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HomeMy WebLinkAbout190-014Originated: Delivered to:26-Aug-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1L-09 50-029-22025-00 910180917 Kuparuk River Plug Setting Record Field- Final 15-Jul-25 0 12 1R-33 50-029-22529-00 910219407 Kuparuk River Leak Detect Log Field- Final 19-Aug-25 0 13 1R-33 50-029-22529-00 910218799 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 14 1Y-06A 50-029-20958-01 910277376 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 23-Aug-25 0 15 1Y-06A 50-029-20958-01 910180481 Kuparuk River Leak Detect Log Field- Final 22-Jul-25 0 16 1Y-06A 50-029-20958-01 910180481 Kuparuk River Plug Setting Record Field- Final 22-Jul-25 0 17 2B-02 50-029-21154-00 910151022 Kuparuk River Packer Setting Record Field- Final 3-Jul-25 0 18 2G-17 50-029-23134-00 910157884 Kuparuk River Leak Detect Log Field- Final 14-Aug-25 0 19 2K-23 50-103-20125-00 910180916 Kuparuk River Plug Setting Record Field- Final 12-Jul-25 0 110 2X-12A 50-029-21189-01 910262801 Kuparuk River Plug Setting Record Field- Final 24-Aug-25 0 1PLEASE 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 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:190-034194-156197-134184-122202-243190-014195-176T40827T40828T40828T40829T40829T40829T40830T40831T40832T408338/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:51:45 -08'00'2K-2350-103-20125-00 910180916Kuparuk RiverPlug Setting RecordField- Final12-Jul-2501202 243190-01419 1 6
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Tuesday, July 22, 2025
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Guy Cook
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
2K-23
KUPARUK RIV UNIT 2K-23
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 07/22/2025
2K-23
50-103-20125-00-00
190-014-0
W
SPT
6080
1900140 1800
2750 2750 2750 2750
590 2000 1925 1910
REQVAR P
Guy Cook
6/11/2025
MIT-OA to 1800 psi per AIO 2C.095.. Testing was completed with a Little Red Services pump truck and calibrated gauges.
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 2K-23
Inspection Date:
Tubing
OA
Packer Depth
410 450 470 470IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitGDC250612081249
BBL Pumped:0.5 BBL Returned:0.5
Tuesday, July 22, 2025 Page 1 of 1
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Tuesday, July 22, 2025
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Guy Cook
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
2K-23
KUPARUK RIV UNIT 2K-23
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 07/22/2025
2K-23
50-103-20125-00-00
190-014-0
W
SPT
6080
1900140 3000
2750 2750 2750 2750
830 1155 1150 1140
REQVAR P
Guy Cook
6/11/2025
MIT-IA to maximum anticipated injection pressure per AIO 2C.095. Testing completed with a Little Red Services pump truck and calibrated
gauges.
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 2K-23
Inspection Date:
Tubing
OA
Packer Depth
460 3470 3350 3300IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitGDC250612080846
BBL Pumped:4 BBL Returned:3.7
Tuesday, July 22, 2025 Page 1 of 1
Originated: Delivered to:3-Jul-25Alaska Oil & Gas Conservation Commiss03Jul25-NR
! "# $$%$ !&$$'($)*%+
($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED3S-705 50-103-20915-00-00 225-047 Kuparuk River WL TTiX IBC FINAL FIELD 20-Jun-252K-23 50-103-20125-00-00 190-014 Kuparuk River WL Hex Plug FINAL FIELD 25-Jun-252L-304 50-103-20613-00-00 210-011 Kuparuk River WL Pressure-Temp Log FINAL FIELD 26-Jun-251B-04 50-029-20595-00-00 181-065 Kuparuk River WL IPROF FINAL FIELD 28-Jun-25Transmittal Receipt//////////////////////////////// 0/////////////////////////////////
+
! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45
%TRANSMITTAL DATETRANSMITTAL #1
67
8 "
! -
+" 8 # !(3 . 8 ) "3
8 # !9
3 :
8" +8 6 8
8 " 8 # !;" " 3
-
3 " 3 ""+
3 +
< +3!%
T40638T40639T40640T406412K-2350-103-20125-00-00190-014Kuparuk RiverWLHex PlugFINAL FIELD25-Jun-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.07.09 09:20:13 -08'00'
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 2K-23 (PTD 190-014) Plan Forward
Date:Tuesday, July 8, 2025 8:18:03 AM
Attachments:AnnComm Surveillance TIO for 2K-23.pdf
From: Bronga, Jaime <Jaime.Bronga@conocophillips.com>
Sent: Monday, July 7, 2025 4:35 PM
To: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Wallace, Chris D (OGC)
<chris.wallace@alaska.gov>
Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>
Subject: KRU 2K-23 (PTD 190-014) Plan Forward
Well Name: 2K-23
Facility: CPF2
PTD: 190-014
Well Type: Inj
AA Number (if applicable): 2C.095
Internal Waiver (Yes/No if applicable): Yes
Type of Issue: Plan Forward
Maximum Pressure (if applicable): 2500
Date of Occurrence (if applicable): 7/1/2025
Hi Chris,
KRU 2K-23 (PTD 190-014) is an injection well with a water injection only waiver due to IAxOA
communication. CPAI shut in and secured the well with a high expansion plug on 6/25/25
because the well was showing tubing restrictions consistent with subsidence. After securing
with the HEX plug the tubing pressure and IA pressure increased. CPAI reported the high IA
pressure on 7/2/2025.
After circulating out the well and pressure testing, it was determined the HEX plug had failed.
The HEX plug was pulled and will be reset. The well’s pressure is now below its OPL. CPAI
intends to keep the well shut in until subsidence remediation is evaluated and decided upon.
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
2K-23 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
2K-23 2025-04-24 960.0 180 -780.0 OA
2K-23 2025-06-12 467.0 300 -167.0 IA
2K-23 2025-07-01 2460.0 1800 -660.0 IA
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 10,147.0 2K-23 9/3/2019 zembaej
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set DV, pulled catcher & HEX plug 2K-23 7/4/2025 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 4/19/2011 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 36.0 115.0 115.0 62.50 H-40 WELDED
SURFACE 9 5/8 8.92 35.3 4,227.6 2,974.7 36.00 J-55 BTC
PRODUCTION 7 6.28 33.0 10,370.1 6,456.7 26.00 J-55 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
31.1
Set Depth …
9,857.9
Set Depth …
6,111.8
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE-MOD
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)
31.1 31.1 0.03 HANGER 8.000 WKM GEN IV TUBING HANGER 3.500
1,789.0 1,656.6 43.16 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY
VALVE (FLAPPER LOCKED OUT
11/4/03)
CAMCO TRDP-
1A SSA
2.812
2,968.5 2,328.5 57.89 GAS LIFT 5.620 MERLA/TMPD MERLA TMPD 2.875
6,056.1 3,932.6 58.70 GAS LIFT 5.620 MERLA/TMPD MERLA TMPD 2.875
7,936.3 4,933.1 57.01 GAS LIFT 5.620 MERLA/TMPD MERLA TMPD 2.875
8,893.9 5,497.7 51.21 GAS LIFT 5.620 MERLA/TMPD MERLA TMPD 2.875
9,337.7 5,777.0 50.47 GAS LIFT 5.793 MERLA/TMPD CAMCO MMG-2 2.920
9,752.7 6,043.7 49.67 GAS LIFT 5.793 MERLA/TMPD CAMCO MMG-2 2.920
9,796.1 6,071.7 49.73 PBR 5.000 BAKER 80-40 PBR w/ 10' STROKE
w/4" SEAL BORE
BAKER 80-40 3.000
9,809.8 6,080.6 49.69 PACKER 6.062 BAKER HB RETRIEVABLE
PACKER
BAKER HB 2.890
9,845.8 6,103.9 49.49 NIPPLE 4.520 OTIS 2.813" XN NIPPLE w/2.75"
NO GO
OTIS XN 2.750
9,857.1 6,111.3 49.43 SOS 4.500 BAKER SHEAR OUT SUB BAKER 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
718.0 715.6 12.40 TIGHT SPOT Tight spot during Subsidence
drift. Only able to drift DMY
HEX plug through this area.
6/2/2025 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)
2,968.5 2,328.5 57.89 1 GAS LIFT DMY BK 1 0.0 11/16/1991 0.000
6,056.1 3,932.6 58.70 2 GAS LIFT DMY BK 1 0.0 11/15/1991 0.000
7,936.3 4,933.1 57.01 3 GAS LIFT DMY BK 1 0.0 5/16/1990 0.000
8,893.9 5,497.7 51.21 4 GAS LIFT DMY BK 1 0.0 11/15/1991 0.000
9,337.7 5,777.0 50.47 5 GAS LIFT DMY RK 1 1/2 0.0 5/16/1990 0.000
9,752.7 6,043.7 49.67 6 GAS LIFT DMY RK 1 1/2 0.0 7/4/2025 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
10,018.0 10,048.0 6,217.0 6,236.9 A-5, 2K-23 1/30/1997 4.0 2 1/8" EnerJet, 0 deg Phase
10,066.0 10,096.0 6,249.0 6,269.1 A-4, 2K-23 5/15/1990 4.0 180 deg. Ph, 4.5" HLS CSG
Guns
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
40.0 103.0 40.0 103.0 Grouting / Top
-Up
Top Job 76 sx 15.7 ppg Arctic Set I ^^Csg
OD=9.625
208.0 4,228.0 208.0 2,975.0 Primary – Full
Bore
Lead 380 bbl 12.1 ppg Arctic Set III + Tail 102 bbl
15.8 ppg Class G... Run 9-5/8" csg - Circ - Pump 80
bbl H2O. Mix & pump AS III Lead, followed by Class
G Tail. Displ w/321 bbl mud. Bump plug w/2000 psi.
CIP @ 17:50 - No cmt returns to surface. **TOC
calculated from annulus volume based on hole
diameter + 20% enlargement ^^Csg OD=9.625
9,453.0 10,370.0 5,850.5 6,456.7 Primary – Full
Bore
Single Stage 49 bbl 15.5 ppg Class G ... Run 7" csg
- Circ csg @ 6.4 BPM, 750 psi - After circ 448 bbl,
lost all returns - Decrease pump rate to 1.5 BPM,
1100 psi - Work back up to 6 BPM, 1700 psi. Batch
up Dowell - Regained returns. Pump 10 bbl CW100
+ 35 bbl Spacer3000. Mix & pump Class G cmt
w/intermittent returns after Spacer rounded shoe -
Pump rate 5 BPM, 1200 psi w/good returns. Displ
w/398 bbl brine @ 10.0 ppg (calc displ @ 394 bbl) -
Did NOT bump plug - Float held. CIP @ 01:00
2/5/90. ^^Csg OD=7
2K-23, 7/6/2025 1:37:04 PM
Vertical schematic (actual)
PRODUCTION; 33.0-10,370.1
Squeeze – Formation Squeeze;
9,909.0 ftKB
Perf; 10,066.0-10,096.0
Perf; 10,018.0-10,048.0
Primary – Full Bore; 9,453.0
ftKB
SOS; 9,857.1
NIPPLE; 9,845.8
PACKER; 9,809.8
PBR; 9,796.1
GAS LIFT; 9,752.7
GAS LIFT; 9,337.7
GAS LIFT; 8,893.9
GAS LIFT; 7,936.3
GAS LIFT; 6,056.1
SURFACE; 35.3-4,227.6
FLOAT SHOE; 4,225.9-4,227.6
FLOAT COLLAR; 4,147.1-
4,148.5
GAS LIFT; 2,968.5
Squeeze – Behind Casing
Squeeze; 2,020.0 ftKB
Primary – Full Bore; 208.0 ftKB
SAFETY VLV; 1,789.0
TIGHT SPOT; 718.0
CONDUCTOR; 36.0-115.0
Grouting / Top-Up; 40.0 ftKB
HANGER; 35.3-39.7
HANGER; 31.1
KUP INJ
KB-Grd (ft)
39.99
RR Date
2/5/1990
Other Elev…
2K-23
...
TD
Act Btm (ftKB)
10,387.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032012500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
61.08
MD (ftKB)
3,500.00
WELLNAME WELLBORE2K-23
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: Flapper Locked Out
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
2,020.0 3,049.0 1,811.5 2,371.7 Squeeze –
Behind Casing
Squeeze
Top Job 30 bbl 15.7 ppg Arctic Set I + Tail 60 bbl 7.5
ppg Arctic Pack... ArcticPack 7" x 9-5/8" annulus:
Water Wash Volume Injected = 400 bbl @ 6 BPM,
900 psi. Mix & pump 30 bbl AS I, followed by 60 bbl
ArcticPack @ 5 BPM, Initial Press = 600 psi, Final
Press = 500 psi. CIP @ 16:00 3/29/90. Press Test
ArcticPack on 4/2/90 w/ 1000 psi; bled to 960 psi in
60 min, Good Test. **TOC calculated from annulus
volume based on hole diameter + 20% enlargement
^^Csg OD=7
9,909.0 10,370.0 6,145.1 6,456.7 Squeeze –
Formation
Squeeze
Squeeze 24.6 bbl 15.8 ppg Class G ... RIH w/sqz
perf gun (2', 6 spf) - Perf @ 10010'-10012' - POOH
L/D perf gun. **TOC calculated from annulus volume
based on hole diameter + 20% enlargement ^^Csg
OD=7
2K-23, 7/6/2025 1:37:05 PM
Vertical schematic (actual)
PRODUCTION; 33.0-10,370.1
Squeeze – Formation Squeeze;
9,909.0 ftKB
Perf; 10,066.0-10,096.0
Perf; 10,018.0-10,048.0
Primary – Full Bore; 9,453.0
ftKB
SOS; 9,857.1
NIPPLE; 9,845.8
PACKER; 9,809.8
PBR; 9,796.1
GAS LIFT; 9,752.7
GAS LIFT; 9,337.7
GAS LIFT; 8,893.9
GAS LIFT; 7,936.3
GAS LIFT; 6,056.1
SURFACE; 35.3-4,227.6
FLOAT SHOE; 4,225.9-4,227.6
FLOAT COLLAR; 4,147.1-
4,148.5
GAS LIFT; 2,968.5
Squeeze – Behind Casing
Squeeze; 2,020.0 ftKB
Primary – Full Bore; 208.0 ftKB
SAFETY VLV; 1,789.0
TIGHT SPOT; 718.0
CONDUCTOR; 36.0-115.0
Grouting / Top-Up; 40.0 ftKB
HANGER; 35.3-39.7
HANGER; 31.1
KUP INJ 2K-23
...
WELLNAME WELLBORE2K-23
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 2K-23 (PTD 190-014) IA Exceeded OPL
Date:Wednesday, July 2, 2025 3:09:35 PM
Attachments:AnnComm Surveillance TIO for 2K-23.pdf
From: Bronga, Jaime <Jaime.Bronga@conocophillips.com>
Sent: Wednesday, July 2, 2025 3:05 PM
To: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Wallace, Chris D (OGC)
<chris.wallace@alaska.gov>
Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>
Subject: KRU 2K-23 (PTD 190-014) IA Exceeded OPL
Well Name: 2K-23
Facility: CPF2
PTD: 190-014
Well Type: Inj
AA Number (if applicable): 2C.095
Internal Waiver (Yes/No if applicable): Yes
Type of Issue: IA Exceeded OPL
Maximum Pressure (if applicable): 2500
Date of Occurrence (if applicable): 7/1/2025
Hi Chris,
KRU 2K-23 (PTD 190-014) is an injection well with a water injection only waiver due to IAxOA
communication. CPAI shut in and secured the well with a high expansion plug on 6/25/25
because the well was showing tubing restrictions consistent with subsidence. After securing
with the HEX plug the tubing pressure has increased. As per our subsidence securing
procedure, we pulled a deep set gas lift valve to allow for circulation from the IA to the tubing
while the well is shut in and economic options on future plans for the well are evaluated. The
tubing and IA pressures have come up to 2500 psi. Bleeds were unsuccessful in reducing the
pressure. CPAI intends to circulate the IA and tubing to water and freeze protect fluids and
conduct pressure tests to evaluate the integrity of the well and HEX plug. The well will remain
shut in and we intend to keep the IA under 2000 psi. If we determine we can not do so, I will
follow up with a plan forward. The OA pressure has not increased with the high IA pressure.
The TIO, schematic, and bleed log is attached.
Warmest regards,
Jaime Bronga
Well Integrity – CPF2 – ConocoPhillips Alaska
Cell: 907-229-8282
2K-23 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
2K-23 2025-04-24 960.0 180 -780.0 OA
2K-23 2025-06-12 467.0 300 -167.0 IA
2K-23 2025-07-01 2460.0 1800 -660.0 IA
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 10,147.0 2K-23 9/3/2019 zembaej
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pulled DV, Set catcher on HEX plug 2K-23 7/1/2025 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 4/19/2011 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 36.0 115.0 115.0 62.50 H-40 WELDED
SURFACE 9 5/8 8.92 35.3 4,227.6 2,974.7 36.00 J-55 BTC
PRODUCTION 7 6.28 33.0 10,370.1 6,456.7 26.00 J-55 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
31.1
Set Depth …
9,857.9
Set Depth …
6,111.8
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE-MOD
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)
31.1 31.1 0.03 HANGER 8.000 WKM GEN IV TUBING HANGER 3.500
1,789.0 1,656.6 43.16 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY
VALVE (FLAPPER LOCKED OUT
11/4/03)
CAMCO TRDP-
1A SSA
2.812
2,968.5 2,328.5 57.89 GAS LIFT 5.620 MERLA/TMPD MERLA TMPD 2.875
6,056.1 3,932.6 58.70 GAS LIFT 5.620 MERLA/TMPD MERLA TMPD 2.875
7,936.3 4,933.1 57.01 GAS LIFT 5.620 MERLA/TMPD MERLA TMPD 2.875
8,893.9 5,497.7 51.21 GAS LIFT 5.620 MERLA/TMPD MERLA TMPD 2.875
9,337.7 5,777.0 50.47 GAS LIFT 5.793 MERLA/TMPD CAMCO MMG-2 2.920
9,752.7 6,043.7 49.67 GAS LIFT 5.793 MERLA/TMPD CAMCO MMG-2 2.920
9,796.1 6,071.7 49.73 PBR 5.000 BAKER 80-40 PBR w/ 10' STROKE
w/4" SEAL BORE
BAKER 80-40 3.000
9,809.8 6,080.6 49.69 PACKER 6.062 BAKER HB RETRIEVABLE
PACKER
BAKER HB 2.890
9,845.8 6,103.9 49.49 NIPPLE 4.520 OTIS 2.813" XN NIPPLE w/2.75"
NO GO
OTIS XN 2.750
9,857.1 6,111.3 49.43 SOS 4.500 BAKER SHEAR OUT SUB BAKER 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
718.0 715.6 12.40 TIGHT SPOT Tight spot during Subsidence
drift. Only able to drift DMY
HEX plug through this area.
6/2/2025 0.000
9,823.0 6,089.1 49.61 CATCHER Set AVA catcher on Hex plug
(34" OAL)
7/1/2025 0.000
9,826.8 6,091.6 49.59 RBP 180-350 HEX PLUG MID-
ELEMENT AT 9830' RKB,
OAL 5.95'
INTERW
ELL
HEX N/A 6/25/2025 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)
2,968.5 2,328.5 57.89 1 GAS LIFT DMY BK 1 0.0 11/16/1991 0.000
6,056.1 3,932.6 58.70 2 GAS LIFT DMY BK 1 0.0 11/15/1991 0.000
7,936.3 4,933.1 57.01 3 GAS LIFT DMY BK 1 0.0 5/16/1990 0.000
8,893.9 5,497.7 51.21 4 GAS LIFT DMY BK 1 0.0 11/15/1991 0.000
9,337.7 5,777.0 50.47 5 GAS LIFT DMY RK 1 1/2 0.0 5/16/1990 0.000
9,752.7 6,043.7 49.67 6 GAS LIFT Open 1 1/2 0.0 6/30/2025 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
10,018.0 10,048.0 6,217.0 6,236.9 A-5, 2K-23 1/30/1997 4.0 2 1/8" EnerJet, 0 deg Phase
10,066.0 10,096.0 6,249.0 6,269.1 A-4, 2K-23 5/15/1990 4.0 180 deg. Ph, 4.5" HLS CSG
Guns
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
40.0 103.0 40.0 103.0 Grouting / Top
-Up
Top Job 76 sx 15.7 ppg Arctic Set I ^^Csg
OD=9.625
208.0 4,228.0 208.0 2,975.0 Primary – Full
Bore
Lead 380 bbl 12.1 ppg Arctic Set III + Tail 102 bbl
15.8 ppg Class G... Run 9-5/8" csg - Circ - Pump 80
bbl H2O. Mix & pump AS III Lead, followed by Class
G Tail. Displ w/321 bbl mud. Bump plug w/2000 psi.
CIP @ 17:50 - No cmt returns to surface. **TOC
calculated from annulus volume based on hole
diameter + 20% enlargement ^^Csg OD=9.625
9,453.0 10,370.0 5,850.5 6,456.7 Primary – Full
Bore
Single Stage 49 bbl 15.5 ppg Class G ... Run 7" csg
- Circ csg @ 6.4 BPM, 750 psi - After circ 448 bbl,
lost all returns - Decrease pump rate to 1.5 BPM,
1100 psi - Work back up to 6 BPM, 1700 psi. Batch
up Dowell - Regained returns. Pump 10 bbl CW100
+ 35 bbl Spacer3000. Mix & pump Class G cmt
w/intermittent returns after Spacer rounded shoe -
Pump rate 5 BPM, 1200 psi w/good returns. Displ
w/398 bbl brine @ 10.0 ppg (calc displ @ 394 bbl) -
Did NOT bump plug - Float held. CIP @ 01:00
2/5/90. ^^Csg OD=7
2K-23, 7/2/2025 9:31:13 AM
Vertical schematic (actual)
PRODUCTION; 33.0-10,370.1
Squeeze – Formation Squeeze;
9,909.0 ftKB
Perf; 10,066.0-10,096.0
Perf; 10,018.0-10,048.0
Primary – Full Bore; 9,453.0
ftKB
SOS; 9,857.1
NIPPLE; 9,845.8
RBP; 9,826.8
CATCHER; 9,823.0
PACKER; 9,809.8
PBR; 9,796.1
GAS LIFT; 9,752.7
GAS LIFT; 9,337.7
GAS LIFT; 8,893.9
GAS LIFT; 7,936.3
GAS LIFT; 6,056.1
SURFACE; 35.3-4,227.6
FLOAT SHOE; 4,225.9-4,227.6
FLOAT COLLAR; 4,147.1-
4,148.5
GAS LIFT; 2,968.5
Squeeze – Behind Casing
Squeeze; 2,020.0 ftKB
Primary – Full Bore; 208.0 ftKB
SAFETY VLV; 1,789.0
TIGHT SPOT; 718.0
CONDUCTOR; 36.0-115.0
Grouting / Top-Up; 40.0 ftKB
HANGER; 35.3-39.7
HANGER; 31.1
KUP INJ
KB-Grd (ft)
39.99
RR Date
2/5/1990
Other Elev…
2K-23
...
TD
Act Btm (ftKB)
10,387.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032012500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
61.08
MD (ftKB)
3,500.00
WELLNAME WELLBORE2K-23
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: Flapper Locked Out
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
2,020.0 3,049.0 1,811.5 2,371.7 Squeeze –
Behind Casing
Squeeze
Top Job 30 bbl 15.7 ppg Arctic Set I + Tail 60 bbl 7.5
ppg Arctic Pack... ArcticPack 7" x 9-5/8" annulus:
Water Wash Volume Injected = 400 bbl @ 6 BPM,
900 psi. Mix & pump 30 bbl AS I, followed by 60 bbl
ArcticPack @ 5 BPM, Initial Press = 600 psi, Final
Press = 500 psi. CIP @ 16:00 3/29/90. Press Test
ArcticPack on 4/2/90 w/ 1000 psi; bled to 960 psi in
60 min, Good Test. **TOC calculated from annulus
volume based on hole diameter + 20% enlargement
^^Csg OD=7
9,909.0 10,370.0 6,145.1 6,456.7 Squeeze –
Formation
Squeeze
Squeeze 24.6 bbl 15.8 ppg Class G ... RIH w/sqz
perf gun (2', 6 spf) - Perf @ 10010'-10012' - POOH
L/D perf gun. **TOC calculated from annulus volume
based on hole diameter + 20% enlargement ^^Csg
OD=7
2K-23, 7/2/2025 9:31:14 AM
Vertical schematic (actual)
PRODUCTION; 33.0-10,370.1
Squeeze – Formation Squeeze;
9,909.0 ftKB
Perf; 10,066.0-10,096.0
Perf; 10,018.0-10,048.0
Primary – Full Bore; 9,453.0
ftKB
SOS; 9,857.1
NIPPLE; 9,845.8
RBP; 9,826.8
CATCHER; 9,823.0
PACKER; 9,809.8
PBR; 9,796.1
GAS LIFT; 9,752.7
GAS LIFT; 9,337.7
GAS LIFT; 8,893.9
GAS LIFT; 7,936.3
GAS LIFT; 6,056.1
SURFACE; 35.3-4,227.6
FLOAT SHOE; 4,225.9-4,227.6
FLOAT COLLAR; 4,147.1-
4,148.5
GAS LIFT; 2,968.5
Squeeze – Behind Casing
Squeeze; 2,020.0 ftKB
Primary – Full Bore; 208.0 ftKB
SAFETY VLV; 1,789.0
TIGHT SPOT; 718.0
CONDUCTOR; 36.0-115.0
Grouting / Top-Up; 40.0 ftKB
HANGER; 35.3-39.7
HANGER; 31.1
KUP INJ 2K-23
...
WELLNAME WELLBORE2K-23
Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2B-02A 50-029-21154-01 910106459 Kuparuk River Multi Finger Caliper Field & Processed 14-Jun-25 0 12 2B-03B 50-029-21151-02 n/a Kuparuk River Radial Bond Record Field- Final 8-Mar-25 0 13 2F-09 50-029-21090-00 910080198 Kuparuk River Plug Setting Record Field- Final 23-May-25 0 14 2F-09 50-029-21090-00 910010602 Kuparuk River Radial Bond Record Field- Final 2-May-25 0 15 2G-17 50-029-23134-00 910106461 Kuparuk River Plug Setting Record Field- Final 9-Jun-25 0 16 2K-23 50-103-20125-00 910099510 Kuparuk River Multi Finger Caliper Field & Processed 2-Jun-25 0 17 2K-34 50-103-20688-00 910096425 Kuparuk River Multi Finger Caliper Field & Processed 15-Jun-25 0 18 2M-08 50-103-20184-00 910027001 Kuparuk River Multi Finger Caliper Field & Processed 9-May-25 0 19 2M-25 50-103-20152-00 910106929 Kuparuk River Plug Setting Record Field- Final 12-Jun-25 0 110 2M-25 50-103-20152-00 910106929 Kuparuk River Tubing Cut Record Field- Final 13-Jun-25 0 1PLEASE 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 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:216-087223-080184-036202-243190-014214-026192-101191-021T40589T40590T40591T40591T40592T40593T40594T40595T40596T405966/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:42:29 -08'00'2K-2350-103-20125-00 910099510Kuparuk RiverMulti Finger CaliperField & Processed2-Jun-2501190-014
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 2K-23 (PTD 190-014) Suspect OA Integrity
Date:Wednesday, January 8, 2025 2:26:50 PM
Attachments:AnnComm Surveillance TIO for 2K-23.pdf
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Wednesday, January 8, 2025 2:00 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>
Subject: KRU 2K-23 (PTD 190-014) Suspect OA Integrity
Hi Chris,
KRU 2K-23 (PTD 190-014) is a water injection well which was flagged for possible OA
integrity issues due to the frequency of OA pressure bleeds. CPAI intends to conduct OA
integrity diagnostics and will share an update when those are concluded. The TIO plot,
bleed log, and schematic are attached. 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
2K-23 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
2K-23 2024-10-23 700 200 -500 OA
2K-23 2024-12-11 700 450 -250 OA
2K-23 2025-01-05 400 200 -200 OA
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB 10,147.0 9/3/2019 2K-23 zembaej
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Pulled Plug & Updtated Tag Depth 9/3/2019 2K-23 zembaej
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
36.0
Set Depth (ftKB)
115.0
Set Depth (TVD) …
115.0
Wt/Len (l…
62.50
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
9 5/8
ID (in)
8.92
Top (ftKB)
35.3
Set Depth (ftKB)
4,227.6
Set Depth (TVD) …
2,974.7
Wt/Len (l…
36.00
Grade
J-55
Top Thread
BTC
Casing Description
PRODUCTION
OD (in)
7
ID (in)
6.28
Top (ftKB)
33.0
Set Depth (ftKB)
10,370.1
Set Depth (TVD) …
6,456.7
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)
31.1
Set Depth (ft…
9,857.9
Set Depth (TVD) (…
6,111.8
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE-MOD
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
31.1 31.1 0.03 HANGER WKM GEN IV TUBING HANGER 3.500
1,789.0 1,656.6 43.16 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE (FLAPPER LOCKED
OUT 11/4/03)
2.812
9,796.1 6,071.7 49.73 PBR BAKER 80-40 PBR w/ 10' STROKE w/4" SEAL BORE 3.000
9,809.8 6,080.6 49.69 PACKER BAKER HB RETRIEVABLE PACKER 2.890
9,845.8 6,103.9 49.49 NIPPLE OTIS 2.813" XN NIPPLE w/2.75" NO GO 2.750
9,857.1 6,111.3 49.43 SOS BAKER SHEAR OUT SUB 3.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
10,018.0 10,048.0 6,217.0 6,236.9 A-5, 2K-23 1/30/1997 4.0 2 1/8" EnerJet, 0 deg Phase
10,066.0 10,096.0 6,249.0 6,269.1 A-4, 2K-23 5/15/1990 4.0 180 deg. Ph, 4.5" HLS CSG
Guns
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 2,968.5 2,328.5 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/16/1991
2 6,056.1 3,932.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/15/1991
3 7,936.3 4,933.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/16/1990
4 8,893.9 5,497.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/15/1991
5 9,337.7 5,777.0 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/16/1990
6 9,752.7 6,043.7 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/8/2015
Notes: General & Safety
End Date Annotation
4/19/2011 NOTE: View Schematic w/ Alaska Schematic9.0
Comment
SSSV: Flapper Locked Out
2K-23, 9/4/2019 8:08:54 AM
Vertical schematic (actual)
PRODUCTION; 33.0-10,370.1
Perf; 10,066.0-10,096.0
Perf; 10,018.0-10,048.0
SOS; 9,857.1
NIPPLE; 9,845.8
PACKER; 9,809.8
PBR; 9,796.1
GAS LIFT; 9,752.7
GAS LIFT; 9,337.7
GAS LIFT; 8,893.9
GAS LIFT; 7,936.3
GAS LIFT; 6,056.1
SURFACE; 35.3-4,227.6
GAS LIFT; 2,968.5
SAFETY VLV; 1,789.0
CONDUCTOR; 36.0-115.0
HANGER; 31.1
KUP INJ
KB-Grd (ft)
39.99
Rig Release Date
2/5/1990
Annotation
Last WO:
End Date
2K-23
H2S (ppm) Date...
TD
Act Btm (ftKB)
10,387.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032012500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
61.08
MD (ftKB)
3,500.00
WELLNAME WELLBORE2K-23
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, July 27, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Brian Bixby
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
2K-23
KUPARUK RIV UNIT 2K-23
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 07/27/2023
2K-23
50-103-20125-00-00
190-014-0
W
SPT
6080
1900140 1520
2810 2810 2810 2810
120 140 140 140
4YRTST P
Brian Bixby
6/27/2023
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 2K-23
Inspection Date:
Tubing
OA
Packer Depth
540 2000 1965 1955IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitBDB230627151732
BBL Pumped:1.7 BBL Returned:1.7
Thursday, July 27, 2023 Page 1 of 1
Wallace, Chris D (CED)
From:
Well Integrity Compliance Specialist CPF1 &2 <n1617@conocophillips.com>
Sent:
Wednesday, October 2, 2019 5:24 PM
To:
Wallace, Chris D (CED)
Cc:
CPA Wells Supt
Subject:
Kuparuk injector 7Z 23 ry_TD 190-0141 30 day monitor completion
Attachments:
2K-23 90 Day TIO plot.JPG; MIT KRU 2K-23 diagnostic MITIA 11 Sept 19.xlsx
Chris,
Kuparuk injector 2K-23 (PTD 190-014) is completing the 30 -day monitor period tomorrow. The well passed a diagnostic
MIT -[A while online and has since shown no signs of loss of integrity. CPA] intends to return the well to normal injection
status. If at any point the well shows signs of compromised barriers the well will be reported as required. Please let us
know if you have any questions or disagree with this plan.
Attached are copies of the current 90 -day TIO plot and 10-426 for the diagnostic MIT -IA.
Dusty Freeborn/Jan Byrne
Wells Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
WELLS TEAM
Conoca' Alps
Chris,
Kuparuk injector 2K-23 (PTD 190-014) was last reported August 4th for failing an MITIA. A tubing plug was set after
which a passing MITT and MITIA were acquired (10-403 attached). The well had previously passed an MITOA and pack
off tests. CPAI intends to bring the well back on injection for a 30 day monitor period. As soon as the well has stabilized
an MITIA will be performed to determine if the leak is symptom of being online or the previous failed MITIA was an
anomaly. The proper paperwork for continued injection or corrective action will be submitted upon conclusion of the
monitor period. Please let us know if you disagree or have any questions with this plan.
Wallace, Chris D (CED)
From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com>
Sent: Wednesday, August 21, 2019 1:52 PM
To: Wallace, Chris D (CED)
Cc: CPA Wells Supt
Subject: KRU 2K-23 (PTD 190-014) Update and plan forward
Attachments: MIT KRU 2K-23 diagnostic MITIA 08-12-19.xlsx
Chris,
Kuparuk injector 2K-23 (PTD 190-014) was last reported August 4`hfor failing an MITIA. A tubing plug was set after which
a passing MITT and MITIA were acquired (10-403 attached). The well had previously passed an MITOA and pack off
tests. CPAI intends to bring the well back on injection for a 30 day monitor period. As soon as the well has stabilized an
MITIA will be performed to determine if the leak is symptom of being online or the previous failed MITIA was an
anomaly. The proper paperwork for continued injection or corrective action will be submitted upon conclusion of the
monitor period.
Please let us know if you disagree or have any questions with this plan.
Regards,
Jan Byrne / Dusty Freeborn
Well Integrity & Compliance Specialist, CPF1 & 2
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
WELLS TEAM
conoc&%Aps
Wallace, Chris D (CED)
From: Well Integrity Compliance Specialist CPF1 &2 <n1617@conocophillips.com>
Sent: Sunday, August 4, 2019 5:38 PM
To: Wallace, Chris D (CED)
Cc: CPA Wells Supt
Subject: RE: Kuparuk injector 2K-23 (PTD 190-014) has shown signs of potential IAxOA
communication.
Attachments: 2K-23 90 Day TIO plot.PNG
Chris-
Kuparuk injector 2K-23 (PTD 190-014) failed the diagnostic MIT -IA that was conducted during the initial set of
diagnostics for suspect IAxOA communication. The well passed an MIT -OA and T & IC pack off tests. The well will be
shut in and freeze protected as soon as reasonably possible. Because the initial set of diagnostics did not indicate IAxOA
communication, further diagnostics will be set up to investigate the failure mechanism of the MIT -IA. Once the
diagnostics have been completed the proper paperwork for continued injection or repairs will be submitted. Please let
me know if you have any questions or disagree with the plan.
Attached is a copy of the updated 90 day TIO plot.
Dusty Freeborn/Jan Byrne
Wells Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
ELLS TEAM
Cawcc'hilps
Ws
From: Well Integrity Compliance Specialist CPH & 2
Sent: Saturday, August 3, 2019 12:37 PM
To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>
Cc: CPA Wells Supt <n1030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2
<n1617@conocophillips.com>
Subject: Kuparuk injector 2K-23 (PTD 190-014) has shown signs of potential IAxOA communication.
Chris-
Kuparuk injector 2K-23 (PTD 190-014) has shown signs of potential IAxOA communication. CPAI intends to leave the
well on water injection and perform a series of diagnostics to confirm or deny the suspect communication. Once the
initial diagnostics have been completed the well will be put on a 90 day monitor period due to the slow nature of the
suspected communication. Depending on the results of the diagnostics and monitor period, the proper paperwork for
continued injection or repair will be submitted. Please let me know if you have any questions or disagree with this plan.
Attached are copies of the 90 -day TIO plot and wellbore schematic.
Dusty Freeborn/Jan Byrne
Wells Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
MEMORANDUM
State of Alaska
2360 -
Alaska Oil and Gas Conservation Commission
TO: Jim Regg //
7` s
DATE: Wednesday, June 26, 2019
SUBJECT: Mechanical Integrity Tess
1/I
P.1. Supervisor tj
-71
2875
530
ConocoPhillips Alaska, Inc.
710-
2K-23
FROM: Lou Laubenstein
KUPARUK RIV UNIT 2K-23
Petroleum Inspector
Sre: Inspector
Reviewed By:
P.I. Sup. 5r
NON -CONFIDENTIAL
Comm
Well Name KUPARUK RIV UNIT 2K-23
Insp Num: mitLOL190611074951
Rel Insp Num:
API Well Number 50-103-20125-00-00 Inspector Name: Lou Laubenstein
Permit Number: 190-014-0 Inspection Date: 6/8/2019
Packer Depth
21c-23 Type Inj W 'ITVD
1900140 (Type Testi SPT Test p
I'umped_i 22 " IBBL Returned:
Notes:
Pretest Initial 15 Min 30 Min 45 Min 60 Min
2360 "'
2360
2360 -
2360
1060—
3000 -
2915 -
I.
2875
530
710
710-
710
Wednesday, June 26, 2019 Page I of 1
t4a-al1f
0qO- \4
• S 2G54c�
WELL LOG TRANSMITTAL #902898175
To: Alaska Oil and Gas Conservation Comm. December 11, 2015
Attn.: Makana BenderRECF i= a c.,�,
333 West 7th Avenue, Suite 100 - ° "
DATA LOGGED
Anchorage, Alaska 99501 r t; 15 L ,9; ` icb/2o,G,
n �'� M K BENDER
AOGCC
RE: Static Bottom Hole Pressure Record: 2K-23 Das2 - 01L./J)Run Date: 11/11/2015
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
2K-23
Digital Data in LAS format, Digital Log Image file 1 CD Rom
50-103-20125-00
Static Bottom Hole Pressure Record (Field Print) 1 Color Log
50-103-20125-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline &Perforating
Attn: Fanny Sari SGAl�HED MAY 0 22016
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-275-2605
Fax: 907-273-3535
FRS_ANC@halliburton.com
Date: Signed: • t , ;/,
• S
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Tuesday,July 14,2015
TO: Jim Regg
P.I.Supervisor ��l �I r I/S SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2K-23
FROM: Chuck ScheveSCANNE e `s KUPARUK RIV UNIT 2K-23
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry :74. --
NON-CONFIDENTIAL
..=NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 2K-23 API Well Number 50-103-20125-00-00 Inspector Name: Chuck Scheve
Permit Number: 190-014-0 Inspection Date: 7/10/2015
Insp Num: mitCS150713095221
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 2K-23 ;Type Inj "v' TVD 1 6080 - Tubing; 2625 - 2625. 2625- f 2625-
PTD 1900140 Type Test SPT Test psi 1520 - IA 920 1980 - 1960 . 1960 •
Interval
4YRTST P/F P OA180 1 200 - 200 200 .
Notes:
Tuesday,July 14,2015 Page 1 of 1
Pages NOT Scanned in this Well History File
XHVZE
This page identifies those items that were not scanned during the initial scanning project.
They are available in the original file and viewable by direct inspection.
I C~0" 0 IJ~ File Number of Well History File
PAGES TO DELETE
RESCAN
[] Color items - Pages:
[] Grayscale, halftones, pictures, graphs, charts-
Pages:
[] Poor Quality Original - Pages:
[] Other- Pages:
DIGITAL DATA
[] Diskettes, No.
[] Other, No/Type
OVERSIZED
[] Logs of various kinds
[] Other
Complete
COMMENTS:
Scanned by:~
[] TO RE-SCAN
Notes:
Bren Vincent Nathan Lowell
Re-Scanned by: Bevedy Bren Vincent Nathan Lowell
Date: /si
NOTScanned.wpd
. •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Tuesday, June 28, 2011
TO: Jim Regg
P.I. Supervisor 7 7 IV i( SUBJECT: Mechanical Integrity Tests
( CONOCOPHILLIPS ALASKA INC
2K -23
FROM: John Crisp KUPARUK RIV UNIT 2K -23
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Supry �a
2
NON - CONFIDENTIAL Comm
Well Name: KUPARUK RIV UNIT 2K - 23 API Well Number: 50 - 103 - 20125 - 00 - 00 Inspector Name: John Crisp
Insp Num: mitJCr110628111121 Permit Number: 190 - 014 - Inspection Date: 6/24/2011
Rel Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well I 2K -23 'Type Inj. W 1 TVD , — 1 —
6080 IA 620 2100 1980 1960
P.T.D 1900 140 TypeTest SPT I, Test psi 1520 ' I OA 350 370 370 370
Interval = P/F P Tubing 2600 2630 2630 2610 1
Notes: 3.5 bbls pumped. No problems witnessed.
Tuesday, June 28, 2011 Page 1 of 1
ConocoPhillips
~~
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 1, 2010
Commissioner Dan Seamount
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100 _ , „ ` ~~ ~ $ _
Anchorage, AK 99501 "" "~" ' ~~ `~`
Commissioner Dan Seamount:
or°~`~
tiq ,
~~
~~~
F"!4I V ~ V ~~ ~:
~, - ~,~~'tnission
~laskn ~ ~~c~~t~ga
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 corrosion
inhibitor, engineered to prevent water from entering the annular space. As per previous
agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments
took place and meets the requirements of form 10-404, Report of Sundry Operations.
The cement was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30th, 31St
2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and
volumes used on each conductor.
Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions.
Sincerely,
MJ Loveland
ConocoPhillips Well Integrity Projects Supervisor
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Date 8/01/10 ~R ~K ~T aen
Well Name
API #
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
26-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010
2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010
2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010
2K-23 50103201250000' 10140 SF n!a 18" n/a 2.6 7!31/2010
2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010
2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010
2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010
2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010
2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010
2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010
2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010
2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010
2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010
2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010
2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010
2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010
2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010
2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010
2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010
2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010
MEMORANDUM
.
State of Alaska .
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg OJ
P.I. Supervisor I\¿tí c.lÞf?
DATE: Wednesday, June 06, 2007
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2K-23
KUPARUK RIV UNIT 2K-23
Src: Inspector
\qó~O\lf
FROM:
Chuck Scheve
Petroleum Inspector
Well Name: KUPARUK RIV UNIT 2K-23 API Well Number: 50-103-20125-00-00 Inspector Name: Chuck Scheve
Insp Num: mitCS070601182113 Permit Number: 190-0 14-0 . /'
Inspection Date: 6/1/2007
Rei Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well 2K-23 Type Inj. w TVD I 6081 IA 350 2420 2400 2400
P.T.D 1900140 TypeTest SPT Test psi I 1520.25 OA 60 60 60 60
Interval 4YRTST P/F P Tubing 2500 2500 2500 2500
Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. ;/'
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv:1?Jz--
Comm
SCANNED JUN· 2 0 2007
Wednesday, June 06, 2007
Page 1 of I
MEMORANDUM
e
State of Alaska
e
Alaska Oil and Gas Conservation Commission
TO: Jim Regg?,
P.I. Supervisor ¡ \ tf¡
I {' ("
~tl.L/~'
DATE: Wednesday, May 17,2006
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2K-23
KUPARUK RIV UNIT 2K-23
, 0\\1"
\ lZt°
FROM: Chuck Scheve
Petroleum Inspector
Src: Inspector
Reviewed By:
-~>~.~
P.I. Suprv -J I:jL-
Comm
NON-CONFIDENTIAL
Well Name: KUPARUK RIV UNIT 2K-23 API Well Number 50-103-20125-00-00 Inspector Name: Chuck Scheve
Insp Num: mitCS060515061408 Permit Number: 190-014-0 Inspection Date: 5/14/2006
ReI Insp Num
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well I 2K-23 ¡Type Inj. j N iTVD 6081 ^T-- IA i 650 2200 2130 2130 i
I i i I
ITypeTest I SPT i Test psi I - ¡-
P.T. 1900140 1520.25 OA i 540 560 560 560 I
i I I I -------L-___
Interval WRTST P/F p Tubing i 1600 1600 I 1600 1600 I
,
Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity.
~C!i\NNEÜ .JUN i
3 2D
Wednesday, May 17, 2006
Page I of I
THE MATERIAL UNDER THIS COVER HAS BEEN
MICROFILMED
ON OR BEFORE
OCTOBER 27, 2000
P
M
C:LORI~IFILM,DOC
E
E
L E W
A T E R IA L U N D E
TH IS M ARK ER
R
STATE OF ALASKA
AL~dKA OIL AND GAS CONSERVATION COMMIS~ION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Operation Shutdown Stimulate X Plugging
Pull tubing Alter casing Repair well
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
319' FNL, 95' FEL, Sec. 11, T10N, R8E, UM
At top of productive interval
1325' FSL, 813' FEL, Sec. 12, T10N, R8E, UM
At effective depth
1181' FNL, 1144' FEL, Sec. 12, T10N, RSE, UM
At total depth
1106' FNL, 1294' FEL, Sec. 12, T10N, RSE, UM
12. Present well condition summary
Total Depth: measured
true vertical
1 0387 feet
6468 feet
6. Datum elevation (DF or KB)
RKB 154
7. Unit or Property name
Kuparuk River Unit
8. Well number
2K-23
9. Permit number/approval number
90-14
10. APl number
50-103-20125
11. Field/Pool
feet
Plugs (measured)
Kuparuk River Field/Oil Pool
None
Effective depth:
measured I 01 6 0 feet
true vertical 6 31 3 feet
Junk (measured) None
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation depth:
Length Size Cemented
8 0' 1 6" 170 Sx AS II
41 91' 9-5/8" 1100SxAS III&
500 Sx Class G
10334' 7" 225 Sx Class G
measured
1 001 8'-1 0048', 1 0066'-1 0096'
true vertical
621 7'-6237', 6249'-6269'
Tubing (size, grade, and measured depth)
3.5", 9.3#/ft., J-55 @ 9858'
Packers and SSSV (type and measured depth)
Packer: Brown HB @ 9810'; SSSV: Camco TRDP-1A-SSA @ 1789'
Measureddepth
115'
4228'
1037O'
Trueverticaldepth
115'
2975'
6523'
13. Stimulation or cement squeeze summary
Fracture stimulate 'A' Sands on 2/13/97 ORIGINAL
Intervals treated (measured)
1 001 8'-1 0048', 1 0066'-1 0096'
Treatment description including volumes used and final pressure
Pumped 73.8 Mlbs of 16/20 ceramic proppant into formation, fl:) was 8400 psi
14. Representative Daily Average Production or Injection Data
Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation 0 1 0 2 0 0 1380
2655
Subsequent to operation
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations X
0 1 61 8 0 1400
16. Status of well classification as:
Oil Gas
Suspended Service X
2483
7. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed ~.,~~ ~,.,~ Title Wells Superintendent
Form 1/0 ~ ~R ~v./06'/¢¢~
/
SUBMI~IN DUPLICATE
STATE OF ALASKA '
AI.~,SKA OIL AND GAS CONSERVATION COMMISo~ON
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Operation Shutdown Stimulate Plugging
Pull tubing Alter casing Repair well
Perforate X
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
319' FNL, 95' FEL, Sec. 11, T10N, R8E, UM
At top of productive interval
1325' FSL, 813' FEL, Sec. 12, T10N, R8E, UM
At effective depth
1181' FNL, 1144' FEL, Sec. 12, T10N, R8E, UM
At total depth
1106' FNL, 1294' FEL, Sec. 12, T10N, RSE, UM
12. Present well condition summary
Total Depth: measured 1 0
true vertical 64
6. Datum elevation (DF or KB)
RKB 154
7. Unit or Property name
Kuparuk River Unit
8. Well number
2K-23
9. Permit number/approval number
90-14
10. APl number
50-103-20125
11. Field/Pool
Kuparuk River Field/Oil Pool
387 feet
68 feet
Plugs (measured) None
feet
Effective depth: measured 1 01 6 0 feet
true vertical 6313 feet
Junk (measured) None
Casing Length Size Cemented
Structural
Conductor 80' 1 6" 170 Sx AS II
Surface 41 91 ' 9 - 5 / 8" 1100 Sx AS III &
Intermediate 500 Sx Class G
Production 10334' 7" 225 Sx Class G
Liner
Perforation depth: measured
1 001 8'-1 0048', 1 0066'-1 0096'
true vertical
6217'-6237', 6249'-6269'
Tubing (size, grade, and measured depth)
3.5", 9.3#/ft., J-55 @ 9858'
Packers and SSSV (type and measured depth)
Packer: Brown HB @ 9810'; SSSV: Camco TRDP-1A-SSA @ 1789'
Measured depth
115'
4228'
10370'
True vertical depth
115'
2975'
6523'
13. Stimulation or cement squeeze summary
14.
Perforate 'A' Sands on 1/30/97 ....
Intervals treated (measured)
10018'-10048' r.
Treatment description including volumes used and final pressure
Perforated using 2-1/8" EJ guns, DP charges, 0° phasing, @ 4 spf, fp was 2500 psi
Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation 0 1152 0 1380
2693
Subsequent to operation
0 1152 0 1380
2693
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations X
16. Status of well classification as:
Oil Gas Suspended Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed (~~~~~~ Title Wells Superintendent
Form 11404/' R'e~ d6~15~¢'~ -
/
Date ~2J~
SUBMIT IN DUPLICATE
ARCO Alaska, Inc,
Post' Office ~.... 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
January 20, 1992
Mr. Blair Wondzell
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear Mr. Wondzell:
In response to your questions concerning the cement integrity in Wells 1L-
I0 and 2K-23, I have researched our drilling records to verify that a cement
squeeze was performed across the Ku~ interval in these wells. As you
noted, based on the initial Cement bond log, the primary cement job in
Well.s 1L-10 and 2K.~.~23 did not appear, to be adequate for these wells to be
operated as Class II UIC wells.' However, both of these wells had
subSequent cement squeezes performed by a completion rig after the
cement bond log but prior t° injection of any fluids into the well. Well 1L-10
was squeezed on June 2, 1990, with 43.2 BBLS of cement to a squeeze
pressure of 2840 psi. Well 2K-23 was squeezed on May 13, 1990, with
29.6 BBLS of cement to a squeeze pressure of 3020 psi.
It is not standard.operating procedure to perform follow-up cement bond
logs on every squeeze, however we do run them on an occasional basis to
evaluate the effectiveness of our squeeze operations. To date, these
follow-up cement bond logs indicate that we have had excellent success
with our cement placement.
if additional data is needed, please contact me at 263-4281.
Sincerely,
C. W. Strickland
Operations Fngineer
CWS/kz
CC:
J. D. Bolling
A. W. McBride
G. W. Targac
P. S. White
KOE 1.5-5
ATO- 1196 ~
ATO- 1448
ATO-1186
ATO-1128
RECEIVED
JAN 2 2 1992
0it & (}as Co~. Commlsslen
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B.d003-C
STATE OF ALASKA ~t
AL/~ OIL AND GAS CONSERVATION COMMISblON
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Operation Shutdown__
Pull tubing Alter casing
Stimulate __ Plugging Perforate _
Repair well Other
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 k
4. Location of well at surface
319' FNL, 95' FEL, Sec. 11, T10N, R8E, UM
At top of productive interval
1186' FSL, 813' FEL, Sec. 12, T10N, R8E, UM
At effective depth
1216' FSL, 875' FEL, Sec. 12, T10N, R8E, UM
At total depth
1012' FNL, 1294' FEL, Sec. 12, T10N, R8E, UM
12.
Present well condition summary
Total Depth: measured
true vertical
1 0387' feet
6451 ' feet
Plugs (measured)
None
6. Datum elevation (DF or KB)
154' RKB
7. Unit or Property name
Kuparuk River Unit
feet
8. Well number
;~k-;~3
9. Permit number/approval number
~0-14
10. APl number
50-1 0;~- 201 25
11. Field/Pool
Kuparuk River Oil Pool
Effective depth:
measured 10288' feet
true vertical 6382' feet
Junk (measured)
None
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation depth:
Length Size
115' 16"
4228' 9 5/8"
1 0370' 7"
measured
10066'-10096'
true vertical
6249'-6269'
Tubing (size, grade, and measured depth)
3.5" J-55 set at 9858'
Packers and SSSV (type and measured depth)
Brown HB @ 9810',
Cemented
1100 SxAS III &
500 Sx Class G
225 Sx Class G
4.5" Casing Gun @ 4 SPF
Camco TRDP-1A-SSA @ 1789'
13. Stimulation or cement squeeze summary
Intervals treated (measured)
Treatment description including volumes used and final pressure
Measured depth
115'
4228'
10370'
True vertical depth
115'
4235'
6439'
REEEIVED
Oil & Sas Cons..Comraisslen
chOrage
14.
Prior to well operation
Subsequent to operation
Representative Daily Average Production or Injection ~t~
OiI-Bbl Gas-Md Water-Bbl Casing Pressure
238 1 71 7 2 11 25
-0-
0- 2OO5 1000
Tubing Pressure
248
1809
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations __
16. Status of well classification as: Water Injector ~
Oil __ Gas Suspended
Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Title
Form 10-404 Rev 09/12/90
Date
SUBMIT IN DUPLICATE
, W Z S E O T
L N A
L E T
PRODUCTION WELL STATUS
%" 10"
·
TP TT WC H~S CS~
PSI CHK DEQ' % PPM PSt_ PSI
261 176 76 1 .15 1200 700
267 176 1~1 29 30 1300 900
'262 176 43 0 -5 1100 600
_
261 176 48 0 . .5-~00 300
.
~61 176 53 0~., 42 800 300
261 176 51 5 15 1000 300
2~0 176 71 I 15 800 600
261 176 46 0 40 800 700
261 176 · 35 a 40 600 400
15 1200 600
0 1000 550
5 800 750
5 1100 600
5 1100 600
5 950. 700
5 1000 150'
5 800 '400
287 176 64 0
256 176 43 0
260 178 41 0
261 176 50 0-
259 176 43 1
261 176 33 0
259 176 19 0
261 17~ 48 0
,·
INdEcTION WELL STATUS
ACT ' 7" I0"
IN,] TT CSQ CSQ
PSI DEQ CHK PSI PSI
i A PR
~ B PR
3 A PR
4 A PR
7 A PR
8 APR
V A PR
11 APR
14- A PR
15 A TS
16 A PR
17 A PR
19 A PR
21 A PR
:2.2 A PR
25 A PR
~6 A PR
TOTALS
W Z S,
E 0 T ALLOW
L N A INJ
L E T PSI
OAS LIFT STATUS
CN
~AS INJ AH H M O
TEMP METER RATE LI .- R, I' D EPL
DE~ READINQ MSCF EB S N E.BI]LS
S/I iP~PACT
68 8020 97~ 0 O00O 0 0
30 2068 0 0 0000 0 0
50 78~0 340 O' 0000 0 0
60 2~70 634 0 OOO0 0 0
50 1870 96~ 0 OOOO 0 0
65 3500 16~8 0 0000 0
50 3400 426 0 0000 0 0
45 160 611 0 OOOO' 0 0
44 7640 a67 0 GO00 O O
60 8200 1257 0 0000 0 0
50 1700 711 0 0000 0 0
40 2120 735 0 0000 0 0
65 100 94.9 0 0000 0 0
' 60 3700 475 0 0000 0 0
50 9400 527 0 0000 0 0
50 8930'\ 203 0 0000 0 0
45 250 909 0 0000 0 0
11613 0 0
INOECTION RATE
.
S/[
H M 0
R I D
S N E
INJ INJ
METER RATE RATE
READING BPD MMSCFD
5 A SW
6 B SW
10 A SW
la A SW
13 B SW
!8 A SW
20 A SW
23 8 SW
24 B SW
TOTALS.
2500 1976 67 ~5 1600 600
2500 1796 67 14 1100 600
.
·
2500 2307 6~ 55' 1100 0
2500 'a3a~ 6~ 176 1400 500
2500 23a7:'"~7. 17~ 1600 500
2500 23~8~-. 67'176 1000 550
2500 180~ ~3 27 1000 9~0
2500 2104 60 loa 1400 800
.
SWI' 14132 + PWI'
,.
.
2600 1609 0.000
7230 1494 0.000
6640 1505 0.000
3990 1859 0 000
350 917 0 000
38~5 1417 0 000
8640 864 0 000
215 2005 0 000
2830 2462 0 000
0 = 1413~ 0.000
0000 0
0000 0
0930 55
0000 0
0000 0
0000 0
0000 0
0000 0
0000 0
1. Type of Request: Abandon
2. Name of Operator
APPLICATION FOR SUNDRY APPROVALS
_ Suspend _
ARCO Alaska. Inc.
3. Address
,P. O. Box 100360, Anchorage, AK 99510
4. Location of well at surface
319' FNL, 95' FEL, SEC 11, T10N, R8E, UM
At top of productive interval
1186' FSL, 813' FEL, SEC 12, T10N, R8E, UM
At effective depth
1216' FSL, 875' FEL, Sec. 12, T10N, R8E, UM
At total depth
1012' FNLr 1294' FELr Sec. 12r T10N~ RSE~ UM
12, Present well condition summary
Total Depth: measured
Effective depth:
Alter casing _ Repair well _
Change approved program _ Pull tubing _
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
10387
true vertical 6 4 51
measured 1 0 2 8 8
true vertical 6 3 8 2
Length Size
115' 16"
4228' 9 5/8"
#
10370'
measured
10066'-10096'
Operation Shutdown _ Re-enter suspended well_
Plugging _ Time extension _ Stimulate _
Variance _ Perforate _ Other
6. Datum elevation (DF or KB)
feet Plugs (measured)
feet Notre
feet Junk (measured)
feet None
RKB 154
7. Unit or Property name
Kuparuk River Unit
8. Well number
2K-23
9. Permit number
90-14
feet
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation depth:
10. APl number
so-103-20125
11. Field/Pool Kuparuk River Field
Kuparuk River Oil Pool
Cemented Measured depth True vertical depth
115' 115'
1100 Sx AS III & 4228' 4235'
500 Sx Class G
225 Sx Class G 1 03 70' 6 4 3 9'
4.5" Casing Gun @ 4 SPF
true vertical
6,249'-6,269'
Tubing (size, grade, and measured depth)
3.5" J-55 set at 9,858'
Packers and SSSV (type and measured depth)
Brown HB ~-~ 9810'~ Camco TRDP-1A-SSA ~ 1789'
13. Attachments Description summary of proposal Detailed operation program X
Convert well from oil producer to water injector. ~'Wellbom schematic attached).
14. Estimated date for-commencing operation 115. Status of well classification as:
November 1991 I Oil m Gas ~
16. If'lDr°p°sal[~ ~ L~o~[~was v,erbally approved O~ ~ 1°/3 ~/~1 I
~ ~' '/ Date approvedI Service Water
Name of approvee
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed '~' ~ , Title operations Enc~ineer
FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity ~ BOP Test_ Location clearance ~
Integrity Test ~,/ Subsequent form require
10- ~-" ~'
Mechanical
Iniector
BOP sketch
Suspended
IApproval No. ,.~.~
~qetumed
Approved b~f order of the Commission
Form 10-403 Rev 09/12/90
ORIGINAL SIGNED BY
LOi~i[-,iiE C,
Commissioner
Date I/' ~ * ?/
SUBMIT IN TRIPLICATE
:tessrs. Fonten(~t and Wllde'~-''
10/26/91
Page 2
1)
2)
3)
4)
5)
6)
7)
8)
9)
Wells 2K-13, 2K-23 and 2K-24
Water Injection Conversions
Charge Code: Downhole 994901; Surface 994928
10/23/91
If possible, obtain final 12 hour welltest and SI well for 72 hours. This will enable an
accurate static BHP measurement which is important for waterflood surveillance
analysis. Notify G. Targac(x6849) to insure that the sundry notices for converting the
wells to water Injection have been approved by the State.
MIRU slickline unit and diesel pump truck.
RIH and set SV in Otis 'XN' or 'D' nipple. Well 2K-24 has 2-7~8" tubing and a Camco
'D' nipple.
Pump diesel down casing while taking return from tubing.
volumes shown below:
Annulur Volume
Wel| to Btm Mandrel
2 K- 1 3 239 bbls
2 K- 2 3 258 bbls
2 K - 2 4 276 bbls
Fill annulus with diesel
3 1/2' tubing X 7" casing
3 1/2' tubing X 7" casing
2 7/8" tubing X 7" casing
RIH to replace GLV's and OV's with DV's (see attached wellbore schematics for depths).
Ensure the casing/tubing annulus is filled with diesel. Pressure test tubing to 2500
psi to ensure DV's are set. Place 2000 psi on casing while pressure testing lo prevent
tubing buckling.
RIH and pull SV. RIH w/Panex gauge or Amerada gauge to mid A Sand perforation for
15 minute static pressure. POOH and take static pressure measurement in the
lubricator.
RDMO Slickline. Notify the State of the Mechanical Integrity Tests (MIT's).
Conduct MIT tests. Packer depths and 7' annular pressures necessary are shown below.
Bleed the annulus to 1000 psi after completing the test.
TVD Depth Required Casing
:YY.,aJJ ~ Pressure for MIT
2 K- 1 3 612 5' 3333 PSI
2 K- 2 3 6 081' 3330 PSI
2 K- 2 4 6 2 04' 3340 PSI
The above pressures were calculated assuming a surface tubing pressure of
2300 psi. If a different surface tubing pressure exists at the time of the test, the
required test pressure should be recalculated using the following equation:
MTP = Ptbg + ((Tubing gradient - Annular gradient) * TVD of Packer) + 500 psi
MTP= Minimum Test Pressure on Tubing/Casing Annulus
Ptbg = Pressure in the tubing at the wellhead
Tubing gradient is assumed to be seawater with a gradient of 0.44 psi/fi
Annular gradient is diesel with a gradient of 0.353 psi/ft
Messrs.' Fontenot and Wil~ ~-"~
10/26/91
Page 3
10)
Prior to Initiating water Injection, a spear should be injected to clean up the
perforations. Depending on the outcome of the tag and bailer samples obtained, the next
step will involve a xylene/mutual solvent spear that will be either bullheaded down
the tubing or placed across the A Sand perforations with coiled tubing. A separate
procedure will be prepared for the CTU cleanouVplacement if necessary. For the spear
recipe, the following volumes should be pumped at matrix rates (roughly 1-2 BPM)
not to exceed 1450 psi surface treating pressure and displace with specified amount of
diesel.
Displacement volume to top perf is critical since a soak is involved and it is Important
that SW not be the displacing fluid as the fluids would swap during the soak.
Approximately half of the xylene mix will be displaced into the perfs and the remaining
half left in the wellbore.
Volume of Volume of Mutual Solvent Displacement Volume
Well ~ Chemlink - 8603 of Diesel to toD .oerf
2K-1 3 16 bbls 1 bbl (6%) 84 bbls
2 K- 2 3 7 bbls 0.5 bbl (7%) 93 bbls
2 K- 2 4 14 bbls 1 bbl (7%) 61 bbls
Allow to soak for 1 hour and overdisplace with SW at approximately 500 BWPD
and gradually increase the injection rate to maximum injection pressure.
WELL 2K-23
PRODUCER APl Ct 501032012400
SURFACE LOCATION' 319' FNL, 95' FEL, SEC 11, T1 ON, R8E, UM
TOP KUPARUK: 1186' FSL, 813' FEL, SEC 12, T10N, R9E, UM
DEPTHS: REFERENCED TO 0' RKB
TUBING SPOOL ELEV: 31' RKB
ALL DEPTHS MD-RKB
16": 62.5# H-40 @ 115'
9 5/8": 36# J-55 @ 4227'
TREE: WKM GEN IV 5000 PSI
J
BAKER PBR: 3.000" ID @ 9796'
BROWN HB PKR: 2.892" ID @ 9810'
OTIS 'XN' NIPPLE: 2.75" X 2.813" ID @ 9846'
SHEAR OUT: 3.000" ID @ 9857'
L
· GLMI'
GLM2:
GLM3:
GLM4:
GLM5:
GLM6:
SPUD: 1/28/90
COMPLETION: 5/16/90
SSSV · CAMCO TRDP-1A-SSA
ID 2.812" @1789'
2969' / 1.0" TMPD / 5/16" Port
6056' / 1.0" TMPD / 1/4" Port
7936' / 1.0" TMPD/DY
8894' / 1.0" TMPD / 1/4" Port
9338' / 1.5" MMG-2/DY
9753' / 1.5" MMG-2 / 3/16" Port
3.5" 9.3# J-55 EUE ABMOD IPC
TUBING TAIL @ 9858'
B
A5
A4
A3
7": 26# J-55 @
10370'
PBTD: 10160'
HOLE ANGLE ACROSS KUPARUK = 48 DEGREES
MAX HOLE ANGLE = 61 DEGREES @ 3500'
VOLUME TO TOP PERF = 93 BBLS
10066'
~.~{.J~ [o ~ ~U~~" ~''~
4 SPF ~ 180° PHASING
~IE~ED 147° CCW
10096'
FILL TAGGED AT 10087' MD-RKB (10/24/91)
REVISION: 10/24/91
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION CON ..... SSION 0
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1 Status of Well Classification of Service Well
OIL ~ GAS [] SUSPENDED r-~ ABANDONED ['-] SERVICE r--]
2 Name of Operator 7 Permit j~ /
ARCO Alaska, Inc ..... 90-14
3 Address 8 APl Number
P.O. Box 100360, Anchorage, AK 99510-0360 LOCATtONSi F?]'; ~.'~;'~-* . 50-103-20125
I / u~'~" ~-.~::¢~LIN ~ Unit or Lease Name
I9
4 Location of well at surface VERtFIE. D
319' FNL, 95'FEL, SEC 11, T10N, RSE UM ff~,mL_.~~ i__...~i/,Z~_//.~It KUPARUK RIVER
AtTop. P_[oducing ,nterval{~;~ ~ ~ t ,,~'J~IED ! 10 Well Number
.s~ 11~?~' FSL, 813' FEL,SEC 7, T10N, R9EUM - j r,,~C._~ '~ 2K-23
At Total Depth REVISED ~' 11 Field and Pool
~11~ 1021'.FI?IL, 1104' FEL, SEC 7, T10N, RDE UM. KUPARUK RIVER FIELD
' 5' Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL
RKB 154'I ADL: 25667 ALK: 2588
1:~ Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 Nol of Completions
1/27/90. 2/3/90. ~..J NA feet MSLJ 1
17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost
10387' MD & 6468' TVD 10160' MD & 6313' TVD YES X~ NO L.JI 1789, feet MD 1400' APPROX
22 Type Electric or Other Logs Run
D IL/S FL/GR/S P/FDC/C N L/CAL/CBL/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 78' 24" 170 SX AS II
.......
... 9 5/8" 36# J-55 SURF 4228' 12-1/4" 1100 SX AS 111,.500 SX CLASS G
7" 26# J-55 :~URF 10370' 8-1/2" 225 SX CLASS G
......
24 Perforations open to Production (MD+'rVD of Top and Bottom and 25 TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD/
3-1/2" 9858' 9810'
10066' - 10096' W/4-1/2" Csg gun @ 4 SPF MD 6249' - 6269' TVD
26 ACID, FRACTURE, CEMENT SQUEEZE, ETC ....
DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED ....
SEE ATTACHED ADDENDUM
.......
.....
27 PRODUCTION TEST
Date First Production IMethod of Operation (Flowing, gas lift, etc.)
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER~BBL CHOKE SIZE I GAS-OIL RAT'IO
iTEST PERIOD ~-
FIowTubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OILGRAVITY-API (corr)
Press. 24~HOUR RATE ,~
,
28 CORE DATA
Brief description of lithology, porositY, fractures, apparent dips and presence of oil,' gas or water. Submit core chips.
None
RECEIVED
OCT o
Fractured 7/28/90
Form 10-407
duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. 30.
GEOLOGIC MARKERS FORMATION TESTS
....
NAME Include interval tested, pressure data, all fluids recoverd and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
KUPARUK C TOP 9944' 6168' NA
KUPARUK C Be'I-rOM 9950' 6172'
KUPARUK A TOP 9999' 6204'
KUPARUK A Be'I-rOM 10187 6331'
31. LIST OF A'I-i'ACHMENTS
GYRO, Frac addendum, Daily Operations
42. I hereby certify that the foregoing is true and correct to the best of my knowle~lge
Signed, ~//~--/~[~/'~~/-'! Title AREA DRILLING ENGINEER 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
ADDENDUM
WELL
2K-23
7/23/90
Frac Kuparuk "A" sand perfs 10066'-10096' 180 deg oriented 147 deg ccw in
nine stages as follows.
Stage 1: Pmp 200 bbls @ 25 bpm 7150-5000 psi
Stage
Stage
Stage
Stage
Stage
Stage
Stage
Stage
60 bbls YF240 Gel H20 prepad @ 20 bpm 4000-4100 psi
45 bbls YF240 Gel H20 prepad @ 15 bpm 3200-3500 psi
30 bbls YF240 Gel H20 prepad @ 10 bpm 2900-3000 psi
2:91 bbls Slick H20 flush @ 3000-5250 psi
3:1600 bbls YF240 Gel H20 pad @ 25 bpm 5550-4250 psi
4:120 bbls YF240 w/2 ppg 16/20 Carbolite @ 25bpm 4250-3950 psi
5:140 bbls YF240 w/4 ppg 16/20 Carbolite @ 20-25 bpm 3950-3900 psi
6:160 bbls YF240 w/6 ppg 16/20 Carbolite @ 20 bpm 3900-3700 psi
7:180 bbls YF240 w/8 ppg 16/20 Carbolite @ 20 bpm 3700-3900 psi
8:120 bbls YF240 w/10 ppg 16/20 Carbolite @ 20 bpm 3900-4200 psi
9: 160bbls YF240 w/12 ppg 16/20 Carbolite @ 20 bpm 4200-7550 psi
Fluid to recover:
Sand in zone:
Sand in csg:
Avg pressure:
2455 bbls
129,905 lbs 16/20 Carbolite
28,886 lbs
4000 psi
D~l~~~upervisor
ARCO Oil and Gas Company,,.'~'. Well History - Initial Report - Daily
Instructiona: Prepare and submit the "Initial Report" on the firs; Wednesday after a well is spudded or workover operations are started.
Daily work prior to spudding should be summarized on the form giving inclusive dates only,
District I County, parish or borough I State
ARCO ALASKA INC. Ii NORTH SLOPE J
Field
IL ...... Unit IWeII no.
KUPARUK RIVER UNIT ImitleaDL: 25667 ALK: 2588
I
J COMPLETIONS
Auth. or W.O, no,
AK3781
Operator ARCO W I
ARCO I 55. 8533
Spudded or W.O. begUnSPUD JDate 01/27/90 JHour 00:00 jP,,o, ta,us ,, a w.o.
Date and depth
as of 8:00 a.m.
05/12/90 (11)
TD: 0
PB:10288
SUPV:GB
05/13/90 (12)
TD: 0
PB:10288
SUPV:GB
05/14/90 (13)
TD: 0
PB:10288
SUPV:GB
05/15/90 (14)
TD: 0
PB:10288
SUPV:GB
05/16/90 (15)
TD: 0
PB:10288
SUPV:DEB
Complete record for each day reported
NORDIC 1
SET BRIDGE PLUG AT 10037' 7"@10370' ~:10.0 NaC1/Br
MOVE RIG FROM 2K-22, ACCEPT RIG AT 1430 3/11/90, ND DRYHOLE
TREE, CHANGE PACKOFF STUDS ON 7" CSG, NU BOPE AND TEST TO
3000 PSI, RU HLS E-LINE, PU SQUEEZE PERF GUN AND RIH, PERF
~2 AT 6SPF, POH, ASF, RIH W/ GR/JB TO 10120, POH,
RIH W/ BP, SET BP AT 10037
DAILY:S32,730 CUM:$1,011,233 ETD:S1,011,233 EFC:$1,511,800
POH W/ RTTS PKR 7"@10370' MW:10.0 NaC1/Br
POH W/ E-LINE, RD HLS E-LINE, MU RTTS PKR ON 3-1/2" DP, RIH,
SET PKR AT 9756', EST. INJ. RATE AT 1.5 BPM AND 2050 PSI,
CLOSE ANNULAR, PU & OPEN BYPASS ON PKR, MIX 150 BBLS CL G
W/ADDITIVES, TEST CMT LINES TO 3500 PSI, PUMP 25 BBLS WATER,
~, 10 BBLS WATER, DISPLACE W/ BRINE, AFTER 5
BBLS WATER IN ANNULUS SHUT BYPASS, INITIAL SQUEEZE PRESS
1550 PSI AT 1.5 BPM, SQUEEZE CMT AWAY, FINAL SQUEEZE PRESS
3030, WOC, BLEED PRESS ON DP, OPEN BYPASS, REV. CIRC., POH
W/ RTTS PKR
DAILY:S62,339 CUM:$1,073,572 ETD:S1,073,572 EFC:$1,511,800
RIH W/BIT & CSG SCRAPER 7"@10370' MW:10.0 NaCl/Br
CONT. POOH, PU 6.125 BIT ~ RIH, TAG CMT AT 9856, DRILL CMT
TO 10,019, TAG DBP AT 10,019, CIRC, TEST SQUEEZE PERFS TO
20._~50 FOR 30 MIN-OK, DRILL BP, WASH TO PBTD,CIRC, POOH, PU
BIT AND CSG SCRAPER, RIH
DAILY:S36,143 CUM:$1,109,715 ETD:S1,109,715 EFC:$1,511,800
RIH W/ PERF GUN #1 7"@10370' MW;10.0 NaCl/Br
CONT. RIH W/ BIT AND CSG SCRAPER TO 10,144, CIRC AND FILTER
BRINE, POOH AND LDDP, RU HLS EL, RIH W/ 6.125 GR/JB, STOPPED
AT 9826, POOH, RIH W/ 5.90 GR/JB TO 10,150, POOH, MU AND RIH
W/ PERF GUN #1
DAILY:S30,147 CUM:$1,139,862 ETD:S1,139,862 EFC:$1,511,800
ATTEMPT TO TEST TREE 7"@10370' MW:10.0 NaCl/Br
CONT. RIH W/ GUN #1, PERF @ 10,096-10,076, ASF, RIH W/ GUN
#2, PERF @ 10,076- 10,066, ASF, RD HLS E-LINE, RIH W/ 3.5"
COMPLETION ASSEMBLY, 316 JTS 3.5"+WKM TBG HGR+CAMCO
TRPD-1A-SSA SSSV+4 MERLA3.5"XI" TMPD GLMS W/ DV+2 CAMCO
1.5" MMG-2 GLMS+BAKER PBR/HB PACKER+OTIS 'XN' NIPPLE+10~
PUP+BAKER SOS, TEST 1/4" SS CONTROL LINE, OK, MU WKM HANGER,
DROP B~LL~ MU LANDING JT, LAND TBG, SET PKR, SAW SHEARS,
· E~ TU~N~, SHEAR ~BR ~ 106K#, TEST SSSV, OK, TEST PACKOFF
AND TREE, COMMUNICATION BETWEEN TREE AND C.L.
DAILY:S56,113 CUM:$1,195,975 ETD:S1,195,975 EFC:$1,511,800
The above is correct
For form preparation II'~di~trit~ution, ~
see Procedures Manu~, Section 10,
Drilling, Pages 86 and 87.
AR3B-459-1-D
SEP 2 6 lggo
z~:~,~i~a Oil .&~.o~' Cons. C0mmissic~
JNumber all daily well hlsto~ form~c~E~,~ no.
they are prepared for eacN we~[~ 'jPage
I
ARCO O~, rind Gas Company
Daily Well History-Final Report
instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold,
"Final Report" should be submitted also when operations are suspended fo~' an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire
operation if space is available.
Accounting cost center code
District County or Parish State
ARC~ AI.ASKA IN'C NORTH SLOPE AK
Field ILease or Unit IWoH no.
;(t]PAR[IK RIVER UNIT ADL: 25667 ALK: 2588 2~-23
Auth, or W.O. no. ]Title
AK3781 I COMP LETTIONS
Operator A.R.Co. W.I.
ARC. C) 55. 8533
~Pudded or W.O. begun
Date
SPUD 01/27/90
Date and depth
as of 8:00 a.m~
05/17/90 (16)
TD: 0
PB:10288
SUPV:DEB
Complete record for each day reported
NORDIC I
I otal number of wells (active or inactive) on this
ost center prior to plugging and
bandonment of this well
I
our IPrior status if a W.O.
I
00:00
RIG RELEASE 7"@10370' MW:10.0 NaC1/Br
TEST TREE, COUIViMUNICATION, NU LOWER TREE, NU UPPER TREE, TST
PACKOFF, OK, TST TREE, OK, TST CONTROL LINE, OK, T~S.~CSG AND
TBNG, OK, SHEAR SOS @ 3500PSI, REVERSE CIRC. 6 BBLS DIESEL
IN ANNULLUS, BULLHEAD 2 BBLS DIESEL INTO TUBING, SECURE WELL
AND RELEASE RIG @ 12:00 HRS 16-MAY-90
DAILY:S167,683 CUM:$1,363,658 ETD:S1,363,658 EFC:$1,511,800
Old TD
Released rig
Classifications (oil, gas, etc.)
Producing method
Potential test data
JNew TD I PB Depth
Date JKind of rig
Type completion (single, dual, etc,)
Official reservo r name(s)
Well no. Date Reservoir Producing Interval Oil or gasTest time Production
Oil on test Gas per day
Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date
corrected
The above is,~rect
Signature ,/ /
For form preparation a{~dist'ributi0n,
see Procedures Manual,~Section 10,
Drilling, Pages 86 and 87.
AR3B-459-3-C
JNumber all daily well history forms consecutively
es they are prepared for each well.
iPage no.
Olvllion ol AllanticRIchffeldCompeny
IIClIOFILMED
SURVEY REPORT
ARCO ALASKA INC..
WELL NO. 2K-23
NORTH SLOPE, ALASKA
FEBRUARY 23, 1990
Gyrodata Incorporated
P.O. Box 79389
Houston, Texas 77224
713,;461-3146
Fax: 713/461-0920
February 23, 1990
Mr. Tim Billingsly
Arco Alaska, Inc.
P. O. Box 100360
Anchorage, Alaska 99510-0360
Re: Well No. 2K - 23
North Slope, Alaska
Dear Mr. Billingsly:
Enclosed please find one (1) original and nine (9) copies of the completed survey of
Well No. 23.
We would like to take this opportunity to thank you for using Gyrodata and we
look forward to serving you in the furore.
Sincerely,
Gary Uttecht
Vice President, Technical Services
GU/cv
Enclosures
Gyrodata Services, Inc. Houston, TX / Lafayette, LA /New Orleans, LA,¥entura, CA / Aberdeen, U.K./Calgary, Alberta
Anchorage, AK / Kuantan, Malaysia / Buenos Aires, Argentina / Bergen, Norway
A Gyrodata
Directional
for
ARCO ALASKA INC.
WELL NUMBER 2K - 23
NORTH SLOPE, ALASKA
Survey
Date Run: 12-FEB-90 09:18:33
Job Number: AK0290G205
Surveyor: MIKE HOWATT
Calculation Method: PADIUS OF CURVATURE
Survey Latitude: 70deg 14min 30sec N
Sub-sea Correction from Vertical Reference: 118.0 ft
Bearings are Relative to TRUE NORTH
Proposed Well Direction: S 60deg 15min 0sec E
Vertical Section Calculated from Well Head Location
Closure Calculated from Well Head Location
Horizontal Coordinates Calculated from Local Horizontal Reference
~CO ALASKA INC.
IELL NUMBER 2K - 23
i~ORTH SLOPE, ALASKA
~'ob Number: AK0290G205
A Gyrodata
Directional
Survey
Page
MEAS INCL BORE HOLE
DEPTH BEARING
ft deg min deg min
.0 0 0
100.0
200.0
300.0
4OO .0
500.0
600.0
700.0
800.0
900.0
1000.0
1100.0
1200.0
1300.0
1400.0
1500.0
1600.0
1700.0
1800.0
1900.0
2000.0
2100.0
2200.0
2300.0
2400.0
0 7
0 7
0 18
1 18
4 7
7 11
11 52
14 48
16 46
18 12
21 6
24 30
27 18
30 55
34 53
38 7
42 17
43 16
47 26
52 19
53 3
55 3
56 27
58 26
N 0 0 E
N59 28E
N85 liE
S 855E
S 39 53 E
DOG-LEG VERT VERT
SEVERITY DEPTH SECTION
deg/100' ft ft
CLOSURE
DISTANCE BEARING
ft deg min
.00 .0 .0 .0 N 0 0 E
MULTI SHOT SURVEY IN 7 INCH CASING
ALL DEPTHS ARE REFERENCED TO KB ELEVATION
KB TO GROUND = 36 FT. ( KB ELEVATION = 154 FT. )
.11 100.0 .0 .1 N 59 28 E
.05 200.0 .2 .3 N 68 6 E
.31 300.0 .5 .5 S 79 57 E
1.05 400.0 1.6 1.7 S 39 14 E
$ 51 12 E 2.86 499.9 6.2
S 49 16 E 3.08 599.4 15.9
S 45 22 E 4.72 698.0 32.0
S 47 52 E 2.99 795.3 54.4
S 48 31 E 1.97 891.5 81.0
S 48 49 E
S 49 17E
S 50 10 E
S 50 32E
S49 6E
S 46 46 E
S 46 52 E
S 47 51E
S 46 58 E
S 49 12 E
S 51 22E
S 52 48E
S 54 26 E
S 56 4E
S 56 50 E
6.4 S 43 51 E
16.3 S 47 42 E
32.8 S 47 31 E
55.9 S 47 9 E
83.1 S 47 29 E
1.43 986.9 110.5
2.90 1081.0 143.4
3.43 1173.2 181.5
2.80 1263.1 224.6
3.69 1350.5 272.4
113.1 S 47 48 E
146.7 S 48 5 E
185.5 S 48 26 E
229.1 S 48 48 E
277.8 S 48 59 E
4.16 1434.4 325.5
3.23 1514.8 383.3
4.21 1591.2 446.2
1.15 1664.6 512.4
4.46 1734.8 582.0
332.1 S 48 48 E
391.5 S ~ 30 E
456.0 S 20 E
523.9 S 48 13 E
595.1 S 48 12 E
5.15 1799.3 657.2
1.36 1859.9 736.0
2.40 1918.6 816.4
1.95 1974.9 898.7
2.08 2028.7 982.8
671.5 S 48 26 E
750.8 S 48 50 E
831.5 S 49 18 E
913.8 S 49 50 E
997.5 S 50 23 E
HORIZONTAL
COORDINATES
feet
.00 N .00 E
.05 N .08 E
.11N .27 E
.09 S .53 E
1.35 S 1.10 E
4.65 S 4.47 E
10.95 S 12.04 E
22.17 S 24.21 E
38.02 S 40.97 E
56.15 S 61.25 E
75.99 S 83.81E
98.02 S 109.20 E
123.07 S 138.76 E
150.94 S 172.40 E
182.33 S 209.56 '
218.71 S 249.88 ~
259.42 S 293.25 E
303.13 S 340.71 E
349.09 S 390.71 E
396.60 S 443.64 E
445.44 S 502.43 E
494.31 S 565.16 E
542.32 S 630.33 E
589.43 S 698.24 E
636.01 S 768.47 E
~RCO ALASKA INC.
JELL NUMBER 2K - 23
~ORTH SLOPE, ALASKA
lob Number: AKO290G205
A Gyrodata
Directional
Survey
Page
MEAS INCL BORE HOLE DOG-LEG
DEPTH BEARING SEVERITY
ft deg min deg min deg/100'
2500.0 58 59
2600.0 56 52
2700.0 56 34
2800.0 59 36
2900.0 58 54
3000.0 57 26
3100.0 57 38
3200.0 57 51
3300.0 58 18
3400.0 60 37
3500.0 61 5
3600.0 60 42
3700.0 58 46
3800.0 59 10
3900.0 59 11
4000.0 59 39
4100.0 58 58
4200.0 58 44
4300.0 58 14
4400.0 58 24
4500.0 58 17
4600.0 57 59
4700.0 57 54
4800.0 57 58
4900.0 57 49
S 56 20 E
S 55 28 E
S53 44E
S 58 3 E
S 57 33 E
S 56 24 E
S 55 1E
S 54 23 E
S 52 28E
S 56 26 E
S 55 59 E
S 55 45 E
S5444E
S 53 20 E
S 53 2E
S 51 11 E
S 52 35 E
S 54 47 E
S 55 49E
S 56 16 E
S 56 36 E
S 57 21 E
S 57 47 E
S 58 16E
S 58 30 E
.7O
2.25
1.48
4.75
.82
1.77
1.18
.58
1.69
4.14
.60
.43
2.12
1.26
.27
1.66
1.38
1.90
1.01
.42
.31
.70
.37
.42
.25
VERT
DEPTH
ft
2080.6
2133.7
2188.6
2241.5
2292.6
2345.4
2399.0
2452.4
2505.3
2556.1
2604.8
2653.5
2703.9
2755.4
2806.7
2857.6
2908.6
2960.4
3012.6
3065.2
3117.6
3170.4
3223.5
3276.6
3329.7
VERT
SECTION
ft
1068.1
1152.5
1235.7
1320.3
1406.2
1491.0
1575.1
1659.3
1743.5
1829.2
1916.3
2003.4
2089.5
2174.7
2259.9
2345.1
2430.2
2515.2
2600.1
2685.0
2769.9
2854.7
2939.3
3024.0
3108.7
CLOSURE
DISTANCE BEARING
ft deg min
1082.5 S 50 53 E
1166.9 S 51 14 E
1250.4 S 51 28 E
1335.0 S 51 45 E
1420.5 S 52 7 E
1505.2 S 52 23 E
1589.4 S 52 34 g
1673.9 S 52 40 E
1758.8 S 52 42 g
1844.8 S 52 47 E
i932.0 S 52 57 g
2019.3 S 53 4 E
2105.6 S 53 9 E
2191.3 S 53 I2 E
2277.1 S 53 12 E
2363.2 S 53 9 E
2449.2 $ 53 6 E
2534.7 S 53 8 E
2619.9 S 53 12 E
2704.9 S 53 17 E
2789'.9 S 53 23 E
2874.7 S 53 29 E
2959.2 S 53 36 E
3043.7 S 53 44 E
3128.1 S 53 51 E
HORIZONTAL
COORDINATES
feet
683.07 S 839.80 E
730.57 S 909.96 E
779.00 S 978.10 E
826.59 S 1048.35 E
872.39 S 1121.07 E
918.69 S 1192.29 E
966.23 S 1261.99 E
1015.10 S 1331.00 E
1065.67 S 1399.15 E
1115.73 S 1469.21 E
1164.29 S 1541.79 E
1213.31 S 1614.11 E
1262.54 S 1685.07 E
1312.86 S 1754.43 E
1364.32 S 1823.17 E
1417.19 S 1891.10 E
1470.27 S 1958.75
1520.95 S 2027.70
1569.48 S 2097.78 E
1617.02 S 2168.36 E
1664.08 S 2239.28 E
1710.37 S 2310.49 E
1755.83 S 2382.01 E
1800.71 S 2453.90 E
1845.12 S 2526.03 E
~CO ALASKA lNG.
/ELL NUMBER 2K - 23
IORTH SLOPE, ALASKA
Iob Number: AKO290G205
A Gyrodat a
Directional
Survey
Page
MEAS INCL BORE HOLE DOG-LEG
DEPTH BEARING SEVERITY
ft deg min deg min deg/100'
5000.0 57 47
5100.0 58 19
5200.0 58 17
5300.0 58 11
5400.0 58 17
5500.0 58 33
5600.0 59 23
5700.0 59 14
5800.0 59 7
5900.0 58 49
6000.0 58 43
6100.0 58 41
6200.0 58 31
6300.0 58 13
6400.0 57 54
6500.0 57 47
6600.0 57 39
6700.0 57 38
6800.0 57 28
6900.0 57 22
7000.0 57 32
7100.0 58 13
7200.0 57 57
7300.0 58 6
7400.0 57 46
S 58 57 E
S 58 14E
S 58 46 E
S 58 50 E
S 59 24E
S 59 27 E
S 58 47 E
S 58 30 E
S 58 46 E
S 58 37 E
S 58 39 E
S 57 32 E
S 57 41 E
S 57 44E
S 57 19 E
S 57 37 E
S 57 41E
S 57 48E
S 57 50 E
S 57 46E
S 58 49 E
S 58 43 E
S 59 12 E
S 59 22 E
S 59 39 E
.39
.82
.45
.12
.49
.26
1.01
.28
.25
.33
.10
.94
.20
.31
.47
.28
.15
.09
.17
.11
.9O
.69
.48
.21
.41
VERT
DEPTH
ft
3383.0
3436.0
3488.5
3541.1
3593.8
3646.1
3697.7
3748.7
3800.0
3851.5
3903.4
3955.3
4007.4
4059.9
4112.8
4166.0
4219.4
4273.0
4326.6
4380.5
4434.3
4487.5
4540.3
4593.3
4646.4
VERT
SECTION
ft
3193.3
3278.1
3363.1
3448.1
3533.1
3618,3
3704.0
3789.9
3875.8
3961.4
4046.9
4132.3
4217.5
4302.6
4387.4
4471.9
4556.4
4640.8
4725.1
4809.3
4893.5
4978.2
5063.0
5147.8
5232.6
CLOSURE
DISTANCE BEARING
ft deg min
3212.5 S 53 59 E
3297.0 S 54 6 E
3381.9 S 54 13 E
3466.7 S 54 19 E
3551.4 S 54 26 E
3636.3 S 54 33 E
3721.7 S 54 40 E
3807.5 S 54 45 E
3893.1 S 54 50 E
3978.6 S 54 55 E
4064.0 S 55 0 E
4149.3 S 55 4 E
4234.6 S 55 7 E
4319.6 S 55 10 E
4404.4 S 55 12 E
4489.0 S 55 15 E
4573.5 S 55 18 E
4657.9 S 55 20 E
4742.2 S 55 23 E
4826.4 S 55 26 E
4910.5 S 55 28 E
4995.1 S 55 32 E
5079.8 S 55 35 E
5164.5 S 55 39 E
5249.0 S 55 43 E
HORIZONTAL
COORDINATES
feet
1889.05 S 2598.35 E
1933.26 S 2670.77 E
1977.72 S 2743.32 E
2021.77 S 2816.04 E
2065.42 S 2889.01 E
2108.75 S 2962.35 E
2152.74 S 3035.89 E
2197.49 S 3109.31 E
2242.19 S 3182.64 E
2286.73 S 3255.84 E
2331.24 S 3328.85 E
2376.41 S 3401.38 E
2422.13 S 3473.45 E
2467.60 S 3545.43 E
2513.16 S 3617.03 E
2558.69 S 3688.40 E
2603.92 S 3759.82
2649.00 S 3831.25
2693.96 S 3902.66 E
2738.87 S 3973.96 E
2783.17 S 4045.67 E
2827.09 S 4118.07 E
2870.86 S 4190.80 E
2914.19 S 4263.73 E
2957.19 S 4336.77 E
~RCO ALASKA INC.
tELL NUMBER 2K - 23
iORTH SLOPE, ALASKA
~'ob Number: AKO290G205
A Gyrodat a
Directional
Survey
Page
MEAS INCL BORE HOLE DOG-LEG
DEPTH BEARING SEVERITY
ft deg min deg min deg/100'
7500.0 58 4
7600.0 57 51
7700.0 57 48
7800.0 57 26
7900.0 57 9
8000.0 56 45
8100.0 55 43
8200.0 55 51
8300.0 55 37
8400.0 54 58
8500.0 52 31
8600.0 51 47
8700.0 50 58
8800.0 51 9
8900.0 51 12
9000.0 51 14
9100.0 51 13
9200.0 50 50
9300.0 50 31
9400.0 50 24
9500.0 50 12
9600.0 49 46
9700.0 49 35
9800.0 49 44
9900.0 49 11
S 61 55 E
S 61 11 E
S 6130E
S 62 12 E
S 6151E
S 62 12 E
S 63 32 E
S 64 7E
S64 17E
S 64 43 E
S 66 34 E
S 66 47 E
S 67 19 E
S 67 34 E
S 67 55 E
S68 3E
S 68 12 E
S 68 28 E
S 68 59 E
S68 17 E
S 69 36 E
S 69 47 E
S 70 2 E
S 68 6E
S 6455 E
1.94
.65
.27
.70
.41
.49
1.51
.50
.26
.75
2.87
.75
.92
.27
.28
.11
.12
.43
.51
.56
1.04
.45
.26
1.48
2.48
VERT
DEPTH
ft
4699.5
4752.5
4805.8
4859.3
4913.4
4967.9
5023.5
5079.7
5136.0
5192.9
5252.1
5313.4
5375.9
5438.7
5501.4
5564.0
5626.7
5689.6
5753.0
5816.6
5880.5
5944.8
6009.5
6074.2
6139.2
VERT
SECTION
ft
5317.3
5402.0
5486.7
5571.1
5655.2
5739.0
5822.0
5904.6
5987.0
6069.0
6149.2
6227.7
6305.3
6382.4
6459.7
6536.9
6614.2
6691.1
6767.6
6843.9
6920.0
6995.5
7070.7
7146.0
7221.5
CLOSURE
DISTANCE BEARING
ft deg min
5333.4 S 55 47 E
5417.8 S 55 53 E
5502.1 S 55 58 E
5586.1 S 56 3 E
5669.8 S 56 9 E
5753.1 S 56 14 E
5835.7 S 56 19 E
5917.7 S 56 26 E
5999.6 S 56 32 E
6081.0 S 56 38 E
6160.7 S 56 45 E
6238.5 S 56 53 E
6315.4 S 57 0 E
6391.9 S 57 '8 E
6468.5 S 57 16 E
6545.1 S 57 23 E
6621.7 S 57 31 E
6698.1 S 57 38 E
6774.0 S 57 46 E
6849.8 S 57 53 E
6925.3 S 58 1E
7000.3 S 58 8 E
7075.0 S 58 16 E
7149.8 S 58 23 E
7225.1 S 58 28 E
HORIZONTAL
COORDINATES
feet
2998.54 S 4410.71 E
3038.93 S 4485.24 E
3079.52 S 4559.52 E
3119.35 S 4633.98 E
3158.82 S 4708.29 E
3198.14 S 4782.32 E
3236.05 S 4856.31 E
3272.53 S 4930.52 E
3308.50 S 5004.92 E
3343.88 S 5079.12 E
3377.14 S 5152.57 E
3408.41 S 5225.07 E
3438.87 S 5297.00 E
3468.70 S 5368.83 E
3498.22 S 5440.94 E
3613.24 S 5729.89
3641.33 S 5801.71
3668.98 S 5873.51 E
3695.56 S 5945.33 E
3721.76 S 6016.93 E
3748.99 S 6088.12 E
3779.27 S 6157.82 E
~RCO ALASKA INC.
JELL NUMBER 2K - 23
IORTH SLOPE, ALASKA
[ob Number: AKO290G205
A Gyrodata
Directional
Survey
Page
MEAS INCL BORE HOLE DOG-LEG VERT VERT
DEPTH BEARING SEVERITY DEPTH SECTION
ft deg min deg min deg/100' ft ft
10000.0 48 34 S 63 43 E 1.10 6205.0 7296.7
10100.0 47 36 S 63 45 E .96 6271.8 7371.0
10145.0 46 43 S 62 48 E 2.51 6302.4 7403.9
CLOSURE
DISTANCE BEARING
ft deg min
7300.0 S 58 31 E
7374.1 S 58 34 E
7407.0 S 58 36 E
HORIZONTAL
COORDINATES
feet
3811.91 S 6225.71 E
3844.84 S 6292.44 E
3859.68 S 6321.92 E
Final Station Closure: 7407.0 feet South 58 deg 35 min 42 sec East
by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc.
Client · ARCO ALASKA, INC.
Field · KUPARUK
Well ' KRU 2K-23
Section at' S 60.25 E
Surveyor..' MIKE HOWATT
07/24/90
Computation'...' RADIUS OF CURVATURE
Survey Date...' 07/17/90
RKB Elevation.' 154.00 ft
API Number · 50-103-20125
Job Number · AK0290G205
INTERPOLATED,MARKERS REPORT
Surface Location' 319 SNL 95 WEL Sll T10N R8E
MARKER
IDENTIFI CATION
MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES
DEPTH ANGLE BKB SUB- S DIST BEARING FROM- WELLHEAD
9-5/8" CASING
TOP KUPARUK C
BASE KUPARUK C
TOP KUPARUK A
0 0.00 0 -154 0 N 0.00 E 0 N 0 E
4228 58.59 2975 2821 2539 S 55.07 E 1535 S 2047 E
9944 48.92 6168 6014 7255 S 64.39 E 3793 S 6188 E
9950 48.88 6172 6018 7259 S 64.32 E 3795 S 6192 E
9999 48.58 6204 6050 7296 S 63.73 E 3812 S 6225 E
PBTD
BASE KUPARUK A
7" LINER
TD
10160 46.72 6313 6159 7415 S 62.80 E 3865 S 6332 E
10187 46.72 6331 6177 7434 S 62.80 E 3874 S 6349 E
10370 46.72 6457 6303 7568 S 62.80 E 3935 S 6468 E
10387 46.72 6468 6314 7580 S 62.80 E 3940 S 6479 E-
_ .
AIJ STUN,
~OL£ ,
LOCI::fT I ON' :
HOUSTON
AUSTIN. TEXA'
CHART NO.
: [
:~F~[ O ::P, Ll:'!SKlq' i Ilxl[:.
I]E2DS' .:'-:
.... i ................ j]Z]:
PERMIT # ? o - / z// WELL NAME ~//~/.,/ .~"--,.2 .~ .
..-
I^o~cc GEOLOGICAL MATERIALS INVENTORY LIST
[ check off or list data as it is re, ceived
"07 ! /o/~/yo dHllin~] histo~ ~-' survey
cored int~wals c~re anal~is , d~ ditch intewals digital data
.... ~02
LOG TYPE " RUN INTERVALS SCALE
NO.
e',.,.,. /,., ,, ./.,-..~ E,,~'~"J / ~ '" / ,~,,,,.r"~ · "
,,,
....
..... .......
,,,
lOJ
.17)
11~i ,.
,
19!
i
ARCO Alaska, Inc.
Date: May 17, 1990
Transmittal Ct: 7760
RETURN TO:
ARCO Alaska, Inc.
Attn: Jenny Gamage
Kuparuk Operations File Clerk
ATO-1119
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.
2K-24
2K-26
2K-23
2K~25
2K-13
KRU State #1
Pulse Echo Evaluaton PET
Pulse Echo Evaluaton PET
Pulse Echo Evaluaton PET
Pulse Echo Evaluaton PET
Pulse Echo Evaluaton PET ·
Pulse Echo Evaluaton PET
Receipt Acknowledged-
2-13-90 7800-9696
2-19-90 8300-10220
2 12 90.w-~o
2-14-90 8146-10130
2-11 -90 6400-9464
2-27-90 5591~-7140
Date' o .........
DISTRIBUTION:
Drilling
NSK
State of Alaska(+Sepia) -
STATE OF ALASKA
~-~SKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon _ Suspend _
Alter casing _ Repair well
Change approved program _
2. Name of Operator
ARCO Alaska, Inc.
3. Address
Operation Shutdown .~. Re-enter suspended well _
_ Plugging _ Time extension _ Stimulate _
Pull tubing_ Variance _ Perforate _ Other
P. O. Box 100360, Anchorage, AK
99510
5. Type of Well:
Development X
Exploratory _
Stratigraphic _
Service
4. Location of well at surface
319' FNL, 95' FEL, Sec. 11 T10N, R8E, UM
At top of productive interval
1343' FNL, 915' FWL, Sec. 7, T10N, R9E, UM (approx)
At effective depth
1236' FSL, 1178' FWL, Sec.7, T10N, R9E, UM (approx)
At total depth
1208' FSL, 1247' FWL, Sec. 7,T10N, R9E, UM (approx)
12.
Present well condition summary
Total Depth: measured
(approx) true vertical
10387' feet Plugs (measured)
6451' feet None
6. Datum elevation (DF or KB)
RKB 154'
7. Unit or Property name
Kuparuk River Unit
feet
8. Well number
2K-23
9. Permit number
90-14
10. APl number
50-103-20125
11. Field/Pool Kupurak River Field/
Kuparuk River Oil Pool
Effective depth: measured
(approx) true vertical
10288' feet Junk (measured)
638 2 feet None
13.
Casing Length
Structural 8 0'
Conductor
Surface 41 91 '
Intermediate
Production 1 03 3 4'
Liner
Perforation depth: measured
Size Cemented
16"
9 5/8" 1100 Sx AS III &
500 Sx Class G
7" 225 Sx Class G
None
true vertical
Tubing (size, grade, and measured depth)
None
Packers and SSSV (type and measured depth)
None
Attachments Description summary of proposal_
Measured depth True vertical depth
115' 115'
4227' 4235' (approx)
1 0370' 6439' (approx)
RECEIVED
MAR -1 1990
Alaska Oil & Gas ,Oon malsslo
ndio ge
Detailed operation program X BOP sketch _
14. Estimated date for commencing operation
March, 1990
16. If proposal was verbally approved
Name of approver
Date approved
15.
Status of well classification as:
Oil X Gas _ Suspended
Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed ~~ "~~ Title AreaDrillincjEnc.:.:jineer
f FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity w BOP Test _ Location clearance__
Mechanical Integrity Test m Subsequent form require
'~,;u~NAL SIGNED
~¥ LONNIE C. SMITt]
Approved by the order of the Commission
Form 10-403 Rev 06/15/88
Commissioner
IApproval No.
Date ,J'. ~ ~? ~
SUBMIT IN TRIPLICATE
ARCO ~,,,. and Gas Company
Well History - Initial Report - Dally
Irlllnloti~al: Prepare and submit the '~ Rl~ert" on the first Wednesday after a well is spudded or workover operations are started,
Daily work pi, log to e~lxJd~?lheuld, be summarized on the form giving inclusive dates only.
District
ARCO ALASKA INC.
Field
KUPARUK RIVER FIELD
Auth. or W,O. no.
ICounty, parish or borough
NORTH SLOPE
Lease or Unit
ADL: 25667 ALK: 2588
Title
DRILLING
KRU 2K-23
IWell no.
Operator
ARCO
Spudded or W.O. begun IDate INcur
SPUD I 01/27/90 I 08:30
ARCO W.I.
55.8533
Prior status if a W,O,
Date and depth Complete record for each day reported
as of 8:00 a.m.
DOYON 14
01/27/90 (1)
TD: 0'( 0
SUPV:CD
01/28/90 (2)
TD: 2557'( 2557
SUPV:CD
01/29/90 (3)
TD: 4246' ( 16891
SUPV:CD
01/30/90 (4)
TD: 4246'(
SUPV:CD
01/31/90 (5)
TD: 7146'( 2900
SUPV:CD
02/01/90 (6)
TD: 8822'( 1676
SUPV:SC
CUT DRLG LINE MW: 0.0 VIS: 0
MOVE RIG FROM 2K-25, NU 20" DIVERTER, CUT DRLG LINE, ACCEPT
RIG @ 0300HRS 1/27/90.
DAILY:S34,287 CUM:$34,287 ETD:S34,287 EFC:$1,570M
DRLG MW: 8.9 VIS:109
CUT DRLG LINE, PU BHA, FUNCTION TEST DIVERTER, DRILL F/ 115'
T/ 2557'.
DAILY:S65,541 CUM:$99,828 ETD:S99,828 EFC:$1,570M
POOH FOR 9.625" CSG MW: 9.3 VIS: 85
DRLG F/ 2557 T/ 4246, CIRC., POOH, PU HOLE OPENER,
RIH, CIRC.,POOH.
DAILY:S55,711 CUM:$155,539 ETD:S155,539 EFC:$1,570M
LOADING RLL TOOL 9-5/8"@ 4227' MW: 8.6 VIS: 33
POOH F/ 9.625" CSG, RU & RUN CASING, CMT W/ 1100 SX ASIII &
500 SX CLASS G, ND DIVERTER,
TOP JOB CMT, INSTALL WKM WELLHEAD, NU ROPE, TEST STACK, OK,
INSTALL WEAR BUSHING, PU BHA, INSTALL RLL DEVICE.
DAILY:S251,643 CUM:$407,182 ETD:S407,182 EFC:$1,570M
DRILL F/4256' TO 7146' 9-5/8"@ 4227' MW: 9.1 VIS: 35
-~ TOOL FAILURE, LD BHA, CHANGE OUT RLL, REORIENT MWD,
iCALIBRATE AND LOAD RLL, PU DC, TIH TO 4122' TAG CMT. FILL
::i:~IPE TEST~ CSG, DRILL OUT FC, CMT, FS AND 10' NEW HOLE. TAG
FCAT 4148'. CIRC. TEST FORMATION TO 600 PSI AT 2977 TVD
W/8;7 PPG MUD, EMW=12.5, NO LEAK OFF. DRILL F/4256' TO
7146'.
DAILY:S58,962 CUM:$466,144 ETD:S466,144 EFC:$1,570M
DRLG 9-5/8"@ 4227' MW: 9.4 VIS: 36
DRLG, POOH TO RETRIEVE DP SCREEN, RIH, DRLG.
DAILY:S56,649 CUM:$522,793 ETD:S522,793 EFC:$1,570M
02/02/90 ( 7)
R~~~ ~~'~ '~ SuPvTD: 9738' (: SC 916)
WIAR-1 1990 02/03/90<
%,1~%,%~$T~10330 ' ( 592)
Nas 0ii & Gas Cons. 0 s v:sc
' ch0m
The above i~orrect
Signa~
see Procedures ~an~al, Section 10,
Drilling, Pages 8~d 87.
POOH TO RETEST FORM. 9-5/8"@ 4227' MW: 9.5 VIS: 37
DRLG, POOH TO SHOE, TEST FORMATION TO 10.3, POOH, CHANGE
BHA, RIH, MIX LCM, PREP TO TEST FORMATION.
DAILY:S52,533 CUM:$575,326 ETD:S575,326 EFC:$0
DRLG 9-5/8"@ 4227' MW:10.1 VIS: 43
POOH TO SHOE TEST FORMATION TO 10.7,RIH, WT. UP MUD TO 10.1,
DRLG.
DAILY:S73,298 CUM:$648,624 ETD:S648,624 EFC:$1,570M
AR3B-459-1-D
INumber all daily well histo~ forms consecutively
as they are prepared for each well.
iPage no.
ARCO O, ,d Gas Company
Daily Well History--Interim
Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed.
Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets untiJ final
completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not leas frequently than every 30 days, or (2)
on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion.
District
Field
ARCO ALASKA INC.
ICounty Or Parish
NORTH SLOPE
Lease or Unit
ADL: 25588 ALK: 2674
IStale
IWell no.
KUPARUK RIVER FIELD
Date and depth
as of 8:00 a.m.
02/04/90 (
TD:10387' (
SUPV:SC
KRU 2K-23
Complete record for each day while drilling or workover in progress
DOYON 14
9
PREP TO RUN 7" CSG 9-5/8"@ 4227' MW:10.1 VIS: 40
DRLG, REPEAT LOGS, POOH LDDP, RU TO RUN CSG.
DAILY:S62,378 CUM:$711,002 ETD:S711,002 EFC:$1,570M
MAR-1 1990
Alaska Oil & Gas Cons, Commissio
Anctiorage
The above is correct
AR3B-459-2-B
Number all daily well history forms consecutively IPage no.
as hey are prepared for each well.
ARCO ,.~il and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representative test data in blocks provided, The "Final Report" form may be used for reporting the entire
operation if space is available.
I Accounting cost center code
District ~ate
ARCO ALASKA INC.
KUPARUK RIVER FIELD
County or Parish
NORTH SLOPE
Lease or Unit
ADL: 25667 ALK: 2588
ITitle
DRILLING
IWell no,
KRU 2K-23
Auth. or W.O, no.
Operator
ARCO
Spudded or W.O, begun
SPUD
Date and depth
as of 8:00 a.m.
A.R.Co. W.I.
55.8533
IDate
J 01/27/90
Complete record for each day reported
DOYON 14
02/05/90 (10)
TD:10387
PB:10288
SUPV:SC
I otal number of wells (active or inactive) on this
est center prior to plugging and
bandonment of this well
our J Prior status if a W,O.
I
08:30
RIG RELASED 7"@10370' MW:10.1 NaCl
RUN AND CMT 7" CSG W/225 SX CLASS G, SET SLIPS AND PACKOFF,
RELEASED RIG @ 0600 HRS-2/5/90.
CUM:$978,503 ETD:S978,503 EFC:$1,570M
RECEIVED
MAE - 1 ]990
Naska.0jJ.& Gas Cons. C0mmissi0r~
Anchorage
TEST TUBING SEAL,
DAILY:S267,501
Old TD New TD PB Depth
Released rig Date IK nd of r g
Classifications (oil, gas, etc.) Type completion (single, dual, etc.)
Producing method I Off c a reservoir name(s)
Potential test data
Well no. Date Reservoir Producing Interval IOil or gas Test time Production
OII on test IGas per day
Pump size, SPM X length Choke size T.P. C.P. Water % IGOR Gravity AHowable Effective date
corrected
The above is correct
sF~; f~;o~ ePdruelPeas r ak~i~>nn~ds ed ic~l r~ nb u~ i0°, n '
Drilling, Pages 88 and 87.
AR3B-459-3-C
INumher all daily well history forms consecutively
as they are prepared for each well.
iPage no.
Dlvllion of Atl.nllcRIchfleldCompany
ARCO Alaska, Inc.
Date: February 15, 1990
Transmittal #: 7671
RETURN TO:
ARCO Alaska, Inc.
ATTN: Jenny Gamage
Kuparuk Operations File Clerk
ATO-1119
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith is the following items. Please acknowledge receipt and return one
signed copy of this transmittal.
2K-23 LIS Tape and Listing ,i~'/ r./¢0 ~/ 2-14-90#90-01-004AK
Receipt Acknowledged:
DISTRIBUTION:
Lynn Goettinger State of Alaska
ARCO Alaska, Inc.
Date: February 15, 1990
Transmittal #: 7670
RETURN TO:
ARCO Alaska, Inc.
ATTN: Jenny Gamage
Kuparuk Operations File Clerk
ATO-111 9
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith is the following items. Please acknowledge receipt and return one
signed copy of this transmittal.
2 K - 2 3 Electromagnetic Resistivity/Dual Gamma Ray 2 - 0 4 - 9 0 4 2 2 9 - 1 0 3 8 7
2 K - 2 3 Compensated Neutron Porosity/ 2 - 0 4 - 9 0 4 2 2 9 - 1 0 3 8 7
Simultaneous Formation Density
Receipt Acknowledged:
DISTRIBUTION:
D & M Drilling Franzen
NSK
State of Alaska(+sepia)
A__CClJI~ULATOR _~Y~,TEM_ =
P,,,, .,t,.., ~,~,, .. !600 '
Pump 1ncr ~lo~. pretl 200 P~it ,,,
Adj u~,t. able ¢;h~as,,
14.Wl~aulf=.11¥ epa.lt, ed shake ~ I ~ I .......
ortg - AOO¢C
e * Operator
c - Supervl~
C.O0~ (rev
· :._. i ..
January 22, 1990
Telecopy~
(907)276-7542
P. J. Archey
Area Drilling Engineer
ARCO Alaska, inc.
P. O. Box 100360
Anchorage, Alaska 99510-0360
Kuparuk River Unit 2K-23
ARCO Alaska, Inc.
Pe~tt No. 90-I4
Sur. Loc. 319'FNL, 95'FEL, Sec. 11, T10N, RSE, ~.
Btmhole Loc. l149'FSL, 1269'F%~L, Sec. 7, T10N, R9E, !~.
Dear Mr. Archey:
Enclosed is the approved application for permit to drill the
above referenced well.
~e pe~it to drill does not exempt you from obtaining additional
pe~its required by law from other governmental agencies, and
does not authorize conducting drilling operations until all other
required permitting determinations are made.
To aid us in scheduling field work, please notify this office 24
hours prior to commencing installation of the blowout prevention
equipment so that a representative of the Commission may be
present to witness testing of the equipment before the surface
casing shoe is drilled. ~here a dIverter system is required,
please also notify this office 24 hours prior to commencing
equipment installation so that the Commission may witness testing
before drilling below the shoe of the conductor pipe.
Chairman of
Alaska Oil and Gas Conservation Commission
BY ORDER OF THE COMMISSION
dl=
Enclosure
cc: Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA
AIJ-~KA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.O05
I
la. Type of Work Drill ;X; Redrill ~ I lb. Type of Well Exploratory._._ Stratigraphic Test _ Development Oil .~X
Re-Entry _ Deepen --I Service _ Development Gas ~ Single Zone ~ Multiple Zone
2_. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool
ARCO Alaska,, In~, RKB 154. Pad 118' GL feet Kuparuk River Field
3. Address 6. Property Designation Kuparuk River Oil Pool
P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25667 ALK 2588
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025)
319' FNL, 95' FEL, Sec. 11 , T10N, R8E, UM KuDaruk River Unit Statewide
At top of productive interval (TARGET) 8. Well number Number
1280' FSL, 1040' FWL, Sec. 7, T10N, R9E, UM 2K-23 #U630610
At total depth 9. Approximate spud date Amount
1149' FSL, 1269' FWL, Sec 7, T10N, R9E, UM 01-24-90 $200,000
1'~'. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
property line 2K-24 10387 MD
1149' ~ TD feet 25' at SURFACE feet 2560 6395TVD feet
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2))
kickoff depth 400 feet Maximum hole angle 57° Maximum surface 1744 psl~ At total depth (TVD) 6395 3360 psig
18. Casing program Setting Depth
size Specification Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length IVD TVD IVD 'I'VD linclude stage data1
24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF
12.25 9.625 36.0# J-55 BTC 4040' 35' 35' 4040' 2947' 1000 Sx AS III &
HF-ERW 500 Sx Class G
.8.5 7" 26.0# J-55 BTC 10387 35' 35' 10387 6395 200Sx Class G &
HF-ERW Top 500' above Kuparuk
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured
true vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
Structural
~ ·
Conductor ,~, : .... :, ~ ~!: / !
Surface i~ ";;! ?~
Intermediate >:~
Production
.
Liner ,~ 'i ,~ ';
Perforation depth: measured
20. Attachments Filing fee ~ Property plat ~ BOP Sketch X Diverter Sketch ~ Drilling program X
Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements
,,,
21. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~'-~C~,~).-, J ~'t ~ Title Area Drilling Engineer Date
Commission Use Only
Permit Number I APl number J Approval date J See cover letter for
~') -.//~Z 50-/O~- --~-O/'~-~d' ~ ] / ? ? / ~y~ other recluirements
Con~tions ot approval Samples required __Y e s .,~ N o Mud log required __ e s N o
Hydrogen sulfide measures__ Yes ,~ N o Directional survey required ,~ Yes __ N o
~ by order of
Approved by Commissioner the commission Dale
Form 10-401 Rev. 7-24-89 .~ ' triplicate
DRILLING FLUID PROGRAM
(2K-23)
Spud to 9-5/8" Drill out to Weight up
surface casing weight uo to TD
Density 8.8-9.0 8.6-9.4 10.1
PV 15-30 8-10 10-14
YP 20-40 5-8 7-10
Viscosity 70-80* 35-40 35-50
Initial Gel 5-15 2-4 4-6
10 Minute Gel 15-30 4-8 5-12
APl Filtrate 10-15 7-9 4-5
pH 9- 1 0 8.5-9 8.5-9.5
% Solids 10 +/- 4-7 <12
Drilling Fluid System:
- Triple Tandem Shale Shaker
- (2) Mud Cleaners
- Centrifuge
- Degasser
- Pit Level Indicator (Visual and Audio Alarm)
- Trip Tank
- Fluid Flow Sensor
- Fluid Agitators
Notes:
- Drilling fluid practices will be in accordance with the appropriate
regulations stated in 20 AAC 25.033.
- Maximum anticipated surface pressure is calculated using a surface casing
leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that
formation breakdown would occur before a surface pressure of 3000 psi
could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment
to 3000 psi.
- The nearest well to 2K-23 is 2K-24 As designed, the minimum distance
between the two wells would be 25' at surface. The wells would
diverge from that point.
- Excess non-hazardous fluids developed from well operations and those
fluids necessary to control the fluid level in reserve pits will be pumped
down the surface/production casing annulus. The annulus will be left with
a non-freezing fluid during any extended shut down in pumping operations.
The annulus will be sealed with 175 sx of cement followed by arctic pack
upon completion of fluid pumping.
* Spud mud should be adjusted to a funnel viscosity between 100-120 to
drill gravel beds.
ARCO ALASKA, Ins.
Pad 2K, Well No" 23 Revlaed Proposal
Kuperuk Field, North Slope, Alaska
1000 _
2000 _
3000_
4000_
5000_
6000_
7000
RKB ELEVATION, 154°
KOP TVD=400 TMD=400 DEP--O
BUILD 3 DEO
5 PER 100 FT
'[21
~,2~3 B/ PERMAFROST TVD=1424 TMD=1481 DEP=298
~%,"~9 T/ UONU SNDS TVD=1544 TMD=1627 DEP=381
~]$7 EOO TVD=2004 TMD=2303 DEP=872
'~~SAK SNDS TVD=2164 TMD=2599 DEP=1120
~ B/ t4 SAK SNDS TVD=2747 TMD 3672 DEP=2022
~~'~' 9 5/8" CSO PT= TVD--2947 TMD=4040 DEP=2331 "-~-10 TVD :3294 THD=4679 DEP=2867
AVERAGE-- ANGLE
T/ ZONE A TVD=6161 TMD=9957 DEP=7299 '-. ".
TAR(~ET CNTR TVD=6224 TMD=lO073 DEP=7396
B/ KUP SNDS TVD=6286 THD=10187 DEP=7492
TD (LOG PT) TVD=6395 TMD=10387 DEP=7660
I I I I I I I
0 ! 000 2000 3000 4000 5000 6000 7000
VERTICAL SECTION
I
8000
HORIZONTAL PROJECTION
SCALE 1 IN. = 1000 FEET
1000 _
m
z 1000 _
I
:: 2000
3000
4000 _
ARCO ALASKA. I
Ped 2K, We I I No, 23 Rev I
Kuper'uk Fi · i d' Nor"l:h SI ope. Al esk
1 000 0 1000 2000
SURFACE LOCATION,
319' FNL, 95' FEL
SEC. 11, T 1 ON, RSE
WEST-EAST
3000 4000 5000
I I I
6000
I
S 60 DEG 9 HI N E
7396' (TO TARGET)
TAROET CENTER
TVD=6224
TMD=tOO73
DEP=T396
SOUTH 3681
EAST 6415
TARGET LOCATION~
1280' FSL. 1040' FWL
SEC27. TION. RGE
TD LOCATION,
1149' FSL. 1269' FWL
SEC. ?. TION. RGE
7000
I
50
0
50 100
1 50 200 250 300 :350
,1 I I i I
150
100
50
50
100
150
400
-
50
)0
200
400
4O0
4OO
400
800
O0
eoo
600
800
0
"°-800
1,,.000
1000
800
100
150
~°'4 400
200
250
I
3OO
I
:350
_ 150
100
50
0
50
100
150
7
5
I I
13 5/8" 5000 [',.51 BOP STACK
ACCUMULATOR CAPACITY TEST
1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL
WITH HYDRAUUC 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 THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT
IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING
PRESSURE.
BOP STACKTEST
1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL.
2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED.
PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT
IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD.
3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES
ON THE MANIFOLD. ALL OTHERS OPEN.
4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES.
INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES.
BLEED TO ZERO PSI.
5. OPEN ANNULAR PREVENTORAND MANUAL KILL AND CHOKE LINE VALVES.
CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES.
6.TEST TO 250 PSI AND 3000 PSI AS IN STEP 4.
7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW
AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY
CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE.
8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BO'F1-OM
RAMS TO 250 PSI AND 3000 PSI.
9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE
BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI.
10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND
UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE
DRILLING POSITION.
11. TEST STANDPIPE VALVES TO 3000 PSI.
12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP.
13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN
AND SEND TO DRILLING SUPERVISOR.
14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY
OPERATE BOPE DAILY.
1. 16" - 2000 PSI STARTING HEAD
2. 11" - 3000 PSI CASING HEAD
3. 11" - 3000 PSI X 13-5/8" - 5000 PSI
SPACER SPOOL
4. 13-5/8" - 5000 PSI PIPE RAMS
5. 13-5/8" - 5000 PSI DRLG SPOOL W/
CHOKE AND KILL LINES
6. 13-5/8" - 5000 PSI DOUBLE RAM W/
PIPE RAMS ON TOP, BLIND RAMS ON BTM
7. 13-5/8" - 5000 PSI ANNULAR
SRE 8/22/89
DOYON 14
KUPARUK RIVER UNIT
20 DIVERTER SCHEMATIC
j L
6
DESCRIPTION
1. ir CONDUCTOR
2. FMC SUP4:~ WELD STARTING HEAD
3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/1~
2000 PSI BALL VALVES
4. 20' 2000 PSI DRIMJNQ SPOOL W/10' OUTLETS
5. 10' HCR BALL VALVES W/10' DNERTER LINES,
A SINGLE VALVE OPEN~ ~TIGALLY UPON
CLOSURE OF ANN~ I~IEVEN1Td~ VALVES CAN BE
DIVERSK)N.
6. ~ ~00 PSI ANNULAR PREVENI~R
R=~M 20~C2S.0~)
MAINTENANCE & OPERATION
3
2
1. UPON INmAL INSTALLATION, CLOSE PREVENTER AND
VERIFY THAT VALVE OPENS PROPERLY.
CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH
DIVERTER LINES EVERY 12 HOURS.
3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN
INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED.
OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND
DIVERSION.
DO NOT SHUT IN WELL
UNDER
ANY ClRCUMBTANCEB
GENERAL DRILLING PROCEDURE
KUPARUK RIVER FIELD
DEVELOPMENT WELLS
1) MIRU.
2) Install FMC diverter system.
3) Drill 12-1/4" hole to 9-5/8" surface casing point according to
directional plan.
4) Run and cement 9-5/8" casing.
5) Install and test BOPE. Test casing to 2000 psig.
6) Drill out cement and 10' new hole. Perform leak off test.
I 'Drill 8-1/2" hole to logging point according to directional plan.
Run open hole logs.
g) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom
of Kuparuk sands.
10) Run and cement 7" casin!). Pressure test to 3500 psig.
11) Downsqueeze Arctic packI and cement in 7" x 9-5/8" annulus.
12) ND BOPE and install temporary Xmas tree.
13) Secure well and release rig.
14) Run cased hole logs.
15) Move in Workover rig. NU BOPE.
16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with
clean brine and TOH standing tubing back.
17) Perforate and run completion assembly, set and test packer.
18) ND BOPE and install Xmas tree.
19) Change over to diesel.
20} Flow well to tanks. Shut in.
21) Secure well and release rig.
22) Fracture stimulate.
OEGASSER
MUD
CLEANER
SHALE
SHAKERS STIR STIR
TYPICAL MUD SYSTEM SCHEMATIC
c
N.TS.
WELLS 1'12 ARE LOCATED IN
SECTION 2, T. I0 N., R. 8
UMIAT MERIDIAN.
WELLS 13'24 ARE LOCATED IN
SECTION II~T. ION.~ R. 8 E.,
UMIAT MERIDIAN.
SECTION I
PROTRACTED Notes:
SECTION CORNER
D.S. 2K
12
~JlTY MAP
I. COORDINATES ARE A.S,R ZONE 4.
T ION '~
SECTION
?. ALL DISTANCES SHOWN ARE TRUE.
.:3. ELEVATIONS ARE B.P.M.S.L.
RECEIVED
DE('; i ~ 1988
4. O.G. ELEVATIONS FROM CED- RIXX-3311, re~4.
5. HORIZONTAL POSITION BASED ON 2-K CONTROL
MONUMENTS PER LOUNSBURY & ASSOCIATES.
6. REFERENCE FIELD BOOK.' L 88-40, pgs. 55,56,
58,59, 65 I~ 66.
SECTION
SECTION I I
·
Well " ASP's , Alasl a uif & d:~-~ Con~, g. omm;:,L;;v:: Dist. Dist. O.G. Pod
No. 'Y' 'X I-~]~;[~dlD.~ LONGITUDE ES.L. F.E.L. Elev. Elev.
I 5/938,'600. la 498,310.17 70514' 36 .519'' 150° 00'r49.133'' 2~6' 94' 114.0 118.5
2 5,938,575.14 498,310.28 70o14' 36.273" 150°00'49.130'' 271' 113.9
3, 5,938,550.30 498,310.35 70° 14' 36.029" 150°00'49.128" 246' 113.8
$6"
4 5,938,525.46 498,310.06 70o14' 35.784" 150°00'49. i 222 113.8
5 5,938,500.19 498,310.12 70o14' 35.536" 150°00'49.134" 196' 113.8
6 5,938,475.14 498,310.33 70014'35.289" 150°00'49.128'' 17'1' 113.8
7 5,938,450.36 498,310.36 70014' 35.046" 150°00'49.127'' 146' 113.8
8 5,938,425.30 498,310.18 70° 14' 34.799'' 150°00'49.132" 121' !13.8
9 5,938,400.30 498,309.98 70o14' 34.553" 150°00'49.137'' 96' 113.8 I
I0 5,958,375.19 498,510.14 70014'34.306'' 150 o00' 49. 133'' 71' 113.9
I I 5,938,350.22 498,310.14 70°14'34.061 " 150°00'49.133'' 46' i 113.9
12 5,938,325.20 498,310.17 70014' 33.815" 150°00'49.131" 21' 94' 113.9 118.5
FN.L.
13 5,938,235.31 498,310.3,7 70 ° 14' 32.930'' 150 °00' 49.125'' 69' 94' 113.7 118.5
14 5,938,210.14 498,310.16 70Ol4' 32.683" 150°00'49.131" 94' 113,.7
15 5,938,185.12 498,310.16 70o14'32.437" 150o00'49. t31'' 119' 113.8 '
16 5,938, 160.11 I 498,310.20 70°14' 32. 191" 150o00'49. 130" 144' 113.8
17 5,938, 135.21 498,310.18 70°14'31.946" 150°00'49.130'' 169' 113.9
18 5,938, 110.19 498,310.29 70°14'31.700" 150°00'49.127''' 194' 114.0
19 5,938,085.20 j 498,310.27 70014'31.454" 150°00'49.127''' 219' 114.0
·
,!
20 5,938,060.14 498,310.22 70° 14' $1.207,, 150° 00'49. 128'' 244' 114.1
21 5,938,035.16 498,310.16 70Ol4'30.96Z 150°00'49.130" 269' 114.0
' 294' 94' 114.0
22 5,938,010.40 ' 498,310.19 70°14'30.718'' 150°00 49. 129"
23 5,937,985.32 j 498,310.13 70°14'30.471'' 150°00'49.130" 319' 95' 114.0
;)4 51937,960'29I 498,310.08 70°14'30.225" 150° 00'49.132" 344' 95' I 113.9 118.5
?~V.
I HEREBY CERTIFY THAT I AM ~'"e~'~_.'' '.°',-Y.I",'&.
PROPERLY REGISTERED AND LICENSED ~.~,' ~ ',T ~.
,. ARCO A ska.
STATE OF ALASKA AND THAT THIS
PLAT REPRESENTS A SURVEY MADE
BY ME OR UNDER MY DIRECT SUPER-
VISION AND THAT ALL DIMENSIONS
AND OTHER DETAILS ARE CORRECT
AS OF NOVEMBER ~0, 1988.
DRILL SITE 2.K
CONDUCTOR AS-BUILTS
Dr. ~,F.' M.O'D C,~.~.y.',~Gm Sbt. I of I
I D~'I~' No. NSK 6.21 I. d 4
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage. Alost(a 99510--0360
Telephone 901 276 1215
December 12, 1988
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject: Conductor As-Built Location Plat- 2K Pad
(Wells I - 24)
Dear Mr. Chatteron:
Enclosed is an as-built location plat for the subject wells.
any questions, please call me at 263-4618.
Sincerely,
If you have
D. Martin
Engineering Aide
DM:hf
Encl osure
RECEIVED
DEC 1 1988
Alaska Oil & Gas Cmos. Commissim]
Ancl~orage
GRU13/010
ARCO Alaska, Inc. is a Subsidiary of Atla~tticRichfir-ld,C~m~pany
ITEM APPROVE I)ATE
?
(2 thrug)"' - ~-
(8)
(3) Admin ~//~//~z5 9.
(~ thru '1'3)' - 10.
/-7~-~ J 11.
(10 and 13) 12.
13.
(4) Casg 1-If-¢
(14 thru 22)
(23 thru 28)
Is the permit fee attached ..........................................
2. Is well to be located in a defined pool .............................
3. Is we~] located proper distance from property line ..................
4. Is we~d located proper distance from other wells ....................
5. Is suz~icient undedicated acreage available in this pool ............
6. Is well to be deviated and is wellbore plat included ................
7. Is operator the only affected party .................................
8. Can permit be approved before fifteen-day wait ......................
Does operator have a bond in force ..................................
Is a conservation order needed ......................................
Is administrative approval needed ...................................
Is the lease number appropriate .....................................
Does the well have a unique name and number .........................
Lease & Well No. /~MPZ C~-~'? [ f/J~// /C~ ~/~l~
YES NO ~~S
L
14.
15.
16.
17.
18.
19.
20.
21.
22.
23.
24.
25.
26.
27.
28.
Is conductor string provided ........................................
Will surface casing protect all zones, reasonably expected to
serve as an underground source of drinking water .....................
Is enough cement used to circulate on conductor and surface ......... ~ ...
Will cement tie in surface and intermediate or production strings ...
Will cement cover all known productive horizons .....................
Will all'casing give adequate safety in collapse, tension and burst.. ,~
Is this well to be kicked off from an existing wellbore .............
Is old wellbore abandonment procedure included on 10-403 ............
Is adequate wellbore separation proposed ............................
Is a diverter system required .......................................
Is the drilling fluid program schematic and list of equipment adequate
Are necessary diagrams and descriptions of diverter and BOPE attached.
Does BOPE have sufficient pressure rating - Test to ~~ psig .. ~f ....
Does the choke manifold comply w/API RP-53 (May 84) ..................
Is the presence of H2S gas probable .................................
/
(6) OTHER
-~/~ ///~/~ For
29.
(29 thr~ 31) 30.
31.
(6) Add:
Geology: En~ineerin~:
32.
rev: 01/30/89
6.011
exploratory and Stratigraphic wells:
Are data presented on potential overpressure zones? .................
Are seismic analysis data presented on shallow gas zones ............
If an offshore loc., are survey results of seabed conditions presented
Additional requirements .............................................
INITIAL GEO. UNIT ON/OFF
POOL CLASS STATUSAREA NO. SHORE
Additional Remarks:
Well History File
APPENDIX
Information of detailed nature that is not
particulady 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 APPENDIX.
No special 'effort has been made to chronologically
organize this category of information.
(NOTE:
**** LIS READ ****
MAXIMUM RECORD LENGTH - 8192 BYTES)
** REEL HEADER **
REEL SEQUENCE # 1
SERVICE NAME: SPERRY
DATE: 90/02/13
ORIGIN OF DATA: RLL
REEL NAME: ARCO
CONTINUATION #: 01
PREVIOUS REEL NAME:
COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT
** TAPE HEADER **
SERVICE NAME: RLL
DATE: 90/02/13
ORIGIN OF DATA: 2K23
TAPE NAME: KUPARUK
CONTINUATION #: 01
PREVIOUS TAPE NAME:
COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT
\
, '"********** END OF FILE (EOF # 1) **********
ICROFILMED
** FILE HEADER **
FILE SEQUENCE # 1
FILE NAME: 2K-23.MWD
SERVICE NAME: RLL
VERSION #: V 2.40
DATE: 90/02/13
MAX. RECORD LENGTH: 1024
FILE TYPE: EO
PREVIOUS FILE NAME:
** COMMENTS **
COMPANY: ARCO ALASKA, INC.
WELL: 2K-23
LOCATION: KUPARUK FIELD, NORTH SLOPE BOROUGH, ALASKA, USA
RIG: DOYON 14
ENGINEERS: M. MOORE & J. GALVIN
COMMENTS: NEUTRON AND DENSITY DATA ARE CALIPER CORRECTED. NEUTRON AND DENSITY
DATA ARE NOT QUANTITATIVE IN NON-ROTATING SECTIONS.
** DATA FORMAT SPECIFICATION **
ENTRY BLOCKS
TYPE SIZE REP CODE ENTRY
4 1 66 255
0 1 66
DESCRIPTION
LOG DIRECTION, DOWN
TERMINATOR (NO MORE ENTRIES)
DATUM SPECIFICATION BLOCKS
NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR
ID ORDER#
DEPT
NFO MWD
NFl MWD
NN0 MWD
NN1 MWD
EWR MWD
ROP MWD
FXE MWD
DRHO MWD
GRC MWD
CAL MWD
RHOB MWD
NPSC MWD
LOG TYP CLS MOD NO. LVL CODE
FT 0 0 0 0 1 4 0 1 68
CTS 0 0 0 0 1 4 0 1 68
CTS 0 0 0 0 1 4 0 1 68
CTS 0 0 0 0 1 4 0 1 68
CTS 0 0 0 0 1 4 0 1 68
OHMM 0 0 0 0 1 4 0 1 68
FT/H 0 0 0 0 1 4 0 1 68
HOUR 0 0 0 0 1 4 0 1 68
G/C3 0 0 0 0 1 4 0 1 68
API 0 0 0 0 1 4 0 1 68
INCH 0 0 0 0 1 4 0 1 68
G/C3 0 0 0 0 1 4 0 1 68
P.U. 0 0 0 0 1 4 0 1 68
** DATA FORMAT SPECIFICATION **
TYPE SIZE REP CODE
4 1 66
0 1 66
ENTRY BLOCKS
ENTRY DESCRIPTION
255 LOG DIRECTION, DOWN
TERMINATOR (NO MORE ENTRIES)
DATUM SPECIFICATION BLOCKS
NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR
ID ORDER# LOG TYP CLS MOD NO. LVL CODE
DEPT FT 0 0 0 0 1 4 0 1 68
NF'0 · MWD
NFl MWD
NN0 MWD
NN1 MWD
EWR MWD
ROP MWD
FXE MWD
DRHO MWD
GRC MWD
CAL MWD
RHOB MWD
NPSC MWD
CTS
CTS
CTS
CTS
OHMM
FT/H
HOUR
G/C3
API
INCH
G/C3
P.U.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
1
1
1
1
1
1
1
1
1
1
1
68
68
68
68
68
68
68
68
68
68
68
68
** DATA VERIFICATION (every 500 FT) **
DEPT NF0 NFl NN0 NN1 EWR
FXE DRHO GRC CAL RHOB NPSC
4050.000
-999.250
-999.250 -999.250 -999.250
-999.250 -999.250 -999.250
4500.000
.411
555.000 647.000 2632.000
-.011 81.401 8.400
5000.000
.917
631.000 679.000 2536.000
-.021 119.041 8.400
5500.000
.461
575.000 639.000 2680.000
-.018 101.529 8.450
6000.000
.542
639.000 695.000 2728.000
-.044 113.787 8.400
6500.000
.291
668.546 648.721 2896.542
-.047 97.159 8.400
7000.000
.449
687.000 727.000 2824.000
-.023 126.909 8.430
7500.000
.472
695.000 751.000 2776.000
-.033 108.528 8.400
8000.000
.926
667.208 636.271 2475.792
-.019 144.422 8.470
8500.000
.827
687.000 727.000 2952.000
-.031 98.026 8.400
9000.000
.540
727.000 783.000 2888.000
-.022 109.410 8.450
9500.000
.731
879.000 991.000 2408.000
-.042 263.466 8.870
10000.000
1.059
710.092 735.251 2758.511
-.039 104.539 8.400
** 674 DATA RECORDS ** FROM
** FILE TRAILER**
FILE NAME: 2K-23.MWD
SERVICE NAME: RLL
VERSION #: V 2.40
DATE: 90/02/13
MAX. RECORD LENGTH:
FILE TYPE: EO
NEXT FILE NAME:
1024
-999.250
-999.250
2632.000
2.226
2728.000
2.184
2760.000
2.350
2648.000
2.352
2764.908
2.365
2760.000
2.320
2856.000
2.427
2497.709
2.321
2968.000
2.282
2952.000
2.415
2440.000
2.439
2797.103
2.437
4050.00 TO
-999.250
-999.250
6.140
40.522
4.892
38.807
3.697
38.068
3.802
37.336
3.719
35.003
3.092
34.030
2.801
33.921
4.517
42.842
3.576
31.630
3.530
30.608
3.290
38.958
4.258
34.419
10450.00 FT
ROP
-999.250
429.102
228.406
275.870
354.599
448.022
168.435
236.096
300.992
247.031
193.215
168.111
29.025
********** END OF FILE (EOF # 2) **********
** FILE HEADER **
FILE NAME: 2K-23.RPT
SERVICE NAME: RLL
VERSION #: V 2.40
DATE: 90/02/13
MAX. RECORD LENGTH:
FILE TYPE: EO
PREVIOUS FILE NAME:
** COMMENTS **
FILE SEQUENCE # 2
1024
REPEAT (RPT) LOG FILES
1. FINAL TOOL CALIBRATION INDICATED A 3 PERCENT CALIBRATION SHIFT. SENSORS
WERE RECALIBRATED AND ALL DATA PROCESSED USING CORRECTED CALIBRATION
VALUES.
** DATA FORMAT SPECIFICATION **
TYPE SIZE REP CODE
4 1 66
0 1 66
ENTRY BLOCKS
ENTRY DESCRIPTION
255 LOG DIRECTION, DOWN
TErmINATOR (NO MORE ENTRIES)
DATUM SPECIFICATION BLOCKS
NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR
ID ORDER#
DEPT
NF0 REPEAT
NFl REPEAT
NN0 REPEAT
NN1 REPEAT
EWR REPEAT
RATE REPEAT
FXE REPEAT
NPSC REPEAT
GRC REPEAT
CAL REPEAT
DRHO REPEAT
RHOB REPEAT
LOG TYP CLS MOD NO. LVL CODE
FT 0 0 0 0 2 4 0 1 68
CTS 0 0 0 0 2 4 0 1 68
CTS 0 0 0 0 2 4 0 1 68
CTS 0 0 0 0 2 4 0 1 68
CTS 0 0 0 0 2 4 0 1 68
OHMM 0 0 0 0 2 4 0 1 68
FT/H 0 0 0 0 2 4 0 1 68
HOUR 0 0 0 0 2 4 0 1 68
P.U. 0 0 0 0 2 4 0 1 68
API 0 0 0 0 2 4 0 1 68
INCH 0 0 0 0 2 4 0 1 68
G/C3 0 0 0 0 2 4 0 1 68
G/C3 0 0 0 0 2 4 0 1 68
** DATA FORMAT SPECIFICATION **
TYPE SIZE REP CODE
4 1 66
0 1 66
ENTRY BLOCKS
ENTRY DESCRIPTION
255 LOG DIRECTION, DOWN
TERMINATOR (NO MORE ENTRIES)
DATUM SPECIFICATION BLOCKS
NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR
ID ORDER# LOG TYP CLS MOD NO. LVL CODE
NFO REPEAT
NFl REPEAT
NN0 REPEAT
NN1 REPEAT
EWR REPEAT
RATE REPEAT
FXE REPEAT
NPSC REPEAT
GRC REPEAT
CAL REPEAT
DRHO REPEAT
RHOB REPEAT
FT
CTS
CTS
CTS
CTS
OHMM
FT/H
HOUR
P.U.
API
INCH
G/C3
G/C3
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
2
2
2
2
2
2
2
2
2
2
2
2
2
0
0
0
0
0
0
0
0
0
0
0
0
0
68
68
68
68
68
68
68
68
68
68
68
68
68
** DATA VERIFICATION
(every 500 FT) **
DEPT NF0 NFl NN0 NN1 EWR
FXE NPSC GRC CAL DRHO RHOB
9663.500 -999.250 -999.250 -999.250 -999.250 -999.250
-999.250 38.666 -999.250 9.460 .000 1.467
10000.000 577.505 598.235 2497.740 2451.827
16.040 30.262 83.430 9.470 .022
** 77 DATA RECORDS **
** FILE TRAILER**
FILE NAME: 2K-23.RPT
SERVICE NAME: RLL
VERSION #: V 2.40
DATE: 90/02/13
MAX. RECORD LENGTH:
FILE TYPE: EO
NEXT FILE NAME:
FROM
1024
9663.50 TO
3.729
2.432
10387.00
RATE
-999.250
154.248
FT
********** END OF FILE (EOF # 3) **********
** TAPE TRAILER**
SERVICE NAME: RLL
DATE: 90/02/13
ORIGIN OF DATA: 2K23
TAPE NAME: KUPARUK
CONTINUATION #: 01
NEXT TAPE NAME:
COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT
** REEL TRAILER **
SERVICE NAME: SPERRY
DATE: 90/02/13
ORIGIN OF DATA: RLL
REEL NAME: ARCO
CONTINUATION #: 01
NEXT REEL NAME:
COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT
