058 N 140'48'11.642 W I
70° 11'54,928 N 140° 48'21.215 W I
70' 12'21.889 N 140'48'21.763 W I
3H-31AL1 T04 0.00 0.00 5,996.00 11,700.951,138,771.35 6,012,183.00
1,635,315.00 70° 12'35.844 N 140° 48'54.047 W
- plan misses target center by 1138444.46usft at 12750.00usft MD (5989.95 TVD, 10005.17 N. -1671.85 E)
1,636,051.00
- Point
140'48'35.988 W
3H -31A Fauft2 0.00 0.00 5,980.00 8,460.95 l,138.578.11 6,008,943.00
1,637,121.00 70° 12'1.715 N 140° 48' 16.437 W
- plan misses target center by 1140251.Otusft at 12750.00usft MD (5989.95 TVD, 10005.17 N. -1671.85 E)
- Polygon
Point 1 5,980.00 0.00 0.00 6,008,943.00
1,637,121.00
Point 5,980.00 1.00 1.00 6,008,944.00
1,637,122.00
3H-31AL1 T02 0.00
0.00
6,009.00 11,006.011,137,507.55 6,011,488.00
1,636,051.00
70° 12'28,008 N
140'48'35.988 W
- plan misses target center by 1139179.84usft
at 12750.00usft MD (5989.95 TVD, 10005.17 N, -1671.85 E)
- Point
3H-31A_Feuftl_M 0.00
0.00
0.00 7,752.871,138,519.23 6,008,235.00
1,637,062.00
70° 11'54.928 N
140" 48'21.215 W
- plan misses target center by 1140209.04usft
at 12750.00usft MD (5989.95 TVD, 10005.17 N, -1671.85 E)
- Rectangle (sides W1.00 H1,000.00 DO.00)
3H-31AL1_T03 0.00
0.00
6,008.00 11,394.981,137,107.44 6,011,877.00
1,635,651.00
70° 12'32.376 N
140° 48'45.753 W
- plan misses target center by 1138780.14usft
at 12750.00usft MD (5989.95 TVD. 10005.17 N. -1671.85 E)
5272018 P!iT lOPM Page 4 COMPASS 5000.14 Build 85
ConocoPhillips
ConocoPhillips Planning Report
BA@HES
a GEwo pang
Database: EDT Alaska Sandbox
Local Coordinate Reference:
Well 31-1-31
Company: ConocoPhillips (Alaska) Inc. -Kup2
TVD Reference:
Mean Sea Level
Project Kupawk River Unit
MD Reference:
3H-31 @2 80.00usft (31-1-31)
Site: Kuparuk 3H Pad
North Reference:
True
Well: 31-1-31
Survey Calculation Method:
Minimum Curvature
Wellborn: 3H-31AL1
15.200.00
5,996.46 23/8"
Design: 3H-31AL1_wp01
3.000
5,989.95
- Point
-1,671.85
TIP/KOP
31-1-31A_Fault2 M 0.00 0.00 0.00
8,460.951,138,578.11 6,008,943.00
1,637,121.00 70° 12'1.715 N 140° 48'16.437 W
- plan misses target center by 1140266.74usft at 12750.00usft MD (5989.95 TVD, 10005.17 N, -1671.85 E)
Stan 7cis
- Rectangle (sides M.00 H1,000.00 D0.00)
5,988.28
10,204.27
Casing Points
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
(waft) Name
(in)
(in)
15.200.00
5,996.46 23/8"
2.375
3.000
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+N/S
+E/ -W
(usft)
(usft)
(usft)
(usft)
Comment
12,750.00
5,989.95
10,005.17
-1,671.85
TIP/KOP
12,820.00
5,990.57
10,064.78
-1,708.51
Stan 7cis
13,000.00
5,988.28
10,204.27
-1,821.67
3
13,200.00
5,990.11
10,360.83
-1,945.31
4
13,500.00
5,994.63
10,583.17
-2,144.16
5
13,700.00
5,997.48
10,723.46
-2,285.97
6
13,950.00
6,004.22
10,893.15
-2,468.11
7
14,250.00
6,009.19
11,102.85
-2,680.24
8
14,550.00
6,008.16
11,312.26
-2,892.71
9
14,750.00
6,008.15
11,443.38
-3,043.08
10
14,950.00
6,004.76
11,574.65
-3,193.27
11
15,200.00
5,996.46
11,744.31
-3,375.38
Planned TO at 15200.00
6272018 1:57:10PM Page 5 COMPASS 5000.14 Build 85
* - ConocoPhillips HER
ConocoPhillips Travelling Cylinder Report HES
TUcompany
Company:
ConocoPhillips (Alaska) Inc. -Kup2
Project
Kuparuk River Unit
Reference Site:
Kuparuk 3H Pad
Site Error.
0.00 usft
Reference Well:
31-1-31
Well Error.
0.00 usft
Reference Wellbore
3H-31AL7
Reference Design:
3H-31AL1_wp01
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 3H-31
31-1-31 G 80.O0usft (3H31)
3H-31 @ 80.00usft (31-1-31)
True
Minimum Curvature
1.00 sigma
EDT Alaska Prod
Offsat Datum
Reference
3H-31AL1_wp01
Depth
Fitter type:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
To
Interpolation Method:
MD Interval 25.00usft Error Model:
ISCWSA
Depth Range:
12,750.00 to 15,200.00usft Scan Method:
Tray. Cylinder North
Results Limited by:
Maximum centercenter distance of 1,712,00 usft Error Surface:
Pedal Curve
Survey Tool Program
Date 6/27/2018
Depth
Depth
From
To
121.00
121.00 16"
(usft)
(usft) Survey Mention)
Tool Name
Description
88.20
10,409.0031-1-31(3H-31)
GCT -MS
Schlumberger GCT multishot
10,409.00
12,750.00 3H-31A_wp02(3H31A)
MWD
MWD- Standard
12,750.00
15,200.00 3H -31A1-7 wp01 (3H-31AL1)
MWD
MWD - Standard
Casing Points
Measured
vertical
Depth
Depth
(usfq
(usft)
121.00
121.00 16"
5,023.10
3,262.47 9 5/e"
15,200.00
6,076.46 2 3/8"
Name
Casing Hole
Diameter Diameter
16
9-516
2-316
26
13-1/2
3
Summary
Kupamk 3H Pad -3H-31-3H-31A-3H-31A_wp02
Ciba slh Error. 0.00 unit
Reference
Offset
Centre to
No -Go
Allowable
Ruk Mai nee: Miner 1110
9
Measured
Measured
Centre
Distance
Deviation
Warning
Site Name
Depth
Depth
Distance
(usft)
from Plan
Offset Well - Wellbore- Design
(usft)
(usft)
(usft)
Rererance
(usft)
Tooaace+
Kuparuk 3H Pad
Cu1na-
Cernrato
No eo
shoe w Wemirq
tmpM
cept6
31-1-28 - 3H-28 - 31-1-28
Oeiah
/nanmN
•NM18
Out of range
31-1-28 - 3H -28A- 3H -28A
Cenhe
0k
Wvktkn
N-111
(um)
Out of ranee
3H-31-31-1-31A-3H-3IA_WP02
13,073.95
13,075.00
23.08
1.40
22.85
Pass - Minor 1/10
3H-32 - 31-1-32 - 3H-32
(sap
fuss)
12.14.99
6,07077
12.775.00
Out of range
3H-32 - 3H-32PB7 - 3H-32PB1
0.15
-179.67
10,02652
-1.68,4 B0
2-11/16
Out of range
Kuparuk 3M Pad
-0.14 FAL-Mlnorl/10
t2,79e%
6,07092
12.600.00
8,072.16
0.24
3M -24 -3M -241-1-03-3M-2411-03
14,900.00
12,700.00
1,657.50
391.75
1,268.19
Pass - Major Risk
3M -28 -3M -28-3M-28
13,411.25
13,025.00
115.70
7.20
112.26
Pass - Minor 1/10
Offset Design
Kupamk 3H Pad -3H-31-3H-31A-3H-31A_wp02
Ciba slh Error. 0.00 unit
survey Prognm: &&GCT -Ma, 105 mm
Ruk Mai nee: Miner 1110
9
Onset WeO Error: 0.00.0
Rehmnce
dens[
semi Mapr Asla
W...d
wnka
Measured
V..c.l
Rererance
0sw
Tooaace+
Msetek00om GMn
Cu1na-
Cernrato
No eo
shoe w Wemirq
tmpM
cept6
rkpth
Oeiah
/nanmN
•NM18
sEyyy
mksi
Cenhe
0k
Wvktkn
N-111
(um)
funs/
Wan
fusel
(v'Al
(°I
fusnl
(Pem
('I
(Pall
(sap
fuss)
12.14.99
6,07077
12.775.00
6,071.00
0.12
0.15
-179.67
10,02652
-1.68,4 B0
2-11/16
0.36
0.66
-0.14 FAL-Mlnorl/10
t2,79e%
6,07092
12.600.00
8,072.16
0.24
0.29
179.50
10,047.47
.1,698.40
2-11116
1.45
11.92
0]8 Pass-M.r1l10
12.024.00
6,070.43
12,82500
6,073.20
0.33
0.4
178.52
10,088.00
-1)1263
2.11116
3.25
1.12
2.43 Pass-MIna1/10
12.049.89
6,068.80
12,850.00
8,074.20
OA3
ew
177.42
10,080.08
-1.727.49
611118
5.20
1.26
126 Pass-Minw1110
12874.94
6,69.28
12,875.00
4075.15
0.54
0.76
176.87
10,107.70
-1,742.95
2-11/16
7.03
1.35
5.98 Pass -Minor 1110
12,900,05
8,06488
12,900.00
6,076.06
0.65
0.92
17410
10,128.&5
-1]59.00
2-11116
8.73
1.40
7.57 Pus-Minor1110
12,925.20
6.M.55
12.925.00
6,076.92
0.76
1.09
175.65
10,145.49
-1.775.63
2.11/16
10.31
1+41
9.07 Pau-Minot/10
12850.39
6.06435
12.950.00
8,077.74
0.88
1.27
175.31
10,163.82
-1,792.82
2-11116
11.78
1.41
10.48 Pa1s-Minor1/10
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse seoarabon
6272018 9:43:54AM Page 2 COMPASS 5000.14 Build 85
ConocoPhillips
8A ER
F�U ,HES
GEm paw
West( -)/East(+) (400 usft/in)
Mean!
Vertical Section at 330.00° (150 usft/in)
1
Project Kuparuk River Unit
Site: Kuparak 3H Pad
Ntl^�reTMre m^^
menee=uonn. ra
N,r..x Fl.le
WELLBORE DETAILS: 3HJ1A111
REFERENCE WFOR OWTION
Parent Wellbore. 3H -31A
coormneb(w )2ebiam'. "3w1,T.Nab
Well: 3H-31
Northing
S°°'e'^n°10 T°"
Te On MD: 12750,00
vcrecel NVO)Rebmu'. ekm3nlnw
Longitude
Wellbore: 3X-314111
OtRNW: m.Rr
498655.24
section rvs7 Pelererce: Ew o.00E)
N 150°
Plan: 3X41AL1_vrya1 (3X-31/3X-]1AL1(
See MD
.1
Azl
1 @K
Maee�awo iN. moDunl3Nai1
eg
T ace
VSect
b nWOM'.
CeGk4n Fb?M: Wrenuni Cw'el0e
8A ER
F�U ,HES
GEm paw
West( -)/East(+) (400 usft/in)
Mean!
Vertical Section at 330.00° (150 usft/in)
1
WELL
DETAILS:
3H-31
,NI -S +E/ -W
Northing
Easting
Latitude
Longitude
0.00 0.00
6000687.91
498655.24
70° 24'47.208
N 150°
0'39.425 W
See MD
Inc
Azl
DS
eg
T ace
VSect
Annotation
1 12750.00
87.37
329.64
5989.95
10005.17 -1671.85
0.00
0.00
9500.66
TIP/KOP
2 12820.00
91.62
327.19
5990.57
10064.78 -1708,51
7.00
330.00
9570.60
Start 7 dls
3 13000.00
89.84
314.71
5988.28
10204.27 -1821.67
7.00
262.00
9747.99
3
4 13200.00
89.12
328.69
5990.11
10360.83 -1945.31
TOD
93.00
9945.40
4
5 1350(1.00
89.18
307.69
5994,63
10583.17 -2144,16
7.00
270.00
10237.37
5
6 13700.00
89.20
321.69
5997.48
10723.46 -2285.97
TDO
90.00
10429.78
6
7 13950.00
87.74
304.25
6004.22
10893.15 -2468.11
7.00
265.00
10667.80
7
8 14250.00
90.39
325.OB
6009.19
11102.85 -2680.24
7.00
83.00
10955.47
8
9 14550.00
90.00
304.09
6008.16
11312.26 -2892.71
7.D0
269.00
11243.06
9
10 14750.00
90.00
318.09
6008.15
11443.38 -3043.08
7.DD
90.00
11431.80
10
11 14950.00
91.93
304.22
6OD4.76
11574.65 -3193.27
7.00
278.00
11620.58
11
12 15200.00
91.84
321.73
5996.46
11744.31 -3375.38
TDO
90.00
11858.56
Planned TD at 15200.0
8A ER
F�U ,HES
GEm paw
West( -)/East(+) (400 usft/in)
Mean!
Vertical Section at 330.00° (150 usft/in)
1
KUP PROD 3H-31
ConoeoPhillips
Qldb'ita. I(I(:.
Well Attributes Max AngM&MD TD
We11032APl/1001 InName WNIbore Btntus Ildfl MO1-1 MBIm mKDI
501032020500 KUPARUK RIVER UNn PROD fi5.93 1,8]661 10.730.0
Commml 1,041PPm1 I Late AnnMAbn EM DMe MINI Rip Releve OaR
SSaV: NIPPLE Last Mb: 35/1997 4099 2113/1994
3Na1. sn 3Gala]:4ess PM
Last Tag
Ikgin mKa) EnG dh IesiMM Ry
Lam Tag: RKB(Ea. 44' of Bellow) 10.5360 51132018 zembaej
Last Rev Reason
Mn..n EnE T Ia51 MM 8y
Rev Reason: Updated Tag 5/13/2010 zembaej
FWJGER. 3Ifi
CONOVLTOR. 4361210
NIPPLE: .0-
9VRFACE: 4185,OH.1�
GAS LIFT, 10.m.z
NIPPLE; come¢
am Assn 1O.3CB8
PACKER: mato]
NIPPLEa0.me
50510.335.]
RPQi F. 10A2fi.610.H4a�
IPERF:10MG-104830-
APERF, 104eza10aad
PRODUGTiON.U] 10.Me
Cask* Strings
On., DasP0n OO Dn1 IDlinl TOPINKBI BetOryNlKKa) aN DvpIM1 IT`/O) NYfLen 11... Gra]e Top TMml
CONDUCTOR 16 IS G62 43.0 121.0 1210 62.50 1440 WELDED
el Depth mKe) sN DepIN MII... lave Tap TnreaJ
np 0eacnplion OD 911 IGlinl iapl 1 ""p"a
SURFACE 95/8 8921 418 5.023.1 2,8896 36.00 J55 BTC
Gating OefaiPlwn GOlinl IDlinl Tapl e) 4tO .91Ka1 SM DepN11Tv01... Len 1... Orta Top Tb@]
PRODUCTION ] 62]6 34.) 10 11,8 5,854.] 26.00 LEO BTC -MOD
Tubing Strings
Tubing U-11ption 81nng Ma... lO1in) Tap l([KO BN DvpM IR. Bel Depth M01 I... W11mM1 G.. Top LwlnR Ion
TUBING 312 2992 316 10,3366 5,56).3 930 L -GO ASIA SUE
Completion Details
TopINDI TOP Incl Nwnlnal
Top IRK01 mKBI r) 1.0ez Com 109.1
-0,
76 37.6 Be Eft MCEVOY GEN 4 TUBING WINGER 3500
488.0 114a 114 NIPPLE CAMCO 05 LANDING NIPPLE 2.812
102702 5,51].1 41.92 NIPPLE CAMCO WI SELECTIVE NFPLE NO GO 2.812
10,308. 5546.9 4063 SEALASSY BAKER K H22 ANCHOR SEAL ASSEMBLY 3.000
In 10. 55476 40.60 PACKER BAKER SA 3PERMAN NT PACKER 3.250
10,3266 5,559.] 4035 NIPPLE CAMCO O NIPPLE NO GO 2 75
103357 5566.6 4028 SO$ BAKER SHEAR OUT SUB 2.992
Perforations & Slots
TOPIrvDI atm l3V[1)
TOp IN(e1 DM mKaI mK91 1RK6) zme
8aq
Gena
lehmwrc
D1. 1
Tree
cum
10,426,010,444.0 5.835.5 5.649.3 Gd.3W31
3/12/2000 4.0
RPERF
a, ph, +1
2I had
.90 deg Dd
10.452.0 10.482.0 5,0554 5.8]84 A -2.A -1.3M81
5/1G1994 4.0
FEW
4112' HSD; 180 deg ph
10.4820 10,1940 5,8)84 5.6818 A-1,SWS1
[1202011 60
APER
assana. Deep Penahnnng
chargee, 60 degree phasing
Mandrel Inserts
r
n
Tep (TVD)
IN Top I.K91
Make
Molal
001114
8ary
VeM
Type
Le6T
TYCa
Pori Size
(Inl
TRO Run
IW11
Runt
Pan
10223. 5482.5
548
OTIS
8%
1112
AS LI
MY
RM
00
0
t /1 /199)
.
Notes: General & Safety
EM Dale
gnnptYlon
11/12/2010
NOTE: View Schemmil w/ Alaska SCllema.9.0
3H-31 Proposed CTD Schematic
16" 62# H-40 shoe @
121' MD
i
I9-5/8" 36# J-55 shoe
0.5023' MD
Liner Top Packer
C4 -sand perfs 10,4
10,444' MD
KOP @ 10,437'M67
A -sand perfs
10,452'-10,494'M
7" 26# L-80 shoe @
10,712' MD
Uooer Completion
3-1/2" 9.3# L-80 EUE 8rd Tubing to surface
3-1/2" DS nipple @ 488' MD (2.812" min ID)
POGLM(s) @ TBD (Post CTD)
3-1/2" Camco gas lift mandrels @ 10,223'
3-1/2" W-1 nipple @ 10,270' MD (2.812" min ID)
Lower Completion
Baker KBH-22 Anchor Seal
Baker SAB -3 Permanent Paker @ 10,311' MD
3-1/2" D nipple @ 10,326' MD (2.75" min ID)
Baker Shear Out Sub @ 10,336' MD
000
3H-31AL1 wp01
Well Plan TD: 15,200' MD
Modeled WOB Limit: -14,800' MD
Top of liner @ 10,320' MD
3H-31 A wp02
Well Plan TD: 15,200' MD
Modeled WOB Limit: -14,800' MD
Billet @ 12,750' MD
TRANSMITTAL LETTER CHECKLIST
WELL NAME:
/ PTD: 2
✓ Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: X-4 171_z l i I/ e ✓ POOL:
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is fob new wellbore segment of existing well Permit
LATERAL
No. Z[f3-DT5 API No. 50 -Il - Z021G66[- e3Q
(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 emit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
/
er Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 3H-31AL1 Program DEV------- Well bore seg
PTD#-. 2180760 Company CONOCOPHILLIPS ALASKA. INC..__ ._ _ _ _ Initial Class/Tvpe - DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disoosal
Appr Date
SFD 6/29/2018
Engineering
Appr Date
MGR 7/5/2018
11
2
13
4
5
6
7
8
9
10
11
12
13
14
15
16
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
Nonconven.. gas conforms to AS31,05,0300. 1.A),0.2.A-D) - - -
NA
Engineering
�Comm�ission Date
Permit fee attached
NA
Lease number appropriate _ _ _ _
Yes
Surface Location lies within ADLQ025531; Top Prod Int & TO lie within ADL0025524.-
Unique welt. name and number - - - - - -
Yes
Well located in. a. defined. pool - -
Yes
Kuparuk River Oil Pool, governed by Conservation Order No. 432D
Well located proper distance from drilling unit boundary...
Yes
Conservation Order No. 432D has no inlerwell. spacing. restrictions. Wellbore will be. more than 500' -
Well located proper distance from other wells - - - -
Yes
from an external property line where ownership or landownership changes. As proposed, well will..... .
Sufficient acreage available in. drilling unit -
Yes
conform to spacing. requirements..
If deviated, is wellbore plat included - - - - - - - - -
Yes
- - - -
Operator only affected party... - - - - - - - -
Yes
- -
Operator has. appropriate bond in force . .............
Yes -
- - - - - - - -
Permit can be issued without conservation order
Yes
Permit. can be issued without administrative. approval - - - - - - - - -
Yes
Can permit be approved before 15 day wait.. ..............
Yes
Welllocated within area andstrataauthorized by Injection Order # (put 10# in -comments) -(For.
NA.
All wellswithin1/4. mile -area. of review identified (For service well only) - - -
NA...
Pre -produced injector:. duration of pre -production less than 3 months. (For service well only) . -
NA
Conductor sking.provided - _ - - - -------- - - - - - - - - - - -
NA
CTD sidetrack in production hole - - - - - -
Surface casing protects all -known USDWs ........... - -
NA - - -
- CTD sidetrack in production hole
CMT vol adequate to circulate -on conductor & surf csg -- - - - - - - - - - - - -
NA .........
CMT vol adequate. to tie-in long string to.surf csg.. - - - - - - -
NA -
- - - Slotted liner in production hole,. TOL. in tubing tail
CMT. will cover all known.productive horizons . . . . . . . . . . . . . ............
NA
- Slotted liner in production hole,TOL-into tubing tail...
Casing designs adequate for C, T, B & permafrost- - - - - - - - .. - - - -
Yes
Adequate tankage or reserve pit - - - - - - . . . . ... .....
Yes
- - - - - - - - - - - - - - - - -
If a re -drill, has a 10-403 for abandonment been approved ... - - - - - - - _ - - -
Yes
- - - - - - -
Adequatewellboreseparation.proposed------ - - - - - - - - - - - - - - -
Yes
If diverter required, does it meet regulations- - - - - - - - - - - - - - - -
NA.
Drilling fluid program schematic & equip list adequate_ .......... - - - - - - -
Yes
BOPEs, do they meet regulation - - - - - - - - - - - ------------ - - - - - - - - - -
Yes .
BOPE press rating appropriate; test to -(put psig in cpmments)_ - _ - - .....
Yes - -
- - - -
Choke manifold complies w/API- RP -53 (May 84)- - - - - - - - - - - - - - - -- - - ---- - -- - -
Yes
Work will occur without operation shutdown- - - - - - - - - -- - - --- - - - - - - - - - - - - - -
Yes
Is presence of 1-112S gas probable - - ... - . - _ . - ..
Yes
Mechanical condition of wells within AOR verified (Foc service well only) - - - - - - - - - - ----
NA ........
_ .. - - - - - - _ - - _ - - ..... - - - - _ - - _ - - - - ...... .
35 Permit can be issued w/o hydrogen sulfide measures ... . . . . . . . . ..... No - - - - 31 -1 -Pad wells are H2S-bearing.. H2S. measures are required, - - - - - - - - -
Geology 36 Data
on resented potential overpressure zones- . . . . . ............. Yes - - - - - - Expected reservoir pressure is 12.1 ppg EMW (with a maximum of 13,0. ppg EMW). Well will be - - - - -
P
Appr Date 37 Seismic analysis of shallow gas.zones- - - - - - - - - - - - - - - - - - - ------ - - - - - - - NA... - _ drilled using B.6 ppg mud,.a coiled -tubing. rig, and managed.pressure drilling technique to - - - - - -
SFD 6/29/2018 38 Seabed condition survey (if off -shore) - - - - - - - - - - - - - - - - - ------------ NA - - - - - - - control formation pressures and maintain -shale stability..... -
39 Contact name/phone for weekly_ progress reports[exploratoryonly]- - - - _ - _ - NA-
Geologic
Commissioner:
Date:
Engineering
�Comm�ission Date
Public
Commi sinner
ae
