Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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Slotted Liner
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$ 79
Associate Reservoir Engineer
Devin Kozak
9 79?
-13,/2+;#B2Devin Kozak Digitally signed by Devin Kozak
Date: 2021.03.31 16:53:40 -08'00'
By Samantha Carlisle at 8:48 pm, Mar 31, 2021
VTL 5/5/21 RBDMS HEW 4/2/2021
SFD 4/1/2021DSR-4/1/21
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Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Set 3.75" P2P W/ K-Valve 3/6/2021 3R-107 zembaej
Casing Strings
Casing Description
CONDUCTOR
OD (in)
20
ID (in)
18.50
Top (ftKB)
40.0
Set Depth (ftKB)
169.0
Set Depth (TVD)…
169.0
Wt/Len (l…
154.34
Grade
65
Top Thread
NA
Casing Description
SURFACE
OD (in)
10 3/4
ID (in)
9.95
Top (ftKB)
39.9
Set Depth (ftKB)
2,253.3
Set Depth (TVD)…
2,169.3
Wt/Len (l…
45.50
Grade
L-80
Top Thread
Hydril 563
Casing Description
INTERMEDIATE
OD (in)
7 5/8
ID (in)
6.88
Top (ftKB)
0.0
Set Depth (ftKB)
7,069.7
Set Depth (TVD)…
3,680.5
Wt/Len (l…
29.70
Grade
L80
Top Thread
H563
Casing Description
LOWER LATERAL
SLOTTED LINER
OD (in)
4 1/2
ID (in)
3.99
Top (ftKB)
5,336.6
Set Depth (ftKB)
13,614.0
Set Depth (TVD)…
3,788.7
Wt/Len (l…
12.60
Grade
L-80
Top Thread
Hyd 563
Liner Details
Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com
Nominal ID
(in)
5,356.33,654.4 87.51 NIPPLE- RS Baker 5.5" RS Nipple, 17# , L-80, Hyd 563 box x box 4.890
5,369.03,654.987.49SBE (Seal Bore
Extension)
Baker 190-47 Sealbore Extension, 20' 5-1/2" L-80
Hyd 563 box X pin
4.750
8,286.23,723.286.71SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #24
3.980
8,306.3 3,724.4 86.60 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #23
3.980
8,987.83,675.093.13 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #22
3.980
9,007.83,674.092.29 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #21
3.980
Tubing Strings
Tubing Description
ESP TUBING
COMPLETION
String Ma…
4 1/2
ID (in)
3.96
Top (ftKB)
34.6
Set Depth (ft…
5,206.7
Set Depth (TVD) (…
3,647.9
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
Hyd 563
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com
Nominal
ID (in)
34.6 34.6 0.00 HANGER VETCO/GE MB 242 13-3/8" x 4-1/2" tubing hanger (4.909 MCA
Box Up)
3.900
4,807.3 3,630.3 87.45 GAUGE/PUMP
SENSOR
HES ROC-150 Annulus DHG ser # ROC-005608-10 + Mandrel 3.919
4,818.4 3,630.8 87.51 GAUGE/PUMP
SENSOR
HES ROC-150 Discharge DHG ser # ROC-005612 + Mandrel 3.919
4,963.8 3,637.3 87.44 Sliding Sleeve 5-1/2" GVSSD, 4 1/2" Vamtop Box x 5 1/2", 23#, Vam FJL Box
(Closed 1/10/21)
3.913
4,967.8 3,637.5 87.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,972.2 3,637.7 87.44 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,973.7 3,637.7 87.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,978.2 3,637.9 87.44 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,979.7 3,638.087.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,984.4 3,638.287.44 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,985.9 3,638.3 87.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,990.4 3,638.5 87.45 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,991.93,638.687.45 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,996.33,638.7 87.45 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,997.83,638.887.45 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
5,002.3 3,639.0 87.45 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
5,003.8 3,639.1 87.45 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
5,008.2 3,639.3 87.46 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
5,009.7 3,639.3 87.46 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 4.548
5,016.1 3,639.6 87.47 Annular
Connection Port
Ann Connection Port 5", 18# Vam FJL Box x 4 1/2" 12.6# Vamtop
Box SN#ACPTX18M0021
3.835
5,039.7 3,640.7 87.51 Profile Sub B-Profile, 4 1/2", 12.6#, L-80 Vamtop Box x Box 3.956
5,053.23,641.287.53 No-go nipple No-Go, 4 1/2" 12.6# Vamtop Box x 4 1/2" Hyd 563 Box 3.813
5,068.23,641.987.55 Sliding Sleeve Camco Sliding Sleeve CMU w/ 3.813 X-nipple, 4 1/2" Hyd 563
SN#2B (Closed 1/9/2021)
3.813
5,116.93,643.987.57 SSSV SSSV NE TRSV-HAL, 6.62" x 3.813 X-nipple TSH-Blue Box x Pin 3.813
5,179.7 3,646.7 87.45 LOCATOR Mechanical locator (Collar 5.5" OD ( NOGO spaced out 3' Seal
assembly)
3.870
5,180.13,646.7 87.45 Seal Assembly Baker 192-47 Seal assembly, 4 1/2" Hyd 563 Box 3.870
Tubing Description
LEM
String Ma…
4 1/2
ID (in)
3.88
Top (ftKB)
5,171.0
Set Depth (ft…
5,384.0
Set Depth (TVD) (…
3,655.6
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
HYD 563
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com
Nominal
ID (in)
5,171.03,646.387.46 PACKER HR ZXP LTP w/HD L-80 & 10’ ext, 5-1/2” 14# Hyd 563 Pin Down 4.890
5,190.7 3,647.287.43SBE (Seal Bore
Extension)
190-47 SBE, 5-1/2” Hyd 563 Box x Pin 4.750
5,226.4 3,648.887.47 NIPPLE DB Camco 4.5 x 3.75” DB-6 Nipple to isolate both laterals (SN# 6918-
3)
3.750
5,249.2 3,649.8 87.51 DIVERTER T1 LEM, Pos #4, 4-1/2” BTC Box x Pin, above hook 3.710
5,252.33,649.987.51 DIVERTER T1 LEM, Pos #4, 4-1/2” BTC Box x Pin, below hook 3.688
MULTIPLE LATERALS, 3R-107, 3/24/2021 2:13:08 PM
Vertical schematic (actual)
LOWER LATERAL SLOTTED
LINER; 5,336.6-13,614.0
Annular Fluid - Flo-Pro Drilling
Mud; 5,192.0-13,614.5
INTERMEDIATE; 0.0-7,069.7
SEAL ASSY; 5,380.7
NIPPLE; 5,329.3
DIVERTER T1; 5,252.3
DIVERTER T1; 5,249.1
Tubing - Pup; 5,245.1
Tubing - Pup; 5,238.3
Tubing - Pup; 5,228.4
NIPPLE DB; 5,226.4
SBE (Seal Bore Extension);
5,190.7
Seal Assembly; 5,180.1
PACKER; 5,171.0
LOCATOR; 5,179.7
SSSV; 5,116.9
INJECTION; 5,092.9
Sliding Sleeve; 5,068.2
No-go nipple; 5,053.2
Profile Sub; 5,039.7
ACCESS ESP ISO-SLEEVE;
5,015.0
Annular Connection Port;
5,016.1
Motor Shroud; 5,009.7
Motor Centralizer; 5,008.2
Motor Shroud; 5,003.8
Motor Centralizer; 5,002.3
Motor Shroud; 4,997.8
Motor Centralizer; 4,996.3
Motor Shroud; 4,991.9
Motor Centralizer; 4,990.4
Motor Shroud; 4,985.9
Motor Centralizer; 4,984.4
Motor Shroud; 4,979.7
Motor Centralizer; 4,978.2
Motor Shroud; 4,973.7
Motor Centralizer; 4,972.2
Motor Shroud; 4,967.8
Sliding Sleeve; 4,963.8
GAUGE/PUMP SENSOR;
4,818.4
GAUGE/PUMP SENSOR;
4,807.3
GAS LIFT; 4,046.1
Annular Fluid - Diesel; 2,633.2-
5,337.2
GAS LIFT; 2,633.3
SURFACE; 39.9-2,253.3
3.75" P2P W/ K-Valve (418
Dome PSI); 1,868.0
Annular Fluid - Saltwater/Brine;
34.6-2,633.2
CONDUCTOR; 40.0-169.0
HANGER; 34.6
KUP PROD
KB-Grd (ft)
39.45
Rig Release Date
2/19/2020
3R-107
...
TD
Act Btm (ftKB)
13,614.0
Well Attributes
Field Name Wellbore API/UWI
500292366000
Wellbore Status
PROD
Max Angle & MD
Incl (°)
98.35
MD (ftKB)
8,717.71
WELLNAME WELLBORE
Annotation End DateH2S (ppm)
2
Date
8/4/2020
Comment
SSSV NE TRSV, HES SAP,6.6…
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com
Nominal
ID (in)
5,329.33,653.287.53 NIPPLE Camco 4.5" x 3.562" DB-6 for parent isolation (SN # 6199-1) 3.563
5,380.7 3,655.4 87.48 SEAL ASSY 190-47 GBH-22 Non Locating Seal Assembly, 4 1/2" STL Box 3.860
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°)Des Com Run Date ID (in)SN
1,868.01,827.623.77 3.75" P2P W/ K-
Valve (418 Dome
PSI)
3.75" P2P W/ K-Valve (418 closing pressure
@ 60°F / 86" OAL)
2/18/2021 0.000
5,015.0 3,639.6 87.47 ACCESS ESP
ISO-SLEEVE
AccessESP Iso-sleeve 1/10/2021 3.000
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB)Make Model OD (in)Serv
Valve
Type
Latch
Ty pe
Port Size
(in)
TRO Run
(psi)Run Date Com
1 2,633.32,501.8Camco 1 GAS LIFT GLV BK 0.188 1,526.01/11/2021
2 4,046.13,482.0Camco 1 GAS LIFT OVBK 0.313 0.01/11/2021
3 5,092.9 3,642.9 HES Halliburt
on
5.6CHEM DCIV-
8000
800.08/8/2020 Max
rate
3GPM
, 700-
800
cracki
ng
press
MULTIPLE LATERALS, 3R-107, 3/24/2021 2:13:10 PM
Vertical schematic (actual)
LOWER LATERAL SLOTTED
LINER; 5,336.6-13,614.0
Annular Fluid - Flo-Pro Drilling
Mud; 5,192.0-13,614.5
INTERMEDIATE; 0.0-7,069.7
SEAL ASSY; 5,380.7
NIPPLE; 5,329.3
DIVERTER T1; 5,252.3
DIVERTER T1; 5,249.1
Tubing - Pup; 5,245.1
Tubing - Pup; 5,238.3
Tubing - Pup; 5,228.4
NIPPLE DB; 5,226.4
SBE (Seal Bore Extension);
5,190.7
Seal Assembly; 5,180.1
PACKER; 5,171.0
LOCATOR; 5,179.7
SSSV; 5,116.9
INJECTION; 5,092.9
Sliding Sleeve; 5,068.2
No-go nipple; 5,053.2
Profile Sub; 5,039.7
ACCESS ESP ISO-SLEEVE;
5,015.0
Annular Connection Port;
5,016.1
Motor Shroud; 5,009.7
Motor Centralizer; 5,008.2
Motor Shroud; 5,003.8
Motor Centralizer; 5,002.3
Motor Shroud; 4,997.8
Motor Centralizer; 4,996.3
Motor Shroud; 4,991.9
Motor Centralizer; 4,990.4
Motor Shroud; 4,985.9
Motor Centralizer; 4,984.4
Motor Shroud; 4,979.7
Motor Centralizer; 4,978.2
Motor Shroud; 4,973.7
Motor Centralizer; 4,972.2
Motor Shroud; 4,967.8
Sliding Sleeve; 4,963.8
GAUGE/PUMP SENSOR;
4,818.4
GAUGE/PUMP SENSOR;
4,807.3
GAS LIFT; 4,046.1
Annular Fluid - Diesel; 2,633.2-
5,337.2
GAS LIFT; 2,633.3
SURFACE; 39.9-2,253.3
3.75" P2P W/ K-Valve (418
Dome PSI); 1,868.0
Annular Fluid - Saltwater/Brine;
34.6-2,633.2
CONDUCTOR; 40.0-169.0
HANGER; 34.6
KUP PROD 3R-107
...
WELLNAME WELLBORE
Casing Strings
Casing Description
L1UPPER LATTER
SLOTTED LINER
OD (in)
4 1/2
ID (in)
3.96
Top (ftKB)
5,252.1
Set Depth (ftKB)
13,578.0
Set Depth (TVD)…
3,771.6
Wt/Len (l…
12.60
Grade
L-80
Top Thread
TXP (BTC)
Liner Details
Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com
Nominal ID
(in)
5,252.13,649.288.96 HANGER Baker "B-3" Flanged hook hanger, 4.5" X 7.63" Inside
casing
5.610
5,271.5 3,649.4 89.48 HANGER Baker "B-3" Flanged hook hanger, 4.5" X 7.63" 'BOW
@ 5271.74' MD
3.950
5,388.03,650.389.04 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(054009-010-21) M
3.958
6,079.5 3,670.289.82 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(054009-010-2) L
3.958
8,199.5 3,703.288.48SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(001893-001-19) K
3.958
8,809.63,664.5 94.00 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(001893-001-16) J
3.958
13,536.63,769.987.62 PBR (Polished
Bore
Receptacle)
4 1/2'' Drillable Packoff Bushing, BTC Box x Pin 2.370
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°)Des Com Run Date ID (in)SN
5,258.0 3,649.3 89.12 WHIPSTOCK 1/28/2020 5.000
MULTIPLE LATERALS, 3R-107L1, 3/24/2021 2:13:43 PM
Vertical schematic (actual)
L1UPPER LATTER SLOTTED
LINER; 5,252.1-13,578.0
WHIPSTOCK; 5,258.0
INTERMEDIATE; 0.0-7,069.7
DIVERTER T1; 5,252.3
DIVERTER T1; 5,249.1
Tubing - Pup; 5,245.1
Tubing - Pup; 5,238.3
Tubing - Pup; 5,228.4
NIPPLE DB; 5,226.4
Annular Fluid - Flo-Pro Drilling
Mud; 5,192.0-13,614.5
SBE (Seal Bore Extension);
5,190.7
Seal Assembly; 5,180.1
PACKER; 5,171.0
LOCATOR; 5,179.7
SSSV; 5,116.9
INJECTION; 5,092.9
Sliding Sleeve; 5,068.2
No-go nipple; 5,053.2
Profile Sub; 5,039.7
ACCESS ESP ISO-SLEEVE;
5,015.0
Annular Connection Port;
5,016.1
Motor Shroud; 5,009.7
Motor Centralizer; 5,008.2
Motor Shroud; 5,003.8
Motor Centralizer; 5,002.3
Motor Shroud; 4,997.8
Motor Centralizer; 4,996.3
Motor Shroud; 4,991.9
Motor Centralizer; 4,990.4
Motor Shroud; 4,985.9
Motor Centralizer; 4,984.4
Motor Shroud; 4,979.7
Motor Centralizer; 4,978.2
Motor Shroud; 4,973.7
Motor Centralizer; 4,972.2
Motor Shroud; 4,967.8
Sliding Sleeve; 4,963.8
GAUGE/PUMP SENSOR;
4,818.4
GAUGE/PUMP SENSOR;
4,807.3
GAS LIFT; 4,046.1
Annular Fluid - Diesel; 2,633.2-
5,337.2
GAS LIFT; 2,633.3
SURFACE; 39.9-2,253.3
3.75" P2P W/ K-Valve (418
Dome PSI); 1,868.0
Annular Fluid - Saltwater/Brine;
34.6-2,633.2
CONDUCTOR; 40.0-169.0
HANGER; 34.6
KUP PROD
KB-Grd (ft)
39.45
Rig Release Date
2/19/2020
3R-107L1
...
TD
Act Btm (ftKB)
13,610.0
Well Attributes
Field Name Wellbore API/UWI
500292366060
Wellbore Status
PROD
Max Angle & MD
Incl (°)
96.52
MD (ftKB)
8,622.33
WELLNAME WELLBORE
Annotation End DateH2S (ppm)
2
Date
8/4/2020
Comment
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By Samantha Carlisle at 11:22 am, Feb 22, 2021
321-093
Rachel Kautz Digitally signed by Rachel Kautz
Date: 2021.02.22 10:50:18 -09'00'
X
20 AAC 25.265(o), Approval is granted for a variance to use a non-surface
controlled subsurface safety valve (SSSV) as the primary SSSV in Kuparuk River Unit producer 3R-107.
X
DLB 02/22/2021VTL 3/2/21
DSR-2/22/21
13,610' DLB
10-404
Per 20 AAC 25.265 (h) (2) witnessed performance test by AOGCC. 24 hour notice.
"
23
3/3/21
dts 3/3/2021 JLC 3/3/2021
RBDMS HEW 3/3/2021
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
February 22, 2021
AOGCC Commissioner
State of Alaska, Oil & Gas Conservation Commission
333 W. 7th Ave., Suite 100
Anchorage, AK 99501
Dear Commissioner,
In accordance with 20 AAC 25.265(o), ConocoPhillips requests approval for a variance to use a non-surface
controlled subsurface safety valve (SSSV) as the primary SSSV in Kuparuk River Unit producer 3R-107.
KRU 3R-107 was completed as a producer in February 2020 with a tubing conveyed, surface-controlled SSSV.
A passing state-witnessed test of the surface-controlled SSSV was last performed in November 2020. However,
following a failed test witnessed by Adam Earl on February 20, 2020, ConocoPhillips has decided to install a
Halliburton K-valve between 1700’-2000’ rather than mobilize coil to investigate the deep SSSV.
Enclosed please find the 10-403 forms for 3R-107 & 3R-107L1 (PTD 219-180 & 219-181), schematic,
proposed operating plan, and the ConocoPhillips SOP for testing non-surface controlled SSSV.
Sincerely,
Rachel Kautz
Production Engineer
ConocoPhillips Alaska, Inc.
907-659-7871
Rachel Kautz
Digitally signed by Rachel
Kautz
Date: 2021.02.22 10:51:02
-09'00'
Proposed Operating Plan
1. When necessary, perform flowing pressure and temperature survey with gauges at the estimated
Halliburton K-valve set depth. Gather data at depth during full-open stable flow, as well as
various other producing conditions, to identify smoothest flowing scenario for good K-valve
operation.
2. Use data to appropriately design and charge K-valve.
3. Install K-valve.
4. Restart and stabilize production at designed conditions for the K-valve installed.
5. Perform and schedule test per ConocoPhillips Standard Operating Procedure (SOP).
6. Incorporate the K-valve test frequency into the current SVS testing cycle at Kuparuk 3R pad.
7. Upon a passing closure test, continue operating the well in normal production service.
TEST PROCEDURE (DS-1B or DS-3R only) – test of non-surface
controlled SSSV (aka “k-valve” or “storm valve”)
These steps will take place after normal testing of the Surface Safety Valve and
Low Pressure Sensing device
1. Close the Wing Valve
2. Build 200-300 psi of tubing pressure above initial FTP reading.
3. Block-in the lift gas at the tree.
4. Open the Wing Valve completely.
5. If the well does not stop flowing within 4 minutes, indicate that the SSSV failed the
test, along with the failure code for “Failed to close” on the ConocoPhillips
Kuparuk Safety Valve Test Report.
6. After the well has stopped flowing, close the Wing Valve.
7. Record the tree cap pressure (IP for the SSSV test).
8. Open the lift gas at the tree.
9. Monitor the wellhead pressure for 3-5 minutes.
10. If the well builds pressure above the shut-in well pressure (IP), indicate that the
SSSV failed the test, along with the fa ilure code for “Failed to hold DP” on the
ConocoPhillips Kuparuk Safety Valve Test Report.
11. Testing is complete; proceed to Rig-Down steps.
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Pulled Gauges 2/18/2021 3R-107 fergusp
Casing Strings
Casing Description
CONDUCTOR
OD (in)
20
ID (in)
18.50
Top (ftKB)
40.0
Set Depth (ftKB)
169.0
Set Depth (TVD)…
169.0
Wt/Len (l…
154.34
Grade
65
Top Thread
NA
Casing Description
SURFACE
OD (in)
10 3/4
ID (in)
9.95
Top (ftKB)
39.9
Set Depth (ftKB)
2,253.3
Set Depth (TVD)…
2,169.3
Wt/Len (l…
45.50
Grade
L-80
Top Thread
Hydril 563
Casing Description
INTERMEDIATE
OD (in)
7 5/8
ID (in)
6.88
Top (ftKB)
0.0
Set Depth (ftKB)
7,069.7
Set Depth (TVD)…
3,680.5
Wt/Len (l…
29.70
Grade
L80
Top Thread
H563
Casing Description
LOWER LATERAL
SLOTTED LINER
OD (in)
4 1/2
ID (in)
3.99
Top (ftKB)
5,336.6
Set Depth (ftKB)
13,614.0
Set Depth (TVD)…
3,788.7
Wt/Len (l…
12.60
Grade
L-80
Top Thread
Hyd 563
Liner Details
Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com
Nominal ID
(in)
5,356.33,654.4 87.51 NIPPLE- RS Baker 5.5" RS Nipple, 17# , L-80, Hyd 563 box x box 4.890
5,369.03,654.987.49SBE (Seal Bore
Extension)
Baker 190-47 Sealbore Extension, 20' 5-1/2" L-80
Hyd 563 box X pin
4.750
8,286.23,723.286.71SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #24
3.980
8,306.3 3,724.4 86.60 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #23
3.980
8,987.83,675.093.13 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #22
3.980
9,007.83,674.092.29 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #21
3.980
Tubing Strings
Tubing Description
ESP TUBING
COMPLETION
String Ma…
4 1/2
ID (in)
3.96
Top (ftKB)
34.6
Set Depth (ft…
5,206.7
Set Depth (TVD) (…
3,647.9
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
Hyd 563
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com
Nominal
ID (in)
34.6 34.6 0.00 HANGER VETCO/GE MB 242 13-3/8" x 4-1/2" tubing hanger (4.909 MCA
Box Up)
3.900
4,807.3 3,630.3 87.45 GAUGE/PUMP
SENSOR
HES ROC-150 Annulus DHG ser # ROC-005608-10 + Mandrel 3.919
4,818.4 3,630.8 87.51 GAUGE/PUMP
SENSOR
HES ROC-150 Discharge DHG ser # ROC-005612 + Mandrel 3.919
4,963.8 3,637.3 87.44 Sliding Sleeve 5-1/2" GVSSD, 4 1/2" Vamtop Box x 5 1/2", 23#, Vam FJL Box
(Closed 1/10/21)
3.913
4,967.8 3,637.5 87.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,972.2 3,637.7 87.44 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,973.7 3,637.7 87.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,978.2 3,637.9 87.44 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,979.7 3,638.087.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,984.4 3,638.287.44 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,985.9 3,638.3 87.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,990.4 3,638.5 87.45 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,991.93,638.687.45 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,996.33,638.7 87.45 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,997.83,638.887.45 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
5,002.3 3,639.0 87.45 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
5,003.8 3,639.1 87.45 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
5,008.2 3,639.3 87.46 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
5,009.7 3,639.3 87.46 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 4.548
5,016.1 3,639.6 87.47 Annular
Connection Port
Ann Connection Port 5", 18# Vam FJL Box x 4 1/2" 12.6# Vamtop
Box SN#ACPTX18M0021
3.835
5,039.7 3,640.7 87.51 Profile Sub B-Profile, 4 1/2", 12.6#, L-80 Vamtop Box x Box 3.956
5,053.23,641.287.53 No-go nipple No-Go, 4 1/2" 12.6# Vamtop Box x 4 1/2" Hyd 563 Box 3.813
5,068.23,641.987.55 Sliding Sleeve Camco Sliding Sleeve CMU w/ 3.813 X-nipple, 4 1/2" Hyd 563
SN#2B (Closed 1/9/2021)
3.813
5,116.93,643.987.57 SSSV SSSV NE TRSV-HAL, 6.62" x 3.813 X-nipple TSH-Blue Box x Pin 3.813
5,179.7 3,646.7 87.45 LOCATOR Mechanical locator (Collar 5.5" OD ( NOGO spaced out 3' Seal
assembly)
3.870
5,180.13,646.7 87.45 Seal Assembly Baker 192-47 Seal assembly, 4 1/2" Hyd 563 Box 3.870
Tubing Description
LEM
String Ma…
4 1/2
ID (in)
3.88
Top (ftKB)
5,171.0
Set Depth (ft…
5,384.0
Set Depth (TVD) (…
3,655.6
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
HYD 563
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com
Nominal
ID (in)
5,171.03,646.387.46 PACKER HR ZXP LTP w/HD L-80 & 10’ ext, 5-1/2” 14# Hyd 563 Pin Down 4.890
5,190.7 3,647.287.43SBE (Seal Bore
Extension)
190-47 SBE, 5-1/2” Hyd 563 Box x Pin 4.750
5,226.4 3,648.887.47 NIPPLE DB Camco 4.5 x 3.75” DB-6 Nipple to isolate both laterals (SN# 6918-
3)
3.750
5,249.2 3,649.8 87.51 DIVERTER T1 LEM, Pos #4, 4-1/2” BTC Box x Pin, above hook 3.710
5,252.33,649.987.51 DIVERTER T1 LEM, Pos #4, 4-1/2” BTC Box x Pin, below hook 3.688
MULTIPLE LATERALS, 3R-107, 2/19/2021 7:09:23 AM
Vertical schematic (actual)
LOWER LATERAL SLOTTED
LINER; 5,336.6-13,614.0
Annular Fluid - Flo-Pro Drilling
Mud; 5,192.0-13,614.5
INTERMEDIATE; 0.0-7,069.7
SEAL ASSY; 5,380.7
NIPPLE; 5,329.3
DIVERTER T1; 5,252.3
DIVERTER T1; 5,249.1
Tubing - Pup; 5,245.1
Tubing - Pup; 5,238.3
Tubing - Pup; 5,228.4
NIPPLE DB; 5,226.4
SBE (Seal Bore Extension);
5,190.7
Seal Assembly; 5,180.1
PACKER; 5,171.0
LOCATOR; 5,179.7
SSSV; 5,116.9
INJECTION; 5,092.9
Sliding Sleeve; 5,068.2
No-go nipple; 5,053.2
Profile Sub; 5,039.7
ACCESS ESP ISO-SLEEVE;
5,015.0
Annular Connection Port;
5,016.1
Motor Shroud; 5,009.7
Motor Centralizer; 5,008.2
Motor Shroud; 5,003.8
Motor Centralizer; 5,002.3
Motor Shroud; 4,997.8
Motor Centralizer; 4,996.3
Motor Shroud; 4,991.9
Motor Centralizer; 4,990.4
Motor Shroud; 4,985.9
Motor Centralizer; 4,984.4
Motor Shroud; 4,979.7
Motor Centralizer; 4,978.2
Motor Shroud; 4,973.7
Motor Centralizer; 4,972.2
Motor Shroud; 4,967.8
Sliding Sleeve; 4,963.8
GAUGE/PUMP SENSOR;
4,818.4
GAUGE/PUMP SENSOR;
4,807.3
GAS LIFT; 4,046.1
Annular Fluid - Diesel; 2,633.2-
5,337.2
GAS LIFT; 2,633.3
SURFACE; 39.9-2,253.3
Annular Fluid - Saltwater/Brine;
34.6-2,633.2
CONDUCTOR; 40.0-169.0
HANGER; 34.6
KUP PROD
KB-Grd (ft)
39.45
Rig Release Date
2/19/2020
3R-107
...
TD
Act Btm (ftKB)
13,614.0
Well Attributes
Field Name Wellbore API/UWI
500292366000
Wellbore Status
PROD
Max Angle & MD
Incl (°)
98.35
MD (ftKB)
8,717.71
WELLNAME WELLBORE
Annotation End DateH2S (ppm)
2
Date
8/4/2020
Comment
SSSV NE TRSV, HES SAP,6.6…
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com
Nominal
ID (in)
5,329.33,653.287.53 NIPPLE Camco 4.5" x 3.562" DB-6 for parent isolation (SN # 6199-1) 3.563
5,380.7 3,655.4 87.48 SEAL ASSY 190-47 GBH-22 Non Locating Seal Assembly, 4 1/2" STL Box 3.860
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°)Des Com Run Date ID (in)SN
5,015.03,639.687.47 ACCESS ESP
ISO-SLEEVE
AccessESP Iso-sleeve1/10/2021 3.000
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB)Make Model OD (in)Serv
Valve
Type
Latch
Ty pe
Port Size
(in)
TRO Run
(psi)Run Date Com
1 2,633.32,501.8Camco 1 GAS LIFT GLV BK 0.188 1,526.01/11/2021
2 4,046.13,482.0Camco 1 GAS LIFT OVBK 0.313 0.01/11/2021
3 5,092.93,642.9 HES Halliburt
on
5.6CHEM DCIV-
8000
800.08/8/2020 Max
rate
3GPM
, 700-
800
cracki
ng
press
MULTIPLE LATERALS, 3R-107, 2/19/2021 7:09:25 AM
Vertical schematic (actual)
LOWER LATERAL SLOTTED
LINER; 5,336.6-13,614.0
Annular Fluid - Flo-Pro Drilling
Mud; 5,192.0-13,614.5
INTERMEDIATE; 0.0-7,069.7
SEAL ASSY; 5,380.7
NIPPLE; 5,329.3
DIVERTER T1; 5,252.3
DIVERTER T1; 5,249.1
Tubing - Pup; 5,245.1
Tubing - Pup; 5,238.3
Tubing - Pup; 5,228.4
NIPPLE DB; 5,226.4
SBE (Seal Bore Extension);
5,190.7
Seal Assembly; 5,180.1
PACKER; 5,171.0
LOCATOR; 5,179.7
SSSV; 5,116.9
INJECTION; 5,092.9
Sliding Sleeve; 5,068.2
No-go nipple; 5,053.2
Profile Sub; 5,039.7
ACCESS ESP ISO-SLEEVE;
5,015.0
Annular Connection Port;
5,016.1
Motor Shroud; 5,009.7
Motor Centralizer; 5,008.2
Motor Shroud; 5,003.8
Motor Centralizer; 5,002.3
Motor Shroud; 4,997.8
Motor Centralizer; 4,996.3
Motor Shroud; 4,991.9
Motor Centralizer; 4,990.4
Motor Shroud; 4,985.9
Motor Centralizer; 4,984.4
Motor Shroud; 4,979.7
Motor Centralizer; 4,978.2
Motor Shroud; 4,973.7
Motor Centralizer; 4,972.2
Motor Shroud; 4,967.8
Sliding Sleeve; 4,963.8
GAUGE/PUMP SENSOR;
4,818.4
GAUGE/PUMP SENSOR;
4,807.3
GAS LIFT; 4,046.1
Annular Fluid - Diesel; 2,633.2-
5,337.2
GAS LIFT; 2,633.3
SURFACE; 39.9-2,253.3
Annular Fluid - Saltwater/Brine;
34.6-2,633.2
CONDUCTOR; 40.0-169.0
HANGER; 34.6
KUP PROD 3R-107
...
WELLNAME WELLBORE
Casing Strings
Casing Description
L1UPPER LATTER
SLOTTED LINER
OD (in)
4 1/2
ID (in)
3.96
Top (ftKB)
5,252.1
Set Depth (ftKB)
13,578.0
Set Depth (TVD)…
3,771.6
Wt/Len (l…
12.60
Grade
L-80
Top Thread
TXP (BTC)
Liner Details
Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com
Nominal ID
(in)
5,252.13,649.288.96 HANGER Baker "B-3" Flanged hook hanger, 4.5" X 7.63" Inside
casing
5.610
5,271.5 3,649.4 89.48 HANGER Baker "B-3" Flanged hook hanger, 4.5" X 7.63" 'BOW
@ 5271.74' MD
3.950
5,388.03,650.389.04 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(054009-010-21) M
3.958
6,079.5 3,670.289.82 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(054009-010-2) L
3.958
8,199.5 3,703.288.48SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(001893-001-19) K
3.958
8,809.63,664.5 94.00 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(001893-001-16) J
3.958
13,536.63,769.987.62 PBR (Polished
Bore
Receptacle)
4 1/2'' Drillable Packoff Bushing, BTC Box x Pin 2.370
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°)Des Com Run Date ID (in)SN
5,258.0 3,649.3 89.12 WHIPSTOCK 1/28/2020 5.000
MULTIPLE LATERALS, 3R-107L1, 2/22/2021 9:29:54 AM
Vertical schematic (actual)
L1UPPER LATTER SLOTTED
LINER; 5,252.1-13,578.0
WHIPSTOCK; 5,258.0
INTERMEDIATE; 0.0-7,069.7
DIVERTER T1; 5,252.3
DIVERTER T1; 5,249.1
Tubing - Pup; 5,245.1
Tubing - Pup; 5,238.3
Tubing - Pup; 5,228.4
NIPPLE DB; 5,226.4
Annular Fluid - Flo-Pro Drilling
Mud; 5,192.0-13,614.5
SBE (Seal Bore Extension);
5,190.7
Seal Assembly; 5,180.1
PACKER; 5,171.0
LOCATOR; 5,179.7
SSSV; 5,116.9
INJECTION; 5,092.9
Sliding Sleeve; 5,068.2
No-go nipple; 5,053.2
Profile Sub; 5,039.7
ACCESS ESP ISO-SLEEVE;
5,015.0
Annular Connection Port;
5,016.1
Motor Shroud; 5,009.7
Motor Centralizer; 5,008.2
Motor Shroud; 5,003.8
Motor Centralizer; 5,002.3
Motor Shroud; 4,997.8
Motor Centralizer; 4,996.3
Motor Shroud; 4,991.9
Motor Centralizer; 4,990.4
Motor Shroud; 4,985.9
Motor Centralizer; 4,984.4
Motor Shroud; 4,979.7
Motor Centralizer; 4,978.2
Motor Shroud; 4,973.7
Motor Centralizer; 4,972.2
Motor Shroud; 4,967.8
Sliding Sleeve; 4,963.8
GAUGE/PUMP SENSOR;
4,818.4
GAUGE/PUMP SENSOR;
4,807.3
GAS LIFT; 4,046.1
Annular Fluid - Diesel; 2,633.2-
5,337.2
GAS LIFT; 2,633.3
SURFACE; 39.9-2,253.3
Annular Fluid - Saltwater/Brine;
34.6-2,633.2
CONDUCTOR; 40.0-169.0
HANGER; 34.6
KUP PROD
KB-Grd (ft)
39.45
Rig Release Date
2/19/2020
3R-107L1
...
TD
Act Btm (ftKB)
13,610.0
Well Attributes
Field Name Wellbore API/UWI
500292366060
Wellbore Status
PROD
Max Angle & MD
Incl (°)
96.52
MD (ftKB)
8,622.33
WELLNAME WELLBORE
Annotation End DateH2S (ppm)
2
Date
8/4/2020
Comment
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Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: CORRECTED GLM's Service Types to Gas Lift and CHEM 1/26/2021 3R-107 pproven
Casing Strings
Casing Description
CONDUCTOR
OD (in)
20
ID (in)
18.50
Top (ftKB)
40.0
Set Depth (ftKB)
169.0
Set Depth (TVD)…
169.0
Wt/Len (l…
154.34
Grade
65
Top Thread
NA
Casing Description
SURFACE
OD (in)
10 3/4
ID (in)
9.95
Top (ftKB)
39.9
Set Depth (ftKB)
2,253.3
Set Depth (TVD)…
2,169.3
Wt/Len (l…
45.50
Grade
L-80
Top Thread
Hydril 563
Casing Description
INTERMEDIATE
OD (in)
7 5/8
ID (in)
6.88
Top (ftKB)
0.0
Set Depth (ftKB)
7,069.7
Set Depth (TVD)…
3,680.5
Wt/Len (l…
29.70
Grade
L80
Top Thread
H563
Casing Description
LOWER LATERAL
SLOTTED LINER
OD (in)
4 1/2
ID (in)
3.99
Top (ftKB)
5,336.6
Set Depth (ftKB)
13,614.0
Set Depth (TVD)…
3,788.7
Wt/Len (l…
12.60
Grade
L-80
Top Thread
Hyd 563
Liner Details
Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com
Nominal ID
(in)
5,356.33,654.4 87.51 NIPPLE- RS Baker 5.5" RS Nipple, 17# , L-80, Hyd 563 box x box 4.890
5,369.0 3,654.9 87.49 SBE (Seal Bore
Extension)
Baker 190-47 Sealbore Extension, 20' 5-1/2" L-80
Hyd 563 box X pin
4.750
8,286.23,723.286.71SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #24
3.980
8,306.3 3,724.4 86.60 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #23
3.980
8,987.83,675.093.13 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #22
3.980
9,007.8 3,674.0 92.29 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, HYD 563,
PN (H301-87-0488) #21
3.980
Tubing Strings
Tubing Description
ESP TUBING
COMPLETION
String Ma…
4 1/2
ID (in)
3.96
Top (ftKB)
34.6
Set Depth (ft…
5,206.7
Set Depth (TVD) (…
3,647.9
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
Hyd 563
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com
Nominal
ID (in)
34.6 34.6 0.00 HANGER VETCO/GE MB 242 13-3/8" x 4-1/2" tubing hanger (4.909 MCA
Box Up)
3.900
4,807.3 3,630.3 87.45 GAUGE/PUMP
SENSOR
HES ROC-150 Annulus DHG ser # ROC-005608-10 + Mandrel 3.919
4,818.4 3,630.8 87.51 GAUGE/PUMP
SENSOR
HES ROC-150 Discharge DHG ser # ROC-005612 + Mandrel 3.919
4,963.8 3,637.3 87.44 Sliding Sleeve 5-1/2" GVSSD, 4 1/2" Vamtop Box x 5 1/2", 23#, Vam FJL Box
(Closed 1/10/21)
3.913
4,967.8 3,637.5 87.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,972.2 3,637.7 87.44 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,973.7 3,637.7 87.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,978.2 3,637.9 87.44 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,979.7 3,638.087.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,984.4 3,638.2 87.44 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,985.93,638.387.44 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,990.4 3,638.5 87.45 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,991.93,638.687.45 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
4,996.3 3,638.7 87.45 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
4,997.83,638.887.45 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
5,002.3 3,639.0 87.45 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
5,003.8 3,639.1 87.45 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 3.893
5,008.2 3,639.3 87.46 Motor Centralizer Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box 3.893
5,009.7 3,639.3 87.46 Motor Shroud Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin 4.548
5,016.1 3,639.6 87.47 Annular
Connection Port
Ann Connection Port 5", 18# Vam FJL Box x 4 1/2" 12.6# Vamtop
Box SN#ACPTX18M0021
3.835
5,039.7 3,640.7 87.51 Profile Sub B-Profile, 4 1/2", 12.6#, L-80 Vamtop Box x Box 3.956
5,053.23,641.287.53 No-go nipple No-Go, 4 1/2" 12.6# Vamtop Box x 4 1/2" Hyd 563 Box 3.813
5,068.2 3,641.9 87.55 Sliding Sleeve Camco Sliding Sleeve CMU w/ 3.813 X-nipple, 4 1/2" Hyd 563
SN#2B (Closed 1/9/2021)
3.813
5,116.9 3,643.9 87.57 SSSV SSSV NE TRSV-HAL, 6.62" x 3.813 X-nipple TSH-Blue Box x Pin 3.813
5,179.7 3,646.7 87.45 LOCATOR Mechanical locator (Collar 5.5" OD ( NOGO spaced out 3' Seal
assembly)
3.870
5,180.1 3,646.7 87.45 Seal Assembly Baker 192-47 Seal assembly, 4 1/2" Hyd 563 Box 3.870
Tubing Description
LEM
String Ma…
4 1/2
ID (in)
3.88
Top (ftKB)
5,171.0
Set Depth (ft…
5,384.0
Set Depth (TVD) (…
3,655.6
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
HYD 563
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com
Nominal
ID (in)
5,171.0 3,646.3 87.46 PACKER HR ZXP LTP w/HD L-80 & 10’ ext, 5-1/2” 14# Hyd 563 Pin Down 4.890
5,190.7 3,647.287.43SBE (Seal Bore
Extension)
190-47 SBE, 5-1/2” Hyd 563 Box x Pin 4.750
5,226.4 3,648.8 87.47 NIPPLE DB Camco 4.5 x 3.75” DB-6 Nipple to isolate both laterals (SN# 6918-
3)
3.750
5,249.2 3,649.8 87.51 DIVERTER T1 LEM, Pos #4, 4-1/2” BTC Box x Pin, above hook 3.710
5,252.3 3,649.9 87.51 DIVERTER T1 LEM, Pos #4, 4-1/2” BTC Box x Pin, below hook 3.688
MULTIPLE LATERALS, 3R-107, 2/1/2021 5:28:09 PM
Vertical schematic (actual)
LOWER LATERAL SLOTTED
LINER; 5,336.6-13,614.0
Annular Fluid - Flo-Pro Drilling
Mud; 5,192.0-13,614.5
INTERMEDIATE; 0.0-7,069.7
SEAL ASSY; 5,380.7
NIPPLE; 5,329.3
DIVERTER T1; 5,252.3
DIVERTER T1; 5,249.1
Tubing - Pup; 5,245.1
Tubing - Pup; 5,238.3
Tubing - Pup; 5,228.4
NIPPLE DB; 5,226.4
SBE (Seal Bore Extension);
5,190.7
Seal Assembly; 5,180.1
PACKER; 5,171.0
LOCATOR; 5,179.7
SSSV; 5,116.9
INJECTION; 5,092.9
Sliding Sleeve; 5,068.2
No-go nipple; 5,053.2
Profile Sub; 5,039.7
ACCESS ESP ISO-SLEEVE;
5,015.0
Annular Connection Port;
5,016.1
Motor Shroud; 5,009.7
Motor Centralizer; 5,008.2
Motor Shroud; 5,003.8
Motor Centralizer; 5,002.3
Motor Shroud; 4,997.8
Motor Centralizer; 4,996.3
Motor Shroud; 4,991.9
Motor Centralizer; 4,990.4
Motor Shroud; 4,985.9
Motor Centralizer; 4,984.4
Motor Shroud; 4,979.7
Motor Centralizer; 4,978.2
Motor Shroud; 4,973.7
Motor Centralizer; 4,972.2
Motor Shroud; 4,967.8
Sliding Sleeve; 4,963.8
GAUGE/PUMP SENSOR;
4,818.4
GAUGE/PUMP SENSOR;
4,807.3
GAS LIFT; 4,046.1
Annular Fluid - Diesel; 2,633.2-
5,337.2
GAS LIFT; 2,633.3
SURFACE; 39.9-2,253.3
4 1/2" SLIP STOP, FLOW THRU
SUB, & SPARTEK GAUGES;
1,855.0
Annular Fluid - Saltwater/Brine;
34.6-2,633.2
CONDUCTOR; 40.0-169.0
HANGER; 34.6
KUP PROD
KB-Grd (ft)
39.45
Rig Release Date
2/19/2020
3R-107
...
TD
Act Btm (ftKB)
13,614.0
Well Attributes
Field Name Wellbore API/UWI
500292366000
Wellbore Status
PROD
Max Angle & MD
Incl (°)
98.35
MD (ftKB)
8,717.71
WELLNAME WELLBORE
Annotation End DateH2S (ppm)
2
Date
8/4/2020
Comment
SSSV NE TRSV, HES SAP,6.6…
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com
Nominal
ID (in)
5,329.3 3,653.2 87.53 NIPPLE Camco 4.5" x 3.562" DB-6 for parent isolation (SN # 6199-1) 3.563
5,380.7 3,655.4 87.48 SEAL ASSY 190-47 GBH-22 Non Locating Seal Assembly, 4 1/2" STL Box 3.860
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°)Des Com Run Date ID (in)SN
1,855.01,815.7 23.40 4 1/2" SLIP
STOP, FLOW
THRU SUB, &
SPARTEK
GAUGES
4 1/2" SLIP STOP, FLOW THRU SUB,
SHOCK ABSORBER, AND SPARTEK
GAUGES (86" OAL)
1/14/2021 0.000
5,015.0 3,639.6 87.47 ACCESS ESP
ISO-SLEEVE
AccessESP Iso-sleeve 1/10/2021 3.000
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB)Make Model OD (in)Serv
Valve
Type
Latch
Ty pe
Port Size
(in)
TRO Run
(psi)Run Date Com
1 2,633.3 2,501.8 Camco 1 GAS LIFT GLV BK 0.188 1,526.0 1/11/2021
2 4,046.13,482.0Camco 1 GAS LIFT OVBK 0.313 0.01/11/2021
3 5,092.9 3,642.9 HES Halliburt
on
5.6CHEM DCIV-
8000
800.08/8/2020 Max
rate
3GPM
, 700-
800
cracki
ng
press
MULTIPLE LATERALS, 3R-107, 2/1/2021 5:28:11 PM
Vertical schematic (actual)
LOWER LATERAL SLOTTED
LINER; 5,336.6-13,614.0
Annular Fluid - Flo-Pro Drilling
Mud; 5,192.0-13,614.5
INTERMEDIATE; 0.0-7,069.7
SEAL ASSY; 5,380.7
NIPPLE; 5,329.3
DIVERTER T1; 5,252.3
DIVERTER T1; 5,249.1
Tubing - Pup; 5,245.1
Tubing - Pup; 5,238.3
Tubing - Pup; 5,228.4
NIPPLE DB; 5,226.4
SBE (Seal Bore Extension);
5,190.7
Seal Assembly; 5,180.1
PACKER; 5,171.0
LOCATOR; 5,179.7
SSSV; 5,116.9
INJECTION; 5,092.9
Sliding Sleeve; 5,068.2
No-go nipple; 5,053.2
Profile Sub; 5,039.7
ACCESS ESP ISO-SLEEVE;
5,015.0
Annular Connection Port;
5,016.1
Motor Shroud; 5,009.7
Motor Centralizer; 5,008.2
Motor Shroud; 5,003.8
Motor Centralizer; 5,002.3
Motor Shroud; 4,997.8
Motor Centralizer; 4,996.3
Motor Shroud; 4,991.9
Motor Centralizer; 4,990.4
Motor Shroud; 4,985.9
Motor Centralizer; 4,984.4
Motor Shroud; 4,979.7
Motor Centralizer; 4,978.2
Motor Shroud; 4,973.7
Motor Centralizer; 4,972.2
Motor Shroud; 4,967.8
Sliding Sleeve; 4,963.8
GAUGE/PUMP SENSOR;
4,818.4
GAUGE/PUMP SENSOR;
4,807.3
GAS LIFT; 4,046.1
Annular Fluid - Diesel; 2,633.2-
5,337.2
GAS LIFT; 2,633.3
SURFACE; 39.9-2,253.3
4 1/2" SLIP STOP, FLOW THRU
SUB, & SPARTEK GAUGES;
1,855.0
Annular Fluid - Saltwater/Brine;
34.6-2,633.2
CONDUCTOR; 40.0-169.0
HANGER; 34.6
KUP PROD 3R-107
...
WELLNAME WELLBORE
Casing Strings
Casing Description
L1UPPER LATTER
SLOTTED LINER
OD (in)
4 1/2
ID (in)
3.96
Top (ftKB)
5,252.1
Set Depth (ftKB)
13,578.0
Set Depth (TVD)…
3,771.6
Wt/Len (l…
12.60
Grade
L-80
Top Thread
TXP (BTC)
Liner Details
Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com
Nominal ID
(in)
5,252.1 3,649.2 88.96 HANGER Baker "B-3" Flanged hook hanger, 4.5" X 7.63" Inside
casing
5.610
5,271.5 3,649.4 89.48 HANGER Baker "B-3" Flanged hook hanger, 4.5" X 7.63" 'BOW
@ 5271.74' MD
3.950
5,388.0 3,650.3 89.04 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(054009-010-21) M
3.958
6,079.5 3,670.2 89.82 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(054009-010-2) L
3.958
8,199.5 3,703.2 88.48 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(001893-001-19) K
3.958
8,809.6 3,664.5 94.00 SWELL
PACKER
PACKER,SWELL, 4 1/2 X 6.125", BAKER, TXP, SN
(001893-001-16) J
3.958
13,536.6 3,769.9 87.62 PBR (Polished
Bore
Receptacle)
4 1/2'' Drillable Packoff Bushing, BTC Box x Pin 2.370
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°)Des Com Run Date ID (in)SN
5,258.0 3,649.3 89.12 WHIPSTOCK 1/28/2020 5.000
MULTIPLE LATERALS, 3R-107L1, 2/1/2021 5:28:14 PM
Vertical schematic (actual)
L1UPPER LATTER SLOTTED
LINER; 5,252.1-13,578.0
WHIPSTOCK; 5,258.0
INTERMEDIATE; 0.0-7,069.7
DIVERTER T1; 5,252.3
DIVERTER T1; 5,249.1
Tubing - Pup; 5,245.1
Tubing - Pup; 5,238.3
Tubing - Pup; 5,228.4
NIPPLE DB; 5,226.4
Annular Fluid - Flo-Pro Drilling
Mud; 5,192.0-13,614.5
SBE (Seal Bore Extension);
5,190.7
Seal Assembly; 5,180.1
PACKER; 5,171.0
LOCATOR; 5,179.7
SSSV; 5,116.9
INJECTION; 5,092.9
Sliding Sleeve; 5,068.2
No-go nipple; 5,053.2
Profile Sub; 5,039.7
ACCESS ESP ISO-SLEEVE;
5,015.0
Annular Connection Port;
5,016.1
Motor Shroud; 5,009.7
Motor Centralizer; 5,008.2
Motor Shroud; 5,003.8
Motor Centralizer; 5,002.3
Motor Shroud; 4,997.8
Motor Centralizer; 4,996.3
Motor Shroud; 4,991.9
Motor Centralizer; 4,990.4
Motor Shroud; 4,985.9
Motor Centralizer; 4,984.4
Motor Shroud; 4,979.7
Motor Centralizer; 4,978.2
Motor Shroud; 4,973.7
Motor Centralizer; 4,972.2
Motor Shroud; 4,967.8
Sliding Sleeve; 4,963.8
GAUGE/PUMP SENSOR;
4,818.4
GAUGE/PUMP SENSOR;
4,807.3
GAS LIFT; 4,046.1
Annular Fluid - Diesel; 2,633.2-
5,337.2
GAS LIFT; 2,633.3
SURFACE; 39.9-2,253.3
4 1/2" SLIP STOP, FLOW THRU
SUB, & SPARTEK GAUGES;
1,855.0
Annular Fluid - Saltwater/Brine;
34.6-2,633.2
CONDUCTOR; 40.0-169.0
HANGER; 34.6
KUP PROD
KB-Grd (ft)
39.45
Rig Release Date
2/19/2020
3R-107L1
...
TD
Act Btm (ftKB)
13,610.0
Well Attributes
Field Name Wellbore API/UWI
500292366060
Wellbore Status
PROD
Max Angle & MD
Incl (°)
96.52
MD (ftKB)
8,622.33
WELLNAME WELLBORE
Annotation End DateH2S (ppm)
2
Date
8/4/2020
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ANCHORAGE, ALASKA 99510-0360
Oct 13, 2020
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner Jessie Chmielowski:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of
these wells was found to have a void in the conductor. These voids were filled with cement if
needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As
per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that
the treatments took place and meets the requirements of form 10-404, Report of Sundry
Operations. The attached spread sheet presents the well name, top of cement depth prior to filling
and volumes used on each conductor.
Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions.
Sincerely,
Roger Mouser
ConocoPhillips Well Integrity Field Supervisor
Roger Mouser Digitally signed by Roger Mouser
Date: 2020.10.13 13:10:42 -08'00'
By Samantha Carlisle at 1:21 pm, Oct 13, 2020
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad
Well Name API # PTD #
Initial top of
cement
Vol. of cement
pumped
Final top of
cement
Cement top off
date
Corrosion
inhibitor
Corrosion
inhibitor/
sealant date
ft bbls ft gal
2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020
2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020
2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020
2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020
3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020
3K-34 50029228790000 1980770 14"
Conductor extension 14" 4/27/2019 9 9/27/2020
3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020
3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020
3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020
3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020
3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020
3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020
3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020
3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020
3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020
3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020
3R-112 50029236370000 2190850 36" 0.60
14"8/14/2020 7 9/26/2020
3S-611 50103207740000 2181030 11' 10" 2.50
8"6/30/2019 2.5 9/27/2020
3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020
3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg ���� ��l �l DATE: September 23, 2020
P. I. Supervisor
FROM: Brian Bixby SUBJECT: SVS Testing / RETEST
Petroleum Inspector KRU 3R-107
Conoco Phillips Alaska
PTD 2191810
9/23/2020: 1 traveled to KRU 3R-107 to witness another retest of the KRU 3R-107
safety valve system (SVS). The SSSV during previous tests on 8/29/2020 and 9/3/2020
failed (primary reason for the tests); other components passed. CPAI Pad Operator
Joey Foshaug performed the test following a revised procedure allowing for longer
bleed down prior to commencing the SSSV differential pressure test. Today's pre-test
conditions:
Tubing/IA/OA Pressures = 192/190/254 psi
Separator Pressure = 80 psi ,
ESP Pressures: Intake = 1183 psi; Discharge = 1384 psi
SVS Pilot: Set = 80 psi; Trip = 68 psi
Sequence of Events:
10:16 am —Summit shutdown the ESP
10:21 — Trip pilot with 235 psi below SSV. With SSV closed and wing valve closed they
bled the void area to ZERO thru the tree cap to verify the SSV holds differential
pressure (SSV - Pass)
10:27 — With Manual IA valve closed and Hydraulic IA valve closed they pressured up
the void area between the valves to 600 psi to verify IA SSV holds differential pressure
(IA SSV - Pass). ✓
10:33 — Leave IA SSV closed to build pressure on IA for differential to test the SSSV.
Pump Intake 1215 psi; Pump Discharge 1430 psi; IA at surface 253 psi.
11:03 — Pump Intake 1236 psi; Pump Discharge 1525 psi; IA at surface 354 psi.
11:33 — Pump Intake 1247 psi; Pump Discharge 1565 psi; IA at surface 395 psi.'
12:03 — Pump Intake 1255 psi; Pump Discharge 1671 psi; IA at surface 429 psi. '
12:08 — Bleed hydraulic pressure to SSSV to allow it to clow; bleed pressure down the
flowline for 7 minutes to get to flowline pressure of 148 psi. Leave open to the flowline
for 2 hours as per their procedure. Recorded pressures every 30 minutes: -
2020-0923 SVS_KRU_3R-I07_bb.docx
Page 1 of 2
Pump IDischargIA at Surface Tubing (psi)
Intake e si
Time Pump si 148 425
1570si 157 425
12:15 g63 1572 425
954 1574 151 425
12.45 952 146
13:15 951 1576 166 425
13:45 1577
14:15 958 reading every
m and monitor for 30 minutes — taking
14:15 — Block in IA SSV at 1415 p IA at Surface si
—to verif the SSSV was closedls h hoedinslDP:
10 minutes si Pum D 151
Time Pum Intake 1578
974 190
14:25 995 1580 208
14:35 1581
1115
14:45
Notes/Observations:
were used for the SVS low pressure pilot
Test gauges with d IA Prcalibrations e readings_
test and tubing and IA p as breakout (as
he IA op and the IA pressure built 57 si on the
t en to the flowline fon 2a hours to allow °r g tes.
After leaving the IA was blocked ► in 30 menu
per their procedure), si on the Pump Intake pressure gauge)
surface gauge (157 p building
_ I thought that waiting 90
minutes was long enough as the IA was slowly
pressure.
I/ntial pressure for the SSSV test. I like to see over 50
There was 281 psi differe
si for SSSV testing but that is what we had. pressures with
p retest
_ The Pump
Intake Pressure was only 68 psi lower than the p
the pump running. not holding a
say the SSSV is fully closed °double check tleaking
he SSSV by just et
_ I cannot honestly ). Also, there is no way must apply pressure to the IA to g
pressure differential).
opening
to see what is below because they
the SSSV to openressure.
Conc_lu_ s_ion: I put on my RBD
MS test report that the SSSV failed to hold differential p
2020-0923_SVS —R — R 107 bb.docx
i
i
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23660-60-00Well Name/No. KUPARUK RIV UNIT 3R-107L1Completion Status1-OILCompletion Date2/19/2020Permit to Drill2191810Operator ConocoPhillips Alaska, Inc.MD13610TVD3773Current Status1-OIL5/18/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/Res/AZM ResNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC3/24/2020 Electronic File: 3R-107L1 EOW - NAD27.pdf32252EDDigital DataC3/24/2020 Electronic File: 3R-107L1 EOW - NAD27.txt32252EDDigital DataC3/24/2020 Electronic File: 3R-107L1 EOW - NAD83.pdf32252EDDigital DataC3/24/2020 Electronic File: 3R-107L1 EOW - NAD83.txt32252EDDigital DataC5/8/2020276 13610 Electronic Data Set, Filename: 3R-107L1 Drilling Mechanics Depth Data.las33008EDDigital DataC5/8/2020270 2258 Electronic Data Set, Filename: 3R-107L1 OTK Memory 13.5inch Section Drilling Data.las33008EDDigital DataC5/8/20205398 13610 Electronic Data Set, Filename: 3R-107L1 OTK Memory 6.75inch Section Drilling Data.las33008EDDigital DataC5/8/20202258 5398 Electronic Data Set, Filename: 3R-107L1 OTK Memory 9.875inch Section Drilling Data.las33008EDDigital DataC5/8/2020270 13610 Electronic Data Set, Filename: 3R-107L1 OTK Memory Composite Drilling Data.las33008EDDigital DataC5/8/2020269 2258 Electronic Data Set, Filename: 3R-107L1 13.5 Inch Section OTK Realtime FE Drilling Data.las33008EDDigital DataC5/8/20205272 13610 Electronic Data Set, Filename: 3R-107L1 6.75 Inch Section OTK Realtime FE Drilling Data.las33008EDDigital DataC5/8/20202258 5272 Electronic Data Set, Filename: 3R-107L1 9.875 Inch Section OTK Realtime FE Drilling Data.las33008EDDigital DataC5/8/2020269 13610 Electronic Data Set, Filename: 3R-107L1 Composite OTK Realtime FE Drilling Data.las33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 Drilling Mechanics Depth Log.cgm33008EDDigital DataMonday, May 18, 2020AOGCCPage 1 of 43R-107L1 OTK ,Memory Composite Drilling Data.las
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23660-60-00Well Name/No. KUPARUK RIV UNIT 3R-107L1Completion Status1-OILCompletion Date2/19/2020Permit to Drill2191810Operator ConocoPhillips Alaska, Inc.MD13610TVD3773Current Status1-OIL5/18/2020UICNoC5/8/2020 Electronic File: 3R-107L1 OTK 2MD Memory Log.cgm33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 2MD Memory Log.cgm.meta33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 2TVD Memory Log.cgm33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 5MD Memory Log.cgm33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 5TVD Memory Log.cgm33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 2MD Realtime Log.cgm33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 2TVD Realtime Log.cgm33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 5MD Realtime Log.cgm33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 5TVD Realtime Log.cgm33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 Drilling Mechanics Time Log Run 06.cgm33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 13.5 Inch Section OTK Memory Drilling Data.dlis33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 6.75 Inch Section OTK Memory Drilling Data.dlis33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 9.875 Inch Section OTK Memory Drilling Data.dlis33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK Memory Drilling Data.dlis33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 Composite OTK Realtime FE Drilling Data.dlis33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK Realtime 13.5 Inch Section Drilling FE Data.dlis33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK Realtime 6.75 Inch Section Drilling FE Data.dls33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK Realtime 9.875 Inch Section Drilling FE Data.dlis33008EDDigital DataMonday, May 18, 2020AOGCCPage 2 of 4
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23660-60-00Well Name/No. KUPARUK RIV UNIT 3R-107L1Completion Status1-OILCompletion Date2/19/2020Permit to Drill2191810Operator ConocoPhillips Alaska, Inc.MD13610TVD3773Current Status1-OIL5/18/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDC5/8/2020 Electronic File: 3R-107L1_BH_EOW Letter.docx33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 Drilling Mechanics Depth Log.pdf33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 2MD Memory Log.pdf33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 2TVD Memory Log.pdf33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 5MD Memory Log.pdf33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 5TVD Memory Log.pdf33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 2MD Realtime Log.pdf33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 2TVD Realtime Log.pdf33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 5MD Realtime Log.pdf33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1 OTK 5TVD Realtime Log.pdf33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1_Drilling Mechanics Time Log_Run6.pdf33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1_Final Surveys.pdf33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1_Final Surveys.txt33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1_Final Surveys.xlsx33008EDDigital DataC5/8/2020 Electronic File: 3R-107L1_Final Survey_DDO.xls33008EDDigital Data0 0 2191810 KUPARUK RIV UNIT 3R-107L1 LOG HEADERS33008LogLog Header ScansMonday, May 18, 2020AOGCCPage 3 of 4
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23660-60-00Well Name/No. KUPARUK RIV UNIT 3R-107L1Completion Status1-OILCompletion Date2/19/2020Permit to Drill2191810Operator ConocoPhillips Alaska, Inc.MD13610TVD3773Current Status1-OIL5/18/2020UICNoCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date: 2/19/2020Release Date:12/11/2019Monday, May 18, 2020AOGCCPage 4 of 4M.Guhl5/18/2020
Transmittal #1273 Detail
Date: 5/8/2020
To (External Party):From (CPAI Contact):
Email*: abby.bell@alaska.gov Email*: richard.e.elgarico@conocophillips.com
First
Name*:Abby First Name*: Ricky
Last Name*: Bell Last Name*: Elgarico
Phone
Number:(907) 79 Phone Number: (907) 265-6580
Company: AOGCC Company: ConocoPhillips
Address: 333 West 7th Ave.Address: 700 G Street
City: Anchorage City: Anchorage
State: AK State: AK
Zip Code: 99501 Zip Code: 99501
Transmittal Info
Sent Via: FTP Tracking #:
Justification:
Data Detail
Quantity*:Description*:Type*:
1 CD4-215l1 LWD Data - CGM,
LAS, PDF, TAPESCAN, TIF Digital
1 CD5-23L1 LWD Data - CGM, LAS,
PDF, TAPESCAN, TIF Digital
1 CD5-23L1-01 LWD Data - CGM,
LAS, PDF, TAPESCAN, TIF Digital
1 3R-105 LWD Data - CGM, LAS,
PDF, TAPESCAN, TIF Digital
1 3R-105L1 LWD Data - CGM, LAS,
PDF, TAPESCAN, TIF Digital
1 3R-107 LWD Data - CGM, LAS,
PDF, TAPESCAN, TIF Digital
1 3R-107L1 LWD Data - CGM, LAS,
PDF, TAPESCAN, TIF Digital
1 CD4-214L1 LWD Data - CGM,
LAS, PDF, TAPESCAN, TIF Digital
1 3O-04L1 LWD Data - CGM, LAS,
PDF, TAPESCAN, TIF Digital
1 3O-04L1-01 LWD Data - CGM,
LAS, PDF, TAPESCAN, TIF Digital
Received by the AOGCC on 05/08/2020
PTD: 2191810
E-Set:33008
1 3O-04L1PB1 LWD Data - CGM,
LAS, PDF, TAPESCAN, TIF
Digital
Attachments:
Received By:
___________________________
Signature:
___________________________
Date:
_________________
Approver:
___________________________
Signature:
___________________________
Date:
_________________
Abby Bell Abby Bell 05/08/2020
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: ____________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:9. Ref Elevations: KB:49.2 17. Field / Pool(s):
GL:9.8 BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20 H-40 169
10 3/4 L-80 2169
7 5/8 L-80 3680
4 1/2 L-80 3772
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press:Calculated Gas-MCF:Oil Gravity - API (corr):
Press. 24-Hour Rate
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Gas
WAG
ConocoPhillips Alaska, Inc 2/19/2020 219-181
P.O. Box 100360 Anchorage, AK 99510-0360 1/29/2020 50-029-23660-60-00
1730' FNL, 2926' FEL, Sec 9, T13N, R9E, UM 2/2/2020 KRU 3R-107L1
623' FNL, 1342' FEL, Sec 9, T13N, R9E, UM Kuparuk River Field/West Sak Oil Pool
1765/1732
2013' FNL, 3179' FEL, Sec 11, T13N, R9E, UM 13578/3772 ADL 355023
520660 6031633
13610/3773 931933000
5258/3650
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,
caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation
record. Acronyms may be used. Attach a separate page if necessary
CASING, LINER AND CEMENTING RECORD
522991 6032754
530966 6031490
5117/3644
CASING WT. PER
FT.GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD
AMOUNT
PULLEDTOP BOTTOM TOP
154.3 40 169 40 42 Existing cement to surface
45.5 40 2253 40 13 1/2 875sx 11.0ppg Class G
29 1 8 Cl G
SLOTTED LINER
29.7 40 7070 40 9 7/8 1057sx 15.8ppg Class G
12.6 5252 13578 3649 6 3/4
TUBING RECORD
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
4 1/2 5207 n/a
SLOTTED LINER@
6085-13578 MD and 3670-3772 TVD….2/13/2020 ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Per 20 AAC 25.283 (i)(2) attach electronic information
PRODUCTION TEST
3/21/2020 ESP
Date of Test: Oil-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio:
2648 402 1 169
3/28/2020 10hrs 1140 140 0
96 beans
(Full Open)
Sr Pet Eng Sr Pet Geo Sr Res Eng
GR/Res/AZM Res
152
Flow Tubing Oil-Bbl:Water-Bbl:
228 228
WINJ
SPLUGOther Abandoned Suspended
Stratigraphic Test
No
No
(attached) No
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By Samantha Carlisle at 10:06 am, Apr 08, 2020
DSR-4/8/2020DLB 04/13/2020
RBDMS HEW 4/14/2020
1908
623 1342'
2013 3179
615
589
Completion Date
2/19/2020
HEW
3180
16.9 MG
GVTL 5/5/20
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
Top of Productive Interval
1706 1677
2019 1964
3066 2871
3445 3154
UG-A 3624 3269
N 3929 3431
4504 3608
TD 13610 3773
West Sak D
31. List of Attachments:Daily Operations Summary, Definitive Survey, Cement Report, Schematic
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Mark Vanderhorst Contact Name:Matt Nagel
Kuparuk Drilling Manager Contact Email:Matt.B.Nagel@cop.com
Authorized Contact Phone:263-4747
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
28. CORE DATA Yes No
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS
NAME Well tested? Yes No
Permafrost - Top If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
Permafrost - Base
Formation @TPI -West Sak D
T-3
K-15
UG-C
UG-B
WS
Formation at total depth:
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
Authorized Name:
Authorized Title:
Signature w/Date:
INSTRUCTIONS
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.
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.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
TPI (Top of Producing Interval).
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
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.
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
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.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment, whichever occurs first.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
No
No Sidewall Cores:
Yes NoNoSidewall Cores:
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
219181
32 25 2
Letter of Transmittal
Baker Hughes g Date:
March 24, 2020
To: From:
Abby Bell Michael Soper
AOGCC Baker Hughes
333 West 7th Ave, Suite 100795 East 94th Avenue
Anchorage, Alaska 99501 ! Anchorage, Alaska 99515
i
Please find enclosed the directional survey data for the following well(s):
3R-107
3R -107L1
RECEIVED
MAR 2 4 2020
AOGGG
(2) Total prints
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Michael Soper
Baker Hughes
Applications Engineer
Michael.SooerCa)bakerhuehes.com
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THE STATE
"ALASKA
GOVERNOR MIKE DUNLEAVY
Chip Alvord
Alaska Drilling Manager
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
Re: Kuparuk River Field, West Sak Oil Pool, KRU 3R -107L1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-181
Surface Location: 1730' FNL, 2926' FEL, SEC. 9, T13N, R9E, UM
Bottomhole Location: 1915' FNL, 3178' FEL, SEC. 11, T13N, R9E, UM
Dear Mr. Alvord:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Enclosed is the approved application for the permit to redrill the above referenced service well.
The permit is for a new wellbore segment of existing well Permit No. 219-180, API No. 50-029-23660-
00-00. 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,
J r M. Price
hair
DATED this 11 day of December, 2019.
*' y t
''
NOV 21 2010
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
1 a. Type of Wor :
Drill ❑ Lateral ❑✓
Redrill ❑ Reentry ❑
Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑
Stratigraphic Test ❑ Development - Oil ❑� Service - Winj ❑ Single Zone ❑r
Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
1 c. Specify if well is proposed for:
Coalbed Gas ❑ Gas Hydrates ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
5. Bond: Blanket ❑Z Single Well ❑
Bond No. 59-52-180
11. Well Name and Number:
KRU 3R -107L1
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
6. Proposed Depth:
MD 13701' TVD: 3776'
12. Field/Pool(s):
Kuparak River Field
West Sak Oil Pool
4a. Location of Well (Governmental Section):
Surface: 1730' FNL & 2926' FEL, Sec 9, T13N, R9E, UM
Top of Productive Horizon:
587' FNL & 1273' FEL, Sec 9, T13N, R9E, UM
Total Depth:
1915' FNL& 3178' FEL, Sec 11, T13N, R9E, UW --i
7. Property Designation:
ADL355023
8. DNR Approval Number:
931933000
13. Approximate Spud Date:
12/25/2019
9. Acres in Property:
3255
14. Distance to Nearest Property:
538'toADL388235
4b. Location of Well (State Base Plane Coordinates - NAD 27):
Surface: x- 520660.18 y- 6,031,633.15 Zone- 4
10. KB Elevation above MSL (ft): 48.9'
GL / BF Elevation above MSL (ft): 9.8'
15. Distance to Nearest Well Open
to Same Pool: 1018' to 3R-106
16. Deviated wells: Kickoff depth: 5,095 feet
Maximum Hole Angle: 93.61 degrees
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Downhole: 1,709 Surface: 1,332
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)
42" 20" 94# H-40 Welded 168'
Surf Surf 168' 168' Existing, cement to surface
13-1/2" 10-3/4" 45.5# L-80 HYD563 2253'
Surf Surf 2253' 2171' 861 sx 11.0 ppg, 283 sx 15.8 ppg
9-7/8" 7-5/8" 29.7# L-80 HYD563 5836'
Surf Surf 5836' 3700' 763 sx Class G 15.8 ppg
6-3/4" 4-1/2" 12.6# L-80 TXP 8606'
5095' 3652' 13701' 3776' N/A
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured):
Casing Length Size Cement Volume MD TVD
Perforation Depth MD (ft): Perforation Depth TVD (ft):
Hydraulic Fracture planned? Yes❑ No ❑r
20. Attachments: Property Plat ❑ BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch e Seabed Report B Drilling Fluid Program e 20 AAC 25.050 requirements 8✓
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: Madeline Woodard
Authorized Name: Chip Alvord Contact Email: madeline.e.woodard co .COM
Authorized Title: Alaska Drilling Manager !� Contact Phone: 907-265-6086
-`� k Date: tt' Zvr 2 `� ( 1
Authorized Signature: e� n
Commission Use Only
Permit to Drill Q
p
Number: i,I -k " 191
API Number:
50- OZc{ (`d - 60 -ion
Permit Approval
Date:
See cover letter for other
requirements.
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, as hydrates, or gas contained in shales:
Other:ftS f fo 3So0 Samples req'd: Yes ❑ No[ Mud log req'd: Yes❑ Noy'
F 2S measures: Yes PRI, No❑ Directional svy req'd: Yes Yv No ❑
�`I!7 v62i- /-tf�lvr /21 ' �f5.t /-V .2.J O 62 'A
11ro �a / 5 5116/CC f f o fie Spatingb exception req'd: Yes ElNoN Inclination -only svy req'd: Yes ElNo
PT ✓ Post initial injection MIT req'd: Yes ❑ No
GL�achtd �o�d � fia r-�S o{ /`ljp�ro ✓rc �
�`t'/Qtlh9 to �hc !N'C// cin-,pl�fio r, r
J APPROVED BY
Approvedby: COMMISSIONER THE COMMISSION Date:Submit Form and
.,�„� �.. �.� � � �� .., �..� � ....., '......... ... ....... .... _, ............ .. ..... ..... .. .. �.. �......... r.... _.. ...._ _.........tai r,uauunonm ni Nny.ayc
�T� ,Z 0 R -1 G I N A L
KRU 3R-107L1(PTD 219-181)
Conditions of Approval
Based on the location of 311-1071-1, that is, a surface location that is 660 feet or less of a coast line (20
AAC 25.265(d)(2)(f)) a SSSV is required if this well is capable of unassisted flow of hydrocarbons to
surface (20 AAC 25.265(d)(1)). If a no -flow test to demonstrate the well is not capable of unassisted flow
of hydrocarbons to surface is conducted and the well passes the test, a SSSV will not be required (20
AAC 25.265(k)). The following guidelines apply.
1. Reference AOGCC Guidance Bulletin 10-004
2. Up to a 30 day production period is acceptable prior to the no -flow test for this well
3. The no -flow test must be conducted within 30 days
4. A procedure must be submitted for AOGCC approval at least two weeks in advance.
5. CPAI must demonstrate that offset injectors have not been shut in prior to the no -flow
test by providing a list of offset injectors with status and injection history for the past 6
months.
Should conditions change, such as increased reservoir pressure due to water injection, an updated no -
flow test may be required
If the well does not pass a no -flow test, and CPAI proposes to use the deep-set operable valve as a SSSV,
the following apply:
I. Provide the control process flow or MID for the SVS system. Specifically for the closing
of the actuated valve on the IA prior to the recombination of the gas with produced
fluids
2. Demonstrate the equivalence of the proposed deep-set operable valve to a SSSV.
3. The deep set operable valve would require a performance test every 6 months like a
typical SSSV.
4. The SSSV or deep set operable valve would be required during ESP operation as well as
gas lift operation.
5. If equivalence between the deep set operable valve and a SSSV cannot be demonstrated
prior to running the completion or in a subsequent performance test(every 6 months),
then a SSSV meeting regulations would be required for the well to remain on
production.
Application for Permit to Drill, Well 3R -107L1
Saved: 20 -Nov -19
November 20, 2019
Alaska Oil and Gas Conservation Commission
333 West 711 Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill Well 3R -107L1, a West Sak D Sand Producer
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots dual -lateral producer well from the
3R pad. The expected spud date for this well is December 25, 2019. It is planned to use rig Doyon 142.
3R-107 is planned to be a horizontal dual -lateral producer in the West Sak D sand upper and lower lobes. The
mainbore/lower lateral (separate PTD application) will consist of a 13-1/2" surface section cased with 10-3/4" casing to
(2,253' MD / 2,171' TVD, a 9-7/8" intermediate section cased with 7-5/8" casing to ±5,836'MD / 3,700' TVD, and the
lower lateral will be drilled with a 6-3/4" bit in the West Sak D sand lower lobe to +/- 13,684' MD / 3,801' TVD and
lined with a 4-1/2" slotted liner. The subsequent production lateral (this PTD application) will be drilled with a 6-3/4" bit
in the West Sak D sand upper lobe and lined with 4-1/2" slotted liner to 13,701' MD / 3,776' TVD. The upper
completion will be run with 4-1/2" tubing.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent
information attached to this application includes the following:
Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a).
Pressure information as required by 20 ACC 25.035 (d) (2).
Casing and cementing program.
A drilling fluids program summary.
A proposed drilling program.
Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b).
A proposed completion diagram.
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20
ACC 25.035 (a) and (b).
2. A description of the drilling fluids handling system.
3. Diagram of riser set up.
If you have any questions or require further information, please contact Madeline Woodard at 265-6086
(madeline.e.woodard@cop.com) or Chip Alvord at 265-6120.
Sincerely,
Chip Alvord
Drilling Manager
Application for Permit to Drill DocumentLVV-,,l W
Kuparuk Well 3R -107L1
Well Name
Requirements of 20 AAC 25.005 (f)
The well for which this application is submitted will be designated as KRU 3R -107L1
Location Summary
Requirements of 20 AAC 25.005(c)(2)
An application for a Permit to Drill must be accompanied b), each of the following items. except f r an item already on file with the commission and
identified in the application.
(2) a plat identifying the properav, and the property's owners and showing
(1) the coordinates of the proposed location of the well at the surface, at the top of each ohjective for•ination, and at total depth, referenced to
governmental section lines.
("B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the
National Geodetic Survey in the National Oceanic and Atrnospher•ic ,4dniiiiisiration:
(C) the proposed depth of the well at the top of each objective formation and at total depth:
Location at Surface 1730' FNL & 2926' FEL, Sec 09, TUN, R9E, UM
NGS Coordinates
Northings: 6,031,633.15' Eastings: 520,660.18'
RKB Elevation
48.9' AMSL
Pad Elevation
9.8' AMSL
Location at Top of
Productive Interval
West Sak D Sand
587' FNL & 1273' FEL, Sec 09, T13N, R9E, UM
NGS Coordinates
Northings: 6,032,779.94' Eastings: 522,306.25'
Measured Depth, RKB: 4,607'
Total Vertical Depth, RKB: 3,612'
Total Vertical Depth, SS: 3,563'
Location at Total Depth 1915' FNL & 3178' FEL, Sec 11, TUN, R9E, UM
NGS Coordinates
Northings: 6,031,483.64' Eastings: 530,967.98'
Measured Depth, RKB: 13,701'
Total Vertical Depth, RKB: 3,776'
Total Vertical Depth, SS: 3,727'
and
(D) other information required by 2014C 25.050(b):
Requirements of 20 AAC 25.050(h)
{f a well is to he intentionally deviated, the application for a Permit to Drill ("Form 10-401) must
(l) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent ii ellbores within 200 feet of artyportion of
the proposed well.
Please see Attachment: Directional Plan
And (2) for all wells within 200 feet of the proposed wellbore
(4) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each
named operator has been furnished a copj of7he application by certified mail; or
(B) state that the applicant is the only affected owner.
The Applicant is the only affected owner.
Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
In application for• a Permit to Drill must be accompanied by each of the following items, except for an hent already on file with the commission and
identified in the application:
(3) a diagram and descrtption of the hlowout prevention equipntertt (BOPS) as required by, 20 4 4C 25 035, 20 AAC 25.030, or 20 AAC 25.037, ata
applicable:
Please reference BOP schematics on file for Doyon 142 and attachment.
Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
An application fora Permit to Drill must be accompanied by each of the following items, except for an itern already oar file with the commission and
identified in the application:
(4) information on drilling, ha_ards, including
(4) the maximinn downhole pressure that may be encountered, criteria used to determine it, and inaximurra potential sru_•face pressure based on a
methane gradient;
The maximum potential surface pressure (MPSP) while drilling 3R -107L1 is calculated using an
estimated maximum reservoir pressure of 1,709 psi (based on 3R-102 downhole gauge data and reservoir
modeling), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak D sand at 3,776' TVD:
D Sand Estimated. BHP = 1,709 psi ' e,l w — $�70 r
D Sand estimated depth = 3,776' TVD - ,I
Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A)
Hydrostatic of full gas column = 377 psi (3,776 TVD * 0.10 psi/ft)
MPSP = BHP — gas column = 1,332 psi (1,709 psi — 377 psi) •
(B) data on potential gas =ones;
The well bore is not expected to penetrate any shallow gas zones.
And (C) data concerning potential causes of hole problems such as abnormallu geo-pressured strata, lost circulation .ones, and _ones that have a
propensin 7 for differential sticking;
See attached 311-107L1 Drilling Hazards Summary
Requirements of 20 AAC 25.005 (c)(5)
An application fora Permit to Drill must be accompanied ki, each of the following items, except for an item alrea4y on file with the commission and
ideni fed in the application:
(i) a description of the procedure for conducting formation integrity tests, as required under 20 AAC2?.030(f);
A procedure is on file with the commission for performing LOT'S.
Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An application for a Permit to Drill must be accompanied by each of the following items, except Jbr an item already on file with the commission and
identified in the application:
(6) a complete proposed casing and cementing program as required by 20 AAC' 2.1.030, and a description of any slotted liner, pre -perforated liner, or
screen to he installed
Casing and Cement Program
Casin and Cementing Pro ram
CsgfTbg OD
Hole
Weight
Length
Top MD/TVD
Btm MD/TVD
(in)
Size
(lbfft)
Grade
Conn.
(ft)
(ft)
00
Cement Program
20
42
94
H-40
Welded
129
Surf
168/168
Existing
Cement to Surface with
10-3/4
13-1/2
45.5
L-80
HYD563
2,253
Surf
2,253 / 2,171
861 sx 11.0 ppg lead,
283 sx 15.8 ppg tail
7-5/8
9-7/8
29.7
L-80
HYD563
5,836
Surf
5,836 / 3,700
763 sx Class G at 15.8 ppg
w/ TOC at 2,890' MD
4-1/2
6-3/4
12.6
L-80
TXP
8,606'
5,095 / 3,652
13,701 / 3,776
N/A
10-3/4" Surface casino run to 2,253' MD / 2,171' TVD
Cement from 2,253' MD to 1,753'(500' of tail) with 15.8 ppg and from 1,753' to surface with 11.0 ppg lead. Assume
250% excess annular volume for lead and tail in the permafrost, 50% annular excess below the permafrost for tail, and
0% excess in 20" conductor.
10-3/4" Surface Casing
Design: 11.0 ppg lead slurry from 1753' to surface and 500' of 15.8 ppg tail slurry
Lead Cement yield=
2.61 ft3/sk
I Tail Cement yield = 1.16 ft3/sk
11.0 ppg Lead Slurry
Conductor
1 68' x 0.24302 bbl/ft x 1.0 (0% excess)
40.8 bbls
Btm of lead to conductor
(1753'- 168) x 0.06478 bbl/ft x 3.5 (250%
excess)
359.4 bbls
Total Lead Cement
400.2 bbls
2247.0 ft3
861 sx
15.8 ppg Class G Tail Slurry
Shoe to Base of Permafrost
(2253'- 1763) x 0.06478 bbl/ft x 1.5 (50%
excess)
48.6 bbls
Base of Permafrost to top of tail
(1763'- 1753) x 0.06478 bbl/ft x 3.5 (250%
excess)
2.3 bbls
Shoetrack
80'x 0.096175 bbl/ft x 1 (0% excess)
7.7 bbls
Total Tail Cement
58.5 bbls
328.7 ft3
283 sx
7-5/8" Intermediate casing run to 5,836' MD / 3,700' TVD
Single stage slurry is designed to be placed from TD to 2,890' MD, which is 500' MD above top of the Ugnu B
(predicted top of hydrocarbon) with 35% excess annular volume.
7-5/8" Intermediate Casing
Design: Single stage 15.8 ppg Class G slurry with 35% excess in OH
Cement yield
1.16 ft3/sk
15.8 ppg Class G Slurry
Shoe to TOC
(5836'- 2890')'x 0.03825 bbl/ft x 1.35 (35% excess)
152.1 bbls
Shoetrack
120'x 0.0.04592 bbl/ft x 1 (0% excess)
5.5 bbls
Total Tail Cement
157.6 bbls
885.1 ft3
763 sx
Diverter System Information
Requirements of 20 AAC 25.005(c)(7)
,n apph'allon loo ea Permit ao Urid masi be accompanied by each of the following items, except for an item alreatl} on,Fie with the conmrission and
identified in the application:
(7) a diagram and description of the diverter system ccs required by 20 AAC 25.035, unless this requirement is waived by the cormnission under 20 AAC
25.035(h)(2);
It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At 3R,
there has not been an indication of shallow gas or gas hydrates through the surface hole interval. The
previously drilled West Sak wells 3R-102, 3R-101, 3R-106, and 3R-111 are within 500' from the
proposed 3R-107 base of permafrost location and did not encounter any shallow gas.
Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(8)
An application for a Permit to Drill must be accompanied by each q/the following items, except for an item already on file with the commission and
identijied in the application:
(8) a drilling fluid program, including a diagram and description of the drilling jknid system, as required by 20 AA( 25.033;
Mud Program Summary
Diagram of Doyon 142 Mud System is on file with AOGCC.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
N/A - Application is not for an exploratory or stratigraphic test well.
Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
N/A - Application is not for an exploratory or stratigraphic test well.
Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
N/A - Application is not for an offshore well.
Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
Ara application.lbr a Permit to Drill must be accompanied by each of the following iterns, except for an item already on file with the commission and
identffled in the application.
Surface
13-1/2" Hole
10-3/4" Casing
Intermediate
9-7/8" Hole
7-5/8" Casing
Production
6-3/4" Hole
4-1/2" Liner
Mud System
Spud
WBM)
LSND
(WBM)
FloPro NT
(WBM
Density
8.8-9.5
9.0-9.5
9.0 — 9.5 ppg
PV
ALAP
ALAP
ALAP
YP
30-80
20-30
15-20
Funnel Viscosity
250-300
Permafrost Base
100-150 to TD
N/A
N/A
Initial Gel
30-50
9 - 11
7-10
10 -minute Gel
30-50
< 20
8-16
API Filtrate
NC
< 6
<6
HTHP Fluid Loss at 160° F
N/A
< 10
<10
H
10.8-11.2
9.5-10.0
9.5-10.0
Diagram of Doyon 142 Mud System is on file with AOGCC.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
N/A - Application is not for an exploratory or stratigraphic test well.
Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
N/A - Application is not for an exploratory or stratigraphic test well.
Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
N/A - Application is not for an offshore well.
Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
Ara application.lbr a Permit to Drill must be accompanied by each of the following iterns, except for an item already on file with the commission and
identffled in the application.
The proposed drilling program is included below. Please refer to Attachment 3 for proposed well
schematic.
1. With 6-3/4" bit, motor, MWD, and magnets, drill —200' of new hole in the West Sak D sand.
2. POOH with motor assembly and LD same.
3. PU 6-3/4" bit and 4-3/4" drilling assembly with MWD/LWD [gamma ray & resistivity]. RIH.
4. Directionally drill the upper lateral to TD in the upper West Sak D sand lobe.
5. BROOH to window, circulate casing clean, and POOH on elevators. LD BHA.
6. PU and RIH with whipstock retrieval assembly.
7. Retrieve whipstock and POOH. LD whipstock.
8. PU and run 4-1/2", 12.6# slotted liner with hook hanger and MWD for orientation.
9. Set hook hanger and release. POOH with liner running tools and LD same.
10. PU and RIH with LEM (lateral entry module) and ZXP top packer.
11. Set LEM and packer. Pressure test packer for 10 min, chart results.
12. Pull wear bushing and run 4-1/2", 12.6# upper completion tubing.
13. Land hanger, run in lockdown screws, and test seals to 5,000 psi.
14. Set BPV and test in the direction of flow.
15. Nipple down BOPE, nipple up tree, and test. Pull BPV.
16. Freeze protect 4.5" x 7.625" annulus.
17. Set BPV and move rig off.
Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application fior a Permit to Drill must he accompanied by each of the fi)llowing items, except for an item already on file with the commission and
idernttfnei in the application.
(1 t) a general description oJ'hou the operator plans to dispose of driling mud and cuttings and a statement ofwhether the operator intends to
request authorization under 20 AAC 25.080 for an annular disposal operation in the well.;
Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well
(DS 1B CRI), Milne Point, Prudhoe DS -4. All cuttings generated will be hauled to the DS 1B CRI, Milne Point, Prudhoe Bay
Grind and Inject Facility (for temporary storage and eventual processing for injection down an approved disposal well), or
stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in
accordance with a permit from the State of Alaska.
Attachments:
Attachment 1 Directional Plan
Attachment 2 Drilling Hazards Summary
Attachment 3 Well Schematic
Attachment 4 BOP Configuration
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philli
ConocoPhillips Alaska
Inc—Kuparuk
Kuparuk River Unit 2
Kuparuk 3R Pad
Plan: 3R-107
50029xxxxx00
3R -107L1
3R-1071-1 wp05
Anticollision Report
20 November, 2019
BakerHughes
ConocoPhillips
ConocoPhillips Anticollision Report BakerHughesrY
Company:
ConocoPhillips Alaska Inc-Kuparuk
Project:
Kuparuk River Unit -2
Reference Site:
Kuparuk 3R Pad
Site Error:
0.00 usft
Reference Well:
Plan: 3R-107
Well Error:
0.00 usft
Reference Wellbore
3R -107L1
Reference Design:
3R-1071_1 wp05
Reference 3R -107L1 wp05
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method: MD Interval 25.00usft Error Model:
Depth Range: 5,094.58 to 13,700.74usft Scan Method:
Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface:
Warning Levels Evaluated at: 2.79 Sigma Casing Method:
Survey Tool Program Date 11/20/2019
From To
(usft) (usft) Survey (Wellbore)
39.10 1,000.00 3R-107 wp07 (3R-107)
1,000.00 2,345.08 3R-107 wp07 (3R-107)
2,345.08 5,094.58 3R-107 wp07 (3R-107)
5,094.58 13,700.58 3R-1071-1 wp05 (3R-1071-1)
Summary
Site Name
Offset Well - Wellbore - Design
Kuparuk 3R Pad
3R-10 - 3R-10 - 3R-10
3R-10 - 3R -10A - 3R -10A
3R-106 - 3R-106 - 3R-106
3R-106 - 3R-106 - 3R-106
3R-111 - 3R-111 - 3R-111
3R-111 - 3R-111 - 3R-111
3R-111 - 3R-111 - 3R-111
3R-111 - 3R-111 L1 - 3R-111 L1
3R-111 - 3R-111 L1 - 3R-111 L1
3R-111 - 3R-111 L1 - 3R-111 L1
3R-111 - 3R-111 L1 PB1 - 3R-111 L1 PB1
3R-111 - 3R-111 L1 P61 - 3R-111 L1 PB1
3R-111 - 3R-111 L1 PB1 - 313-111 L1 P81
3R -12D - 3R -12A- 3R -12A
Plan: 3R-103 - 3R-103 - 3R-103 wp06
Plan: 3R-103 - 3R-1031-1 - 3R-1031_1 wp02
Plan: 3R-104 - 3R-104 - 3R-104 wp05
Plan: 3R-105 - 3R-105 - 3R-105_wpl0
Plan: 3R-105 - 3R -105L1 - 3R-105L1_wp02
Plan: 3R-107 - 3R-107 - 3R-107 wp07
Plan: 3R-107 - 3R-107 - 3R-107 wp07
Plan: 3R-108 - 3R-108 - 3R-108_wp04
Plan: 3R-108 - 3R-108 - 3R-108_wp04
Plan: 3R-108 - 3R-108 - 3R-108_wp04
Plan: 3R-109 - 3R-109 - 3R-109_wp05 (Draft B)
Plan: 3R-109 - 3R -109L1 - 3R-1091-1 wp02
Kuparuk Oliktok
Oliktok Point State 1 - Oliktok Point State 1 - Oliktok Poin
Well Plan: 3R-107
Plan: 9.8+39.10 @ 48.90usft (Doyon 142)
Plan: 9.8+39.10 @ 48.90usft (Doyon 142)
True
Minimum Curvature
2.00 sigma
OAKEDMPI
Offset Datum
ISCWSA
Tray. Cylinder North
Combined Pedal Curve
Added to Error Values
Tool Name Description
GYD-GC-SS Gyrodata gyro single shots
MWD+IFR2+SAG+MS OWSG MWD + IFR2+ Sag + Multi -Station Correction
MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction
MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Depth
Depth
Centres
Ellipses
Factor
(usft)
(usft)
tusft)
lusft)
5,116.27
5,500.00
1,180.85
1,127.69
22.213 CC, ES, SF
Out of range
5,931.57
6,450.00
1,019.47
933.16
11.812 CC
13,656.81
14,165.00
1,259.36
851.79
3.090 ES, SF
5,851.83
5,075.00
913.62
873.17
22.587 CC
5,878.27
5,150.00
915.78
870.23
20.103 ES
5,941.91
5,675.00
1,082.67
1,008.11
14.520 SF
5,851.83
5,075.00
913.62
873.17
22.587 CC
5,878.27
5,150.00
915.78
870.23
20.103 ES
5,941.91
5,675.00
1,082.67
1,008.11
14.520 SF
5,851.83
5,075.00
913.62
873.17
22.587 CC
5,878.27
5,150.00
915.78
870.23
20.103 ES
5,941.91
5,675.00
1,082.67
1,008.11
14.520 SF
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
5,416.83
5,425.00
47.92
37.28
4.505 CC
13,699.98
13,684.41
103.08
-213.29
0.326 STOP Drilling, ES, SF
5,100.00
4,425.00
656.29
586.80
9.444 CC
5,100.00
4,450.00
657.26
586.56
9.297 ES
13,691.69
13,075.00
1,375.95
978.71
3.464 SF
5,097.74
4,975.00
567.88
494.17
7.704 CC, ES, SF
5,100.00
5,025.00
572.61
495.45
7.422 CC, ES, SF
Out of range
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
11/20/2019 9:52:02AM Page 2 COMPASS 5000.14 Build 85G
ConocoPhillips
ConocoPhillips Anticollision Report BakerHughes lli'!�;
Company:
Project:
Reference Site:
Site Error:
Reference Well:
Well Error:
Reference Wellbore
Reference Design:
ConocoPhillips Alaska Inc-Kuparuk
Kuparuk River Unit -2
Kuparuk 3R Pad
0.00 usft
Plan: 3R-107
0.00 usft
3R-1071-11
3R-1071-1 wp05
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well Plan: 3R-107
Plan: 9.8+39.10 @ 48.90usft (Doyon 142)
Maw 9.8+39.10 @ 48.90usft (Doyon 142)
True
Minimum Curvature
2 00 sigma
OAKEDMP1
Offset Datum
Reference Depths are relative to Plan: 9.8+39.10 @ 48.90usft (Doyon 1 Coordinates are relative to: Plan: 3R-107
Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4
Central Meridian is 150° 0'0,000 W Grid Convergence at Surface is: 0.160
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
11/20/2019 9:52:02AM Page 3 COMPASS 5000.14 Build 85G
Separation Factor Plot
9.OD—
...._
I I I
• ., !
______ ___-------- ---_----j---------�--___.- _...-.._.-..-.
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__._.__ ._._._.-..-.
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LL
0
(O-
Q-----1-_
! ! I
-_-II _-�_----I_---_ ____
- --_-I__
Cn
�
Normal Operations
I I
I
3.00
Caution MonilorOosey
I I I
Take Immediate Action
I I I I
I
STOPDnlling ! !
0.0()-
0 2500
5000 7500 10000
12500
Measured Depth
LEGEND
3R�0.3a10.3i�0.V1 i113F1 �1LtA 11Lfw n3Ri0B.3Rif9.3R�09v�aw
aawu3aiw.3wiaew 3w»�,x»�L�reiarx�m��w �aaiw.3wiwawiww low
aani.»iii3wniw w�x�m,m�ar.3n.�m�ww �.3a�w,3wicai.3wmL�www
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
11/20/2019 9:52:02AM Page 3 COMPASS 5000.14 Build 85G
3R-107 & 3R -107L1 Drilling Hazards Summary
13-1/2" Open Hole / 10-3/4" Casing Interval
Hazard
Risk Level
Mitigation Strategy
Washouts / Hole Sloughing
Moderate
Cool mud temperatures, minimize circulating times
Concretions
when possible.
Broach of Conductor
Low
Monitor cellar continuously during interval.
Gas Hydrates
Low
Control drill, reduced pump rates, reduced drilling fluid
temperatures, additions of ScreenKleen.
Running Sands and Gravels
Low
Maintain planned mud parameters, increase mud weight,
Whipstock Retrieval
Moderate
use weighted sweeps.
Hole swabbing on trips
Low
Trip speeds, proper hole filling (use of trip sheets),
Hole Swabbing on Trips
Moderate
pumping out.
Anti -Collision
Low
Follow real time surveys very closely, shut in nearby
Tight Hole
Low
wells that have collision concerns, utilize gyro survey to
ensure survey accuracy through zone with magnetic
interference.
9-7/8" Open Hole / 7-5/8" Casing Interval
Hazard
Risk Level
Mitigation Strategy
Hole swabbing on trips
Moderate
Trip speeds, proper hole filling (use of trip sheets),
Concretions
pumping out.
Anti -Collision
Moderate
Follow real time surveys very closely, shut in nearby
Getting Liner to Bottom
Moderate
wells that have collision concerns, and perform real time
survey corrections.
Stuck Pipe
Low
Good hole cleaning, monitor real time T&D, stabilized
Whipstock Retrieval
Moderate
BHA, decreased mud weight.
Abnormal Reservoir Pressure
Low
Normally pressured, ensure adequate mud weight prior
Hole Swabbing on Trips
Moderate
to drilling into reservoir. BOP training and drills.
Lost circulation
Low
Monitor ECD, mud rheology, LCM.
Tight Hole
Low
Control with proper drilling practices. Perform wiper
trip if hole conditions dictate.
6-3/4" Open Hole / 4-1/2" Liner Interval
Hazard
Risk Level
Mitigation Strategy
Fault Crossings and
Moderate
Use developed best practices for concretion drilling. Ensure
Concretions
good communication between Wellsite Geologist and DD prior
to crossin faults.
Getting Liner to Bottom
Moderate
Properly clean hole on trip out with BHA, add lubes to mud
system prior to tripping out to aid in torque and drag, and keep
DLS to a minimum. Utilize Su erSliders if necessary.
Whipstock Retrieval
Moderate
A dedicated clean out run prior to attempting to pull whipstock
can be used to reduce the risk of fishing operations.
Hole Swabbing on Trips
Moderate
Trip speeds, proper hole filling (use of trip sheets), pumping out
or backreamin .
3R-107 Drilling Hazards Summary.doc
11120120198:57:36 AM
Lost Circulation
Moderate
Monitor ECD, mud rheology, LCM program, and have
additional fluid stored on location.
Differential Sticking
Moderate
Follow mud program, keep pipe moving when able.
Anti -Collision
Moderate
Follow real time surveys very closely, shut in nearby wells that
are of concern for collision. Utilize AziTrak tool to maintain
eolo ical certainty to stay in zone.
Casing Wear
Moderate
Maintain low doglegs in the surface interval and use
SuperSliders if necessary for drilling, milling, and liner running
operations
Abnormal Reservoir
Low
Stripping drills, shut-in drills, increased mud weight if higher
Pressure
pressure encountered.
Stuck Pipe
Low
Good hole cleaning, PWD tools monitoring and analysis,
decreased mud weight.
3R-107 Drilling Hazards Summarydoc
11/20/20198:57:36 AM
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ConocclPhillips
311-107 Dual Lateral Slotted Liner Producer
w 8-107 07
Alaska
Attachment 4 BOP Configuration
The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can
be found with the Doyon 142 documentation on file with the State.
Loepp, Victoria T (CED)
From: Woodard, Madeline E <Madeline.E.Woodard@conocophilIips.com>
Sent: Tuesday, December 10, 2019 8:58 AM
To: Loepp, Victoria T (CED)
Subject: 3R-107 Correct Wellbore Schematic
Attachments: 3R-107 wp07.pdf
Victoria,
See the correct schematic attached. I am really sorry about that, as I mentioned 311-1071-1 PTD application has the
correct schematic (same as attached).
Thanks,
Madeline Woodard
Drilling Engineer
ConocoPhillips Alaska, Inc
Office: 907-265-6086
Mobile: 907-764-8095
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TRANSMITTAL LETTER CHECKLIST
WELL NAME: Y\ R Lk, 3 PHO 7 L, I
PTD: ]� 19 - 16 I
V
development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: t t K_werpom: A E,,5+ S al Vim. 0
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
LATERAL
The permit is for a new wellbore segment of existing well Permit
No. S 19 - Ip , API No. 50- oz4 2366o - QO -_00
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50- -
- -) from records, data and logs acquired for well
name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
Jcomposite
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, WEST SAK OIL - 490150
Well Name: KUPARUK RIV UNIT 3R-1071_1 — Program DEV Well bore seg ❑d
PTD#:2191810 Company ConocoPhillips Alaska. Inc. _ _ Initial Class/Type - DEV / PEND GeoArea 890 Unit 11160 __ _ _ - On/Off Shore On Annular Disposal ❑
Administration 1
Permit fee attached
NA
119
2
Lease number appropriate-
Yes -
3
Unique well name and number
Yes
4
Well located in a defined pool
Yes
_NA_
5
Well located proper distance_ from drilling unit boundary
Yes
CMT will coverall known -productive horizons
6
Well located proper distance_ from other wells_
Yes
I23
7
Sufficient acreage available in drilling unit- - - - - -
Yes
8
If deviated, is wellbore plat included
Yes Directional_ plan view and well_bor_eprofile provided. -----------------------
9
Operator only affected party -
Yes _
10
Operator has appropriate bond in force
Yes
11
Permit can be issued without conservation order_ ----------------------
Yes - - -
Appr Date
12
Permit can be issued without administrative approval
Yes
If_diverter required, does it meet regulations_
13
Can permit be approved before 15 -day wait - -
Yes
DLB 12/3/2019
Drilling fluid program schematic & equip list adequate
Yes
Max formation pressure is 1720 psig(8.7 ppg EMW); will drill w/_8_.8-9.5 ppg EMW
VTL 12/6/2019
14
Well located within area and strata authorized by Injection Order # (put_10# in_comments) (For
NA
15
All wells within 1/4 mile area -of review identified (For service well only) - - - -
NA_ - - - - -
Yes
16
Pre -produced injector: duration of pre production less than 3 months (For service well only)
NA_
Choke manifold complies w/API RP -53 (May 84)
17
Nonconven. gas conforms to AS31.05.030Q.1.A),0.2.A-D)
NA_
Geologic Engineering Public
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18
Conductor string provided
- - - NA_
Conductor set for KRU 3R-107_
Engineering
119
Surface casing_p_rotects all -known USDWs - - - - -
NA_
Surface casing will be set for KRU 3R-107
120
_CMT _vol -adequate to circulate on conductor _& surf_csg
NA_
21
CMT vol_ adequate_ to tie -in -long string to surf csg_
_NA_
22
CMT will coverall known -productive horizons
No
Productive interval will be completed with uncemented slotted_ liner_
I23
Casing designs adequate for C T, 6 & permafrost
Yes _
i24
Adequate tankage or reserve pit
Yes
Rig has steel tanks, all waste -to approved disposal wells - ----- ------------------
25
If_a_re-drill, has_a 1.0-403 for abandonment been approved
NA_
26
Adequate wellbore separation -proposed
Yes
Anti -collision analysis complete; no major risk failures
27
If_diverter required, does it meet regulations_
NA_
Appr Date
28
Drilling fluid program schematic & equip list adequate
Yes
Max formation pressure is 1720 psig(8.7 ppg EMW); will drill w/_8_.8-9.5 ppg EMW
VTL 12/6/2019
29
BOPEs, do they meet regulation
Yes _
30
BOPE_press rating appropriate; test to -(put psig in comments)
Yes
MPSP is 1340 psig; will test BOPs_to 3500 psig
31
Choke manifold complies w/API RP -53 (May 84)
Yes
32
Work will occur without operation shutdown
Yes
33
Is presence of H2S gas probable
Yes
H2S measures required
34
Mechanical condition of wells within AOR verified (For service well only)
NA_
35
Permit can be issued w/o hydrogen sulfide measures
No_
The highest H2S recorded in the West Salk open in 3R-101 was 20 ppm on 1.0/07/19._
Geology
36
Data_presented on_ potential overpressure zones
Yes
H2S measures are now required as aprecaution for West Salk development on 3R Pad.
Appr Date
37
Seismic analysis of shallow gas zones
NA
DLB 12/3/2019
38
Seabed condition survey (if off -shore)
NA_
39
Contact name/phone for weekly progress reports [exploratory only] -
- - - - - NA
- - - - - - - - - - - - - - - -
Geologic Engineering Public
Commissioner: Date: Commissioner: Datemmiss' n Date p�
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