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From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 2B-11 (PTD 184-035) Variance Request
Date:Thursday, August 21, 2025 9:32:25 AM
From: Wallace, Chris D (OGC)
Sent: Thursday, August 21, 2025 9:31 AM
To: Bronga, Jaime <Jaime.Bronga@conocophillips.com>
Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J
<Erica.J.Livingston@conocophillips.com>
Subject: RE: KRU 2B-11 (PTD 184-035) Variance Request
Jaime,
Your request of 72 hr injection to complete the planned diagnostics is approved.
Thanks and Regards,
Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907)
793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska
Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended
recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure
of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please
delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you,
contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov.
From: Bronga, Jaime <Jaime.Bronga@conocophillips.com>
Sent: Thursday, August 21, 2025 9:08 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J
<Erica.J.Livingston@conocophillips.com>
Subject: KRU 2B-11 (PTD 184-035) Variance Request
Well Name: 2B-11
Facility: CPF2
PTD: 184-035
Well Type: Inj
AA Number (if applicable):
Internal Waiver (Yes/No if applicable):
Type of Issue: Variance Request
Maximum Pressure (if applicable):
Date of Occurrence (if applicable):
Hi Chris,
KRU 2B-11 (PTD 184-035) is a WAG injection well currently shut in for IA repressurization on
water and gas injection. The well also has a surface casing leak at 186 ft. CPAI intends to log
the well to determine the source of IA repressurization. To do this, we would like to bring the
well on water injection ahead of the log and during the log. We request a maximum of 72 hours
to get the well on stable injection and complete logging. The IA pressure will be bled as needed
to maintain the OPL of 2000 psi. The well will then be shut in and remain shut in until proper
repairs and approvals are received. Please respond to this email if you have any questions and
to approve this temporary variance.
Warmest regards,
Jaime Bronga
Well Integrity – CPF2 – ConocoPhillips Alaska
Cell: 907-229-8282
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 2B-11 (PTD 184-035) Failed SCLD
Date:Tuesday, July 15, 2025 1:18:50 PM
From: Bronga, Jaime <Jaime.Bronga@conocophillips.com>
Sent: Tuesday, July 15, 2025 1:13 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J
<Erica.J.Livingston@conocophillips.com>
Subject: KRU 2B-11 (PTD 184-035) Failed SCLD
Well Name: 2B-11
Facility: CPF2
PTD: 184-035
Well Type:
AA Number (if applicable):
Internal Waiver (Yes/No if applicable):
Type of Issue: Plan Forward
Maximum Pressure (if applicable):
Date of Occurrence (if applicable):
Hi Chris,
KRU 2B-11 is a WAG injection well that is shut in due to TxIA on water and gas. This was
reported to the AOGCC on July 10, 2025 and the failed MIT-OA was reported to the AOGCC on
7/14/2025. CPAI conducted a surface casing leak detection and found a leak in the surface
casing at 186’ rkb. The well is currently shut in and will remain shut in until proper repairs,
testing and administrative approval are completed. Please let me know if you have any
questions or disagree with the plan.
Warmest regards,
Jaime Bronga
Well Integrity – CPF2 – ConocoPhillips Alaska
Cell: 907-229-8282
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 2B-11 (PTD 184-035) Failed MITOA
Date:Monday, July 14, 2025 8:45:23 AM
From: Bronga, Jaime <Jaime.Bronga@conocophillips.com>
Sent: Monday, July 14, 2025 8:43 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J
<Erica.J.Livingston@conocophillips.com>
Subject: KRU 2B-11 (PTD 184-035) Failed MITOA
Well Name: 2B-11
Facility: CPF2
PTD: 184-035
Well Type:
AA Number (if applicable):
Internal Waiver (Yes/No if applicable):
Type of Issue: Failed MITOA
Maximum Pressure (if applicable):
Date of Occurrence (if applicable):
Hi Chris,
KRU 2B-11 is a WAG injection well that is shut in due to TxIA on water and gas. This was
reported to the AOGCC on July 10, 2025. As part of our diagnostics, an MIT-OA was conducted
on 7/13/2025 and failed. CPAI intends to conduct a Surface Casing Leak Detection test to
understand the leak point of the OA. The IA did not show any pressure response during the
MITOA and liquid leak rate test. The well is currently shut in and will remain shut in until proper
repairs and testing are completed. Please let me know if you have any questions or disagree
with the plan.
Warmest regards,
Jaime Bronga
Well Integrity – CPF2 – ConocoPhillips Alaska
Cell: 907-229-8282
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 2B-11 (PTD 184-035) Plan Forward
Date:Thursday, July 10, 2025 9:50:03 AM
Attachments:AnnComm Surveillance TIO for 2B-11.pdf
From: Bronga, Jaime <Jaime.Bronga@conocophillips.com>
Sent: Thursday, July 10, 2025 9:35 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J
<Erica.J.Livingston@conocophillips.com>
Subject: KRU 2B-11 (PTD 184-035) Plan Forward
Well Name: 2B-11
Facility: CPF2
PTD: 184-023
Well Type: Inj
AA Number (if applicable):
Internal Waiver (Yes/No if applicable):
Type of Issue: Plan Forward
Maximum Pressure (if applicable):
Date of Occurrence (if applicable):
Hi Chris,
CPAI reported KRU 2B-11 (PTD 184-035) to the AOGCC On 6/23/2025 for TxIA on gas injection.
The well was WAG to water injection and CPAI conducted diagnostics. The well is showing TxIA
on water injection as well. CPAI intends to shut in the well to conduct further diagnostics.
Proper notification will be made if CPAI intends to bring the well back online for further review.
Please let me know if you have any questions or disagree with this plan. The TIO plot,
schematic, and bleed log are attached.
Warmest regards,
Jaime Bronga
Well Integrity – CPF2 – ConocoPhillips Alaska
Cell: 907-229-8282
2B-11 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
2B-11 2025-05-17 1900 1000 -900 IA
2B-11 2025-05-18 1900 1000 -900 IA
2B-11 2025-06-11 1950 1000 -950 IA
2B-11 2025-06-22 1600 1000 -600 IA
2B-11 2025-07-02 1450 1050 -400 IA
2B-11 2025-07-05 1138 180 -958 IA
2B-11 2025-07-06 220 500 280 IA
2B-11 2025-07-07 908 500 -408 IA
2B-11 2025-07-09 1800 1100 -700 IA
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 7,440.0 2B-11 8/28/2024 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Added patch 2B-11 2/22/2025 jconne
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 ninam
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 37.0 116.0 116.0 65.50 H-40 WELDED
SURFACE 9 5/8 8.92 36.5 2,892.5 2,782.4 36.00 J-55 BTC
PRODUCTION 7 6.28 34.9 7,659.0 6,146.3 26.00 J-55 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
33.6
Set Depth …
7,342.6
Set Depth …
5,909.3
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDABM
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
33.6 33.6 0.16 HANGER 8.000 GRAY TUBING HANGER 3.500
1,935.8 1,930.0 13.74 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE
(LOCKED OUT 8/24/98)
BAKER FVL 2.810
7,044.5 5,689.0 42.84 GAS LIFT 5.312 MMH FMHO Comment: STA 1 MMH FMHO 2.867
7,088.0 5,720.9 42.64 PBR 4.000 BAKER 10 PBR BAKER 3.000
7,102.5 5,731.6 42.57 PACKER 5.968 BAKER FHL RETRIEVABLE
PACKER
BAKER FHL 3.000
7,140.2 5,759.4 42.46 GAS LIFT 5.312 MMH FMHO Comment: STA 2 MMH FMHO 2.867
7,210.2 5,811.1 42.26 GAS LIFT 5.312 MMH FMHO Comment: STA 3 MMH FMHO 2.867
7,248.5 5,839.5 42.18 BLAST JOINT 4.500 BLAST JOINT (1) 2.992
7,279.5 5,862.5 42.12 BLAST RING 4.500 BLAST RING (1) 2.992
7,312.1 5,886.7 42.02 GAS LIFT 5.312 MMH FMHO Comment: STA 4 MMH FMHO 2.867
7,327.1 5,897.8 41.94 LOCATOR 4.500 BAKER LOCATOR SUB w/ 5'
SEALS
BAKER 3.000
7,327.9 5,898.4 41.93 PACKER 5.875 BAKER FB-1 PACKER BAKER FB-1 4.000
7,330.4 5,900.3 41.92 SBE 5.000 BAKER SEAL BORE EXTENSION BAKER 4.000
7,340.6 5,907.9 41.86 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750
7,342.1 5,909.0 41.86 WLEG 4.570 BAKER WIRELINE RE-ENTRY
GUIDE, ELMD 7320' PER SWS
IPROF 2/25/2000
BAKER 2.992
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
7,075.6 5,711.8 42.69 PACKER -
PATCH - UPR
2.72" PIIP UPPER PACKER
WITH MOE = 7078' RKB.
INCLUDES EXAPNSION JNT,
SPACER PIPE, AND
ANCHOR LATCH.
OAL OF UPPER PKR,
EXAPANSION JNT, AND
SPACER PIPE (W/
EXPANSION JNT FULLY
OPEN) = 38.65'
TTS PIIP CPP3
5371
2/22/2025 1.625
7,079.8 5,714.9 42.68 SPACER
PIPE
SPACER PIPE & ANCHOR
LATCH W/ SPLINE
EXPANSION JOINT
(STROKED OPEN 5'). OAL
FULLY OPEN (EXPANSION
JOINT + BEVEL COUPLING +
SPACER PIPE) = 34.77'
CPEJ
27207
2/22/2025 1.614
7,109.6 5,736.8 42.55 PACKER -
PATCH - LWR
2.72" PIIP LOWER PACKER,
MOE AT 7112, OAL = 4.43'
TTS PIIP CPAL
35209
,
CPP3
5233
2/22/2025 1.625
7,140.0 5,759.3 42.46 LEAK LEAK AT 7140' RKB
IDENTIFIED VIA IPROF
11/22/2024 2.992
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
7,044.5 5,689.0 42.84 1 GAS LIFT DMY BK 1 0.0 5/17/2024 0.000
7,140.2 5,759.4 42.46 2 INJ CV BK 1 0.0 11/29/2024 0.313
7,210.2 5,811.1 42.26 3 INJ DMY BK 1 0.0 7/31/1991 0.000
7,312.1 5,886.7 42.02 4 INJ DMY BK 1 0.0 7/19/1996 12:30 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,261.0 7,287.0 5,848.8 5,868.0 C-4, UNIT B, 2B-
11
5/10/1984 12.0 IPERF 120 degrees phasing, SOS 5
1/2" Guns
7,377.0 7,387.0 5,935.0 5,942.5 A-3, 2B-11 5/31/2015 6.0 APERF 2.5" DIAMETER, 6 SPF, 60
DEG PHASE, MILLENIUM II
HSC GUN
7,396.0 7,422.0 5,949.2 5,968.7 A-4, 2B-11 7/12/1984 4.0 IPERF 2 shots @ 80 deg., 1 shot @
90 deg., & 1 shot @ 27, DA 2
1/16" Link Kone
2B-11, 2/23/2025 9:19:29 AM
Vertical schematic (actual)
PRODUCTION; 34.9-7,659.0
FLOAT SHOE; 7,657.1-7,659.0
FLOAT COLLAR; 7,568.6-
7,570.2
IPERF; 7,441.0-7,466.0
IPERF; 7,396.0-7,422.0
APERF; 7,377.0-7,387.0
WLEG; 7,342.1
NIPPLE; 7,340.6
SBE; 7,330.4
PACKER; 7,327.9
LOCATOR; 7,327.1
GAS LIFT; 7,312.1
IPERF; 7,261.0-7,287.0
GAS LIFT; 7,210.2
GAS LIFT; 7,140.2
LEAK; 7,140.0
PACKER - PATCH - LWR;
7,109.5
PACKER; 7,102.5
PBR; 7,088.0
SPACER PIPE; 7,079.8
PACKER - PATCH - UPR;
7,075.6
GAS LIFT; 7,044.5
SURFACE; 36.5-2,892.5
FLOAT SHOE; 2,890.5-2,892.5
FLOAT COLLAR; 2,810.0-
2,811.7
SAFETY VLV; 1,935.8
CONDUCTOR; 37.0-116.0
HANGER; 36.5-40.8
HANGER; 33.6
KUP INJ
KB-Grd (ft)
42.01
RR Date
3/22/1984
Other Elev…
2B-11
...
TD
Act Btm (ftKB)
7,676.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292108900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
47.62
MD (ftKB)
5,500.00
WELLNAME WELLBORE2B-11
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: LOCKED OUT
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,441.0 7,466.0 5,982.9 6,001.6 A-3, 2B-11 7/12/1984 4.0 IPERF 1 shot @ 90 deg., 1 shot at
270 deg., 2 shots @ 1, DA 2
1/16" Link Kone
2B-11, 2/23/2025 9:19:29 AM
Vertical schematic (actual)
PRODUCTION; 34.9-7,659.0
FLOAT SHOE; 7,657.1-7,659.0
FLOAT COLLAR; 7,568.6-
7,570.2
IPERF; 7,441.0-7,466.0
IPERF; 7,396.0-7,422.0
APERF; 7,377.0-7,387.0
WLEG; 7,342.1
NIPPLE; 7,340.6
SBE; 7,330.4
PACKER; 7,327.9
LOCATOR; 7,327.1
GAS LIFT; 7,312.1
IPERF; 7,261.0-7,287.0
GAS LIFT; 7,210.2
GAS LIFT; 7,140.2
LEAK; 7,140.0
PACKER - PATCH - LWR;
7,109.5
PACKER; 7,102.5
PBR; 7,088.0
SPACER PIPE; 7,079.8
PACKER - PATCH - UPR;
7,075.6
GAS LIFT; 7,044.5
SURFACE; 36.5-2,892.5
FLOAT SHOE; 2,890.5-2,892.5
FLOAT COLLAR; 2,810.0-
2,811.7
SAFETY VLV; 1,935.8
CONDUCTOR; 37.0-116.0
HANGER; 36.5-40.8
HANGER; 33.6
KUP INJ 2B-11
...
WELLNAME WELLBORE2B-11
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 2B-11 (PTD 184-035) Suspect Integrity
Date:Monday, June 23, 2025 12:28:59 PM
Attachments:AnnComm Surveillance TIO for 2B-11.pdf
From: Bronga, Jaime <Jaime.Bronga@conocophillips.com>
Sent: Monday, June 23, 2025 11:45 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J
<Erica.J.Livingston@conocophillips.com>
Subject: KRU 2B-11 (PTD 184-035) Suspect Integrity
Well Name: 2B-11
Facility: CPF2
PTD: 184-035
Well Type: Inj
AA Number (if applicable):
Internal Waiver (Yes/No if applicable):
Type of Issue: Suspect Integrity
Maximum Pressure (if applicable):
Date of Occurrence (if applicable):
Hi Chris,
KRU 2B-11 is a WAG injection well currently on MI injection. The well is exhibiting signs of TxIA
integrity on gas injection. CPAI intends to WAG the well back to water injection and conduct a
monitoring period for TxIA on water injection and then update the AOGCC with a plan forward.
Please let me know if you have any questions or disagree with this plan.
Warmest regards,
Jaime Bronga
Well Integrity – CPF2 – ConocoPhillips Alaska
Cell: 907-229-8282
2B-11 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
2B-11 2025-05-17 1900 1000 -900 IA
2B-11 2025-05-18 1900 1000 -900 IA
2B-11 2025-06-11 1950 1000 -950 IA
2B-11 2025-06-22 1600 1000 -600 IA
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 7,440.0 2B-11 8/28/2024 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Added patch 2B-11 2/22/2025 jconne
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 ninam
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 37.0 116.0 116.0 65.50 H-40 WELDED
SURFACE 9 5/8 8.92 36.5 2,892.5 2,782.4 36.00 J-55 BTC
PRODUCTION 7 6.28 34.9 7,659.0 6,146.3 26.00 J-55 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
33.6
Set Depth …
7,342.6
Set Depth …
5,909.3
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDABM
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
33.6 33.6 0.16 HANGER 8.000 GRAY TUBING HANGER 3.500
1,935.8 1,930.0 13.74 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE
(LOCKED OUT 8/24/98)
BAKER FVL 2.810
7,044.5 5,689.0 42.84 GAS LIFT 5.312 MMH FMHO Comment: STA 1 MMH FMHO 2.867
7,088.0 5,720.9 42.64 PBR 4.000 BAKER 10 PBR BAKER 3.000
7,102.5 5,731.6 42.57 PACKER 5.968 BAKER FHL RETRIEVABLE
PACKER
BAKER FHL 3.000
7,140.2 5,759.4 42.46 GAS LIFT 5.312 MMH FMHO Comment: STA 2 MMH FMHO 2.867
7,210.2 5,811.1 42.26 GAS LIFT 5.312 MMH FMHO Comment: STA 3 MMH FMHO 2.867
7,248.5 5,839.5 42.18 BLAST JOINT 4.500 BLAST JOINT (1) 2.992
7,279.5 5,862.5 42.12 BLAST RING 4.500 BLAST RING (1) 2.992
7,312.1 5,886.7 42.02 GAS LIFT 5.312 MMH FMHO Comment: STA 4 MMH FMHO 2.867
7,327.1 5,897.8 41.94 LOCATOR 4.500 BAKER LOCATOR SUB w/ 5'
SEALS
BAKER 3.000
7,327.9 5,898.4 41.93 PACKER 5.875 BAKER FB-1 PACKER BAKER FB-1 4.000
7,330.4 5,900.3 41.92 SBE 5.000 BAKER SEAL BORE EXTENSION BAKER 4.000
7,340.6 5,907.9 41.86 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750
7,342.1 5,909.0 41.86 WLEG 4.570 BAKER WIRELINE RE-ENTRY
GUIDE, ELMD 7320' PER SWS
IPROF 2/25/2000
BAKER 2.992
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
7,075.6 5,711.8 42.69 PACKER -
PATCH - UPR
2.72" PIIP UPPER PACKER
WITH MOE = 7078' RKB.
INCLUDES EXAPNSION JNT,
SPACER PIPE, AND
ANCHOR LATCH.
OAL OF UPPER PKR,
EXAPANSION JNT, AND
SPACER PIPE (W/
EXPANSION JNT FULLY
OPEN) = 38.65'
TTS PIIP CPP3
5371
2/22/2025 1.625
7,079.8 5,714.9 42.68 SPACER
PIPE
SPACER PIPE & ANCHOR
LATCH W/ SPLINE
EXPANSION JOINT
(STROKED OPEN 5'). OAL
FULLY OPEN (EXPANSION
JOINT + BEVEL COUPLING +
SPACER PIPE) = 34.77'
CPEJ
27207
2/22/2025 1.614
7,109.6 5,736.8 42.55 PACKER -
PATCH - LWR
2.72" PIIP LOWER PACKER,
MOE AT 7112, OAL = 4.43'
TTS PIIP CPAL
35209
,
CPP3
5233
2/22/2025 1.625
7,140.0 5,759.3 42.46 LEAK LEAK AT 7140' RKB
IDENTIFIED VIA IPROF
11/22/2024 2.992
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
7,044.5 5,689.0 42.84 1 GAS LIFT DMY BK 1 0.0 5/17/2024 0.000
7,140.2 5,759.4 42.46 2 INJ CV BK 1 0.0 11/29/2024 0.313
7,210.2 5,811.1 42.26 3 INJ DMY BK 1 0.0 7/31/1991 0.000
7,312.1 5,886.7 42.02 4 INJ DMY BK 1 0.0 7/19/1996 12:30 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,261.0 7,287.0 5,848.8 5,868.0 C-4, UNIT B, 2B-
11
5/10/1984 12.0 IPERF 120 degrees phasing, SOS 5
1/2" Guns
7,377.0 7,387.0 5,935.0 5,942.5 A-3, 2B-11 5/31/2015 6.0 APERF 2.5" DIAMETER, 6 SPF, 60
DEG PHASE, MILLENIUM II
HSC GUN
7,396.0 7,422.0 5,949.2 5,968.7 A-4, 2B-11 7/12/1984 4.0 IPERF 2 shots @ 80 deg., 1 shot @
90 deg., & 1 shot @ 27, DA 2
1/16" Link Kone
2B-11, 2/23/2025 9:19:29 AM
Vertical schematic (actual)
PRODUCTION; 34.9-7,659.0
FLOAT SHOE; 7,657.1-7,659.0
FLOAT COLLAR; 7,568.6-
7,570.2
IPERF; 7,441.0-7,466.0
IPERF; 7,396.0-7,422.0
APERF; 7,377.0-7,387.0
WLEG; 7,342.1
NIPPLE; 7,340.6
SBE; 7,330.4
PACKER; 7,327.9
LOCATOR; 7,327.1
GAS LIFT; 7,312.1
IPERF; 7,261.0-7,287.0
GAS LIFT; 7,210.2
GAS LIFT; 7,140.2
LEAK; 7,140.0
PACKER - PATCH - LWR;
7,109.5
PACKER; 7,102.5
PBR; 7,088.0
SPACER PIPE; 7,079.8
PACKER - PATCH - UPR;
7,075.6
GAS LIFT; 7,044.5
SURFACE; 36.5-2,892.5
FLOAT SHOE; 2,890.5-2,892.5
FLOAT COLLAR; 2,810.0-
2,811.7
SAFETY VLV; 1,935.8
CONDUCTOR; 37.0-116.0
HANGER; 36.5-40.8
HANGER; 33.6
KUP INJ
KB-Grd (ft)
42.01
RR Date
3/22/1984
Other Elev…
2B-11
...
TD
Act Btm (ftKB)
7,676.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292108900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
47.62
MD (ftKB)
5,500.00
WELLNAME WELLBORE2B-11
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: LOCKED OUT
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,441.0 7,466.0 5,982.9 6,001.6 A-3, 2B-11 7/12/1984 4.0 IPERF 1 shot @ 90 deg., 1 shot at
270 deg., 2 shots @ 1, DA 2
1/16" Link Kone
2B-11, 2/23/2025 9:19:29 AM
Vertical schematic (actual)
PRODUCTION; 34.9-7,659.0
FLOAT SHOE; 7,657.1-7,659.0
FLOAT COLLAR; 7,568.6-
7,570.2
IPERF; 7,441.0-7,466.0
IPERF; 7,396.0-7,422.0
APERF; 7,377.0-7,387.0
WLEG; 7,342.1
NIPPLE; 7,340.6
SBE; 7,330.4
PACKER; 7,327.9
LOCATOR; 7,327.1
GAS LIFT; 7,312.1
IPERF; 7,261.0-7,287.0
GAS LIFT; 7,210.2
GAS LIFT; 7,140.2
LEAK; 7,140.0
PACKER - PATCH - LWR;
7,109.5
PACKER; 7,102.5
PBR; 7,088.0
SPACER PIPE; 7,079.8
PACKER - PATCH - UPR;
7,075.6
GAS LIFT; 7,044.5
SURFACE; 36.5-2,892.5
FLOAT SHOE; 2,890.5-2,892.5
FLOAT COLLAR; 2,810.0-
2,811.7
SAFETY VLV; 1,935.8
CONDUCTOR; 37.0-116.0
HANGER; 36.5-40.8
HANGER; 33.6
KUP INJ 2B-11
...
WELLNAME WELLBORE2B-11
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Tuesday, April 22, 2025
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Adam Earl
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
2B-11
KUPARUK RIV UNIT 2B-11
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 04/22/2025
2B-11
50-029-21089-00-00
184-035-0
W
SPT
5731
1840350 1500
1710 1710 1710 1710
70 70 70 70
OTHER P
Adam Earl
3/9/2025
MIT-IA tested as per Sundry 324-449
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV UNIT 2B-11
Inspection Date:
Tubing
OA
Packer Depth
1460 2500 2470 2460IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitAGE250309141722
BBL Pumped:0.9 BBL Returned:0.9
Tuesday, April 22, 2025 Page 1 of 1
9
9
9 9
9
9 9
999
99
9 9
9
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2025.04.22 12:44:53 -08'00'
Originated: Delivered to:7-Mar-25
Halliburton Alaska Oil and Gas Conservation Comm.
Wireline & Perforating Attn.: Natural Resource Technician
Attn: Fanny Haroun 333 West 7th Avenue, Suite 100
6900 Arctic Blvd. Anchorage, Alaska 99501
Anchorage, Alaska 99518
Office: 907-275-2605
FRS_ANC@halliburton.com
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of the sender above
WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#
1 1A-20 50-029-22112-00 909816971 Kuparuk River Packer Setting Record Field- Final 16-Feb-25 0 1
2 1A-24 50-029-22984-00 909816969 Kuparuk River Multi Finger Caliper Field & Processed 12-Feb-25 0 1
3 1A-24 50-029-22984-00 909816969 Kuparuk River Plug Setting Record Field- Final 15-Feb-25 0 1
4 1C-156 50-029-23750-00 909809782 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 1
5 1E-11 50-029-20787-00 909890720 Kuparuk River Leak Detect Log Field- Final 1-Mar-25 0 1
6 1E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 1-Mar-25 0 1
7 1E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 28-Feb-25 0 1
8 1E-22 50-029-20884-00 909890664 Kuparuk River Leak Detect Log Field- Final 27-Feb-25 0 1
9 1Q-04 50-029-21250-00 909678506 Kuparuk River SBHP Record Field- Final 9-Nov-24 0 1
10 2B-11 50-029-21089-00 909890473 Kuparuk River Packer Setting Record Field- Final 21-Feb-25 0 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
Date:Signed:
Transmittal Date:
T40190
T40191
T40191
T40192
T40193
T40193
T40193
T40194
T40195
T40196
190-162
200-181
223-023
182-051
182-214
184-234
184-035
3/7/2025 Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.03.07 10:25:17 -09'00'
184-035
2B-11 50-029-21089-00 909890473 Kuparuk River Packer Setting Record Field- Final 21-Feb-25 0 1
Originated: Delivered to:9-Dec-24
Alaska Oil & Gas Conservation Commiss 09Dec24-NR
ATTN: Meredith Guhl
333 W. 7th Ave., Suite 100
600 E 57th Place Anchorage, Alaska 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
WELL NAME API #
SERVICE ORDER
#FIELD NAME
SERVICE
DESCRIPTION
DELIVERABLE
DESCRIPTION DATA TYPE DATE LOGGED
1R-03A 50-029-21406-01-00 200-021 Kuparuk River WL IPROF FINAL FIELD 8-Nov-24
3S-718 50-103-20884-00-00 224-034 Kuparuk River WL TTiX PPROF FINAL FIELD 20-Nov-24
2B-11 50-029-21089-00-00 184-035 Kuparuk River WL IPROF FINAL FIELD 22-Nov-24
3S-617 50-103-20864-00-00 223-085 Kuparuk River WL IPROF FINAL FIELD 30-Nov-24
3M-22 50-029-21740-00-00 187-067 Kuparuk River WL LDL FINAL FIELD 2-Dec-24
1J-156 50-029-23311-00-00 206-067 Kuparuk River WL IPROF FINAL FIELD 2-Dec-24
2H-11 50-103-20052-00-00 185-261 Kuparuk River WL IPROF FINAL FIELD 4-Dec-24
Transmittal Receipt
________________________________ X_________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Nraasch@slb.com SLB Auditor -
TRANSMITTAL DATE
TRANSMITTAL #
A Delivery Receipt signature confirms that a package (box, envelope,
etc.) has been received. The package will be handled/delivered per
standard company reception procedures. The package's contents have
not been verified but should be assumed to contain the above noted
media.
# Schlumberger-Private
T39843
T39844
T39845
T39846
T39847
T39848
T39849
2B-11 50-029-21089-00-00 184-035 Kuparuk River WL IPROF FINAL FIELD 22-Nov-24
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.12.10 08:20:31
-09'00'
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 2B-11 (PTD 184-035) IPROF
Date:Wednesday, November 20, 2024 8:15:18 AM
From: Wallace, Chris D (OGC)
Sent: Wednesday, November 20, 2024 8:14 AM
To: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Subject: RE: KRU 2B-11 (PTD 184-035) IPROF
Jaime,
I approve your temporary injection plan with e-line as below.
Thanks and Regards,
Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907)
793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska
Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended
recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure
of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please
delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you,
contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov.
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Tuesday, November 19, 2024 2:37 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Subject: KRU 2B-11 (PTD 184-035) IPROF
Hi Chris,
KRU 2B-11 (PTD 184-035) is being repaired for TxIA in the PBR with a tubing patch. The
tubing patch will create a restriction that limits injection mandrel reconfiguration. Prior
to setting the tubing patch, CPAI desires to gain further injection profile splits. I am
emailing to request permission to put 2B-11 on injection while Eline is onsite. Eline will
manage the IA pressure generated by the known TxIA while on location. The well will not
be on injection prior or after eline departs the location. Please let me know if you have
any questions or disagree with the plan.
Warmest regards,
Jaime Bronga
Well Integrity – CPF2 – ConocoPhillips Alaska
Cell: 907-229-8282
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Patch
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
7676'None
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
(907) 265-1053
Well Interventions Engineer
2B-11
6158' 7128' 5750' 7128' MD
N/A
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
jaime.bronga@conocophillips.com
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
7102' MD and 5732' TVD
7328' MD and 5898' TVD
1936' MD and 1930' TVD
Jaime Bronga
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025655
184-035
P.O. Box 100360, Anchorage, AK 99510 50-029-21089-00-00
Kuparuk River Field Kuparuk River Oil Pool
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Kuparuk River Oil Pool
TVD Burst
7343' MD
MD
116'
2782'
116'
2892'
6146'7659'
16"
9-5/8"
79'
2856'
7261-7287', 7377-7387', 7396-
7422', 7441-7466'
7624'
5849-5868', 5935-5942', 5949-
5969', 5983-6002'
7"
Perforation Depth TVD (ft):
3-1/2"
Packer: Baker FHL Rtvbl Packer
Packer: Baker FB-1 Packer
SSSV: Baker FVL Sfty VLV (Locked out)
Perforation Depth MD (ft):
J-55
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
8/11/2024
By Grace Christianson at 3:52 pm, Aug 01, 2024
Digitally signed by Jaime Bronga
DN: OU=Conoco Phillips Alaska, CN=Jaime
Bronga, E=jaime.bronga@conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.08.01 11:38:07-08'00'
Foxit PDF Editor Version: 13.0.0
Jaime
Bronga
324-449
X
X
A.Dewhurst 05AUG24 DSR-8/12/24
10-404
VTL 8/13/2024*&:
Jessie L. Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2024.08.13 15:02:29
-08'00'08/13/24
RBDMS JSB 081424
Well Work Justi
cation & Objectives:
2B-11 is a water injector that exhibits TxIA while on Seawater injection. Diagnostics identi ed a LLR
of 0.09gpm from T to IA and VIVID log was ran that identi ed a leak in the production packer with a
possible leak path through the PBR. This program will set an expansion patch across the two leak
points and will complete a C sand shut o* prior to setting the patch due to the patch ID restriction.
Risks/Job Concerns:
Patching an injector requires a 10-403 and 10-404
Steps:
DSL
1. Pull Catcher from 7122'rkb.
2. Pull RBP from 7127'rkb.
3. Pull dummy from injection mandrel at 7140' rkb.
4. Set extended packing dummy into injection mandrel at 7140'rkb.
5.Drift and tag with SBHP. Note nature of the tag. Perform SBHP at ~7350' rkb.
6.Perform spinner log with baseline pass down, injection pass up and station stops at 7120' rkb,
7160'rkb to con rm extended packing dummy is holding while injecting seawater at 2 bpm
(equivalent of 3000 bpd).
7. Continue station stops at 7200'rkb, 7230' rkb, 7290' rkb, and 7330'rkb to con rm additional C
sand injection valve dummies are holding.
8. Displace seawater with17 bbls diesel for freeze protect. If leak in C sand is identi ed, stop job for
log processing and plan forward. If no leak, proceed:
9. Set lower packer center element at 7110' rkb.
10. Run TTS into lower packer. CMIT-TxIA with diesel to 2000 psi to con rm packer is set.
10. Set Upper 3-1/2 PIIP, Expansion Joint, Anchor Latch with center element at 7085'rkb.
11. Set TTS into upper packer. MIT-T with diesel to 2000 psi to con rm packer is set.
12. RD. Well integrity engineer will notify operations when it is approved to put the well back on
injection.
DHD:
1. After well is returned to seawater injection, perform MIT-IA to 3000 psi.
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB (Est. 8' of Fill & 197' of Open Perfs) 7,458.0 2B-11 7/26/2019 zembaej
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set DMY 2B-11 5/17/2024 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 ninam
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 37.0 116.0 116.0 65.50 H-40 WELDED
SURFACE 9 5/8 8.92 36.5 2,892.5 2,782.4 36.00 J-55 BTC
PRODUCTION 7 6.28 34.9 7,659.0 6,146.3 26.00 J-55 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
33.6
Set Depth …
7,342.6
Set Depth …
5,909.3
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDABM
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
33.6 33.6 0.16 HANGER 8.000 GRAY TUBING HANGER 3.500
1,935.8 1,930.0 13.74 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE
(LOCKED OUT 8/24/98)
BAKER FVL 2.810
7,044.5 5,689.0 42.84 GAS LIFT 5.312 MMH FMHO Comment: STA 1 MMH FMHO 2.867
7,088.0 5,720.9 42.64 PBR 4.000 BAKER 10 PBR BAKER 3.000
7,102.5 5,731.6 42.57 PACKER 5.968 BAKER FHL RETRIEVABLE
PACKER
BAKER FHL 3.000
7,140.2 5,759.4 42.46 GAS LIFT 5.312 MMH FMHO Comment: STA 2 MMH FMHO 2.867
7,210.2 5,811.1 42.26 GAS LIFT 5.312 MMH FMHO Comment: STA 3 MMH FMHO 2.867
7,248.5 5,839.5 42.18 BLAST JOINT 4.500 BLAST JOINT (1) 2.992
7,279.5 5,862.5 42.12 BLAST RING 4.500 BLAST RING (1) 2.992
7,312.1 5,886.7 42.02 GAS LIFT 5.312 MMH FMHO Comment: STA 4 MMH FMHO 2.867
7,327.1 5,897.8 41.94 LOCATOR 4.500 BAKER LOCATOR SUB w/ 5'
SEALS
BAKER 3.000
7,327.9 5,898.4 41.93 PACKER 5.875 BAKER FB-1 PACKER BAKER FB-1 4.000
7,330.4 5,900.3 41.92 SBE 5.000 BAKER SEAL BORE EXTENSION BAKER 4.000
7,340.6 5,907.9 41.86 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750
7,342.1 5,909.0 41.86 WLEG 4.570 BAKER WIRELINE RE-ENTRY
GUIDE, ELMD 7320' PER SWS
IPROF 2/25/2000
BAKER 2.992
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
7,122.0 5,746.0 42.51 CATCHER 2.79" Catcher w/RBP NO-GO
bottom sub (OAL = 64")
5/11/2024 0.000
7,127.6 5,750.1 42.50 RBP 2.725" PIIP RBP set mid-
element @ 7130' RKB (OAL =
7.22') (4.02' from top of PKR to
EQ piston)
TTS PIIP CPP3
5357/
CPEQ
35015
5/11/2024 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
7,044.5 5,689.0 42.84 1 GAS LIFT DMY BK 1 0.0 5/17/2024 0.000
7,140.2 5,759.4 42.46 2 INJ DMY BK 1 0.0 4/23/2010 0.000
7,210.2 5,811.1 42.26 3 INJ DMY BK 1 0.0 7/31/1991 0.000
7,312.1 5,886.7 42.02 4 INJ DMY BK 1 0.0 7/19/1996 12:30 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,261.0 7,287.0 5,848.8 5,868.0 C-4, UNIT B, 2B-
11
5/10/1984 12.0 IPERF 120 degrees phasing, SOS 5
1/2" Guns
7,377.0 7,387.0 5,935.0 5,942.5 A-3, 2B-11 5/31/2015 6.0 APERF 2.5" DIAMETER, 6 SPF, 60
DEG PHASE, MILLENIUM II
HSC GUN
7,396.0 7,422.0 5,949.2 5,968.7 A-4, 2B-11 7/12/1984 4.0 IPERF 2 shots @ 80 deg., 1 shot @
90 deg., & 1 shot @ 27, DA 2
1/16" Link Kone
7,441.0 7,466.0 5,982.9 6,001.6 A-3, 2B-11 7/12/1984 4.0 IPERF 1 shot @ 90 deg., 1 shot at
270 deg., 2 shots @ 1, DA 2
1/16" Link Kone
2B-11, 8/1/2024 10:40:34 AM
Vertical schematic (actual)
PRODUCTION; 34.9-7,659.0
FLOAT SHOE; 7,657.1-7,659.0
FLOAT COLLAR; 7,568.6-
7,570.2
IPERF; 7,441.0-7,466.0
IPERF; 7,396.0-7,422.0
APERF; 7,377.0-7,387.0
WLEG; 7,342.1
NIPPLE; 7,340.6
SBE; 7,330.4
PACKER; 7,327.9
LOCATOR; 7,327.1
GAS LIFT; 7,312.1
IPERF; 7,261.0-7,287.0
GAS LIFT; 7,210.2
GAS LIFT; 7,140.2
RBP; 7,127.6
CATCHER; 7,122.0
PACKER; 7,102.5
PBR; 7,088.0
GAS LIFT; 7,044.5
SURFACE; 36.5-2,892.5
FLOAT SHOE; 2,890.5-2,892.5
FLOAT COLLAR; 2,810.0-
2,811.7
SAFETY VLV; 1,935.8
CONDUCTOR; 37.0-116.0
HANGER; 36.5-40.8
HANGER; 33.6
KUP INJ
KB-Grd (ft)
42.01
RR Date
3/22/1984
Other Elev…
2B-11
...
TD
Act Btm (ftKB)
7,676.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292108900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
47.62
MD (ftKB)
5,500.00
WELLNAME WELLBORE2B-11
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: LOCKED OUT
Originated: Delivered to:9-Jul-24
Halliburton Alaska Oil and Gas Conservation Comm.
Wireline & Perforating Attn.: Natural Resource Technician
Attn: Fanny Haroun 333 West 7th Avenue, Suite 100
6900 Arctic Blvd. Anchorage, Alaska 99501
Anchorage, Alaska 99518
Office: 907-275-2605
FRS_ANC@halliburton.com
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of the sender above
WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#
1 1H-10 50-029-22346-00 909358839 Kuparuk River Patch Setting Record Field- Final 27-May-24 0 1
2 1H-104 50-029-23610-00 909292908 Kuparuk River Leak Detect Log with ACX Field & Processed 22-Apr-24 0 1
3 1L-06 50-029-21164-00 n/a Kuparuk River Leak Detect Log Field- Final 7-May-24 0 1
4 1L-06 50-029-21164-00 909298478 Kuparuk River Multi Finger Caliper Field & Processed 8-May-24 0 1
5 1L-06 50-029-21164-00 n/a Kuparuk River Plug Setting Record Field- Final 7-May-24 0 1
6 1L-24 50-029-22170-00 909422478 Kuparuk River Multi Finger Caliper Field & Processed 4-Jul-24 0 1
7 1L-24 50-029-22170-00 909422478 Kuparuk River Patch Setting Record Field- Final 6-Jul-24 0 1
8 1R-35 50-029-23050-00 909353301 Kuparuk River Multi Finger Caliper Field & Processed 29-May-24 0 1
9 2A-14 50-103-20040-00 909382630 Kuparuk River Patch Setting Record Field- Final 13-Jun-24 0 1
10 2B-11 50-029-21089-00 n/a Kuparuk River Plug Setting Record Field- Final 11-May-24 0 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
Date:Signed:
Transmittal Date:
T39155
T39156
T39157
T39157
T39157
T39158
T39158
T39159
T39160
T39161
193-030
218-084184-133
191-066201-210
185-145184-035
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.07.10 13:13:09
-08'00'
2B-11 50-029-21089-00 n/a Kuparuk River Plug Setting Record Field- Final 11-May-24 0 1 T39161T39161
185 145184-035
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:NSK DHD Field Supervisor
To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC)
Cc:Well Integrity Specialist CPF1 & CPF3; Well Integrity Specialist CPF2
Subject:10-426 Forms from 5-29-24 and 6-3-24
Date:Tuesday, June 4, 2024 10:19:22 AM
Attachments:image001.png
MIT KRU 2B-11 SI TEST 05-29-24.xlsx
MIT KRU 1E-1,8,15,17 and 22 06-03-24.xlsx
MIT KRU 3B-16 06-03-24.xlsx
MIT KRU 3O-06 06-03-24.xlsx
MIT KRU 3S-617 06-03-24.xlsx
Please see the attached 10-426 form for 2B-11 SI MITIA on 5-29-24 and the 10-426 form’s for
1E-01,08,15 17 & 22, as well as 3B-16, 3O-06 and 3S-617. If you have any questions or
concerns, please let me know
Thanks,
Bruce Richwine/Matt Miller
DHD Field Supervisor
KOC F-wing 2-14
(907) 659-7022 Office
(907) 943-0167 Cell
N2238@COP.com
.58%
37'
Submit to:
OOPERATOR:
FIELDD // UNITT // PAD:
DATE:
OPERATORR REP:
AOGCCC REP:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 1840350 Type Inj N Tubing 001111Type TestP
Packer TVD 5732 BBL Pump 1.8 IA 0 3300 3250 3240 3230 3225 Interval 4
Test psi1500BBL Return OA000000Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes
INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
ConocoPhillips Alaska Inc,
Kuparuk / KRU / 2B Pad
Arend / Casey
05/29/24
Notes:Did not quantify bleed back, U-tubed IA to Tubing for MIT-T post MITIA
Notes:
2B-11
Notes:
Notes:
Notes:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
MMechanicall Integrityy Test
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Form 10-426 (Revised 01/2017)2024-0529_MIT_KRU_2B-11
9
9
9
9
9
999
9
9
-5HJJ
2B-11
9
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: Kuparuk injector 2B-11 (PTD# 184-035) Report of suspected TxIA on seawater diagnostics plan change.
Date:Tuesday, April 23, 2024 1:04:29 PM
Attachments:image001.png
AnnComm Surveillance TIO for 2B-11.pdf
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Tuesday, April 23, 2024 11:03 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF2
<n2549@conocophillips.com>
Subject: Kuparuk injector 2B-11 (PTD# 184-035) Report of suspected TxIA on seawater diagnostics
plan change.
Chris-
Kuparuk injector 2B-11 (PTD #184-035) was reported yesterday for suspected TxIA
communication while on seawater injection. As previously reported, diagnostics were
completed and TxIA integrity were proven while on produced water. CPAI initially intended to
shut in and secure the well prior to performing diagnostics on sea water but after reviewing
previous diagnostics performed on similar seawater failures with produced water integrity,
CPAI now believes it would be beneficial to perform the initial diagnostics while the well is still
on seawater injection to ensure the suspected failure mechanism is still active. Depending on
the results of the initial diagnostics, CPAI submit the proper notifications for continued
injection or repair as required. Please let me know if you have any questions or disagree with
the plan.
Dusty Freeborn
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Monday, April 22, 2024 3:01 PM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF2
<n2549@conocophillips.com>
Subject: Kuparuk injector 2B-11 (PTD# 184-035) Completion of initial diagnostics and 30 day monitor
period
Chris-
Kuparuk injector 2B-11 (PTD #184-035) has returned to seawater injection and is now suspected of
TxIA communication. CPAI previously monitored the well for 30 days on produced water in which
TxIA integrity was proven. The well was swapped back to sea water injection and DHD is now
reporting suspected TxIA communication due to multiple bleeds and recharging IA pressure. CPAI
intends to shut in and secure the well to investigate the failure mechanism. Depending on the
results of the diagnostics the proper paperwork for continued injection or repair will be submitted as
required. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you
have any questions or disagree with the plan.
Dusty Freeborn
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
From: Well Integrity Specialist CPF2 n2549@conocophillips.com
Sent: May 23, 2022 1:36 PM
To: Wallace, Chris D (CED) chris.wallace@alaska.gov
Cc: Well Integrity Specialist CPF2 n2549@conocophillips.com
Subject: Kuparuk injector 2B-11 (PTD# 184-035) Report of multiple bleeds on the IA
Chris-
Kuparuk injector 2B-11 (PTD #184-035) has completed the initial set of diagnostics and 30 day
monitor period. The well passed both T & IC pack off tests and the diagnostic MIT-IA. During the 30
day monitor period the IA showed pressure stabilization once it was WAG’d to produced water.
Because the initial report of IA pressure increase was on while the well was on sea water injection.
CPAI will verify the IA condition when returned to sea water injection and report as needed. For the
time being the well will be returned to normal injection status due to proven IA integrity while on
produced water injection. Attached is the copy of the current 90 day TIO plot and well bore
schematic.
Dusty Freeborn
Wells Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Friday, April 8, 2022 1:36 PM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Subject: Kuparuk injector 2B-11 (PTD# 184-035) Report of multiple bleeds on the IA
Chris-
Kuparuk injector 2B-11 (PTD# 184-035) was reported by operations for multiple bleeds on the IA to
maintain a tubing and IA differential pressure. DHD will conduct an initial set of diagnostic testing
and depending on the results the proper paperwork for continued injection or repair will be
submitted at that time. Please let me know if you have an questions or disagree with the plan.
Attached is a 90 day TIO plot and well bore schematic.
Dusty Freeborn
Wells Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB (Est. 8' of Fill & 197' of Open Perfs) 7,458.0 7/26/2019 2B-11 zembaej
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Updated Tag Depth 7/26/2019 2B-11 zembaej
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
37.0
Set Depth (ftKB)
116.0
Set Depth (TVD) …
116.0
Wt/Len (l…
65.50
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
9 5/8
ID (in)
8.92
Top (ftKB)
36.5
Set Depth (ftKB)
2,892.5
Set Depth (TVD) …
2,782.4
Wt/Len (l…
36.00
Grade
J-55
Top Thread
BTC
Casing Description
PRODUCTION
OD (in)
7
ID (in)
6.28
Top (ftKB)
34.9
Set Depth (ftKB)
7,659.0
Set Depth (TVD) …
6,146.3
Wt/Len (l…
26.00
Grade
J-55
Top Thread
BTC
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
33.6
Set Depth (ft…
7,342.6
Set Depth (TVD) (…
5,909.3
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDABM
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
33.6 33.6 0.16 HANGER GRAY TUBING HANGER 3.500
1,935.8 1,930.0 13.74 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 8/24/98) 2.810
7,088.0 5,720.9 42.64 PBR BAKER 10 PBR 3.000
7,102.5 5,731.6 42.57 PACKER BAKER FHL RETRIEVABLE PACKER 3.000
7,248.5 5,839.5 42.18 BLAST JOINT BLAST JOINT (1) 2.992
7,279.5 5,862.5 42.12 BLAST RING BLAST RING (1) 2.992
7,327.1 5,897.8 41.94 LOCATOR BAKER LOCATOR SUB w/ 5' SEALS 3.000
7,327.9 5,898.4 41.93 PACKER BAKER FB-1 PACKER 4.000
7,330.4 5,900.3 41.92 SBE BAKER SEAL BORE EXTENSION 4.000
7,340.6 5,907.9 41.86 NIPPLE CAMCO D NIPPLE NO GO 2.750
7,342.1 5,909.0 41.86 WLEG BAKER WIRELINE RE-ENTRY GUIDE, ELMD 7320' PER SWS
IPROF 2/25/2000
2.992
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
7,261.0 7,287.0 5,848.8 5,868.0 C-4, UNIT B, 2B
-11
5/10/1984 12.0 IPERF 120 degrees phasing, SOS 5
1/2" Guns
7,377.0 7,387.0 5,935.0 5,942.5 A-3, 2B-11 5/31/2015 6.0 APERF 2.5" DIAMETER, 6 SPF, 60
DEG PHASE, MILLENIUM II
HSC GUN
7,396.0 7,422.0 5,949.2 5,968.7 A-4, 2B-11 7/12/1984 4.0 IPERF 2 shots @ 80 deg., 1 shot @
90 deg., & 1 shot @ 27, DA
2 1/16" Link Kone
7,441.0 7,466.0 5,982.9 6,001.6 A-3, 2B-11 7/12/1984 4.0 IPERF 1 shot @ 90 deg., 1 shot at
270 deg., 2 shots @ 1, DA 2
1/16" Link Kone
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 7,044.5 5,689.0 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 11/6/1988
2 7,140.2 5,759.4 MMH FMHO 1 INJ DMY BK 0.000 0.0 4/23/2010
3 7,210.2 5,811.1 MMH FMHO 1 INJ DMY BK 0.000 0.0 7/31/1991
4 7,312.1 5,886.7 MMH FMHO 1 INJ DMY BK 0.000 0.0 7/19/1996 12:30
Notes: General & Safety
End Date Annotation
NOTE: View Schematic w/ Alaska Schematic9.0
Comment
SSSV: LOCKED OUT
2B-11, 7/27/2019 7:10:17 AM
Vertical schematic (actual)
PRODUCTION; 34.9-7,659.0
IPERF; 7,441.0-7,466.0
IPERF; 7,396.0-7,422.0
APERF; 7,377.0-7,387.0
WLEG; 7,342.1
NIPPLE; 7,340.6
SBE; 7,330.4
PACKER; 7,327.9
LOCATOR; 7,327.1
GAS LIFT; 7,312.1
IPERF; 7,261.0-7,287.0
GAS LIFT; 7,210.2
GAS LIFT; 7,140.2
PACKER; 7,102.5
PBR; 7,088.0
GAS LIFT; 7,044.5
SURFACE; 36.5-2,892.5
SAFETY VLV; 1,935.8
CONDUCTOR; 37.0-116.0
HANGER; 33.6
KUP INJ
KB-Grd (ft)
42.01
Rig Release Date
3/22/1984
Annotation
Last WO:
End Date
2B-11
H2S (ppm) Date...
TD
Act Btm (ftKB)
7,676.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292108900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
47.62
MD (ftKB)
5,500.00
WELLNAME WELLBORE2B-11
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: Kuparuk injector 2B-11 (PTD# 184-035) Completion of initial diagnostics and 30 day monitor period
Date:Monday, April 22, 2024 3:12:19 PM
Attachments:image001.png
AnnComm Surveillance TIO for 2B-11.pdf
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Monday, April 22, 2024 3:01 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF2
<n2549@conocophillips.com>
Subject: Kuparuk injector 2B-11 (PTD# 184-035) Completion of initial diagnostics and 30 day monitor
period
Chris-
Kuparuk injector 2B-11 (PTD #184-035) has returned to seawater injection and is now suspected of
TxIA communication. CPAI previously monitored the well for 30 days on produced water in which
TxIA integrity was proven. The well was swapped back to sea water injection and DHD is now
reporting suspected TxIA communication due to multiple bleeds and recharging IA pressure. CPAI
intends to shut in and secure the well to investigate the failure mechanism. Depending on the
results of the diagnostics the proper paperwork for continued injection or repair will be submitted as
required. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you
have any questions or disagree with the plan.
Dusty Freeborn
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
From: Well Integrity Specialist CPF2 n2549@conocophillips.com
Sent: May 23, 2022 1:36 PM
To: Wallace, Chris D (CED) chris.wallace@alaska.gov
Cc: Well Integrity Specialist CPF2 n2549@conocophillips.com
Subject: Kuparuk injector 2B-11 (PTD# 184-035) Report of multiple bleeds on the IA
Chris-
Kuparuk injector 2B-11 (PTD #184-035) has completed the initial set of diagnostics and 30 day
monitor period. The well passed both T & IC pack off tests and the diagnostic MIT-IA. During the 30
day monitor period the IA showed pressure stabilization once it was WAG’d to produced water.
Because the initial report of IA pressure increase was on while the well was on sea water injection.
CPAI will verify the IA condition when returned to sea water injection and report as needed. For the
time being the well will be returned to normal injection status due to proven IA integrity while on
produced water injection. Attached is the copy of the current 90 day TIO plot and well bore
schematic.
Dusty Freeborn
Wells Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Friday, April 8, 2022 1:36 PM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Subject: Kuparuk injector 2B-11 (PTD# 184-035) Report of multiple bleeds on the IA
Chris-
Kuparuk injector 2B-11 (PTD# 184-035) was reported by operations for multiple bleeds on the IA to
maintain a tubing and IA differential pressure. DHD will conduct an initial set of diagnostic testing
and depending on the results the proper paperwork for continued injection or repair will be
submitted at that time. Please let me know if you have an questions or disagree with the plan.
Attached is a 90 day TIO plot and well bore schematic.
Dusty Freeborn
Wells Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB (Est. 8' of Fill & 197' of Open Perfs) 7,458.0 7/26/2019 2B-11 zembaej
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Updated Tag Depth 7/26/2019 2B-11 zembaej
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
37.0
Set Depth (ftKB)
116.0
Set Depth (TVD) …
116.0
Wt/Len (l…
65.50
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
9 5/8
ID (in)
8.92
Top (ftKB)
36.5
Set Depth (ftKB)
2,892.5
Set Depth (TVD) …
2,782.4
Wt/Len (l…
36.00
Grade
J-55
Top Thread
BTC
Casing Description
PRODUCTION
OD (in)
7
ID (in)
6.28
Top (ftKB)
34.9
Set Depth (ftKB)
7,659.0
Set Depth (TVD) …
6,146.3
Wt/Len (l…
26.00
Grade
J-55
Top Thread
BTC
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
33.6
Set Depth (ft…
7,342.6
Set Depth (TVD) (…
5,909.3
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDABM
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
33.6 33.6 0.16 HANGER GRAY TUBING HANGER 3.500
1,935.8 1,930.0 13.74 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 8/24/98) 2.810
7,088.0 5,720.9 42.64 PBR BAKER 10 PBR 3.000
7,102.5 5,731.6 42.57 PACKER BAKER FHL RETRIEVABLE PACKER 3.000
7,248.5 5,839.5 42.18 BLAST JOINT BLAST JOINT (1) 2.992
7,279.5 5,862.5 42.12 BLAST RING BLAST RING (1) 2.992
7,327.1 5,897.8 41.94 LOCATOR BAKER LOCATOR SUB w/ 5' SEALS 3.000
7,327.9 5,898.4 41.93 PACKER BAKER FB-1 PACKER 4.000
7,330.4 5,900.3 41.92 SBE BAKER SEAL BORE EXTENSION 4.000
7,340.6 5,907.9 41.86 NIPPLE CAMCO D NIPPLE NO GO 2.750
7,342.1 5,909.0 41.86 WLEG BAKER WIRELINE RE-ENTRY GUIDE, ELMD 7320' PER SWS
IPROF 2/25/2000
2.992
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
7,261.0 7,287.0 5,848.8 5,868.0 C-4, UNIT B, 2B
-11
5/10/1984 12.0 IPERF 120 degrees phasing, SOS 5
1/2" Guns
7,377.0 7,387.0 5,935.0 5,942.5 A-3, 2B-11 5/31/2015 6.0 APERF 2.5" DIAMETER, 6 SPF, 60
DEG PHASE, MILLENIUM II
HSC GUN
7,396.0 7,422.0 5,949.2 5,968.7 A-4, 2B-11 7/12/1984 4.0 IPERF 2 shots @ 80 deg., 1 shot @
90 deg., & 1 shot @ 27, DA
2 1/16" Link Kone
7,441.0 7,466.0 5,982.9 6,001.6 A-3, 2B-11 7/12/1984 4.0 IPERF 1 shot @ 90 deg., 1 shot at
270 deg., 2 shots @ 1, DA 2
1/16" Link Kone
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 7,044.5 5,689.0 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 11/6/1988
2 7,140.2 5,759.4 MMH FMHO 1 INJ DMY BK 0.000 0.0 4/23/2010
3 7,210.2 5,811.1 MMH FMHO 1 INJ DMY BK 0.000 0.0 7/31/1991
4 7,312.1 5,886.7 MMH FMHO 1 INJ DMY BK 0.000 0.0 7/19/1996 12:30
Notes: General & Safety
End Date Annotation
NOTE: View Schematic w/ Alaska Schematic9.0
Comment
SSSV: LOCKED OUT
2B-11, 7/27/2019 7:10:17 AM
Vertical schematic (actual)
PRODUCTION; 34.9-7,659.0
IPERF; 7,441.0-7,466.0
IPERF; 7,396.0-7,422.0
APERF; 7,377.0-7,387.0
WLEG; 7,342.1
NIPPLE; 7,340.6
SBE; 7,330.4
PACKER; 7,327.9
LOCATOR; 7,327.1
GAS LIFT; 7,312.1
IPERF; 7,261.0-7,287.0
GAS LIFT; 7,210.2
GAS LIFT; 7,140.2
PACKER; 7,102.5
PBR; 7,088.0
GAS LIFT; 7,044.5
SURFACE; 36.5-2,892.5
SAFETY VLV; 1,935.8
CONDUCTOR; 37.0-116.0
HANGER; 33.6
KUP INJ
KB-Grd (ft)
42.01
Rig Release Date
3/22/1984
Annotation
Last WO:
End Date
2B-11
H2S (ppm) Date...
TD
Act Btm (ftKB)
7,676.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292108900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
47.62
MD (ftKB)
5,500.00
WELLNAME WELLBORE2B-11
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: Kuparuk injector 2B-11 (PTD# 184-035) Completion of initial diagnostics and 30 day monitor period
Date:Wednesday, May 25, 2022 9:23:42 AM
Attachments:image001.png
AnnComm Surveillance TIO for 2B-11.pdf
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Monday, May 23, 2022 8:25 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Subject: Kuparuk injector 2B-11 (PTD# 184-035) Completion of initial diagnostics and 30 day monitor
period
Chris-
Kuparuk injector 2B-11 (PTD #184-035) has completed the initial set of diagnostics and 30 day
monitor period. The well passed both T & IC pack off tests and the diagnostic MIT-IA. During the 30
day monitor period the IA showed pressure stabilization once it was WAG’d to produced water.
Because the initial report of IA pressure increase was on while the well was on sea water injection.
CPAI will verify the IA condition when returned to sea water injection and report as needed. For the
time being the well will be returned to normal injection status due to proven IA integrity while on
produced water injection. Attached is the copy of the current 90 day TIO plot and well bore
schematic.
Dusty Freeborn
Wells Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Friday, April 8, 2022 1:36 PM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Subject: Kuparuk injector 2B-11 (PTD# 184-035) Report of multiple bleeds on the IA
Chris-
Kuparuk injector 2B-11 (PTD# 184-035) was reported by operations for multiple bleeds on the IA to
maintain a tubing and IA differential pressure. DHD will conduct an initial set of diagnostic testing
and depending on the results the proper paperwork for continued injection or repair will be
submitted at that time. Please let me know if you have an questions or disagree with the plan.
Attached is a 90 day TIO plot and well bore schematic.
Dusty Freeborn
Wells Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB (Est. 8' of Fill & 197' of Open Perfs) 7,458.0 7/26/2019 2B-11 zembaej
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Updated Tag Depth 7/26/2019 2B-11 zembaej
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
37.0
Set Depth (ftKB)
116.0
Set Depth (TVD) …
116.0
Wt/Len (l…
65.50
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
9 5/8
ID (in)
8.92
Top (ftKB)
36.5
Set Depth (ftKB)
2,892.5
Set Depth (TVD) …
2,782.4
Wt/Len (l…
36.00
Grade
J-55
Top Thread
BTC
Casing Description
PRODUCTION
OD (in)
7
ID (in)
6.28
Top (ftKB)
34.9
Set Depth (ftKB)
7,659.0
Set Depth (TVD) …
6,146.3
Wt/Len (l…
26.00
Grade
J-55
Top Thread
BTC
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
33.6
Set Depth (ft…
7,342.6
Set Depth (TVD) (…
5,909.3
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDABM
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
33.6 33.6 0.16 HANGER GRAY TUBING HANGER 3.500
1,935.8 1,930.0 13.74 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 8/24/98) 2.810
7,088.0 5,720.9 42.64 PBR BAKER 10 PBR 3.000
7,102.5 5,731.6 42.57 PACKER BAKER FHL RETRIEVABLE PACKER 3.000
7,248.5 5,839.5 42.18 BLAST JOINT BLAST JOINT (1) 2.992
7,279.5 5,862.5 42.12 BLAST RING BLAST RING (1) 2.992
7,327.1 5,897.8 41.94 LOCATOR BAKER LOCATOR SUB w/ 5' SEALS 3.000
7,327.9 5,898.4 41.93 PACKER BAKER FB-1 PACKER 4.000
7,330.4 5,900.3 41.92 SBE BAKER SEAL BORE EXTENSION 4.000
7,340.6 5,907.9 41.86 NIPPLE CAMCO D NIPPLE NO GO 2.750
7,342.1 5,909.0 41.86 WLEG BAKER WIRELINE RE-ENTRY GUIDE, ELMD 7320' PER SWS
IPROF 2/25/2000
2.992
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
7,261.0 7,287.0 5,848.8 5,868.0 C-4, UNIT B, 2B
-11
5/10/1984 12.0 IPERF 120 degrees phasing, SOS 5
1/2" Guns
7,377.0 7,387.0 5,935.0 5,942.5 A-3, 2B-11 5/31/2015 6.0 APERF 2.5" DIAMETER, 6 SPF, 60
DEG PHASE, MILLENIUM II
HSC GUN
7,396.0 7,422.0 5,949.2 5,968.7 A-4, 2B-11 7/12/1984 4.0 IPERF 2 shots @ 80 deg., 1 shot @
90 deg., & 1 shot @ 27, DA
2 1/16" Link Kone
7,441.0 7,466.0 5,982.9 6,001.6 A-3, 2B-11 7/12/1984 4.0 IPERF 1 shot @ 90 deg., 1 shot at
270 deg., 2 shots @ 1, DA 2
1/16" Link Kone
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 7,044.5 5,689.0 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 11/6/1988
2 7,140.2 5,759.4 MMH FMHO 1 INJ DMY BK 0.000 0.0 4/23/2010
3 7,210.2 5,811.1 MMH FMHO 1 INJ DMY BK 0.000 0.0 7/31/1991
4 7,312.1 5,886.7 MMH FMHO 1 INJ DMY BK 0.000 0.0 7/19/1996 12:30
Notes: General & Safety
End Date Annotation
NOTE: View Schematic w/ Alaska Schematic9.0
Comment
SSSV: LOCKED OUT
2B-11, 7/27/2019 7:10:17 AM
Vertical schematic (actual)
PRODUCTION; 34.9-7,659.0
IPERF; 7,441.0-7,466.0
IPERF; 7,396.0-7,422.0
APERF; 7,377.0-7,387.0
WLEG; 7,342.1
NIPPLE; 7,340.6
SBE; 7,330.4
PACKER; 7,327.9
LOCATOR; 7,327.1
GAS LIFT; 7,312.1
IPERF; 7,261.0-7,287.0
GAS LIFT; 7,210.2
GAS LIFT; 7,140.2
PACKER; 7,102.5
PBR; 7,088.0
GAS LIFT; 7,044.5
SURFACE; 36.5-2,892.5
SAFETY VLV; 1,935.8
CONDUCTOR; 37.0-116.0
HANGER; 33.6
KUP INJ
KB-Grd (ft)
42.01
Rig Release Date
3/22/1984
Annotation
Last WO:
End Date
2B-11
H2S (ppm) Date...
TD
Act Btm (ftKB)
7,676.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292108900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
47.62
MD (ftKB)
5,500.00
WELLNAME WELLBORE2B-11
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: Kuparuk injector 2B-11 (PTD# 184-035) Report of multiple bleeds on the IA
Date:Friday, April 15, 2022 3:17:35 PM
Attachments:image001.png
AnnComm Surveillance TIO for 2B-11.pdf
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Friday, April 8, 2022 1:36 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Subject: Kuparuk injector 2B-11 (PTD# 184-035) Report of multiple bleeds on the IA
Chris-
Kuparuk injector 2B-11 (PTD# 184-035) was reported by operations for multiple bleeds on the IA to
maintain a tubing and IA differential pressure. DHD will conduct an initial set of diagnostic testing
and depending on the results the proper paperwork for continued injection or repair will be
submitted at that time. Please let me know if you have an questions or disagree with the plan.
Attached is a 90 day TIO plot and well bore schematic.
Dusty Freeborn
Wells Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB (Est. 8' of Fill & 197' of Open Perfs) 7,458.0 7/26/2019 2B-11 zembaej
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Updated Tag Depth 7/26/2019 2B-11 zembaej
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
37.0
Set Depth (ftKB)
116.0
Set Depth (TVD) …
116.0
Wt/Len (l…
65.50
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
9 5/8
ID (in)
8.92
Top (ftKB)
36.5
Set Depth (ftKB)
2,892.5
Set Depth (TVD) …
2,782.4
Wt/Len (l…
36.00
Grade
J-55
Top Thread
BTC
Casing Description
PRODUCTION
OD (in)
7
ID (in)
6.28
Top (ftKB)
34.9
Set Depth (ftKB)
7,659.0
Set Depth (TVD) …
6,146.3
Wt/Len (l…
26.00
Grade
J-55
Top Thread
BTC
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
33.6
Set Depth (ft…
7,342.6
Set Depth (TVD) (…
5,909.3
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDABM
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
33.6 33.6 0.16 HANGER GRAY TUBING HANGER 3.500
1,935.8 1,930.0 13.74 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 8/24/98) 2.810
7,088.0 5,720.9 42.64 PBR BAKER 10 PBR 3.000
7,102.5 5,731.6 42.57 PACKER BAKER FHL RETRIEVABLE PACKER 3.000
7,248.5 5,839.5 42.18 BLAST JOINT BLAST JOINT (1) 2.992
7,279.5 5,862.5 42.12 BLAST RING BLAST RING (1) 2.992
7,327.1 5,897.8 41.94 LOCATOR BAKER LOCATOR SUB w/ 5' SEALS 3.000
7,327.9 5,898.4 41.93 PACKER BAKER FB-1 PACKER 4.000
7,330.4 5,900.3 41.92 SBE BAKER SEAL BORE EXTENSION 4.000
7,340.6 5,907.9 41.86 NIPPLE CAMCO D NIPPLE NO GO 2.750
7,342.1 5,909.0 41.86 WLEG BAKER WIRELINE RE-ENTRY GUIDE, ELMD 7320' PER SWS
IPROF 2/25/2000
2.992
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
7,261.0 7,287.0 5,848.8 5,868.0 C-4, UNIT B, 2B
-11
5/10/1984 12.0 IPERF 120 degrees phasing, SOS 5
1/2" Guns
7,377.0 7,387.0 5,935.0 5,942.5 A-3, 2B-11 5/31/2015 6.0 APERF 2.5" DIAMETER, 6 SPF, 60
DEG PHASE, MILLENIUM II
HSC GUN
7,396.0 7,422.0 5,949.2 5,968.7 A-4, 2B-11 7/12/1984 4.0 IPERF 2 shots @ 80 deg., 1 shot @
90 deg., & 1 shot @ 27, DA
2 1/16" Link Kone
7,441.0 7,466.0 5,982.9 6,001.6 A-3, 2B-11 7/12/1984 4.0 IPERF 1 shot @ 90 deg., 1 shot at
270 deg., 2 shots @ 1, DA 2
1/16" Link Kone
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 7,044.5 5,689.0 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 11/6/1988
2 7,140.2 5,759.4 MMH FMHO 1 INJ DMY BK 0.000 0.0 4/23/2010
3 7,210.2 5,811.1 MMH FMHO 1 INJ DMY BK 0.000 0.0 7/31/1991
4 7,312.1 5,886.7 MMH FMHO 1 INJ DMY BK 0.000 0.0 7/19/1996 12:30
Notes: General & Safety
End Date Annotation
NOTE: View Schematic w/ Alaska Schematic9.0
Comment
SSSV: LOCKED OUT
2B-11, 7/27/2019 7:10:17 AM
Vertical schematic (actual)
PRODUCTION; 34.9-7,659.0
IPERF; 7,441.0-7,466.0
IPERF; 7,396.0-7,422.0
APERF; 7,377.0-7,387.0
WLEG; 7,342.1
NIPPLE; 7,340.6
SBE; 7,330.4
PACKER; 7,327.9
LOCATOR; 7,327.1
GAS LIFT; 7,312.1
IPERF; 7,261.0-7,287.0
GAS LIFT; 7,210.2
GAS LIFT; 7,140.2
PACKER; 7,102.5
PBR; 7,088.0
GAS LIFT; 7,044.5
SURFACE; 36.5-2,892.5
SAFETY VLV; 1,935.8
CONDUCTOR; 37.0-116.0
HANGER; 33.6
KUP INJ
KB-Grd (ft)
42.01
Rig Release Date
3/22/1984
Annotation
Last WO:
End Date
2B-11
H2S (ppm) Date...
TD
Act Btm (ftKB)
7,676.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292108900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
47.62
MD (ftKB)
5,500.00
WELLNAME WELLBORE2B-11
MEMORANDUM
TO: Jim Regg���
P.I. Supervisor
FROM: Bob Noble
Petroleum Inspector
Well Name KUPARUK RIV UNIT 213-11
Insp Num: mitRCN220206101511
Rel Insp Num:
NON -CONFIDENTIAL
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Monday, February 14, 2022
SUBJECT: Mechanical Integrity Tests
ConocoPhillips Alaska, tnc.
2B-11
KUPARUK RIV UNrr 213-11
Src: Inspector
Reviewed By
P.I. Supry �3-
Comm
API Well Number 50-029-21089-00-00 Inspector Name: Bob Noble
Permit Number: 184-035-0 Inspection Date: 2/5/2022
Notes:
Monday, February 14, 2022 Page 1 of I
Packer
Depth Pretest
Initial 15 Min
30 Min 45 Min 60 Min
Well 2B-11
-
Type In W TVD
Type
Tubing
1580
1580
1580
PTD 1840350
Test I SPT Nest SI
YP P
1500 "
575
2300 2190 -
2175 �
-
20
20
BBL Pumped:
2 BBL Returned:2
OA
zo
zo
Interval
4YRTST PIF
P CJI
Notes:
Monday, February 14, 2022 Page 1 of I
• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg (Jet%tom DATE: Tuesday,November 15,2016
�' 1(
P.I.Supervisor I ( t SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2B-I1
FROM: Brian Bixby KUPARUK RIV UNIT 2B-11
Petroleum Inspector
Src: Inspector
Reviewed By: nn
P.I.Supry �J(`
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 2B-11 API Well Number 50-029-21089-00-00 Inspector Name: Brian Bixby
Permit Number: 184-035-0 Inspection Date: 11/13/2016
Insp Num: mitBDB161113152450
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 2B-11 Type Inj W TVD 5731 - Tubing l 960 - 960 • 960 - 960
PTD 1840350 - Type Test SPT Test psi 1500 IA I 450 1800 1750 - 1735 - I
Interval 4YRTST P(F ; P ✓ OA 270 - 280 280 280 -
Notes: 1.1 BBLS Diesel to fill IA.Bled back 1.5 BBLS
sumo APR .U
Tuesday,November 15,2016 Page 1 of 1
• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg ���� I l3 j(� DATE: Wednesday,May 04,2016
P.I.Supervisor � ' ('1 SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2B-11
FROM: Chuck Scheve KUPARUK RIV UNIT 2B-11
Petroleum Inspector
Src: Inspector
Reviewed B,
P.I.Supry -J 60---
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 2B-11 API Well Number 50-029-21089-00-00 Inspector Name: Chuck Scheve
Permit Number: 184-035-0 Inspection Date: 5/1/2016
Insp Num: mitCS160502124317
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well' 2B-11 . Type Inj N-TVD 5731 - Tubing 1050 . 1050 _ 1 1050 - 1050 -
PTD 1840350 - !Type Test SPT;Test psi 1500 - IA I 450 2040 - 1950- 1930 -
Interval{ '1tTST P/F j P ' OA 170 170 - 170 i 170-
Notes:
SCANNED SEP 2 7 2016
Wednesday,May 04,2016 Page 1 of 1
STATE OF ALASKA
AL,. _A OIL AND GAS CONSERVATION CONI, .,SION
REPORT OF SUNDRY WELL OPERATIONS
1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r
Performed Suspend r Perforate p Other Stimulate
r Alter Casing I— Change Approved Program r
Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: r-
2
2 Operator Name: 4.Well Class Before Work 5 Permit to Drill Number
ConocoPhillips Alaska, Inc. Development r Exploratory r 184-035
3.Address. 6 API Number:
P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21089-00
7.Property Designation(Lease Number): 8 Well Name and Number:
ADL 25655 KRU 2B-11
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):
none Kuparuk River Field/Kuparuk River Oil Pool
11 Present Well Condition Summary:
Total Depth measured 7676 feet Plugs(measured) None
true vertical 6159 feet Junk(measured) None
Effective Depth measured 7569 feet Packer(measured) 7103, 7328
true vertical 6078 feet (true vertical) 5732, 5898
Casing Length Size MD ND Burst Collapse
CONDUCTOR 79 16 116 116
SURFACE 2856 9.625 2893 2782
PRODUCTION 7624 7 7659 6146
SCANNED I, 1 2 01-': r: c.
JUN 2 2 'tl4'-
Perforation depth: Measured depth: 7261-7287, 7377-7387, 7396-7422, 7441-7466
True Vertical Depth: 5849-5868, 5935-5943, 5949-5969, 5983-6002 .i -` .'
Tubing(size,grade,MD,and TVD) 3.5,J-55, 7343 MD, 5909 TVD
Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL RETRIEVABLE PACKER @ 7103 MD and 5732 TVD
PACKER-BAKER FB-1 PACKER @ 7328 MD and 5898 TVD
SAFETY VLV-BAKER FVL SAFETY VALVE(LOCKED OUT 8/24/98)@ 1936 MD and 1930 TVD
12.Stimulation or cement squeeze summary:
Intervals treated(measured): no stimulation or cement squeeze during this operation
Treatment descriptions including volumes used and final pressure:
13 Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 3698
Subsequent to operation shut-in
14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15 Well Class after work:
Daily Report of Well Operations p Exploratory r Development r Service Fi Stratigraphic r
Copies of Logs and Surveys Run r 16.Well Status after work Oil r Gas r— WDSPL r
Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ P. WAG r GINJ r SUSP r SPLUG r
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt.
none
Contact John Peirce @ 265-6471 Email John.W.Peirce(a�conocophillips.com
Printed Name John Peirce Title Sr. Wells Engineer
Signature Zte......tt-lif? : Phone:265-6471 Date l0 j /i� i�
_ RBDMS ."."_ - 1 2015
Form 10-404 Revised 5/2015 Submit Original Only
')R-11 WELL WORK SUMMARY
DATE ' SUMMARY
5/11/2015 TAGGED @ 7515' SLM EST (49' RATHOLE); DRIFT W/ 2.50" SPENT DMY GUN
TO SAME. READY FOR E-LINE (PERF).
5/31/2015 PERFORATED THE A SAND AT A DEPTH INTERVAL OF 7377'TO 7387' USING A
10', 2.5" DIAMETER, 6SPF, 60 DEG PHASING. CORRELATED TO SLB ACOUSTIC
CEMENT BOND LOG DATED 10-APR-1984 USING GAMMA RAY. CCL TO TOP
SHOT 7.5'. CCL STOP DEPTH AT 7369.5'.
KUP INJ 2B-11
ConocoPhillipsWell Attributes Max Angle&MD TD
Alaska,!M. Wellbore APUUWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(kKB)
torax'd'hiIiipc 500292108900 KUPARUK RIVER UNIT INJ 47.62 5,500.00 7,676.0
... Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date
2B-11,6/1/20152:07:08 PM SSSV:LOCKED OUT Last WO: 42.01 3/22/1984
Vertical schematic(I.uai)
'Annotation Depth(kKB) End Date Annotation Last Mod By End Date
Last Tag:SLM 7,515.0 5/11/2015 Rev Reason:TAG,PERFORATIONS hipshkf 6/1/2015
--- t=. 1r
li I Casing Strings
1 I Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)...WtlLen(I...Grade Top Thread
BANGER;336 ;,1. CONDUCTOR 16 15.062 37.0 116.0 116.0 65.50 H-40 WELDED
Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)...Wt/Len(i...Grade Top Thread
r'If SURFACE 9 5/8 8.921 36.5 2,892.5 2,782.4 36.00 J-55 BTC
f 0 Casing Description OD(In) ID(In) Top(kKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread
PRODUCTION 7 6.276 34.9 7,659.0 6,146.3 26.00 2-55 BTC
Tubing Strings
1.,„,„,,,,,,,,„uu,u,,,,,,u,uu,.u„,,,u,ua4wu coca.Tubing Description 'String Ma...IID(in) 'Top(f0KB) I Set Depth(ft..'Set Depth)TVD)I...IWt(1h/ft) 'Grade 'Top Connection
TUBING 31/2 2.992 33.6 7,342.6 5,909.3 9.30 J-55 EUE8RDABM
Completion Details
Nominal ID
Top(kKB) Top(ND)(kKB) Top Incl("I item Des Com tin)
33.6 33.6 0.16 HANGER GRAY TUBING HANGER 3.500
M,CONDUCTOR;37.0-116.0- '
1,935.8 1,930.0 13.74 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 8/24/98) 2.810
7,088.0 5,720.9 42.64 PBR BAKER 10 PBR 3.000
7,102.5 5,731.6 42.57 PACKER BAKER FHL RETRIEVABLE PACKER 3.000
SAFETY VLV;1,9358 ..IP 4 7,248.5 5,839.5 42.18 BLAST JOINT BLAST JOINT(1) 2.992
7,279.5 5,862.5 42.12 BLAST RING BLAST RING(1) 2.992
7,327.1 5,897.8 41.94 LOCATOR BAKER LOCATOR SUB w/5'SEALS 3.000
7,327.9 5,898.4° 41.93 PACKER BAKER FB-1 PACKER 4.000
7,330.4 5,900.3 41.92 SBE BAKER SEAL BORE EXTENSION 4.000
7,340.6 5,907.9 41.86 NIPPLE CAMCO D NIPPLE NO GO 2.750
7,342.1 5,909.0 41.86 WLEG BAKER WIRELINE RE-ENTRY GUIDE,ELMD 7320'PER 2.992
SWS PROF 2/25/2000
SURFACE;36.5-2,892.5--
Perforations&Slots
Il
Shot
GAS LIFT;7,044.5 Dena
Top(ND) Btm(ND) (shot&t
Top(kKB) Btm(kKB) OMB) (EKE) Zone Date t) Type Com
7,261.0 7,287.0 5,848.8 5,868.0 C-4,UNIT B, 5/10/1984 12.0 IPERF 120 degrees phasing,
2B-11 SOS 5 1/2"Guns
7,377.0 7,387.0 5,935.0 5,942.5 A-3,28-11 5/31/2015 6.0 APERF 2.5"DIAMETER,6 SPF,
PBR;7,088.0 --- 60 DEG PHASE,
INN II HSC
PACKER;7,102.5 n. GUN
" r.
7,396.0 7,422.0 5,949.2 5,968.7 A-4,2B-11 7/12/1984 4.0 IPERF 2 shots @ 80 deg.,1
shot @ 90 deg.,8 1 shot
@ 27,DA 2 1/16"Link
GAS LIFT;7,140.2 - Kone
II 7,441.0 7,466.0 5,982.9 6,001.6 A-3,2B-11 7/12/1984 4.0 IPERF 1 shot @ 90 deg.,1 shot
at 270 deg.,2 shots @ 1,
GAS LIFT;7.2162 a DA 2 1/16"Link Kone
IMandrel Inserts
st
.ii
-' on Top(TVD) Valve Latch Port Size TRO Run
N Top(kKB) (kKB) Make Model OD(In) Sere Type Type (in) (psi) Run Date Com
IPERF;7,261.0-7,287.091 7,044.5 5,689.0 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 11/6/1988
2 7,140.2 5,759.4MMH FMHO 1INJ DMY BK 0.000 0.0 4/23/2010
I3 7,210.2 5,811.1 MMH FMHO 1 INJ DMY 'BK 0.000 0.0 7/31/1991
4 7,312.1 5,886.7 MMH FMHO -1 INJ DMY BK 0.000 0.0 7/19/1996 12:30
I Notes:General&Safety
End Date Annotation
NOTE:View Schematic w/Alaska Schematic9.0
GAS LIFT;7,312.1
LOCATOR;7,327.1 ,
PACKER;7,327.9 _, ca
SBE;7,330.4
NIPPLE;7.340.6 7 F
WLEG;7,342.1
APERF;7,377.0-7,387.0-.
(PERF;7,396.0'7.422.0 -
(PERF;7,441 0-7,466.0-
PRODUCTION.34.9-7,659.0 •
25°l(0`:v_
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm. June 17, 2015
Attn.: Makana Bender
333 West 7th Avenue, Suite 100 DATA LOGGED
-Z iq/2015
Anchorage, Alaska 99501 E C E r t,E K BENDER
JUN 19 2U1L
RE: Perforation Record: 2B-11
Run Date: 5/31/2015
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
2B-11
Digital Data in LAS format, Digital Log Image file 1 CD Rom
50-029-21089-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Fanny Sari
6900 Arctic Blvd.
Anchorage, Alaska 99518 BANNED It
Office: 907-275-2605
Fax: 907-273-3535
FRS_ANC@halliburton.com
Date: Signed: / ' .41241~-,L1
Z.5515
WELL LOG TRANSMITTAL DATA LOGGED
/252015
K BENDER
To: Alaska Oil and Gas Conservation Comm. March 6, 2015
Attn.: Makana Bender
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501 RECEIVED
MAR 24 ?015
RE: Injection Profile : 2B-11 AOGCC
Run Date: 2/18/2015
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
2B-11
Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom
50-029-21089-00
Injection Profile Log 1 Color Log
50-029-21089-00
SCANNED
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Fanny Sari
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-275-2605
Fax: 907-273-3535
FRS_ANC@halliburton.com
Date: Signed: 117) s e € t
ge Project Well History File Page
XHVZE
This page identifies those items that were not scanned during the initial production scanning
phase. They are available in the original file. may be scanned during a special rescan activity or
are viewable by direct ins pection of the file.
RESCAN DIGITAL DATA OVERSIZED (Scannable)
[] Color items: [] Diskettes No. [] Maps:
[] Grayscale items: [] Other, No/Type [] Other items scannable by
large scanner
[] Poor Quality Originals: .~
OVERSIZED (Non-Scannable)
Other:
:[3. , Logs of various kinds.
NOTES:
[] Other
BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; /S/
Project Proofing
BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: /SI
Scanning Preparation __~ x 30= ~), + = TOTALPAGES /qO
Produc.on Scanning ~':'~ ' ? ~
Stage 1 PAGE COUNT FROM SCANNED FILE: ~ ~
PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES ~ NO
Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~S NO
ReScanned (individual page [special attention] scanning completed)
RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE:
Isl
General Notes or Comments about this file:
Quality Checked (done)
10/25/02Rev3NOTScanned.wpd
• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: DATE: Thursday, May 31, 2012
Jim Regg
P.I. Supervisor l el c'( 6/((v SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2B -11
FROM: Matt Herrera KUPARUK RIV UNIT 2B-I1
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Supry ..igg—
NON - CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 2B - 11 API Well Number 50 - 029 - 21089 - 00 - 00 Inspector Name: Matt Herrera
Permit Number: 184 - 035 - Inspection Date: 5/10/2012
Insp Num: mitMFH120513132534
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 2B-11 Type Inj W' 5731 - IA 800 1 2460 . 2440 , 2410 - 2390
PTD 1840350 . Type Test SPT Test psi 1500 , OA 530 . 750 , 740 740 740 -
Interval 4YRTST P/F � 1 '' Tubing 1850 1850 1850 1850 1850 -
Notes: IA tested to 2500 psi per DHD personnel. Could not get pressure to stabilize will retest. Test determined to be inconclusive.
Thursday, May 31, 2012 Page 1 of 1
• •
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: Thursday, May 31, 2012
P.I. Supervisor CI ' I ( z SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2B -11
FROM: Matt Herrera KUPARUK RIV UNIT 2B -11
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Supry .1
NON - CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 2B - 11 API Well Number 50 029 - 21089 - 00 - 00 Inspector Name: Matt Herrera
Permit Number: 184 - 035 - Inspection Date: 5/10/2012
Insp Num: mitMFH120513133734
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 2B-11 - Type Inj W TVD 5731 IA 2300 , 2540 - 2520 2520 -
PTD 1840350 - Type Test SPT Test psi 1500 - OA 680 , 695 690 690
Interval 4YRTST P/F P ' Tubing 1840 , 1840 1840 1840 ,
Notes: Retest from earlier after pressure stabilization / IA tested to 2500 psi per DHD personnel
SkANNED JUL 1 2 ZG1,
Thursday, May 31, 2012 Page 1 of 1
• t�(A. 1 i
Prt 1e4035
'Regg, James B (DOA)
From: NSK Problem Well Supv [n1617 @conocophillips.com] n Ke
Sent: Monday, May 14, 2012 8:07 PM n ` 145/1 ,
To: Regg, James B (DOA) 6
Cc: Brooks, Phoebe L (DOA); Dethlefs, Jerry C; NSK Problem Well Supv
Subject: RE: Kuparuk witnessed MIT's
Attachments: 2B -09 schematic.pdf; MIT KRU 2D -04 05- 10- 12.xls
Jim,
2D -04 — Attached is a corrected MIT form with the MITOA added on it. I apologize for not having that on there. The initial
pressure on the OA was 0 psi and remained 0 psi throughout the test so the OA shut in equipment would not have tripped
during the CMIT TxIA.
2B -08 — The 6019' TVD is for the bottom packer for a tubing patch. The TVD for the Baker FHL production packer is
5831' TVD as noted on the schematic you are referencing.
2B -09 — The top production packer is at 5805' TVD and the lower packer is at the 5956' TVD. Attached is a wellbore
schematic for reference.
./2B -11 — I was unsure what to put in the result box so the test was designated inconclusive in the comment box. Thank
you for clarifying for future reference.
Please let me know if you have any further questions.
Brent Rogers / Kelly Lyons
Problem Wells Supervisor
ConocoPhillips Alaska, Inc.
Desk Phone (907) 659 -7224
Pager (907) 659 -7000 pgr. 909 Jill I CU lZ
From: Regg, James B (DOA) [mailto jim.regg(&alaska.gov]
Sent: Monday, May 14, 2012 5:13 PM
To: NSK Problem Well Supv
Cc: Brooks, Phoebe L (DOA)
Subject: [EXTERNAL]RE: Kuparuk witnessed MIT's
KRU 2D -04 (PTD 1841510)
- Did not see results of MITOA?
- Please explain the 1000psi pre -test pressure on IA. According to AIO2B.037, this well is required to have
installed and operational an auto shut in tied to the OA, with a required trip pressure of 1000psi. I understand
that this would have to be defeated for the CMIT, a pre -test pressure of 1000psi is confusing
KRU 2B -08 (PTD 1840260)
- Packer TVD should be 6019 ft based on the most recent well schematic in our well records (attached to 10 -404
for sundry 311 -147).
- This raises a broader question relating to packer TVD. AOGCC and operators made a significant time
commitment a few years back — including numerous reviews of well data — to resolve packer TVD differences;
seems we are frequently discussing /debating packer TVD with CPAI. How does CPAI and AOGCC resolve this?
KRU 2B -09 (PTD 1840270)
- Packer TVD again; you show 5805 ft; we show 5956 ft; this time I do not have a well schematic to base this on,
and no recent sundry notices /reports. At least the test pressure is unaffected
KRU 2B -11 (PTD 1840350)
1
•
- Initial test shown inconclusive {pressure „
essure loss did not stabilize); show this test result as I „
Jim Regg
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907 - 7934236
From: NSK Problem Well Supv [ mailto :n1617Ca�conocophillips.com]
Sent: Saturday, May 12, 2012 8:38 PM
To: Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay
Subject: Kuparuk witnessed MITs
All,
Attached are the test forms for the MIT's performed on 05/10/12. These included 2B pad (wells 06 & 10 were not tested
as they were shut in at the time of testing), 2D -04 CMIT TxIA & MITOA as per AIO 2B.037 and the witnessed retest of 2H-
16.
Please let me know if you have any questions.
Brent Rogers / Kelly Lyons
Problem Wells Supervisor
ConocoPhillips Alaska, Inc.
Desk Phone (907) 659 -7224
Pager (907) 659 -7000 pgr. 909
2
02/09/09
~~`: - _ - ~
Schlumberger -DCS ~ ~ } ~ `''`~~~,~ ~`~~ ~ ~ ~~
2525 Gambell Street, Suite 400 ,, , _ `~`~""
Anchorage, AK 99503-2838
ATTN: Beth
Well Job #
.__._~
Log Description
NO. 5063
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Date BL Color CD
1 L-13 11978475 PRODUCTION PROFILE / - L `j 08/16/08 1 1
2A-26 AZJZ-00010 USIT ~- Zj 01/16/09 1 1
1D-141A ANHY-00041 FLOWING BHP --Q 01/21/09 1 1
3K-15 B04C-00004 INJECTION PROFILE " l 01/21/09 1 1
1E-105 AZED-00019 INJECTION PROFILE 01/23/09 1 1
1 E-119 AYS4-00023 INJECTION PROFILE J 01/23/09 1 1
3J-01 AYS4-00024 INJECTION PROFILE ~ -t 01/24/09 1 1
2V-06 AZED-00022 INJECTION PROFILE /$ - 1 01/26/09 1 1
2K-22 AZED-00024 LDL /'~-,~ / 01/28/09 1 1
2L-301 AZED-00025 SBHP SURVEY --/ - 01/29/09 1 1
1R-03A ANHY-00045 INJECTION PROFILE T ~~-$` 02/09/09 1 1
28-11 AZED-00028 INJECTION PROFILE ~..- 02/01/09 1 1
2F-16 AZED-00029 INJECTION PROFILE V 02/02/09 1 1
3J-05 AZED-00030 INJECTION PROFILE 02/03/09 1 1
3G-07A AYS4-00033 PRODUCTION PROFILE j S 02/04/09 1 1
1 D-03 ANHY-00042 LDL ~ ~- - 02/05/09 1 1
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
g~,,,
l •'
•
MEMORANDUM
To: Jim Regg ~~~ ~ I ~ 7~u5,~
P.I. Supervisor f
FROM: $ob Noble
Petroleum Inspector
•
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Monday, May 19, 2008
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA RvC
2B-il
KUPARUK RIV i~NIT 2B-1 I
Src: [nspector
NON-CONFIDENTIAL
Reviewed Bv:
P.I. Suprv ~~
Comm
Well Name: KUPARUK RN UNIT 2B-1 l
IIISp Num: mitRCN080s 12081019
Rel Insp Num:
API Well Number: so-o29-2 to89-o0-0o Inspector Name: Bob Noble
Permit Number: 18a-035-0 Inspection Date: s. t Ii2oos
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
~- _ -- - ^ - __ _ - --~- j -,- - ---- -
Well 2B I I ,Type In). i i TVD X735 / IA 1380 2960 ~ ~ X890 ', 2840 2830 r'
W _ QA 340 _ - -- -- -
1840301 i SPT -- X960 ~ 700 6~0 650 - 650- I _---- - - -
P.T TypeTest Test psi ~I _ _
---
4YRT ----_ --- -- --___ - -- -
Interval ST P/F P ~ Tubing z4zs zazs zags zazs z4zs _
Notes' Took this well out to 4s min.
~~~~ MA`s ~ 20Ei
Monday, May 19, 2008 Paee t of I
~;
4~.
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
May 14, 2008
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Mr. Maunder:
~~NE® MAY ~ 0 200$
i ~ '!
:.fit h, ~~ ', .~ ~
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 spreadsheetserves as notification that
the treatments took place and meets the requirements of form 10-404, Report of Sundry
Operations.
The cement was pumped April 3 2008 and the corrosion inhibitor/sealant was pumped on April
20th and 30th of 2008. The attached spreadsheet presents the well name, top of cement depth
prior to filling, and volumes used on each conductor.
Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions.
Sincerely,
~~ j~
_..
Perry Kle
ConocoPhillips Well Integrity Projects Supervisor
,~.
ConocoPhillips Alaska Inc.
Surface Casiing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Date
Kuparuk Field
5/14/2008
Well Name
PTD #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft al
26-01 184-115 25' 5" 3.25 23" 4/3/2008 1.7 .4/20/2008
2B-02 184-122 30' S" 0.5 20" 4/3/2008 4.3 4/20/2008
26-03A .203-009 4' 0.5 33" 4/3/2008 10.2 4/20/2008
2B-04 184-120 30' 4 28" 4/3!2008. 6.4 4/20/2008
2B-06 184-022 26' 5 19" 4/3!2008 8.5 4/20/2008
2B-09 184-027 74' , 10.5 32" 4/3/2008 11.1 4/20/2008
2B-10 184-029 74' 10.5 33" 4/3/2008 17 4/20/2008
213-11 184-035 50' ~ 7.5 29" 4/3/2008 6 4/20/2008
26-12 184-038 6' 1 29" 4/3/2008 6 4/20/2008
2H-01 184-077 SF n/a SF n/a 2.5 4!30/2008
2H-02 184-073 SF n/a SF n/a 2 4/30/2008
2H-03 184-070 SF n/a SF n/a 4 4/30/2008
2H-04 184-055 SF n/a SF n/a 2 4/30/2008
2H-08 185-171 2' 6" n/a 2' 6" n/a 25 4/30/2008
2H-10 185-260 SF n/a SF n/a 2 4/30/2008
2H-11 185-261 SF n/a SF n/a 2.5 4/30/2008
2H-12 185-262 SF n/a SF n/a 2.5 4/30/2008
2H-13 184-096 2" n/a 2" n/a 2 4/30/2008
2H-14 184-095 SF n/a SF n/a 2 4/30/2008
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conserntion Commission
TO:
Jim Regg
Pol. Supervisor
DATE: Wednesday, June 23, 2004
Sll BJ ECT: 1\ lechamcallntegrity Test:;
CONOCOPHlLUPS AlASKA. [NC
FROM:
Chuck Scheve
Petroleum Inspector
2B-[ 1
KUPARlÆ RIV UNlT lB-ll
Src: Inspector
Reviewed B:y:
Pol. Supn'
Comm
NON-CONFIDENTIAL
\Vell Name: KUPARUK RJV UNIT 28-11
Insp Num: mllCS040621 I 15424
Rei Insp Num:
API Well Number: 50-029-21089-00-00
Permit Number: 18..\-035-0
Inspector Name: Chuck Scheve
I nspection Date: 6/20/2004
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well I lB-ll Type Inj. I P TVD I 6158 IA 1180 2560 ~510 I 2510
P.T. I 18-10350 TypeTest I SPT Test psi I 1-13~.75 OA 120 120 110 120
Inten/al '¡',¡"RTST PIF P Tubing 1550 1550 1550 1550
Notes: The pretest pressures were observed for 30+ minutes and found stable. This well has a waiver poster indicating tubing x IA communication.
Ga..... or water mjection allo\\ed IA pressure not to exceed 3000 psi. The tubing x IA communication was not apparent during this 30 minute
tesl.
~o AcGCc qPft¿"~) '5l-LU:~~J ~_,-ìqJer) jße-
\Vednesday. June 23 200-1
Page 1 of I
MEMORANDUM
State of Alaska .
Alaska Oil and Oas ConserVation Commission
TO: Dan Seamount
Commissioner
THRU: Blair Wondzell
P.I. Supervisor
FROM: John Cris~
Petroleum Inspector
NON- CONFIDENTIAL
DATE: September 9, 2000
SUBJECT: Mechanical Integrity Tests
Phillips Alaska Inc.
2B Pad
10.11.12
Kuparuk River Unit
Kuparuk River Field
Packer DePth Pretest -' Initial 15 Min. 30 Min.
Wel{] 2B-10 I Typelnj. I S I T:V.D. I 5735 I mubingl 2950 I 2950 I 2950 I 2950 ~
P.T.D..I 1840290IType. test)' i= ITestpsil 1~434 I Casingl 1050 i ~950 ! 1940 i 1940.1 p/F i'_p.
Notes:
WellI 2B-11
P'.T.D.I 1840350
Notes:
Well[ 2B-12
P.T.D.I 1840380
Notes:
WellI
P.T.D.I
Notes:
' p.T.r~l
Notes:
.
I TYPe 'hi' I I 'T'V'D' I :, I TUbing I I I I. I'nter~a'l '
I TYPe testl I Test psiI ' I Casing I I I ' I I P/F I
Type INJ. Fluid Codes
F = FRESH WATER INJ.
G = GAS INJ.
S = SALT WATER INJ.
N = NOT INJECTING
Type Test
M= Annulus Monitoring
P= Standard Pressure Test
R= Internal RadiOactiVe Tracer Survey
A= Temperature Anomaly Survey
D= Differential Temperature Test '
Test's Details
2 Mits performed, no failures witnessed.
.I.T.'s performed: _2
Attachments:
Number of Failures: _0
Interval
I= Initial Test
4= 'FOur Year Cycle
V= Required by Variance
W= Test during Workover
O= Other (describe in notes)
Total Time dudng tests: 1 hr.
-.
MIT report form
5/12/00 L.G.
MIT KRU 2Bb 9-9-00jc.xls
9/13t00
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Dan Seamount
Commissioner
DATE: September 9, 2000
THRU: Blair Wondzell
P.I. Supervisor
FROM: John Cris'~'
Petroleum Inspector
SUBJECT: Mechanical Integrity Tests
Phillips Alaska Inc.
2B Pad
10,11,12
Kuparuk River Unit
Kuparuk River Field
NON- CONFIDENTIAL
Packer Depth Pretest Initial 15 Min. 30 Min.
we,I 28-40 Type,nj.I s I~.v.o:l ~,~ I Tubing I 2950 12950 I 2950 J 2950 I lnterVall 4
P.T.D.I 1840290 Type testl 'P I Testpsil 1434 ICasingI 1050 I ~950 i 1940 i ~940I P/FI P-
Notes:
WellI 2B-11 I Typelnj.
P;T.D.I 1840350 IType test!
Notes:
WellI 2B-1'2 IType,nj.I s I T.V.D.I~0 I'l:ubingl 2450--I 2450 I 2450I=~o Ilnterva, l' 4
P.T.D'.I 4840380 ITypetestl P' ITestpsil 14§5'lCasingI 1050 I 1950 I 1925 I ~925I P/FI P,
Notes:
WellI [Type Inj.
'P.T.D.I I Type test
Notes:
WailI I Type Inj.
P.T.D.I IType test
Notes:
Type INJ. Fluid Codes
F -- FRESH WATER INJ.
G = GAS INJ.
S = SALT WATER INJ.
N = NOT INJECTING
Type Test
M= Annulus Monitoring
P= Standard Pressure Test
R= Internal Radioactive Tracer Survey
A= Temperature Anomaly Survey
D= Differential Temperature Test
2 Mits performed, no failures witnessed.
Test's Details
.Interval
I= Initial Test
4= Four Year Cycle
V= Required by Variance
W= Test during Workover
O'- Other (describe in notes)
M.I.T.'s performed: 2
Attachments:
Number of Failures: 0
Total Time during tests: 1 hr,
CC:
MIT report form
5/12/00 L.G.
MIT KRU 2Bb 9-9,00jC.xls
og/11/2000
· STATE OF ALASKA
~ OIL AND G/~ CONSERVATION COM~ION
REPORT OF SUNDRY WELL OPERATIONS
1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well
Alter casing_ Repair well _ Plugging _ Time extension _ Stimulate
Change approved program Pull tubing Variance Perforate Other
2. Name of Operator
ARCO Alaska, Inc,
3. Address
P. O. Box 100360, Anchorage, AK
99510
5. Type of Well:
Development __
Exploratory _
Stratigraphic
,Service ~
4. Location of well at surface
1292' FSL, 838' FEL, SEC.19, T11N, R93, UM
At top of productive interval
1159' FNL, 1324' FWL, SEC.19, T11N, R93, UM
At effective depth
1159' FNL, 1324' FWL, SEC.19, T11N, R93, UM
At total depth
976' FNL~ 1531' FWL~ SEC.19~ T11N~ R93~ UM
12. Present well condition summary
6. Datum elevation (DF or KB)
RKB 126'
7. Unit or Property name
Kuparuk River Unit
feet
8. Well number
2B-11
9. Permit number
84-35
10. APl number
5o-029-21089
11. Field/Pool Kuparuk River Field
Kuparuk River Oil Pool
Total Depth:
measured 7 6 7 6' feet
true vertical 6 1 5 8' feet
Effective depth: measured 7569' feet Junk (measured)
true vertical 6079' feet FILL AT 7491'
Casing Length Size Cemented
Structural
Conductor 1 1 6' 1 6" 190 SX CS II
Surface 2 8 92' 9 5/8" 690 SX PF E &
Intermediate 250 SX PFC
Production 7 6 5 9' 7" 300 SX CLASS G &
Liner 250 SX PFC
Perforation depth: measured
7261 '-7287'
7441 '-7466'
true vertical
5849'-5868',
Tubing (size, grade, and measured depth)
3 1/3" J-55 SET AT 7324'
13.
Plugs (measured)
Packers and SSSV (type and measured depth)
BAKER FHL @ 7084', BAKER FB-1 @ 7309', BAKER FVL @ 1917'
Stimulation or cement squeeze summary
Intervals treated (measured)
Measured depth True vertical depth
116' 116'
2892' 2782'
7659'
12 SPF 120 DEGREE PHASING, 7396'-7422' 4 SPF
Ai
REQUEST APPROVAL TO CONTINUE INJECTION AS IS_ ~chorage SEE A~ACHED ~H~TIC, ~C.
Treatment description including volumes used and final pressure
14.
Pressure
Reoresentative Daily Average Production or In!ection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing
Prior to well operation
1700' 2050 900
Subsecluent to operation 2 6 7 3 2 8 0 0
15. Attachments 16, Status of well classification as:
Copies of Logs and Surveys run__ Water Injector __ IWAG INJECTOR
Daily Report of Well Operations X Oil_ Gas Suspended
17, I hereby certify that the foregoing is true and correct to the best of my knowledge,
,Service
1300
Date
Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE
KUPARUK WELL 2B;'ri
APl #:
SPUD DATE:
ORIGINAL RKB:
500292108900 ADL LEASE: 25655 PERMIT #:
03114184 COMPLETION DATE: 05/11/84 WORKOVER DATE:
SURFACE LOCATION: 1292-FSL,828-FEL, SEC19,T11N,RgE
TOP OF KUPARUK: 1159-FNL,1324-FWL,SEC20,T11 N,RgE
TD LOCATION: 976-FNL,1531 -FWL,SEC20,T11N,RgE
NI depbSs am MD-RKB to top of equipment unless otherwise noted
126 TUBING SPOOL: PAD ELEVATION:
WELLTYPE: WAG INJECTOR
CASING and TUBING DETAILS
SIZE WEIGHT GRADE DEPTH
16' 62,5# H-40 116
9.625' 36# J-55 2892
7' 26# J-55 7659
3.5' 9.3# J-55 '7324
LINER DETAILS
SIZE WEIGHT GRADE TOP
BTM
TUBING JEWELRY
ITEM TYPE ID DEPTH
SSSV BAKER FVL 2.81' 1917
SBR BAKER PBR 3.0' 7069
PKR BAKER FI-IL 7084
PKR BAKER FB-1 7309
NOC-.-.-~ CAMCO 'D' NIPPLE 2.75' 7322
SHROUT BAKER 7323
MISC. DATA
DESCRIPTION
KICK OFF POINT:
MAX HOLEANGLE: 47 deg
HOLE ANGLETHRU KUP: 42 deg
LAST TAG DATE: 11/18/85
RATHOLE: ~c~ ft
FISH/OBSTRUCTION:
PBTD:
PBTDSS:
91
GAS LIFT and FLOW INFORMATION
VALVE
DEPTH
1400
7569
5952
84-35
STN DEPTH MANDREL SIZE
I 7O26 1.0"
2 7121 1.0'
3 7191 1.0'
4 7293 1.0'
PERFORATION DATA
INTERVAL ZONE FT SPF PHASE
7261-7287 C 26 12 120
7396-7422 A 26 4
7441-7466 A 25 4
PORT
SIZE
DV
FO
FO
FO
COMMENTS
DRESSER-ATLAS
.
Alaska .Oil & Gas Cons. Commission
'Anchorage
REVISION DATE: 02/01/85
REASON:
WELL
ARCO Alaska, In~,;,~.
Subsidiary of Atlantic Richfield Company'-
I PBDT
p~% -,~
CONTRACTOR
REMARKS
WELL SERVICE REPOR'
OPERATION AT J~PORT TIME
I DAYS
I
Weather Temp. Chill Factor I Visibility I Wind Vel. Sig
Report °F °Fi miles k ~ {~)
WELL SERVICE REPOF
ARCO'Alaska,
,~midlaW of Atl&ntlc Richfield Company
WELL ]PBDT I
,~EMARKS
OPERATION AT REPORT TIME
II
-
["] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK
Report 'F 'F miles knots I~\c ~~ - "~ O
ARCO Alaska, Inc.
Date:
September 20, 1989
Transmittal #: 7560
RETURN TO:
ARCO Alaska, Inc.
Attn: Madeline N. Rivera
Kuparuk Records Clerk
ATO-1 119
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith are the following items. Please acknowledge.receipt and return
one signed copy of this transmittal.
1 Q-03 Kuparuk Fluid Level Report 9 - 7- 8 9
2 B-1 I Kuparuk Fluid Level Report 9- 6- 8 9
2 B - 1 2 Kuparuk Fluid Level Report 9 - 8 - 8 9
2 H- 1 6 Kuparuk Fluid Level Report 9 - 8 - 8 9
3 C- 13 Kuparuk Fluid Level Report 9 - 5 - 8 9
3 H - 01 Kuparuk Fluid Level Report 9 - 5 - 8 9
Tubing
Tubing
Tubing
Tubing
Casing
Tubing
Receipt
Acknowledged'
DISTRIBUTION:
BP Chevron Unocal Mobil State of Alaska . D&M
ATTACHMENT 1
PACE 2
KUPARUK RIVER FIELD
CONSERVATION ORDER 198
RULE 4 - INJECTIVITY PROFILES
SECOND QUARTER 1987 SUBMITTAL
WELL APl DATE OF DATE OF DATA TYPE REASON FOR
NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/
50-029 INJECTION SURVEY SURVEY SURVEY
2B-11 21089 11/19/85
2H-O1 20033 03/15/86
2H-04 20027 03/15/86
50-103
2T-04 20074 03/30/87
2T-09 20071 03/30/87
2T-11 20075 03/30/87
2T-15 20062 03/30/87
2T-16 20063 03/30/87
50-029
3A-02 21431 01/21/87
3A-04 21433 01/21/87
3A-10 21457 01/21/87
~.~,~:~ 21458 01/21/87
WELL
COMPLETION
06/16/87 SPINNER FOLLOWUP A&C S
06/05/87 SPINNER FOLLOWUP A&C S
06/07/87 SPINNER FOLLOWUP A&C S
06/13/87 SPINNER INITIAL A&C SS
06/16/87 SURVEY INITIAL A S
06/21/87 SPINNER INITIAL A&C SS
06/16/87 SURVEY INITIAL A&C SS
06/16/87 SURVEY INITIAL A&C SS
C3A-14 21490 04/14/87
·
iy...Ib
iq lsv
05/25/87 SPINNER INITIAL
05/8'1 SURVEY INITIAl-
05/8'1 SURVEY INITIAL
05/27/87 t~~ INI'rlAL
05/87 SURVEY INITIAL
A&C SS
A&C SS
A S
A&C SS
A S
ZONES
TAKING
WAT ER
A&C
A&C
A&C
A&C
A
A&C
A
A
A&C
A
A
A&C
A
INJECTION
BWPD
RECEIVED
3485
1833
59O
Alaska Oil & Gas Cons. Commission
Anchorage
2500
1200
1650
c,//
ARCO Alaska, Inc..
Post Office B-'"6'~100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
OI{IGINA
June 19, 1989
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear Mr. Chatterton'
Attached in triplicate are multiple Applications for Sundry Approvals on the following
Kuparuk wells.
Well : Agtion
Anticipated Start Date
2 B- 1 1 Tbg. Leak June, 1989
2D-08 Perforate June, 1989
2C-15 Acidize June, 1989
2G-13 Fracture June, 1989
2G-15 Fracture ~ June, 1989
2G-08 Fracture June, 1989
If you have any questions, please call me at 265-6840.
Sincerely,
G. B. SmallwOod
Senior Operations Engineer
RECEIVED
JUN 2 2 1989
Alaska 0il & Gas Cons. Commission
Anchorage
CC:
J. Gruber ATO 1478
J. R. Brandstetter ATO 1120
L. Perini ATO 1130
KOE1.4-9
w/o attachments
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA
AI-~KA OIL AND GAS C(~SERVATION COM MI~"~ON
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well
Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _
Change approved program _ Pull tubing _ Variance _ Perforate _
2. Name of Operator
ARCO Alaska. Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510
5. Type of Well:
Development X
Exploratory _
Stratigraphic _
Service
4. Location of well at surface
1292' FSL, 828' FEL, Sec.19, T11N, R9E, UM
At top of productive interval
1159' FNL, 1324' FWL, Sec. 20, T11N, R9E, UM
At effective depth
1159' FNL, 1324' FWL, Sec. 20, T11N, R9E, UM
At total depth
976' FNL, 1531' FWL~ Sec. 20, T11N, R9E, UM
12. Present well condition summary
Total Depth: measured 7676' feet
true vertical 6158' feet
Effective depth: measured 7569' feet
true vertical 6 0 7 9' feet
Plugs (measured)
Cement:
Junk (measured)
Fill at 7491'
Other ..~
6. Datum elevation (DF or KB)
RKB 126'
7. Unit or Property name
Kuparuk River Unit
feet
8. Well number
2B-11 //U ~'~
9. Permit number
84-35
10. APl number
50-029-21 089
11. Field/Pool Kuparuk River Field
Kuparuk River Oil Pool
Casing Length Size
Structural
Conductor 1 1 6' 1 6"
Surface 2892' 9 5/8"
Intermediate
Production 7 6 5 9' 7"
Liner
Perforation depth: measured
7261-7287' 12 SPF
7441'-7466' 4 SPF
true vertical
Cemented
Measured depth True vertical depth
120
190 Sx CS II I 16' 116'
690 Sx PF E & 2892' 2782'
250 Sx PFC
300 Sx Class G & 7659' 61 46'
250Sx PFC
degree phasing,7396'-7422'
4 S RECEIVED
5849'-5868', 5949'-5968', and 5983' - 6002' TVD
Tubing (size, grade, and measured depth
3 1/2" J-55 set at 7324'
Packers and SSSV (type and measured depth)
Baker FHL @ 7084'~ Baker FB-1 @ 7309', Baker FVL @ 1917'
13. Attachments Description summary of proposal ~ Detailed operation program
Request a sundry approval to continue injection "as is" (Wellbore schematic attached).
14. Estimated date for commencing operation 115. Status of well classification as:
June, 1989 J Oil _ Gas _
16.If proposal was verbally approved
Name of approver Date approved Service Water
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed ,/~ ¢(.,~ ~ /'~_ ~/'~-~'~,,~"~le SR. OPERATIONS ENGINEER Date
~/ FOR COMMISSION USE ONLY
JUH 2 2 ]989
Alaska 0ii & Gas Cons. CommissJ0j
Anchorage
BOP sketch
Suspended
Injector
Conditions of approval: Notify Commission so representative may witness
Plug integrity __ BOP Test _ Location clearance__
Mechanical Integrity Test_ Subsequent form require
ORIGINAL SIGNED BY
LONNIE C, SMITH
~,pproved by the order of the Commission
Commissioner
JApproval No.
Approved Copy
Returned
Date
Form 10-403 Rev 5/03/89
SUBMIT IN TRIPLICATE
ApPlication for Sundry Approval for 2B-11
Suspected Tubing to 7" Casing Communication
Attachment
This notice is to request continued injection into Kuparuk Well 2B-11. This well has a
suspected tubing leak which is causing pressure communication between the tubing
7" casing. There is no sign of deterioration in th ·
first sign of a possible tubinn ~. ,.,...~.,__ e _c. asmg integrit to he and
~, le,.,,, ~,,vu~um w nntlr,,-,~ .-- ,-. Y. t formation. The
has Passed two recently performed MIT's as shown in the attached documents. We are
currently monitoring pressures closely, as ..... ~u ,j uecember of 1988. The well
RECEIVED
JUN 2 2 ] 89
Alaska Oil & Gas Cons. Cornmissior~
Anchorage
KUPARUK WELL 2B-i-i
APl #:
SPUD DATE:
ORIGINAL RKB:
500292108900 ADL LEASE: 25655 PERMIT #:
03/14/84 COMPLETION DATE: 05/11/84 WORKOVER DATE:
SURFACE LOCATION: 1292-FSL,828-FEL,SEC19,T11N,R9E
TOP OF KUPARUK: 1159-FNL,1324-FWL,SEC20,T11 N,R9E
TD LOCATION: 976-FNL,1531 -FWL,SEC20,T11 N,R9E
All depths are MD-RKB to top of equipment unless otherwise noted
126 TUBING SPOOL: PAD ELEVATION:
WELLTYPE: WAG INJECTOR
CASING and TUBING DETAILS
SIZE WEIGHT GRADE DEPTH
16" 62.5# H-40 116
9.625" 36# J-55 2892
7" 26# J-55 7659
3.5" 9.3# J-55 7324
LINER DETAILS
SIZE WEIGHT GRADE TOP
BTM
TUBING JEWELRY
ITEM TYPE ID DEPTH
SSSV BAKER FVL 2.81" 1917
SBR BAKER PBR 3.0" 7069
PKR BAKER FHL 7084
PKR BAKER FB-1 7309
NOGO CAMCO 'D' NIPPLE 2.75" 7322
SHROUT BAKER 7323
' L
91
GAS LIFT and FLOW INFORMATION
VALVE
STN DEPTH MANDREL SIZE
1 7026 1.0"
2 7121 1.0"
3 7191 1.0"
4 7293 1.0"
PERFORATION DATA
INTERVAL ZONE FT SPF PHASE
7261-7287 C 26 12 120
7396-7422 A 26 4
7441-7466 A 25 4
84 -35
PORT
SIZE
DV
FO
FO
FO
COMMENTS
DRESSER-ATLAS
MISC. DATA
DESCRIPTION
KICK OFF POINT:
MAX HOLEANGLE: 47 deg
HOLE ANGLETHRU KUP: 42 deg
LAST TAG DATE: 11/18/85
RATHOLE: ~d(c~ I ft
FISH/OBSTRUCTION:
PBTD:
PBTDSS:
DEPTH
1400
7569
5952
RECE!VED
.,
6~s Coho. commission
Anchorage,
REVISION DATE: 02/01/85
REASON:
.ARCO'AlaSka, In¢ ~
Subsidiary of Atlantic Richfield Compan~'-.~'
WELL SERVICE REPORT
WELL
CONTRACTOR
REMARKS
OPERATION AT J~.PORT TIME
RECEivED
Al3s.ka 0!! & ~as C:c,r.,~.
r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK
Weather Temp' I Chill Fact°r J Visibility JWindVel'Report *F *F miles
· ARCOAlaska, Ir ~
Subsidiary of Atlantic Richfield Comi~'-.-.~'
WELL JPBDT
CONTRA~,~t~
,'~EMARKS
OPERATION AT REPORT TIME
WELL SERVICE REPORT
l'7C, 5
II
7 C.S C~ --
?"
Z ,.J Z (.) "~ %' ,
Alaska Oii & (.:~as '"~
buiqS, '''~ ' ·
- bO£flffit$.SlOFl
Anchurag~
r--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK
STATE OF ALASKA
ALASKA~IL AND GAS CONSERVATION co~TVIMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1. DRILLING WELL []
COMPLETED WELL []X
OTHER []
2.
7. Permit No.
Na ARfc°oerALASKA, INC. 8 4-35
3. Address 8. APl Number
P. O. BOX 100360, ANCHOPAGE, ALASKA 99510 50- 029-21 089
4. Location of Well
SURFACE LOCATION- 1292'FSL, 828'FEL, Sec. 19,
TllN, R9E, UM
5. Elevation in feet (indicate KB, DF, etc.)
RKB 126' PAD 90
12.
I 6
. Lease Designation and Serial No.
ADL 25655, ALK 2581
9. Unit or Lease Name
KUPARUK RIVER UNIT
10. Well Number
2B-11
11. Field and Pool
KUPARUK RIVER FI ELD
KUPARUK RIVER OIL
POOL
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF:
(Submit in Triplicate) (Submit in Duplicate)
Perforate [] Alter Casing [] Perforations [] Altering Casing
Stimulate [] Abandon FI Stimulation [] Abandonment
Repair Well [] Change Plans [] Repairs Made [] Other
Pull Tubing [] Other [] Pulling Tubing []
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25.105-170).
On November
to a water
conversion
5, 1985 Kuparuk well 2B-11 was converted from a producer
injector well as part of the full field waterflood
effort. Water is being injected into the "A" sand.
Alaska Oil & Gas Cons.
14. I hereby certify that the foregoing is true and correct to the best of my kno~l~jd~eAR~ jK
Signed ...~. ./~ g'~-"------~ Title OPERAT! ONS COORD I NATO~ate -
The space below for Commission use
11/15/85
Conditions of Approval, if any:
By Order of
Approved by_ COMMISSIONER the Commission Date __
Form 10-403
Rev. 7-1-80
Submit "Intentions" in Triplicate
and "Subsequent Reports" in Duplicate
ARCO Alaska, Inc_
Post OfficeL.-~.~ 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
December 4, 1985
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
Dear Mr. Chatterton:
Attached in duplicate are subsequent notices
following wells at the Kuparuk River Field:
Well Action
Date Performed
on
the
1F-4 Conversion
1F-5 Conversion
1F-8 Conversion
1G-3 Conversion
1G-4 Conversion
1L-3 Conversion
1L-5 Conversion
1Q-8 Conversion
1Q-12 Conversion
1Q-14 Conversion
1R-3 Conversion
1R-10 Conversion
1Y-7 Conversion
1Y-10 Conversion
1Y-15 Conversion
1Y-13 Conversion
2B-6 Conversion
2B-8 Convers.ion
2B-11 Conversion
2B-12 Conversion
2C-2 Conversion
2C-4 Conversion
2C-5 Conversion
2C-7 Conversion
2D-4 Conversion
2D-5 Conversion
2F-3 Conversion
2F-4 Conversion
2F-15 Conversion
2F-16 Conversion
2D-10 Conversion
2D-16 Conversion
10124185
10/24/85
10/24/85
10/25/85
10/25/85
10/24/85
10/24/85
10125185
10/25/85
10/25/85
10/26/85
10/26/85
10/26/85
10/26/85
10/26/85
10/26/85
11/5/85
11/5/85
1115185
11/5/85
1116185.
1116185
1116185
1116185
11/6/85
11/6/85
1112185
11/2/85
1112185
11/2/85
11/6/85
11/6/85
.. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
..
ARCO Alaska, Inc
Post Office r~ 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
September 20, 1985
Mr. L. C. Smith ~
Alaska Oil and Gas Conservation Commission
3001 Porcupine Street
Anchorage, AK 99501
Dear L. C. Smith:
Per our conversation on September 4, 1985, ARCO Alaska,
Inc. proposes to convert 110 production wells to water
injection to implement fullfield waterflood of the
Kuparuk River Unit.
As discussed a single "blanket" sundry notice (form
10-403) has been completed for all well proposed to be
converted to water injection. Individual subsequent
sundry notices will be filed when the actual well
conversions occur.
As stated in form 10-403, well conversion to water
injection will occur in two primary stages. The first
stage will convert approximately four wells per
drillsite to achieve a nine-spot pattern. First stage
conversions are expected to be completed by
approximately 10/15/85, prior to waterflood startup.
The second stage of conversions will convert
approximately four additional wells per drillsite to
achieve a line drive pattern. Second stage conversions
are expected to be completed mid-December to January
1986.
I would like to express my thanks and appreciation to
the Commission in working with ARCO Alaska, Inc. in
this area. If you have any questions please call me at
263-4212.
Sincerely,
T. M. Drumm
Kuparuk Operations Coordinator
cc: J.F. Beall
TMD:ps:013
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
1E- 6
-26
IF- 2 - 4
- 5
- 8
1G- 2 - 3
- 4
- 5
IL- 1
- 3
- 5
- 7
-16
iQ- 1
- 2
- 7
- 8
-11
-12
-13
-14
IR- 3
- 8
-10
-13
1Y- 1
- 7
-10
-13
2B- 5
- 6
- 7
- 8
- 9
-10
-11
-12
2C- 1
- 2
- 3
- 4
- 5
MARK: 009
Permit
80- 78
82-166
81-211
172
132
16'2
82-138
149
161
83- 20
84-173
158
123
145
181
84-231
232
218
209
199
193
85- 44
45
85-177
73
96
150
83- 50
68
51
15
84- 4
22
24
28
27
29
35
38
83- 83
93
89
94
99
API#
029-20493
029-20840
029-20881
20846
20807
20836
029-20813
20824
20835
20908
029-21196
21182
21155
21171
21202
029-21247
21248
21234
21225
21216
21210
21306
21307
029-21406
21333
21351
21385
029-20933
20950
20934
20903
029-21067
21078
21080
21079
21082
21084
21089
21092
029-20962
20972
20968
20973
20978
Lease
& Serial
Convert
Date
25651
Il
469
lO/15/85
lO/15/85
25652
II
2578
lO/15/85
lO/1-5/85
lO/15/85
lO/15/85
25640
2571
10/15
10/15
10/15
10/15
/85
/85
/85
/85
25659
Il
2585
12/15
10/15
10/15
12/15
10/15
/85
/85
/85
/85
/85
25634
2567
lO/15
12/15
12/15
lO/15
12/15
lO/15
12/15
lO./15
/85
/85
/85
/85
/85
/85
/85
/85
25635
2568
lO/15
lO/15
lO/15
lO/15
/85
/85
/85
/85
25
25
25
641
646
548
572
577
662
12/15/85
12/15/85
12/15/85
12/15/85
25
25
656
655
Il
2582
I!
I!
2581
12/15/85
10/15/85
12/15/85
10/15/85
12/15/85
12/15/85
10/15/85
10/15/85
25654
2580 12/15/85
" 10/15/85
" 12/15/85
" 10/15/85
RECEi
~.laske Oil & Gas Cons. Co,m .... s,o
STATE OF ALASKA
ALASK/~,_~L AND GAS CONSERVATION C~_~MISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1. DRILLING WELL []
COMPLETED WELL
OTHER []
2. Name of Operator 7. Permit No.
ARCO Alaska, Inc. see attached
3. Address 8. APl Number
P.O. Box 100360, Anchorage, Alaska 99510 so- see attached
Location of Well
5. Elevation in feet (indicate KB, DF, etc.)
N/A
6. Lease Designation and Serial No.
see attached
9. Unit or Lease Name
Kuparuk River Unit
10. Well Number
see attached
11. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
12.
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF:
(Submit in Triplicate) (Submit in Duplicate)
Perforate [] Alter Ca'sing [] Perforations [] Altering Casing []
Stimulate [] Abandon [] Stimulation · [] Abandonment []
Repair Well [] Change Plans [~ Repairs Made [] Other []
Puil Tubing [] Other X~ Pulling Tubing []
Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25.105-170).
10
Pursuant to form 10-403, it is proposed that the attached list of JAproducing
wells in the Kuparuk River Field be converted to water injection. The conversion will
occur in two stages. The first conversion: to a nine-spot.pattern will occur
approximately 10/15/85. The second conversion to a line drive pattern will occur
approximately 12/15/85. Injection will be into the A and C sands.
crn F~r~ Not
£CE VED
SEP 2 0 !9B5
Gas Cons. commission
Anchorage
14. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed ~,/¢~._~ ~.¢~-~=- Tit~e. Kuparuk Operations Coordinator Date
The space below for Commission use
9/18/85
Conditions of Approval, if any:
Form 10-403
Rev. 7-1-80
Approved Copy
~..eturned /
By Order of
COMMISSIONER the Commission Date
Submit "Intentions" in Triplicate
and "Subsequent Reports" in Duplicate
./
ARCO Alaska, Inc'
Post Offic~'-~o~ 360
Anchorage, Alaska 99510
Telephone 907 277 5637
Date: 1/23/85
Transmittal No:
4925
RETURN TO:
ARCO ALASKA, INC.
ATTN: Records Clerk
ATO-1115B
P.O. Box 100360
Anchorage, AK 99510
smitted herewith are the following items. Please acknowledge receipt
return one signed copy of this transmittal.
BHP REPORTS & SEQUENCE OF EVENTS
2B-lw~> 10/16/84' '"Static" SBHP
2B-i~~- 10/17/84 " "
2B-2~ 10/17/84 " "
2B-6~- 6/02/84 "
2B-10~-~ 6/02/84 "
2B-11~- 6/03/84 "
2B-12N~ 6/02/84 "
2B-14~f- 10/28/84 " "
2B-13y--~ 10/28/84 " "
2D-5.A- 10/05/84v " "'
2G-l~ 9/21/84 "Static/G. Ring"
2G-2 * -' 9/22/84 " "
2G-3 .~ 9/23/84 " "
2G-4 ~ 9/23/84 " "
2G-8 %--- 9/30/84
2F-15, 4/13/84
2X-13 ~ 12/18/84
2X-14-~- 12/21/84
2X-15 ~- -' 12/23/84
2X-16) "12/21/84
· .
"Static/G. Ring/Tag"
SBHP
Receipt Acknowledged:
lB-3 ~ ~?' ~6/26/84
lB-4 ;~ ~i~ ~..__- 6/26/84
lB-6 ~-'~ ~.7/01/84
1E-2 ~-?' 6/22/84
1E-7 ~ '~ ~/14/84
1E-4 ~- 10/15/84
1E-12~.>- 6/24/84"
1E-20~~ 6/23,22/84
!E-22~--- 4/23/84
1E-25g~ 6/23/84
1E-25¥ 11/09/84
1E-29-~ .... / 6/23/84
1E-29~ 10/14/84
1F-4 *~- 9/14/84
1F-4 W'~ 9/14/84
1F-7 '~ "~ 7 / 05 / 84
1F-11 ~-~ 4/25/84
1F-14~ ..... 2/07/84
1F-15%~ 2/14/84
1G-10 ~ 6/29/84
¢iG-i~ ~ 9/13/84
/10-3 5/16/84
vlG-5' 6/29/84
1H-4 ~ 6/24/84
1Y-3 ~- 1/21/84
1Y-51'- 5/06/84
1Y-9%~ 5/06/84
1G-14.-~'' 1/12/84
1L-277 10/21/84
iL-3 -6-~ Date:
DISTRIBUTION
B. Currier
BPAE
Chevron
D & M
Drilling
Geology
Mobil
NSK Ops.
W, Pasher
G. Phillips
Phillips Oil
J. Rathmell
SBHP
" "Static"
" "Static"
,I '1
II
ti ti
,!
ti
l,
" "Static"
ti 11
II ,!
ti 11
!t I!
!I !,
II 11
11
,!
11
---. 5 /c,at
State
Sohio
Well :Files
ARCO Alaska, Inc
Post Office'-~-.~x 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
July 5, 1984
Mrs. Elaine Johnson
State of Alaska
Alaska Oil & Gas
Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: Conductor As-Built Location Plats
Wells 5-12, 1-4, 13-16
Dear Elaine'
Enclosed are as-built location plats for the
If you have any questions, please call me at
Sincerely,
J. Gruber
Associate Engineer
JG/tw
GRU8/L27
Enclosures
- 2B-Pad
subject wells.
263-4944.
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
DRI SITE 2-B CONDU_....,.
-., j A~'~- BUILT LOCATIONS
4
II . m " I
WELL 5 Y: 5 954 664.79 Lot. ?0017'!4.4884
! 479 I:'EL,519 FSI.. EL. 91.0', 0. G. 87.0'
WELL. 6 Y = 5 9.547[9.50 Lot. 70°17't5.02.49''
X=- 508 141.09 L. on~. 149°56~0P..784"
504 FEL., 573'FSL
......
WELL ? Y= $~54-'~?~.9?- L'c~t. ?0°!7'15,567-;5''
X' 505 II6.!6 Long. 14g°5~'0-~.508''
s2e FEL,~2e FSL £L. ~l.~', O.G.
WELL 8 Y: 5 954828.53 Lot/70o[7't6.0998'
X = 508 091.27 Long. i49°56'04.g3~''
553 FEL,682 FSL EL. 91.O'~O.G 87.0'
wElL 9 ¥-5 SSS ~8.86 'Lo;.'TO°l?~'{.oz34'' --'
X, 507 863,~;6 Long. I,~9056'~0,86~''
?79 FEL, !I83 FSL EL. 89.4'~0.G. 85.5'
, ,,
X = 507 838.34 Long. t49°56'I 1.585"
· 803 FEL, Ig38 FSL E~Bg.4',O.6.85.0'
, .,., .
30 29 WELL II Y=5 955458.~ Lat. 70"!7'22.0985''
x= 507813.47 Long. 149°56'lZ.306''
~ 8Z8 FEL, IZ92 FSL EL. 89.5',0.G. 84.0'
~-WELL !~' Y: 5955 49Z.55 L:t. 70;~7'~.~'"
X~ 507 788.5~ Long. I49°56'I3.033
85~ FEL,1547 FSL
. ~ ~. _ -- ~ ............... ~. ~ .... --~ I .......... =
LOCATED IN P~OTRACTED SECTION 19 /~~.._[
TOWNSHIP tl N,,RANGE 9 E., UMIAT MERIDIAN. ~ 49~h ~
BASIS OF LOCATION I~ ~MPORARY MONUMENTS 8S NORTH ' ~ ~ · ~ ~ ~ ¢~ % . ..
~ 2B ~UTH PER LHO & A~. ~ ~.. . ..,'
O.G. ELEV. BASED ON O.G CONCURS PER ~RNS.~OGER --~ ~J L ~ .~ j.~ ~~?~'.;~L
DWG. NO. 88-t2-3080 REV. ~.
i ~~ ~ ~ I HEREBY CERTIFY~n~A~I A~ ~b"ERLY REGI~ERED
~ATE
OF
! } /~Ik ~_Ll / { CorRECT ~s OF JANUARY ,IZ;1984.. -,,~ .........
t / E_.._~'X ~'~ ~ '" ~~ ARCO Al~Sko, Inc. '-
i ) ' h, CONDUCTOR AS-BUILT
~ - [ ~ ~ ~ ~ ~ ~~~ Dote: Jonuory 17,1984 $cole= I =400
KUPARUK ENGINEERING'----"
Type of Tape
Date Tape Number
.
.--
DISTRIBUTION
r State-~tof- AK f
Oeoio~'y/C" Smith
Sign G return the attached-
copy as receipt of dat~aj[0 3~4
~ .~~,/ A!aska Oil & C~.,~ Cons. Commission
Anchorage
OH LIS
Return to: ARCO ALASKA, INC.
ATTN: Fauua m. W~T; ~
ATO-1115B
P.0. Box 100360
Anchorage, AK 99510
Please note: Blueline, Sepia,~ Tape, Photocopy
ARCO Alaska, f ~
Post Offlb--c-~B0x 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
June 8, 1984
Mr. C. V. Chatterton
Commi s s i oner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK. 99501
SUBJECT: 1B-11GI
Dear Mr. Chatterton:
Enclosed is a Subsequent Sundry Notice for the subject well.
you have any questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Drilling Engineer
JG/tw
GRU7/L87
Enclosure
If
?:ECEIVED
jUN 0 $ i984
~,,; ,:, ~}?~ Cons. Commission
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
-r
KUPARUK ENGINEERING ~-~
Well Name:
Transmittal
DISTRIBUTION
NSK Operations
Dr il 1 lng
Geolbgy/Ken
Blueline
Bluel ine
Film
Blueline & Sepia
Date Run eL
Sign & return the attached
ecei~f~ of ~at.~
copy as r
. -;! :5._iS '...,~28. (;Olli~niSSi.
ATTN: P~u~
ATO-1115B
P.0. Box 100360
Anchorage, AK 99510
MEMORANDUM
TO:
THRU:
FROM:
Sta e of Alaska
Chai~ 2/!~z-.,
FILE
NO:
Lonnie C. Smith/~-"'
Co mm i ss ,i~e~,~ . TELEPHONE NO:
Blair E. Wondzetl SUBJECT:
Senimr Petroleum Engineer
June 7, 1984
A.2e.18
Gas Injection into "A"
Sand, Kuparuk Well
1B-11GI.
Kuparuk River Field Well 1B-11GI was spudded on December 15, 1981,
13 3/8 casing set at 2615', 9 5/8" casing set at 9572', and 7"
liner from 10,698' to 9260'; the well was originally perforated in
the water leg of the "A" sand with 4 SPF at intervals from
10,849'-10,401'; the rig was released on January 20, 1982.
Gas injection for February (1982) was 22,400 MCF; because of the
low rates, an unsuccessful attempt to clean out fill with a Coil
tubing unit was made on February 24 and 25. The well was shut in
during March and April, 1982; at that time a rig was moved in to
clean out the well, to isolate the "A" and "C" sand, to perforate
the "C" sand, and to recomplete with a single tubing string.
In May and June, 1982 both "A" and "C" sands were open for
injection; rates of 339,090 MCF and 384,060 MCF were obtained for
May and June respectively.
From June 27 until December 23, 1982, only the "A" sand was open
for injection, monthly rates varied between 87,610 MCF and 119,967
MCF (excluding December) were obtained.
With both sands open for injection, monthly rates during 1983
varied from a low of 458,880 MCF to a high of 600,050 MCF.
Tom Schmitt (263-4440) of ARCO said they believed that the "A" sand
would not take gas because there was no voidage in the area of
1B-11GI and that the water was relatively incompressible.
.02-00 lA(Rev. 10/79)
.ARCO Alaska, Ir
Post Offi(~e'E"~'~ 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
May 25, 1984
Mr. C. V. Chatterton
Commi s si oner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK. 99501
SUBJECT: 2B-11
Dear Mr. Chatterton:
Enclosed are the well completion report and gyroscopic survey for
the subject well. If you have any questions, please call me at
263-4944.
Sincerely,
D. Gruber
Associate Engineer
JG:tw
GRU7/L67
Enclosure
RECEIVED
MAY ! ]984
Alaska 0il & Gas Cons. Commisslort
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
1. Status of Well Classification of Service Well
OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 84-35
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21089
4. Location of well at surface!'i LOCAiONs'Il 9. Unit or Lease Name
1292' FSL, 828' FEL, Sec.19, TllN, RgE, UM VERIFIED ! Kuparuk River Unit
At Top Producing Interval 10. Well Number
1159' FNL, 1324' FWL, See.20, TllN, RgE, UM Surf
..... 2B-1
'i~ 11. Field and Pool
B.
H.
At Total Depth
976' FNL, 1531' FWL, Sec.20, TllN, RgE, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool
126' RKB ADL 25655, ALK 2581
12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No-ofC°mpIeti°ns
03/14/84 03/21/84 05/11/84I N/A feet MSLI 1
17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost
7676'MD,6158'TVD 7569'MD,6078'TVD YES [] NO [] 1936 feet MDI 1450' (approx)
22. Type Electric or Other Logs Run
DI L/SFL/Cal/FDC/CNL/SP/GR, CBL/GR, Gyro
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5// H-40 Surf 116' 24" 190 sx Col d Set I I
9-5/8" 36.0# J-55 Surf 2892' 12-1/4" 690 sx Permafrost E & 25~) sx Permafrost C
7" 26.0# J-55 Surf 7659' 8-1/2" 300 sx Class "G" & 250 s:( Permafrost C
24. Perforations open to Production (MD+TVD of Top and Bottom and 25~ TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
7281' - 7287' 3-1/2" 7343' 7328' & 7102'
7261' - 7281' w/12 spf See Completion Summary
26. ACID, FRACTURE, CEMENT SOUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
N/A
·
27. N/A PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR el L-BBL GASIMCF WATER-BBL CHOKE SIZE [ GAS-OIL RATIO
I
TEST PERIOD I~
Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF . WATER-BBL OILGRAVITY-API (corr)
Press. 24-HOUR RATE ~
28. -- CORE DATA
Brief descrioti°n °f lith°l°gy' P°r°sity' fractures' apParent dips and presence °f °il' gas °r water' Submit c°re chlJ~s'E C E I V ED None '
11984
Alaska Oil & Gas Cons. Commission
Anchorage
STATE OF ALASKA
' !' ALASN,-¢OI L AN D GAS CONSERVATIONi;_~M MISSION (~/'y:~_
WE L COMPLETION OR RECOMPLETION REPORT AND LOG
Form 10-407 GRU7/WC18 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. 30.
GEOLOGIC MARKERS FORMATION TESTS
'.
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. OEPTH 'TRUE VERT. DEPTH GOR, and time of each phase.
Top Upper Sand 7260' 5847' N/A
Base Upper Sand 7286' 5867'
Top Lower Sand 7368' 5928'
Base Lower Sand 7578' 6085'
31. LIST OF ATTACHMENTS
Drilling Histor¥~ Completion Surmary, Gyroscopic Survey {2 copies)
32. I hereby certify that the foregoing is true and correct to the best of my knowled§e
Signed Title Ar~_a I~r~ 11 i no I~ngr_ Date
INSTRUCTIONS
General' This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
2B-11
DRILLING HISTORY
NU 20" hydril and diverter. Spudded well @ 1400 hrs on 3/14/84. Drld 12¼
hole to 2905'. Ran 73 jts 9-5/8" 36# J-55 BTC csg w/shoe @2892'. Cmtd 9-5/8
csg w/690 sxs Permafrost "E" and 250 sxs Permafrost "C" cmt. Bumped plug
w/1500 psi. Floats held ok. ~ 20" hydril & diverter. Instld 9-5/8 packoff
& tstd. NU BOPE & tstd to 3000'psi - ok witnessed by~ Tstd csg to
1500 psi - ok. Drld FC & cmt. Drld FS and 10' new form. Tstd form to 11.5
ppg - EMW - ok. Drld 8½" hole to 7676'TD as of 3/21/84. Ran logs
DIL/SFL/GR/SP/FDC/CNL/CAL f/7670' to 2892'. Ran 176 jts 7", 26#, J-55 HFERW
BTC csg w/shoe @7659'. Cmtd 7" csg w/300 sxs class "G". Bumped plug w/3000
·
psi. Displ brine from well, performed arctic pack w/250 sxs Permafrost "C" &
58 bbls arctic pack. Secured well and released rig @ 1830 hrs on 3/22/84..
DH125
4/16/84
±h
RECEIVED
MAY 1 ]984
Alaska Oil & Gas Cons, Commission
Anchorage
2P~-11
Completion Summary
RU Dresser-Atlas/Sperry-Sun. Removed lower tree assembly. Ran gauge
ring/JB/CBL/GR f/7552' - 6200'; good bond. Ran Gyro. RD
Dresser-Atlas/Sperry-Sun. Installed lower tree assembly. Secured well.
Accepted rig @ 1800 hrs, 05/08/84. ND tree. NU BOPE & tstd - ok. Spotted
a 25 bbl Bridgesal pill. Perforated the following intervals w/12 spf:
7281' - 7287'
7261' - 7281'
RIH w/gauge ring/JB to PBTD. RIH & set FB-1 W/L pkr @ 7328' Ran 3-1/2"
completion assy w/tail @ 7343', FHL pkr @ 7102', & SSSV @ 193~'. Tstd tbg
to 4000 psi - ok. Tstd ann (top pkr) to 3500 psi - ok. Bled pressure off
ann & tbg. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/30 bbls
diesel followed by Kuparuk crude. Tstd tbg to 2200 psi - ok. Tstd 7" x
3-1/2" ann to 1500 psi - ok. Bled ann to 0 psi. Set BPV. Secured well &
released rig @ 1015 hrs, 05/11/84.
GRU7/CS17:tw
RECEIVED
MAY 11984
Alaska Oil & Gas Cons. Commission
Anchorage
.,.
~ ~: ~i~!.~!?~!!~ii!i~i?j!!i?~iii:i:i!~!iii::?!?: ?i?~!i!:i!~ii~ii~..:;: ???i!?ji?!!~" '7 '?. i~' i~!!: ii . · ~.~!;~:. ~>" :<: (:::):i~ ~"'"~'?'~ "- ...'~ ;><:; ~. ~.' "' ' '
. . ........ ~ ~ ........ ..... ¥.-..%.,: ~ ~.~ · : ~ . '..
KLIPARLIK '~' R ~ ~ ~F'RIL 1 l ~ 17:34 ,JOB NUMBER AK-BCI-40022
ALASKA ' ~ ~ ~ ~ ~ KELLY BLISHIN~3 ELEV. = 126.00 FT.
......... ~ ~--~ * ' ~ ~~- ~ ............................................................................... - ........ ~ ............. t"'-": :-' ~''' .... ' ' ~ :~"~' .......... ~ ......................
".:: ':':::F?' :'~.ii~F~,:::~:M:?i:; ~:i~:i:::i:~ :':':~::: · :;~:::.:.'::Fi!h~:~l~:"' . :~M:: ' .:~::: :' ~.>::. ::.::
~E~SLIRED VER T ~ C~L ~RT~ ~ Nl~ ~ NAT ~ ON D ~ REC T
DEPTH DEPTH DEPTH :.;:~' DEG M I N DEOREES DEG / 1 O0 NORTH/SOLrTH EAST / WE~T':~ ". SECT I O~
"::::::::::::::::::::::: :. ::.:'::-:: ::::::;:, . .: ::.::::::::::::::::::::::::::. ,:.:::: · : ::::::::::::::::::: :: :;, .:~:::::~::~;;:: .. :::: ::::h:~' :. :::" .::'::.:;:::. '::...:.:::::.M :.: ' ": :::. :: :[E::?( ::~: '"::~::;~ :~:~;: ~:~:~ :' ~:~[~[~d~;::::'.~[~:::::;:~]::::!~:~::~iF.[[LF~; ~ : ~:~::~]][(][~[~[~[~::::[~E:~'.::~,':':~E:~[~?
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KLIF'ARL;K APRIL 11., 1'P84
ALASKA
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MEASURED VERTICAL VERTI,QAL, INCLINATION DIREK:TI tin
DEPTH DEPTH i~EP:TH -'" DEG M I N DEGREEF-;
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D E G / 10 ('}
._lOB NUMBER AK-BO-40<'~22
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MEASURED VERTICAL
INCLINATION
DIRECTION
DEPTH DEF'TH DEP~H~?~ DEG M I N DEGREES
KELLY BUSHING ELEV. = 126.o0 FT.
LlUU~J'"I- L~ "' 1 LI I RL .' ::",, -"::":".':.'
'.SEVERITY REIZ:TANGULAF? COORDINATES :V'E. R= I C:ALt" -
DEG / 1 AO NCIRTH /:--:OLITH EAST / WEST ' 'SECT I Obi'
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6300 5158.64 50:32.64 45 57 N 4'F~. 8'P E 0.34 23!:~4.32 N 1644.6? E 28t~'~. 10
6400 5227. 'DS 5101. '75 46 17 N 4'P. 6'? E 0.36 2440.85 N 16'?S). 75 E 2'~6'F~. 68
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"I'HE CALCLILATION PRnF:EDURES ARE BASED ON THE USE OF THREE I]IMENSI()NAL F~ADILIS O1:-- F:IJI..'~VATLIRE METHOD,
: :ARC~::.!~!i!~LA~KA~ I NU:.:: ' .~i~i~;~¢¢~ DATE
KLIPARUK APRIL 11, 1984 dOB NLIMBER AK-BO-40022
ALASKA KELLY BUSHING ELEV. = 126.00 FT.
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]"RUE SUB-S~R TOTRL
MEASURED VERT I CAL VERT I C~L RECTANGLILAR COORD I NATES MD- TVD VERT I CAL
2000 1992.11 1866. 11 64.2:3 N 55.30 E 7.8'F~ 7.88
3000 2868.46 2742.46 4:30.07 N :344.4:3 E 1:31.54 12:3.65
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7676 6158:47 6032.47 3011.$74 N 2359.30 E 1517.53 173.43
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KUPARUK ':' .'::.'.':.. APRIL 11, 1'P84 JOB NUMBER AK-BO-40022
ALASKA
KELLY BUSHING ELEV.' = 126'00 FT.
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l 1-, :1.9:E:4 .Jl-~B NLIMBER AK-BO-40022
KELLY BUSHING ELEV. = 126.00 FT.
lO0 FEET OF SUB-SEA DEPTH', ..:';:":.:"i.,::'!..:.:::.:. ........ :';::..::i!::; :. :;?~:i:i ~ii ii ii:: ~:
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KLFARUK ~:- AF'RIL 11 19:34 ._lOB NLIMBER AK-BO-40022
ALASKA . : .::',~ KELLY BUSHING ELEV. = 12~,.~O FT.
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""~'.~.." ' ;~. APRIL 11, 1'P:34 JOB NI_IMBER AK-BO-4C~022
KELLY BUSHING ELEV. = 1~6,00 FT.
TRUE ']suB'~A l"O T AL
MEA'.SUREI3 VERT I C:AL vERTiCAL REC:TANGLIL_AF;~ CI-II'"IF;~EI I i',1~:~ TES MD-TVD VERT I C':AL
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I<UP~RUK APRIL 11, 17:34 ,_lOB NUMBER AK-'BO-40022
~LAS;K~ KELLY BLIS;HINO ELEV. = 126.00 FT.
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MEASURED VERT I C:AL ' VERT;~L REC:TANGULAR C:OCIRD I NATES;
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7368 5927.72 ._,oC [ 72 2876 78 N 22{'~6.50 E TOF' L.L~Ef.~ S:AN~I
7500 6026.._Pill._ 5'~00. ...~=._, 29:34.5R N 2272. 1 :'3 E S;LIRVEY DEf:'TH
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~ ~[~:~ ::.:~.:~::~:J::.~: :~[:~ ::~S. ::~$;~8~:~:::~x[~:[:<~:~:~::~:~::L:~x:~:~:~: ::: .~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::,1:[~:; L: ,::~:: , ~:: , : ::~:~:::: ::..,: J: ::..:,.:::: J:;::: .x .. ::. :... :.:......::.',-:_ ..,.~.: .x:: :.-::.:::.~.~.~.E:.Lg~;,~,.~,j~F~:~; ,~ :::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::: x :;x :::'g::;:~',,;,h';,': ::::::::::::::::::::: x. :: :~ ::::~g~: : :.~,~ ::::::::~:t;~.:~ .:, .
.......... ...... ........... "' ............ '::::' ' ............. ............................... ':':::~:' ......... ':::':' "¥:~:' "' :~"~'" .... .... ~ :~H]::]E~:E~?~i~?:ii~i::~~:: ~":~:~.
:.:: :.. ~'.::~:::~:~:':~':~:':'.':':':':'.'~:':':?:~'~%':~':':,:':' ....... ~'~'::.. ~.. ':': :': :. :::::::::::::::::::::::.: :: .~ .~ '"~ .. ~: ':.: · .. :~::~:~ . ·
.. ~:~:?i~!i~:~.~L::': :~:~:]:~:~:i:~:~:~?~:~::~i:~:i:~:~:i:~:~:~:i:~:~:~:~1:~G~:~:1: :~:~:~:'::} ':'::~:~i~i~:.~3~:~ii~ :.::. :~!~:,:~<' -'¥2~;~:::~:1:L:?;72.~:i'::::: :2 2.1:~:?~:}:~:E . 2::..~:': ~ .... ::::::::::::::::::::::::: .
,.?""/::".,:. '/,'.~ SEC lt~ ~Ti~N ,ROgE
, ~ ,~,; :.,':. ,,,' ~,,
~'-' ' ~:;' '-' . '" ' ~1 '-'
TCIP UPPER S~ND '7260'' '.: ._,,:,47.4~ .... 7~ i 46 '282'P. ~ 7N 52.1 ~
':2: ', :' ..... '"'":?'~ ........... '"'"':. ': :'"':: · ::?::L: :: :' ," · . ~ ~j Y'~i 'Y":: : :. : ' ,:: ': · ~ - ,~
/?:.: :'-~ :: ::::::::::::::::::: :~':':~?~?:~?:: :':' ::::::::::::::::::::::::::::: :::? ::: :~ :::: .. ~' ~'' /.:.~ :.:L:~::::~?: :.~:::~ :~ :. :~ - ,? ~,~ .............
................................................................................................................... ' ................................ ' ......................................................... .......... ':" .... 5952'; 27
B~SE I_O~ER '.S~ND 7578 /-, (') ::: F~ ..... .02 ...,:"? ~:~ ""; ... ;.. 02 2'P68 . :36N 23~0 .7'PE
TOTAL DEPTH DR I LLER 7676 6158.47 60:32.47 :3011. 'P4N 2:259. :30E
,,.,:.x,:,:.:.:.:..:. ~: :.,,.:,.:.:.:+: .i :...: ......~+.,...,...,.,.,......,.:.:+:.:+:.:.,.:..,,...,-...; .,x,,.:.: ..:..,:,::.,i:: :.:,:,:.:,x,::.:.:.: x.:.:,:t,:,.,:,i.::,:.:.,,x,:,::,x :, x.:: x.: .:.::.: ::.:, :::.. ,i :,.%.:,:.: :.~.~. .... ,,..,........ ... ,, ....x .,- -' · ,. . .. : .: :x:: :. ,:...: ,......,..., .., ..., ,.... ,.:,,...- ,,. :,x ;.:.:,x :,:.:,:.:,:...:.:.:,:,x.:,x.:+:,..:,:.x :.:.:.x.: x.:.x.>m x ::~::~x~:.:':~:~>:':.;.:~:~::~:~:¥:.:~:.x+~.~:~:~:.:~:~:.¥~:~:~:+x~::~.::~>::~:~:.
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:::::::::::::::::::::::::::::
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:::::::::::::::::::::::::::::::::::::::::: ::.::.:::::::~::::::~:~:::::::::;::::::~:~$;::::::.:::::::::::::::g::::::;:::::::::::::~:::::::;:::::::::::::::::;:::::b:;..:;:;:::.::::::~.:::::::::::.:::.;:.:.;`::;.:.;.:';~;~.:.;~;~:.;~;~:<.~.:.~:~:':.:.;`~:~.~;~>~>~:.:`:~:`:.:~:`;:~;.~;`;':*:.:'>:':`:.~:~:``~:~:`:~:`'::`:~:':`:;~;':::.:.:`.:..::~:.;.:.:.;~:~:~:~:'::.:.;.;.;.~;.;s~.`;~.:.;.;.;';':;':.:~:~:~;.;;`'.";:'~``;:;.`.:~`.`~;~```~ :,.:.,, ,,,,,: ,,,~,:,,??..:~;4.;.~x,x~.:,..:.:,:,~.,~...,....,,.,s+., '..'.,.,,,,: .,...,~,,,'~x~.','.',:':?,,,,','.', ;r,,,'".,' .2'"',','"'"",". ,',',:",~'"'""" : ':,' ~,~,~'":~ ~'"'"'"'""--'"'"~'"'"~'""'"'''"'"-: .......
, F:;.~:.L. LY ULI~:;H/NI_~ EL. EV, ::= I:Z6, L)C) FI,
,
:::.:::::::. ,, :::::::::::::::::::::::::::::: :x::: ===================== ...... ~...~....: ....... .:.:.:,.:,,:. x.:..;: :.:::: ':,, : ::;:.x ·,:.:.,,-.,: :. , ~ ::: ..................... ~, ,.,.:,~.p.. ::~::.::,¥~ .~.,:~,:,.,
::::::::::::::::::::::::: =======================================================================-:. :-::.;;., :::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::: :. . ,::.::::::::,::?.~.: :.:.:::..::,~:::: :::::::;..:: , , : : :: : . ;::: ,,::: '.::,,:: :: ;:::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::
ARCO Alaska, Inc.
Our Boss Gyroscopic Survey
Job No. AK-BO-40022
Well: DS 2B-11 (SEC 19 TllN R9E)
Kuparuk Field
North Slope, Alaska
Survey Date: April 10, 1984
Operator: McGui~/~
Scale: 1" = 1000'
-10~0.00
']'RUE NORTH
-3000.00
r 0,00 ·
~oob. oo %ob. oo
~face I~x=ation
1292 F~ 828
--1000.00
HCIR I ZONTRL PROJECT I ON
0.00
ARCO Alaska, Inc.
Our Boss Gyroscopic Survey
Job No. AK-BO-40022
Well: DS 2B-11 (SEC 19 TllN R9E)
Kuparuk Field
North Slope, Alaska
Survey Date: April 10, 1984
Operator: ~re/Samec
Scale: 1" = 1500 '
1500.00
3000.00
4500.00
6000.00
7500.00
-7676
3825.97 @ N 38° 4'E
lsbo. oo aoho. oo 45ho. oo
VERTICAL
PBOJECTION.
Suggested form to be inserted in each "Active" well folder to d~.eck
for timely compliance with our regulations.
· Operator; W~i N~re and Number
Reports and Materials to be received by: ~- /~ Date
Required Date Received Remarks
·
· Ccmpletion Report Yes
._ Well . History, Yes
-..
Samples
·
Mud Leg
.. ,
f ~
Core Description
.Registered Survey Plat ~.~
Inclination Survey /~/~
Drill Stem Test Reports~/~/~./~.~.._ ....
-.
·
·
ARCO Alaska, Ir
Post O f f i ~-~=-~'~'~'100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
May 22, 1984
Mr. C. V. Chatterton
Commi ssi oner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK. 99501
SUBJECT: 2B-11
Dear Mr. Chatterton:
Enclosed is a Subsequent Sundry Report for the subject well.
you have any questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
GRU7/L59:tw
Enclosure
If
RECEIVED
Alaska Oil & Bas Cons. Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA
ALASk._.OIL AND GAS CONSERVATION ._.J~MMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1. DRILLING WELL [] COMPLETED WELL OX
2. Name of Operator 7. Permit No.
ARCO Alaska, Inc. 84-35
3. Address 8. APl Number
P. O. Box 100360, Anchorage, AK 99510 50- 029-21089
OTHER []
4. Location of Well
Surface:
1292' FSL, 828' FEL, Sec.19, TllN, RgE, UM
5. Elevation in feet (indicate KB, DF, etc.)
RKB 126'
12.
I 6. Lease Designation and Serial No.
ADL 25655 ALK 2581
9. Unit or Lease Name
Kuparuk River Unit
10. Well Number
2B-11
11. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF:
(Submit in Triplicate)
Perforate [] Alter Casing [] Perforations
Stimulate [] Abandon [] Stimulation
Repair Well [] Change Plans [] Repairs Made
Pull Tubing [] Other [] Pulling Tubing
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each compietion.)
(Submit in Duplicate)
Altering Casing
[] Abandonment
[] Other
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonmentsee20 AAC 25.105-170).
RU Dresser-Atlas/Sperry-Sun. Removed lower tree assembly. Ran gauge ring/JB/CBL/GR f/7552' - 6200'; good
bond. Ran Gyro. RD Dresser-Atlas/Sperry-Sun. Installed lower tree assembly. Secured well.
Accepted rig ~ 1800 hfs, 05/08/84. ND tree.
Perforated the following intervals w/12 spf:
NU DOPE & tstd - ok.
7281' - 7287'
7261' - 7281'
Spotted a 25 bbl Bridgesal pill.
RIH w/gauge ring/JB to PBTD. RIH & set FB-1W/L pkr @ 7328'. Ran 3-1/2" completion assy w/tail @ 7343', FHU
pkr @ 7102', & SSSV @ 1936'. Tstd tbg to 4000 psi - ok. Tstd-ann (top pkr) to 3500 psi - ok. Bled pressure
off ann & tbg. ND DOPE. NU tree & tstd to 5000 psi - ok. Disp well w/30 bbls diesel followed by Kuparuk
crude. Tstd tbg to 2200 psi - ok. Tstd 7" x 3-1/2" ann to 1500 psi - ok. Bled ann to 0 psi. Set BPV.
Secured well & released rig @ 1015 hrs, 05/11/84.
14. I hereby ce~.l;ify that the foregoing is true and correct to the best of my knowledge.
Signed Title Area Dri 11 i ng Engi neet
The spa o mission use
Condi~j~e'ns of A~.,~0val, if any:
RECEIVED
MAY 2-5 1984
Alaska Oil & Gas Con~. Commission
An~,horage
Date
Approved by
By Order of
COMMISSIONER the Commission
Date
Form i0-403 GRU7/SN23
Rev. 7-1-80
Submit "Intentions" in Triplicate
and "Subsequent Reports" in Duplicate
KUPARUK ENGINEERING
Well Name:
Transmittal
DISTRIBUTION
NSK Operat ions Blueline
Dr ill lng Bluel ine
Geo lbg~~_W__ .....
retur~,.~he___ .~ , .attached~ ~' ~ D
copy as recef~,~-.~a¥', ~ .~,,~
Return to: ARCO A~S~, INC.
ATTN: D. Fay ALL~SON
ATO-1115B
P.0. Box 100360
Anchorage, AK 99510
,~ ~. KUPARUK ENGINEERING
Well Name: ~-// .
Transmittal ~/ .~ ~Q
Lo~ Date
z~,~ !~,~ - ~,~. ~/~'.' ~i~,I~z
Run ~'
DISTRIBUTION
NSK Operat ion Blueline
Dr illing Blueline
Geology/L. J. BI/Se
R&D Blueline
D&M Blueline
F.G. Baker Blueline
D.B. Schafer Blueline
G eology/Ken Film
/~tgn & return the .t~ta~c~e~ copy as re~ip/D
Anchorage
Return to: ARCO ALASKA, INC.
ATTN: D. Fay ALLISON
ATO-1115B
P.O. Box 100360
Anchorage, AK 99510
OHFinal
ARCO Alask.;:,
Post O ffice'=~"~' 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
April 15, 1984
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear Mr. Chatterton:
Enclosed are the Monthly State Reports for the following wells:
2B-9 2F-7 WSP #3
2B-10 2F-8 WSP #9
2B-11 2F-9 WSP #12
2B-12 2F-10 Hemi Springs State #1
2A-1 WSP #1S
Thank you.
Sincerely,
z A~tir~ D~%~rict Drilling Engineer
JBK/SH1: ih
ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany
~ ' STATE OF ALASKA ~ 'r~ ~
M NHLY0 T AL I AND GAS CONSERVATION O~IMISSION (a~.~'~!!~'
REPORT OF DRILLING AND WORKOVER OPERATION 'Y/A
1. Drilling well
Workover operation [~]
3'Ad(;~e/s0. BOX 100360, Anchorage, AK 99510
4. Location of Well
1292' FSL, 828' FEL, Sec.19, TllN, R9E, UM
at surface
5. Elevation in fe~t (indicat~ K~F, etc.)I 6. Lease Desiqnation and Serial No.
PAD 90', 126' ADL 25655 ALK2581
Ma~h
For the Month of
8. APl Nu0~l~r_21089
50-
9. Uni e s Name
k~ ~lver Unit
'°.w fal
11, Field and Pool
KPK River Field
KPK River Oil Pool
, 1¸9
84
2. Depth at end of month, foot~e drilled, fishing jpbs, ~irectional drilling problems, spud date, remarks .
Spudded well @ 1400 hrs, 03/14/84. Drld 12¼" hole to 2905'. Ran, cmtd & tStd 9-5'/8"
csg. Drlg 8½" hole to 7676'TD. Ran logs. Ran, cmtd and tstd 7" csg. Displ brine from
well, performed arctic pack. Secured well. and released rig @ 1830 hfs on 3/22/84.
13. Casing or liner run and quantities of cement, results of pressur9 tests
9-/8" 36# J-55 BTC csg w/shoe @ 2892'. Cmtd w/690 sxs Permafrost "E" and 250
Permafrost "C". 7" 26# J-55 HFERW BTC csg w/shoe @7659'. Cmtd w/300 sxs class "G".
SXS
14. Corin~ resume and brief description
N/A
1§. Logs run and depth where run
DIL/SFL/CAL/FDC/CNL/SP/GR f/7670 to 2892'
16. DST data, perforating data, shows of H2S, miscellaneous data
N/A
APF~ i 9
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
NOTE--Repo~ or~h~/f'o~Cn is required for-each calendar month, regardless of the status of operations, and must be filerd in/~uplicate with the Ala, l(a
Oil and Gas~Cons~va~'o~Commission by the 15th of the succeeding month, unless otherwise directed.
Form 10~,04 v , HI Submit in dup'licate
Rev. 7-1-80
2B-11
DRILLING HISTORY
NU 20" hydril and diverter. Spudded well @ 1400 hrs on 3/14/84. Drld 12¼
hole to 2905'. Ran 73 jts 9-5/8" 36# J-55 BTC csg w/shoe @2892'. Cmtd 9-5/8
csg w/690 sxs Permafrost "E" and 250 sxs Permafrost "C" cmt. Bumped plug
w/1500 psi. Floats held ok. ND 20" hydril & diverter. Instld 9-5/8 packoff
& tstd. NU BOPE & tstd to 3000'psi - ok witnessed by D.O.G. Tstd csg to
_
1500 psi - ok. Drld FC & cmt. Drld FS and 10' new form. Tstd form to 11.5
ppg - EMW - ok. Drld 8½" hole to 7676'TD as of 3/21/84. Ran logs
DIL/SFL/GR/SP/FDC/CNL/CAL f/7670' to 2892'. Ran 176 jts 7", 26#, J-55 HFERW
BTC csg w/shoe @7659'. Cmtd 7" csg w/300 sxs class "G". Bumped plug w/3000
psi. Displ brine from well, performed arctic pack w/250 sxs Permafrost "C" &
58 bbls arctic pack. Secured well and released rig @ 1830 hrs on 3/22/84..
DH125
4/16/84
ih
KUPARUK ENGINEERING
1'0: ~ ~>~vv~'~/k~ ~ ~_~L--~-~ FROH: D. Fay Allison
~/_/~n _~$ WELL NAME'
DATE'
see below
Transmitted herewith are the following'
PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY
Well Description Date
/~E I PT AC ,NOWLEDGED:
PLEASE RETURN RECEIPT TO'
·
ARCO ALASKA, INC.
ATTN' D. FAY ALLISON - ATO/1115-B
P. O. BOX 100360
ANCHORAGE, AK. '99510
DATE'
MEMORANDUM
TO:
THRU:
State of Alaska
ALASKA OIL AND GAS CONSERVATION CO1,R4ISSIOM
C. V. ~~/erton
Chai~'
Lonnie C. Smith
Commissioner
DATE:
FILE NO:
TELEPHONE NO:
FROM:
SUBJECT:
Doug Amos ~
Petroleum Inspector
April 9, 1984
D.41.12
Witness the BOP Test
at ARCO' s Kup 2B- 11,
Sec. 19, TllN,RgE,L~,
Permit No. 84-35 on
Doyon Rig No. 9.
Thursday, .March 15, 1984: After witnessing the retest of Sohio'S
Safety Valve failure's, I traveled to ARCO Kuparuk 2B-11 well to
witness 'the BOP test there.
Friday,. March 16, 1984: The BOP test commenced at 4:00 pm and was
concluded at 5:00 pm. There were no failures and i filled out an
AOGCC BOP test report which is attached.
In summary, I witnessed the successful BOP test at ARCO Kuparuk
2B-11 well.
Attachment
02-O01A(Rev. ~0/79)
~RCO Alaska, In¢
Post Office"lS'6~ox 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
March 15, 1984
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 2B-11
Dear Mr. Chatterton:
Enclosed is a Sundry Notice for the subject well. We propose to
complete this well with our workover rig.
Since we expect to start this work on May 20, 1984, your earliest
approval will be appreciated. If you have any questions, please
call me at 263-4970.
ely,
·
/Area/J~ril 1 ing Engineer
JBK/GRU6L33:tw
Enclosures
RE E VED
,, ....... ]984
/~laska 0il & Gas Cons, Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany
O&G #4
4/80
STATE OF ALASKA
ALASKA OIL & GAS CONSERVATION CObIMISSION
B.O.P.E. Inspection Report
Ope rater
< i~ocation: Sec 14 T
' i~-b~il ling Contractor
Inspector
Date
Well~u~. Z6-il
~eprese.tative ~~, .~,~
Permit # ~ - :~
~l~/~ C~s~n~ Set ~ Z~Z.' ~t.
P3 !
Well Sign
General Housekeeping
Reserve pit
Rig
ACCUMULATOR SYSTEM
BOPE Stack
Annular Preventer
Pipe Rams ~ ~
Blind Rams
Choke Line Valves
H.C.R. Valve ~/
Kill Line Valves
Check Valve
Test Results: Failures
Test Pres sure
Full Charge Pressure_ ~ l~gd)C) psig
Pressure After Closure {.~ ~)F) psig
200 psig Above Precharge Attained:
Full Charge Pressure Attained: ~
N2 ~Z~3oo/~ZOO~ZZCaD ~ '~ Z-(~O psig
Controls: Master . ~ ~
Remote ~.~' Blinds switch cover
Kelly and Floor Safety Valves
Upper Kelly
Lower Kelly
Ball Type /
Inside BOP
Choke Manifold
Test Pressure
Test Pressure
Test Pressure
Test Pressure
~/i Test Pressure
NO. Values
No. flanges
Adjustable Chokes
Hydrauically operated choke
Test Time
Repair or Replacement of failed equipment to be made within
Inspector/Commission office notified.
hrs.. ~ ~
d~ys and
mind. sec.
min.,.~sec
It
Remarks:
Distribution
orig. - AO&GCC
cc -Operator
cc - Supervisor Inspector
STATE OF ALASKA
ALASK,..~IL AND GAS CONSERVATION Q_~MISSION
SUNDRY NOTICES AND REPORTS ON WELLS
OTHER I~X -~'~
1. DRILLING WELL []
COMPLETED WELL []
2. Name of Operator 7. Permit No.
ARCO Alaska, Inc. 84-35
3. Address 8. APl Number
P. O. Box 100360, Anchorage, AK 99510 50- 029-21089
4. Location of Well
Surface: 1292' FSL, 828' FEL, Sec.19, T11N, R9E, UN
5. Elevation in feet (indicate KB, DF, etc.)
1 26' RKB
12.
I 6. Lease Designation and Serial No.
ADL 25655 ALK 2581
9. Unit or Lease Name
Kuparuk River Unit
10. Well Number
2B-11
11. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF:
(Submit in Triplicate)
'~]- Alter Casing [-]- Perforations
Perforate
Stimulate [] Abandon [] Stimulation
Repair Well [] Change Plans [] Repairs Made
Pull Tubing [] Other '3~L Pulling Tubing
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
(Submit in Duplicate)
[] Altering Casing []
[] Abandonment []
[] Other []
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25.105-170).
ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1.
be as follows:
1)
2)
3)
4)
A mast truck will be utilized to run the CBL/VDL/GR and Gyro.
The rig will be moved on location; the BOPE will be nippled up and tested.
The procedure will
Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports.
The well will be completed with 3-1/2", 9.2#/ft, J-55, BTC tubing.
A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested
weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within
the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. Th~
subsurface safety valve will be installed and tested upon conclusion of the job.
I
I
Estimated Start: May 20, 1984
14. I hereby ce, r45~ that the foregoing is true and correct to the best of my knowledge.
Th e space ~w~or ~/~/sion use
Conditio41~ of Appr(~if any:
By Order of
Approved by _I]Y IlAtlRY W. K~[£~ COMMISSIONER the Commission
Approvec~ Cop),
,~__~Returned
Date ~-----~ -//~""~'~...
Form 10-403
Rev. 7-1-80 GRU6/SN12
Submit "Intentions" in Triplicate
an¢ "Subsequent Report~" in Duplicate
March 8, 1984
Mr. Jeffrey B. Kewin
Area Drilling Engineer
ARCO Alaska, Inc.
P. O. Box 100360
Anchorage, Alaska 99510
Re.. Kuparuk River Unit 2B-!1
ARCO Alaska, Inc.
Permit No. 84-35
Sur. Loc. -1292'¥SL, 828'FEL, See. 19, TIIM, RgE, U?~.
Btmhole Loc. 4133'FSL, 1A59'FWL, gee.
Dear Mr. Kewin ~
Enclosed is the approved application for permit to drill the
above referenced well.
If coring is conducted, a one cubic inch chip from each foot of
recovered core is required. Samples of well cuttings and a mud
log are not required. A continuous directional survey is
required as per 20 AAC 25.050(b)(5). If available, a tape
containing the digitized log information shall be submitted on
all logs for copying except experimental logs, velocity
and d!pmeter surveys.
Many rivers in Alaska and their drainage system8 have been
classified as important for the spawning or migration of
anadromou~ fish. Operations in these areas are subject to
AS 16.05.870 and the regulation~ pr~omulgated thereunder (Title 5,
Alaska Administrative Code). Prior to commencing operations you
may be contacted bv the Habitat Coordinator's Office, Department
of Fish and Gm. me.
Pollution of any water~ of the Stat~ is prohibited by AS 46,
Chapter 3, Article 7 and the regulations promulgated thereunder
(Title 18, Alaska Administrative Code, Chapter 70) and by the
Federal Water Pollution Control Act, as amended. Prior to
commencing operations you may be contacted by a representative of
the Department of Environmental Conservation.
To aid us in ~cheduling field work, please notify this office ~4
hours prior to commencing in~ta!lation of the blowout prevention
Jeffrey B. Ke-~in
Kupar~k River Unit 2B-l!
~_i March 8, t984
equipment so that a representative of the Commission may be
present to witness testing of the aqulpment before the surface
casing shoe is dr~led ~here a d!vert~r ~v~t~m i~ requi~ed,
please also notify thi~ offence~4 hourm prior to commencing. ~ .~ ~ ~
equipment insts!latton so that the Commls~ion may witna~s testing
before dr~.l!ing below the sho~ of the conductor pipe,
In. the event of suspension or abandonment, please give this
office adequate advance notification so that we may have a
witness pr~nt.
Very truly yours,
·
.,
·
C. V, Chatterton ~y O~D~}! ~ t~,q5 go~:~ss~o~
Chairman of
Alaska Oil and Gas Conservation Co~!s~ion
Enclosur~
D~partment of Fish & Game, Habitat Sectf. on w/o encl.
Department of F~nvironmental Conm~rvati~n w/o mnc!~
STATE OF ALASKA
ALASKA ~ AND GAS CONSERVATION CO~ISSION
P :RMIT TO DRILL
20 AAC 25.005
la. Type of work.
DRILL
REDRILL
DEEPEN
lb. Type of well
EXPLORATORY []
DEVELOPMENT OIL
DEVELOPMENT GAS []
SERVICE [] STRATIGRAPH IC,~..~
SINGLE ZONE [~]X
MULTIPLE ZONE
2. Name of operator
ARCO Alaska, Inc.
3. Address
P. 0. Box 100360, Anchorage, Alaska 99510
4. Location of well at surface
1292' FSL, 828' FEL, Sec.19, T11N, RgE, UN
At top of proposed producing interval
3893' FSL, 1266' FWL, Sec. 20, T11N, R9E, UN
At total depth
4133' FSL, 1459' FWL, Sec. 20, T11N, RgE, UN
5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no.
RKB 126', PAD 90' I ADL 25655 ALK 2581
12. Bond information (see 20 AAC 25.025) Federal Insurance Company
Type Statewi de Surety and/or number #8088-26-27
13. Distance and direction from nearest town 14. Distance to nearest property or lease line
30 mi. NW of Deadhorse miles 1292 feet
16. Proposed depth (MD & TVD) 17. Number of acres in lease
7563' MD, 6229' TVD feet 2485
19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures
KICK OFF POINT 1450 feet. MAXIMUM HOLE ANGLE 42 oI (see 20 AAC 25.035 (c) (2)
9. Unit or lease name
Kuparuk River Unit
10. Well number
2B-11
11. Field and pool
Kupa ruk Ri vet Fi el d
Kuparuk River Oil Pool
Amount $500,000
15. Distance to nearest drilling or completed
2B-10 well 60~ ~ surface feet
18. Approximate spud date
2720 psig@ 8¢)°F Surface
3125 psig@ 6080 ft. TD (TVD)
SIZE
Hole Casing Weight
~4" 16" 65.5#
~ 2-1/4" 9-5/8" 36.0#
i-1/2" 7" 26.0# J-55 HF-I
22. Describe proposed program:
Proposed Casing,
Coupling
We1 d
:RW BTC
:RW BTC
CASING AND LINER
Grade
H-40
J-55 HF-I
.iner and Cementing Program
SETTING DEPTH QUANTITY OF CEMENT
Length M D
80' 36' I 36'
I
2822
TOP TVD
35' 35'
I
I
1
33' I 33'
7530
MD BOTTOM TVD
116'11 116'
2857 ' I 2733 '
I
7563'16229'
I
I
(include stage data)
+ 200 cf
610 sx Permafrost E &
250 sx Permafrost C
300 sx Class G
ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximate]y 7563' MD (6229'
TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter wil] be insta]led on the 16"
conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the
9-5/8" surface pipe. It will be tested upon instal]ation and weekly thereafter. Test pressure wi]l be 3000 psig
(1800 psi for annular). Expected maximum surface pressure is 2720 psi. Pressure calculations are based on
virgin reservoir pressure. Surface pressure is calcu]ated with an unexpanded gas bubble at surface, including
temperature effects. Casing wi]l be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids
will be left in uncemented annuli through the permafrost interval. Completion operations with the workover rig
wi]l be covered under a separate sundry notice. 2B-11 will be 60' away from 2B-10 at the surface. There are no
other close we]lbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 9-5/8"
x 7" annulus. The 9-5/8" x 7" annu]us will be left with a non-freezing fluid during any interruptions in the
'disposal process.
TITLE Area Drilling Engineer
DATE
CONDITIONS OF APPROVAL
Samples required
[]YES .~O
Permit number
APPROVED BY
Form 10-401
Mud log required
[]YES ~NO
Directional Survey required I APl number
,~¥ES []NO 1 50- o z-~- ~ ,:, ,~'
SEE COVER LETTER FOR OTHER REQUIREMENTS
,COMMISSIONER DATE March 8: 1984
by order of the Commission
Submit in triplicate
i
!
_
-[-
-7--7
i--
.....
-'~ ',
......
::!~ ~l ~':":
:;::~:::::
Surface Diverter System
1. 16"-2000 psi Tankco starting head.
2. Tankco quick connect assy.
3. 16" X 20" 2000 psi double studded adapter.
4. 20" 2000 psi drilling spool w/lO" side outlets.
5. 10" ball valves, hydraulically actuated, w/10" lines
to reserve pit. Valves to open automatically upon
closure of annular preventer.
6. 20" 2000 psi annular preventer.
7. 20" bell nipple.
Maintenance & 0Deration
1. Upon initial installation close annular preventer and
verify ~hat ball valves have opened properly.
2. Close annular preventer and blow air through diverter
lines every 12 hours;
3. Close annular preventer in the event that gas or fluid
flow to surface is detected. If necessary, manually
override and close ball valve to upwind diverter line.
Do not shut in well under any circumstances.
1 6" Conductor
BLIND
'3
I-ID
DIAGRAM ~1
13-5/8" 5000 PSI RSRRA BOP STACK
1, 16" - 2000 psi Tankco starting head
2, 11" - 3000 psi casing head
11" - 3000 psi x 13-5/8" - 5000 psi spacer spool
4, 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling
spool
6, 13-6/8" - 5000 psi pipe rams
6, 13-5/8" - 5000 psi drilling spool w/choke and kill
lines
7, 13-5/8" - 5000 psi pipe rams
8. 13-5./8" - 5000 psi blind rams
g, 12-5/8" - 5000 psi annular
ACCUMULATOR CAPACITY TEST
~1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER
LEVEL WITH HYDRAULIC FLUID.
2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH
1500 PSI DOWNSTREAM OF THE REGULATOR.
3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY
AND RECORD THE TIME AND PRESSURE REMAINING AFTER
ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF.
4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT
IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING
PRESSURE.
.
13-5/8" BOP STACK TEST
1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL.
2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT-
ED. PREDETZRMINE DEPTH THAT TEST PLUG WILL SEAT
AND SEAT IN WELl}iF. AD. RUN IN LOCK DOWN SCREWS IN
HF.~.
3. CLOSE ANNULAR PREVENTER AND V~cg~FJ~S ~S~ O1~ CHOKES.
DON~T TBST AGAINST CLOSED CHOKES
4. TEST ALL COMPONENTS TO 2SO PSI AND HOLD 'FOR 10
MINUTES.
5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10
MINUTES. BLEED TO ZERO PSI.
6. OPEN ANNULAR PREYENTER AND CLOSE TOP SET OF PIPE
RAMS.
7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR i0
B. ~.~'PRESSUR~ DOWNSWREAM OF CHOKE ISOLATION
V. AL.V~S~ TO ZERO PSI TO TEST VALVES.
TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY,
WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI
DOWNSTREAM. BLEED SYSTEM TO ZERO PSI.
9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF
P I PE RAMS.
10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0
MINUTES BLEED TO ZERO PSi.
11. OPEN BOt'TOM SET OF PIPE RAMS. BACK OFF RUNNING
JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS. _AND
TEST TO 3000 PSI FOR lO MINUTES. BLEED TO
PSI.
12, OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE
MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND
ALL VALVE'S ARE SET IN DRILLING POSITION,
13, TEST STANDPIPE VALVES TO 3000 PSI,
14, TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH
KOOMEY PUMP,
lS RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST
' FORM SIGN AND SEND T0 DRILLING SUPERVISOR.
16.PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC-
TIONALLY OPERATE BOPE DAILY.
ARCO Alaska, Inc.
Post Office B(~'~--'t00360
Anchorage, Alaska 99510
Telephone 907 276 1215
v'
February 16, 1984
Mr. C. V. Chatterton
Commi s s i one r
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' Kuparuk 2B-11
Dear Mr. Chatterton'
Enclosed are'
An application for Permit to Drill Kuparuk 2B-11, along with
a $100 application fee
Diagrams showing the proposed horizontal and vertical
projections of the wellbore
o A proximity plat
A diagram and description of the surface hole diverter
system
o A diagram and description of the BOP equipment
Since we estimate spudding this well on March 23, 1984, your
earliest approval will be appreciated.
If you have any questions, please call me at 263-4970.
Sincerely,
/Area B~f~illing Engineer
jBK/JG6/L04' tw
Attachments
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
ARCO Alaska, ' -- -
Post Ot-...~ c~ox 100360 ----~
Anchorage, Alaska 99510
Telephone 907 276 1215
February 1, 1984
Mrs. Elaine Johnson
State of Alaska
Alaska Oil & Gas
Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: Conductor As-Built Location Plat - 2B Pad - Wells 5-12
Dear Elaine:
Enclosed is an as-built location plat for the subject wells.
If you have any questions, please call me at 263-4944.
Sincerely,
J. Gruber
Associate Engineer
JG5/L154: tw
Enclosure
.'
ARCO Alaska, Inc. is a Subsidiary of AtlanlicRIchfieldCompany
19 2O
30
·
CONDUCTORS 5-12
AS. BUILT
LOCATED IN PROTRACTED SECTION 19
TOWNSHIP II N., RANGE 9 E., UMIAT MERIDIAN.
BASIS OF ELEVATION IS TBM 2_B 7 8~ 2B 8 PER LHD&Asso::
BASIS OF LOCATION IS TEMPORARY MONUMENTS 28 NORTH
& 2. B SOUTH PER LHD ~ Assoc.
O.G. ELEV. BASED ON O.G CONTOURS PER STEARNS-ROGER
OWG. NO. 8B-12-30£0 REV. 3.
· f ' ~
AS. BUILT LOCATIONS
WELL~.~ ,': 5
x:
479
954 664.79
508 166.01
FEL, 519 FSL
Lat. 70° 17' 14.4884"
Long. 149° 56'02.059"
I
EL. 91.0 ~ O.G. 87.0'
WELL 6
Y=5
X:
504
954 719.30 Lot. 70° 17'i5.0249''
508 141.09 Long. 149°56'02_.784''
I
FEL, 573 FSL EL. 91.0 ~ O.G. 87.2'
WELL 7
Y: 5 954 773.92
X: 508 116.16
528 FEL,628 ~'SL
Lat. 70° 17'15.562-3''
Long. 149°56'03.508''
I
EL. 91.1, O.G. BT.O'
WELL 8
Y: 5 954 828.53
X: 508091.27
553 FEL,682 FSL
Lat. 70.° 17'16.0998"
Long. 149056'04.232''
EL. 91.0', O.G. 87.0'
WELL 9
Y: 5 955:528.86
X: 507 863.26
779 FEL, 1183 FSL
Lat. 70°17' 21.02.34"
Long. 149° 56'10.861"
EL. 89.4'~ O.G. 85.5'
WELL I0
Y: 5 955
X: 507
803 FEL
38:3.54 Lot. 70°tT'2-I,5614"
838.34 Long. 149°56'll.585"
,1238 FSL EL. 89.4',O.G. 85.0'
WELL !1
Y:5
X:
828
955 458. II Lc3t. 70° 17'22.0985"
507813.47 Long. 149°56'12.308''
FEL, 1292 FSL EL. 89.5', O.G. 84.0'
WELL 12
Y:5
X:
853
955 492.55 Lat. 70°17'22.6341"
507 788.52 Long. 149°56'13.033''
~EL,1347 FSL EL. 89.5', O.G. 84.0'
I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED 8l
LICENSED TO PRACTICE LAND SURVEYING IN' THE. STATE OF
ALASKA ~ THAT THIS PLAT REPRESENTS A SURVEY MADE
UNDER MY DIRECT SUPERVISION 8~ THAT ALL DETAILS ARE
CORRECT AS OF-"~JANUARY 17, 1984.
(IMlfl I'd lllJ $¥1flVltl~
Kuporuk
ARCO AIQske, inc. -.
Project North Slope Drilling
DRILL SITE ?_.B
CONDUCTOR AS. BUILT
LOCATIONS
Date: January. 17~1984 Scale: 1":400'
Draugt~tsman: /l,f.2
Owg. no.: NSK:9.05.202.11
','ii.".[:.?-._..'.':.9~iITEM'.~~[0~:''DATE .... ':':::!J: ' "'(:.'!!' '."-"':??":. ' '. ':'??'':::-, ": '..: .-":"'-':' ':'." "':...:-' ."-.' :.' . '. '...".: :.. ' [yES . NO ."' .'' . ' '"-'- "REMARKS
:',:">-!..: ' "':.:i'.":'~[:. ' _.~. ':'~f ' ' ~. ":: '.' :' -':".~'! :.: .... .'- . . .
~ ~$"'~~'~-v:~'7' ~',' '~'~n ~o ~ 10~.s~ ~ ~~ ~oo~. ............. .... ...; .......
. .." ~z thru. 8) · 3. ~s ~ell located proper distance from property line .................
62 Is well located'proper d~stanee from other wells ..' ...... ~ ..........
'._ 5.. Is sufficient unded~cated acreage available ~n th~s pool ............
" . , 6.. I~ Well to be devSated and.~s well bore plat ~neluded ...............
7. Is operator the on17 affeetod party .................................
8. Can 'pemSt be approved before ten-da7 wa~t ..........................
' (9' thru' 1
#g'~ 3-7-Yq
'(10' ~nd 11)
(~) cas~ ~. ~-7-~
'~(12 thru 20)
(5) BOPE
(21 thru
(6) Add:
.
10.
11.
12.
13.
14.
15.
16.
17.
18,
19.
.20.
21.
22.
23.
24.
25.
Does operator have a bond in force ..................................
Is a conservation order needed .. ......................... . ...........
Is administrative approval needed ................................. ...
Is'"conduCtor string-' provided '
eeeeeeeee eeeeeeeeeeeeeeeeeeeee eeeeeeee
Is enough cement used to circulate on conductor and surface .........
Will cement tie in surface and'intermediate or production strin§s ...
Will cement. cover all known productive horizons .. .............. ,~
Will'surface casing protect fresh water zones ...l...i.'' . ..... ]
Will. ali.casing give adequate safety in collapse, tension and burst'
Is this well to be kicked off from an existing welibore ..............
,
Is old wellbore abandonment procedure included on'10-403 ..... , ......
Is dequate well bore Separation prOposed ' ' #~/~
a eeee.eee.eeee.eeeeeeeeeee.e
Is a 'diverter system required .,...' ' . ..... ~
Are necessary diagrams of diverter ~ BO{'e~6ip~t i~ighg~ ] 1.1.1
Does BOPE have sufficient pressure rating -Test 'to '~.zz~-C) psig .
Does the choke manifold .comply w/AP1 RP-53 (Feb. 78).. .................
Additional requirements ...............................................
N~ T s u gN / TT£ O
Additional Remarks:
.
Geolosy: Eng~e, er~in$:
HWK .~ LC~ BEW
WV~' JK~~_ HJH ~-~
rev: 12/08/83
INITIAL GEO. 'UNIT ON/OFF
POOL CLASS. STATUS AREA NO. SHORE
~,~o/,,o 0~ 1~ ;) ~f ., 1,.I~o
,
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIXi
No special'effort has been made to chronologically '
~ ·
..
organize this category of information.
//
JP nl,n,~02 VEmlPlCAmIn~i L?ST.[~,'{] PAGE 1
** REICflP[) TYPF 137
I,!N Il' ,. YPE CATE SIZE CODE
000 000 016 065
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000 000 008
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000 000
000 000 002 065
000 000 008 06
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************************************************************************************
;%LASWA CONPU'T'ING CW, NTER
************************************************************************************
3~P~Nv = A~L~N~IC ~ICH~IEL~
[KDD : KUPARI~K
]UNTY = NnRmH SLOPE BOROIJGH
ISCOSITY
= 9,6~5" ~ 2.~8~' ' BT'if STZF = 1~,5" TO 7663'
= X"C POI.,Y~{~P
= ~o.~ ~,~./o ~,~ = .~.STO ~ 58,0 Dr
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= 9..5 ,~ R~C = ~.810 ~ 58 0 DF
= ~.0 ( ..... R~.~ a'f 8~'~ = ~.578 ~ {46,0 DF
, , , , , , , , , , , , , , , , , , , , , * , , , , , ,
*
· SCML~BEPGER Lr!.G$ INCLUDWD WTTH THIS M,~GNETIC TAPE',
DUAL !~,~D~CTIO~ SPH~RIC~I, LY FOCUSFD LOG (DIL)
· wO~TI(J~., DE~SI'TY CO~PFNSA~ED LOC (FDN]
,
, , , , , $ , , , , , , , * , , * , , , , , ~ ~ ,
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