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From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 1D-06 (PTD 179-096) Update and plan forward
Date:Thursday, March 16, 2023 8:41:20 AM
Attachments:AnnComm Surveillance TIO for 1D-06.pdf
MIT KRU 1D-06 diagnostic MITIA 2-13-23.xlsx
From: Byrne, Jan <Jan.Byrne@conocophillips.com>
Sent: Wednesday, March 15, 2023 10:31 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: KRU 1D-06 (PTD 179-096) Update and plan forward
Chris,
KRU 1D-06 (PTD 179-096) subsequent the report on February 9, 2023 for suspect IA pressure
increase DHD performed a passing MITIA, passing pack off tests, and adjusted the IA pressure for the
monitor period. The IA has remained stable throughout the monitor period and shown no
indications of annular communication. The well is being returned to ‘normal’ status at this time. If
the well exhibits any suspect behavior in the future it will be reported and addressed at that time. A
90 day TIO trend and 10-426 for the diagnostic MITIA are attached.
Please let me know if you disagree or have any questions with this plan.
Regards,
Jan Byrne
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 265-6471
Cell phone: (808) 345-6886
Submit to:
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 1790960 Type Inj W Tubing 1379 1378 1378 1378 Type Test P
Packer TVD 6265 BBL Pump 7.9 IA 79 3000 2950 2950 Interval O
Test psi 3000 BBL Return OA 28 30 30 30 Result P
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Notes:Diagnostic MITIA
Notes:
1D-06
Notes:
Notes:
Notes:
ConocoPhillips Alaska Inc,
Kuparuk / KRU / 1D Pad
Caudle
02/13/23
Form 10-426 (Revised 01/2017)MIT KRU 1D-06 diagnostic MITIA 2-13-23 (002)
1D-06 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
1D-06 2023-01-25 906 595 -311 IA
1D-06 2023-01-29 1015 506 -509 IA
1D-06 2023-02-05 1249 511 -738 IA
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB (Est. 189' of Fill, Leaving 102' of Open
Perfs)
8,144.0 10/16/2019 1D-06 zembaej
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Updated Tag Depth 10/16/2019 1D-06 zembaej
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.25
Top (ftKB)
28.0
Set Depth (ftKB)
108.0
Set Depth (TVD) …
108.0
Wt/Len (l…
65.00
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
10 3/4
ID (in)
9.95
Top (ftKB)
28.0
Set Depth (ftKB)
2,974.0
Set Depth (TVD) …
2,684.8
Wt/Len (l…
45.50
Grade
K-55
Top Thread
Casing Description
7" TIEBACK
OD (in)
7
ID (in)
6.28
Top (ftKB)
26.5
Set Depth (ftKB)
2,071.2
Set Depth (TVD) …
2,009.3
Wt/Len (l…
26.00
Grade
L-80
Top Thread
BTC-M
Casing Description
PRODUCTION
OD (in)
7
ID (in)
6.28
Top (ftKB)
2,068.2
Set Depth (ftKB)
8,586.6
Set Depth (TVD) …
6,890.7
Wt/Len (l…
26.00
Grade
K-55
Top Thread
BTC
Tubing Strings
Tubing Description
TUBING - WO 2015 -
3 1/2"
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
22.3
Set Depth (ft…
7,836.3
Set Depth (TVD) (…
6,240.7
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
8rd
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
22.3 22.3 0.05 HANGER CAMERON TUBING HANGER 2.950
989.5 989.5 0.47 EXPANSION CAMCO MODEL D EXPANSION JT W/ SHEAR PINS 2.900
7,707.3 6,130.1 31.35 SEAL ASSY BAKER 80-40 SEAL ASSY 3.000
7,714.4 6,136.1 31.30 PBR BAKER 80-40 PBR 4.000
7,757.8 6,173.3 31.01 PACKER BAKER FHL PACKER 2.930
7,810.4 6,218.4 30.69 NIPPLE CAMCO LANDING NIPPLE W/RHC INSTALLED 2.813
7,828.1 6,233.6 30.62 OVERSHOT BAKER POORBOY OVERSHOT 3.610
Tubing Description
TUBING - ORIGINAL
- 3 1/2"
String Ma…
4
ID (in)
3.00
Top (ftKB)
7,833.0
Set Depth (ft…
7,927.6
Set Depth (TVD) (…
6,319.5
Wt (lb/ft) Grade Top Connection
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
7,850.2 6,252.7 30.53 PBR BAKER PBR w/ 10' STROKE 2.875
7,864.0 6,264.6 30.47 PACKER BAKER HB RETRIEVABLE PACKER 2.875
7,870.2 6,269.9 30.45 SBR BAKER SBR 3.000
7,893.8 6,290.3 30.35 PACKER BAKER FHL RETRIEVABLE PACKER 2.891
7,913.3 6,307.1 30.28 NIPPLE CAMCO D NIPPLE NO GO 2.750
7,926.7 6,318.7 30.24 SOS BAKER SHEAR OUT SUB, TTL ELMD @ 7923' PER SWS IPROF
7/29/1999
3.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
8,042.0 8,130.0 6,418.5 6,494.6 C-2, C-3, C-4,
UNIT D, 1D-06
6/9/1981 4.0 IPERF
8,130.0 8,143.0 6,494.6 6,505.8 UNIT B, 1D-06 9/11/2008 6.0 RPERF 2.5" HSD 2506 PJ HMX
GUN, 60 DEG PHASING
8,311.0 8,329.0 6,651.1 6,666.8 A-5, 1D-06 6/9/1981 4.0 IPERF
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 7,650.4 6,081.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 10/19/2015
Notes: General & Safety
End Date Annotation
NOTE:
1D-06, 10/17/2019 8:04:26 AM
Vertical schematic (actual)
PRODUCTION; 2,068.2-8,586.6
IPERF; 8,311.0-8,329.0
RPERF; 8,130.0-8,143.0
IPERF; 8,042.0-8,130.0
SOS; 7,926.7
NIPPLE; 7,913.2
PACKER; 7,893.8
TUBING SPACE OUT; 7,891.8
SBR; 7,870.2
PACKER; 7,864.0
PBR; 7,850.2
OVERSHOT; 7,828.0
NIPPLE; 7,810.4
PACKER; 7,757.8
PBR; 7,714.4
SEAL ASSY; 7,707.3
GAS LIFT; 7,650.4
SURFACE; 28.0-2,974.0
7" TIEBACK; 26.5-2,071.2
Production Casing Cement; 26.5
ftKB
EXPANSION; 989.5
CONDUCTOR; 28.0-108.0
HANGER; 22.3
KUP INJ
KB-Grd (ft)
34.00
Rig Release Date
10/11/1980
1D-06
...
TD
Act Btm (ftKB)
8,941.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292041800
Wellbore Status
INJ
Max Angle & MD
Incl (°)
48.98
MD (ftKB)
4,400.00
WELLNAME WELLBORE1D-06
Annotation
Last WO:
End Date
9/12/2015
H2S (ppm) DateComment
SSSV: LOCKED OUT
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
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From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 1D-06 (PTD 179-096) Report of suspect IA pressure increase
Date:Thursday, February 9, 2023 9:10:02 AM
Attachments:1D-06 TIO plot.pdf
From: Byrne, Jan <Jan.Byrne@conocophillips.com>
Sent: Thursday, February 9, 2023 9:05 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: KRU 1D-06 (PTD 179-096) Report of suspect IA pressure increase
Chris,
KRU 1D-06 (PTD 179-096) is exhibiting suspect IA pressure increase. Operations bled the IA pressure
down multiple times, but the IA has continued to repressurized. DHD will perform initial diagnostics
after which the IA pressure will be adjusted and the well will be placed on a 30 day monitor. Any
required paperwork for corrective action or continued injection will be submitted once a plan
forward has been made. A 90 day TIO trend and wellbore schematic is attached.
Please let me know if you disagree or have any questions with this plan.
Regards,
Jan Byrne
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (808) 345-6886
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1D-06 90 -Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
1D-06
2022-11-10
1335
487
-848
IA
1D-06
2022-12-02
2293
1245
-1048
IA
1D-06
2023-01-25
906
595
-311
IA
1D-06
2023-01-29
1015
506
-509
IA
1D-06
2023-02-05
1249
511
-738
IA
-\ KUP INJ WELLNAME 1D-06 WELLBORE 1D-06
O'll'ns
Well Attributes Max AngleB MD TD
1'
Alaska, Inc.
F,ela Name WNIbore APWWI Wellhore SlanN Icl (°) MD(nKBI APA B1m (nKB)
K PAR K R R N T 1 IN 8.98 d 400.00 8,941.0
Comment X25(ppm) Dale MnWvlbn End Dale KBGNIflI Rig Release Bate
SSSV: TOOLest WO: 91122015 34.00 10111/1980
1 Dom, 1011 Dean 804 Be AM
Last Tag
Veal"lamme pang
Annwtlon
Depth (MR)
End Dab
WNlbore
foal Moa By
Leet Tag:RKBEst. 189of Fill, Leaving 102' m Open
8,144.01011612019
1D-06
zembaej
--
-- -
Pelfs)
11ANDERSBS
Last Rev Reason
.......... _.. _-
;;p�-.
patented, End Dm wmliametsI Mca By
Rev Reason: Updated Tag DePtl 131162019 1DL6 zembaej
•
Casing Strings
Caaing Denote- OD (in) ID (in) Top IM(BI Set Depth (dual Set Depth OVEN-, Shi g._Onde Top Thread
CONDUCTOR 16 15.25 28.0' 108.0 108.0 65.00 H40 WELDED
Casing Description OD (in) ID (in) Top(.) Sri Depth ARM) Set Depth TVD)... VALen 9... fxade Tap named
SURFACE 103/4 9.95 28.0 2,974.0 2,684.8 45.50 K55
CONDUCTOR, iH.0.1 W.0
I
Cssing Description OB (in) IB (n) TopntllB) SN Depth thus) Set Depth TVD)... WCLen 9... Grade Tap TnreM
7"TIEBACK 7 6.28 26.5 2,0]1.2 2,009.3 26.00 L30 BTC4d
Cssmg Ceacnption OB lint ID lin) Top plus) SN Depth DIKE) 50 Depth IND)... WdLen(L.. Wade Top ihreatl
PRODUCTION ] fi28 2,068.2 8,586fi 6890.7 26.00 KSS BTC
ExPAxaiox:am.s
Tubing Strings
Tubing Deanlmim String Mu..
ID (in)
Top DIKE)
set Depn (X..
Set Depth (ND)Graae
Top Lonna 11on
PmMNon Leairy Lamem 26E
rine
TUBING -W02015- 3112
299
22.3
],836.3
fi240]
9.30
L-80
8rd
3112"
Completion Details
NOmmm
Top UND)M3O.62
Top IXKB) (XKB) hem Des Can I[Ohn)
22.3 22.3HANGER CAMERON TUBING HANGER 2.950
989.5 989.5EXPANSION CAMCO MODEL D EXPANSION JT WI SHEAR PINS 2.900
7,707.3 6,130.1SEALASSY BAKER 80.40 SEAL ASSY 3.000
r TIEBACK2BE]071,2
7,714.4 6136.1PER BAKER 80-00 PBR 4.000
SURFACE. 9X0.2.974.0
7,757.8 6,173.3PACKER BAKER FHL PACKER 2.930
7,810.4 6?18ANIPPLE CAMCO LANDING NIPPLE WIRHC INSTALLED 2.813
7,828.1 fi233.6OVERSHOT BAKER POORBOY OVERSHOT 3.610
Tubing buic"i. String Me... ID that
Top DIKE)
Se� Ceptn ll..
But Depth D -VD) U..
Wt g ling
Graae
Timemnd,lon
TUBING - ORIGINAL 4 300
7,833.0
7,92].6
6,319.5
GAS LIFT. 7,50.4
-31I2-
Completion Details
TOP OVD) Top Incl xammJ
TOP(MB) rlel N ft.. D.. cam Blip
7,850.2 6,252.7 30.53 PER BAKER PBR wl 10' STROKE
2.875
SEAL ASSY; 7.7D7.3
7,864.0 6,264.6 30.47 PACKER BAKER HB RETRIEVABLE PACKER
2.875
PRR;7,7444
],8]0.2 6,269.9 30.45 SBR BAKER SBR
3.000
7,893.8 6,290.3 30.35 PACKER BAKER FHL RETRIEVABLE PACKER
2.891
PACKER; 7,7nap
7,913.3 6,307.1 30.28 NIPPLE CAMCO D NIPPLE NO GO
2.750
],926.] 6,318.7 30.24 SOS BAKER SHEAR OUT SUB, TTL ELMD@]923' PER SWS (PROF
3.000
]12911999
Perforations & Slots
wPPLEOa1pa
sh.
Ben
Tap TORS elm OVEN (anuem
TopfflKB) m(.KB) IIKB) (dust LIn. no Dale I Type
Com
8,0420
8,130.0
6,418.5
6,494.6
C-2, C3, C-4,
UNIT D, 1D-06
MOSS
4.0 (PERF
OVERSHOT. 7.828.0
8,130.0
8,143.0
6,494.6
6,505.8
UNIT B, ID -06
911112008
6.0
RPERF
2.5"HSD 2506 PJ HMX
GUN, 60 DEG PHASING
8,311.0
8,329.0
6,651.1
6,666.8
A-5. 1D -D6
6511881
6.0 IPERF
POP; 7.85 3
Mandrel inserts
st 1 1
PACKER: 7.up.0
SBR;7,8T0.2
e1i
TUBING SPACE OUT, ],BD10
ToftKBg Tyry; tp.h
N Top lflKB) IXKB) Mah Matltl ODlip Ser, Type Type
POISim
lip
TRO Run
1p.i)41112B11
PACKER; 7...
1 7650.4 6,081.6 CAMCO MMG 1112 GAS LIFT DMY RK
Notes: General & Safety
Ena one
Mnnnian
ev.]
NIPPLE. 7.913.2-
SOS;
808; 7.9M.7
IPERF,%W.OA,130.0�
RPERF', SUISB I,Q,0
IPERF', 8.3110a,3A0
PRODUCTION, 2,058.2$5868-
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, July 22, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Guy Cook
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1D-06
KUPARUK RIV UNIT 1D-06
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 07/22/2022
1D-06
50-029-20418-00-00
179-096-0
W
SPT
6265
1790960 1566
1240 1240 1240 1240
60 60 60 60
4YRTST P
Guy Cook
7/10/2022
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 1D-06
Inspection Date:
Tubing
OA
Packer Depth
780 2010 1960 1950IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitGDC220709073838
BBL Pumped:1.1 BBL Returned:1.2
Friday, July 22, 2022 Page 1 of 1
9
9
9 9
9
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2022.07.22 16:18:14 -08'00'
MEMORANDUM • • State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: Friday, July 13, 2018
P.I. Supervisor ll`�jej Z� �� I SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA, INC.
I D-06
FROM: Lou Laubenstein KUPARUK RIV UNIT ID -06
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Supry
NON -CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 1D-06 API Well Number 50-029-20418-00-00 Inspector Name: Lou Laubenstein
Permit Number: 179-096-0 Inspection Date: 7/10/2018 -
Insp Num: mitLOL180711093852
Rel Insp Num:
Packer Depth Pretest
Initial 15 Min 30 Min 45 Min 60 Min
WellI1D-06
- __.
PTD 1790960
Type Inj GTVD 6265 - Tubing 3055
-. -__- T_.__.
Type est SPT Test psi 1566 IA 750
3060 '� 3070 3060 '
2000 1950 1950
BBL Pumped:
1.3 IBBL Returned: 1.2 OA - - - 14 _
-13 - 14 14
IntervaI
_
--
avRTST
Notes:
SCANOW AUU U 9 zuid
Friday, July 13, 2018 Page 1 of 1
• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: DATE: Thursday,November 19,2015
P.I.SSupervisor /CC l - 'I`f 2 1 l5 SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1D-06
FROM: Jeff Jones KUPARUK RIV UNIT 1D-06
Petroleum Inspector
Src: Inspector
Reviewed By�:n
P.I.Supry T317,--
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 1D-06 API Well Number 50-029-20418-00-00 Inspector Name: Jeff Jones
Permit Number: 179-096-0 Inspection Date: 11/6/2015
Insp Num: mitJJ151106163310
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well I 1D-06 - Type Inj I W TVD I 6265 - Tubing 2088 - 2150 2113 2115 -
PTD I 1790960 - Type Test SPT(Test psi I 1566 IA 1020 2780 ' 2740 - 2740 -
Interval INITAL P/F r P / OA 2 ' 1 • 2 - 2
Notes: 1.4 BBLS diesel pumped. 1 well inspected,no exceptions noted.
SCANNE® SEP 16 2O1&
Thursday,November 19,2015 Page 1 of 1
tnc1 el CO
• • 2.(r,4{A O Z,
WELL LOG TRANSMITTAL#
DATA LOGGED
1,0/291201$
K.BENDER
To: Alaska Oil and Gas Conservation Comm. October 23, 2015
Attn.: Makana Bender
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RECEIVED
OCT 28 2015
RE: Multi Finger Caliper(MFC): 1D-06 ��G V�
Run Date: 9/18/2015
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
1D-06
Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom
50-029-20418-00
sCANN
ED
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline &Perforating
Attn: Fanny Sari
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-275-2605
Fax: 907-273-3535
FRS_ANC@halliburton.com
Date: Signed: MALLSzoci/) o_eit.eett
STATE OF ALASKA
ALSKA OIL AND GAS CONSERVATION COIVOISION
I.
REPORT OF SUNDRY WELL OPERATIONS
1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing 17 Operations Shutdown r
Performed: Suspend r Perforate
Other Stimulate r Alter Casing �"�/' Change Approved Program
Plug for Redrill r Perforate New Pool r Repair Well P. Re-enter Susp Well r Other: E
2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development r Exploratory r179-096
3.Address: 6.API Number:
Stratigraphic r Service p
P. O. Box 100360,Anchorage,Alaska 99510 50-029-20418-00
7.Property Designation(Lease Number): 8.Well Name and Number:
ADL 25650 KRU 10-06
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):
CBL Kuparuk River Field/Kuparuk River Oil Pool
11.Present Well Condition Summary:
Total Depth measured 8610 feet Plugs(measured) 7860
true vertical 6911 feet Junk(measured) none
Effective Depth measured 8453 feet Packer(measured) 7758, 7864, 7894
true vertical 6775 feet (true vertical) 6173, 6265,6290
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 80 16 108 108
SURFACE 2946 10.75 2974 2685
PRODUCTION 6518 7 8587 6891
� NOV2 2015
- E
Perforation depth: Measured depth: 8042-8143, 8311-8329 OCT 2 0
True Vertical Depth: 6419-6506, 6651-6667 ����
AOGCC
Tubing(size,grade,MD,and TVD) 3.5",J-55, 7928'MD/6320'TVD and 3.5", L-80, 7836'MD/6241'TVD
Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL PACKER @ 7758 MD and 6173 TVD
PACKER-BAKER HB RETRIEVABLE PACKER @ 7864 MD and 6265 TVD
PACKER-BAKER FHL RETRIEVABLE PACKER @ 7894 MD and 6290 TVD
NO SSSV
12.Stimulation or cement squeeze summary:
Intervals treated(measured): no stimulation or cement squeeze during this operation
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation shut-in
Subsequent to operation shut-in
14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations r'. Exploratory r Development r Service Stratigraphic
Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r
Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG P. GINJ r SUSP r SPLUG r
17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:
315-024
Contact Diana Guzman (a).265-6318 Email Diana.Guzmanconocophillips.com
Printed Name Diana Guzman Title Sr. Wells Engineer
Signature Phone:265-6318 Date j p / 1(7., / IS
5
Qvn- "2/ 1I/5-
RBDMS OCT 212015
Form 10-404 Revised 5/2015 A0/044,/ Submit Original Only
ti KUP INJ • 1D-06
ConocoPhillips
/ ® Well Attributes Max Angle&MD TD
Alaska IOC, Wellbore API/UWI Field Name Wellbore Status n ) MD(ftKB) Act Blot(ftKB)
Os pp,l�pp 500292041800 KUPARUK RIVER UNIT INJ Ind(°48.98 4,400.00 8,941.0
... - Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date
1D-06,10116/20152'.01 55 PM SSSV:LOCKED OUT Last WO: 9/12/2015 34.00 10/11/1980
Vertical schematic(actual)
Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
............. ..... ....._...................... r
Last Tag:SLM 8,130.0 1/30/2014 Rev Reason:WORKOVER smsmith 10/1/2015
�i
HANGER;22 3 .iFig .
astng trings
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
CONDUCTOR 16 15250 28.0 108.0 1080 65.00 H40 WELDED
Casing Descnplion OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
SURFACE 103/4 9.950 28.0 2,974.0 2,684.8 45.50 K-55
Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
7"TIEBACK 7 6.276 26.5 2,071.2 2,009.3 26.00 L-80 BTC-M
CasingDescription OD(in) ID(in) To (MB) Set Depth(ftKB) 'Set Depth(TVD)...Wt/Len(I...Grade TopThread
P PI ) ( P
PRODUCTION 7 6.276 2,068.2 8,586.6 6,890.7 26.00 K-55 BTC
'MfcbniDUCTOR�28.atoe:0.Od^^'.' Tubing Strings
Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/fl) Grade Top Connection
TUBING-WO 2015- 31/2 2.992 223 7,8363 6,240.7 9.30 L-80 8rd
3 1/2"
EXPANSION:989.5 Completion Details
Nominal ID
Top(ftKB) TOp(TVD)(ftKB) Top Incl(°) Item Des Com (in)
22.3 22.3 0.05 HANGER CAMERON TUBING HANGER 2.950
989.5 989.5 0.47 EXPANSION CAMCO MODEL D EXPANSION JT W/SHEAR PINS 2.900
I i I 7,707.3 6,130.1 31.35 SEAL ASSY BAKER 80-40 SEAL ASSY 3.000
7,714.4 6,136.1 31.30 PBR BAKER 80-40 PBR 4.000
7,757.8 6,173.3 31.01 PACKER BAKER FHL PACKER 2.930
• 7,810.4 6,218.4 30.69 NIPPLE CAMCO LANDING NIPPLE W/RHC INSTALLED 2.813
•
]'TIEBACK;26.5-2.0712 7,828.1 6,233.6 30.62 OVERSHOT BAKER POORBOY OVERSHOT 3.610
SURFACE;28.0-2,974.0 •
Tubing Description !String Ma...ID(in) 1Top(ftKB) Set Depth(ft..f Set Depth(TVD)(...Wt(Ib/ft) Grade 1Top Connection
TUBING-ORIGINAL 4 3.000 7,833.0 7,92761 6.319.5
-31/2"
Completion Details
Nominal ID
Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in)
7,850.2 6,252.7 30.53 PBR BAKER PBR w/10'STROKE 2.875
GAS LIFT:7,650.4 7,864.0 6,264.6 30.47 PACKER BAKER HB RETRIEVABLE PACKER 2.875
111 7,670.2 6,269.9 30.45 SBR BAKER SBR 3.000
7,893.8 6,290.3 30.35 PACKER BAKER FHL RETRIEVABLE PACKER
2.891
7,913.3 6,307.1 30.28 NIPPLE CAMCO D NIPPLE NO GO 2.750
SEAL ASSY;7,707.3 - 7,926.7 6,318.7 30.24 SOS BAKER SHEAR OUT SUB,TTL ELMD @ 7923'PER 3.000
SWS(PROF 7/29/1999
PBR;7,714.4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
Top(TIM) Top Incl
Top(ftKB) (ftKB) (°) Des Com Run Date ID(in)
PACKER;7,757.8 7,856.0 6,257.7 30.51 CATCHER 2.78"CATCHER(OAL=49") 9/1/2015
�' 7,860.3 6,261.4 30.49 PLUG 2.69"WEATHERFORD SPECIAL CLEARANCE 9/1/2015
• WRP
Perforations&Slots
NIPPLE;7,810.4 Shot
Dens
Top(ND) Btm(TVD) (shots/f
Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com
8,042.0 8,130.0 6,418.5 6,494.6 C-2,C-3,C-4, 6/9/1981 4.0 IPERF
OVERSHOT;7,828.0 UNIT D,1D-
06
8,130.0 8,143.0 6,494.6 6,505.8 UNIT B,10- 9/11/2008 6.0 RPERF 2.5"HSD 2506 PJ HMX
06 GUN,60 DEG PHASING
8,311.0 8,329.0 6,651.1 6,666.8 A-5,10-06 6/9/1981 4.0 IPERF
PBR;7,85021 �I
CATCHER;7,856.0 'II,'III Mandrel Inserts
St
on III o Top(ftKB)
Valve Latch Port Size TRO Run
111111'))))I7!°�//''�//''�))''''' N Top(ftKB) (ftKB) Make Madel OD(in) Sery Type Type (in) (psi) Run Date Com
PACKER;7,864.0 1 7,650.4 6,081.6 CAMCO MMG 11/2,GAS LIFT SOV RKP 0.000 0.0 9/18/2015 DCRI
PLUG;7,860.3 Notes:General&Safety
SBR;7,8702
If
. End Date Annotation
in NOTE:
mos
TUBING SPACE OUT;7,891.8
PACKER;7,893.8
NIPPLE:7,913.2 yi,
I
11
SOS;7,926.7 '3Y,
(PERF;B4O42.0-8,130.0
RPERF;8,130.0-8,143.0
IPERF;8,311.0-8,329.0
PRODUCTION;2,088.2-8,588.6 .
• 0
Operations Summary (with Timelog Depths)
N.. 1D-06
Cortocophilhps
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation ` (ftKB) End Depth(ftKB)
9/12/2015 9/12/2015 2.00 MIRU MOVE RURD P Load up welding shop,mechanic 0.0 0.0
17:00 19:00 shop,electrical shop,and satellite
office and move to 1D pad.
9/12/2015 9/12/2015 1.00 MIRU MOVE RURD P PJSM. Jack up the pits,install the 0.0 0.0
19:00 20:00 jeep,and pull pits away from the sub.
9/12/2015 9/12/2015 2.00 MIRU MOVE RURD P PJSM. Bridle up the derrick and prep 0.0 0.0
20:00 22:00 derrick to layover.
9/12/2015 9/13/2015 2.00 MIRU MOVE RURD P PJSM. Pull derrick pins and lay down 0.0 0.0
22:00 00:00 the derrick.
9/13/2015 9/13/2015 2.00 MIRU MOVE RURD P Raise cellar door and beaver slide. 0.0 0.0
00:00 02:00 Jack up the sub and pull mats from
underneath the sub.
9/13/2015 9/13/2015 1.00 MIRU MOVE MOB P Move sub off 1A-28 and move to the 0.0 0.0
02:00 03:00 edge of the pad leaving room for the
pits to move by. Move pits to KOC.
9/13/2015 9/13/2015 2.00 MIRU MOVE MOB P Move the sub down 1A access road 0.0 0.0
03:00 05:00 and set down just before the spine
road.
9/13/2015 9/13/2015 3.00 MIRU MOVE WAIT P Load mats off 1A access road and 0.0 0.0
05:00 08:00 move around the rig.
SimOps: Clean up around the cellar
and pad. Load out miscellaneous
equipment.
9/13/2015 9/13/2015 3.00 MIRU MOVE MOB P Move the sub onto the spine road and 0.0 0.0
08:00 11:00 to KOC.
9/13/2015 9/13/2015 1.00 MIRU MOVE WAIT P Wait for field crew change. 0.0 0.0
11:00 12:00
9/13/2015 9/13/2015 2.00 MIRU MOVE MOB P Move the sub from KOC to 1D pad 0.0 0.0
12:00 14:00 and stage sub to the side of location.
9/13/2015 9/13/2015 2.50 MIRU MOVE RURD P Set rig mats around well 1D-06 and 0.0 0.0
14:00 16:30 lay out herculite. Stage DSA,tubing
head adapter,and tubing head behind
the well. Hang the tree in the cellar.
9/13/2015 9/13/2015 1.75 MIRU MOVE MOB P PJSM. Spot the rig and center over 0.0 0.0
16:30 18:15 well 1D-06. Set mats under the rig.
9/13/2015 9/13/2015 3.00 MIRU MOVE RURD P Due to the soft location where the pits 0.0 0.0
18:15 21:15 will sit,lay mats for the length of the
pits,and lay transitions.
9/13/2015 9/13/2015 0.75 MIRU MOVE MOB P PJSM. Spot the pits up to the sub. 0.0 0.0
21:15 22:00
9/13/2015 9/13/2015 1.50 MIRU MOVE RURD P PJSM. Raise the derrick and install 0.0 0.0
22:00 23:30 the derrick pins.
9/13/2015 9/14/2015 0.50 MIRU MOVE RURD P Raise the cattle chute and pin. 0.0 0.0
23:30 00:00
9/14/2015 9/14/2015 3.50 MIRU MOVE RURD P Finish securing the cattle chute. 0.0 0.0
00:00 03:30 Setup berming around cellar,and pits.
Install lines at interconnect. Finish rig
accept checklist and accept the rig at
03:30 hours on 9/14/15. Start taking
on seawater to the pits.
9/14/2015 9/14/2015 3.00 MIRU MOVE RURD P PJSM. RU rig floor,spool tugger, 0.0 0.0
03:30 06:30 spool winches,hammer up the kelly
hose,bridle down,and pin the block to
the top drive. Set up LEPD tank.
Page 1/17 Report Printed: 10/15/2015
• •
'A Operations Summary (with Timelog Depths)
0.
0
1D-06
ConocoPhillips
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
9/14/2015 9/14/2015 4.00 MIRU WELCTL RURD P AES RU hard line to the choke house 0.0 0.0
06:30 10:30 and kill tank. RU hard line to the
cellar. RU circulation lines to the
manifold. RU to the tree out to the kill
tank for well kill operation. Install
hydraulic service loop on TD. RU rig
floor and organize equipment.
9/14/2015 9/14/2015 1.00 MIRU WELCTL SEQP P Blow air through hard line to ensure it 0.0 0.0
10:30 11:30 is clean and PT the hard line with 120
psi of air(good test).
9/14/2015 9/14/2015 1.50 MIRU WELCTL SEQP P Fill surface lines with seawater and 0.0 0.0
11:30 13:00 test to 3600 psi(good test).
9/14/2015 9/14/2015 1.50 MIRU WELCTL MPSP P RU lubricator, PT to 1500 psi(good 0.0 0.0
13:00 14:30 test),pull BPV(850 psi on the tubing),
and RD lubricator. Open OA to bleed
tank.
9/14/2015 9/14/2015 1.00 MIRU WELCTL SEQP P PT hard line to the kill tank and 0.0 0.0
14:30 15:30 manifold to 2000 psi(good test).
9/14/2015 9/14/2015 2.00 MIRU WELCTL KLWL P Bleed the tubing from 850 psi to 0 psi 0.0 0.0
15:30 17:30 and bleed the IA from 850 psi to 150
psi. Pump 69 bbls of 8.5 ppg
seawater down the IA to displace the
freeze protect out of the tubing. RU to
the tubing and pump 291 bbls of 8.5
ppg seawater down the tubing taking
returns out the IA to the kill tank at 4
BPM.
*Rig on high line power at 16:30
hours*
9/14/2015 9/14/2015 0.50 MIRU WELCTL OWFF P Observe the well for flow for 30 0.0 0.0
17:30 18:00 minutes,well static.
9/14/2015 9/14/2015 0.75 MIRU WELCTL RURD P Blow down all lines and RD circulating 0.0 0.0
18:00 18:45 equipment.
9/14/2015 9/14/2015 0.25 MIRU WHDBOP MPSP P Install 3"'H'BPV with dry rod. 0.0 0.0
18:45 19:00
9/14/2015 9/14/2015 2.00 MIRU WHDBOP NUND P Break the bolts on the tree and tubing 0.0 0.0
19:00 21:00 head adapter. PU joint of 4"DP and
MU 3-1/2"EUE x 4"HT-40 crossover.
Screw into the top of the tree,and
unseat the tree/tubing head adapter
with 5K on the TD. ND the tree,set
outside,and ND the tubing head
adapter. Inspect the tubing hanger lift
thread and check the lift threads with 3
-1/2"EUE pup. Function the ULDS,
all functioned properly. Install test dart
into the BPV.
9/14/2015 9/15/2015 3.00 MIRU WHDBOP NUND P NU the BOPE stack. 0.0 0.0
21:00 00:00
9/15/2015 9/15/2015 1.00 MIRU WHDBOP NUND P Finish tightening the bolts on the 0.0 0.0
00:00 01:00 BOPE stack. Install the riser,fill the
air boots,and install the mouse hole.
9/15/2015 9/15/2015 1.50 MIRU WHDBOP RURD P RU BOPE testing equipment. Fill the 0.0 0.0
01:00 02:30 stack with fresh water and purge the
lines. Shell test the BOPE stack.
Page 2/17 Report Printed: 10/15/2015
:::t,
.01
ilfti Operations Summary (with Timelog Depths)
0
1D-06
conocillips
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) ; End Depth(ftKB)
9/15/2015 9/15/2015 0.50 MIRU WHDBOP BOPE P Conduct initial BOPE test to 250/3000 0.0 0.0
02:30 03:00 psi: test 2-7/8"x 5"VBR's(upper pipe
rams)with 3-1/2"and 4"test joint;test
annular to 250/3000 with 3-1/2",and
4"test joints;conducted CPAI Koomey
drawdown test(all tested passed).
The test was witnessed by AOGCC
inspector Chuck Scheve.
Note: The 7"solid body rams(lower
pipe rams)will be tested with a 7"test
joint after 3-1/2"tubing is pulled from
the well
Tests:
#1)Blinds,Kill Demco,Chokes 1,2,3,
&16(Passed)
#2)Chokes 4,5,&6(Passed)
9/15/2015 9/15/2015 1.00 MIRU WHDBOP BOPE T #3)HCR Kill,3-1/2"EUE 8rd TIW, 0.0 0.0
03:00 04:00 Chokes 7,8,&9. Low test passed but
high test failed. Trouble shoot and
determined HCR kill is leaking. Cycle
HCR kill,retest,and same result.
Grease HCR kill,retest,and same
result. Need to change out the HCR
kill.
9/15/2015 9/15/2015 3.50 MIRU WHDBOP BOPE P Continue to test BOPE 250/3000 psi. 0.0 0.0
04:00 07:30 4)Man Kill;3-1/2"EUE 8rd TIW;
Chokes 7,8,9-pass
5)Chokes 10, 11-pass
6)Top Drive IBOP;chokes 12, 13, 14
-pass
7)Top Drive LWCV;Choke 15-pass
8)Annular with 3-1/2"TJ;HCR choke;
3-1/2"dart valve-pass
9)UPR with 3-1/2"TJ;TIW;Man.
Choke-pass
10)Annular with 4"TJ;Outer test
spool-pass
11)UPR with 4"TJ; Inner test spool-
pass
Accumulator test:starting pressure
2900 psi,final 1750 psi,first 200 psi
recharge 45 seconds,final recharge
164 seconds,6 N2 bottles with 2100
psi average.
9/15/2015 9/15/2015 3.75 MIRU WHDBOP BOPE T Replace HCR kill valve,function and 0.0 0.0
07:30 11:15 grease valve
9/15/2015 9/15/2015 1.00 MIRU WHDBOP BOPE P Pick up 4"test joint and test HCR Kill 0.0 0.0
11:15 12:15 valve 250/3000 psi against annular
and outer test spool-pass.
9/15/2015 9/15/2015 1.25 MIRU WHDBOP RURD P Rig down testing equipment. blow 0.0 0.0
12:15 13:30 down lines.
9/15/2015 9/15/2015 1.00 MIRU WHDBOP MPSP P Pull test dart and back pressure valve. 0.0 0.0
13:30 14:30
9/15/2015 9/15/2015 0.50 COMPZN RPCOMP RURD P Rig up to pull 3-1/2"decompletion. 0.0 0.0
14:30 15:00 Rig up Cameo control line spooler.
Rig up Weatherford tongs.
Page 3/17 Report Printed: 10/15/2015
Operations Summary (with Timelog Depths)
0144
1D-06
ConoccoPhillips
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
::.Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
9/15/2015 9/15/2015 0.75 COMPZN RPCOMP PULL P Pick up landing joint and screw into 7,833.0. 7,808.0
15:00 15:45 hanger. BOLDS. Observe tubing
grow-5'prior to pulling. Work pipe up
to 149K,tubing came free. Pull
hanger to floor
9/15/2015 9/15/2015 1.25 COMPZN RPCOMP CIRC P Circulate annular volume at 5 bpm 7,808.0 7,808.0
15:45 17:00 388 psi.
9/15/2015 9/15/2015 2.50 COMPZN RPCOMP PULL P POOH with decompletion from tubing 7,808.0 7,330.0
17:00 19:30 cut at 7,833',spooling up control line
and taking SS bands off. PUW 115K,
observe erratic drag off bottom from
105K to 120K. Drag becoming less
erratic with-150'of tubing coming out
of the hole. Observe control line hang
up,slack off and continue to POOH
ensuring control line coming with pipe.
9/15/2015 9/15/2015 1.50 COMPZN RPCOMP PULL T Observe control line balled up at SS 7,330.0 7,330.0
19:30 21:00 band on joint 17. Spool up excess
control line. Attempt to POOH with
decompletion,control line not coming
up. Slack off until contol line starts
going down and attempt to POOH,
control line still does not come up with
pipe,no additional drag noted with
decompletion. Consult with town.
9/15/2015 9/15/2015 0.25 COMPZN WELLPR OTHR P Clamp control line to tubing;One SS 7,330.0 7,330.0
21:00 21:15 band below a collar and two above.
Severe control line and
9/15/2015 9/15/2015 0.25 COMPZN WELLPR SFTY P Well control drill:kick while tripping. 7,330.0 7,330.0
21:15 21:30
9/15/2015 9/15/2015 0.50 COMPZN WELLPR BHAH P Make up crossover and storm packer. 7,330.0 7,369.0
21:30 22:00 Make up bumper sub.
9/15/2015 9/16/2015 2.00 COMPZN WELLPR PULD P Single in hole with storm packer and 7,369.0 7,814.0
22:00 00:00 decompletion of 4"drill pipe to 484',
PUW 130K,SOW 60K.
9/16/2015 9/16/2015 0.50 COMPZN WELLPR MPSP P Set storm packer as per Baker rep. 7,814.0 7,814.0
00:00 00:30 Top of storm packer at 464',COE
471.5'. Release from storm packer
9/16/2015 9/16/2015 1.00 COMPZN WELLPR TRIP P POOH standing back drill pipe 484.0 0.0
00:30 01:30
9/16/2015 9/16/2015 0.75 COMPZN WELLPR RURD P Rig up testing equipment,flood HCR 0.0 0.0
01:30 02:15 Kill
9/16/2015 9/16/2015 0.75 COMPZN WELLPR MPSP P Test storm packer to 1000 psi for 15 0.0 0.0
02:15 03:00 minutes-good.
9/16/2015 9/16/2015 0.25 COMPZN WELLPR RURD P Drain stack. Blow down HCR Kill 0.0 0.0
03:00 03:15
9/16/2015 9/16/2015 0.50 COMPZN WELLPR OWFF P Check OA pressure. Open OA and 0.0 0.0
03:15 03:45 monitor for 30 minutes,static.
9/16/2015 9/16/2015 0.75 COMPZN WELLPR NUND T Begin N/D BOPE; Pull and L/D 0.0
03:45 04:30 mousehole. Pull Riser. Remove
turnbuckles
9/16/2015 9/16/2015 0.75 COMPZN WELLPR NUND T N/U BOPE,install moushole and riser,
04:30 05:15 connect turnbuckles to test 7"LPR
and annular.
9/16/2015 9/16/2015 0.75 COMPZN WELLPR BOPE P Set test plug and RILDS. Pick up 7" 0.0 0.0
05:15 06:00 test joint. Fill stack
9/16/2015 9/16/2015 1.00 COMPZN WELLPR BOPE P Test LPR's and annular on 7"test joint
06:00 07:00 250/3000 psi for 5 minutes-pass.
Page 4/17 Report Printed: 10/15/2015
r; ib;ti:4 ta*‘t , o •
.,„ ' Operations Summary (with Timelog Depths)
1D-06
ConocoPhidtps
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
9/16/2015 9/16/2015 0.75 COMPZN WELLPR BOPE P L/D test tool. Drain stack. Pull test 0.0 0.0
07:00 07:45 plug.
9/16/2015 9/16/2015 2.00 COMPZN WELLPR NUND P Nipple down BOPE and DSA
07:45 09:45
9/16/2015 9/16/2015 2.25 COMPZN WELLPR RURD P Remove every other bolt on tubing
09:45 12:00 spool. Several bolts siezed. Function
lock down screws on casing head,
Two lock downs siezed on. Rig up
Hydratight to grow casing.
9/16/2015 9/16/2015 2.50 COMPZN WELLPR CUTP P Grow casing. Initial pressure on
12:00 14:30 Hydratight jacks(5)15,000 psi;
estimated 350,000 K up force. Grow
casing as per PESI;21"of growth.
9/16/2015 9/16/2015 0.50 COMPZN WELLPR CUTP P Pick up 7"Itco spear and make up to 1
14:30 15:00 joint of drill pipe. Engage casing. Pick
up 150K(estimated 10K over pipe
weight). Casing stretched 19". Total
stretch and growth 40". Set
emergency slips.
9/16/2015 9/16/2015 1.50 COMPZN WELLPR CUTP P Release spear and lay down drill pipe 0.0 0.0
15:00 16:30 and spear.
9/16/2015 9/16/2015 2.00 COMPZN WELLPR CUTP P Rig up Wach's cutter. Cut 39"excess
16:30 18:30 casing and casing hanger.
9/16/2015 9/16/2015 1.75 COMPZN WELLPR WWSP P Install secondary packoff bushing.
18:30 20:15 Nipple up tubing spool.
9/16/2015 9/16/2015 0.75 COMPZN WELLPR WWSP P Pressure test casing packoff void
20:15 21:00 250/3000 psi-pass.
9/16/2015 9/16/2015 2.00 COMPZN WELLPR WWSP P Nipple up BOPE,install riser,turn 0.0 0.0
21:00 23:00 buckles and mouse hole.
9/16/2015 9/17/2015 1.00 COMPZN WELLPR WWSP P Set test plug. Rig up to test BOPE 0.0 0.0
23:00 00:00 break
9/17/2015 9/17/2015 1.00 COMPZN WELLPR BOPE P Fill stack and test BOPE breaks 0.0 0.0
00:00 01:00 250/3000 psi against blind rams and
HCR valves. Low test leaking.
Function blind rams,low test leaking.
Close manual kill. Test pass.
9/17/2015 9/17/2015 1.50 COMPZN WELLPR BOPE T Grease HCR Kill valve. Test HCR Kill 0.0 0.0
01:00 02:30 valve,due to leak while testing breaks.
HCR Kill not holding pressure. Re-
grease HCR Kill Valve.
Retest 250/3000 psi-pass.
9/17/2015 9/17/2015 0.75 COMPZN WELLPR BOPE P Rig down testing equipment. Suck out 0.0 0.0
02:30 03:15 stack,pull test plug.
9/17/2015 9/17/2015 0.50 COMPZN WELLPR BOPE P Clean and clear rig floor. 0.0 0.0
03:15 03:45
9/17/2015 9/17/2015 0.75 COMPZN WELLPR BHAH P Make up retrieving head for storm 0.0 23.0
03:45 04:30 packer and bumper sub
9/17/2015 9/17/2015 0.75 COMPZN WELLPR TRIP P Trip in hole with Drill pipe from derrick 23.0 464.0
04:30 05:15 from 23'to 464'. PUW 45K,SOW
45K.
9/17/2015 9/17/2015 0.25 COMPZN WELLPR MPSP P Engage storm packer as per Baker. 464.0 464.0
05:15 05:30
9/17/2015 9/17/2015 1.00 COMPZN WELLPR PULD P POOH with Storm Packer and 7,794.0 7,794.0
05:30 06:30 decompletion laying down drill pipe
PUW 100K,SOW 80K;25K less up
weight since setting stom packer.
Page 5/17 Report Printed: 10/15/2015
Operations Summary (with Timelog Depths)
ae 1D-06
ConocoPhillips
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X - Operation (ftKB) End Depth(ftKB)
9/17/2015 9/17/2015 1.00 COMPZN WELLPR BHAH P Lay down bumper sub and storm 7,353.0 7,330.0
06:30 07:30 packer
9/17/2015 9/17/2015 0.50 COMPZN RPCOMP RURD P Rig up Weatherford power tongs, 7,330.0 7,330.0
07:30 08:00 Camco spooler. Change out pipe
handling equipment.
9/17/2015 9/17/2015 12.00 COMPZN RPCOMP PULL P POOH with 3-1/2"decompletions from 7,330.0 0.0
08:00 20:00 7330'PUW 90K SOW 75K.
Recovered 28 SS bands. Lay down
cut joint and inspect,cut OD 3.54".
9/17/2015 9/17/2015 0.50 COMPZN RPCOMP RURD P Rig up and pull wear bushing. 0.0
20:00 20:30
9/17/2015 9/18/2015 3.50 COMPZN RPCOMP RURD P Finsih loading,strapping and drifting 3
20:30 00:00 -1/2"completion string.
9/18/2015 9/18/2015 1.00 COMPZN RPCOMP RURD P Put completion equipment in order. 0.0 0.0
00:00 01:00 Prep rig floor to RIH with completion
9/18/2015 9/18/2015 2.00 COMPZN RPCOMP PUTB P PJSM. RIH with 3-1/2"completion 0.0 379.0
01:00 03:00 string to 3,79'.
9/18/2015 9/18/2015 0.50 COMPZN RPCOMP PUTB X Tag up with completion string at 379'. 379.0 317.0
03:00 03:30 Pick up 5'and attempt to slack off,
unable to. Pick up 5'and attempt to
slack off again,unable to. Lay down
two joints attempting to slack off.
Discuss options with town.
9/18/2015 9/18/2015 0.50 COMPZN RPCOMP CIRC X Circulate 3 annular volumes at 3 bpm. 317.0 317.0
03:30 04:00
9/18/2015 9/18/2015 1.00 COMPZN RPCOMP PULL X Slack off with completion string to 317.0 0.0
04:00 05:00 347',tag up. Pick up 2'and attempt to
slack off,unable to. POOH with 3-1/2"
completion. Observe wear on GLM,
Packer,'DS'Nipple.
9/18/2015 9/18/2015 1.00 COMPZN WELLPR RURD X Rig down Weatherford,Clean and 0.0 0.0
05:00 06:00 clear rig floor. Load 48 drill pipe in
shed.
9/18/2015 9/18/2015 1.00 PROD1 WELLPR RURD X Rig up dutch riser 0.0 0.0
06:00 07:00
9/18/2015 9/18/2015 0.50 PROD1 WELLPR SVRG X Service and inspect top drive,crown 0.0 0.0
07:00 07:30 and drawworks.
9/18/2015 9/18/2015 3.50 PROD1 WELLPR WAIT X Wait on E-Line unit. 0.0 0.0
07:30 11:00
9/18/2015 9/18/2015 3.00 PROD1 WELLPR FLOG X Spot in Halliburton E-Line unit and rig 0.0 0.0
11:00 14:00 up.
9/18/2015 9/18/2015 0.50 PROD1 WELLPR FLOG X Make up 40 arm caliper. 0.0 0.0
14:00 14:30
9/18/2015 9/18/2015 1.25 PROD1 WELLPR FLOG X RIH with 40-arm caliper on E-Line. 0.0 0.0
14:30 15:45 Coorelate with Dresser Atlas Acoustic
CBL log dats 10/09/1980,8'correction
down. Inspect 7"casing from 2,020'
to surface.
9/18/2015 9/18/2015 1.50 PROD1 WELLPR FLOG X Lay down 40-arm caliper. Pick up 0.0 0.0
15:45 17:15 CBL
9/18/2015 9/18/2015 2.75 PROD1 WELLPR FLOG X RIH with Cement bond log tool on E- 0.0 0.0
17:15 20:00 Line, Coorelate with Dresser Atlas
Acoustic CBL log dats 10/09/1980,8'
correction down. Log cement from
3500'to surface. Top of cement
2,175'. Centrilizer on tool string
recovered 1 SS band from previous
completion string.
9/18/2015 9/18/2015 1.00 PROD1 WELLPR ELOG X Wait on caliper data to be processed. 0.0 0.0
20:00 21:00
Page 6/17 Report Printed: 10/15/2015
,. ' Operations Summary (with Timelog Depths)
1D-06
ConocoPhiil ps
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation -- (ftKB) End Depth(ftKB)
9/18/2015 9/18/2015 1.00 PROD1 WELLPR WAIT X Discuss plan forward with town. 0.0 0.0
21:00 22:00 Casing damaged noted between 330'-
360'and 535'to 735'.
9/18/2015 9/18/2015 1.00 PROD1 WELLPR ELNE X Prepare next tool string. Make up 0.0 0.0
22:00 23:00 Baker 20 tool on E-line.
9/18/2015 9/19/2015 1.00 PROD1 WELLPR WAIT X Wait on WRBP from Deadhorse. 0.0 0.0
23:00 00:00
9/19/2015 9/19/2015 1.00 PROD1 WELLPR ELNE X Make up WRBP on Baker 20 running 0.0 0.0
00:00 01:00 tool
9/19/2015 9/19/2015 1.75 PROD1 WELLPR ELNE X RIH with WRBP on E-Line. Coorelate 0.0 0.0
01:00 02:45 with Dresser Atlas Acoustic CBL log
dats 10/09/1980,8'correction down.
Set WRB COE at 2,650'. Top at
2,647.5'. POOH
9/19/2015 9/19/2015 0.50 PROD1 WELLPR MPSP X Pressure test WRBP to 1000 psi for 0.0 0.0
02:45 03:15 10 minutes-good.
9/19/2015 9/19/2015 0.75 PROD1 WELLPR ELNE X Rig down E-Line 0.0 0.0
03:15 04:00
9/19/2015 9/19/2015 0.50 PROD1 WELLPR RURD X Set Wear bushing. 0.0 0.0
04:00 04:30
9/19/2015 9/19/2015 1.25 PROD1 WELLPR PULD X PJSM. RIH picking up drill pipe from 0.0 478.0
04:30 05:45 pipe shed with mule shoe to 478'
9/19/2015 9/19/2015 0.50 PROD1 WELLPR SFTY X Safety Stand up. Review recent 478.0 478.0
05:45 06:15 incident with hand rolling ankle.
Discuss the need to stay focused.
9/19/2015 9/19/2015 2.25 PROD1 WELLPR PULD X Conitnue picking up drill pipe from 478.0 2,537.0
06:15 08:30 pipe shed RIH with mule shoe to
2,537'. PUW 75K,SOW 65K
9/19/2015 9/19/2015 3.50 PROD1 WELLPR MPSP X Rig up and dump 1200lbs of sand 2,537.0 2,537.0
08:30 12:00 down drill pipe ontop of WRBP
9/19/2015 9/19/2015 1.50 PROD1 WELLPR MPSP X Allow sand to settle on top of WRBP 2,537.0 2,537.0
12:00 13:30
9/19/2015 9/19/2015 2.00 PROD1 WELLPR TRIP X Slack off and tag top of sand at 2,587'. 2,537.0 0.0
13:30 15:30 POOH,standing drill pipe back in
derrick.
9/19/2015 9/19/2015 0.50 PROD1 WELLPR RURD X Pull wear bushing 0.0 0.0
15:30 16:00
9/19/2015 9/19/2015 1.75 PROD1 WHDBOP RURD X Set test plug. Fill BOP stack and 0.0 0.0
16:00 17:45 purge out air. Rig up test hose lines.
Page 7/17 Report Printed: 10/15/2015
. •
0 Operations Summary (with Timelog Depths)
1 D-06
Coino oPhililips
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKS)
9/19/2015 9/19/2015 5.25 PROD1 WHDBOP BOPE X Test BOPE's with 3-1/2"and 7"test 0.0 0.0
17:45 23:00 joints 250/3000 psi. States right to
witness test waived by Johnnie Hill
1)Blind rams;Kill Demco;chokes 1,
2,3,and 16-pass
2)HCR Kill;chokes 4,5,6-pass
3)Manual Kill;chokes 7,8,9-pass
4)Chokes 10, 11 -pass
5)Chokes 12, 13, 14-pass
6)Annular with 3-1/2"test joint;dart
valve;HCR Kill;choke 15-pass
7)HT40 TIW;UPR with 3-1/2"TJ;
HCR Choke-pass
8)Annular with 7"TJ;Manual Choke-
pass
9)LPR with 7"TJ-pass
10)TD IBOP;Outer test spool valve-
fail
Accumulator test:starting pressure
2950 psi,final pressure 1850 psi.
First 200 psi recharge 32 seconds,
final recharge 118 seconds. 6N2
bottles with 2050 psi average.
9/19/2015 9/20/2015 1.00 PROD1 WHDBOP BOPE XT Cont testing BOPE's bleed off 0.0 0.0
23:00 00:00 pressure and purge air.
10)TD IBOP;Outer test spool valve-
fail.
Grease test spool valves
9/20/2015 9/20/2015 0.50 PROD1 WHDBOP BOPE XT Continueto test BOPE's with 3-1/2" 0.0 0.0
00:00 00:30 and 7"test joints 250/3000 psi. States
right to witness test waived by Johnnie
Hill.
After greasing outer and inner test
spool valves
10)TD IBOP;Outer test spool valve-
fail. Determine TD IBOP is leaking.
9/20/2015 9/20/2015 0.50 PROD1 WHDBOP BOPE X Test BOPE's 0.0 0.0
00:30 01:00
11)Manual TD;outer test spool-pass
12)Manual TD,Inner test spool-pass
9/20/2015 9/20/2015 0.75 PROD1 WHDBOP RURD X Blow down lines and top drive. Drain 0.0 0.0
01:00 01:45 BOPE. Pull test plug.
Simops:Monitor OA for 30 minutes-
static.
9/20/2015 9/20/2015 2.75 PROD1 WELLPR NUND X Nipple down BOP,and tubing spool. 0.0 0.0
01:45 04:30 Prep slips to be able to pull out with
casing;take top plate off slips and
rotate 90 degrees to hold slip body
together.
Simops:Change out hydraulic IBOP
valve on top drive.
Page 8/17 Report Printed: 10/15/2015
Operations Summary (with Timelog Depths)
1D-06
Conoao2 0 `Philkps
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
9/20/2015 9/20/2015 2.00 PROD1 WELLPR RURD X Open cellar doors and load spacer 0.0 0.0
04:30 06:30 spool in cellar. Prep spool and casing
head.
Simops:Continue to work on IBOP.
9/20/2015 9/20/2015 2.75 PROD1 WELLPR NUND X Nipple up BOPE, DSA and spacer 0.0 0.0
06:30 09:15 spool. Instal riser and mouse hole.
Simops:Continue to work on IBOP.
9/20/2015 9/20/2015 0.50 PROD1 WELLPR BOPE X Rig up testing equipment. Fill BOP 0.0 0.0
09:15 09:45 stack.
9/20/2015 9/20/2015 0.50 PROD1 WELLPR BOPE X Test casing and spool breaks against 0.0 0.0
09:45 10:15 WRBP 250/2500 psi for 5 minutes-
good.
9/20/2015 9/20/2015 2.50 PROD1 WHDBOP BOPE XT Test TD upper IBOP 250/3000 psi- 0.0 0.0
10:15 12:45 fail. Rebuild valve on IBOP and install
IBOP.
Continue to test BOPE.
Test IBOP 250/3000 psi for-5
minutes pass.
9/20/2015 9/20/2015 4.50 PROD1 WHDBOP RGRP XT Observe actuator valve on IBOP 0.0 0.0
12:45 17:15 leaking air. Re-kit air actuator stem.
Test IBOP 250/3000 psi for 5 minutes
-pass.
9/20/2015 9/20/2015 0.50 PROD1 WHDBOP RURD XT Rig down test lines,blow down TP. 0.0 0.0
17:15 17:45
9/20/2015 9/20/2015 0.25 PROD1 CSGRCY BHAH X Pick up Baker multi-string cutter. 0.0 0.0
17:45 18:00
9/20/2015 9/20/2015 2.25 PROD1 CSGRCY TRIP X RIH with 7"multi-string cutter to 2067' 0.0 2,067.0
18:00 20:15 PUW 70K,SOW 60K
9/20/2015 9/20/2015 1.00 PROD1 CSGRCY CPBO X Establish circulation at 3 bpm 250 psi 2,067.0 2,067.0
20:15 21:15 to open cutters. Slack off and observe
collar at 2,087'with 5K down. Shut
down pumps. Pick up to 2,035 and
establish circulation. Slack off and
observe collar at 2,047'with 5 K down.
Shut down pumps and slack off to
2,067'. Establish rotary at 80 rpms
free torque 1,450 ft-lbs. Pump at 4
bpm 395 psi to open cutters,stage
pump rate up to 6.5 bpm 1050 psi.
Observe erratic torque as cutters open
from 1800-3500 ft-lbs. Observe
pressure begin to decrease down to
480 psi;observe torque drop to 1300-
1700 ft-lbs. Observe pressure on OA
increase from 0 to 170 psi;all three
indicating 7"casing is cut. Continue to
rotate for additional 10 minutes.
9/20/2015 9/20/2015 2.25 PROD1 CSGRCY TRIP X Monitor well for 10 minutes-static. 2,067.0 0.0
21:15 23:30 POOH with Baker Multi-string cutter,
standing drill pipe back in derrick. L/D
multi-string cutter.
9/20/2015 9/21/2015 0.50 PROD1 CSGRCY RURD X Clean and clear rig floor. 0.0 0.0
23:30 00:00
9/21/2015 9/21/2015 1.00 'PROD1 CSGRCY BHAH X Pick up and make up 7"spear on one 0.0 0.0
00:00 01:00 joint of drill pipe.
Page 9/17 Report Printed: 10/15/2015
Operations Summary (with Timelog Depths)
0
ril
1D-06
ConocoPhilips
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) _ Phase Op Code Activity Code _Time P-T-X_ Operation (ftKB) End Depth(ftKB)
9/21/2015 9/21/2015 0.50 PROD1 CSGRCY FISH X Engage 7"casing. Pick up 10K over 0.0 2,065.0
01:00 01:30 to verify.
9/21/2015 9/21/2015 0.50 PROD1 CSGRCY RURD X PJSM on displacing arctic pack. 2,065.0 2,065.0
01:30 02:00 Check line to open top tank. Blow air
through line. PT line.
9/21/2015 9/21/2015 0.25 PROD1 CSGRCY FISH X Pick up on 7"casing,free at 95K. 2,060.0 2,060.0
02:00 02:15 PUW 80K.
9/21/2015 9/21/2015 1.75 PROD1 CSGRCY CIRC X Circulate out arctic pack to open top 2,060.0 2,060.0
02:15 04:00 tank with 140 degree fresh water at
4.5 bpm 285 psi. Pump 150 bbls,shut
down and allow hot water to soak
while sucking out tank for 30 minutes.
Pump 30 high viscosity spacer with
2.5 ppb Duovis followed by seawater.
9/21/2015 9/21/2015 0.75 PROD1 CSGRCY RURD X Rig down and blow down lines. 2,060.0 2,060.0
04:00 04:45 Monitor well for 10 minutes,drain
BOPE.
9/21/2015 9/21/2015 0.50 PROD1 CSGRCY BHAH X Pull 7"casing spear and casing to rig 2,040.0 2,040.0
04:45 05:15 floor. L/D spear.
9/21/2015 9/21/2015 0.50 PROD1 CSGRCY PULL X Remove casing slips/packoffs from 2,040.0 2,040.0
05:15 05:45 casing.
9/21/2015 9/21/2015 1.75 PROD1 CSGRCY RURD X Pick up weatherford casing tongs. Rig 2,040.0 2,040.0
05:45 07:30 up to POOH with 7"casing.
9/21/2015 9/21/2015 5.50 PROD1 CSGRCY PULL X POOH laying down 7"26#BTC casing 2,040.0 0.0
07:30 13:00 from 2,067'PUW 85K,SOW 73K,to
surface. Observed several buckled
joints-pictures in well file.
9/21/2015 9/21/2015 1.00 PROD1 CSGRCY RURD X Rig down casing tongs. Change out 0.0 0.0
13:00 14:00 pipe handling equipment
9/21/2015 9/21/2015 1.00 PROD1 CASING RURD X Load pipe shed with(6)drill collars. 0.0 0.0
14:00 15:00 Bring up BHA to rig floor.
9/21/2015 9/21/2015 3.00 PROD1 CASING BHAH X Make up BHA:dress off shoe,string 0.0 243.0
15:00 18:00 mills,and jars to 243'
9/21/2015 9/21/2015 2.00 PROD1 CASING TRIP X Trip in the hole with dress off 243.0 2,054.0
18:00 20:00 assembly to 2,054'.PUW 77K,SOW
75K
9/21/2015 9/21/2015 1.25 PROD1 CASING MILL X Pick up and establish parameters: 2,054.0 2,065.0
20:00 21:15 pump rate 7 bpm,210 psi;rotation 80
rpms 1352 ft-lbs. Shut down rotary.
Slack off and tag stump at 2,064.5'.
Rotate 1/4 turn to slide over stump
with dress off shoe. Dress off casing
stub at 80 rpms with 2500 ft-lbs.
Dress off 0.5'. Pick up,shut down
rotary and confirm stump depth at
2,065'.
9/21/2015 9/21/2015 0.50 PROD1 CASING CIRC X Circulate 2 annular volumes at 7 bpm 2,065.0 2,065.0
21:15 21:45 225 psi.
9/21/2015 9/21/2015 0.50 PROD1 CASING SVRG X Inspect and service crown,top drive, 2,065.0 2,065.0
21:45 22:15 and drawworks.
9/21/2015 9/22/2015 1.75 PROD1 CASING TRIP X POOH with dress off assembly to 243'. 2,065.0 243.0
22:15 00:00
9/22/2015 9/22/2015 2.50 PROD1 CASING BHAH X Lay down BHA as per Baker from 243' 243.0 0.0
00:00 02:30 to surface.
9/22/2015 9/22/2015 1.50 PROD1 CASING RURD X Clean and clear rig floor. 0.0 0.0
02:30 04:00
Page 10/17 Report Printed: 10/15/2015
Operations Summary (with Timelog Depths)
►.t
1D-06
ConocoPhdt ps
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
9/22/2015 9/22/2015 5.00 PROD1 CASING RURD X Rig up to RIH with 7"casing. Bring 0.0 0.0
04:00 09:00 casing tongs,Bowen overshot patch,
ES cementer,and bow spring
centrilizers to rig floor. Rig up line on
OA to take returns for cement job to
cuttings box. Blow air through line
and ensure clear. Spot in SLB
cementers,blow air through line to
ensure clerar. Pick up cement head,
rig up XO to floor valve.
9/22/2015 9/22/2015 5.00 PROD1 CASING PUTB X RIH with casing. Make up Bowen 0.0 2,025.0
09:00 14:00 patch and ES cementer. BakerLok
connections to first joint(two collars
above and below ES cementer). RIH
with 7"BTCM 26#L-80 casing picking
up joints from shed. Install Bowspring
centrilizers on every joints for first 25
joints(1000')followed by every other
joint to surface. 37 Bowspring
centrilizers ran. RIH to 2,025'PUW
80K,SOW 80K(35K blocks).
9/22/2015 9/22/2015 1.00 PROD1 CASING PRTS X PT 10-3/4"surface casing to 500 psi- 2,025.0 2,025.0
14:00 15:00 good.
9/22/2015 9/22/2015 2.25 PROD1 CASING HOSO X Continue to RIH to 2,065'. Space out. 2,025.0 2,068.0
15:00 17:15 Engage casing stub and swallow
2.98'. Pick up 200K to confirm
engaged. Slack off to 100K.
9/22/2015 9/22/2015 0.75 PROD1 CEMENT RURD X Rig up cement head and cement lines. 2,068.0 2,068.0
17:15 18:00
9/22/2015 9/22/2015 0.50 PROD1 CEMENT SEQP X PJSM with SLB,Halliburton,and 2,068.0 2,068.0
18:00 18:30 Baker on cementing. Flood lines and
PT SLB lines to 4000 psi-good.
9/22/2015 9/22/2015 0.50 PROD1 CEMENT PRTS X Pressure test casing with SLB to 2,068.0 2,068.0
18:30 19:00 2,500 psi for 15 mintues,staging up to
3000 psi for 5 minutes-both tests
good.
9/22/2015 9/22/2015 0.50 PROD1 CEMENT CIRC X Continue to stage up SLB pumps to 2,068.0 2,068.0
19:00 19:30 shear out ES cementer at 3,120 psi,
good indication on surface.Circulate
annular volume at 5 bpm 550 psi.
9/22/2015 9/22/2015 1.50 PROD1 CEMENT CMNT X Cement as per detail with SLB. 2,068.0 2,068.0
19:30 21:00 Pump 5 bbls of fresh water,followed
by 125 bbls(25%excess)of 15.7 AS1
cement. Drop closing plug. Displace
cement with 5 bbls fresh water. Shut
down and switch to rig pumps.
Continue to displace with 73.5 bbls of
seawater;taking cement returns to
cuttings box. 25 bbls of cement seen
at surface.
Bump closing plug and pressure up to
1900 psi close ES cementer. Good
indication on suface cementer closed.
Bleed back to trip tank,noted 1 bbls
bleed back prior to being static.
Cement in place at 21:00.
9/22/2015 9/22/2015 1.00 PROD1 CEMENT WWWH X Flush stack with cement retarder pill 2,068.0 2,068.0
21:00 22:00 out to cuttings box. Blow down lines.
Suck out casing stick up.
Page 11/17 Report Printed: 10/15/2015
=' Operations Summary (with Timelog Depths)
0
1D-06
C.orxxoPhillipis
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth.
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
9/22/2015 9/23/2015 2.00 PROD1 WELLPR NUND X Split BOPE stack from DSA to well 2,068.0 2,068.0
22:00 00:00 head. Observe cement just below OA
valve. Rig up to install emergency
slips.
9/23/2015 9/23/2015 0.50 PROD1 WELLPR OTHR X Install emergency slips with pipe in 2,068.0 2,068.0
00:00 00:30 tension(105K). Run in lock down
screws.
9/23/2015 9/23/2015 1.00 PROD1 WELLPR CUTP X PJSM. Rig up Wach's cutter. Cut 2,068.0 0.0
00:30 01:30 20.08'of excess casing.
9/23/2015 9/23/2015 2.00 PROD1 WELLPR NUND X Set stack back on wellhead. Break 0.0 0.0
01:30 03:30 bolts on DSA and Spacer spool.
Stand BOP back on stump. Remove
DSA and spacer spool.
Simops:load strap and drift drill
collars. Clean and clear rig floor.
Break out pup joints used to space
out.
9/23/2015 9/23/2015 2.00 PROD1 WELLPR NUND X Nipple up tubing spool: Clean up cut 0.0 0.0
03:30 05:30 and wellhead. Nipple up tubing head
with seconary packoff bushing
installed.
9/23/2015 9/23/2015 0.50 PROD1 WELLPR PRTS X Test casing packoff to 250/3000 psi- 0.0 0.0
05:30 06:00 good.
9/23/2015 9/23/2015 3.00 PROD1 WELLPR NUND X Nipple up BOPE. Install riser and 0.0 0.0
06:00 09:00 mousehole.
9/23/2015 9/23/2015 1.00 PROD1 WELLPR BOPE X Rig up to test BOPE break. Set test 0.0 0.0
09:00 10:00 plug and fill stack.
9/23/2015 9/23/2015 0.50 PROD1 WELLPR BOPE X Test BOPE break;tubing head to 0.0 0.0
10:00 10:30 BOPE. 250/3000 psi for five minutes-
good.
9/23/2015 9/23/2015 0.50 PROD1 WELLPR BOPE X Rig down testing equipment. Pull test 0.0 0.0
10:30 11:00 plug. Set wear bushing
9/23/2015 9/23/2015 2.75 PROD1 WELLPR BHAH X M/U BHA#6;6-1/8"bit to clean out ES 0.0 308.0
11:00 13:45 cementer.
9/23/2015 9/23/2015 1.25 PROD1 WELLPR TRIP X Trip in the hole from 308'to 1929'. 308.0 1,929.0
13:45 15:00
9/23/2015 9/23/2015 3.00 PROD1 WELLPR DRLG X Establish parameters:PUW 69K, 1,929.0 2,057.0
15:00 18:00 SOW 65K. Establish circulation at 6
bpm 325 psi. Wash down and tag up
at 2,054'. Drill out plug with 80 rpms
2000 ft-lbs WOB 3-5K to 2057'.
9/23/2015 9/23/2015 0.75 PROD1 WELLPR TRIP X RIH and tag top of sand at 2587. 2,057.0 2,587.0
18:00 18:45
9/23/2015 9/23/2015 0.50 PROD1 WELLPR DRLG X Establish rotary at 80 rpms and 2000 2,587.0 2,587.0
18:45 19:15 ft-lbs. Dry drill on sand for 20 minutes.
Monitor well for 10 minutes.
9/23/2015 9/23/2015 1.50 PROD1 WELLPR TRIP X POOH from 2588'PUW 78K,SOW 2,587.0 308.0
19:15 20:45 74K to 308
9/23/2015 9/23/2015 1.75 PROD1 WELLPR BHAH X Stand back drill collars. Lay down 308.0 0.0
20:45 22:30 BHA.
9/23/2015 9/23/2015 0.50 PROD1 WELLPR PRTS X Pressure test 7"casing to 3000 psi for 308.0 308.0
22:30 23:00 15 minutes-good test.
9/23/2015 9/24/2015 1.00 PROD1 WELLPR BHAH X M/U BHA#7 Reverse circulating junk 0.0 150.0
23:00 00:00 basket as per Baker.
9/24/2015 9/24/2015 0.75 PROD1 WELLPR BHAH X Continue to make up BHA#7 to 306'. 150.0 306.0
00:00 00:45
Page 12/17 Report Printed: 10/15/2015
• •
'" .' 11:','*LY'::::.:'
Operations Summary (with Timelog Depths)
0
R
1 D-06
+ConocoPhillips
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr)` Phase Op Code Activity Code Time P-T-X Operation - (ftKB) End Depth(ftKB)
9/24/2015 9/24/2015 1.25 PROD1 WELLPR TRIP X Trip in hole from 306'to 2,588'PUW 306.0' 2,588.0
00:45 02:00 83K,SOW73K. Tag sand at 2,588.
9/24/2015 9/24/2015 1.25 PROD1 WELLPR WASH X Establish rotary 60 rpms, 1900 ft-lbs, 2,588.0 2,598.0
02:00 03:15 stage pumps up to 9.5 bpm 1850 psi.
Wash down to 2,598'while circulating
two annular volumes with RCJB.
Observe sand,small aluminum metal
and rubber come over the shakers.
9/24/2015 9/24/2015 0.50 PROD1 WELLPR SVRG X Service,inspect and grease top drive. 2,598.0' 2,598.0
03:15 03:45
9/24/2015 9/24/2015 1.75 PROD1 WELLPR TRIP X Trip out of hole with BHA#7 reverse 2,598.0 306.0
03:45 05:30 criculating junk basket from 2598'to
306'.
9/24/2015 9/24/2015 0.50 PROD1 WELLPR BHAH X Lay down BHA. Stand back drill 306.0 0.0
05:30 06:00 collars and clean out RCJB's,
aluminum chunk and two peices of
rubber recovered.
9/24/2015 9/24/2015 1.50 PROD1 WELLPR BHAH X PJSM. Pick up BHA#8 RCJB. 0.0 306.0
06:00 07:30
9/24/2015 9/24/2015 0.75 PROD1 WELLPR TRIP X Trip in hole to 2,598'. PUW 80K, 306.0 2,598.0
07:30 08:15 SOW 75K
9/24/2015 9/24/2015 0.75 PROD1 WELLPR WASH X Wash down to 2,601'with 60 rpms 2,598.0 2,601.0
08:15 09:00 2500 ft-lbs at 9.5 bpm 1900 psi.
9/24/2015 9/24/2015 1.00 PROD1 WELLPR TRIP X POOH with BHA#8 RCJB to 306' 2,601.0 306.0
09:00 10:00
9/24/2015 9/24/2015 0.50 PROD1 WELLPR BHAH X Stand back drill collars. Break out 306.0 0.0
10:00 10:30 RCJB;packed with sand and
aluminum.
9/24/2015 9/24/2015 0.50 PROD1 WELLPR BHAH X Make up RCJB;BHA#9. 0.0 306.0
10:30 11:00
9/24/2015 9/24/2015 1.00 PROD1 WELLPR TRIP X Trip in hole from 306'to 2610' PUW 306.0 2,610.0
11:00 12:00 80K,SOW 75K.
9/24/2015 9/24/2015 0.50 PROD1 WELLPR WASH X Wash down from 2,610'to 2,614' 2,610.0 2,614.0
12:00 12:30 washing sand from top of WRBP with
60 rpms,2500 ft-lbs,9.5 bpm 1900
psi.
9/24/2015 9/24/2015 2.00 PROD1 WELLPR TRIP X POOH with BHA#9 to 306'. 2,614.0 306.0
12:30 14:30
9/24/2015 9/24/2015 1.50 PROD1 WELLPR BHAH X Lay down BHA,break out RCJB- 306.0 0.0
14:30 16:00 sand recovered.
9/24/2015 9/24/2015 1.00 PROD1 WELLPR RURD X Clean and clear rig floor. 0.0 0.0
16:00 17:00
9/24/2015 9/24/2015 0.50 PROD1 WELLPR BHAH X Make up Model"M"retrieval head. 0.0 0.0
17:00 17:30
9/24/2015 9/24/2015 1.50 PROD1 WELLPR TRIP X Trip in the hole to 2,641'PUW 74K, 0.0 2,641.0
17:30 19:00 SOW 71K.
9/24/2015 9/24/2015 0.75 PROD1 WELLPR WASH X Wash down to top of WRBP at 2,641' 2,641.0 2,641.0
19:00 19:45 at 9 bpm 500 psi.
9/24/2015 9/24/2015 0.75 PROD1 WELLPR CIRC X Circulate annular volume x 2 until 2,641.0 2,641.0
19:45 20:30 returns are clean. Observe sand and
minimal aluminum over shakers,at 9
bpm 500 psi.
9/24/2015 9/24/2015 0.50 PROW WELLPR MPSP X Engage WRBP at 2,641'. 2,641.0 2,641.0
20:30 21:00
9/24/2015 9/25/2015 3.00 PROD1 WELLPR PULD X POOH laying down drill pipe from 2,641.0 0.0
21:00 00:00 2,641'to surface.
9/25/2015 9/25/2015 1.25 COMPZN RPCOMP RURD X Drain stack. Pull wear ring. Set test 0.0
00:00 01:15 plug.
Page 13/17 Report Printed: 10/15/2015
• •
• �' '`3 Operations Summary (with Timelog Depths)
644
'41VINNIMAIM1D-06
,20
ConocoPhilhps
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
9/25/2015 9/25/2015 1.25 COMPZN RPCOMP WWWH X Wash out BOPE stack.Drain stack
01:15 02:30
9/25/2015 9/25/2015 5.50 COMPZN RPCOMP RURD XT Attempt to pull test plug. Test plug
02:30 08:00 won't pull. Break out tool. Make up bit
sub. Run in on top of test plug and
pump high viscosity sweep. Pick up
joint and attempt to pull test plug.Still
unable to pull. Latch elevators and
work test plug with link tilt with 15K.
Rig up supersucker and attempt to
clean off top of plug. Screw into test
plug and attempt to pull. Work up to
30K over with 1/8 turns. Test plug out
of hole
9/25/2015 9/25/2015 0.75 COMPZN RPCOMP RURD XT Break out test plug. Lay down test
08:00 08:45 joint.
9/25/2015 9/25/2015 1.25 COMPZN RPCOMP WWWH XT Wash out tubing profile with down
08:45 10:00 wash tool. Blow down top drive.
Break out XO's.
Call out model'G'plug and new test
plug.
9/25/2015 9/25/2015 1.25 COMPZN RPCOMP WAIT XT Wait on model'G'plug from Baker
10:00 11:15
9/25/2015 9/25/2015 0.50 COMPZN RPCOMP RURD XT Set test plug. Fill BOPE
11:15 11:45
9/25/2015 9/25/2015 0.75 COMPZN RPCOMP PRTS XT Test tubing profile against test plug
11:45 12:30 250/3000 psi to ensure tubing hanger
packoff will test. High test failed,
dripping out IA. Unable to get tubing
hanger to test.
9/25/2015 9/25/2015 0.50 COMPZN RPCOMP RURD XT R/D testing tool. Pull test plug,blow
12:30 13:00 down lines.
9/25/2015 9/25/2015 1.00 COMPZN RPCOMP MPSP XT Make up model'G'plug. Trip in hole
13:00 14:00 93'and set plug as per Baker.
9/25/2015 9/25/2015 0.50 COMPZN RPCOMP PRTS XT Test model'G'plug to 1500 psi for 5
14:00 14:30 minutes-good.
9/25/2015 9/25/2015 0.50 COMPZN RPCOMP RURD XT Blow down lines. Drain BOPE's.
14:30 15:00
9/25/2015 9/25/2015 2.25 COMPZN RPCOMP NUND XT Nipple down BOPE's.
15:00 17:15
9/25/2015 9/25/2015 0.75 COMPZN RPCOMP OTHR XT Inspect tubing spool,multiple
17:15 18:00 scratches. Attempt to buff out with
emery cloth. Discuss with Cameron
rep.
9/25/2015 9/25/2015 1.00 COMPZN RPCOMP NUND XT Nipple down tubing spool.
18:00 19:00
9/25/2015 9/25/2015 1.50 COMPZN RPCOMP WWSP XT Install secondary packoff bushing in
19:00 20:30 new spool and nipple up.
9/25/2015 9/25/2015 0.50 COMPZN RPCOMP WWSP XT PT casing packoffs 250/3000 psi-
20:30 21:00 good.
9/25/2015 9/25/2015 2.50 COMPZN RPCOMP NUND XT Nipple up BOPE's and install riser and
21:00 23:30 mouse hole.
9/25/2015 9/26/2015 0.50 COMPZN RPCOMP BOPE XT Set test plug.
23:30 00:00
9/26/2015 9/26/2015 0.50 COMPZN RPCOMP BOPE XT PT BOP to tubing break 250/3000 psi 0.0 0.0
00:00 00:30 for five minutes-good.
9/26/2015 9/26/2015 1.00 COMPZN RPCOMP MPSP XT Make up model'G'retrieving tool,trip 0.0 90.0
00:30 01:30 in hole to 90'and engage model'G'
plug.
Page 14/17 Report Printed: 10/15/2015
• •
• , Operations Summary (with Timelog Depths)
.ti
,:; 1D-06
ConocoPhill ps
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
9/26/2015 9/26/2015 0.50 COMPZN RPCOMP PULD XT POOH laying down drill pipe. 90.0 0.0
01:30 02:00
9/26/2015 9/26/2015 0.50 COMPZN RPCOMP RURD X Rig up to RIH with 3-1/2"completion. 0.0 0.0
02:00 02:30 Rig up Weatherford power tongs.
9/26/2015 9/26/2015 1.50 COMPZN RPCOMP PUTB X PJSM. RIH with 3-1/2"completion as 0.0 379.0
02:30 04:00 per detail to 379'.
9/26/2015 9/26/2015 10.50 COMPZN RPCOMP PUTB P PJSM. RIH with 3-1/2"completion as 379.0 7,823.0
04:00 14:30 per detail to 7,823'.
9/26/2015 9/26/2015 1.50 COMPZN RPCOMP RURD P Rig up to circulate. Make up head pin 7,823.0 7,823.0
14:30 16:00 on joint. Remove air slips and
stripping rubber
9/26/2015 9/26/2015 1.00 COMPZN RPCOMP PUTB T Break circulation at 1 bpm 60 psi. 7,823.0 7,831.0
16:00 17:00 Observe pressure increase at 7,831'.
Slack off 10K down,weight came off.
Continue slacking off to 7,834'and
stack 15K down. Observe weight drop
off. Slack off to 7,835'with 25K WOB,
unable to swallow tubing stub. Pick
up to 7,825',pump pressure 160 psi.
Stage pumps up to 3 bpm to clear
overshot,pressure 250 psi. Slow
pumps down to 1 bpm and slack off.
Observe pressure increase at 7,831',
attempt to swallow overshot twice
more with similar results.
9/26/2015 9/26/2015 0.50 COMPZN RPCOMP RURD T Rig down cement line and head pin. 7,831.0 7,831.0
17:00 17:30
9/26/2015 9/27/2015 6.50 COMPZN RPCOMP PULL T POOH with tubing standing back in 7,831.0 1,000.0
17:30 00:00 derrick to 1000'.
9/27/2015 9/27/2015 1.50 COMPZN RPCOMP PULL T Continue to POOH with 3-1/2" 1,000.0 150.0
00:00 01:30 decompletion as per detail to 150'.
9/27/2015 9/27/2015 1.50 COMPZN RPCOMP PULL T Lay down PBR,packer,'DS'nipple 150.0 0.0
01:30 03:00 and overshot. Inspect overshot.
Partial stainless steel band inside of
overshot,slight wear on outside of
overshot,wear inside overshot.
9/27/2015 9/27/2015 1.00 COMPZN RPCOMP BHAH T Bring RCJB and crossovers to rig 0.0 0.0
03:00 04:00 floor. Rig up to RIH with RCJB
9/27/2015 9/27/2015 0.50 COMPZN RPCOMP BHAH T Make up BHA,RCJB and crossovers. 0.0
04:00 04:30
9/27/2015 9/27/2015 5.50 COMPZN RPCOMP TRIP T RIH w/RCJB on 3-1/2 EUE 8rd 0.0 7,831.0
04:30 10:00 Tubing to top of stump @ 7,831-ft 99K
up wt,75k do wt.
9/27/2015 9/27/2015 1.00 COMPZN RPCOMP RURD T RU head pin in tubing joint,MU to 7,831.0 7,831.0
10:00 11:00 stump and RU circulation hose.
9/27/2015 9/27/2015 1.00 COMPZN RPCOMP CIRC T Pump 35 bbl high visc sweep @ 8 7,831.0 7,831.0
11:00 12:00 bpm 2,050 psi while washing down
and locating stump. Pick up off of
stump and continue to function tool
while circulating surface to surface.
9/27/2015 9/27/2015 1.00 COMPZN RPCOMP RURD T RD circulating equipment while 7,831.0 7,831.0
12:00 13:00 monitoring the well for flow.
9/27/2015 9/27/2015 4.50 COMPZN RPCOMP TRIP T POOH laying down 6 joints and stand 7,831.0 0.0
13:00 17:30 back 249 joints.
9/27/2015 9/27/2015 0.50 COMPZN RPCOMP BHAH T Break out RCJB; 1 stainless steel 0.0 0.0
17:30 18:00 band recovered.
9/27/2015 9/27/2015 0.50 COMPZN RPCOMP RURD 'T Clean and clear rig floor. Prep to run 0.0 0.0
18:00 18:30 3-1/2"completion.
Page 15/17 Report Printed: 10/15/2015
• •
;.i.0Operations Summary (with Timelog Depths)
o
1D-06
Conoc llips
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
9/27/2015 9/28/2015 5.50 COMPZN RPCOMP PUTB T PJSM RIH with 3-1/2"completion as 0.0 6,800.0
18:30 00:00 per detail to 6800'.
9/28/2015 9/28/2015 2.00 COMPZN RPCOMP PUTB T Continue to trip in hole with 3-1/2" 6,800.0 7,826.0
00:00 02:00 completion string as per detail from
6800'to 7823'. PUW 100K,SOW 75K
9/28/2015 9/28/2015 1.00 COMPZN RPCOMP RURD T Rig up head pin to circulate. 7,826.0 7,826.0
02:00 03:00
9/28/2015 9/28/2015 1.00 COMPZN RPCOMP HOSO T Establish circulation at 2 bpm 90 psi. 7,826.0 7,837.0
03:00 04:00 Slack off and observe pressure
increase at 7833'with 5K down
weight. Observe weight drop off.
Continue to slack off to 7834.5'
observe overshot shear screws shear
at 8K. Continue to slack off to 7836'.
Taking weight. Slack off to 7837'with
20K down. Unable to slack off any
more. Pick up to 7830'and engage
pumps,observe pressure increase at
7,833'. Continue to slack of and tag
up at same spot. Repeat process with
same results. Consult with town
engineer.
9/28/2015 9/28/2015 0.50 COMPZN RPCOMP CRIH P Pick up to 7,830'and spot corrosion 7,830.0 7,830.0
04:00 04:30 inhibited brine from mule shoe up to
PBR. Pump 10 bbls corrosion
inhibited brine at 4 bpm 380 psi.
9/28/2015 9/28/2015 1.25 COMPZN RPCOMP PACK P Drop ball and rod and wait 15 minutes. 7,830.0 7,714.0
04:30 05:45 Pressure up to 2500 psi to set FHL
packer,Pressure IA to 3,000 psi while
holding TBG pressure. Verify
integrity,Bleed off IA. Pull 10k OSW
and shear out of PBR w/2,500 psi still
on TBG. Bleed off Tbg and relocate
PBR top at 7,714-ft.
9/28/2015 9/28/2015 1.50 COMPZN RPCOMP HOSO P Calculate space out. Lay down partial 7,714.0 7,714.0
05:45 07:15 joint and two full joints. Pick up 4.28'
pup joint followed by full joint. Make
up tubing hanger and landing joint.
9/28/2015 9/28/2015 1.25 COMPZN RPCOMP CRIH P Displace well to corrosion inhibited 7,714.0 7,714.0
07:15 08:30 fluid at 4 bpm 600 psi.
9/28/2015 9/28/2015 0.50 COMPZN RPCOMP RURD P Blow down lines. Rig dow circulation 7,714.0 7,714.0
08:30 09:00 hoses. Drain BOP stack.
9/28/2015 9/28/2015 0.25 COMPZN RPCOMP THGR P Land hanger,RILDS. 7,714.0 7,736.0
09:00 09:15
9/28/2015 9/28/2015 1.50 COMPZN RPCOMP PRTS P PT tubing to 3500 psi for 10 minutes. 0.0 0.0
09:15 10:45 Bleed to 2000 psi and PT IA to 3000
psi for 30 minutes. Both tests good.
Bleed off IA and Tubing. Pump down
IA and shear out SOV
9/28/2015 9/28/2015 1.00 COMPZN RPCOMP RURD P Blow down lines. Rig down landing 0.0 0.0
10:45 11:45 joint and circulation equipment.
9/28/2015 9/28/2015 0.50 COMPZN WHDBOP MPSP P Set'HP'BPV 0.0 0.0
11:45 12:15
9/28/2015 9/28/2015 2.25 COMPZN WHDBOP OTHR P Rig down Weatherford tongs. Clean 0.0 0.0
12:15 14:30 and clear rig floor,lay down tongs and
crossovers.
Page 16/17 Report Printed: 10/15/2015
• •
0
Operations Summary (with Timelog Depths)
0.
1D-06
Conoco hitt ps
Rig: NABORS 9ES Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
9/28/2015 9/28/2015 7.50 COMPZN WHDBOP SVRG P Perform BWM inspection. 0.0 0.0
14:30 22:00
Install test joint and function annular
element. Appears in good condition.
Open ram doors and inspect rams.
Change out lower pipe rams to 2-7/8"
x 5"VBR's
9/28/2015 9/28/2015 1.50 COMPZN WHDBOP NUND P Nipple down BOP stack and set back 0.0 0.0
22:00 23:30 on stump
9/28/2015 9/29/2015 0.50 COMPZN WHDBOP OTHR P Clean and prep wellhead. 0.0 0.0
23:30 00:00
9/29/2015 9/29/2015 2.75 COMPZN WHDBOP NUND P PJSM nipple up tubing head adapter. 0.0 0.0
00:00 02:45 PT packoffs 250/5000 psi-good.
9/29/2015 9/29/2015 1.25 COMPZN WHDBOP NUND P Nipple up tree. Surface safety valve 0.0 0.0
02:45 04:00 orientated towards BOP stack. Shim
up BOP stack to allow room for SSV.
9/29/2015 9/29/2015 1.75 COMPZN WHDBOP PRTS P Rig up and pressure test tree 0.0 0.0
04:00 05:45 250/5000 psi-good.
9/29/2015 9/29/2015 0.50 COMPZN WHDBOP MPSP P Pull test dart and'HP'BPV. 0.0 0.0
05:45 06:15
9/29/2015 9/29/2015 0.75 COMPZN WHDBOP OTHR P Secure BOP stack to stump and from 0.0 0.0
06:15 07:00 top.
9/29/2015 9/29/2015 0.50 COMPZN WHDBOP SVRG P Break down squeeze manifold, 0.0 0.0
07:00 07:30 inspect,and change out gaskets.
9/29/2015 9/29/2015 0.50 COMPZN WHDBOP FRZP P RU LRS. RU hoses and manifold to 0.0 0.0
07:30 08:00 freeze protect,verify line up,and PT
lines to kill tank with air.
9/29/2015 9/29/2015 1.00 COMPZN WHDBOP FRZP P PJSM. PT lines to 2500 psi(good 0.0 0.0
08:00 09:00 test). Pump 75 bbls of diesel freeze
protect down the IA taking returns out
the tubing to the kill tank at 2 BPM
(ICP=450 psi and FCP=900 psi).
9/29/2015 9/29/2015 0.50 COMPZN WHDBOP FRZP P RD LRS. Place the IA and tubing in 0.0 0.0
09:00 09:30 communication allowing the well to u-
tube and equalize.
9/29/2015 9/29/2015 0.50 COMPZN WHDBOP FRZP P Blow down lines and RD hoses for u- 0.0 0.0
09:30 10:00 tube. Drain tree to the wing valve for
setting the BPV.
9/29/2015 9/29/2015 0.50 COMPZN WHDBOP MPSP P PJSM. Install'H'BPV. 0.0 0.0
10:00 10:30
9/29/2015 9/29/2015 1.50 DEMOB MOVE RURD P Secure the tree. Clean and clear the 0.0 0.0
10:30 12:00 cellar. RD hoses in the pits. Blow
down steam and water in the pits.
Break down the interconnect. Secure
the well and release the rig at 12:00
hours. Final well pressures: Tubing=
0 psi,IA=0 psi,and OA=0 psi.
Page 17/17 Report Printed: 10/15/2015
PTO l7-1 —a
•
Loepp, Victoria T (DOA)
From: Loepp, Victoria T (DOA)
Sent: Thursday, September 03, 2015 2:53 PM
To: 'Guzman, Diana'
Subject: KRU 1D-06(PTD 179-096.Sundry 315-024) Request for packer depth waiver
Follow Up Flag: Follow up
Flag Status: Completed
Diana,
A waiver is granted to allow the placement of the packer up to 300' MD above the top perforation of 8042' MD based on
information provided in this waiver request. (20 AAC 25.412(b)). Please include this waiver with the approved PTD. The
modified procedure as outlined below is approved.
Thanx,
Victoria
Victoria LoeppED MAR 0 S 2016
Senior Petroleum Engineer `,�CMNN
State of Alaska
Oil&Gas Conservation Commission
333 W.7th Ave,Ste 100
Anchorage,AK 99501
Work: (907)793-1247
Victoria.Loeppealaska.qov
CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged
information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended
recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to
you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov
From: Guzman, Diana [mailto:Diana.Guzman@lconocophillips.com]
Sent: Tuesday, August 25, 2015 4:52 PM
To: Loepp, Victoria T(DOA)
Subject: Request for variance - Sundry 315-024 - PTD 179-096
Dear Victoria,
The following is to request permission for an alternate packer placement depth which is outside of the designated <_200'
MD prescribed by 20 AAC 25.412(b),for the sundry approved on January 23, 2015 with number 315-024 (PTD: 179-096).
The proposed completion submitted with the approved sundry to workover 1D-06 had not planned for a newer packer.
Upon careful consideration we are requesting permission to set the new packer at"'7753' RKB,which is above where
the current gas lift mandrel sits (see current schematic).The reasoning for this request is that we would prefer to
mitigate the risk of pulling the packer at 7864'while we're trying to pull the seals free.The modified procedure would
include the following steps:
i
• A pre-rig chem cut at 7828 D.
•
• RIH with a poor boy overshot, landing nipple and a packer to engage the tubing stub at 7828'
The new packer depth is above the deepest GLM since we prefer not to set packers in casing that has been subject to
stagnant fluid between the deepest GLM and the packer.
I attached a copy of the Acoustic Cement Bond Log VDL performed by Arco on October 9, 1980 for your review.The
CBL/VDL shows a good cement bond to casing in our desired packer setting depth at 7753' RKB.
Attached are also the following:
• New schematic with the updated proposed completion for 1D-06
• Current schematic for 1D-06
• A copy of the approved sundry 315-024
If you have any questions or require any further information, please contact me at 265-6318.
Thank you for your time.
Sincerely,
Diana Guzman
Senior Wells Engineer
ConocoPhillips Alaska Inc.
Drilling&Wells
700 G Street(ATO-1502)
Anchorage,AK 99501
Main:907-265-6318
Cell:305-332-6332
Fax:918-662-1893
2
KUP INJ I 17 q 6 o• 1 D-06
ConocoPhillips `4 Well Attributes Max Angle&MD TD
Alaska,Inc. Wellbore API/UWI Field Name -Wellbore Status nd r) MD(9848) Act Btm(RKB)
c,...,0,4,.„,,, I` 500292041800 KUPARUK RIVER UNIT INJ 48.98 4,400.00 8,941.0
••• Comment H25(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date
10-06,6120/20151:06:35 PM SSSV:LOCKED OUT Last WO: 8/11/1991 38.991 10/11/1980
Vertcal schematc(actual)
'Annotation Depth(R(B) End Date Annotation Last Mod By End Date
Last Tag:SLM 8,130.0 1/30/2014 Rev Reason:PULLED CATCHER,PULLED fehallf 6/20/2015
PLUG
-'' CasingStrings
HANGER;22-0 g
Casing Description OD(n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVO)... Wt/Len(L..Grade Top Thread
CONDUCTOR 16 15.250 25.0 80.0 80.0 65.00 H-40 WELDED
Casing Description 00(1n) ID(in) Top(9848) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread
SURFACE 103/4 9.950 26.0 2,974.0 2,684.8 45.50 K-55
Casing Description OD lin) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread
PRODUCTION 7 6.276 265 8,586.6 5890.7 26,00 K-55 BTC
Tubing Strings
.11 Tubing Description String Me...ID(in) Top(ftKB) Set Depth(R..Set Depth(TVD)(...Wt(IbRt) Grade Top Connection
TUBING WO 3 1/2 2.992 22.0 7,927.6 6,319.5 9.30 J-55 EUE-MOD
Completion Details
..via
Nominal ID
Top(ftKB) Top(1VD)(ftKB) Top Incl r) Item Des (in)
- -"- 22.0' 22.0 0.05 HANGER CAMERON GEN IV HANGERCom 3.500
1,937.3 1,896.4 30.44 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE(LOCKED OUT 2.812
6/25/2003)
-`-M CONDUCTOR;25.0-8O obol✓.."-is .,r 7,850.2" 6,252,7 30.53 PBR BAKER PBR w/10'STROKE 2.875
7,864.0 6,264.6 30.47 PACKER BAKER HB RETRIEVABLE PACKER 2.875
7,870.2 6,269.9 30.45 SBR BAKER SBR 3.000
7,893.8 6,290.3' 30.35'PACKER BAKER FHL RETRIEVABLE PACKER 2.891
SAFETY VLV;1,937.3 7,913.3 6,307.1 30.28 NIPPLE CAMCO D NIPPLE NO GO 2.750
7,926.7 6,318.7 30.24 SOS BAKER SHEAR OUT SUB,TTL ELMD @ 7923'PER 3.000
SWS PROF 7/29/1999
Perforations&Slots
Shot
SURFACE;26.0-2,974.0 • Dens
Top(TVD) Btm(TVD) (shots/t
Top(RKB) Btm(RKB) (RKB) (RKB) Zone Date 0 Type Corn
8,042.0 8,130.0 6,418.5 6,494.6 C-2,C-3,C-4, 6/9/1981 4.0 IPERF
UNIT D,1D-
O6
8,130.0 8,143.0 6,494.6 6,505.8 UNIT B,ID- 9/11/2008 6.0 RPERF 2.5"HSD 2506 PJ t1MX
06 GUN,60 DEG PHASING
8,311.0 8,329.0 6,651.1' 6,666.8 A-5,1D-06 6/9/1981 4.0 (PERF
GAS LIFT;7600.9 Mandrel Inserts
St
ati
on
_-._- N Top(TV)) Valve Latch Port Size TRO Run
Top(ftKB) (RKB) Make Model OD(in) Seen Type Type (in) (psi) Run Date Com
-i' 7,801.0 6,210.3 CAMCO MMG-2 OPEN 0.000 0.0 8/7/2014
P8R;7800.2
AM
PACKER;1,864.0
SBR;7,870.2
TUBING SPACE OUT;7,891.8
PACKER;7,893.8 r a 4
NIPPLE;7,913.2
—_
SOS;7.926.7
I
IPERF;8,0/208,130.0. I
I
RPERF;8,130.08,143.0 I
I
IPERF;8,311.08,329.0
1
PRODUCTION;26.5-8,586.6
•
ConocoPhillips -
1D-06
Proposed Completion
P&R Tubing&Csg Stretch
...._
P - 11 A:
CONDUCTOR-16",65#,H-40 •
WELDED @ 80'MD ,.�,
II Baker 7"Overshot Casing Patch
-4-- SURFACE CSG 10.75",45.5#,K-55 BTC @ 2974'MD
MP 1— 3'/z"x 1"MMG GLM
J -4--- BAKER PBR WITH SEAL LOCATOR
tiiiiBAKER RETRIEVABLE PACKER @ 7753'
D e - 2.875"DS NIPPLE PROFILE
4— 3'/2"POOR-BOY OVERSHOT
ol [
-4— 3W TUBING CHEM CUT @ 7828'
IBAKER HB RETRIEVABLE PACKER @ 7864'
t BAKER 3'W SEAL BORE RECEPTICLE @ 7870'
11:111.1.711
r r BAKER FHL RETRIEVABLE PACKER @ 7894'
t— CAMCO D NIPPLE NO GO @ 7913'
TUBING—3.5"9.3#,J-55,EUE-MOD —•.-
_9
� ,7 F♦— ELMD TTL @ 7928'
UNIT 0,C-3,C-2,C-1 IPERF @ 8042'-8130' --0-----t---- 7.--:--=--
=
UNIT B,IPERF @ 8130'-8143' �_
A-5 IPERF @ 8311'-8329' n
PRODUCTION CSG—7",26#,K-55 @ 8587'MD --M.-
..__
►G
Date: August 25"2015 I Dram By: liana Guzman 1
r•••:":0FAlaska Oil and Gas
Iy/,�s� THE STATE, �M of Conservation Commission
_ ALASI�:A
333 West Seventh Avenue
GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572
ZrZnla
Main: 907.279.1433
'
FALASY', 2N5 Fax. 907.276.7542
,� www.aogcc.alaska.gov
cc
Diane Guzman
Senior Wells Engineer
ConocoPhillips Alaska, Inc.
P.O. Box 100360 1 1
Anchorage, AK 99510
Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 1D-06
Sundry Number: 315-024
Dear Ms. Guzman:
Enclosed is the approved application for sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the
AOGCC an application for reconsideration. A request for reconsideration is considered timely if
it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend.
Sincerely,
/° 9*
Cathy . Foerster
Chair
2 Pi
DATED this day of January, 2015
Encl.
. : STATE OF ALASKA
• AL a OIL AND GAS CONSERVATION COMM )N
' APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r, Change Approved Program r
Suspend r Rug Perforations r Perforate r Pull Tubing F • Time Extension r
Operational Shutdown r Re-enter Susp.Well r StimulateAlter casing 9 r-Other: r
2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number:
ConocoPhillips Alaska, Inc. • Exploratory r Development r 179-096
3.Address: Stratigraphic r Service 17 ,
6.API Number:
P.O. Box 100360,Anchorage,Alaska 99510 50-029-20418-00
7.If perforating, 8.Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require spacing exception? Yes r No F KRU 1 D-06
9.Property Designation(Lease Number): 10.Field/Pool(s):
ADL 25650 - Kuparuk River Field/Kuparuk River Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total depth MD(ft): Total Depth TVD(ft)• Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured):
8610 • 6911 • 7907' none
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 55 16 80' 80'
SURFACE 2948 10.75 2974' 2685'
RECEIVED
PRODUCTION 8560 7 8587' 6891'
JAN 1 1 2015
AOGCC
Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft):
8042'-8143',8311'-8329' - 6419'-6506',6651'-6667' I3.5 J-55 7928
Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft)
PACKER-BAKER HB RETRIEVABLE PACKER MD=7864 TVD=6265
PACKER-BAKER FHL RETRIEVABLE PACKER MD=7894 TVD=6290 •
SSSV-CAMCO TRDP-4A MD=1938 TVD=1897 ,
12.Attachments: Description Surrmary of Proposal l✓ 13. Well Class after proposed work:
Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r
14.Estimated Date for Commencing Operations: 15. Well Status after proposed work:
1/30/2015 Oil r Gas r WDSPL r Suspended r
16.Verbal Approval: Date: WINJ r GINJ r- WAG r • Abandoned r
Commission Representative: I GSTOR r SPLUG r
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Diana Guzman @ 265-6318
Email: Diana.Guzmanaconocophillips.com
Printed Name Diana Guzman Title: Sr. Wells Engineer
Signature F xx C(7/1„.1„.„„‘__ Phone:265-6318 Date I/1 LI-' 15
Commission Use Only
Sundry Number:
Conditions of approval: Notify Commission so that a representative may witness 3\5^ 024
Plug Integrity r BOP Test V Mechanical Integrity Test r Location Clearance r
SOP OP 1-05 f (i O L1 to 6 /2 5 , ( , P 5 P 2 \
/5 p 5 ' )
S7�fc wtn
� • e-55rd / 774 rrli-ir-r-d ftrr Sf-ct but' ccl 1njr.ct/owl .
Spacing Exception Required? Yes ❑ No 27 Subsequent Form Required: 1 c - l-C 4--
AAPPROVED BY
pproved by:
9;1)(-( 4 — COMMISSIONER THE COMMISSION Date: /-23 —/4--
,,,_ 6 ZZ/'/,j Approved application Is valid tor 12 month$/trom the date of approval.
Form 10-403(Revised 10/2012) ? i/ I il RS—
Submit Form and Attachments in Du licate
ORIGINAL ���/�BDMSAA. JAN 26201 "-°2.3
ConocoPhillips RECEIVED
Alaska JAN 14 2015
P.O. BOX 100360
ANCHORAGE,ALASKA 99510-0360 AOGCC
January 13,2014
Commissioner Cathy Foerster
State of Alaska
Alaska Oil&Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage,Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska,Inc. hereby submits an Application for Sundry Approval to workover the Kuparuk Well 1D-
06(PTD# 179-096).
Well 1D-06 was originally drilled in 1980 and completed as a pre-producing injector in 1981. 1D-06 became an A
and C sand injector in 1983 during a workover to repair a leaking packer at 7960'. During 1991 a rig workover was
performed in order to repair a leaking packer at 7872'. 1D-06 was then completed with a new stacked packer and
3'Y2"completion.Until May 1997 well 1D-06 was a gas injector used for gas storage.
Well 1D-06 failed a mechanical integrity test for the tubing (MIT-T) on July 2014. Follow up diagnostics
concerning the fai e. MIT-T were per ormes and a leak detect log identified a leak in the tubing at 5062'. The lower
packer also showed a leak at 7895' and 7896'. A gyro and caliper log performed on January and March 2014
indicated that the 1D-06 tubing is showing signs of subsidence. 1 D-06 is currently shut-in awaiting a rig workover.
Before being shut-in in 2014,well 1D-06 was injecting between 3000 to 7000 bwpd.
The purpose of this workover is to place the production casing back in tension to combat the effects of future
subsidence,replacing the top 200' of the 7"production casing,if necessary,as well as regain control of the injection
into the A and C sands. This will be accomplished by stretching the production casing and replacing the tubing from
the upper packer. This Sundry is intended to document the proposed work on the injection well, as well as request
approval to workover the well.
If you have any questions or require any further information,please contact me at 907-265-6318.
Sincerely,
Diana Guzman
Wells Engineer
CPAI Drilling and Wells
1D-06 Rig Workover
Pull & Replace Tubing,
Stretch Production Casing
(PTD #: 179-096)
Current Status: This well is currently shut in and awaiting pre-RWO well work.
Scope of Work:
• Pull and replace upper selective
• Stretch production casing. (A cut of the production casing and a Baker Csg patch may be necessary after V
stretching the casing due to a possible mandrel hanger with a 4.5' long tubing pup below).
General Well info:
Well Type: Injector
MPSP: 2815 psi using 0.1 psi/ft gradient(Most recent SBHP=3450 psi on 07/23/14) ✓
Reservoir Pressure/TVD: 3450 psi/6355' TVD(10.5 ppg)on 07/23/14
Wellhead type/pressure rating: McEvoy Gen I/5M psi TH,3M Csg Hd.
BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams
TIFL/MIT results: CMIT—T x IA passed July 24,2014
MIT—T failed July 24,2014
MIT—IA passed February 5,2014
MIT—OA passed February 5,2014
Earliest Estimated Start Date: February 1,2015
Production Engineer: Ashok Mishra
Workover Engineer: Diana Guzman
Work:265-6318
E-mail:Diana.Guzman@conocophillips.com
Pre-Rig Work
1. Perform a combo DDT TxIA.
a. If combo DDT fails rig up DSL:
i. RIH with WRP and locate X-nipple(-7872')in the SBR. Set WRP above the X-nipple.
ii. Perform a combo(DDT and TxIA)to confirm plug integrity.
iii. Confirm that the SSSV is locked out.
2. PT tubing and casing packoffs,FT LDS's.
3. Set BPV.
Proposed Procedure:
1. MIRU
2. Pull BPV. Circulate workover fluid. Obtain S1TP& SICP, if still seeing pressure at surface,calculate new
KWF,weight up,and repeat circulation as necessary. Verify well is dead.
3. Set BPV&blanking plug or two-way check,PT from below if possible.ND tree,NU BOPE&test to 3000
psig.
4. Pull blanking plug&BPV. Screw in landing joint,BOLDS's,and pull tbg hgr to the rig floor.
5. POOH laying down 3 '/2"tubing.
a. If tubing will not pull free,RU E-line: Cut the tubing.RDMO E-line.
b. If the SSSV doesn't pull free through damaged casing, set the tubing in slips. Cut the control line
and band it to the tubing.
•
•
1D-06 Rig Workover
Pull & Replace Tubing,
Stretch Production Casing
(PTD #: 179-096)
c. RIH with tubing one joint below tight spot in the casing. MU storm packer and set -500' MD.
Release from storm packer,PT and perform a NFT.ND BOPE.
6. While pulling out of hole, MU storm packer. Set storm packer at—500'. NDBOP&Tbg head, stretch the
casing, reland casing, cut excess casing, replace tbg head & IC packoffs, NU BOP & test. Pull storm
packer.
a. If casing cannot be relanded due to mandrel hanger,set in temporary slips.
b. RIH with Multistring cutter and cut casing at—200' (mid casing joint).POOH laying down cutter.
c. MU to casing with spear or landing joint. PU 1'. No-flow test. POOH laying down casing.
Determine if casing cut needs to be dressed off by looking at the pulled half of the cut.
d. If cut needs to be dressed: RIH w/dressing mill and dress cut. POOH standing back DP.
e. RIH with new casing and casing patch. Engage patch. Set patch and PU. PT casing and PT OA.
ND BOPE. Set casing in slips with tension.
f. Cut casing with Wachs cutter. Install packoffs. NU tubing head and pressure test packoffs. NU
BOPE and test.
7. RIH and fish tubing stub if needed.
8. MU new 3 '/2"injector completion.RIH to PBR until fully located,
9. MU hanger. Load the IA w/corrosion inhibited completion fluid.Land the hanger,RILDS.
10. PT the tubing and IA.Ramp up the IA pressure quickly to shear the SOV.
11. Pull the landing joint,install two-way check.PT two-way check through IA.
12. ND BOPE,NU tree. Pull BPV,install tree test plug. Test tree. Pull tree test plug.
13. Freeze protect well.
14. Set BPV.
15. RDMO.
Post-Rig Work
1. Reset well house(s)and flowlines of adjacent wells.
2. Pull BPV.
3. RU Slickline: Pull SOV from GLM replace w/DV. Set up for injection.
4. RIH and retrieve WRP in SBR(if installed),
5. RIH and retrieve catcher and WRP.
6. Handover to Ops to put back on injection.
ConocoPhilli s- -
1D-06
Proposed Completion
P&R Tubing&Csg Stretch
CONDUCTOR-16",65#,H-40 ►.
WELDED @ 80'MD
148 Baker 7"Overshot Casing Patch
SURFACE CSG 10.75",45.5#,K-55 BTC @ 2974'MD
3'/i'x 1"MMG GLM
0 — 2.875"DS NIPPLE PROFILE
BAKER PBR WITH SEAL LOCATOR @ 7850'
BAKER HB RETRIEVABLE PACKER @ 7864'
4 BAKER 3%"SEAL BORE RECEPTICLE @ 7870'
- BAKER FHL RETRIEVABLE PACKER @ 7894'
ITC I D — CAMCO D NIPPLE NO GO @ 7913'
TUBING-3.5"9.3#,J-55,EUE-MOD --►
E_4111 ELMD TTL @ 7928'
UNIT D,C-3,C-2,C-1 IPERF @ 8042'-8130' —10-_
UNIT B,IPERF @ 8130'-8143' ►_
A-5 IPERF @ 8311'-8329'
PRODUCTION CSG-7",26#,K-55 @ 8587'MD — -
Date: January 9,2015 I Drawn By: Diana Guzman
s E KUP INJ 1D-06
r ConocoPhillips u Well Attributes Max Angle&MD TD
Alaska,Inc. Wellbore APVUWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB)
conn,,;min,p, 500292041800 KUPARUK RIVER UNIT INJ 48.98 4,400.00 8,941.0
... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date
1D-06,8/820146.01.28 AM SSSV:LOCKED OUT Last WO: 8/11/1991 38.99 10/11/1980
Vertical schematic(acluap Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
Last Tag:SLM 8,130.0 1/30/2014 Rev Reason:SET CATCHER,GLV C/0 hipshkf 8/8/2014
.............
HANGER,220 Casing Strings
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread
CONDUCTOR 16 15.250 25.0 80.0 80.0 65.00 H-40 WELDED
Casing Description OD(in) ID(in) Top(ftKB) Set Depth OMB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
SURFACE 103/4 9.950 26.0 2,974.0 2,684.8 45.50 K-55
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(FMB) Set Depth(ND)... WVLen(I...'Grade Top Thread
PRODUCTION 7 6.276 26.5 8,586.6 6,890.7 26.00 K-55 BTC
Tubing Strings
Tubing Description String Ma...ID(in) Top(MB) Set Depth(ft..Set Depth(ND)(.,,Wt(Ib/ft) Grade Top Connection
L TUBING WO 312 2.992 22.0 7,927.6 6,319.5 9.30 J-55 EUE-MOD
ma.Completion Details
Nominal ID
I
Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in)
22.0 22.0 0.05 HANGER CAMERON GEN IV HANGER 3.500
I1,937.3 1,896.4 30.44 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE(LOCKED OUT 2.812
6/25/2003)
,./S.A.A.CONDUCTOR;25.080.0'
7,850.2 6,252.7 30.53 PBR BAKER PBR W/10'STROKE 2.875
7,864.0 6,264.6 30.47'PACKER BAKER HB RETRIEVABLE PACKER 2.875
7,870.2 6,269.9 30.45 SBR BAKER SBR 3.000
SAFETY VLV,19373 '!�I, 7,893.8 6,290.3 30.35 PACKER BAKER FHL RETRIEVABLE PACKER 2.891
7,913.3 6,307.1 3028 NIPPLE CAMCO D NIPPLE NO GO 2.750
7,926.7 6,318.7 30.24 SOS BAKER SHEAR OUT SUB,TTL ELMD @ 7923'PER 3.000
SWS(PROF 7/29/1999 '
SURFACE;26.0-2,974.0-4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
Top(ND) Top Incl
Top(ftKB) (ttKB) (7 Des Com Run Date ID(in)
7,904.0 6,299.1 30.32 CATCHER 2.77"CATCHER(GAL=37") 8/6/2014
7,907.0 6,301.7 30.31 PLUG 2.69"WEATHERFORD WRP 7/24/2014
Perforations&Slots
Shot
Dens
Top(ND) Btm(ND) (shots/I
GAS LIFT;7,800.9 Top(ftKB) Btm(ftKB) (MB) (ftKB) Zone Date t) Type Com
8,042.0 8,130.0 6,418.5 6,494.6 C-2,C-3,C-4, 6/9/1981 4.0 (PERF
UNIT D,1D-
06
8,130.0 8,143.0 6,494.6 6,505.8 UNIT B,1D- 9/112008 6.0 RPERF 2.5"HSD 2506 PJ HMX
06 GUN,60 DEG PHASING
8,311.0 8,329.0 6,651.1 6,666.8 A-5,1D-06 6/9/1981 4.0 IPERF
PBR;7,550.2 Mandrel Inserts n
St
PACKER;7,864.0 at) C
on Top(ND) Valve Latch Port Size TRO Run
!I No Top(ftKB) (ftKB) Make Model OD 00) Sery _ Type Type (in) (psi) Run Date m
SBR;7970.2 1 7,801.0 6,210.3 CAMCO MMG-2 OPEN 0.000 0.0 8/7/2014
TUBING SPACE OUT;7,891.8
PACKER;7,893.8
F.CATCHER;7,904.0 (1
PLUG;7.807.0
NIPPLE;7,913.2-
SOS;7,926.7
IPERF;8,042.0-8,130.0
RPERF;8,130.0.8,143.0--..
IPERF;8,311.08,329.0 44-
/ - 4--
PRODUCTION;
PRODUCTION;28.5-8986.8--
MEMORANDUM
State of Alaska
Permit Number: 179-096-0
Alaska Oil and Gas Conservation Commission
To Jim Regg� (
DATE: Monday, August 04, 2014
Rel Insp Num:
SUBJECT: Mechanical Integrity Tests
P.I. Supervisor
15 Min 30 Min 45 Min 60 Min
ell 1D-06 Type Inj W-TTVD 6265 Tubing 2084 2116 "
CONOCOPHILLIPS ALASKA INC
--—
1 D-06
FROM: JeffJones
KUPARUK RIV UNIT ID -06
Petroleum Inspector
361
378
Src: Inspector
Reviewed By:
Notes: The inner annulus would not pressure up to test pressure and would not bleed down below tubing
P.I. Supry ,"(;—
approx. 1 BBL/ minute, failing the MIT. This well was shut in and freeze protected. 1 well inspected, no exceptions noted.
NON -CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 1D-06 API Well Number 50-029-20418-00-00
Inspector Name: Jeff Jones
Permit Number: 179-096-0
Inspection Date: 7/13/2014
Insp Num: mitJJ140715163529
Rel Insp Num:
Packer Depth Pretest Initial
15 Min 30 Min 45 Min 60 Min
ell 1D-06 Type Inj W-TTVD 6265 Tubing 2084 2116 "
1790960 SPT 1566 � 1180 - 2540
TD Type Test Test psi IA
--—
Interval
4YR
P/F T F i
OA
361
378
Notes: The inner annulus would not pressure up to test pressure and would not bleed down below tubing
pressure and appeared to be injecting
approx. 1 BBL/ minute, failing the MIT. This well was shut in and freeze protected. 1 well inspected, no exceptions noted.
SCANNE® OCT 3 0 2W
Monday, August 04, 2014 Page 1 of 1
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm.
Attn.: Makana Bender
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Multi Finger Caliper (MFC): 1D-06
Run Date: 3/12/2014
�-71-arc
v -A 35 0
DATA LOGGED
.(O/S/2014
. M K BENDER
May 19, 2014
RECEIVED
JUN 0 2 2014
AOGCC
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
matthew.cook@halliburton.com
1D-06
Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom
50-029-20418-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Matthew Cook
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-273-3572
Fax: 907-273-3535
matthew.cook@halliburton.com
Date: _
Signed: M ),
Wallace, Chris D (DOA)
From: NSK Problem Well Supv <n1617@conocophillips.com>
Sent: Monday, July 14, 2014 7:35 AM
To: Wallace, Chris D (DOA)
Cc: Senden, R. Tyler
Subject: Report of failed MITIA Kuparuk Injector 1D-06 (PTD 179-096) 7-14-14
Attachments: 1D-06 schematic.pdf; 1D-06 90 day TIO 7-14-14.JPG; MIT KRU 1D-06 7-13-14.xls
Chris,
Kuparuk WAG injector 1D-06 (PTD 179-096) failed a witnessed MITIA yesterday during the 4 yr pad testing. Initial TIO pressures
were 2084/1180/361. The IA was unable to be pressurized above 2540psi. In addition, when attempting to bleed the IA pressure
off, the pressure could not be bled below 2020psi and it climbed back up to 2425psi within 15min. The well was shut in and freeze
protected yesterday. At that point, the IA pressure began to decline as the well cooled down. IA is currently reading
—1400psi. Follow-up tubing packoff testing did pass yesterday, so the wellhead seals are not the suspected source of
communication. Well intervention with Slickline and Eline will be scheduled as needed and the appropriate paperwork will be filed
when the path forward has been established. The well will be added to the monthly report.
Attached are the schematic, 90 day TIO plot and MIT form.
Well Name
1 D-06
Notes: Failed MITIA
Start Date
411512014
Days
90
End Date
7/14/2014
Annular Communication Surveillance
INH P
1000
-
Ar
Date
Brent Rogers /Kelly Lyons
Problem VVeUa Supervisor
Con000PhiUipoAlaska, Inc
Desk Phone (007)05Q'7224
Pager (QU7)G50'7O00pgrQU0
KUP INJ 1D-06
ConocoPhillip5 I U.
Well Attributes
Max Angle & MD
TD
AfaSkB I, tl.
Wellbore APIIUWI Field Name Wellbore Status
500292041800 KUPARUK RIVER UNIT INJ
ncl (`) MD (HKB)
48.98 4.400.00
Act Blm (HKB)
8,941.0
Comtnertt H25 (ppm) Date Annotation End Date
SSSV: LOCKED OUT Last WO: 8/11/1991
KB -Gra (H) Rip RaNase Oata
38.99 10/11/1980
to-,. 5.23. row 2 53 16 PM
Vertical schematic actual
Annotation Depth (HKB) End Date Annotation Las/ Mod Uy
End Data
Last Tag: SLIM 8,130.0 1/30/2014 Rev Reason: Mandrel Orientation lehallf
5123/2014
.......................................................................................................................
HANGER: 22.3
Casing Strings
Casing Description OD (in)ID (inI Top (HKB) Set Depth (fIKB) Set Depth (TVD)... WtlLen (I... Grade
Top Thread
CONDUCTOR 1G 15.250 25.0 80.0 80.0 65.00 H-40
WELDED
Casing Description OD (in) ID (in) Top (HKB) Set Depth (HKB) Set Depth (TVD)... WVLen (I... Grade
Top Thread
SURFACE 103/4 9.950 26.0 2,974.0 2,684.8 45.50 K-55
Casing Description OD (in) ID (in)Top (HKB) Set Depth ( KB) Set Depth (TVD)... WtlLen (I... Grade
Top Thread
PRODUCTION 7 6.276 26.5 8.586.6 6.890.7 26.00 K-55
BTC
Tubing Strings
T 1 , 1g String Ma... ID lin) Top (hK8) Set Depth Irl. Set Depth (ND) (... Wt (Iblft) Gide
Top C lection
T,
TUEINI W11 31l 7'JJl 7.927E G�.19.'� 'J .'�(i I.,`.
I
1404)
Completion Details
Nominal ID
a.
Top (HKB To
I p (TVD) (HKB) Top Incl (°) Item Das Com
(in)
r
22.3 22.3 0.05 HANGER CAMERON GEN IV HANGER
3.500
1,937.6 1,896.7 30.46 SAFETY VLV CAMCO TRDP4A SAFETY VALVE (LOCKED OUT
6/25/2003)
2.812
CONDUCTOR; 25.0-80.0
7,850.3 6,252.8 30.53 PBR BAKER PER w/ 10' STROKE
2.875
7.864.0 6,264.6 30.47 PACKER BAKER HB RETRIEVABLE PACKER
2.875
7,870.2 6,270.0 30.45 SBR BAKER SBR
3.000
7,893.8 6,290.3 30.35 PACKER BAKER FHL RETRIEVABLE PACKER
2.891
7,913.3 6,307.1 30.28 NIPPLE CAMCO D NIPPLE NO GO
2.750
SAFETY VLV, 1,937.6
7,926.7 6,318.7 30.24 OS BAKER SHEAR OUT SUB, TTL ELMD @ 7923' PER
3.000
SINS IPROF 7/29'1999
Perforations & Slots
shat
SURFACE; 260-2,974.0
Top (TVD)
am, (TVD)
Dens
(sholslf
Top (fIKB)
BIT, (ftKB)
(HKB)
(HKB)
Zone
Date
t)
Type
Com
8,042.0
8,130.0
6,418.5
6,494.6
C-2, C-3, C4,
6/9/1981
4.0 IPERF
UNIT D, 1D -
O6
8,130.0
8,143.0
6,494.6
6,505.8
UNIT B, 1D-
9/11/2008
6.0 RPERF
2.5" HSD 2506 PJ HMX
06
GUN. 60 DEG PHASING
8,311.0
8.329.0
6,651.1
6,666.8
1 A-5, 1D -O6
6/9/1981
1 4.0 IPERF
GAS LIFT: 7,801 o
Mandrel Inserts
at
ati
N Top (HKB)
Top (TVD)
(HKB)
Mak.
Model OD (in)
Sary
VaM Latch Port Sim
Typ. Type (in)
TRO Run
(psi)
Run
Date
Com
7,801.0
6,210.3 CAMCO
MMG-2 1 112
GAS LIFT
JDMY IRK 0.0001
0.018l18/1991
1:00
PBR: 7.850.3
PACKER; 7,864.0
SBR; 7,870.2
TUBING SPACE OUT; 7,891 8
as
PACKER; 7,893.8
as
NIPPLE. 7,913 3
SOS. 7.926 7
IPERF: 8,0420-0,130.0
RPERF. 8.130.0-8.143.0
IPERF; 8,311.0.8,329.0
PRODUCTION; 28.5-8,586.6
t
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
Submit to: iim.reggCcDalaska.gov; AOGCC.Inspectors(dalaska.gov; Phoebe. brooks(a, ala ska.gov chris.wallace(g alaska.00v
OPERATOR:
FIELD / UNIT / PAD
DATE:
OPERATOR REP:
AOGCC REP:
ConocoPhillips Alaska, Inc.
Kuparuk / KRU / 1 D
07/13/14
Wilson
Jeff Jones
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well
1D-06
Type In'.
W TVD 6,265' Tubing 2,084 2.116 2,116 2,112 Interval
4
P.T.D.
1790960
Type test
I P Test psi 1566.25 Casing 1,180 2,540 2,420 2,420 1 P/F
F
Notes: Could not pressure above 2540 psi OA 361 378 378 378
Well
I Type In'.
I TVD I Tubing Interval
P.T.D.
I Type test
I Test psi I Casing P/F
Notes: OA
Well
I Type In'.
I TVD
Tubing Interval
P.T.D.
I Type test
I Test psi
Casing P/F
Notes: OA
Well
I Type Inj.1
I TVD Tubing Interval
P.T.D.
I Type test
I Test psi Casing P/F
Notes: OA
Well
I Type In'.
I TVD Tubing Interval
P.T.D.
I Type test
I Test psi Casing P/F
Notes: OA
TYPE INJ Codes
D = Drilling Waste
G = Gas
I = Industrial Wastewater
N = Not Injecting
W = Water
Form 10-426 (Revised 11/2012)
TYPE TEST Codes
M = Annulus Monitoring
P = Standard Pressure Test
R = Internal Radioactive Tracer Survey
A = Temperature Anomaly Survey
D = Differential Temperature Test
MIT KRU 1D-06 7-13-14.xls
INTERVAL Codes
I = Initial Test
4 = Four Year Cycle
V = Required by Variance
O = Other (describe in notes)
MEMORANDUM ~ State of Alaska
Alaska Oil and Gas Conservation Commission
TO: DATE: Tuesday, August 10, 2010
Jim Regg C~ , o
P.I. Supervisor t 1 ~ ~ "' I ~ 1 SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1 D-06
FROM: LOl] GI'1m11d1 KUPARUK RIV UNIT 1D-O6
Petroleum Inspector
Src: Inspector
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv ~~>/
Comm
Well Name: KUPARUK RN UNIT 1D-06 API Well Number: 50-029-20418-00-00 Inspector Name: Lou Grimaldi
Insp Num: mitLG100717092405 Permit Number: 179-096-0 Inspection Date: 7/17/2010
Rel Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well 1D-o6 Type Inj. G' TVD 6265 IA 840 1805 1752 1733 ~
P.T.D 1790960 'iT)'peTest SPT Test psi 1566 ~ QA i 301 301 305 306 ~ -
Interval OTHER ~ p~ P ~ Tubing 2674 2678 2674 2672
Notes: Repeat test from yesterday dueto annulus not full. 1.9 bbl's pumped. Test within acceptable decline.
r ~~ r
,n;S
Tuesday, August 10, 2010 Page 1 of 1
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
~~
Au ust 3 2010 `
g ~ 1~
1 3~,,,,;~~~V
Commissioner Dan Seamount , ;, ~~ ~_ 2U1~~
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100 _ ~,,t~SSiOn
Anchorage, AK 99501 ~:...'. ~. :~ , ,~~ ~ ~1KsK~ ~~"~ ~ ~i`&i Ce~`g
Commissioner Dan Seamount:
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 corrosion inhibitor/sealant was pumped August 1St & 2na 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.
ConocoPhillips Well Integrity Projects Supervisor
•
ConocoPhillips Alaska Inc.
Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
./,
Report of Sundry Operations (10-404)
Kuparuk Field
Date 8/03/10 ~ e ~ n ~ ~ o e n
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
ff bbls ft al
1A-26 50029221150000 1901660 SF n/a 12" n/a 2.6 8/1/2010
1A-27 50029221240000 1901800 SF n/a 27" n/a 4.3 8/1/2010
1 D-03 50029204080000 1790840 17" n/a 17" n/a 1 8/2/2010
1 D-06 50029204180000 1790960 16" n/a 16" n/a 1.7 8/2/2010
1D-07 50029204300000 1791120 17" n/a 17" n/a 4.3 8/2/2010
1L-05 50029211550000 1841230 17" n!a 17" n/a 3.4 8/1/2010
1L-21 50029220439000 1910060 17" n/a 17" n/a 4.3 8/1/2010
1L-24 50029221700000 1910660 32" n/a 32" n/a 7.5 8/1/2010
•
MEMORANDUM
TO: Jim Regg ~ J
P.I. Supervisor ' )~j~ ~(7711i~~
FROM: $Ob NOble
Petroleum Inspector
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Friday, July 23, 2010
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1D-06
KUPARUK RIV UNIT 1D-06
Src: Inspector
NON-CONFIDENTIAL
Reviewed Byr
P.I. Suprv J~~
Comm
Well Name: KUPARUK RIV UNIT 1D-O6 API Well Number: 50-029-20418-00-00 Inspector Name: Bob Noble
Insp Num: mitRCN100718151237 Permit Number: 179-096-0 Inspection Date: 7/16/2010
Rel Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well
P.T.D -~-
1 D-06 "'
~T~'pe Ind, ~
1790-960 ITypeTest =~VD
G 6265 ~
SPT II TCSt pSl ~ 1566
jA
QA
744 ~ i
284
1794
284
IriteCVal 4YRTST P~Ii` F ~ TUblrig 2661 2661
Notes: 5.6 BBLs pumped and we had not pressured up. So I told them to load the hole and bleed the gas off and we would do it later.
„~~}.~~ ' Ft ,~ ~ ~l ~ .
~.w
Friday, July 23, 2010 Page 1 of 1
•
ConocoPhillips
November 13, 2008
:~
Robert Christensen
Production Engineering Specialist.
Greater Kuparuk Unit , NSK-69
PO Box 196105
Anchorage, AK 99519-6105
Phone: (907)659-7535
Fax: 659-7314
Tom Maunder, P.E.
Senior Petroleum Engineer O
State of Alaska, Oil & Gas Conservation Commission G~
33 W. 7`" Ave. Ste. 100 `~ 1
Anchorage, AK 99501
Dear Mr. Maunder,
ConocoPhillips Alaska, Inc. has begun Gas Injection is association with the Kuparuk
River Oil Pool 1 D FOR Expansion.
Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips
Alaska, Inc. for Wells 1D-O5, 1D-06. 1D-10, 1D-11, 1D-11L1, and 1D-11L2. This report
records the commencement ofwater-alternating-gas injection service.
If you have any questions regarding this matter, please contact myself at 659-7535.
Sincerely,
Robert D. Christensen
Attachments
~ hvs w ~`~\ ~ s c,~\~.G~ ~ dal IBC-?
~c9-s-~ `S~-'~ `i a~~cc~i~ ~ ~G.~S
~__-.--
~~'~~'p~~l~
•
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other
1 D EORX
Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^
Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ ~h~
2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 179-096
3. Address: Stratigraphic ^ Service ^~ - 6. API Number:
P. O. Box 100360, Anchora e, Alaska 99510 50-029-20418-00 .
7. KB Elevation (ft): 9. Well Name and Number:
RKB 105' 1 D-06
8. Property Designation: ~G ~~S•O ~ 10. Field/Pool(s):
ADL 2 5 /(• ~ °~ Kuparuk River Field /Kuparuk Oil Pool
11. Present Well Condition Summary:
Total Depth measured 8610' feet
true vertical 6911' feet Plugs (measured)
Effective Depth measured 8453 feet Junk (measured)
true vertical 6775 feet
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 80' 16" so' 80'
SURFACE 2869' 10-3/4" 2974' 2685'
PRODUCTION 8481' 7" 8586' 6890'
Perforation depth: Measured depth: 8042'-8130'; 8130'-8143'; 8311'-8329'
true vertical depth: 6419'-6495'; 6495'-6506'; 6651'-6667'
nd m
T
bi
i
d
th
d d
T~~ ~~r~~~
"
'
u
ng (s
ze, gra
e, a
easure
ep
) 3-1/2
, J-55, 7928
MD.
~
Packers &SSSV (type 8~ measured depth) Packers = Baker'HB', Baker'FHL' Packers = 7864', 7894' ~/
' ~ ~ 1~ I
SSSV = Camco TRDP-4A SSSV = 1938
12. Stimulation or cement squeeze summary:
Intervals treated (measured)
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure
Prior to well operation 3439 888 2187
Subsequent to operation 1549 513 1668
14. Attachments 15. Well Class after proposed work:
Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service^
Daily Report of Well Operations _X 16. Well Status after proposed work:
Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
N/A
contact Bob Christense /Vacant
Printed Name o rt D. __ ~ ensen Title Production Engineering Technician
Signature - Phone: 659-7535 Date I' ~ ~ 8~
Form 10-404 Revised 04/2004 Submit Origl~r~~4 /~
1 D-06
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
11/03/08 Commenced 1D EORX WAGIN In'ection
09/11 /08
07/10/06
PERFORATE FROM 8130' - 8143' USING 2.5" HSD 2506 PJ HMX GUN, 6 SPF, 60 DEG
PHASING.
1 D- 06, State witnessed (Jeff Jones}, 4-year MITIA -passed. Initial T/I/0= 1930/970/590,
Pressured up the IA to 2660 psi. Start MITIA T/I/0= 1950/2660/680, 15 min. reading T/I/0=
1950/2570/680, 30 min. reading T/IlO= 1955/2540/680
KU P
1 D-06
ConocoPhillips
well Attributes
Wellbore AP W WI
Field Name
Well Sbtua Iselin mtbn (°) MD (RK8)
Total Depth (RKB)
1
500292041800
KUPARUK RIVER UNIT
INJ 48.98 4,400.00
8,610.0
Comment
H2S (ppm) Date
Annotatlon End Dab KB13rd (R)
Rig Releua Date
SSSV: Locked Out
7/1/2008
Last WO: 8/11/1991 38.99
10/11/1980
Well -1 D-06 9/18(2008 11.51:10 AM
Schematic - Actual
M.
Annotation Depth (RK8) End Date Annotatlon
End Date
Last Tag: 8,327.0 8/25/2006 Rev Reason: TAG FILL, PERF
7/23/2008
Casing Strings
String String ID
Set Depth Set Depth (TVD) String Wt String
Casin Description
OD (In) (in) Top (RKB)
(RKB) (RKB) (Ibs/lt) Grade
String Top Thrd
111111
CONDUCTOR
16 15.063 0.0
80.0 80.0
SURFACE
103/4 9.766 0.0
—100H-40
2,974.0 2,684.9 45.50 K-55
CONDUCTOR,
PRODUCTION
1 71 6.151 0.0
8,586.0 6,890.2 26.00 K-55
so
Tubing Strings
String String Set Depth String Wt String
Tubing Description
OD (in) ID (In.) Top (RKB)
(RKB) Set Depth (TVD) (RK8) (lb./ft) Grade
String Top Th.
TUBING
3 112 2.9921 0.01
7,928.01 6,319.7 9.30 J-55
EUE-MOD
SSSV, 1,938
Other In Hole All Jewel : Tubing Run & Retrievable Fish etc.
Description
Comment
Run Date ID In
SSSV
SSSV: Locked Out
Camco TRDP-4A (locked out 6/25/2003)
8/11/1991 2.813
GAS LIFT
CAMCO/MMG-2/1.5/DW/RK///Comment: STA 1
8/18/1991 2.867
SURFACE,
PBR
F:.:
Bakerw/1V strokePBR
8/11/1991 3.000
2974
PACKER
Baker'HB'PACKER
8/11/1991 2.875
SBR
Baker SBR
8/11/1991 3.000
PACKER
Baker'FHU RETRIEVABLE PACKER
8/11/1991 2.891
7,913.0 NIPPLE
Csmco'D' Nipple NO GO
8/11/1991 2.750
GAS LIFT,
7,801
7,927.0 SOS
113.ke,
8/11/1991 2.992
7,928.0 TTL
ITTL ELMO @ 792T PER SWS IPROF 7/29/1999
8/11/1991 2.992
rforations
Shot
Top (TVD) St. (TVD)
Dens
T RKB Btm B
(RKB) (RKB) Type
Zone (sem- Dab
Comment
PBR, 7,850
8,042.0 8,130.0
6,418.5 6,495.0 IPERF
C-2, CJ, C-4, 4.0 619/1981
UNIT D, 1D-06
8,130.0 8,143.0
6,495.0 6,506.1 RPERF
UNIT B, 1D-06 6.0 9/1 MM 2.5" HSD 2506 PJ HMX GUN, 60
DEG PHASING
8,311.0 8,329.0
6.651.11 6,666.8 IPERF
A,5, 1 D-08 4.0 6/9/1981
L
PACKER, 7,864
S8R, 7 870
Lj
PACKER, 7891
NIPPLE, 7913
SOS, 7,927
TTL, 7 928
(PERF,
8,002.8,130-=
RPERF,
8,1308,143 -'
(PERF.-
8.311.8.329 A
PRODUCTION,
8 586
TO 8610
• STATE OF ALASKA
ALASKA OIL_AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS..
1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^
Alter Casing ^ Pull Tubing ^ Perforate New Pool ^• Waiver ^ Time Extension ^
Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^
2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number:
COnOCOPhllllp5 Alaska, InC. Development ^ Exploratory ^ 179-096 / "
3. Address: Stratigraphic ^ Service ^~ 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-029-20418-00
7. KB Elevation (ft): 9. Well Name and Number:
RKB 105' 1 D-06
8. Property Designation: `,!v ~
~~
~S 7 ~ 10. Field/Pool(s):
l
e+
ADL 2~ Kuparuk River Field /Kuparuk Oil Poo
.
11. Present Well Condition Summary:
Total Depth measured 8610' feet
true vertical 6911' feet Plugs (measured)
Effective Depth measured 8453' feet Junk (measured)
true vertical 6775' feet
Casing Length Size MD TVD Burst Collapse
Structural
CONDUCTOR 80' 16" 80' 80'
SURFACE 2869' 10-3/4" 2974' 2685'
PRODUCTION 8481' 7" 8586' 6890'
Perforation depth: Measured depth: 8042'-8130', 8130'- 143', 8311'-8329' s„~~~,r~#~y~,i ~~~ ~ ,~ ~ I/~~ ~
9
ti
~
•'
{"
y
m
`
ur C L.~ ~ ,.. ~:' 1~ ~ to
true vertical depth: 6419'-6495', 6495'- 6506', 6651'-6667'
Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7928' MD.
Packers &SSSV (type & measured depth) Baker'HB' pkr, Baker'FHL' retriev. Pkr @ 7864', 7894'
SSSV @ 1938'
12. Stimulation or cement squeeze summary:
Intervals treated (measured) not applicable
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure
Prior to well operation 2855
Subsequent to operation 3384 -
14. Attachments 15. Well Class after work:
Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service
Daily Report of Well Operations _X 16. Well Status after work:
Oil^ Gas^ WAG^~ GINJ^ WINJ ^ WDSPL^
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
none
Contact John Peirce @ 265-6471
Printed Name John Peirce Title Wells Engineer
Signature .___- Phone: 265-6471 Date ~",3G~ -C78
G ~ Pre a d b haron Allsu -Dra 263-4612
---__ ~ ~ase_~
~F~ U~,, ~ ~ 2~Dd
Form 10-404 Revised 04/2006 / ~ ~ ~'"R ~ ` Submit Original Only ~ 101
1 D-06 Well Work
DATE SUMMARY
9/6/08 TAGGED SOFT BOTTOM @~5' SLM, SAMPLE OBTAINED. IN •
PROGRESS.
9/7/08 ATTEMPT D. GUN DRIFT BUT SET DOWN IN SEVERAL PLACES.
BRUSH & FLUSH TBG W/ 40 BBLS DIESEL TO 7900' SLM. DRIFT TBG W/
16' OF 2.5" TO 8200' SLM.1300 LB PICKUP WEIGHTS. JOB COMPLETE.
9/11/08 PERFORATE FROM 8130' - 8143' USING 2.5" HSD 2506 PJ HMX GUN, 6
SPF, 60 DEG PHASING.
~ ,
-' KUP 1D-06
~fl1"'tOCt
?P~'tl~~t}?5 l ~ weu nttr~i}ates
.
j
I WNlbore APIIUWI Fieltl Name
~
Well Status -
InGll n t)
MD (RKB)
Total Depth tf[KB)
.. .
.. 500292041800
KUPARUK RIVER UNIT INJ _ 45.98
, 4,400.00 , 8,610.0
------------____-- Comment H2S (ppm) Date Annotation End Date K81Prd (R) Rig Release Date
~~'
~~ ~
~
~ .SSSV: Locked Out ... 0 711/2008 Last WO: I 8/1111991 38.99 10/11/1980
~~
~ ~ -4nnotation Depth (RKB) End Date Annotatlon (End Date
_ Last Tap: 8.327.0 8/25/2006 Rev Reason: TAG FILL. PERF I 7/2312008
Casing Strings
String String ID j Set Depth Set Depth (ND) String Wt String
_
.. Casitg Description ' OD (in) (in) ( Top (RKB) (RKB) (RKB) (Ibs/R) Gratle String Top Thrd
1 1
0 ~
~ ~ ' ~ 103/
CONDUCTOR,
~ F PRODUCTION
7 6.1
51 0.0 8586.0 68 0.2 26.00 K-
Tubin Strings _
1 Ong S tL~utt g J ~t.
Tubing Descrpt on C I I IC tin) Top (RKB( IttkE11 tict Depth (ND) IttK P.) III ttl Gr n trim ioy in,e
TUBING I _..?92 0.0 I =19' i 5 EIIo-MCID
sssv,ls3a Other En HOI® tAll Jewelry: Tubing RuP& RetnevabEeyFish, etc.)
lop (flt(B) fmscnption I Comment kun Date ID pn)
1,938.0 SSSV SSSV: Locked Out Camtb TRDP-4A (locked out 6125/2003) 8/11/1991 2.813
7,801.0 GAS LIF7 CAMCO/MMG2/1.S/DMYlRK/ll Comment: STA 1 8/18/1991 2.867
suRFACE,
] 7,850.0 PBR Baker wl l0'stroke PBR 8/11/1991 3.0001
z,9
4 7,864.0 PACKER Baker'HB' PACKER 8/11/1991 2.8751
7,870.0 SBR Baker SBR 8/1 7 11 99 1 ' 3.000.
7,894.0 PACKER Baker'FHL' RETRIEVABLE PACKER 811111991 1 2.891
7
913.0 NIPPLE Camco'D' Nipple NO GO &1111991 2.750
,
GAS LIFT,
7,801
. 7,927.0 SOS Baker SIt 111991 2.992
7,928.0 TTL TTL ELMD @ 7923' PER SWS IPROF 7Y1911999 SIt 1/1991 2.992
~ Perforat
_ ions
_ _
..
: Shoi
~
.
.
'~ Top (ND) Btm (TVD) Dens I
I
Top (RKB) ~ Comment
Btm (RKB) (RKB) (RKB) Type Zone ; lahoc.. Date
PBR, 7,850 $,042,0 8,130.0 1 6,418.5 6,495.0 (PERF C-2, C-3, C-4, ' 4.0 6/911981
' UNIT D, 1 D-06 I
I
5,130.0 8,143.0 6,495.0 6,506.1 RPERF UNIT B, 1D-06 6.0 9I11Y2008 2.5" HSD 2506 PJ HMX GUN, 60
DEG PHASING
8,311.0 8,329.0 6,651.1 6,666.8 (PERF A-5, 1D-O6 4.01 6/9/1981
PACKER, 7,881
SBR, ],870
PACKER, 7,894
NIPPLE. 7.913
503.7,947 }.
L
TTL, 7,928 {
IPERF,
8,0424,130
RPERF,
8,1308,10.1
(PERF,
8,3114,329
PRODUCTION,
8,588
TD, 8,810
RECEiVED
09/11/06
SEP 1 2 2006
Scblumbel'ger
~~/",Ift.'i\'1i:::1fì CEt: ~ c 2r:n\.
~W'U¡:nC,¡¡jl!#,J 1# 1 ~! . ¡Jt.C
NO. 3955~ Oil & Gas Cons. Commission
Anchorage
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
~J .:r-ZL l--:ri - 0 C? (:,
Field: Kuparuk
Well
Log Description
Color
CD
Date
BL
Job#
2M-35 11213795 LDL 08/16/06 1
1 Y -24A 11213786 SBHP 07/25/06 1
2X-12A 11249946 PROD PROFILE W/DEFT 08/25/06 1
1 D-06 11249948 INJECTION PROFILE 08/26/06 1
1A-10 11216318 INJECTION PROFILE 08/28/06 1
1J-184 11249951 PRODUCTION PROFILE 08/29/06 1
1 J-127 11249953 PRODUCTION PROFILE 08/31/06 1
1J-170 11249954 PRODUCTION PROFILE 09/01/06 1
1G-04 11216321 INJECTION PROFILE 08/31/06 1
1 D-12 11216322 PRODUCTION PROFILE 09/01/06 1
2F-06 11216320 FLOWING BHP SURVEY 08/30/06 1
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
.
.
MEMORANDUM
e
State of Alaska e
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg
P.I. Supervisor
~ /} rl__ ,l...."
.' '1 i'-. ,(j~-
\:....i''Í'í ,,~-'! u
{{ l
DATE: Wednesday, July 12,2006
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
ID-06
KUPARUK RIV UNIT ID-06
111 ' ocrb
FROM:
Jeff Jones
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Suprv '1f':?-
Comm
NON-CONFIDENTIAL
Well Name: KUPARUK RIV UNIT 10-06 API Well Number 50-029-20418-00-00 Inspector Name: Jeff Jones
Insp Num: mitlJ060711181643 Permit Number: 179-096-0 Inspection Date: 7110/2006
Rei Insp Num
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well ! ID-06 ¡Type Inj. I W J TVD 6265 IA i 970 2660 2570 2540 I
I
P.T. I 1790960 ¡TypeTest ! SPT Test psi 1566.25 lOA i 590 680 680 680 -¡-
, ! --
Interval 4YRTST P/F P \-/'/ Tubing! 1930 1950 1950 1955
Notes 5.6 bbls diesel pumped. 1 well house inspected; no exceptions noted.
Wednesday, July 12,2006
Page 1 of 1
....'",'.,. e
. COl'locoPhilllps Alaska, Il'Ic,
-
KRU
1 D-06
1 D.o6 ... ... ..
TUBING ": API: 500292041800 Well Tvpe: INJ Angle @ TS: 30 deg @ 8043
(0-7928, ;: , SSSV Tvpe: TRDP Orig Completion: 10/11/1980 Angle cæ TD: 30 deg cæ 8610
00:3.500, '. Annular Fluid: Last W/O: 8/11/1991 Rev Reason: TAG FILL
10:2.992) , Reference Log: Ref Log Date: Last Update: 9/18/2004
SURFACE : Last T aa: 8388 TD: 8610 ftKB
(0'2974, ~ :- Last Taa Date: 6/25/2003 Max Hole Anale: 49 dea @ 4400
00:10.750,
Wt:45.50) ~ Casl"aStrina - ALL STR.INGS . ...
, . Description Size Top Bottom TVD Wt Grade Thread
, CONDUCTOR 16.000 0 80 80 65.00 H-4Q
. ¿ SURFACE 10.750 0 2974 2685 45.50 K-55
Gas Lift PRODUCTION 7.000 0 8586 6890 26,00 K-55
1drel/Oummy ~
Valve 1 Tubil1aStrillCl- TUBING ". '. ... .... .,..... ......
(7801-7802, Size I Top I Bottom I TVD I Wt I Grade I Thread
OD:5750) '. 3.500 I 0 I 7928 I 6320 I 9.30 1 J-55 I EUE-MOD
PerfonJtions. Surl'lIriarv. .. ....
.: Interval TVD Zone Status Ft SPF Date Type Comment
~
8042 - 8130 6418 - 6495 UNIT 88 4
,C-4,C-3,C-
ROOUCTION ~ .------- 8311 - 8329 6651 - 6667 A-5 18 4
(0-8586. Gas. Lift MandrêlsNalvês .. .. .... .. .....
OD:7.000, St I MD I TVD I Man Man Type I VMfr I V Type V OD I Latch I Port I TRO I Date Vlv
wt:26.00) '.
=----- Mfr Run Cmnt
~ 1 I 78011 6210 I Camco I MMG-2 I I DMY 1.5 1 RK I 0.000 I 0 18/18/1991
: Other tl luas,. e:IuÎp.,etc.l-JEWELR.Y .... .. .... < .....
..... ....
PKR ,. Decth TVD Tvce Descriction ID
(7864-7865, 1938 1897 SSSV Cameo TRDP-4A 2.813
00:6.156) 7850 6253 PBR Baker w/1 0' stroke 3.000
~ 7864 6265 PKR Baker 'HB' 2,875
~ 7870 6270 SBR Baker 3.000
~ :. 7894 6290 PKR Baker 'FHL' RETR, 2.891
:: 7913 6307 NIP Cameo 'D' Nipple NO GO 2.750
~ 7927 6319 SOS Baker 2.992
.' 7928 6320 m 2.992
SBR FE
(7870-7871,
00:3.500) ~
:: -=--- ,
<
< .....
PKR
(7894-7895,
00:6.156)
~ ...
,
NIP
(7913-7914, , U ~
00:3.500)
,
.'
50S
(7927-7928, ~ ,
00:3.500)
TTL ,
,
(7928-7930, < ~
OD:3.500) .:
Perf -~ -
(8042-ß 130) - -
- '.-
- :'-
-~ -
-~ ~-
-.' ~-
-: -
Perf -~ '.-
(8311-8329) - I--
-'. ~f---
~
-': .1--
-. :1--
--~ ::
-:; ~I--
,
MEMORANDUM
TO: Randy Ruedrich
Chair
THRU: Jim Regg
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: June 20, 2003
SUBJECT: Mechanical Integrity Tests
ConocoPhillips Alaska Inc.
P.I. Supervisor , ' ) 06, 09, 106, 109, 111
FROM: John H. Spaulding ! Kuparuk River Unit
Petroleum Inspector Kuparuk River Field
NON- CONFIDENTIAL
Well
P.T.D.
Notes:
P.T.D.
Notes:
Well
P.T.D.
Notes:
Well
P.T.D.
Notes:
Well
P.T.D.
Notes:
1 D-06
1790960
Packer Depth Pretest Initial 15 Min. 30 Min.
Type lnj.I S I T.V.D. 16265 I Tubingl~e~ 1~790 11790 1179O I Inte al 4
TypetestI P ITestpsil 1566 I CasingI 1360I 2500 I 2500I 2490I P/F I P
1980650ITypetestl P I Testpsil 1538 ICasingI 390 I 2535 I 2520 I 25101 P/F I P
1972400ITypetestl P ITestpsil 908 I Casingl 460 I 2620 I 2620 I 26101 P/F I P
1972350 I Type test] P I Test psiI 888 I Casingl POS. I 25501 25501 25501 P/F I P
1D-111 I Type Inj.
1981660 I Type test
Type INJ. Fluid Codes
F = FRESH WATER INJ.
G = GAS I NJ.
S = SALT WATER I NJ.
N = NOT INJECTING
Type Test
M= Annulus Monitoring
P= Standard Pressure Test
R= Internal Radioactive Tracer Survey
A= Temperature Anomaly Survey
D= Differential Temperature Test
Test's Details
Interval
I= Initial Test
4= Four Year Cycle
V= Required by Variance
W= Test during Workover
O= Other (describe in notes)
.l~had a positive pressure (basically 0 psi) when checked prior to rig up of the pump. The IA was pressured up to
2500 psi as noted and innnediately started to bleed down. After 15 min. pressure was at 400 psi. Ultimately the IA went
clear to 0 psi on the guage. As I was checking the IA the last time I noticed that diesel was coming up through the
the hanger flutes. Approxiamtely 5 gals. over flowed into the cellar area. This was cleaned up. I contacted Tom
Maunder and he suggested that the well be shut-in until CPAI offered a repair program to the AOGCC. Jerry Dethlefs
Dethlefs CPAI rep. concurred with the shut-in advice.
M.I.T.'s performed: 5 Number of Failures: 1_
Attachments:
Total Time during tests:. 3 hours
CC:
MIT report form
5/12/00 L.G.
CANNED 0 &- 2003
mit kru ld 6-20-03 js 1 .xls
7/17/2003
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Operations perfOrmed* Operatmn shutdown_ Stimulate _ Plugging_ Perk)rate_
Pull tubing ~ AEer casing~ Repair well _ Other _X Gl to WAG ~;_ _mcaon
2 Name of Operator
Phdhps Alaska, Inc.
3 Address
P. O. Box 100360
Anchorage, AK 99510-0360
4 Locabon of well at surface
359' FNL, 601' FEL, Sec. 23, T11N, R10E, UM
5 Type of Well
Development _
Exploratory _
Strat~graph~c _
Sennce_X
(asp's 560489, 5959304)
6 Datum elevabon (DF or KB feet)
RKB 105 feet
7 Umt or Property name
Kuparuk Umt
8 Well number
1 D-06
At top of producbve ~nterval
1087' FSL, 1323' FWL, Sec. 24, T11N, R10E, UM
At effecbve depth
At total depth
4460' FNL, 3879' FEL, Sec. 24, T11N, R10E, UM
(asp's 562525, 5955220)
9 Permit number / approval number
179-096 /
10 APl number
50-029-20418
11 F~eld / Pool
Kuparuk Oil Pool
12 Present well cond~bon summary
Total depth measured
true verbcal
Effecbve depth measured
true verbcal
Casing Length Size
CONDUCTOR 80' 16"
SURFACE 2869' 10-3/4"
PRODUCTION 8481' 7"
8610 feet Plugs (measured)
6911 feet
feet Junk (measured)
feet
Cemented
200 sx Perm C
1600 sx Fondu & 250 sx AS II
306 sx Class G & 185 sx Tad In
Measured Depth
80'
2974'
8586'
True vertical Depth
80'
2685'
6890'
Perforabon depth
measured 8042-8130; 8311-8329
true verbca164t9-6495; 6651-6667
Tubing (s~ze, grade, and measured depth) 3-1/2", 9,3#, J-55 'l'bg @ 7928' MD.
Packers & SSSV (type & measured depth) BAKER 'HB' ~ 7864' MD; BAKER"I=HL' RETR @ 7894' MD;
CAMCO TRDP-4A @ t 9;38' MD..
RECEIVED
NOV
13 Sbmulabon or cement squeeze summary
Intervals treated (measured) N/A
Treatment descnpbon ~nclud~ng volumes used and final pressure
14
Prior to well operabon
Subsequent to operation
Od-Bbl
Representabve Dady Average Producbon or Inlecbon Data
Gas-Md Water-Bbl
15313
Casing Pressure Tubing Pressure
1750 4~.50
1443 1750 950
15 Attachments
Cop~es of Logs and Surveys run __
Dady Report of Well Operabons ___X
Gas __ Suspended __
Service _X WAG Injedaon
17 I hereby cerbfy that the foregoing ~s true and correct to the best of my knowledge
S~gned ~ Title Productmn Engmeenng Supervmor
Jeff A Spen~r
Questions? Call Jeff Spencer 659-7226
Date /~////'~-~'J~ /
Prepared by Robert Chnstensen 659-7535
Form 10-404 Rev 06/15/88 ·
ORIGINAL
SUBMIT IN DUPLICATE
1 D-06 (~
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date
Event Summary
5/3/991Commenced EOR Injection
!
I
OPERATOR: ARCO Alaska Inc..
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechani~al Integrity Test
FIELD l UNIT t PAD: K~F, KRU,
NOV 0 8 995
~)il & Gas Cons. Commissio~
, ~chorage
DATE: ! I/6/9.5
COMMEN~ WI~'ESS ~D
COMMENTS WITNESS ~D
C~ENT~ ~NESS ~O
3~13 1 ~ 11 I' D/E~ 'I7.3=~'2~ I 7,2~,~ I 2.a75 I ~ t'2'~3,~ ~ 2,9~ 2~5~ I 2.~'2,575 I2'9~2,5~ I 1~ P~I
COMMENTS:
COMMEN~:
'TU~ING INJECTION FLUID: ANNULAR FLUID: P.P.G. G tad. WELL TEST:
P = PRODUCED WATER INJ. DIESEL ~. ~ ~,.36 Inilie~
S = SALT WATER 1NJ GLYCOL I &'. 0 O 4 - Yen;'
M = M)SCIBLE INJ. SALTWA'i'ER ] o. oo woe, er
I = INJECTION DRILLING MUD I O. 00 Other
N = NOT INJECTING OTHER I 0. 0 0
AOGCC REP SIGNATURE
OPERATOR REP SIGNATURE
WVD eY J HERRING
ERICL. ZUSPAN
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION ~ISSION
REPORT OF SUNDRY WELL OP£R TION
16 IN
1. Operations performed:
Pull tubing
2. Name of Operator
ARCO Alaska. Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510
Operation Shutdown
Alter casing
5. Type of Well:
Development
Exploratory
IStratigraphic
4. Location of well at surface
363' FNL, 600' FEL, Sec. 23, T11N, R10E, UM
At top of productive interval
1087' FSL, 1323' FWL, Sec. 24, T11N, R10E, UM
At effective depth
916' FSL, 1374; FWL, Sec. 24, T11N, R10E, UM
At total depth
816' FSL, 1402' FWL, Sec. 24, T11N~ R10E~ UM
12. Present well condition summary
Total Depth: measured 861 0°
true vertical 6 6 91 1'
Stimulate m Plugging Perforate
Repair well Other ~
6. Datum elevation (DF or KB)
feet
feet
105' RKB feet
7. Unit or Property name
Kuparuk River Unit
8. Well number
1D-06
9. Permit number/approval number
79-§6/#261
10. APl number
50-029-20418
11. Field/Pool
Kuparuk River Oil Pool
Plugs (measured) None
Effective depth: measured 8453' feet
true vertical 6775' feet
Junk (measured) None
Casing Length
Structural 8 0'
Conductor
Surface 2 9 74'
Intermediate
Production 85 8 6'
Liner
Perforation depth: measured
Size Cemented
1 6" 200 Sx Perm C
1 0-3/4" 1600 sx Fondu
250 sx AS II
7" 306 sx Class G
185 sx Tail
8311'-8329', 8042'-8130'
Measured depth True vertical depth
80' md 80' tvd
2974' md 2685' tvd
8586' md 6890' tvd
RECEIVED
true vertical 6651°-6667', 6418'-6495'
Tubing (size, grade, and measured depth)
3 1/2", 9.3#, J-55 @ 7928'
Packers and SSSV (type and measured depth)
Baker 'FHL' ~ 7894', Camco 'TRDP-4A' ~ 1938'
13. Stimulation or cement squeeze summary
0c'r 2 5 1991
Gas Cons. C0m~ss'ton
Intervals treated (measured)
Treatment description including volumes used and final pressure
14.
Represerltative Daily Average Production or Iniection Data
OiI-Bbl Gas-Md Water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation
Subsequent to operation
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations
16. Status of well classification as:
Water Injector m
Oil 'I{. Gas Suspended
17. I h_.~ereby certify tha~foregoing is true and correct to the best of my knowledge.
~~~~~~ ~ ~l~~ineer
Form h- ev
Date
SUBMIT IN DUPLICATE
ARCO ALASKA INC.
DAILY OPERATIONS
PAGE: 1
WELL: 1D-06
BOROUGH: NORTH SLOPE
UNIT: KUPARUK RIVERUNIT
FIELD: KUPARUK RIVER FIELD
LEASE: ADL 25650
API: 50-029-20418
PERMIT 79-96
APPROVAL: Conservation Order No. 261
ACCEPT RIG: 08/07/91 01:00
RELEASE RIG: 08/12/91 05:00
OPERATION: WORKOVER
RIG: NORDIC 1
AFE: AK6187
WI: 55.252072
08/07/91 (1)
TD: 0
PB: 8453
SUPV:GB/DS
08/08/91 (2)
TD: 0
PB: 8453
SUPV:DB/SW
08/09/91 (3)
TD: 0
PB: 8453
SUPV:DB/SW
08/10/91 (4)
TD: 0
PB: 8453
SUPV:DB/SW
PULLING DV F/GLM @ 7811' MW: 7.0 Diesel
MIRU NORDIC 1,RU HARD LINE,PULL BPV, RU CIRC LINES,TEST CHOKE
LINE TO 2000 PSI, BLEED DOWN ANNULUS F/650 PSI TO 200 PSI
SITP=0,RU OTIS SLICKLINE,RIH ATTEMPT TO PULL DV F/GLM @
7811',COULD NOT LATCH DV, POH, RIH W/LIB
DAILY:S59,128 CUM:$59,128 ETD:S59,128 EFC:$350,000
RIH W/2.80"GR ON SLICKLINE MW: 0.0 Seawater
BLEED OFF ANN GAS,POH W/LIB,RIH W/OK-5 TOOL TO RETR. DV, POH
W/O DV, RIH W/OK-1 TO RETR DV, POH W/DV, STD BK OTIS SLICKLINE
CIRC HOLE VOL W/SEA WATER DN TBG, RU OTIS SLICKLINE,RIH EQLZ
A-2 PLUG @ 7891',POH W/PRESS RELIEF TOOL, RIH W/RETR TOOL, POH
W/A-2 PLUG, RD OTIS SLICKLINE, SITP=1535 PSI/SICP=1250 PSI
INJECT 22 BBLS SEAWATER DN TBG @ 3 BPM/1850 PSI,SHUT IN WELL
SITP=1490 PSI/SICP=1350 PSI REV CIRC 38 BBLS DN ANN, RETURNS
TO PITS,CIRC DN TBG @ 2.5 BPM/1700 PSI W/SEA WATER, SITP=1400
PSI,BRING IN THIXSAL @ 12.4 PPG,WT UP TO 13.0+ PPG
SITP=1500 PSI/SICP=1250 PSI,PUMP 9 BBL OF SATURATED NACL W/3
PPB XC POLYMER SWEEP,TAKE KICK IN ANN, SI WELL, RU OTIS
SLICKLINE,TEST LUBR. TO 2700 PSI,RIH TO SET A-2 PLUG @ 7891'
TOOL STOPPED @ 2416' WLM, POH TO GET GR
DAILY:S28,147 CUM:$87,275 ETD:S87,275 EFC:$350,000
POH W/COMPLETION MW:13.1 THXL
RIH W/2.805" GR, OBSTRUCTION MOVED DOWNHOLE W/GR, INJECT 50
BBL SEAWATER DN TBG @ 2.2 BPM/2425 PSI,CONT RIH W/GR TO
7911'WLM, POH W/GR, RIH W/A2 PLUG, SET PLUG IN D NIPPLE,POH
SITP 1600 PSI/SICP 2750 PSI,BLEED OFF ANN & TBG, SITP 700
PSI/ SICP 1000 PSI,CIRC OUT GAS W/SEAWATER @ 3 BPM/1500 PSI
PUMPING DN TBG, RIH & RETRIEVE A2 PLUG, RD SLICKLINE, INJECT 40
BBL SEAWATER DN TBG @ 3.3 BPM/2050 PSI SITP 1350 PSI/SICP
1275 PSI,CIRC 39 BBL 9.9 PPG NACL BRINE @ 3 BPM/1050 PSI,
FOLLOW W/59 BBL THIXSAL, INJECT 31 BBL, SICP 1350 PSI,SITP 0
PSI,CIRC 13.1 PPG THIXSAL @ 3 BPM/6-700 PSI,BRING IN AND WT
UP THIXSAL TO 13 PPG, CONT CIRC THIX- SAL @ 2 BPM/1000 PSI
THIXSAL TO SURFACE,LOST 47 BBL, SET BPV, ND TREE/NU BOPE, PULL
BPV, INSTALL 2-WAY CHECK, TEST BOPE TO 3500 PSI,MU LANDING JT
TEST ANNULAR TO 3000 PSI,PULL/SHEAR BAKER EXPANDA JT,POH
W/COMPLETION
DAILY:S82,839 CUM:$170,114 ETD:S170,114 EFC:$350,000
CBU MW:13.1 THXL
PREP. CIRC HOLE,CIRC 212 BBL @ 1 BPM/700 PSI,PULL ONE STD
WET,CONT CIRC, PUMP DRY JOB, POH 31 STD, LD SSSV, RIH W/31 STD
MU/SET RTTS 2' BELOW TBG SPOOL, TEST RTTS,ND BOP,NU CAMERON
11" 3K X 7 1/16" 5K TBG SPOOL,NU BOP,SET TEST PLUG, TEST BOP
FLANGE/CHOKE AND KILL LINES TO 3500 PSI,PULL TEST PLUG
RELEASE RTTS,POH W/ SAME,CIRC DN TBG @ 1 BPM/700 PSI
DAILY:S34,352 CUM:$204,466 ETD:S204,466 EFC:$350,000
RECEIV£D
OCT 2 5 1991
Alaska Oil a Gas Cons. Comm'tss't_m
Anchorage
WELL: 1D-06
OPERATION: WORKOVER
RIG: NORDIC 1
PAGE: 2
08/11/91 (5)
TD: 0
PB: 8453
SUPV:DB/SW
08/12/91 (6)
TD: 0
PB: 8453
SUPV:DB/SW
LAND 3-1/2" COMPLETION MW:13.3 THXL
CIRC DN TBG @ 1BPM/750 PSI,POH W/3 1/2" TBG, REDRESS EXPANDA
JT,RIH W/EXPANDA JT,PKR, JT TBG, GLM W/PUPS, 194 JTS TBG, SSSV
W/PUPS, 61 JTS TBG, SPACE OUT AND VERIFY POSITION, LAND TBG
RIG RELEASE-MOVE TO 2A-16 MW:13.3 THXL
SPACE OUT/VERIFY POSITION, LAND TBG, RU OTIS SLICKLINE,TEST
LUB. 2500 PSI,RIH W/ STANDING VALVE TO D NIPPLE,UNABLE TO
SHEAR OFF DUE TO THIXSAL, SET BKR HB PKR W/2500 PSI ON
TBG/1000 PSI ON ANN, TEST CSG W/1000 PSI,LOST 30 PSI/15 MIN
POH W/STANDING VALVE, RD SLICKLINE, SHEAR PBR W/89K# PULL, SET
BPV,ND BOPE,NU TREE, TEST TREE TO 5000 PSI,RU TO DISPLACE
WELL, REV CIRC WELL W/62 BBL 10.0 PPG NACL SWEEP FOLLOWED BY
DIESEL AT 1 BPM, LOST 118 BBLS,TEST SSSV, S/I WELL, SITP=2100
SICP=2250 PSI,BLOW DN LINES,SET BPV, RIG RELEASED @ 0500 HR
8/12/91,MOVE TO 2A-16
DAILY:S20,607 CUM:$268,157 ETD:S268,157 EFC:$350,000
DATE:
~ ~OILANDGAS~RVATION~IV~ DN D RIG IN A L
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon _
Alter casing _
Change approved program _ Pull tubing X
2. Name of Operator 5. Type of Well:
Development _
Exploratory _
Stratigraphic _
Suspend _ Operation Shutdown _ Re-enter suspended well _
Repair well X Plugging _ Time extension _ Stimulate _
Variance PeHorate Other
6. Datum elevation (DF or KB)
ARCO Alaska. Inc.
3, Address
P. O. Box 100360, Anchorage, AK 99510
4. Location of well at surface
363' FNL, 600' FEL, Sec. 23, T11N, R10E, UM
At top of productive interval
1087' FSL, 1323' FWL, Sec. 24, T11N, R10E, UM
At effective depth
916' FSL, 1374; FWL, Sec. 24, T11N, R10E, UM
At total depth
816' FSLr 1402' FWL~ Sec. 24r T11Nr R10E~ UM
12. Present well condition summary
Total Depth: measured 8 61 0' feet
true vertical 6 91 1 ' feet
Effective depth: measured 8 4 5 3' feet
true vertical 6 7 7 5' feet
Plugs (measure"
?
Junk (mea?~'red)
Casing Length Size
Structural
Conductor 8 0' 1 6"
Surface 2974' I 0-3/4"
Intermediate
Production 8 5 8 6' 7"
Liner
Perforation depth: measured
8311'-8329', 8042'-81 30'
Cemented
RKB 105'
7. Unit or Property name
Kuparuk River Unit
feet
8. Well number
1D-06
9. Permit number
79-96
10. APl number
I 50-029-20418 ~
11. F~ .~'Ku~paruk River~=ield
K~aruk River Oil Pool ~
Measured depth True vertical depth
200 Sx Perm C 8 0' 8 0'
1600 Sx Fondu & 2974' 2685'
250 Sx AS II
306 Sx Class G 8586' 6890'
185 Sx Tail In
RECEIVED
true vertical
6651'-6667', 6418'-6495'
Tubing (size, grade, and measured depth
3 1/2" J-55 set at 7905'
Packers and SSSV (type and measured depth)
Baker 'FHL' ~ 7872'~ Camco WRDP ~ 1921'
13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch _
J U L 1 1991
Alaska Oil & Gas Cons. Oommiss~o[~
Anchorage
Repair seals in wellhead and rerun completion with additional packer to isolate suspected packer leak.
14. Estimated date for commencing operation 15. Status of well classification as:
August 2. 1~)~)1 Oil __ Gas __ Suspended __
16. If proposal was verbally approved
Name of approver Date approved Service Gas Iniector
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed ~f'~//~ ~ Title: Area Drilling Engineer
/ FOR COMMISSION USE ONLY
Date
Conditions of approval: Notify Commission so representative may witness
Plug integrity _ BOP Test
Mechanical Integrity Test ,~.
.Approved by the order of the Commission
Form 10-403 Rev 06/15/88
Original Signed By
David W. Johnston
Location clearance
Subsequent form require
Approved Copy
IApprova_l No.
Commissioner
SUBMIT iN YF~IP~'~CATE
KRU 1D-06 Workovor
General Procedure
Pre-rig work
1. Install plug in 'D' nipple. Ensure dummy valve is in GLM.
2. Bleed off tubing and annulus pressure.
3. Install BPV.
Rig work
1. MIRU Nordic #1.
2. Pull BPV. Pull dummy valve in GLM. Circulate well to water.
3. Pull plug from 'D' nipple and monitor SITP.
.
Displace well to mud. MW based on SITP and 100 psi
overbalance. Set BPV.
5. ND tree and NU BOP stack. Pull BPV.
6. POH w/completion to SSSV and LD same.
7. PU storm packer and set just below wellhead.
8. ND BOP's and replace 7" packoff.
9,
10.
11.
NU BOP's and test same. Pull storm packer. ]~ ~Cf ] V~D
Cont. pull existing completion and stand back.
Rerun 3-1/2" single completion inspecting tubing ~eo~lfI~cons. Cornrnissio~
Replace couplings or joints as necessary. Run new tubingAnehoraoo
hanger, SCSSSV, SBR, and additional packer, PBR.
12. Land tbg hgr, set test plug, ND BOP's. Install and test tree.
13. Displace well leaving tubing full of water and annulus full of
clean diesel.
14. RD and MO WOR. WLM 7-20-91
/
/
Drill Site
lA
Wel 1 No.
~ 1A-4
"~1A-5
X°lA_7
~lA-9
~1A-11
'~1A-12
'~1A-14
'~ 1A-15
'~lA-16A
ATTACHMENT II
KUPARUK RIVER UNIT
Production Logs
Log Date
7/6/83
10/29/83
2/8/8 X
5/7/82/
1/25/82-~'--
3/23/83 /
1/19/83"7
3/21/83/
3/8/82
4/1/82
615/82
511118Lx,,,
Drill Site
18
Wel 1 No. Log Date
__
""18-1 12/26/81
~18-2 6/25/81
'~18-3 11/16-18/81"-7
'~ 3/12/82/
~18-6 11/18/81k,
"~ 9/10/82/ ~
~18-7 ' 11/23/81
~'18-8 12/28/81",~
"~ 8~4~82/
~IB-g ~ 6/24/82,..,7~'
~ 8/3/84"
Drill Site Well No. Log Date
5/9/8'1
5/8/81
7/13/81
~]/8/8~->
3/9/81/
2/26/81
11/30/81
5/19/81
5/21/81
Drill Site
10
Well No. Log Date
' ~"10-1 1/80'~> ~
~ 5/23/83/
'"~1D-3 8/5/80
10-4 ~7/30/80'x~ ~
~ 8/13/80/
~10-~ 6/11/81
~10-6 6/9/81 .-.
~10-7 6/8/81
%JlD-8 (WS-8) 5/10/78 -
.o
KUPARUK £NGINEER~NG (
Well Name:
DISTRIBUTION
I~D
D&M
Stat~-of Alaska
B. Adams
Union (Lambert)
Sohio (Burwas~)
Mobil
Chevron
Phillips
Sign &.ret~rr~he a~
Alaska Oil & Gas Cons. Commission
Anchorage
fi/turn to: ARCO ALASKA, INC.
ATTN: P,q~,~ m WF..TI'~
ATO-1115B
P.0. Box 100360
Anchorage, AK 99510
PBU
3/15/84
ARCO Alaska, In<
Post Office :,ox 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
March 16 , 1984
Mr. C. V. Chatterton
State of Alaska
Oil and Gas Conservation
3001 Porcupine Drive
Anchorage, AK 99501
Dear Mr. Chatterton:
Commission
Attached in duplicate
following wells at the
Well Action
~D-6 Acidize
1Y-2 Acidize
If you have
any questions,
are subsequent notices on the
Kuparuk River Field:
Date Performed
1/25/84
2/19/84
please call me at 263-4253.
Mike L. Laue
Kuparuk Operations
Coord i nator
MLL/kmc
Attachment (Duplicate)
LiAR 1 ',3 i984
Al:~ska 0il & Gas Cons. Commission
Ae]herage
ARCO Alaska, Inc is a Subsidiary of Atlant,cR~chfleldCompany
(" STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION MMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1 DRILLING WELL []
COMPLETED WE LL)(3
2 Name of Operator
ARCO ALASKA, INC.
3 Address
P. O. BOX 360, ANCHORAGE, ALASKA 90510
OTHER []
7 Permit No
79-96
8. APl Number
50- 029-20418
9 Umt or Lease Name
KUPARUK RIVER UNIT
10 Well Number
1D-6
11 F~eld and Pool
KUPARUK RIVER FIELD
4 Location of Well
SURFACE LOCATION' 363' FNL, 600' FEL, Sec. 23,
T11N, R10E, UH
5 Elevation ~n feet (ind~cate KB, DF, etc )
101' (RKB) Pad 80'
12
6 Lease Designation and Serml No KUPARUK R I VER 0 ! L
ADL 25645. ALK 2576 POOl
Check Approprmte Box To Indicate Nature of Notme, Report, or Other Data
NOTICE OF INTENTION TO SUBSEQUENT REPORT OF
(Submit m Tr~phcate) (Submit m Duplicate)
Perforate [] Alter Casing [] Perforations [] Altering Casing []
Stimulate [] Abandon [] Stimulation [] Abandonment []
Repair Well [] Change Plans [] Repairs Made [] Other []
Pull Tubing [] Other [] Pulling Tubing []
(Note Report multIple completions on Form 10-407 w~th a submitted Form 10-407 for each completion )
13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any
proposed work, for Abandonment see 20 AAC 25 105-170)
On 1-25-84 performed acid job in an attempt to clean up gas injection
well 1D-6. Tested all lines to 4000 psi. Pumped 3500 gallons 12% HCL at
1½ BPM and 3300 psig. Acid job gas injection rate is about 20 MMCF/day
versus 18.6 MMCF/day before acid job.
, ;
~,laska 0il & Gas O,~ns. Oommission
14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge
The space below for CommIssion use 0 P E R AT I 0 N S
COORDINATOR
Date
Conditions of Approval, if any
By Order of
Approved by COMMISSIONER the Commission
Form 10-403
Rev 7-1-80
Submit "Intentions" ~n Triplicate
and "Subsequent Reports" ~n Duplicate
ARCO Alaska, Inc~r
Post Office'u,.,,, 360
Anchorage, Alaska 99510
Telephone 907 277 5637
January 24, 1984
Mr. C. V. Chatterton
State of Alaska
Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
Dear Mr. Chatterton:
Attached is a notice of intention regarding
of Kuparuk gas injection well 1D-6.
If you have any questions, please call me at
acid treatment
263-4527.
Charles K. House
Kuparuk Operations Coordinator
CKH/kmc
Attachment (In Triplicate)
ARCO Alaska, Inc Js a subsidiary of AtlantJcR~chfleldCompany
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATIONCDMMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
I DRILLING WELL []
COMPLETED WELL
OTHER
2 Name of Operator 7 Permit No
ARCO ALASKA, [NC. 79-96
3 Address 8 APl Number
P. O. BOX 360, ANCHORAGE, ALASKA 99510 5o- 029-20418
4 Location of Well
SURFACE LOCATION' 363' FNL, 600' FEL, Sec. 23,
T11N, R10E, UH
5 Elevation ~n feet (~ndlcate KB, DF, etc )
101' (RKB) Pad 80'
6 Lease Designation and Serial No
ADL 25645, ALK 2576
12
9 Unit or Lease Name
KUPARUK RIVER UNIT
10 Well Number
1D-6
11 F~eld and Pool
KUPARUK RIVER FIELD
KUPARUK RIVER OIL
POOL
Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data
NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF'
(Submit m Triplicate) (Submit ~n Duplicate)
Perforate [] Alter Casing [] Perforations [] Altering Casing
Stimulate [] Abandon [] Stimulation [] Abandonment
Repair Well [] Change Plans [] Repairs Made [] Other
Pull Tubing [] Other )(] Pulhng Tubing []
(Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion )
13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25 105-170)
An acid treatment is proposed to cleanup Kuparuk gas injection we]l 1D-6.
The treatment wi]] incorporate use of a coiled tubing unit and nitrogen
to aid the clean up. Acid wi]] be 3200 ga]ions of 12% HCL.
Expected Start Date' 1-23-84
(Verbal approval received from L. C. Smith 1/23/84.)
Subsequent Work Reported
on Form No. ~ Dated
14 I hereby certify.that the f~rego~ng ~s tr.ue and correct to the best of my knowledge
v OPERATIONS
The space below for Commission use
COORDINATOR
Date
Conditions of Approval, ~f any
Approved by ~ L[~I[ ~' ~il~_~ COMMISSIONER
Al~oved Copy
Returned
By Order of .....
the Commission
Date
Form 10-403
Rev 7-1-80
Submit "lntent,ons" ~n Triplicate
and "Subsequent Reports" ~r3 Duphcate
ARCO Alaska, Inc.'~j""
Post Office Box 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
January 3, 1984
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 1D-6
Dear Mr. Chatterton:
Enclosed is a Subsequent Sundry Report for the subject well.
you have any questions,~please call me at 263-4944.
Sincerely,
. Gruber
Associate Engineer
JG/GRU5L95:tw
Enclosure
If
ARCO Alaska, Inc ~s a Submd~ary of AtlanhcRichfieldCompany
STATE Of ALASKA
ALASKA ,~ AND GAS CONSERVATION CO( .VllSSION
SUNDRY NOTICES AND REPORTS ON WELLS
1 DRILLING WELL []
COMPLETED WELL E~X
OTHER I-] ~
2 Name of Operator 7 Permit No ARCO Alaska, Inc. 79-96
3 Address 8 APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-20~18 /
4 Location of Well
Surface: 363' FNL,
600' FEL, Sec.23, T11N, R10E, UM
5 Elevation ~n feet (md~cate KB, DF, etc )
12
101' RKB
Lease Designation and Serial No
ADL 256~5 ALK 2576
9 Unit or Lease Name
Kuparuk River Unit
10 Well Number
1D-6
11 F~eld and Pool
Kuparuk Eiver Field
Kuparuk River Oil Pool
Check Appropriate Box To Indicate Nature of Not,ce, Report, or Other Data
NOTICE OF INTENTION TO SUBSEQUENT REPORT OF.
(Submit in Tr~phcate) (Submit m Duplmate)
Perforate [] Alter Casing [] Perforations [] Altering Casing
Stimulate [] Abandon [] Stimulation [] Abandonment
Repair Well [] Change Plans [] Repairs Made [] Other
Pull Tubing [] Other [] Pulhng Tubing
(Note Report multlplecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for eachcomplet~on)
13 Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25 105-170)
Accepted rig ~ 1230 hfs, 10/29/83. Perf'd 7915t - 7918' w/~+ spf; killed well. Unable to tst 7" csg to 3000
psi - suspect 7" hanger. Installed BPV. ND tree. NU BOPE & tstd. Pulled 3-1/2" tubing, RIH & set RTTS @
297'. PU 7" csg below RTTS (@ 297') to top of pkr & "D" nipple plug @ 7993' .to 3000 psi - held. P0H w/RTT5.
Checked 7" packoff & found it to be leaking. RIH & set RTT5 ~ 60'. ND BOPE & 11", 3000 psi tbg 'spool; remove
7", 3000 psi packoff. NU 11", 5000 psi tbg spool; ins~:a]led 7", 5000 psi packoff & t:std - ok. NU BOPE &
tstd - ok. Tstd csg f/RTTS ~ 60' to 3000 psi - ok. LD tbg hanger & release RTTS. T0H & LD RTT5. Ran 3-1/2't
completion assy w/tail ~ 799~~, pkr ~ 7955', & SSSV ~ 1979'. Tstd packoff to 5000 psi - ok, Tstd 3-1/2" x 7'1
ann, - ok. Installed BPV. ND BOPE. NU tree & tstd to 5000 psi - ok. Pulled "C" lock in SSSV ~ 1979'. Disl~
well to Kuparuk crude & diesel, Closed SSSV. Set BPV. Secured well & released rig ~ 1530 hfs, 11/03/83. /
14 I hereby cert~f~that the foregoing ~s true and correct to the best of my knowledge
S~gned T~tle Area Drilling Engineer
- / '--'m/ofC~s '- '
The space bel/e'w f s~on use
Condltions4~f Approval, if any
By Order of
Approved by COMMISSIONER the Commission
Date
Form 10-403
Rev 7-1-80 GRU5/SN53
Submit "Intentions" ~n Triplicate
and "Subsequent Reports" m Duphcate
ARCO Alaska, Inc ~
Post Office B~x 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
December 1, 1983
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 1D-6
Dear Mr. Chatterton:
Enclosed is a Sundry Notice for the subject well. We propose to
pull the tubing and repair this well.
Since we expect to start this work soon, your earliest approval
will be appreciated. If you have any questions, please call me
at 263-4970.
Sincerely,
A~ea D~ri 11 ing Engineer
JBK/JG5L58: tw
Enclosures
ARCO Alaska, Inc is a Subsidiary of AtlanhcR~chfleldCompany
STATE OF ALASKA
ALASKA [ .~ AND GAS CONSERVATION Cd~ MISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1 DRILLING WELL []
COMPLETED WELL EXX
OTHER []
2 Name of Operator 7 Permit No
ARCO Alaska, Inc. 79-96
3 Address 8 APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-20q18
4 Location of Well
Surface: 363' FNL, 600' FEL, Sec.23, T11N, R10E, UM
5 Elevation in feet (mdmate KB. DF. etc )
105' RKB
Lease Designation and Serial No
ADL 25650
9 Unit or Lease Name
Kuparuk River Unit
10 Well Number
1D-6
11 F~eld and Pool
Kuparuk River Field
Kuparuk River 0il Pool
Check Approprmte Box To Indicate Nature of Not~ce, Report, or Other Data
NOTICE OF INTENTION TO SUBSEQUENT REPORT OF
12.
(Submit in Triplicate)
Perforate [] Alter Casmng [] Perforations
Stimulate [] Abandon [] Stimulation
Repmr Well ~[ Change Plans [] Repairs Made
Pull Tubing j~ Other [] Pulhng Tubing
(Note Report mulBple completions on Form 10-407 w~th a submitted Form 10-407 for each completmn )
(Subm,t ~n Duplicate)
[] Altermg Casing []
[] Abandonment []
[] Other []
13 Describe Proposed or Completed Operations (Clearly state all pertinent details and g~ve pertment dates, mcludmg estimated date of startmg any
proposed work, for Abandonment see 20 AAC 25 105-170)
ARCO Alaska, Inc., proposes to repair this well. The 3-1/2" tubing will be pulled & the leaking packer will
be repaired/replaced. The 3-1/2" completion ~h~iD~ will be rerun with the necessary provisions for
subsurface safety equipment.
A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and
operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the
permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The
subsurface safety valve will be installed and tested upon conclusion of the job.
Estimated Start: December 2, 1983
Verbal approval received from M. Minder, AOGCC.
ou~sequent Work Reported
on Form No.///~-¢~'~D~tecl
14 t hereby.ee~y that the foregomg.~s true and correct to the best of my knowledge
S.gned /~-'~~.~.(~.4~.~' T,tle Area Drilling Engineer
The spa Io~f m~ss~on use
Cond,~s of Appel, ,f any
Date 12/01/83
BY LO~IHiE C. SI~1ITlt [~¥ Order of
Approved by. COMMISSIONER the Commission
Appro',.ed ~.
Returned
Date
Form 10-403
Rev 7-1-80 GRUS/SN31
Submit "Intentions" ~n Tr~plmcate
and "Subsequent Reports" ~n Duplicate
ARCO Alaska, Inc. ~
Post Off,ce Box 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
October 21, 1983
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' 1D-6
Dear Mr. Chatterton-
Enclosed is a Sundry Notice for the subject well. We propose to
convert 1D-6 to a gas injection well.
Since we expect to start this work on October 26, 1983, your
earliest approval will be appreciated. If you have any
questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG:tw
GRU4/L118
Enclosure
cc' B. J. LaForce, ATO 1490
Well File
ARCO Alaska, Inc is a Subsidiary of AtlanhcRichfleldCompany
STATE OF ALASKA &
ALASK,~ alL AND GAS CONSERVATION MMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1 DRILLING WELL []
7 Permit No
2 Name of Operator
COMPLETED WELL []
OTHER []
A~CO A!~$~e~ Inc. .
3 Address
P.O. Box !0~3~n~ Anehorage~ Alaska 99510
4 Location of Well
Surface Loc: 363' FNL, 600' FEL, Sec. 23, T11N, RIOE, UM
Bottom Hole Loc: 630' FSL, 1115' FWL, Sec. 24, T11N, RIOE, UM
5 Elevation .n feet (~ndlcate KB, DF, etc )
Lease Demgnat~on and Serial No
79-96
8 APl Number
50--029-20418
9 Umt or Lease Name
Kuparuk River Unit
10 Well Number
1D-6
11 F~eld and Pool
Kuparuk River Field
Kuparuk River 0il Pool
i05' RK6
12
ADL 25650
Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data
NOTICE OF INTENTION TO SUBSEQUENT REPORT OF
(Submit ~n Triplicate)
Perforate [] Alter Casing [] Perforations
Stimulate [] Abandon [] Stimulation
Repair Well [] Change Plans [] Repairs Made
Pull Tubing [~ Other [] Pulhng Tubing
(Note Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion )
(Submit in Duplicate)
[] Altenng Casing []
[] Abandonment []
[] Other []
13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25 105-170)
ARCO Alaska, Inc., proposes to convert well 1D-6 to gas injection. The procedure will be as follows:
(1) The tubing will be perforated at 7915' and 9.1 ppg kill weight brine will be circulated.
(2) The tubing will be pulled.
A bridge plug will be run to test the 7" production casing.
(4) The 3000 psi tubing head will be replaced with a 5000 psi tubing head.
(5) The bridge plug will be retrieved and new 3-1/2" AB Modified tubing will be run and tested to
4000 psi.
A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly
and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli
within the permafrost interva]. A 5000 psi WP wireline lubricator will be used and tested on all
wireline work. The subsurface saf~ valve will be installed and tested upon conclusion of the job.
Estimated Start: October 26, 1983
14 I hereby cerlzfy that the foregoing ~S true and correct to the best of my knowledge
S,gned /Z/Z.~k- ,/~. L~ Title Area Drilling Engineer
'/-'"-.f"l/ -//~ -
The space~lov~ffo'rp~mission use
Cond,tio~ of App¢~, ,f any
OIIIGiflAl SIGHED
BY ltAIIRY VL t~IJ(~LEq
Approved by. COMMISSIONER
Approved Copy
Returned --
By Order of
the Commission
Form 10-403
Rev 7-1-80
Submit "Intentions" ~n Triplicate
and "Subsequent Reports" in Ouphcate
Forms/Sundry10
ARCO Alaska, Inc. I~
Post OfficeB~,.. 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
October 18, 1983
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: Revised Well Completion Reports
Dear Mr. Chatterton:
Enclosed are revised well completion reports and gyroscopic
surveys for the following wells:
1D-1
1D-2
1D-4
1D-5
1D-6
If you have any questions, please call me at 263-4944.
Sincerely,
J. Gruber
Associate Engineer
JG:tw
GRU4/L110
Enclosures
ARCO Alaska, thC ~s a Subsidiary of AtlanhcRichheldCompany
[ STATE OF ALASKA I~' ~ ~
ALASKA ,L AND GAS CONSERVATION C ..,MISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1 Status of Well REVISED Class~hcat~on of Serv,ce Well
oILX~] GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2 Name of Operator 7 Perm,t Number
ARCO Alaska, Inc. 79-96
3 Address 8 APl Number
P. 0. Box 100360, Anchorage,, AK 99510 5O- 029-20418
4 Location of well at surface 9 Umt or Lease Name
363' FNL, 600' FEL, 5ec.23, T11N, R10E, UM Kuparuk River Unit
At Top Producing Interval 10 Well Number
1087' FSL, 1323' FWL, Sec.24, T11N, R10E, UM 1D-6
At Total Depth 11 F~eld and Pool
816' FSL, 1402' FWL, Sec.24, T11N, R10E, UM Kuparuk River Field
5 Elevation ~n feet (md~cate KB, DF, etc ) ~ 6 Lease Designation and Serial No Kuparuk River 0i l Pool
101' RKBIADL 256~5, ALK 2576
12 Date Spudded 13 DateTD Reached 14 Date Comp,Susp orAband ~15 Water Depth, ~f offshore [16 No of Completions
03/05/80 10/08/80 10/11/80~ N/A feet MS L~ 1
17 Total Depth (MD+TVD) 18 Plug Back Depth (M~D) 19 DlrectlonalSurvey I 20 Depth where SSSV set I 21 Thlckness of Permafrost
8610'ND,6911 'TVD 8453'HD,6775'TVD YES~ NO ~~ 1764 feet MD~ 1400' (Approx)
22 Type Electric or Other Logs Run
SP/DIL/BHCS/GR, FDC/CNL/GR, Gyro/CCL, CBL/VDL/CCL/GR
23 CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 65.0~ H-40 Surf 80' 24" 200 sx Permafrost C
10-3/4" 45.5~ K-55 Surf 2974' 13-3/4" 1600 sx Fondu & 250 sx A~ II
7" ,26.0~ K-55 Surf 8586' 8-3/4" 306 sx Class "G" & 185 s~ Tail in
24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD
~nterval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD)
8311' - 8329' 3-1/2" 7994' 7960'
8098' - 8130'
8066' - 8098' 26 ACID, FRACTURE, CEMENTSOUEEZE, ETC
8042' - 8066' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
N/A
27 N/A PRODUCTION TEST
Date F~rst Production Method of Operation (Flowing, gas lift, etc )
DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO
TEST PERIOD ~
Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press 24-HOUR RATE ~
28 COP E DATA
Brmf description of I~thology, porosity, fractures, apparent d~ps and presence of o~1, gas or water Submit core ch~ps
NONE
OCT
Form 10-407 GRU4/WC15 Submit ~n dupl.cate
Rev 7-1-80 CONTINUED ON REVERSE SIDE
29 30
GEOLOGIC MARKERS FORMATION TESTS
NAME Include tnterval tested, pressure data. all flu,ds recovered and gravity.
MEAS DEPTH TRUEVERT DEPTH GOR. and ttme of each phase
Top Upper Sand 80~2t 6~18~
Base Upper Sand 8151t 6513~ N/A
Top Lower Sand 8299~ 66~1'
Base Lower Sand 8:~95~ 672~~
31 LIST OF ATTACHMENTS
Gyroscopic Survey (2 copies)
32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge
INSTRUCTIONS
General Th~s 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 ~njection, steam injection, air injection, salt
water d~sposal, water supply for injection, observation, ~nject~on for ~n-situ combustion.
Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given ~n other spaces on this form and ~n 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
~n ~tem 27. Submit a separate form for each additional ~nterval 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 th~s well should show the details of any multiple stage cement-
~ng 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
ICUPARUK ENG~ZNG
TO: William VanAlen
DATE: ~~/~ ~47¥,T, NAME:
Transmitted herewith are the following:
D. W. Bose/Lorie L. Johnson
PLEASE NOTE: BL - BI/3ELI/krE, S - SEPIA, F - FILM, T - TAPE,
ATIN: LORLE L. JOHNSON - AFA/311
P. O. BOX 360 ,'~r,~,, , . ",,
ANCHORAGE, AK. 99510
STATE OF ALASKA ~
ALASKA .~AND GAS CONSERVATION CO ./IISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1 Status of Well Classification of Service Well
OIL i-IX GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2 Name of Operator 7 Permit Number
ARCO Alaska, Inc. 79-96
3 Address 8 APl Number
P.0.Box 360, Anchorage, AK 99510 5o- 029-20418
4 Locat,on of well at surface 363'FNL, 600'FEL, Sec 23, TllN, R10E, UM 9 Unlt or Lease Name
Kuparuk 25650
AtTopProduclnglnterval 926'FSL, 1057'FWL, Sec 24, T11N, R10E, UM 10WellNumber
1D-6
At motal Depth 630'FSL, 1115'FWL, Sec 24, T11N, R10E, UM 11 F,eldandPoo~
Kuparuk River Field
5 Elevation m feet (indicate KB, DF, etc ) 6 Lease Designation and Serial No
105' RKB ADL 25650 Kuparuk River 0il PooI
12 Date Spudded 13 Date T D Reached 14 Date Comp, Susp or Aband 115 Water Depth, if offshore 116 No of Complet,ons
3/5/80 10/8/80 10/11/80I -- feetMSLI 1
17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 D~rect~onal Survey I 20 Depth where SSSV set 21 Thickness of Permafrost
L
8610' 6865' 8453' 6730' YES r~x NO []I 1764 feet MD 1650' (approx.)
22 Type Electrm or Other Logs Run
SP/DIL/BHCS/GR, FDC/CNL/GR, Gyro/CCL, CBL/VDL/CCL/GR
23 CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
10 ~)/4" 45.5 K-55 Surf. 297~' 1:) :)/~ l&O0 sx Fnndll
250 .~x A.~-TT .
7" 26 K-55 Surf 8586' 8 3/4" 306 sx Class G & f85sx Tail in
·
24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD
interval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD)
8042'-8130' t 1/2" 7994'
8311'-8329' w/4 SPF
26 ACID, FRACTURE, CEMENT SQUEEZE, ETC
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
N/A
27 PRODUCTION TEST
Date F~rst Production I Method of Operation (Flowing, gas I~ft, etc )
12/16/81J Flowinc
Date of'¥est Hours Tested PRODUCTION FOR~ OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GA'S-OIL RATIO
F,/10/P, 1 10.1 TESTPERIOD I~ ~7,~ !51--
Flow Tubing Casing Pressure CALCULATED OILIBBL GAS-MCF WATER-BBL OII]~t~ITY-API (corr)
Press ~_~0 __ 24-HOUR RATE I~ 885 359 -- 22~0
28 COP E DATA
Brief description of I~thology, porosity, fractures, apparent d~ps and presence of o~I, gas or water Submit core ch~ps
N/A RECEIVED
MAR 1 5 1982
'~d~, ~ & 6as Cons. C0mmis~i0~
Form 10-407 Submit ~n duphcate
Rev 7-1-80 CONTINUED ON REVERSE SIDE
29 30
GEOLOGIC MARKERS FORMATION TESTS
NAME Include ~nterval tested, pressure data, all fluids recovered and gravity,
MEAS DEPTH TRUEVERT DEPTH GOR, and t~me of each phase
Top Kuparuk
River Form. 8042 ' 6377 '
Base Kuparuk
River Form. 8402' 6686'
31 LIST OF ATTACHMENTS
32 I hereby certify that the foregomg is true and correct to the best of my knowledge
Slgrled ~, ~.~~--~ Title 6,ir, ea 0ps . eng['.Date ~e ~' 0' 198~1~
INSTRUCTIONS
General' This form ~s designed for submitting a complete and correct well completion report and Icg on
all types of lands and leases ~n Alaska.
Item 1. Classlhcat~on of Service Wells' Gas injection, water injection, steam ~nject~on, air ~njection, salt
water d~sposal, 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 th~s form and in any attachments.
Item 16 and 24. If th~s well ~s completed for separate production from more than one ~nterval (multiple
completion), so state ~n ~tem 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 ~nterval.
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, ~nd~cate "none".
Form 10-407
i;O,,T, t SI~ OPL, ,.. ~:G I "E ER I :,G,,
,P~'."~l_ .~ ek/?,,~n Slmo,~-en
DATE' q- Z~- 8/ _ I!ELL RA:iE' ~.5'~g
Transmiteed here:,;itn are the follc',:lng'
PLEASE IIOTE' BL BLUELI
- ,,=, S - SEPIA F FILl1 T - TAPE
/ cv,,'F
RECE I PT ACii;;O',;L rDG[CD t: .~ ~C ]~~~~TE' Sf_-" 9
~- ~ -,,,- .......... . ~ ~ ~ ~c,, , A!a, ska(lJ~ &go-Gms C~nl'sslon
PLa,.Sz RE,~.,c,, l,a~z~,- 10. A.,E~ /,[_,~.~,, I,C. Anchorage
"' ATTIC. A;;:I SI:'O:~SE~! - AFA/311
P.O. gO'< 360
STATE OF ALASKA (~,
ALASKA iL AND GAS CONSERVATION C v~MISSION
SUNDRY NOTICES AND REPORTS ON WELLS
OTHER [] ~ 1~
1 DRILLING WELL []
2 Name of Operator
~ARC0 Al.aska, Inc
COMPLETED WE LI.,~
3 Address
P.O.Box 360, Anchorage, AK 99510
4 Location of Well
lurface Location:
363', FNL, 600' FEL,
Sec. 23, TllN, R10E
5 Elevation ~n feet (indicate KB, DF, etc )
KB=!05 '
12
Lease Designation and Serial No
25~50
7 Permit No
79-96
8 APl Number
50- 029-20413
9 Umt or Lease Name
Kuparuk 25650
10 Well Number
D-6
11 F~eld and Pool
~uparuk River FieId
Kuparuk River Oil Pool
Check Appropriate 8ox To Indmate Nature of Notme, Report, or Other Data
NOTICE OF INTENTION TO SUBSEQUENT REPORT OF
(Submit ~n Tr~phcate)
Perforate [] Alter Casing [] Perforauons
Stem ulate [] Abandon [] Stem u lat~on
Repair Well [] Change Plans [] Repairs Made
Pull Tubing [] Other [] Pulhng Tubing
(Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion )
(Subm,t ,n Duplicate)
[]~[ Altering Casing []
[] Abandonment []
[] Other []
13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any
proposed work, for Abandonment see 20 AAC 25 105-170)
Began perf operations on 6/9/81 . RU, tested lub to 3000 psi.
Perf'd intervals 8311'-8329' & 8098'-8130', 8066'-8098' & 8042'-8066'.
RIH with HP, Spinner, Gradio & Temp Tools. Flowed well @ 860 BOPD.
GOR=420, FTP=300psi, FBHP=2057 psi, ran production logs. SI well
f/BHPBU. Final SI BHP=3226 psi. POH with PL string. Secured well
on 6/10/81
NOTE: HP Tool set at 6265'ss
RECEIVED
SEP 2 9 ]!:~!
Alaska Oil & Gas Cons. C0mmJssJ0~
Anchorage
14 I hereby ~,f~hlt the forego,ng ,s true and correct to the best of my knowledge
Area Operations Engineer
S~gned . _ . Title
The space be _ for Commission
Date
Cond,t,ons of Approval, if any
By Order of
Approved by COMMISSIONER the Commission
Date
Form 10-403
Rev 7-1-80
Submit "Intentions" ~n Triplicate
and "Subsequent Reports" in Duplicate
NORTlt SLOPE EiIGIHEERI~IG
,=~,,~, ITT~,~ = $~3
TO' ~/~ ~,~/K~~ FROM'
J. J. Pa'.:elek/Ann Stmonsen
DATE' c~ _.// -¢~ ! WELL ,NAME'
Transmitted herewith are tile following
PLEASE IIOTE' BL - BLUELIi~E, S - SEPIA, F - FILM, T - TAPE
C-fi'
PLrJc. S.Z/~ RETijRri~ P, ECE I ?T TO .
DATE :,,,- 1 '", , , '
ARCO ALASV'*
,~*, I !lC.
ATTiI: Atlt~ SI:'O~£Etl - AF9/311
P.O. BO'< 360
A?ICi:O~AGE, AK 9~510
, STATE OF ALASKA
ALASK( 3IL AND GAS CONSERVATION (~ MMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1. DRILLING WELL [] COMPLETED WELL](3 OTHER []
2. Name of Operator 7 Perm,t No
ARCO Alaska Inc. 79-96
3 Address 8. APl Number
Box 360 Anchorage, Alaska 99510 50-029-20418
4 Location of Well 9. Umt or Lease Name
Surface Location: Kuparuk 25650
10. Well Number
D-6
1 1. F,eld and Pool
5 Elevat,on ,n feet (,nd,cate KB, DF, etc )
7(R e]evatin = 105
12.
363' FNL, 600' FEL,
Sec 23, TllN, R10E
6. Lease Des,gnat,on and Ser,al No Prudhoe Bay Field
ADL 25650 Kuparuk River Oil Pool
Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data
NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF'
(Submit m Tr~phcate) (Submit m Dupl,cate)
Perforate EX Alter Cas,ng [] Perforauons [] Altering Casing
Sumulate [] Abandon [] Stimulation [] Abandonment
Repair Well [] Change Plans [] Repa,rs Made [] Other
Pull Tub,ng [] Other [] Pulhng Tubing []
(Note. Report mult,ple completlons on Form 10-407 w,th a submitted Form 10-407 for each completion )
13 Descr,be Proposed or Completed Operat,ons (Clearly state all pertinent detads and g,ve pert,nent dates, ~nclud,ng estimated date of start,rig any
proposed work, for Abandonment see 20 AAC 25 105-170)
Atlantic Richfield Company proposes to perforate and flow test selected
interval of 8044-8126 (upper Kuparuk Sands) and 8311-8329 (lower Kuparuk
Sands). All wireline work will be done through a 3000 psi lubricator,
which will be pressure tested after being installed on the wellhead.
All perforated intervals, test volumes, and production log runs will be
reported on a subsequent report.
Expected start date 5-29-81
14 I hereby cert,fy that the forego,ng ~s true and correct to the best of my knowledge
~,~, -- Kuparuk Startup Director
The spa~;below for C~mm'lSSlOn useii~'''''~'' ~
Date
5/22/81
Condmons of Approval, ~f any
Returned
])]~IG(IIIA[ SI~tt[D
BY
C.
Sh~ITH
By_Qrder of
Approved by LDNT']IE COMMISSIONER the Commlss,on
Date
Form 10-403
Rev. 7-1
Subm,t "Intent,ohs" ,n Tr,phcate
and "Subsequent Reports" ~n Duphcate
NORTH SLOPE DISTRICT ENGINEERING
TRANSMITTAL
TO' ~ V' Oa~v~ A'ICW, FROM' Jerry
DATE' b ~_F.. ~1 19 ~ ~ WELL NAME'
J. Pawelek/Leo Lash
Transmitted herewith are the following for the subject well'
DATE SCALE XEROX
BHC Sonic/Gamma Ray Log
Cement Bond Log/VDL
Compensated Formation Density Log
Compensated Neutron-Formation Density
Compensated Neutron Log
Core Analysis - Interval
Core No.
Core Description (SWC) - Interval
Core Description (Conv.) - Core No.
Directional Survey - Gyro
Single Shot
· Multi-shot
Drill Stem Test - Test No.
Dual Induction Laterolog
Formation Density Log
Formation Density Log/Gamma Ray
Spectralog
TVD-DIL
Differential Temperature Log
Spinner Survey
Fluid Density
Casing Collar Log
Perforating Record
Neutron Lifetime Log
Ca~rbop-Oxygqn Log
RECEIPT ACKNOWLEDGED FOR'
DATE'
'~~LEASE RETURN RECEIPT TO'
RECEIVED
DEC- 3 1980
Alaska Oil & Gas Cons. Commission
~nchmage
ARCo Oii and Gas Company
Attn' Mr. Leo Lash
P.O. Box 360 - Rm. #311-FAB
Anchorage, AK 99510
SEPIA
....
BL
LINE
FILM
! I
!
NORTH SLOPE DISTRICT ENGINEERING
TRANSMITTAL#
Transmitted herewith are the following for the subject well:
DATE SCALE XEROX
-! o5~ I
--i
~_~_co~- ]
IRES LNG
--J I ENG
I 2 ENO l
I 3 ~.~
FROM' Oerr~ O. Pawelek/Leo Lash '~l
-- t STAT TE~
I ~ STAT
Cq~tF~R.
~" ~.
BL ~
SEPIA LINE FILM
BHC Sonic/Gamma Ray Log
Cement Bond Log/VDL
Compensated Formation Density Log
Compensated Neutron-Formation Density
Compensated Neutron Log
Core Analysis - Interval
Core No.
Core Description (SWC) - Interval
Core Description (Conv.) - Core No.
Directional Survey - Gyro '
Single Shot
Multi-shot ~
Drill Stem Test - Test No. '~
Dual Induction Laterolog
Formation Density Log
Formation Density Log/Gamma Ray
Spectral og
TVD-DIL
Differential Temperature Log
Spinner Survey
Fluid Density
Io..~J-$O Casing Collar Log
Perforating Record
Neutron Lifetime Log
Ca.rbop-Oxygqn Log
·
RECEIPT ACKNOWLEDGED FOR:
DATE:
EASE RETURN RECEIPT TO-
RECEIVED
DEC- ] !980
Al~$kaOil&GmCons. Commissicm
ARCo Oil and Gas Company
Attn: Mr. Leo Lash
P.O. Box 360 - Rm. #311-FAB
Anchorage, AK 99510
NORTH SLOPE DISTRICT ENGINEERING
TRANSMITTAL # ~ ~"~'- ( ~j~P~o
FROM' Jerry J. Pawelek/Leo Lash
Transmitted herewith are the following for the subject well'
DATE SCALE XEROX
BHC Sonic/Gamma Ray Log
Cement Bond Log/VDL
Compensated Formation Density Log
Compensated Neutron-Formation Density
Compensated Neutron Log
Core Analysis - Interval
Core No.
Core Description (SWC) - Interval
Core Description (Conv.) - Core No.
Directional Survey - Gyro
Single Shot
Multi-shot
Drill Stem Test - Test No.
Dual Induction Laterolog
Formation Density Log
Formation Density Log/Gamma Ray
Spectralog
TVD-DIL
Differential Temperature Log
Spinner Survey
Fluid Density
Casing Collar Log
Perforating Record
Neutron Lifetime Log
Carbon-Oxygen Log
BL
SEPIA LINE
COMM_ 7 ,,.
CO,M,~
.~._~,~_-~.- E N .0 i
,.L~. G,._OL '-
_1 3GF'~ I STAT T~C
I Sr^T TEC-
CONFER:
F~LF.:
_
,
_
FILM
RECEIPT ACKNOWLEDGED FOR:
DATE:
pLV~EASE RETURN RECEIPT TO'
RECEIVED
A_~ Alaska Oil ~ GRs Con}. Commission
xuo u~-I anaAl~$1~ra~mpany
Attn: Mr. Leo Lash
P.O. Box 360- Rm. #311-FAB
Anchorage, AK 99510
NORTH SLOPE DISTRICT ENGINEERING
TRANSMITTAL
DATE: j~OI/ /J/'~/ /~z~
FROM' Jerry J. Pawelek/Leo Lash
NELL NAME' /(/~j)/t~£/~/~ b-
Transmitted herewith are the following for the subject well-
DATE ~ XEROX
CONFER:
FILF:
BL
SEPIA LINE FILM
BHC Sonic/Gamma Ray Log
Cement Bond Log/VDL
Compensated Formation Density Log
Compensated Neutron-Formation Density
Compensated Neutron Log
Core Analysis - Interval
Core No.
Core Description (SWC) - Interval
Core Description (Conv.) - Core No.
Directional Survey - Gyro
Single Shot
Multi-shot -,.,
.
Drill Stem Test - Test No.
Dual Induction Laterolog
Formation Density Log
Formation Density Log/Gamma Ray
Spectralog
TYD-DIL
Differential Temperature Log
Spinner Survey
Fluid Density
Casing Collar Log
Perforating Record
Neutron Lifetime Log
Carbon-Oxygen Log
RECEIPT ACKNOWLEDGED FOR'
/DATE'
LEASE RETURN RECEIPT TO'
RECEIVED
DEC 1 ].98,0
Alaska ~J & G~s Cons. Oommtssl~n
ARCo Oil and Gas Company
Attn- Mr. Leo Lash
P.O. Box 360 - Rm. #311-FAB
Anchorage, AK 99510
ARCO Oil and Gas( npany
North Slope'~, ,tnct
Post Ofhce Box 360
Anchorage, Alaska 99510
Telephone 907 277 5637
November 26, 1980
Mr. Hoyle Hamil ton
State of Alaska
Alaska Oil and Gas
Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject: DS 17-4 Permit #80-85
DS 5-2 Permit #74-36
DS 2-4 Permit #70-17
DS 17-5 Permit #80-96
DS 15-10 Permit #80-88
DS 15-21 Permit #80-91
DS 14-9 Permit #80-89
Kuparuk
E-7 Permit #80-80
D-6 Permit #79-96
D-7 Permit #79-112
D-5 Permit #79-95
E-4 Permit #80-57
E-8 Permit #80-81
D-3 Permit #79-84
Dear Sir'
Enclosed please find'
1. A completion report, drilling history and a gyroscopic
multishot survey for wells; DS 17-4, E-7, D-6, D-7 &
E-8.
2. A Sundry Notice of subsequent report for wells; DS 5-2,
DS 2-4, D-3, D-5 & E-4. (An updated Completion Report
will be filed, for D-3, D-5 & E-4 as soon as produc-
tion test data becomes available.)
3. A monthly report of drilling for wells; DS 17-5, DS 15-10,
DS 15-21, DS 14-9,~E-8 & D-7.
Very truly yours~ ,
~,~.. ?. ^. YanDusen
D~str~ct Dr~ll~n~ [n§~neer
PAV:sp
Enclosures
' 1 !?",~,
ARCO Oil and Gas Company ~ a D~v~s~on of Atlant~cR~chfJeldCompany
Form P--7
( SUBMIT IN DUP'~ · TE*
STATE OF ALASKA (See otller In-
structions on
reverse side)
OIL AND GAS CONSERVATION COMMITTEE
WELL COMPLETION OR RECOMPLETION REPORT AND LOG*
WELL[--] DRYCi
b TYPE OF COMPLETION
NEW WORK r--I DEEP' F--'I PLUG DIFF
WELLr~ OVER I I EN I I BACK[] RESER [--] O, he,
2 NAME OF OPERATOR
Atlantic Richfield Company
3 ADDRESS OF OPERATOR
P.O. Box 360, Anchorage, Alaska 99510
4 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)*
At surface
363' FNL & 600' FEL Sec 23, TllN, RIOE, UM
At top prod interval reported below
926'Atto, al£,St~ & 1057' FWL Sec 24, Tl lN, RI OE, UM
630' FSL & lll5' FWL Sec 24, TllN, R10E, UM
13 DATE SPUDDED 114 DATETD REACHED ~15. DATECOMP, SUSP, ORABAND
3/5/80 [ 10/8/80 I 10/11/80
18 TOTAL DEPTH, MD&TVD 119 PLUG BACK MD&TVDI20 IF MULTIPLECOMPL,
I HOw MANY*
8610MD 6865 TVD 8~HMD 6730 TVDI sln§le
22 PRODUCING INTERVAL(S)LOF THIS C~)~TJ[Q~[~TOP, Sand 8299 MD
t Kuparuk 8020 MD B.~TTLJO~[~,NAME (MD & TVD)*
T Up Sand 8042 MD 6376 TVD B Low Sand 8328 MD
R lin q~nH Rl~& Mn ~&7q tvn R Kuparuk Rqoa un
24 T~PE-EFLE.(~T~'I~?AND-O=I'~E'R [.~)-GS R0~
SP/DIL/BHCS/GR, FDC/CNL/GR, Gyro/CCL, CBL/VDL/CCL/GR
cASING RECORD (Report all strings set In well)
25
CASING SIZE i WEIGHT, LB/FT
16" I 65
SIZE
n/a
26
GRADE I DEPTH SET (MD)
H-40 I 80'
K-55 I 2974' I
K-55 I 7994'
LINER RECORD
TOP (MD) BOTTOM (MD)
28 PERFORATIONS OPEN TO PRODUCTION
SACKS CEMENT*
(interval, size and number)
5 APl NUMERICAL CODE
50-029-20418
6 LEASE DESIGNATION AND SERIAL NO
ADL 25650
7 IF INDIAN, ALLOTTEE OR TRIBE NAME
8 UNIT, FARM OR LEASE NAME
Kuparuk 25650
9 WELL NO
D-6
n/a
10 FIELD AND POOL, OR WILDCAT Kuparu k
Prudh0e Ba,y Field/River 0il
1 SEC, T, R, M, (BOTTOM HOLE Pool
OBJECTIVE)
Sec 24, TllN, RIOE UM
12 PERMIT NO
79-96
1 2~ ROTARY TOOLS ,NTERV^LS ?R,L'ED B~ CABLE*OO,S
all
23 WAS DIRECTIONAL
6597 TVD SURVEY MADE
6622 TVD yes
~lq7Q tvr~
HOLE SIZE I CEMENTING RECORD L AMOUNT PULLED
24" 200 sx Permafrost to surtace
13-3/4'I 1600 SX' fondu & 250 sx A~-II to surface
8-3/4"1 306 sx Class G & 185 sx Tail in
27 TUBING RECORD
SCREEN (MD) SIZE DEPTH SET (MD)
3½" 7994'
29 ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC
PACKER SET (MD)
7960'
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
3O PRODUCTION
DATE FIRST PRODUCTION IPRODUCTION METHOD (Flowing, gas hft, pumping--size and type of 13ump)
n/a
DATE OF TEST I HOURS TESTED CHOKE SIZE ]TEsTPROD'NpERIoDFOR~ iOI L-BB L
PREssFLOW TUBING IICASING PRESSURE 24-HouRCALCULATEDRATE~ OIL-BBL I GAS--MCF
31 DISPOSITION OF GAS (Sold, used for fuel vented, etc )
GAS-MCF WATER--BB L GAS--el L RATIO
I
jWATER--BBL JO,L GRAVITY-APl {CORR )
TEST WITNESSED BY
DATE
32 LIST OF ATTACHMENTS
Drilling Hi'Dry, Gyroscopic Survey
33 I hereby ce r t, f~ ~ n)~ at j~d :n.fo~mat,on is co. plete and correct as determined from ail available records
SIGNED{""~'~%~~~' ~ ~J~ ~J- ' TITLE Di stri ct Dri 11 ing Eng.
~(See instructions and Spaces for Additional Data on Reverse Side)
INSTRUCTIONS
General Th~s form ~s designed for submitting a complete and correct well completion report and Icg on all types of
lands and leases ~n Alaska
Item: 16: Indicate which elevation ~s used as reference (where not otherwise shown) for depth measurements g~ven ~n
other spaces on th~s form and ~n any attachments
Items 20, and 22: If th~s well ~s completed for separate production from more than one ~nterval zone (multiple com-
pletIon), so state ~n ~tem 20, and ~n ~tem 22 show the producing ~nterval, or ~ntervals, top(s), bottom(s) and name(s)
(~f any) for only the ~nterval reported ~n ~tem 30 Submit a separate report (page) on th~s form, adequately ~dent~hed,
for each addtt~onal ~nterval to be separately produced, showing the additional data pertinent to such ~nterval
Item 26 "Sacks Cement" Attached supplemental records for th~swell should show the detmlsof any multiple stage
cementing and the location of the cementing tool
Item 28: Submit a separate complet~on report on th~s form for each ~nterval to be separately produced (See~nstruct~on
for ~tems 20 and 22 above)
34 SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS,
WATER AND MUD 35 GEOLOGIC MARKERS
NAME
MEAS, DEPTH TRUE VERT. DEPT
NONE
T Kuparuk 8020' 6358'
T Up Sand 8042' 6376'
B Up Sand 8]54' 6473'
T Low Sand 8299' 6597'
B Low Sand 8328' 6622'
B Kuparuk 8453' 6679'
36 CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS
AND DETECTED SHOWS OF OIL, GAS OR WATER
NONE
DRILLING HISTORY
KUPARUK D-6
Spudded well @ 1200 hrs on 3/5/80. Drld 13-3/4" hole to 2996'. Circ
and cond mud. RU and run 10-3/4" csg w/shoe at 2974'. Cmt 10-3/4"
csg w/1600 sx Fondu and 250 sx Arctic Set II. Displace hole w/oil base
mud. Circ and cond mud, NU well heads. Tst pkoff, NU tree, well sus-
pended, move rig to West Sak site. Released rig @ 1100 hrs 3/11/80.
Accept rig @ 0600 hrs 9/28/80. Circ and displ old oil base mud Drl
8-3/4" hole to 8941'. Run Open holes. Run #1 SP/DIL/BHCS/GR t~ 8488'.
Run #2 FDC/CNL/GR to 8488'. Shoot sidewall cores. RU & run 209 its
7" 26# K-55 BTC csg, w/shoe @ 8586' Circ and cond mud. Cmt w/306 sx
11.9 ppg Class G cmt and 185 sx taii in. Instl 7" pkoff and test to
3000 psi. Run cased hole logs, run #1 Gyro/CCL, Run #2 CBL/VDL/CCL/GR.
Tst Arctic Pack to 1000 psi, 1 hr. Run 3½" tbg and completion assy
w/tail @ 7994' and pkr @ 7960'. Displ to diesel. Drop ball, set pkr,
ND BOPE, NU and tst tree. Monitor long term tbg tst. Release rig @
1800 hrs 10/11/80.
Eastman
A PETROLANE COMPANY
REPORT
of
SUB-SURFACE
DIREC TIONA L
SURVEY
Arco 0il & Gas
COMPANY
Pad D, Well No: 6
WELL NAME
Kuparuk Field, North Slope~ Alaska
LOCATION
JOB NUMBER
A980DO023
TYPE OF SURVEY
Directional Single Shot
DATE
8/Mar/80
SURVEY BY
Mike Gates
OFFICE
....... .... "~'-'-~..-"Alaska
Eastman
Wh p§t oc k
¢
P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 3494617
TWX 910-881-5066/Cable: EASTCO
October 22, 1980
Arco 0il & Gas
P. 0. Box 1479
Anchorage, Alaska 99510
Well Number: Pad D, Well No: 6
Location: Kuparuk Field, North Slope, Alaska
Type of Survey: Directional Single Shot
Date: March 8, 1980
Method of Computation: Radius of Curvature
Surveyor: Mike Gates
Job Number: A980D0023 .~ J -~-
ATTN: Bob Hines
Dear Mr. Hines,
I am enclosing the original and one copy of the
Directional Single Shot Survey run on the above men-
tioned well.
We wish to take this opportunity to thank you
for calling on our services and trust that we may
continue to serve you in the future.
Sincerely,
~im Turnage
District Operations Manager
Alaska District
cc: file
eno.
JT/cfw
D~rect~onal Dnllers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide
ARCO OIL. ~ GAS ......
F'AO lq, WELl_ NO: ,5 ~.I~IS/DSS JOB NU~ ~980D002S
KtJF'AI~UK FIE[ D, NORTH SLOPE, ALASKA
HMS, O-2956t'lD, DAlE RUN~ 9-MAR-80, SURVE:YOR: M LUND
DSS, 3127-8453 MB, DRILL. ER: H GAFES
-~VERTICAL SECTrON CALCULATED IN PLANE OF PROPOSAL ~.,:.~.~
BIREC[ION,~ S 28 DEGo ~. 0 MINo E
,
RECOR. D OF SURVEY
RAIqlUS OF CURVATURE METHOD
· SRCO OIL.. ,Y., GAS '
F'AD D, WELL NO~ 6 MMS/DSS dOB NO: A980D0023
NUPARUN F1EID, NORTH SLOPE, ALASKA
COHF'UT~ l' 1 ON'
¥I~E DATE
12:12:58 2'2-0CT-80
PAGE NO. I
........ TRUE ~'
MEASIJREB DRIFT DRIFT COURSE VERTICAL VERTICAL R E C T A N G U L A R C L 0 S U R E DOGLEG
D£F'I~I ANGL.E DIRE'CTION LENGTH DEF'TH SECTION C 0 0 R D I N A l' E S DISTANCE DIRECTION SEVERI['~
FEE T D PI 0 FEET F'EEI' FEET FEET FEET D M DG/IOOF l
O, 0 0 0 O. 0,00 0,00 0.00 0+00 0,00 0 0 0,00
11~..~ I 0 S 77' W 115, 114,99 -0,26 O.*S- S 0,98 W 1,00-S 77 0 W 0.87
207. 0 SO N 79 W 9'2. 206+99 -0.80
299. 0 0 0 92. 298+,~ 1+05 0.17 S ..+57 W 2.57 S 86 13 W 0.54
~ -1,'~~
~ 0,01 N 2,65 W o,65 N 89 44 W O.
S91. 0 ]5 N 24 W 92. S90.,~ - .
aSS. 0 0 0 92. 482.98 -1.45 0.20 N 2.73 W 2.74 N 85 54 W 0.27
~5+ 0 45 N 26 E 92. 574.98 -1.81 0+74 N 2.46 W~ 2.57 N,73 22 W 0.82
~'~'/d,~. 0 SO N S4 W 92. 666.98 -2.68 1.69 N 2.53 W S+04 N 56 15 W 0.72
759. 0 0 0 92. ~o ~ O? N 0.76 W 3.4o N 53 4'~ W 0.54
zoo+9? -S.08 -. ........
851. 0 $0 S 87 W 92. 850.97 -$.25 2.00 N S+16 W S.74 N 57 S6 W 0.54
943.
1035.
1127.
1219.
1~11.
·
i 1403.
i 1495.
1587.
1679.
0 45 S 66 W 92+ 942.97 -3.50 ~ 1.77 N 4.13 W 4.49 N 66 47 W 0.36
I 15 S 8 W 92+ 1034+95 ~-~.85 "~' -
· . ~ ~ jj ~ 0.54 N 5.05 W 5.08 N 83 5? W 1.16
,~ 0 S 22 E 92+ 11~6.89 O.SO 2.80 S 4.64 W =; 42 S 58 51W o.19
5 15 S ~7 E 92+ 1218.64 ,, 6.89 8.55 S 1~9 W 8.66 S 9 15 W 2+69
8 0 S 38 E 92. 1~10.02 .... ~ 17.36 ~' ~16.97 S,, , 5.07 E 17.71 S 16 ~8 E '2.99
11 0 S-,o E 92+ 1400+75 32.38 29.17 S 14 10 E 32 40 S -.o 48 E 3.30
'2 52 '"9
14 30 S 34 E 92+ 1490+46 52.55 45+90 S'\ 5,60 E +56 S , 9 E 3.81
18 0 S SS E 92. 1578.78 78.17 67.37 S 739.80 E 78.25 S 30 35 ~ 3.82
56.73 E 109.31 S 31 16 E 3.80
1 30 S 3S E 92, 166~.SU 109.13 9S.4TM S~
S 35 E 92. 1749.87 145.24 ...... 123.54 S 77.04 E"-- 145.59 S S1 ,,7 E 3.90
. 1771~* 25 0
1955.
2047.
2139.
28 0 S 36 E 92. 1832+]9 185.94 156.95 S 100 87 E 186 ~7 S 32 44 E
S1 0 S 35 E 92. 1912.25 230.85 193+8~ S 127+18 E~ 231.83 S 33 16 E S.SO
_ ~o. ='~= O0 E o81.58 S 33 24 E S.98
34 30 S 33 E 92. 1989+6~ 280+33 0'~' 08 S 1,,o.
36 0 S 31 E 92+ 2064.75 SSS.SO 280.11 S 185.14 E 334.66 S SS 11 E 2+06
39 0 S 29 E 92. 2137.73 389.26 S28+60 S 211 14 E 390.59 ~ ....~ 43 E S 52
2323;.
2415+-
2507.
'.2599.
2691 ~
41 45 S 30 E 92, 2207+81 448.83 380.47 S 240.48 E 450.09 S 32 18 E 3.07
43 0 S SO E 92. 2275+77 510.80 434.16 S 271.48 E- 512.06 S 32 I E 1.36
43 0 S 28 E 92+ 2343+06 573.53 489+04 S S01+90 E 574.72 S 31 41 E 1.48
43 15 S 28 E 92+ 2410.20 636+42 544+57 S S~1.43 E 637.49 S 31 20 E 0.27
43 0 S 26 E 92. 2477+$5 699.30 600.60 S SU9.98 E~ 700.22 S S0 56 E 1+51
~RC.O OIL & GAS - ' ' COHF'UT~TION" PAGE NO. 2
"AD D, WELl. NO: 6 MbS/DSS dUB NO~ A~80DO02~ TIME [;ATE ,
xUF'ARUIx Flf'LD, NORmal SL.O~'E, ALASKA 12;12;58 22-0CT-80
TRUE
'IEASURED DRIFT DRIFT COURSE VERIlCAL VERTICAL R E C T A N G U L A R C L 0 S U R E DOGLEG
. ,~EL:TION C 0 0 R IJ i N A ~ E S BISTANCE DIREC]ION SEVERI FY
DEF'I ¢1 A~GL E DIRL CI'~ON LENGTH DEF'TH c- , . .
t"E'ET D ~1 ~ FEET FEET FEEl' FELT FEEF D ~t DG/iOO~' I
2783. 43 30 S 27 E 92, 2544.J6 762.32 657.02 S 388.11 E 763.08 S 30 34 E 0.92
2875. 42 0 S 29 E 9~'... 2611.92 824.76 71°-.15 S 417.42 E 825.47 S 30 ..'~3 E -'.20
2938. 42 0 S 28 E 63. °658 74 ~z~:
~ · ~o~.91 749.~'~.0 S 437.54 E 867.60 S 30 17 E 1.06
2956. 42 0 S 29 E 18. 26-'°/..11 878.96 -'"./~9.78 S 44~.28 E 879.64 S 30 16 E 3.72
FIE' IN F'OINI' FROM PREVIOUS E/W ~lHS
%.,7. 42 30 S 30 E 17]. 2798.69 993.88 859.60 S 500.33 E 994.61 S 30 12 E 0.66
3344. 43 SO S 30 E. 217. 2957.39 1141.73 987.1'2 S 575.45 E. 1142.60 S 30 14 E 0.46
3592.. 43 0 S 30 E 248. 3138.03 1311.47 ~ 11~3.53 S 661.6~ E 1~1'~.~ 52 S $0 16 E 0.20
~840. 4~ 30 S 29 E ~°48. 3318.66 1481.31 1280.69 S 746.65 E 1482.45 S 30 15 E 0.34
4090. 46 0 S~."9 £ -~50. $496°20 1657.24 14~3~. .86 S 833.31E 1&58.42 S 30 10 E 1.00
4240. 46 0 S~8 F 150. 3600.3~ 1'76~.12 ~ ~" . 1528,~3 ~ ~ 885.62 E 1766.30 S 30 6 E. 0.48
4612. 48 0 S 30 E 372, 3854.09 ~ '2037.07"~ 1765.00 S 1019.58 E 2038.33 S 30 I E 0.67
4766. 48 0 S '"9 E 154.. 3957.13 ~m151.44 ~1864.11S · 1076.80 E 21'=~:~...77 S 30 I E 0.48
4891. 48 0 S 29 E 125. 4040.77 2244.30. '..1944.96 S:~, 1122.55 E 2'245.66 S 30 0 E 0.00
. 1~.~.42 S ~1 .65 E m ~'"~
...... 4~..99 S 29 57 E 0.00
5170 48 0 S 29 E 279. 4227.46 ~451.57 2 ~'
5419. 47 30 S.~ E 249. 4394.88 2635.82 2285.84 ~.~ 1315.41E ~637.30 S 2~ ~'.~- E 0. 20
5728. 46 15 S 29 E 309. 4606.].1 _~861.~7_ 2482.13 S 1426.46 E ~°86~-.82 S 29 53 E 0.40
16128.- 44 0 S 28 E 400. 4888.31 3144.66 .... 2730.03 S 1563.8/ E ~ 3146.23 S 29 48 E 0.59
588. 40 45 S 26 E 460. 5228.09 3454.60 3005.59 S 1705.80 E 3455.91 S 29 35 E 0.80
. . . ~.0.62 E 3726.81 S ~9 15 E 0 91
%"Y021. 37 0 S 24 E 433 5565 13 3725 93 3251.85 S 1
7177 35 0 S 3 E 1.56 ~6~1 S3 3817 34 3335.92 S 1857.18 E 3818.05 S 29 6 E 1.54
7375. 33 0 S 20 E 198. 5855.47 3927.33 3438.92 S 1897.76 E 3927.80 S 28 54 E 1.32
7766. 31 45 S 16 E 391. 6185.69 4133.46 3637.99 S 1962.44 E 4133.54 S 28 21E 0.o3
7918. 31 0 S 15 E 152. 6315.46 4210.72 3714.°~:~ S 1983.59 k 4210. 73 S 28 6 E' O. 60
8139. 30 30 S 15 £ 221. 6505.39 4320.82 5823.39 S 2012.83 E 4320.86 S 27 46 E 0.23
-8453c- 30 0 S 14 E 314. 6776.63 4474.63 -3976.53 S ~.~.nn'::~ 44 E-~ 4474.97 S 27 18 E 0.25
..... FINAL CLOSURE - DIRECTION:
lqlSTANCE 1
..7 DEGS 18 MINS 0 SECS E
S n-
4474.97 FEET
I"It S/[3Ss: 'l - Nb
----I (UPFIRUt( FIELD, NORTH SLOPE, FILt4$KFI ...... ! .... 3EP__INjBOIC[t.r_~R,- TVO
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·
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, . , , , , , , , , , , , , . , , ,
........
ARCO ALASKA, INC.
PAD ID, WELL NO: 6 SIOMA-GYRO dOB NO: AO~83Z0206
SIGMA-GMS, 0-8586 MD, SURVEYORS: CORAM/PEFFERKORN, DATE RUN: 11-SEP-83
SIGMA 175 NO. 18184, PROBE NO. 058 .
FORESIGHT;_.N 27.08E ~
SURVEY TAKEN FROM WELLHEAD
VERTICAL SEcTioN CALCULA/IN
A PETROLANE C(_)MPANY
RECORD OF SURVEY
ARCO ALASKA, INC. - .............................................. COMP-UTATIC~ ....... PAGE NO,---- ~
PAD 1D, WELL NO: 6 SIGMA-GYRO dOB NO: AO983Z0206 TIME DATE
KUPARUK FIELD, NORTH SLOPE, ALASKA 13:58:35 07-0CT-83
TRUE
MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S LI R E DOGLEC,
DEPTH ANGLE DIRECTION LENGTH- DEPTH --SEC~ION-~ .... TVD .... -C-.O--O-R-D-~-N-A~-~-E-$-DI$~P2~ICE~--DIRECTION SEVERIT
FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/IOOF
O.
100.
200.
300.
400.
0 0 ...... 0 ....0 ........... 0.- ......... 0.-00 ...... 0~00,-- -,101-.-00 ...... --0,00 ........ 0.00 ......... 0.00 .... 0 0 0,00
0 13 S 15 19 E 100. 100.00 0.18 -1.00 0.18 S 0.05 E 0.19 S 15 1¢/ E 0.22
0 11 S 16 43 W 100. 200.00 0.48 99.00 0.51 S 0.05 E 0.52 S 5 3 E 0.11
0 11 G.: ,. 18 2~ W,- 100. -300.-00 .......... 0.7..0 .... 1-9~,-00
0 8 S 78 17 W 100. 400.00 0.76 299.00 1.00 S 0.25 W 1.0.3 S 14 8 W O.
500.
600.
700.
800.
900.
1000.
1100.
1200.
1300.
1400.
0 8 N-40 22 E
0 10 N 59 55 E 100. 600.00
0 9 S 66 19 E 100. 700.00
0 7 S- 31-.-2~-W ...... 100 ..... ,~00~,00 .........
0 12 S 48 30 W 100. 900.00
0 30 S 27 14 E
2 27 S 26 7 E
~ 7 S 32 23 E
8 7 S 33 57 E
11 21 S 31 52 E
100, -500,00 ..... 0,~58 .... 3~-~.(:~ ........ 0,84--S---- ..... -0~.34-W ..... 0~9i----$- 22 --1 W - - 0.25
0.68 S 11 2 W 0.06
0.67 S 10 32 E 0.14
0~87__.S_.~ 1 1- E 0.20
1.07 S 0 11 E 0.0c~
_1.63 -S- 3 34 W O.
4.06 S 15 2 E 1.95
10.58 S 23 50 E 2.69
22.03- S 28 42 E _3.01
38.91 S 30 32 E 3.25
1500. 14 ~ S 31 13 E 100. --ld95.01 ..... 61~3~.-13F~.-01-- --52.7~--S ....... 3~.57-£ .... 61...~7 $ 30-54 E 3.39
1600. 18 38 S 30 55 E 100. 1590.78 90.06 1489.78 77.33 S 46.38 E 90.17 S 30 57 E 3.70
1700. 22 38 S 2~ 15 E 100. 1684.34 125.27 1583.34 107.81S 64.04 E 125.40 $ 30 43 E ~4
1800, .-26 --0 S-JO- 8 ~ ..... 100~---!.775,~6 ........... --~6~,42 ....... 1~74~4~ 143~58 S 8~1~43 E !66~56 ~--30-2:-E ..... ~
1~00. 29 18 S 33 17 E 100. 1864.03 212.72 1763.03 183.05 S 108.82 E 212.95 S 30 44 E 3.61
2000.
'2100.
2200.
2300.
2400.
32 22 S 31 I~-E ..... 100 ..... ~4~.,,88 ....... 2Y~3,B3_ ..... 184B~88_Z~22~_3A_S. ,_136.,20_E~2_~.18. S.31 2 E __ 3.23
35 18 S 28 58 E 100. 2032.~4 319.46 1~31.94 274.51 S 164.15 E 319.84 S 30 53 E 3.21
38 4 S 28 21 E 100. 2113.13 37~.19 2012.13 326.~2 S 192.80 E 379.54 S 30 32 E 2.7~
41 ~ S 28-44 £ -- 100. 2.190-.16 ...... 442.~3__208~.1& ..... 382.~2 S---223.25_E _~.4~3.25 _S 30 15 E 3.07
42 40 S 2~ 23 E 100. 2264.58 50~.72 2163.58 441.30 S 255.69 E 510.03 ~ 30 5 E 1.58
2500,.. 43 12 S 26-3.9 E__ 100 ........... ~,.~ ...... 571~2__2236~73_-__~~_~.~6~E__~07 .... S_2~51._E .... 1.~4
2600. 43 16 S 25 42 E 100. 2410.65 646.29 2309.65 562.91 $ 317.90 E 646.47 S 29 27 E 0.65
2700. 43 14 S 25 10 E 100. 2483.4~ 714.75 2382.49 624.80 S 347.,34 E 714.86 S 29 4 E 0.37
2900. 42 2 S 27 57 E 100. 2629.82 851.03 2528.82 746.79 S 408.20 E 851.07 S 28 40 E 1.62
ARCO ALASKA,~.INC
PAD 1D, WELL NO: 6 SIGMA-GYRO
KLIPARUK FIELD, NORTH SLOPE, ALASKA
TRUE
...mOB NO: A0983Z0206
,
DA31!~_t.[T_~T~ON .... PAGE_NO,__ 2
TIME DATE
13: 58: Jo 07-0CT-83
MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N 0 U L A R C: L 0 S U R E DOGLE[,
DEPTH ANGLE,DIRECTION LENGTH___ DEIBTH .... ~SECTIGN ___T_~ C o o R O_L_N_fl_]~ ~ S n!STANC~ ~I~ECT_IL-II~_SEVERI]
FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/100F
3000. 41 53~8_28AQ~E ..... lO~__2ZO~iB___~IZ~8~_~O~IB- .B.O~~_~ .__~.&~_E _._~lZ.~__8 28 ~7 E 0.21
3100. 42 23 S 29 40 E 100. 2778,34 984.~6 2677,34 864.51 S 472.0~ E ~85,01 S 28 38 E 1.12
3200. 43 0 S 2~ 27 E 100. 2851.84 1052.75 2750.84 ~23,4~ S 505.54 E 1052.81 S 28 42 E 0.63
3300, 43 47 S 2~ 3~ E~ 100. _2~2~5=.1__1121~--2823-51 ~83.27 S
3400. 43 4~ S 28 57 E 100. 2~6.69 1190.61 2895.69 1043.64 S 573.21 E 11~0.69 S 28 47 E O.
3600. 43 12 S 28 38 E
3800. 43 40 S 27 57 E
..... 3~00.,i A~_30.S_27__18_~ ....
4000. 46 19 S 26 34 E
3500.
100. 3142.01 1328.02 3041.01 1164.31 S 638.~7 E 1328.11 S 28 45 E 0.1~
200. 3287.25 1465.52 3186.25 1285.38 S 704.14 E 1465.61 S 28 43 E 0,33
100. 3429.28 1&06.2~ 3328.28 1410.51 S 768.&5 E 1606.35 S 28 35 E 1.8~
4100, 46 39 S,27_.47 E
4200. 46 21 S 26 39 E
4300. 47 42 S 27 18 E
4400, 48 59 S.27_58 E
4500. 48 41S 28 I E
1678,q~4~_ S_28_32 E 0.94
1751.36 S 28 28 E 0.88
1824.50 S 28 25 E 1.43
1974.48 S 28 22 E 0.30
4600. ~8 33 8_29 ~6 E__ 100.._~B~3~=,~__2047~8~373_2,5_4_._1.80.3.,08_8 ..... 77~.3&_£ _2_0~9~_..51___,5.q 28 23 H .1.~2
4700. 48 2 S 28 8 E 100. 3900,07 2124.12 37~.07 1868,41 8 1010.4~ E 2124.16 8 28 24 E 1.32
4800. 47 52 S 28 16 E 100. 3~67.05 2198.38 3866.05 1933.85 S 1045,5~ E 21~8.42 S 28 24 E
4~00 ..... A7,_5Z_S._27__Si_E ___lOll ..... 4024,0~.. 22.7,2,5? 3923.09 199~.32 ~ 1_0~/1,~2 ~ 2272.62
5000. 47 47 S 27 58 E 100. 4101.17 2346.75 4000.17 2064.84 S 1115.26 E 2346.78 S 28 22 E 0.17
5100. _47 24 S 2.8 O~E ........100 ...... _4168,.&l_~20~S8 .... __4_OAZ.._&I__2/30. O.~._,S_ ..... II~?~8?_L__2~dZO,&I._ ~ 28_22 E__ 0.38
5200. 47 36 S 27 35 E 100. 4236.17 24~4.31 4135.17 21~5.28 S 1184.26 E 24~4.34 S 28 21 E 0.37
5300. 47 20 S 28 51 E 100. 4303.78 2568.00 4202.78 2260.21 S 121~,10 E 2568,03 S 28 20 E 0.~7
5400. 47 ~6 S 27~5~ E~__ 1QO .... A371~.70___2&Al..~3~ ~27_0..7_0___-~232A.~S .... 1253~,~7_8_E,__26~l~2___S;__28_21~E_ _0.74
5500. 46 51 S 28 2 E 100. 4439.~3 2714.50 4338.~3 238~.36 S 1288.26 E 2714.53 S 28 20 E 0.27
5&00.~. ~&57_ S. 28.23.~E_ 100 .... ~0B~2&._278_7~.=,~/__4407-26 2453_._Zl_L~.t~~55 _~_28_.20__E ..0.27
5700, 46 10 S 27 45 E 100. 4577,02 2860.13 4476,02 2517,77 $ 1356,74 E 2860.15 S 28 1~ E 0.~1
5800. 46 26 S 27 32 E 100. 4646.11 2~32,43 4545,11 2581.82 S 13~0,4~ E 2~32.45 S 28 18 E 0.31
........ ~O0 .... ~5 43 $ 27 .~8 E _ lOO ..... ~715~48 .... ;i00-4.~.5.---~&1-4,-4,2t--?~,5-,~0-.--,S--~1~2~-5-~,~ 3o04.4_L~.28._lT.E_. 0.~7
6000. 44 41S 26 57 E 100, 4785,~4 3075.39 4684.~4 2707.00 S 1455.81E 3075,40 S 28 15 E 1.04
ARC:O ALASKA. I NC. .~ ................................................ CON~'U~A-%ION ...... P-AGE NO.- .... 3
F'AD 1D, WELL NO: 6 SIGMA-GYRO , dOB NO: AO983Z0206 TIME DATE
KUPARUK FIELD, NORTH SLOPE, ALASKA 13: 58:35 07-0CT-83
TRUE
MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C: T A N O U L A R C L Em S U R E DOGLE6
DEF'TH ANGLE DIRECTION L~NGTH ....... DE~TH ..... ~ECTION-~ .... T~D~-C-O~ ~~-~N-A-T-E-~~C~-~IREG~ION- ~EVERI]
FEET D M D M FEET FEET FEET FEET FEET FEET D M DO/100F
6100. 43 56 S 24 ~&~E ...... l~O0.-~4857.5~L---3145.~2~-~75&..~50 ..... ~%71.32--$- 1487.3%~E---3~45.23----~-28 13 E
6200. 43 24 S 26 20 E 100. 4929.84 3214.25 4828.84 2833.08 S 1518.24 E 3214.25 S 28 11 E
6300. 42 33 S 26 24 E 100. 5003.00 3282.39 4902.00 2894.16 S 1548.51 E 3282.39 S 28 9 E
6400. 41 41 S 25 21 E 100. _5077~._18__334~40~.-4~7~.~8---.~LSZI~.SCL$~157~.-78-E--.-33~9-~O
6500. 41 12 $ 24 58 E 100. 5152.14 3415.50 5051.14 3014.41 S 1605.92 E 3415.50 S 28 3 E
O. 76
0.61
O. ,'35
O.
~&O0. 40 ~1S 24 20 E - 100.- 52~8.~06 3480.47~51~7...0.~-~3~3.,.57~$~1633~0~-E---3480~-47---~-27-5~ E 1.25
6700. 39 34 S 24 8 E 100. 5304.90 3544.33 5203.90 3131.93 S 1659.33 E 3544.34 S 27 55 E 0.47
6800. 38 13 S 23 52 E 100. 5382.73 3606.95 5281.'73 3189.28 S 1684.87 E 3606.98 S 27 51E 1.36
7000. 35 58 S 22 38 E 100. 5542.4~ 372~.83 5441.49 32~.7~ S 1732.4~ E 3726.~1 S 27 42 E 1.00
7100. 35 25 S 22 17 E I 56~3. .74 E 3785.01--S_27 37 E 0.59
7200. 34 44 S 22 13 E 1~ 5905.~"¢i~' ~"~~~..'~'~l'J'zr.'~. ~~--~ ~.51 E 3842.22 S 27 32 E 0.68
7:300. :34 3~ S 21 24 E l~ 5787.83 3~~~.~~~ ~.bl E 3898.76 S 27 27 E 0.5~
7400. 33 41 S 21 54 E l(~ 3~~i~~~~~ ~~.30 E 395~.5~ 6-27~22 E- 0.88
7600. 32 11S 18 2~ E~ 100 .... ~038.81 ..... ~.O&l-~O,- 5~37.81-- 3613.38-S--1855.~1-E .~061.91 -S 27 11E 0.87
7700· 31 24 S 17 51E 100. 6123.81 4113.30 6022.81 3663.44 S 1871.83 E 4113.95 S 27 4 E 0·85
7800. 30 44 S 17 14 E 100. &209.46 4164.03 6108.46 3712.64 S 1887.39 E 4164.85 S 26 57 E r~4
7900 ...... 30---205--lb-33-E .... 100..---~-9~~13~87~.~1~;~0 37~1.;25 ~ !902--~5 E 4214=~-9---..~6-50--~ ..... ~ ~3
8000. 29 59 S 16 52 E 100. 6382.06 4263.12 6281.06 3809.37 S 1916.59 E 4264.35 S 26 42 E 0·38
8100. 30 9 S 1~ 41~E _~1OQ ~8~b_O_~312._2~ .... &3~.7~_~Q__38~7~3~_~..~l~31.D~E__~..3_l~...ZI .... S_26 ~ E
8200. 30 24 S 16 27 E 100. 6554.97 4361.65 6453.97 3905.67 S 1945.43 E 4363.36 S 26 29 E
8300. 29 40 S 16 46 E 100. 6641.54 4410.70 6540.54 3953.63 S 1959.73 E 4412.68 S 2~ 22 E
8400· 29 37 S 15~5~ E 100. _~2.8~45__~5~.1~ .... ~2.~7~5 .... ~001~9_S ..... 1~3..~___~4~1~41__S_2~15 E
Q. 19
0.28
O. 75
O. 39
PROJECTED TO PBTD
~'"=~¢,~,~,. ~. 2:7 S 15 59 E 53. 6774.53 4484.75 6673.53 4026.27 S 1980.89 E 4487.18 S 26 12 E
0.00
,~BROdEGTED TO TD ....................
8610. 29 37 S 15 59 E
157. 6911,02 4560.61 681 O, 02 4100.86 S 2002.26 E 4563, 56 S 26 1 E 0.00
FINAL CLOSURE - DIRECTION:
T"~'r f~'~-'T'~'~hl~--r~_ ·
S 26 DEOS 1 MINS 27 SECS E
ARCO ALASKA~ INC.
PAD 1D~ WELL NO: 6 SIGMA-GYRO dOB NO: AO~83Z0206
KU~RU~,,_E.IELD~_NOE~ELSLDIRE,_--~L~S~
SIGMA-GMS, 0-8586 MD, SURVEYORS: CORAM/PEFFERKORN, DATE RUN: 11-SEP-83
SIGMA 175 NO. 18184, PROBE NO. 058
FORESIGHT: N 27 0SE
SURVEY TAKEN FROM WELLHEAD
... .Eastman
ARCO ALASKA, INC, - ............................................
F'AD 1D~ WELL NO: 6 SIGMA-GYRO dOB NO: AO?83Z0206
KUPARUK FIELD, NORTH SLOPE, ALASKA
MARKER ....... TRUE SUBSEA
CODE
NAME - ~
4-COH~UTATI ON .......... PAGE NOr-- ~
T I ME DATE
14: 1:3: 41 07-0CT-83
MEASURED VERTICAL MD-TVD VERTICAL R E C T A N G U L A R E: L 0 S U R E VERTICAL
DEPTH ......... DE~H .... --DIEE~--D~ ..... C-O-O-~-D--I.N-A ~_F__~_DIS~ANCE---[II~ECT~ON-~HICKNE$$
FEET FEET FEET FEET FEET FEET D M
~TOP UPPER SAND .......... 8042,~O__-~iS,'4~&23,~--~&3~.A~--38*2~5~.~$-./~2~7 E-- 4285,08-~-$ 2&-40 E --
BASE UPPER SAND 8151,00 6512.65 1638.4 6411.65 3881,?? S 1738.38 E 433?,03 S 26 32 E
TOP LOWER SAND 82??.00 6640,67 1658.3 653?.67 3753,15 S 175~,57 E 4412,18 S 26 22 E
BASE I_OWER SAND 83~5,00~ ~724,11 l&7-O,~ ~F.~3~ll__3?z~8,-742-.~~8-~-*~4~%~$-2~-1~-E .......... -~
....Eastman
Whipstocl
A P~"TR(')I ANF COMPANY
Eastman
Whipstock
A PETROLANE COMPANY
ARCO 0il and Gas
COMPANY
Kuparuk D-6
WELL NAME
Prudlioe Bay Alaska
LOCATION
DIRECTIONAL DRILLERS/SUB-SURFACE SURVEYORS/INSTRUMENT & TOOL RENTALS/SALES/WORLDWIDE
astman
Whipstock
P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617
TWX 910-881-5066/Cable: EASTCO
March ll, 1980
ARCO 0il & Gas
P.O. Box 1479
Anchorage, Alaska
99510
Well Number: Kuparuk D-6
Location: Prudhoe Bay, Alaska
Type of Survey: Magnetic Multishot
Date: March 9, 1980
Method of Computation: Radius of Curvature
Surveyor: Max Lund
Job Number: A380S0269
Attn: Bob Hines
Dear Mr. Hines;
I am enclosing the original and one copy of the
Magnetic Multishot Survey run on the above mentioned
well.
We wish to take this opportunity to thank you for
calling on our services and trust that we may continue
to serve you in the future.
Sincerely,
J'~~m Turna g e
District Operations Manager
JT/cw
rh,,.~,,-,h,.,,n ¢,1 i"%r,llr~rc/% ,h-q, ,r'fn("P RI ~rvPvors/Instn ]ment& Tool Rentals/Sales/Worldwide
ARCO OIL & GAS
K'URARUK' [;-6
F'RUDHOE ~-~AY, ALASKA
[~HS 9 MARCH 80
SURVEYOR- MAX LUND
VERTICAL SECTION CALCULATED IN PLANE OF PROPOSAL~'
DIRECTION; S 28 [mEG.' '0 MIN, E
RECORD OF SURVEY
RADIUS OF CURVATURE METHOD-
ARCO OIL. g GAS
KLIRARUI~ [;-6
F'RUDIqOE BAY, ALASKA
COMPUTATION
TIME DATE
00:35:07 00--00
PAGE NO. 1
i
MEASURED DRIFT
DEPTH
FEET
DRIFT
ANGLE DIRECTION LENGTH
D M D F E E T
O. 0 0
115. i 0
07. 0 30
,:99. 0 0
39].. 0 15
TRUE
COURSE VERTICAL VERTICAL R E C T A N G U L A R
DEPTH SECTION
FEET FEET
0 O.
S 77 W 115.
N 79 W 92,
0 92.
N 24 W 92,
C L 0 S U R E DOGLEG
C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT~
FEET FEET D bi DG/100F]
0o00 0.00 0.00 0.00 0,00 0 0 0.00
114.99 -0.26 0.23 $ 0.98 W 1.00 S 77 0 W 0,87
206.99 -0.80 0.25 S 2.17 W 2.19 S 83 31W 0.63
390.98 -1.25 0.01 N 2.65 W 2,65 N 89 44 W 0.27
~.eg. 0 0 0 92.
575. 0 45 N 26 E 92.
667. 0 30 N 34 W 92.
759. 0 0 0 92.
851. 0 30 S 87 W 92,
482.98 -1.45 0.20 N 2.73 W 2.74 N 85 54 W 0.27
574.98 -1.81 0.74 N 2.46 W 2.57 N 73 22 W 0.82
666.98 -2.68 1.69 N 2.53 W 3.04 N 56 15 W 0.72
758,97 -3.08 2.02 N 2,76 W 3.42 N 53 42 W 0.54
850,97 -3.25 2.00 N 3.16 W 3.74 N 57 36 W 0.54
943. 0 45
1035. i 15
1127. 3 0
1219. 5 15
1311. 8 0
S 66 W
S 8 W
S 22 E
S 37 E
S 38 E
92, 942.97
92. 1034.95
92',-- 1126.89
92. 1218.64
92, 1310.02
-3.50 1.77 N 4o13 W 4.49 N 66 47 W 0.36
-2.85 0.54 N 5.05 W 5.08 N 83 52 W 1.16
0,30 2,80 S 4,64 W 5.42 S 58 51 W 2.19
6.89 8,55 S 1.39 W 8.66 S 9 15 W 2.69
17.36 16.97 S 5.07 E 17.71 S 16 3~ E 2.99
1403. 11 0 S 35 E
1495. 14 30 S 34 E
L587. 18 0 S 33 E
~79. 21 30 S 33 E
~,~.71. 25 0 S 35 E
92. 1400.75
92. 1490.46
92. 1578.78
._
92. 1665.35
92. 1749.87
32.38 29.17 S 14,10 E 32.40 S 25 48 E 3.30
52.55 45,90 S 25.60 E 52.56 S 29 9 E 3.81
78.17 67,37 S 39.80 E 78.25 S 30 35 E 3.82
109.13 93.43 S 56.73 E 109.31 S 31 16 E 3.80
145,24 123.54 S 77.04 E 145.59 S 31 57 E 3.90
1863. 28 0 S 36 E
1955. 31 0 S 35 E
2047. 34 30 S 33 E
2139. 36 0 S 31 E
2231. 39 0 S 29 E
92. 1832.19
92. 1912.25
92. 1989.62
92. 2064.75
92. 2137.73
185,94 156.95 S 100,87 E 186.57 S 32 44 E 3.30
230.85 193.83 S 127.18 E 231.83 S 33 16 E 3.30
280.33 235.08 S 155.00 E 281.58 S 33 24 E 3.98
333,30 280.11 S 183.14 E 334.66 S 33 11 E 2.06
389.26 328.60 $ 211.14 E 390.59 S 32 43 E 3.52
2323. 41 45 S 30 E
24~5. 43 0 S 30 E
2507. 43 0 S 28 E
2599. 43 15 S 28 E
269l. 43 0 S 26 E
92. 2207.81
92. 2275.77
92. 2343.06
92. 2410.20
92. 2477.35
448.83 380.47 S -~240.48 E 450.09 S 32 18 E 3.07
510,80 434.16 S 271.48 E 512.06 S 32 i E 1.36
573.53 489.04 S 301.90 E 574.72 S 31 41E 1.48
636.42 544,57 S 331.43 E 637.49 S 31 20 E 0.27
699.30 600.60 $ 359.98 E 700.22 S 30 56 E 1.51
·
,']RCO OIL & GAS
KURARUK D-6
F'E'UDHOE BAT, ALASKA
COMF'UTAI'I ON
TIME [~ATE
00:B5:07 00-'-00
PAGE NO. 2
TRUE
MEASURED [;RIFT [;RIFT COURSE VERTICAL VERTICAL R E C T A N G U L A R C L 0 S U R E DOGLEG
DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION ~ 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT
FEET D M D FEET FEET FEET FEET FEET D H DG/IOOF
J783.
2875.
2938.
2 -6.
PROJECTED
43 ~0 S 27 E 92, 2544.36 762.32 657.02 S 388.11 E 763°08 S 30 34 E 0o~2
42 0 S 29 E 92. 2611.92 824.76 712.15 S 417.42 E 825.47 S 30 23 E 2.20
42 0 S 28 E 6~o 2658.74 866.~1 749,20 S 437.54 E 867,60 S 30 17 E 1.06
42 0 S 29 E 18. 2672.11 878.96 759.78 S 443.28 E 879.64 S 30 16 E
2996. 42 0 S 29 E 40.
FINAL CLOSURE - DIRECTION; ,
DISTANCE;~'
2701.84 905~72 78~.19 S
S ~O'DEGS 1~ HINS 24 SECS~E
906.40 FEET
456.26 E 906.40 S 30 1~ E 0o00
I ,
COMPLETION REPORT
ARCO OIL b GAS
GYROSCOPIC SURVEY
RADIUS OF CURVATURE METHOD~ ~MP~TION
COMPUTED FOR SDC BY F~ LIN~j~Y ~ AS~C
30 OCT 80
KUPARUK D-6
KB ELEV 105 FT,
JOB NO 4470
~]' RECORD OF SURVEY " /
ALL CALCULATIONS'PERFORMED BY I B M ELECTRONIC COMPU'KER
TRUE
MEAS. DRIFT VERTICAL
DFPTH ANGLE DEPTH
D M
SUB DRIFT
SEA DIREC
DEG.
0 0 0
lO0 0 15 99.99
200 0 30 199.99
300 0 15 299.99
400 0 15 399.99
500 0 15 499,99
600 0 15 599.99
700 0 0 699.99
800 0 15 799.99
900 0 15 899.99
1000 1 0 999.98
0.00 -105.00 N O,OOE
-5,00 NBT.07W
94.99 N70.20W
194.99 S82.75W
294.99 S51.70W
394.99 S30.33E
494.99 S74.57E
594.99 N27,60W
694.99 N24.65W
794,99 N84,70W
894,98 S26,75E
1100 2 45 1099.92 994.92 S22.78E
1200 5 0 1199.69 1094.69 S32.82E
1300 8 30 1298.98 1193.98 S34,32E
1400 11 45 1397.41 1292.41 S31.83E
1500 15 0 1494.68 1389.68 S29.42E
1600 19 15 1590.23 1485.23 S28.48E
1700 23 0 1683.49 1578,49 S28.53E
1800 27 0 1774.10 1669.10 S32.12E
1900 30 15 1861.87 1756.87 S31.60E
2000 32 45 1947.12 1842.12 S29.03E
2100 35 45 2029,77 1924,77 S26,40E
2200 38 30 2109,50 2004.50 S25.55E
2300 42 0 2185,81 2080.81 S25,25E
2400 43 15 2259,39 2154,39 524.75E
TOTAL COORDINATES
0.00 S 0.00 W
O,20 N 0,06 W
0.58 N 0.58 W
0.65 N 1,23 W
0,48 N 1,62 W
0,09 N 1.70 W
0.16 S 1.36 W
0.O2 S 1.25 W
0.16 N 1.35 W
0.40 N 1.69 W
0.33 S 2.19 W
3.30 S 0.82 W
9.27 S 2.31E
19.06 S 8,81E
33.79 S 18.40 E
53.69 S 30,19 E
79.45 S 44.44 E
111,11S 61.63 E
147.58 S 82.96 E
188.26 S 108,25 E
233.36 S 134,62 E
283~18 S 160.78 E
337.43 S 187.22 E
395.79 S 214.93 E
457.16 S 243.55 E
CLOSURES
DISTANCE ANGLE
D M S
0.00 S O 0 0 W
0.21 N 18 32 5 W
0.83 N 45 5 34 W
1,39 N 61 56 36 W
1.70 N 73 16 0 W
1.70 N 86 44 40 W
1.37 S 83 13 15 W
1.25 S 88 42 39 W
1,36 N 82 56 47 W
1,74 N 76 26 42 W
2.22 S 81 25 0 W
3.40 S 14 5 9 W
9.55 S 14 2 31E
21.00 S 24 49 15 E
38.48 S 28 34 50 E
61,59 S 29 20 52 E
91.03 S 29 13 9 E
127.06 S 29 1 0 E
L69,30 S 29 20 35 E
217.17 S 29 53 53 E
269.41 S 29 58 44 E
325.64 S 29 35 16 £
385.89 S 29 1 23 E
450.38 S 28 30 13 E
517.99 S 28 2 45 E
DOG LEG
SEVERITY
DEG/IOOFT
0.000
0.250
0.250
0.250
0.134
0.328
0.188
0.250
0.250
0.250
0.751
1,750
2,251
3.500
3.252
3.254
4,251
3.750
4,068
3,253
2.611
3.1~1
2.770
3.503
1.272
SECTION
DISTANCE
0.00
-0.21
-0.76
-1.06
-1.06
-0.72
-0,35
-0,44
-0.~
-1.
-0.50
2.75
9,47
20,97
38.21
61.06
90.27
126.06
167.84
215.00
266.67
322.64
382.83
~47,30
514.92
ARCO KUPARUK D-6
GYROSCOPIC SURVEY
JOB NO 4470
30 OCT 80
RECORD OF SURVEY
ALL CALCULATIONS PERFORMED BY I B ~ ELECTRONIC COMPUTER
TRUE
MEAS, DRIFT VERTICAL
DEPTH ANGLE DEPTH
9 M
SUB DRIFT
SEA DIREC
DEG,
TOTAL COORDINATES
2500 43 30 2332,08 2227,08 S23,47E
2600 44 0 2404,91 2299,31 S22,12E
2700 44 0 2476,25 2371.25 S23.98E
2800 44 0 2548,18 2443,18 S24,80E
2900 42 30 2621,02 2516.02 S23,90E
3000 42 0 2695,04 2590,04 S23,13E
3100 43 0 2768,76 2663,76 S23,37E
3200 43 0 2841,90 2736.90 S23.45E
519.84 S
583.59 S
647.51 S
710.78 S
773,20 S
834.85 S
896.92 S
959,51S
3300 44 0 2914.44 2809.44 S23,72E 1022,59 S
9400 44 0 2986.37 2881.37 S23.40E 1086,27 S
3500 43 45 3058.46 2953.46 S23.08E 1149.95 S
3600 43 45 3130,69 3025,69 S22,78E 1213,64 S
3700 44 0 B202,78 3097.78 S22,53E 1277,60 S
3800 44 0 3274.71 3169.71 S22,62E 1341,74 S
3900 46 30 3345.11 3240,11 S21.38E 1407.58 S
4000 46 30 3413.94 3308.94 S21.50E 1475.10 S
4100 47 0 3482.46 3377,46 S21.30E 1542.92 S
4200 47 0 3550,66 3445,66 S21,42E 1611,03 S
4300 47 0 3618,86 3513.86 S21,55E 1679,08 S
4400 49 0 3685.77 3580,77 S23.58E 1747.70 S
4500 49 0 3751.38 3646,38 S23.73E 1816.83 S
4600 48 45 3817.15 3712.15 S23,80E 1885.77 S
4700 48 30 3883.24 3778.24 S23.97E 1954.38 S
'4800 48 15 3949,67 3844.67 S23,97E 2022,~9 S
4900 48 30 4016,09 3911.09 S24.17E 2090.94 S
5000 48 BO 4082,36 3977,36 S23.93E 2159.33 S
271.60 E
298.39 E
325.59 E
354.27 E
382.52 E
409 · 35 E
436,02 E
463.11 E
490.65 E
518.42 E
545.77 E
572 · 71 E
599,41 E
626.07 E
652.68 E
679.19 E
705.77 E
732.40 E
759.19 E
787.70 E
817.98 E
848.34 E
878.72 E
909,09 E
939 · 58 E
970. lO E
5100 48 15 4148,78 4043.78 S24.00E 2227.64 S 1000,46 E
5200 48 0 4215,53 4110,53 S23,72E 2295,74 S 1030,58 E
CLOSURES
DISTANCE ANGLE
D M S
586.52 S 27 35 7 E
655.45 S 27 4 50 E
724.76 S 26 41 41 E
794.17 S 26 29 35 E
862.65 S 26 19 22 E
929.81 S 26 ? 12 E
997.29 S 25 55 32 E
1065.42 S 25 45 53 E
IID4.2i S 25 37 56 E
I203.64 S 25 30 46 E
1272.89 S 25 23 20 E
I341.98 S 25 I5 44 E
14ii.22 S 25 8 4 E
i480.62 S 25 0 5i E
I551.54 S 24 52 35 E
i623.95 S 24 43 23 E
i696.67 S 24 34 49 E
1769.70 S 24 26 51 E
1842.74 S 24 19 47 E
1917,01 S 24 15 41 E
1992,48 S 24 14 19 E
2067,80 S 24 13 16 E
2142,84 S 24 12 34 E
2217,59 $ 24 12 5 E
2292.34 S 24 ii 49 E
236?.24 S 24 i1 33 E
2441.99 S 24 11 8 E
2516.45 S 24 10 33 E
DOG LEG
SEVERITY
DEG/iOOFT
0,656
0,821
1.292
0,570
1.555
0.807
1,006
0.055
1,008
0.222
0,293
0.207
0.278
0.063
2.584
0.087
0.511
0,088
0.095
2.310
O,i13
0,253
0,268
0,250
0.274
0.180
0.253
0.294
SECTION
DISTANCE
583.54
652.68
722.12
791.52
859.96
927.17
994.71
1062.88
1131.68
1201,11
1339.L
1408.84
1~78.30
1549.31
1621.85
1694.68
1767.82
1840.95
1915.25
1990.68
2065.96
2140.95
22%5.65
2290.34
2365.18
2439.88
2514.29
5300-47 45 4282,61 4177.61 S2B.80E 2363,62 S 1060,47 E
~
2590,61 $ 24 9 50 E
0,254
2688.42
..
AR~O .KUPARUK D-6
GYROSCOPIC SURVEY
JOB NO 447O
RECORD OF SURVEY
ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER
30 OCT 80
·
TRUE
MEAS, DRIFT VERTICAL
DEPTH ANGLE DEPTH
D N~
SUB DRIFT
SEA DIREC
DEG,
TOTAL COORDINATES
5400 47 30 4350.01 4245.01 S23.87E 2431.19 S 1090.32 E
5500 47 30 4417.56 4312.56 S24.00E 2498.58 S 1120.23 E
5600 47 15 4485.28 4380.28 S24.07E 2565.78 S 1150.20 E
5700 47 0 4553.32 4448.32 S24.07E 2632.69 S 1180.09 E
5800 47 0 4621.52 4516.52 S24.03E 2699.48 S 1209.89 E
5900 46 0 4690.36 4585.36 S23.73E 2765.80 S 1239.26 E
6000 45 15 4760.29 4655.29 S23.52E 2831.29 S 1267.90 E
6100 45 0 4830.85 4725.85 S23.40E 2896.30 S 1296.11E
6200 44 0 4902,17 4797,17 S22,75E 2960,78 S 1323,59 E
6300 43 15 4974.56 4869.56 S22.52E 3024.46.S 1350.14 E
6400 42 15 5047,99 4942-99 S21,85E 3087.31 $ 1375,77 E
6500 41 30 5122.45 5017,45 S21.40E 3149.36 $ ~ 1400.37 E
6600 41 0 5197,63 5092,63 S20,43E 3210,95 S 1423,91E
6700 40 0 5273.67 5168.67 S20,13E 3271.87 S 1446.42 E
6800 39 0 5350.84 5245.84 S20.68E 3331.49 S 1468.59 E
6900 38 0 5429.10 5324.10 S21.27E 3389.61 S 1490.88 E
7000 36 45 5508,56 5403.56 S18.85E 3446.63 S 1511.69 E
7100 36 0 5589,08 5484.08 S17.72E 3502,94 S 1530.30 E
7200 35 30 5670.23 5565.23 S17.82E 3558.58 S 1548,13 E
7300 35 0 5751.90 5646,90 S17.50E 3613.57 S 1565.64 E
7400 34 0 5834.31 5729.31 S15.77E 3667.84 S 1581.86 E
7500 33 45 5917,33 5812.33 S14.62E 3721,63 $ 1596.46 E
7600 33 30 6000.60 5895.60 S13.67E 3775.32 S 1610.00 E
7700 32 15 6084.59 5979.59 $12.52E 3828.19 S 1622.29 E
7800 31 30 6169.51 6064.51 S12.13E 3879.78 S 1633.57 E
7900 31 15 6254.88 6149,88 511.72E 3930.72 S 1644.32 E
8000 31 0 6340.49 6235.49 $11.90E 3981,32 S 1654.90 E
8100 31 0 6426.21 6321.21 Sll.70E 4031~,~3 S 1665.44 E
8200 30 30 6512.15 6407.15 S10.92E 4081.87 S 1675.46 E
CLOSURES
DISTANCE ANGLE
D M S
DOG LEG
SEVERITY
DEG/IOOFT
2664.49 S 24 9 17 E
2738.22 S 24 8 56 E
2811,80 S 24 8 45 E
2885.08 S 24 8 38 E
2958.21 S 24 8 30 E
3030.75 S 24 8 7 E
3102.22 S 24 7 25 E
3173.08 S 24 6 32 E
3243.16 S 24 5 11E
3312.13 S 24 3 22 E
3379.98 S 24 1 7 E
3446.67 S 23 58 20 E
3512.51S 23 54 54 E
3577.33 S 23 50 56 E
3640.82 S 23 47 20 E
3703.00 S 23 44 30 E
3763.57 S 23 40 56 E
3822.62 S 23 35 55 E
3880.75 S 23 30 40 E
3938.16 S 23 25 31E
3994.41S 23 19 46 E
4049.59 S 23 13 4 E
4104.29 S 23 5 45 E
4157.75 S 22 57 57 E
4209.66 S 22 50 0 £
4260.?9 S 22 42 3 E
4311.56 S 22 34 15 E
4362.17 S 22 26 40 E
4412.35 S 22 18 59 E
0,253
0,096
0,253
0.250
0.029
1.012
0,757
0,257
1.048
0,758
1.045
0.776
0.651
1.008
1,023
1.025
1,521
0.846
0.501
0.511
1.137
0.434
0,382
1.292
0,758
0,273
0,255
0,103
0.539
SECTION
DISTANCE
2062.25
2735.92
2809.45
Z882.67
2955.75
3028.24
3099.68
3170,52
3240.59
3~09,58
3377.45
3444.20
3510.13
3575.05
3638,6,~%
3700.8
3761.55
3820,74
3879.02
3936.59
3992,99
4048.36
4103.24
4156.90
4208.98
4260,27
4311.18
4361.90
4412.17
ARCO -KUPARUK D-6
GYROSCOPIC SURVEY
JOB NO 4470
RECORD OF SURVEY
ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER
30 OCT 80
·
TRUE
MEAS, DRIFT VERTICAL
DEPTH ANGLE DEPTH
D M
SUB DRIFT
SEA DIREC
DEG,
TOTAL COORDINATES
8300 30 45 6598,20 6493-20 510.77E 4131.90 S 1685,05 E
8400 30 30 6684.25 6579.25 510.93E 4181,93 S 1694.64 E
THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TD
8610 30 30 6865.19 6760.19 510.93E 4286,58 5 1714.85 E
BOTTOM HOLE CLOSURE 4616.87 FEET AT S 21 48 14 E
CLOSURES
DISTANCE ANGLE
D M S
4462.28 S 22 11 10 E
4512.24 S 22 3 33 E
4616.87 S 21 48 14 E
DOG LEG
SEVERITY
DEG/IOOFT
0,253
0,253
0,000
SECTION
D i STANCE
4462.19
~512.20
4616.87
ARCO .KUPARUK D-6
GYROSCOPIC SURVEY
JOB NO 4470
INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS
TRUE
CODE MEASURED VERTICAL TOTAL COORDINATES C L 0 S U R E
NAME DEPTH DEPTH DISTANCE ANGLE
D H S
30 OCT 80
·
SUB
SEA
T KUPARUK 8020 I 6357,63 3991,43 S 1656.87 E
T UP SAND 8042 6376,49 4002,55 S 1659,03 E
B UP SAND 8154 6472.56 4058,95 S 1670.59 E
T LOW SAND 8299 6597.34 4131.53 S 1684.22 E
B LOW SAND 8328 6622,27 4145,98 S 1687.53 E
B KUPARUK 8394 6679.08 4179,07 S 1693,36 E
PLUG BACK 8453 6729.92 4208,42 S 1699,31 E
TD 8610 6865,19 4286,58 S 1714,85 E
4321,66 S 22 32 37 E 6252,63
4332,76 S 22 30 49 E 6271,49
4389.30 S 22 22 16 E 6367,56
4461.63 S 22 10 41 E 6492.34
4476.26 S 22 8 51 E 6517,27
4509.11 S 22 3 28 E 6574.08
4538,~5 S 21 59 17 E 6624.92
4616,87 S 21 48 14 E 6760,19
ARCO .KUPARUK D-6
GYROSCOPIC SURVEY
JOB NO 4470
MEASURFD DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH,
30 OCT 80
TRUE
MEASURED VERTICAL SUB MD-TVD VERTICAL
DEPTH DEPTH SEA DIFFERENCE CORRECTION
TOTAL COORDINATES
205 205. 100 0 0
305 305. 200 0 0
405 405. 300 0 0
505 505. 400 0 0
605 605. 500 0 0
705 705, 600 0 0
805 805. 700 0 0
905 905. 800 0 0
1005 1005. 900 0 0
1105 1105. 1000 0 ~ 0
1205 1205. 1100 0 0
1306 1305. 1200 1 1
1408 1405. 1300 2 1
1511 1505- 1400 5 3
1616 1605. 1500 10 5
1723 1705, 1600 18 8
1835 1805. 1700 29 11
1950 1905. 1800 45 16
2070 2005. 1900 64 19
2194 2105. 2000 89 25
2326 2205. 2100 120 31
2463 2305. 2200 157 37
2601 2405. 2300 196 39
2740 2505, 2400 235 39
2878 2605. 2500 273 38
3013 2705. 2600 308 35
3149 2805, 2700 344 36
3287 2905, 2800 381 37
3426 3005. 2900 421 40
3564 3105. 3000 459 38
3703 3205. 3100 498 ',~ 39
3843 3305. 3200 537 39
3987 3405, 3300 582 45
4133 3505. 3400 628 46
4279 3605, 3500 674 46
0.60 N 0.62
0.65 N 1.25
0.47 N 1,64
0.07 N 1,69
0,16 S 1,34
0.02 S 1.25
0.18 N 1.36
0.40 N 1,71
0.41 $ 2.15
3.52 S 0.73
9.64 5 2,55
19,80 S 9.31
35,16 S 19.22
56.15 S 31.54
84,08 S 46.90
119,17 S 66,00
161,34 S 91,50
210.38 S 121,27
267.76 S 152.86
334.27 S 185.19
411,62 S 222,27
496,56 S 260,83
584,20 S 298,64
673,03 S 336,52
759,90 S 375,74
842.87 S 412,75
927.68 S 449.07
1014.50 S 486.46
1102.80 S 525.44
1190,79 S 562,83
1279.53 $ 600.19
1369.75 S 637,27
1466.50 S 675,29
1565,45 S 714.41
1664.97 S 753.11
ARCO .KUPARUK D-6 GYROSCOPIC SURVEY JOB NO 4470
·
MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA
DEPTH.
~0 OCT
·
8O
TRUE
MEASURED VERTICAL
DEPTH DEPTH
SUB MD-TVD VERTICAL
SEA DIFFERENCE CORRECTION TOTAL
COORDINATES
4429 37Q5,
4581 3805,
4733 3905,
4883 4005.
5034 4105.
5184 4205.
5333 4305.
5481 4405,
5629 4505,
5776 4605,
5921 4705,
6063 4805,
6204 4905.
6541 l 5005,
6476 5105,
6610 5205,
6741 5305,
6869 5405,
6995 5505,
7120 5605,
7243 5705.
7364 5805,
7485 5905.
7605 6005,
7724 6105,
7842 6205.
7958 6305-
8075 6405,
8192 6505.
8308 6605,
8424 6705,
8540 6805,
3600 724
3700 776
3800 828
3900 878
4000 929
4100 979
4200 1028
4300 1076
4400 1124
4500 1171
4600 1216
4700 1258
4800 1299
4900 1336
5000 1371
5100 1405
5200 1436
5300 1464
5400 1490
5500 1515
5600 1538
5700 1559
5800 1580
5900 1600
6000 1619
6100 1637
6200 1653
6500 1670
6400 1687
6500 1703
6600 1719
6700 1735
5O
52
52
5O
51
5O
49
48
48
47
45
42
41
~37
31
28
26
25
23
21
21
2O
19
18
16
17
17
16
16
16
1767,85
1873.01
1976.98
2079.60
2182.73
2284.98
2386.~9
2486,00
2585.23
2683.31
2779,72
2872.42
2963.31
3050,44
5134.?5
5216.96
3296,39
3371,90
3443,98
3513.98
3582.19
3648.51
3713.71
5778.01
3840,69
3901,02
5960.19
4019,~3
4077, 5
4135.88
4193,93
4251.91
796.26 E
841.83 E
888.32 E
933,74 E
980.12 E
1025,49 E
1070.01E
1114.04 E
1158.86 E
1202.63 E
1245,16 E
1285.36 E
1324,61 E
1360,53 E
1393,98 E
1426,09 E
1455.34 E
1483,58 E
1510,20 E
1533,68 E
1555.35 E
i575.90 E
1593.78 E
I610.62 E
1624.95 E
1638.00 E
1650.05 E
1662,27 E
1674,02 E
1685,75 E
1696,75 E
1706.98 E
ARCO ,KUPARUK D-6
GYROSCOPIC SURVEY
·
JOB NO 4470
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH,
TRUE
MEASURED VERTICAL SUB
DEPTH DEPTH SEA TOTAL COORDINATES
1000 999. 894, 0,32 S 2,20 W
2000 1947, 1842. 233,51 S 134,37 E
3000 2695. 2590, 835.09 S 408.79 E
4000 3413. 3308. 1475.30 $ 678,67 E
5000 4082. 3977, 2159.62 S 969,44 E
6000 4760, 4655, 2831.60 S 1267,19 E
7000 5508. 5403. 3446.83 S 1511,14 E
8000 6340. 6235. 3981.46 S 1654,19 E
30 OCT 80
·
,(
TII N, RIO£~ U.M.
HORIZONTAL VIEW
ARCO OIL & GAS
KUPARUK :-
RADIUS OF CURVATUE
GYRO8COPIO
-'SCALE I"- I000"
NOV 6~ 1960
1200
240O
'2SO0
5600'
40(
ALL DEPTHS SHOWN
ARE TVD
-r
800 - ' "'
1600
SURFACE LOCATION IS
363' SNL~ 600' WEL, SEC. 25
_TIIN~ RiOE~
$~00
3600
4400
48
.
. ,.
' 5P-O0
VERTICAL SECflON -
ARCO OIL & GAS
KUPARUK ?~D-6 :"
R ADI U8 OF CURATURE
~ GYROSCOPIC -
SCALE I"= I000'
'"'NOV 4, 19'80 "-
~ ~
ALL DEPTS'8 SHOWN
ARE TVD
6000
~" 6400
CIi ITIi IIC
KUP,~RUK D.6
RADIUS OF CURVATURE
COMPLE. ION GYRO
DIRECTIONAL SURVEY REPORT
RECEIVED
NOV 2 8 1980
Alaska 0il & Gas Cons. Commission
Anchorage
ORIGINAL
COMPLETION REPORT
ARCO OIL & GAS
GYROSCOPIC SURVEY
RADIUS OF CURVATURE METHOD OF COMPUTATION
COMPUTED FOR SDC BY FM LINDSEY & ASSOC
·
30 OCT 80
I~U~AR UK D- 6_
KB ELEV 105
JOB NO 4470
RECORD OF SURVEY
ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUI~ER
TRUE
MEAS, DRIFT VERTICAL
DFPTH ANGLE DEPTH
D hi
SUB DRIFT
SEA DIREC
DEG,
0 0 0
100 0 15 99.99
200 0 30 199,99
300 0 15 299,99
400 0 15 399,99
500 0 15 499.99
600 0 15 5q9.99
700 0 0 699,99
800 0 15 799.99
900 0 15 899,99
1000 I 0 999,98
0.00 -105,00 N 0.00E
-5.00 N37.07W
94.99 N70,20W
194,99 S82.75W
294.99 S51,70W
394,99 S30,33E
494,99 S74,57E
594,99 N27,60W
694,99 N24,65W
794,99 N84,70W
894,98 S26,75E
1100 2 45 1099.92 994,92 S22.78E
1200 5 0 1199.69 1094,69 S32.82E
1300 8 30 1298,98 1193,98 S34.32E
1400 11 45 1397,41 1292,41 S31,83E
1500 15 0 1494.68 1389.68 S29,42E
1600 lO 15 1590,23 1485.23 S28,48E
1700 23 0 1683,49 1578.49 S28.53E
1800 27 0 1774,10 1669,10 S32,12E
1900 30 15 1861.87 1756.87 $31.605
2000 32 45 1947.12 1842.12 $29.03E
2100 35 45 2029,77 1924,77 S26,40E
2200 38 30 2109,50 2004.50 S25.55E
2300 42 0 2185.81 2080.81 S25.25E
2400 43 15 2259,39 2154,39 S24.75E
TOTAL COORDINATES
0.00 S 0.00 W
0.20 N 0,06 W
0.58 N 0,58 W
0.65 N 1.23 W
0.48 N 1.62 W
0.09 N 1.70 W
0.16 S 1.36 W
0.02 S 1.25 W
0.16 N 1.35 W
0.40 N 1,69 W
0.33 S 2.19 W
3.30 S 0.82 W
9.27 S 2.31 E
19.06 S 8.8i E
33.79 S 18.40 E
53,69 S 30.19 E
79,45 S 44.44 E
111,11 S 61.63 E
147.58 S 82,96 E
188,26 S 108,25 f
233.36 S 134.62 E
283.18 S 160.78 E
337,43 S 187.22 E
395,79 S 214.93 E
457.16 S 243.55 E
CLOSURES
DISTANCE ANGLE
D M S
O.00 S 0 0 0 W
0.21 N 18 32 5 W
0.83 N 45 5 34 W
1,39 N 61 56 36 W
1.70 N 73 16 0 W
1.70 N 86 44 40 W
1.37 S 83 13 15 W
1.25 S 88 42 39 W
1,36 N 82 56 47 W
1,74 N 76 26 42 W
2.22 S 81 25 0 W
3.40 S 14 5 9 W
9.55 S 14 2 31 E
21.00 S 24 49 15 E
38.48 S 28 34 50 E
61,59 S 29 20 52 E
91,03 S 29 13 9 E
127,06 S 29 1 0 [
169,30 $ 29 20 35 E
217.17 S 29 53 53 E
269.41 S 29 58 44 E
325,64 S 29 35 16 E
385,89 S 29 1 23 E
450.38 S 28 30 13 E
517.99 S 28 2 45 E
DOG LEG
SEVERITY
DEG/iOOFT
0,000
0.250
0.250
0,250
0.134
0.328
0,188
0.250
0.250
0.250
0.751
1.750
2,251
3.500
3,252
3.254
4,251
3.750
4,008
3,253
2.611
3,131
2.770
3.503
1.272
SECTION
DISTANCE
0.00
-0.21
-0.76
-1.06
-1.06
-0.72
-0.35
-0."~
-1,b~
-0.50
2.75
9,47
20.97
38.21
61.06
90.27
126.06
167.84
215.00
206.67
~22.64
382.~3
~47,30
b14.92
ARCO KUPARUK D-6
GYROSCOPIC SURVEY
JOB NO 4.470
30 OCT 80
RECORD OF SURVEY
ALL CALCULATIONS PERFORMED BY I B ~ ELECTRONIC COMPUTER
TRUE
MEAS. DRIFT VERTICAL
DEPTH ANGLE DEPTH
SUB DRIFT
SEA DIREC
DEG,
TOTAL COORDINATES
2500 43 30 2332,08 2227.08 S23,47E
2600 44 0 2404.31 2299,31 S22.I2E
2700 44 0 2476.25 2371.25 S23.98E
2800 44 0 2548,18 2443.18 S24,80E
2900 42 30 2621.02 2516.02 S23,90E
3000 42 0 2695,04 2590,04 S23,13E
3100 43 0 2768,76 2663,76 S23,37E
3200 43 0 2841,90 2736,90 S23,45E
519.84 S 271.60 E
583.59 S 298.39 E
647,51 S ~'.325.59 E
710-78 S 354.27 E
773.20 S 382.52 E
834.85 S 409.35 E
896.92 S 436,02 E
959.51 S 463,11 E
3300 44 O 2914.44 2809.44 S23,72E 1022.59 S
3400 44 0 2986.37 2881,37 S23.40E 1086,27 S
3500 43 45 3058.46 2953.46 S23.08E 1149.95 S
3600 43 45 3130.69 3025.69 S22.78E 1213.64 S
3700 44 0 3202,78 3097,78 S22,53E 1277,60 S
3800 44 0 3274.71 3169.71 S22,62E 1341.74 S
3900 46 30 3345.11 3240.11 S21,38E 1407,58 S
aO00 46 30 3413,94 3308,94 S21,50E 1475,10 S
4100 47 0 3482,46 3377,46 S21.30E 1542.92 S
4200 47 0 3550.66 3445.66 S21.42E 1611.03 S
4300 47 0 3618.86 3513.86 S21,55E 1679,08 S
4400 49 0 3685.77 3580.77 S23.58E 1747.70 S
4500 49 0 3751.38 3646.38 S23.73E 1816.83 S
4600 48 45 3817,15 3712,15 S23,80E 1885,77 S
4700 48 30 3883.24 3778.24 S23.97E 1954.38 S
4800 48 15 3949,67 3844,67 S23,97E 2022,69 S
4900 48 30 4016,09 3911.09 S24,17E 2090,94 S
5000 48 30 4082,36 3977.36 S23,93E 2159,33 S
490.65 E
518.42 E
545.77 E
572.71 E
599.41 E
626.07 E
652.68 E
679.19 E
705 · 77 E
732.40 E
759 · 19 E
787.70 E
817.98 E
848.34 E
878 · 72 E
909,09 E
939 · 58 E
970 · 10 E
5100 48 15 4148.78 4043.78 524,00E 2227.64 S 1000,46 E
5200 48 0 4215,53 4110,53 S23,72E 2295,74 S 1030,58 E
CLOSURES
DISTANCE ANGLE
D M S
586.52 S 27 35 7 E
655.45 S 27 4 50 E
724.76 S 26 41 41 E
794.17 S 26 29 35 E
862.65 S 26 19 22 E
929.81 S 26 7 12 E
997.29 S 25 55 32 E
1065.42 S 25 45 53 E
1134.21 S 25 37 56 E
1203.64 S 25 30 46 E
1272.89 S 25 23 20 E
1341.98 S 25 15 44 E
1411,22 S 25 8 4 E
1480.62 S 25 0 51 E
1551.54 S 24 52 35 E
1623.95 S 24 43 23 E
1696,67 S 24 34 49 E
1769.70 S 24 26 51 E
1842.74 S 24 19 47 E
1917,01 S 24 15 41 E
1992.48 S 24 14 19 E
2067.80 S 24 13 16 E
2142.84 S 24 12 34 E
Z217,59 $ 24 12 5 E
2292.34 S 24 11 49 E
2367.24 S 24 li 33 E
2441.99 S 24 11 8 E
2516.45 S 24 10 33 E
DOG LEG
SEVERITY
DEG/IOOFT
0.656
0.821
1-292
0.570
1.555
0.607
1.006
0,055
1,008
0.222
0.293
0.207
0.278
0.063
2.584
0.087
0.511
0.088
0.095
2.310
0.113
0.253
0.268
0,250
0.274
0.180
0.253
0.~94
SbCTION
DISTANCE
652,68
722.12
791.52
859.96
927.17
994.71
1062,88
1131.68
1201.~,,~
1270.
1339,5~
1408.84
1~78.30
1549.31
1621.85
1694.68
1767.82
1840.95
1915.25
1990.68
2065.96
2140.95
2215,65
2290,34
2305.18
2439.88
2514.29
5300 47 45 4282.61 4177.61 S23.805 2363.62 S 1060.47 E
2590.61 $ 24 9 50 E
0.254
2588 .z+2. ,
AP~O
KUPARUK
D-6 GYROSCOPIC SURVEY JOB NO 4470
3O OCT 80
RECORD OF SURVEY
ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER
t"EAS, DRIFT
DEPTH ANGLE
P M
5400 47 30
5500 47 30
5600 47 15
5700 47 0
5800 47 0
5900 46 0
6000 45 15
6100 45 0
62 O0 44 0
6300 43 15
6400 42 15
6500 41 30
6600 41 0
6700 40 0
6800 39 0
6900 38 0
7000 36 45
7100 36 0
7200 35 30
7300 35 0
7400 34 0
750O 33 45
7600 33 3O
7700 32 15
7800 31 30
7900 31 15
8000 31 0
8100 31 0
8200 30 30
TRUE
VERTICAL SUB DRIFT TOTAL COORDINATES C L 0
DEPTH SEA DIREC DISTANCE
DEG,
4350.01 4245.01 523.87E 2431.19 S 1090,32 E 2664.49
4417.56 4312.56 S24.00E 2498.58 S 1120,23 E 2738.22
4485,28 4380,28 S24,07E 2565,78 S 1150,20 E 2811,80
4553,32 4448,32 S24,07E 2632,69 S 1180,09 E 2885.08
4621,52 4516.52 S24,03E 2699.48 S 1209,89 E 2958,21
4690,36 4585,36 S23,73E 2765,80 S 1239,26 E 3030,75
4760,29 4655,29 S23.52E 2831,29 S 1267,90 E 3102.22
4830,85 4725.85 S23.40E 2896,30 S 1296,11E 3173,08
4902,17 4797,17 S22,75E 2960.78 S 1323,59 E 3243,16
4974,56 4869.56 S22,52E 3024.46 S 1350,14 E 3312.13
5047,99 4942,99 S21.85E 3087.31S 1375.77 E 3379.98
5122,45 5017,45 S21.40E 3149,36 S 1400,37 E 3446,67
5197,63 5092.63 S20,43E 3210,95 S 1423,91 E 3512,51
5273,67 5168,67 S20,13E 3271.87 S 1446,42 E 3577,33
5350.84 5245.84 S20.68E 3331.49 S 1468,59 E 3640.82
5429.10 5324,10 S21.27E 3389.61 S 1490.88 E 3703,00
5508.56 5403,56 518.85E 3446,63 S 1511.69 E 3763,57
5589,08 5484.08 S17,72E 3502,94 S 1530,30 E 3822,62
5670.23 5565,23 S17,82E 3558.58 S 1548,13 E 3880.75
5751.90 5646.90 S17.50E 3613,57 S 1565.64 E 3938,16
5834,31 5729.31 S15,77E 3667.84 S 1581.86 E 3994,41
5917,33 5812,33 S14,62E 3721,63 S 1596,46 E
6000,60 5895,60 S13,67E 3775,32 S 1610,00 E
6084,59 5979,59 S12,52E 3828,19 S 1622,29 E
6169,51 6064,51 S12,13E 3879,78 S 1633,57 E
6254,88 6149,88 Sll,72E 3930,72 S 1644,32 E
6340,49 6235,49 Sl1,90E 3981,32 S 1654,90 E
6426,21 6321,21 Sll.70E 4031,73 S 1665.44 E
6512.15 6407,15 S10.92E 4081,87 S 1675.46 E
S U R E S
ANGLE
O M
DOG LEG
SEVERITY
DEG/100FT
524 9 17 E
S 24 8 56 E
524 8 45 E
524 8 38 E
524 8 30 E
524 8 7 E
524 7 25 E
524 6 32 E
S 24 5 ll E
S 24 3 2`) E
S 24 1 7 E
S 23 58 20 E
S 23 54 54 E
S 23 50 55 E
S 23 47 20 E
S 23 44 30 E
S 23 40 56 E
S 23 35 55 E
S 23 30 4O E
S 23 25 31 E
S 23 19 46 E
4049.59 S 23 13 4 E
4104.29 S 23 5 45 E
4157.75 S 22 57 57 E
4209,66 S 22 50 0 E
4260,79 S 22 42 3 E
4311.56 S 22 34 15 E
4362,17 ..% 22 26 4,0 E
4412.35 S 22 18 59 E
0.253
0.096
0.253
0.2.50
0.029
1.012
0.757
0.257
1.048
0.758
1,045
0,776
0,651
1.008
1,023
1.025
1.521
0.846
0.501
0.511
1.137
0,434
0,382
1,292
0.758
0.273
0.255
0,103
0.539
SECTION
DISTANCE~.~
2662.25
2735.92
2809.45
Z882,67
2955.75
3028,24
3099.68
3170.52
3240.59
3309,5d
3377.45
3444.20
3~10.13
3575.05
3638.r-~
3700.c
3761.55
3820,74
3879,02
3936,59
3992,99
4048,36
4103,24
4156.90
420~.98
4260.27
4311.18
4301.90
4412.17
ARCO KUPARUK D-6
GYROSCOPIC SURVEY
JOB NO 4470
3O OCT 80
RECORD OF SURVEY
ALL CALCULATIONS PERFORMED BY I B ~/, ELECTRONIC COMPUTER
TRUE
MEAS. DRIFT VERTICAL
DEPTH ANGLE DEPTH
D M
SUB DRIFT
SEA DIREC
DEG,
TOTAL COORDINATES
8300 30 45 6598,20 6493.20 SiO,7?E 4131,90 S 1685,05 E
8400 30 30 6684.25 6579,25 S10.93E ~181,93 S 1694.64 E
THE FOLLOWING INFOR~IATION IS EXTRAPOLATED TO TD
8617/30 30 6865.19 6760.19 S10,93E 4286.58 S 1714.85 E
ROTTOM HOLE CLOSURE 4616.87 FEET AT S 21 48 14 E
CLOSURES
DISTANCE ANGLE
D M
DOG LEG
SEVERITY
4462.28 S 22 1~ 10 E
~512.24 S 22 3 ~3 E
4616.87 S 21 48 14 E
DEG/iOOFT
0.253
0.253
0,000
SECTION
DISTANCF,~,,,~
4462.19
4m12.20
4616.87
ARCO KUOAm, UK D-6 GYROSCOPIC SURVEY JOB NO 4470
INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS
TRUE
CODE ".lE ASUR E D VERTICAL
NAM[ DEPTH DEPTH
TOTAL COORDINATES
CLOSURE
DISTANCE ANGLE
D M S
30 OCT 80
·
SUB
SEA
T KUPARUK 8020 6357.63
T UP SAND 8042 6376.49
B UP SAND 8154 6472.56
T LOW SAND 8299 6597,34
B LOW SAND 8328 6622.27
B KUPARUK 8394 6679.08
PLUG BACK 8453 6729.92
TD 8610 6865.19
3991,43 S
4002.55 S
4058,95 S
4131.53 S
4145,98 S
4179,07 S
4208.42 S
4286,58 S
1656.87 E
1659.03 E
1670.59 E
1684.22 E
1687.53 E
1693.36 E
1699.31 E
1714.85 E
4321.66 S 22 32 37 E 6252.63
4332.76 S 22 30 49 E 6271.49
4389.30 S 22 22 16 E 6367.56
4461.63 S 22 10 41 E 6492.34
4476.26 S 22 8 51 E 6517.27
4509.11 S 22 3 28 E 6574.08
4538.55 S 21 59 17 E 6624,92
4616.87 S 21 48 14 E 6760.19
ARCO KUPARUK D-6
MFASURFD DEPTH AND
OTHER
GYROSCOPIC SURVEY
DATA FOR EVERY EVEN 100
JOB NO 4470
FEET OF SUB SEA
DEPTH,
3O OCT
·
8O
MEASURED
DEPTH
TRUE
VERTICAL
DEPTH
SUB MD-TVD VERTICAL
SEA DIFFERENCE CORRECTION
TOTAL
COORDINATES
2O
30
40
5O
6O
?0
8O
90
100
110
120
130
140
151
161
172
183
195
2O7
219
246
260
274
287
301
314
328
342
37O
413
42?
205.
305.
405,
505,
605,
705,
805,
905,
1005,
1105,
1205.
1305,
1405.
1505.
1605.
1705,
1805.
1905,
2005.
2105.
2205.
2305.
2a05.
2505.
2605.
2705.
2805.
2905.
3005.
3105.
3205.
3305,
3405.
3505.
3605.
100 0
200 0
300 0
400 0
500 0
600 0
700 0
800 0
900 0
1000 0
1100 0
1200 1
1300 2
1400 5
1500 10
1600 18
1700 29
1800 45
1900 64
2000 89
2100 120
2200 157
2300 196
2400 235
2500 273
2600 308
27OO 344
2800 381
2900 421
3000 459
3100 498
3200 537
3300 582
3400 628
3500 674
0
0
0
0
0
0
0
0
0
0
0
1
1
3
5
8
11
16
19
25
31
37
39
39
38
35
36
37
4O
38
39
39
45
46
46
0.60
0.65
0,47
0.07
0.16
0.02
0.18
0.40
0.41
3.52
9,64
19,80
35,16
56,15
84.08
119.17
161.34
210,38
267,76
334.27
411.62
496.56
584.20
673.03
759.90
842,87
927,68
1014.50
1102,80
1190.79
1279.53
1369,75
1466,50
1565,45
1664,97
N 0.62 W
N 1.25 W
N 1.64 W
N 1,69 W
S 1,34 w
S 1.25 W
N 1.36 W
N 1,71 W
$ 2,15 W
S 0.73 W
S 2.55 E
S 9.31E
S 19.22 E
S 31,54 E
S 46,90 E
S 66,00 E
S 91,50 E
S 121,27 E
S 152.86 E
S 185.19 E
S 222,27 E
S 260,83 E
S 298,64 E
S 336.52 E
S 375.74 E
S 412.75 E
S 449,07 E
S 486,46 E
S 525,44 E
S 562,83 E
5 600,19 E
S 637.27 E
S 675.29 E
5 714,41 E
S 753,11 E
ARCO KUPARUK D-6 GYROSCOPIC SURVEY
MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100
JOB NO 4470
FEET OF SUB SEA
DEPTH,
OCT 80
·
F~EAStJRED
DFPTH
TRUE
VERTICAL SUB MD-TVD
DEPTH SEA DIFFERENCE
VERTICAL
CORRECTION
TOTAL
COORDINATES
4429
4581
4733
4~83
5034
5184
5333
5481
5629
5776
5921
6063
6204
6341
6476
6610
6741
6869
6995
7120
7243
7364
74q5
7605
7724
7842
7958
8075
8192
8308
8424
854O
3705. 3600 724
·
3805, 3700 776
3905. 3800 828
4005. 3900 878
4105- 4000 929
4205, 4100 979
4305. 4200 1028
4405, 4300 1076
4505, 4400 1124
4605, 4500 1171
4705, 4600 1216
4805, 4700 1258
4905, 4800 I299
5005. 4900 1336
5105. 5000 1371
5205. 5100 1405
5305. 5200 1436
5405, 5300 1464
5505. 5400 1490
5605. 5500 1515
5705. 5600 1538
5805. 5700 1559
5905. 5800 1580
6005, 5900 1600
6105, 6000 1619
6205. 6100 1637
6305, 6200 1653
6405, 6300 1670
6505. 6400 1687
6605. 6500 1703
6705, 6600 1719
6805. 6700 1735
50
52
52
50
51
50
49
48
48
47
45
42
41
37
35
34
31
28
26
25
23
21
21
20
19
18
I6
17
17
i6
16
16
1767.85 S
1873.01S
1976.98 S
2079.60 S
2182.73 S
2284.98 S
2386.09 S
2486.00 S
2585.23 S
2683.31S
2779.72 S
2872.42 S
2963.31S
3050.44 S
3134.75 S
3216,96 S
3296,39 S
3371,90 S
3443.98 S
3513.98 S
3582.19 S
3648.51S
3713.71S
3778.01S
3840.69 S
3901,02 S
3960.19 S
4019.23 S
4077,85 $
4135.88 S
4193.93 S
4251.91S
796.26 E
841 · 83 E
888.32 E
933,74 E
980.12 E
1025,49 E
1070.01 E
1114.04 E
1158.86 E
1202.63 E
1245.16 E
1285,36 E
1324,61 E
1360,53 E
1393.98 E
1426.09 E
1455,34 E
1483 · 58 E
1510,20 E
1533,68 E
1555.35 E
i575.90 E
1593.78 E
I610.62 E
i624.95 E
1638,00 E
1650,05 E
1662,27 E
1674,02 E
1685,75 E
1696.75 E
1706,98 E
ARCO KUPARUK D-6
INTERPOLATED VALUES FOR
TRUE
MEASURED VERTICAL
DEPTH DEPTH
EVEN
1000 999. 8
2000 1947. 18
3000 2695. 25
4000 3413, 33
5000 4082. 39
6000 4760. 46
7000 5508. 54
8000 6340. 62
GYROSCOPIC SURVEY
JOB NO 4470
1000 FEET OF MEASURED DEPTH,
SUB
SEA TOTAL COORDINATES
94. 0.32 S 2.20 W
42 · 233 · 51 S 134.37 E
90. 835.09 S 408.79 E
08. 1475.30 S 678.67 E
77. 2159.62 S 969.44 E
55. 2831.60 S 1267.19 E
03. 3446.83 S 1511.14 E
35. 3981.46 S 1654.19 E
30 OCT 80
·
TII N~ RIOE~ U.M.
14
24OO
o_
24
HORIZONTAL VIEW
ARCO OIL 81 GAS
KUPARUK D-6
RADIUS DF CURVATUE
GYROSCOPIO
SCALE I"= I000"
NOV 5~ 1980
2800
3200
f~ SGoo
4000
'1
ALL DEPTHS SHOWN
ARE TVD
4400
4800
5200
5600
6000
6400
.6800
TVD = 6865'
TMD = 8610'
40~
8OO
1200-
SORFACE LOCATION IS
:56:5' SNL, 600' WEL, SEC. 2:5
TIIN, RIOE, U.M.
VERTICAL SECTION
ARCO OIL 8~ GAS
KUPARUK D-6
RADIUS OF CURATURE
GYROSCOPIC
SCALE I"= I000'
NOV 4~ 1980
16o(~,~
2ooo-~
24oo-~ _ _
2800 -~
"'~ '3~'°° 36oo~ ALL DEPTHS SHOWN
ARE TVD
4000~,. " .~ _ ''----'T----. ~--""
_ 4400 '~ -
.... 6000 -~
TVD =6865'
6so0 TMD = 8610'
Check Form
for timely compliance with our regulations.
Operator, Well ~ame and Number
Completion Report
Reports and Materials to be received by: /f--/~-
Date
Well History
Samples
Required
Yes
Mud Log
Core Chips
Core Description
Registered Survey Plat
Inclination Survey
Directional Survey
Drill stem Test Reports
Production Test Reports
Logs Run
Digitized Log Data
Yes
Date Received
Remarks
December 1, 1980
Mr. P. A. Van Dusen
District Drilling Engineer
Arco Oil and Gas Comapny
P.O. Box 360
Anchorage, Alaska 99510
Re:
DS
P.B.U. DS 11-14
P. B.U._~-~4
Kuparu ~_?3
Kuparuk D-7
K uparuk E-7
Kuparuk E-8
We have checked our files and do not find Completion Reports
(form 10-407) on the subject wells. ~';e understand the report
on P.B.U. DS 2-17 was waiting for a final directional survey to
be received. Available information indicates the other wells
have been drilled and were completed as unperforated oil wells
during October, 1980.
Please check your transmittals to confirm that the forms have
been sent. If they have not, send the appropriate 10-407 forms
at this time. Please let us know if it is necessary to delay
the final reports until receipt of directional surveys on any
of the wells.
Sincerely,
John A. Levorsen
Petroleum Geologist
JAL ~ mm
NORTH SLOPE DISTRICT ENGINEERING
TRANSMITTAL #__~_~__~
TO: ~V U~ AI~
FROM' Jerry J. Pawelek/Leo Lash
WELL ,A E' L3-
Transmitted herewith are the following for the subject well'
DATE SCALE XEROX
lO-SD'SD
BHC Sonic/Gamma Ray Log
Cement Bond Log/VDL
Compensated Formation Density Log
Compensated Neutron-Formation Density
Compensated Neutron Log
Core Analysis - Interval
Core No.
Core Description (SWC) - Interval
Core Description (Conv.) - Core No.
Directional Survey - Gyro
Single Shot
Multi-shot
Drill Stem Test - Test No.
Dual Induction Laterolog
Formation Density Log
Formation Density Log/Gamma Ray
Spectral og
TVD-DIL
Differential Temperature Log
Spinner Survey
Fluid Density
Casing Collar Log
Perforating Record
Neutron Lifetime Log
Carbon-Oxygen Log
BL
SEPIA LINE FILM
- __
£OMM
COMM
--
RES ENG
1 ENG
--_
2 ENG
4
-- 1 q-Or
'FILF:
RECEIPT ACKNOWLEDGED FOR'
DATE'
PLEASE RETURN RECEIPT TO'
RECEIVED
NOV 2 8 1980
Alaska Oil & Gas Cons. Commission
ARCo Oi 1 a~Ct~asgeCompany
Attn- Mr, Leo Lash
P.O. Box 360 - Rm. #311-FAB
Anchorage, AK 99510
TO'
NORTH SLOPE DISTRICT ENGINEERING
TRANSMITTAL # &/~
lZ;I ~EoL
~/~/ ~/~, ~ ~ ~' FROM' Jerry O. Pawelek/Leo La~STAT
InLF
Transmitted herewith are the following for the subject well'
BL
DATE SCALE XEROX SEPIA LINE FILM
IC>/~ BHC Sonic/Gamma Ray Log
Cement Bond Log/VDL
.10//~ Compensated Formation Density Log ~"
Io/~, Compensated Neutron-Formation Density
Compensated Neutron Log
Core Analysis - Interval
Core No.
Core Description (SWC) - Interval
Core Description (Conv.)- Core No.
Directional Survey - Gyro
Single Shot
Mul ti -shot
Drill Stem Test - Test No.
ID~(~ Dual Induction Laterolog
Formation Density Log
Formation Density Log/Gamma Ray
Spectral og
TVD-DIL
Differential Temperature Log
Spinner Survey
Fluid Density
Casing Collar Log
Perforating Record
Neutron Lifetime Log
Carbon-Oxygen Log ^ ~
RECEIPT ACKNOWLEDGED FOR'
DATE'
ASE RETURN RECEIPT TO'
ARCo Oil and Gas Company
Attn- Mr. Leo Lash
P.O. Box 360 - Rm. #311-FAB
Anchorage, AK 99510
NORTH SLOPE DISTRICT ENGINEERING
TRANSMITTAL
FROM: Jerry J. Pawelek/Leo Las
WELL NAME'
Transmitted herewith are the following for the subject well'
DATE SCALE XEROX
· BHC Sonic/Gamma Ray Log
Cement Bond Log/VDL
Compensated Formation Density Log
Compensated Neutron-Formation Density
Compensated Neutron Log
Core Analysis - Interval
Core No.
Core Description (SWC) - Interval
Core Description (Conv.) - Core No.
Directional Survey - Gyro
$/~.~0 ~ Single Shot .~.
Multi-shot
Drill Stem Test - Test No.
Dual Induction Laterolog
Formation Density Log
Formation Density Log/Gamma Ray
Spectral og
TVD-DIL
Differential Temperature Log
Spinner Survey
Fluid Density
Casing Collar Log
Perforating Record
Neutron Lifetime Log
Carbon-Oxygen Log
. I 3 ENg .. I
-Ii4-ENG
I
"1 3 GEO~
--T-STAT TEC
r--T-,! $_'rAT TEC,
-FILF;
~ _
BL
SEPIA LINE FILM
RECEIPT ACKNOWLEDGED FOR.
DATE-
~PLEASE RETURN RECEIPT TO-
ARCo Oil and Gas Company
Attn- Mr. Leo Lash
P.O. Box 360 - Rm. #311-FAB
Anchorage, AK 99510
ARCO Oil and Ga~ ,mpany
Alaska D~stt~.
Post Office Bo× 360
Anchorage, Alaska 99510
Telephone 907 2?? 563~
October 7, 1980
Mr. Hoyle Hamilton
State of Alaska
Alaska Oil and Gas
Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject~:_ up~aruk~_D~(Permit No. 79-96)
.... Kuparuk E-7 (Permit No. 80-80)
DS 11-14 (Permit No. 80-73)
DS 17-4 (Permit No. 80-85)
Dear Sir'
Enclosed please find our Monthly Reports of Drilling
Operations for the subject wells.
Very truly yours,
P. A. VanDusen
District Drilling Engineer
PAV'sp
Enclosures
ARCO Oil and Gas Company is e Du,~s~c ' -~,,':t, '~ , ' , e ~ ~ '
Form No 10404
REV 3-1-70
,f
SUBMIT IN DUPLICATE
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMITTEE
MONTHLY REPORT OF DRILLING
AND WORKOVER OPERATIONS
5. AP! NUMERICAL CODE
50-029-20418
6. LEASE DESIGNATION AND SERIAL NO
ADL 25650
2. NAME OF OPERATOR 8, UNIT FARM OR LEASE NAME
Atlantic Richfield Company Kuparuk 25650
3. ADDRESS OF OPERATOR 9. WELL NO.
P.O. Box 360, Anchorage, Alaska 99510 D-6
4 LOCATION OFWELL
363' FNL, 600' FEL, Sec 23, TllN, RIOE, UM
10. FIELD AND POOL, OR WILDCAT Prudhoe Bay
Field/ Kuparuk River Oil Pool
11 SEC. T. R. M. (BOTTOM HOLE OBJECTIVE)
Sec 24, TllN, RIOE, UM
12. PERMIT NO
79-96
13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USEDt PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE
AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS.
Report of operations for September, 1980
Resume Drillin~ Operations 0600 hrs, 9/27/80. Move rig over well. ND tree.
NU BOP stack and test same. Circulate and displace well w/new oil base mud.
Drld out 10-3/4" csg and newS~3/4"hole to 3016'. Test fm to 10.5 ppg EMW.
As of 9/30/80, prepare to drill out below 10-3/4" csg.
0OT 1 0
SIGNED, . TITLE District Drilling Eng. DATE
NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed ,n duplicate with the
oil and gas conservation comm,ttee by the 15th of the succeeding month,unless otherwise directed.
~ WE LL 5
I W~LL ~1 Y = 5,959,904.19
!
LAT 70 1 ~O3.&72"
-~ GOI' i ~l 49°30 '
< [ LONG = 1 36. 426"
I : '
~; ; >~l WELL ~2 Y = 5,959,784.20
'O1~ X = ~60,485.20
~[ LAT 70~18'O2.492''
I
j < , ~ LONG ~ 149°30'36.424'I,
!' :>-~ WELL , 3 Y = 5 ,959,664.22
I -
i D$~ -~ ~ ' -- LONG = 149°30~36.42
,Ti ~:~ (TII~ l~lO~,U~.) WELL ~* Y = 5,959,544.23
~ D, X = ~60.487 32
~, D~ ,, , LAT = 70~18'O0.~31''
~ LONG 149°30' 36.4~8~
I
<PS~ ~ , WELL 5 Y = 5 ~59,424.25
! ~ x = 60 488.38
~ > , ~ LAT 70 17~58.951''
I
~ LONG = 149°30'36.415'
, , WELL -6 Y = 5,959,304.26
~ I m , . X = 60 489.44
i~ ~ ' ~ LAT = 70 17~57.771''
, Ol~ , > <
i~ LONG = 149°30'36.41 3"
~ ~ ~ WELL ~7 Y = 5,959,184.28
D~ ~, X = ~60 490.51
~W~T ~AK~ LAT 70 17156.591''
~ LONG = 149°30'36.409'
I ~ I
: I
WELL ;'8 Y = 5,959,064,29
. X = ~60,491.56
~C~LE. 1"=2OO' ~ LAT = 70~]7'55.4~1"
LONG = 149~30'36.407~
~,~.."' ~'"..~ ~1 HEREBY CERTIFY THAT I AM
~*:'49~ ~
~ .... ~ ......... ~ ........ zz~ _ TO PRACTICE LAND SURVEYING IN
~.~~~~ THE STATE OF ALAS ~ AND THAT
THIS PLAT REPRESENTS AN AS-
g~-' ........ ' ~%~ DETAILS ARE CORRECT AS OF ;
_11 I I I
0.%. D, WELL5 LOCATION5 A -BUILT
· II IIII I II I I II I III
AllantmRichfieldOompany ~ DATE; DRAWING
NORTH AMERICAN PRODUCING DIVISION
ALASKA DISTRICT KUPARUK
ARCO Oil and Gas{
mpany
Alaska D~stnc~
Post Office Box 360
Anchorage Alaska 99510
Telephone 907 277 5637
September 30, 1980
Mr. Hoyle Hami 1 ton
State of Alaska
Alaska Oil and Gas
Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject:~D-6, Permit No. 79-96
Dear Mr. Hamilton:
/
RES E; G -
~ ~N~'
~-1 GEOL
o oy
STAT TFC
1
CONFr'R:
FILF:
Enclosed is a Sundry Notice detailing work to be
done on the above mentioned well.
Very truly yours,
P. A. VanDusen
District Drilling Engineer
PAV/sp
Enclosure
Ref. Cf O1 L-O001
File Cf K 4.93
ARCO Oil and Gas Company ~s a Dials;o,', o~ AIlanh( N,chfl~-hiCompany
Form 10-403
REV. 1o10-73"
Submit "1 ntentlons" in Triplicate /
& "SubSe~luent Reports" in Duplicate
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMITTEE
SUNDRY NOTICES AND REPORTS ON WELLS
(Do not use this form for proposals to drill or to deepen
Use "APPLICATION FOR PERMIT--" for such proposals.)
WELL L.LLJ WELL L.J OTHER
2. NAME OF OPERATOR
Atlantic Richfield Company
3. ADDRESS OF OPERATOR
P.O. Box 360, Anchorage,, Alaska 99510
4. LOCATION OF WELL
At surface
363 FNL & 600' FEL, Sec 23, TllN, R10E, UM
at target
6250 SS, 1320' FWL & 1320' FSL, Sec 24, TllN, RIOE, UM
13. ELEVATIONS (Show whether DF, RT, GR, etc.)
TOP OF PAD = 71'
14.
Check Appropriate Box To Indicate Nature of Notice, Re
APl NUMERICAL CODE
50-029-20418
LEASE DESIGNATION AND SERIAL NO.
ADL 25650
7. IF INDIAN, ALLOTTEE OR TRIBE NAME
8. UNIT, FARM OR LEASE NAME
Kuparuk 25650
i9. WELL NO.
D-6
10. FIELD AND POOL, OR WILDCAT
Prudhoe Ba.y/ Kuparuk River Oil Pool
11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE)
Sec 24, TllN, RIOE
12. PERMIT NO.
79-96
3ort, or Other Data
NOTICE OF INTENTION TO.=
TEST WATER SHUT-OFF ~ PULL OR ALTER CASING
FRACTURE TREAT ~.~ MULTIPLE COMPLETE
SHOOT OR AClDIZE ~ ABANDON*
REPAIR WELL ! J CHANGE PlaN5
(Other)Resume operations
SUBSEQUENT REPORT OF:
WATER SHUT-OFF ~ REPAI RING WELl.
FRACTURE TREATMENT ALTERING CASING
SHOOTING OR AClDIZlNG ABANDONMENT*
(Other)
(NOTE~ Report results of multiple completion on Well
COmpletion or Recompletion Report and Log form.)
15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, includ~ng estimated date of
starting any proposed work.
Kuparuk D-6 was spudded 3-5-80. 13-3/4" hole was drilled to 2996', 10-3/4" csg set
@ 2974' & cmts w/12 ppg Fondu as per orig well plan. Well was displaced w/oil base
mud and tree installed. Rig released and operations suspended 3-12-80 to enable
rig to move to West Sak 15.
We are resuming operations on D-6 and intend to follow the plan as outlined in
the permit. Please note the following changes: 8-3/4" hole to TD instead of
9-7/8" & TD @ 6730' TVD : 8330' MD. All other info (target location, completion
equip, BOP info, etc.) remains unchanged.
Subsequent Work Reported
on Form No./O ,- 9/~.~ Dated/~._~j2_./.~o
hereby certify that the foregoing is true and correct
(This space for State o~) , ~d~
APPROVED aY ~ TITLE COMlvlISSZONZX~
COND,T,ONS OF ~P~OVAL, ,F ~'.' BY dRDER OF T~ COMMISSION
See Instructions On Reverse Side
DATE
Approved Copy
Returned
ALASKA OIL AND GAS CONSERVATION COMMISSION
Hoyle H. Hamiltoni~
Chairman/Comm~ss
Thru= Lonnie C. Smith
Commissioner ~
Ben LeNorman
Petroleum Inspector
September 30, 1980
BOPE test on Arco's Kup-
aruk #D-6, Sec. 23,
TllN, R10E,
Kuparuk River Undefined.
Saturday, September 2?, 1980 - I departed my home at 5~30 am for
a' '6..00 am ShoWup a~d ?~00 am departure via Wien flight %71 for
Deadhorse arriving at 9240 am. Weather= +21°F, blowing snow,
wind 25 mph from the east.
BOPE tests on Kuparuk E-? were completed at midnight, the sub-
je=t of a separate report.
Sunday, September 28, 1980 - BOPE tests on Kuparuk D-6 began at
~"i0.0 Pm :b&t Were su~ndod at 10,15 pm due to problems with the
accumulator system. Investigation revealed inner seals within
~he Shaffer spherical annular preventer had failed. This fail-
ure resulted in accumulator reservoir fluid being pumped into
the well bore and prevented recovery of accumulator pressure to
3000 psi.
Since on site repair of the annular preventer was not pra~ical a
replacement preventer was obtained at Service city. This re-
placement preventer had a bad element which prolonged the delay.
Monday, Sept~r 29,_ 1980- The remote blowout preventer con-
fro1 had two 'pr0blems~ The HCR valve could be closed but could
not be opened from the remote, and the blind rams could be
opened but could not be closed from the remote station. I asked
that these electrical problems be repaired before I left the
location.
Testing resumed at 5..00 pm with the accumulator system exceeding
API specifications. Additionally, repairs were made on the
remote control system and it was demonstrated for me.
I departed Kuparuk airstrip via twin otter at 6=00 pm and ar-
rived at Deadhorse at 6=20 pm. i departed Deadhorse via Wien
flight #10 at 7=20 pm arriving in Anchorage via Fairbanks at
10:00 pm and at my home at 10..30 pm.
In summary, I witnessed successful BOPE tests on Arco's Kuparuk
D-6.
O&G # 4
.4/80
( '
ISTATE OF ALASKA ( /
3J.d~SK~ OIL & GAS CONSERVATION COMMISSION
B .O. P. E. Inspection Report
Operator
Location: Sec ~ T
Drilling Contractor
Date
Representative
Permit #
Set
Rig #/.~_/ Representativ~
Location, General
Well Sign
General Housekeeping
Reserve pit ,
Rig
o/¥
BOPE Stack
Annular Preventer
Pipe Rams
Blind Rams
Choke Line Valves
H.C.R. Valve
Kill Line Valves
Check Valve
Test Pres sure
ACCUMULATOR SYSTEM
Full Charge Pressure ~ ~9 psig
Pressure After Closure //~-- psig
200 psig Above Precharge Attained: min.~"sec
Full Charge Pressure Attained: ~" min ~ sec
N2 ~7~. ~~. ~1~
Controls: Master ~/~
Remote O/~ Blinds switch cover~
Kelly and Floor Safety Valves
Upper Kelly. Test Pressure
Lower Kelly Test Pressure
Ball Type ~%)/~ Test Pressure
Inside BOP,, .~)/~, Test Pressure
Test Pressure
Choke Manifold
No. Valves
No. flanges
Adjustable Chokes
Hydrauically operated choke
Test Results: Failures ~0 Test Time ~ hrs.., ~
Repair or Replacement of failed equipment to be made within days and
Inspector/Commission office notified.
Distribution
orig. - AO&GCC
cc - Operator
cc - Supervisor
Inspector /.~ ~~~-
September 24, 1980
Mr. Hoyle Hamilton
State of Alaska
Division of Oil & Gas
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject' As-Built Survey Plats
Dear Sir'
In an effort to Insure that your files are complete, we
copies of our well location as-built survey plats for all wells
permitted thus far in 1980, excluding those included in our original
drilling permit applications.
Very truly yours,
P. A. VanDusen
District Drilling Engineer
PAV/JBK/jh
Att achments
ARCO Oil and Gas ( /~pany
North Slope L,,otrlct
Post Office Box 360
Anchorage, Alaska 99510
Telephone 907 277 5637
April 11, 1980
Hoyl e Hami 1 ton
State of Alaska
Alaska Oil & Gas
Conservation Commission
3001 Porcupine Drive
ANchorage, Alaska 99501
~:S ENG !
~- FN?~~,,
-'",tG- I
1.., ')~OL
"~ GEOL
- \T TEC
Subject' DS 6-11, Permit No. 79-110
DS 14-8, Permit No. 78-67
D-6, Permit No. 79-96
Dear Sir:
Enclosed please find Monthly Reports for the above-men-
tioned wells.
Very truly yours,
P.A. VanDusen
District Drilling Engineer
PAV/ls
Enclosure
ARCO Oil and Gas Company Is a Division of AtlanhcR~chfleldCornpany
R! S 3-1 '0
SLBMIT IN DUPLICATL
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMITTEE
MONTHLY REPORT OF DRILLING
AND WORKOVER OPERATIONS
WELL %YELL OTllER
2. NAME OF OPERATOR
Atlantic Richfield Company
3. ADDRESS OF OPERATOR
P.O. Box 360, Anchorage, Alaska
4. LOCATIO\ OF ~nELL
363' FNL & 600' FEL
99510
SEC 23, T11N, RIOE, UM
5. APl NL MERICAL CODE
50-029-20418
6. LEASE DESIG\¥IION AND SERIAL NO.
ADL 25650
7. IF INDI AN'ALOTTEE OR TRIBE N~ME
8. L'~IT FARM OR LE4SENbME
Kuparuk 25650
9. ~ELL NO.
D-6 (xx-24-11-10)
i 10. FLF~ r~ A.N,D POOL. C~R .WILI~C_ AX
'Prudhoe Ba¥~ Kuparuk River Oil
11. SEC. T ~ M. (BOSOM ilOLE Pool
OBJE~I~ E)
SEC 24, T11N, RIOE, UM
12. PERMIT NO.
79-96
13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN ttOLE SIZE, CASING AND CEMENTING JOBS INCLLDING DEPTtl SET A\'D VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TP._&CKED ttOLE
AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS.
Report of Operations for Honth of Harch, 1980
Spudded well @1200 hrs, 3/5/80. Drld 13-3/4" hole to 2996'. Ran 10-3/4" 45.5 #K-55
csg w/shoe @2974'. Cmtd csg w/1600 sx Fondu & 250 sx Arcticset II cmt. Set pkoff.
NU diverter. Made cleanout trip w/9-7/8" bit. Displ w/oilbase mud. ND diverter,
NU wellheads. Tstd pkoff, ok. NU tree. Released rig @ 1100 hrs., 3/11/80. Well
will be suspended until mid-1981.
SIGNED _-~, n, _. _ TITLE District. t)ri!!ing Fng. D~,TE fl~,or';! /4. /f,~O
NOTi:-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duphcate with the
oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed.
DATE: ~/7--~s ~ WELL
lransm~tsed herewith are the foll~~~ DATE
Jerry J. Pawel ere Woodring
NAME:
subject wel 1'
SCALE XEROX
SEPIA BI. LINE
~HC Sonic/Gamma Ray Log
Cerent Bond Log/VDL
Compensated Formation Density Log
Compensated Neutron-Formation Density
Compensated Neutron Log
Core Analysis - Interval
Core No.
Core Description (SWC) - Interval
Core Descrip. tion (Conv.) - Core No.
Directional Survey- Gyro
Single Shot
Multi-shot
Drill Stem Test - Test No.
Dual Induction Laterolog
Formation Density Log
Formation Density Log/Gamma Ray
Location Plat
TVD-DIL
Differential Temperature Log
Spinner Survey
Fluid Density
Casing Collar Log
Perforating Record
Nuclear F1 o-log
RECEIPT._
ACK!~OWLEDGED FOR'
DATE:
rr- , ,~
R~TUR,, RECEIPT TO'
ARCo Oil and Gas Company
Attn: Mr. Pete Woodring
P.O. Box 360- Rm. =449
Anchorage, AK 99510
1 / 10/,.',0
Hovend~er 30, 1979
Ret Xuparuk 25650 well No. D-6
ARCO Otl and Gas Company
Pernit Ho. 79096
Sur. LOG. s 363' I,fL & 600* FEL, Sec 23, llx, R10E, uN
Bottomhole Loc.~ 1320' FWL & 1320' FSL, Sec 24, T~I]~, R10E, UM
Hr. J. A. VanD~sen
District DEil ling Bngineer
ARCO Oil and Gas Ccmpan~
P. O. Box 360
Anchorage, Alaska 99S10
!~ear Hr. VanDusen~
Xnolosed is the approved application for permit to drill the
above referenced vel I.
Well samples, core chips and a mud log are not required. A
directional survey is required. ~£ available, a tape contain-
ing the digitimed ~.log in£o~mation on all logs shall be sub-
mitted for copying except experimental logs, velocity surveys
and dipmeter surveys.
Many rivers tn Alaska and their drainage systems have been
classified as ~uportant for the spawning or migration o£
anadromous £1sh. Operations in these areas are sub~ect to AS
16.S0.870 and the regulations promulgated thereunder (Title
Ale.aka Administrative Code). Prior to commencing operations
you me:f be contacted by the Habitat Coordinator's o£fice,
Department o£ Fish and Ga~e.
Pollution of any waters of the State is prohibited by AB 46,
Chapter 3, Article 7 and the regulations promulgated thereunder
(Title 18, Alaska Ada~Lnistrative Code, Chapter 70) and by the
Federal Water Pollution Control Act, as amended. Prior to
~. J. A. VanDusen
auparuk 25650 Nell No. D-6
-2-
November 30, 1979
commencing operations you may be contacted By a representative
o£ the Department of Environmental Conservation.
Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska
Department o£ Labor ts being notified of the ~ssuance of th~s
permit to d~il I.
To a~d ua in scheduling field work, we would appreciate your
notifying this o£fice within 48 hou~s after the veil ts
spudded. We would also l~ke to be notified so that a repre-
sentative of the consdssion may be present to witness testing
of blowout preventer equipment before 8ur£ace casing shoe is
drilled.
In the event of suspension or abandonment, please give this
office adequate advance not~ftcation so that we may have a
Very truly
~Hoyl~ I. Hamilton
Chalrmn of
Alaska Oil & Gas Conservation C~mmission
coz Department of Fish & Game, Habitat Section w/o encl.
Department of' Environmental Conservation w/o/anti.
De~aEtment of Labor~ Supe~visor, LaI2oE Law ¢c~pliance
Division w/o anti.
ARCO Oil and Ga~'
~mpany
North Alaska. ~str~ct
Post Ofhce Box 360
Anchorage, Alaska 99510
Telephone 907 277 5637
November 26, 1979
Mr. Hoyle Hamilton
State of Alaska
Alaska Oil & Gas
Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99051
Subject : D-6
Dear Mr. Hamil ton:
Enclosed is our Application for Permit to Drill, a sketch of the
surface diverter system, a certified survey plot, and the $100.00
filing fee.
Very truly yours,
P. A. VanDusen
District Drilling Engineer
PAV:mb
Enclosures
ARCO Oil and Gas Company Is a D~v~s~on of AtlanhcRichf~eldCompany
Form 10-401
REV 1-1-71
la. TYPE OF WORK
SUBMIT IN TZ .ATE
(Other instructions on
reverse s~de)
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMITTEE
PERMIT TO DRILL OR DEEPEN
DRILL ~]
DEEPEN [-"1
b TYPE OF WELL
WELL WELL OTHER
2. NAME OF OPERATOR
ARCo Oil and Gas Company
3 ADDRESS OF OPERATOR
P.O. Box 360, Anchora.qe~ Alaska
4 LOCATION OF WELL At surface
SINGLE
ZONE
MULTIPLE
99510
363' FNL & 600' FEL, SEc 23, TllN, RIOE, UM
At proposed prod zone
6250' SS, 1320' FWL & 1320' FSL, Sec 24, TllN, RIOE, UM
13 DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE*
30 miles Northwest of Deadhorse
,~. ~ONDI~OR~ATION Oi 1 and Gas Bond
~E Statewidesuretya~/urNo. #8011-38-40 (Federal Insurance Co.)
APl # 5b-029-20418~-~ ~'
6. LEASE DESIGNATION AND SERIAL NO.
~'~:~" 'ADt 22650 ' '-"" ......
7. IF INDIAN, ALL'field--BE NAME
8 UNIT FARM OR LEASE NAME
Kuparuk 25650
9 WELL NO.
I)-6
10 FIELD AND POOL, OR WILDCAT
Prudhoe Bay Kuparuk River Oil
i1 SEC., T, R., M, (BOWOM PO01
HOLE OBJECTIVE)
Sec 24, TllN, RIOE
*mount $1 00,000
15. DISTANCE FROM PROPOSED *
LOCATION TO NEAREST
PROPERTY OR LEASE LINE, FT
(Also to nearest dng, umt, Lt any)
4680'
18 DISTANCE FROM PROPOSED LOCATION
TO NEAREST WELL DRILLING, COMPLETED,
OR APPLIED FOR, FT
120'
21 ELEVATIONS (Show whether DF, RT, CR, etc.)
Not surveyed - approx 70' Gl
23
16 No OF ACRES IN LEASE
2560
19 PROPOSED DEPTH
6750'TVD
PROPOSED CASING AND CEMENTING PROGRAM
17. NO.ACRES ASSIGNED
TO THIS WELL
320
20 ROTARY OR CABLE TOOLS
Rotary
22 APPROX. DATE WORK WILL START
2-5-80
SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement
24" 16" 65 H-40 80+.~ Cml; .'i;o surf- ao'orox 200 ft3~
13-3/4" 0-3/4" 45.5 K-55BTC 2800±MD Cml; to surf - aoorox 2300 ft°
·
Q-7/R" 7" 26, K-55RTI': R4fi2+MD £mt with annrox ~0flll ft o _
, ,
ARCo Oil and Gas Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool development well
to approximately ±8462'MD,±6750'TVD. Selected intervals will be logged and tested. A 20" x
2000 psi annular diverter will be installed on the 16" conductor while drilling the surface
hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the surface pipe. It will
be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. The well
will be completed with 3½" 9.2# J-55 buttress tubing. Non-freezing fluids will be left on un-
cemented annuli thru the permafrost interval. Selected intervals will be perforated within
the Kuparuk formation and reported on subsequent report. A downhole safety valve will be in-
stalled and tested upon conclusion of job.
I~ ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal is to deepen g~ve data on present productave zone and proposed
new producUve zone. If proposal is to drdl or deepen chrectwnally, g~ve pertinent data on subsurface locations and measured and true
vertacal depths. G~ve blowout preventer program.
24. I hereby certify that the Fosegomg is True and Correct
TITLE
District Drl§. Engr.
(Tlus space for State office use)
SAMPLES AND CORE CHIPS REQUIRED
[]YES ~-~
DIRECTIONAL SURVEY REQUIRED
CONDITIONS OF APPROVAL, IF ANY
MUD LOG
[] YES ,~0
OTHER REQUIREMENTS
[]NO
PERMIT NO.. 7 ~" 76
APPOVED BY TITLE Chaj man
*S~e Instruction' on
Reverse
Side
E.Y C'7~DF..R O,=rTHE COMMI.RSION
A P I. NUMERICAL CODE
~ -- on.4 - z~ ~ yin'
APPROVAL DATE November 30; !979
DATE 11- 30- 79
SURFACE DIVERT[!', SYSTEil
.o
2.
3.
lG'""x 20" X-over
20" 2000 psi (lrilling spool
20" 2000 psi annular preventer
6" butter, fly w~lves
-~
~ WE- LL 5
I
-. ~,~I~LL :' ! Y TM 5,959,904.19
~ x = ,~60,484.14
! -~. ~oO1' ~ LAT 70"18'O3.672"
~ LONG = 149030'36.426''
: I
~ I
~ ~ ' ~4ELL '2 Y = 5,959,784.20
DI~ X = ~60,485.20
i~ ~ LAT 70~18'O2.492''
~ , ~ LO~IG = 149°30' 36 424",
) ~ ~4ELL · ~ Y = 5,959 664 22
-~ X = ~60 486.26
..... 24 --
I ~ (TII~I~RIO~,UM-)' 14ELL -'~ Y = 5,959 544 23
, I ~ , .
' I ~ X = ~60,487.32
I ' [~1 ~ 70~!8'00.1~!
' ~ .] I LONG 149°30' 3~.418'~
i I
~ ' [O~G = I~9°~0
: ,, ,
I ~ I v ~¢ELL . 6 Y = 5,959,304.26
~ ) ~ ~ m - X = ~60 489.44
'~ I ~ LAT 70 17~57.771''
~. 'Ol~ ~ >
~ LOrlG = 149°30'36.413"
~ O WELL =7 ~ = 5,959,184.28
~ D ~ ~ ' X = ~60,490.5
> ~
~ WE~T ~AK8 LAT 70~7' ~6. 591''
i ,
~/ ~ LONG 149~30' 36.409'
WELL ;'8 Y = 5,959,O64.29
~ · X = ~60,491.56
~CAL~:l"=2oo' .. LAT = 70~7'55.411''
LONG = 149~30'36.407"
.~ .' , '-.O~,~, ~1 HEREBY CERTIFY THAT I AM
"'-','- ~,-~ r~. '~, ..,~ ~. PROPERLY REGISTERED AND LICEtlSED
..'.- .(.~7.:'...2., ..... :.~'/:~- TO PRACTICE LAND S~TI~
,~,,,,//~., -_ ,; 2. ' THE sTATE OF ALASKA AuD ~uaT
.- ' ','~-~-"- .... . ' ; THIS PLAT REP~ESEIITS. AN AST
~'. '¢'~-".", '; TitAT ALL DI~ENSI0~S AND OTIIE~
~'" ..... ' ..... DETAILS ARE ~,OL~E[T~AS OF
I ~ I ...................... ~ 7 - ;'" ~-- .:7:~ ~ .... -- ...... ?u' ~_~
WELLS 1,2,5,4,5,6,7,$8 LOCATION5 A6-BUILT
.... t ~ ..... __. ' _' ~.L ; .... ' ~ J . ; '; :_:~' F:~:L
AllanlicRichfieldCompany ¢ DATE: DRAWING
.O.T. P.O.UC Ua . V,S OU
ALASKA DISTRICT ." KUPARUK
CHE~ LIST FOR NEW WELL PERMITS
I. Is the permit fee attached ..........................................
2. Is %.~11 to ~ located in a defined pool .............................
3. Is a registered survey plat attached ................................
4. Is %~11 located proper distance frcm property line ..................
5. Is well located proper distance frcm other wells ....................
6. Is sufficient underdicated acreage available in this pool
7. Is %~11 to be deviated ..............................................
8. Is operator the only affected party .................................
9. Can permit be approved before ten-day ~it ..........................
[0. Does operator have a bond in force ..................................
~ ~ rvation rd eded
La. Is a conse o er ne ......................................
/
[2. Is administrative approval needed ...................................
[3. Is conductor string provide~I ........................................
No Remarks
(2) Loc. ~
(3) Admin.
/
[4. Is enough cement used to circulate on conductor ar~ surface .........
Will cement tie in surface and intermediate or production strings
Will cement cover all known productive horizons .....................
L5.
t6.
17.
Will surface casing protect fresh ~ater zones ....................... ~
(4) Casg. ~
18.
19.
Will all casing give adequate safety in collapse, tension and barst.. ~_
Does BOPE have sufficient pressure rating - Test to ~ O ~ psig .. ~
Approval Reccmmended:
~dd itional Requirements:
Geology:
Engin~eering: ·
rev: 06/21/7
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
11 000000 7777771777 000000 77777777';7
11 000000 7777777777 000000 7777777777
1111 O0 O0 77 O0 O0 77
1111 O0 O0 77 O0 O0 77
1! O0 0000 77 O0 0000 77
11 O0 0000 77 O0 0000 77
11 O0 O0 O0 77 O0 O0 O0 77
11 O0 O0 O0 77 O0 O0 O0 77
11 0000 O0 77 0000 O0 77
11 0000 O0 77 0000 O0 17
11 O0 O0 77 O0 O0 77
11 O0 O0 77 O0 O0 77
111111 000000 77 000000 17
111111 000000 77 000000 77
660666 11 11 000000 666666
660666 1! ll 000000 666666
66 i111 1111 O0 O0 66
bO 1111 1111 O0 O0 66
66 11 11 O0 0000 06
66 11 11 O0 0000 66
66666666 11 11 O0 O0 O0 06666606
66066666 ll 11 O0 O0 O0 66660666
66 66 11 11 0000 O0 66
66 66 11 11 0000 O0 66
66 66 ll 11 O0 O0 06
66 66 11 11 O0 O0 66
Obbbb6 111111 111111 000000 066660
666666 111111 111111 000000 660666
66
60
bO
06
*START* USER PCAL [10707,61106] dOb SHIP 5EO. 3785 DAT~ Ol-mOV-80 19:]2:50
MUNITOP SWS KLIOE40 SEP-80. *START*
*START* USER PCAL [10707,61106] jOB SHIP 6EO. 9785 DATE O1-NOV-80 19:]2:50
MUN1TtJR S~S KI.,IOE40 SEP-80. *START*
ii
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*START* USE}{ PCAL L10707,bllO6J dob bHIP
MONIT[IR SWS KLIOE40 SEP'80. *START*
["-ILk: DSht~:bHIP.TO<2_55>[l_0707 611061 CREATED:
PRINTED: O1--NOV 80 1~13310q
OUkOk SW'll~CI~ES: /l~lLfi,:l~Olq[' /COPiES:I
/SPACING:I /LiMIT:127 /fORMS:NORMAL
SEO. ]785 DATk 01-NOV-80
01-NOV-80 1~:58:22
19:32:50
~HIP ~U ;
6BI~'PING INSTRUC~ll.)NS
ISSUED 25-0CT-80 23:44
BY CA~
PCCC
PCCC
THAN~S.....
¥¥ ¥~ EEEEEEEEEE
¥¥ ~¥ EEEELLEEEE ~RRRRRR~
VV V¥ EL ~R RR
VV VV EE RR R~
VV VV EE ~R
VV VV EE ~
VV YV EEELELEE PRRRRRRR
VV VV EEEELEEE RRRRRRRR
VV VV EE R~
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VV VV LE R~
VV EEELEELEEL R~
VV EEEE, EEEEEE R~ PR
IIiiii
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000000 000000 222222
000000 000000 222222
00 O0 O0 O0 22 22
O0 O0 O0 00 22 22
00 0000 00 0000 22
O0 0000 O0 0000 22
O0 O0 O0 O0 O0 O0 22
O0 O0 O0 O0 O0 O0 22
0000 O0 OOOO O0 22
0000 O0 0000 O0 22
O0 O0 O0 O0 22
00 O0 00 O0 22
000000 000000 2222222222
000000 000000 2222222222
,STARI~, USLR PCAL 110707,61106] dOB SHIP SEO.
MONITOR S~$ ~LIOE40 SkP-80. *START*
FILE: DS~H:VLRIPV.002<057>[10707 61106] CREA2LD:
t-R1NTED: 01-NOV-00 19:3~:13
QUEUE Sw]ICHES: /PILL:FORT /COPIES:I
/SPACING:I /LiMI£:127 /f'ORMS:NORMAL
~785 DAT~
01-NOV-80
O1-NUV-80
19:31:52
1g:32:50
SCHLUMBERGER COMPUTING CbNTER
10707,61106
REEL bEADk~
LENGIH: 132 BYTES
REEL NAME: P.C.A.L.
Sf, PV1CE NAME: EDIT
REEL CONTINUATION NUMBER: 01
PREVIOUS REEL NAME:
C~]MMkNTS: LIS ~ORMAT CbST£]MkR TAPE
DATE: 80/10/25
TAPE UEADB~
LENGIH: 132 BYTE6
TAPE NAME: 61106 DALE: 80/10/25
~ERVICE NAME: EDIT
TAPE CONTINUATION NUMBER: 01
PREVIOUS TAPE NAMe:
C()MMkNTS:
TAPE COMMENTS
CASING DRILLER 10.75@2974/BIT $1Zk 8.75/FLUID TYPE DIL'BAS~/
DENS 10.6/VISC 48.0/PH 0.O/FLUID LOSS ~.0 ML/RM
MAX EEC TMP 132 ~/
.. .... N~ SP & NtJ S~LU RLCOPDLD DUE TO OIL BASE MUD.....
TAKEN FROM RUN#I Dlb LOGGED 060CT80
~ ILE HE, AD[~R
LENGTH: 62 D ¥ TE,5
~ ILE NAM~: EDiI' .001
MAXIMUM PB~SICA6 RECORD LENGTH:
PREVItJUS FILE NAME:
1024 BYTES
~ELL SITE iNfORMATiON RECORD
LENGTH:
COMPANY:
wELL:
flkLD:
RANGE:
TOWN:
S~CT]ON:
C(]UNTY:
180 U~TES
ATLANIIC RICHf'IELD CO.
~UPARU~ D-6
MUPARUK
IOE
~iN
23
N. SLOP~
DATA F[)RMAT SPkCI~ICAI1UN
LkNGIf~: 730
ENTR~ BLOCKS:
IYPE
O
REP CODE EN~R~
66 0
lC TUUL
I DkPf
2 ILD
3 ILM D1L
4 GE DIL
5 GR CNL
CALl CNL
7 DRHO CNL
NPHI CNL
9 RHOB CNL
10 NRA~ CNL
NCNL CNL
12 FCNL CNL
GR BHC
14 DI ~HC
15 THOB
16 UHAN
17 POTA
SVORD# UNITS AP1 APl APl APl P ILE{ SIZE EXP PROC SAM REP DEPT SHIFT
FI 0 0 0 0 0 4 0 0 1 68 0 0
OHMM 7 12 40 0 0 4 0 0 1 68 0 0
OHMM 7 12 44 0 0 4 0 0 1 68 0 0
GAPI 7 31 32 0 0 4 0 0 1 68 0 0
GAPI 42 31 32 O 0 4 0 0 1 68 0 0
IN 42 28 I O 0 4 0 0 ! 68 0 0
G/C3 42 44 0 0 0 4 0 0 I 68 0 0
PU 42 68 3 O 0 4 0 0 1 O8 0 0
G/C] 42 35 1 0 0 4 0 0 1 68 0 0
C/C 42 42 I 0 0 4 0 0 1 68 0 0
CPS 42 ]4 92 O 0 4 0 0 1 68 0 0
CPS q2 ]4 93 0 0 4 0 0 1 68 0 0
GAP1 O0 ]1 32 0 0 4 0 0 1 68 0 0
US/F b0 52 32 0 0 4 0 0 1 08 0 0
PPM 0 0 0 0 0 4 0 0 I 68 0 O
PPM 0 0 0 0 0 4 0 0 I 68 0 0
NONE 0 0 0 0 0 4 0 0 1 ~8 0 0
GAPI 0 0 0 0 0 q 0 0 1 68 0 0
DEPTH
8510.000
8500. 000
8100.000
8300.000
8200.000
8100.000
8000.OO0
lqo0.o00
7800.000
MNEMONIC
I bD
CALl
NR~T
DT
SGR
lbo
CALl
NRA3
bT
SGR
CALl
NHA1
DT
SGR
16D
CALI
NRAT
DT
ILD
CALl
NRAT
DT
SGR
lbD
CALl
NRAT
DT
SGR
IbD
CALl
NRAT
DT
1LO
CALl
m}~AT
DT
1LD
CALl
NRAT
DT
VALU
·
8.
3.
104.
13.
·
5.
3.
104.
13.
.
8.
3.
100.
110.
.
8.
2.
99.
83.
.
8.
2.
92.
80.
.
8.
2.
90.
55.
.
8.
3.
104.
132·
.
8.
3.
112.
122.
·
8.
3.
114.
197.
90
75
49
18
22
90
49
18
22
53
67
17
O0
68
717
758
971
75O
688
O1
80
77
75
63
o7
72
02
75
13
95
22
45
88
O0
44
30
82
75
50
52
bl
63
O0
MNEMONIC
ILM
DRHO
NCNL
THOR
IbM
DRHU
NCNb
THOR
D~HO
NCNb
~HOR
ibm
DRHO
NCNL
IbM
DRHO
NCNL
I'HOR
IbM
DRHU
NCNb
THOR
IbM
DRHU
NCNb
THOR
IbM
DRHO
NCNb
THOR
IbM
mCNL
IHOR
VALUE
2.236
-0.489
666.000
1.624
2.236
-0.157
6U6.000
1.624
2·623
0.002
2090.000
11.648
2.795
0.03!
2504.000
10.g77
5.266
0.021
2588.000
9.344
10.063
0.013
3124.O00
6.383
1.771
0.015
1904.000
14.203
1.915
0.002
1773.000
12.109
2.463
0.001
1878.000
10.664
MNkMON1C
NPHI
fCNb
URAN
NPHI
~CNL
URAN
NPHi
~CNL
URAN
GR
NPHI
kCNb
ORAN
NPHI
~CNL
URAN
NPH1
fCN6
URAN
GR
NPH1
PCNL
URAN
GR
NPHI
~CNL
URAN
GR
NPHI
~CNb
URAN
VALUE
289·750
46.680
175.625
0.106
289.750
46.680
175.625
0.106
110.625
37.402
627.000
3.303
85.813
33.105
8O4.5OO
0.537
85.125
33·789
793.000
1.472
52·063
24.107
1174.000
1.055
121.063
41.895
504.500
4.508
114.188
44.482
439.000
4.469
193.125
44.043
498.500
14.852
MNEMONIC
GR
RHUB
GR
PUTA
GR
RHUD
GR
POTA
GR
RHOO
GR
PUTA
GR
RHOB
GR
PUTA
GR
RHUB
GR
POTA
GR
GR
POTA
GR
RHUB
GH
PU~A
GR
GR
PUTA
GR
RHOB
GR
PO'fA
VALUE
13.22/
1.583
289.750
0.004
13.227
1.863
289.750
0.004
109.000
2.441
110.625
0·023
94.688
2.471
85.U13
O.021
86.750
2.410
85.125
O.019
55.750
2.31b
62.063
0.013
125.000
2·434
121.063
0.028
123.063
2.377
114.188
0.024
1U9.125
2.303
193.125
0.028
7700.000
7600.000
7500.0O0
7400,000
7300.000
7200,000
71 O0. 000
7000.000
6900.000
MN kMiJN lC
ILD
CALI
NRA'I
DT
CALl
NRAr
DT
iLD
CALl
NRAT
DT
iI,D
CALl
NRAT
DT
1LD
CALl
NRAI
DT
ILD
CALl
NRAT
DT
ILD
CALl
NRAT
OT
ill)
CALl
NRAT
DT
lbD
CALl
NRAT
DT
SGR
VA
11
28
-99
-99
-99
-99
-99
-99
-99
-99
-99
-99
-99
-99
-99
-99
-99
-99
-99
-99
LU
.
8.
3.
3.
6.
.
8.
3.
117.
153,
.
9.
3.
106.
125.
8.
9.
9.
9.
9.
9.
9.
9.
.
9.
9.
9.
9.
.
9.
9.
9.
9.
I .
9.
9.
9.
9.
.
9.
9.
9.
9.
529
844
436
375
750
549
969
477
375
375
244
109
219
375
125
537
922
300
300
300
740
219
3OO
300
300
352
266
300
300
300
139
305
300
300
300
594
406
300
300
300
574
383
3O0
300
3O0
MNEMONIC
ILM
DRHO
NCNb
IbM
DBHO
NCNb
IHOR
1bM
DRHO
NCNb
TH{JR
ILM
DRHO
NCNb
THOR
DRHO
NCNb
THOR
IbM
DRHU
NCNb
ILM
DRHO
NCNb
THUR
DRHO
NCNb
I'HOR
ILM
DRHO
NCNb
THU~
VAblJk
1.637
0.017
1787.000
10.164
2.559
-0.003
1953.000
7.625
3.154
0.0O4
2354.000
11.148
3.494
-999.300
-999.]00
-999.300
3.744
-999.300
-gg9.300
-999.300
3.377
-999.]00
-999.~00
-999.300
~.359
-999.300
-999.300
-999.300
1.589
-999.300
-999.300
-999.300
1.602
-999.300
-999.300
-999.300
GR
NPHI
~CNL
URAN
GR
NPH1
~CNL
URAN
G~
NPHI
~CNL
ORAN
GR
NPHI
~CNi,
URAN
GR
NPHI
PCNL
URAN
GR
NPHI
~CNL
URAN
NPH1
~CNL
URAN
GR
NPHI
DCNL
URAN
GR
NPHI
~CNL
URAN
VALUE
212.500
41.846
501.250
25.906
lb0.875
42.383
527.500
12.547
122.813
37.500
657.500
5.559
106.125
-999.300
-999,300
-999.300
157.000
-999.300
-999.300
-999.300
171.375
-999.300
-999.300
-999.300
127.375
-999.300
-999.300
-999.300
135.875
-999.300
-999.300
-999.300
186.625
-999.300
-999.300
-999.300
MNEMONIC
GR
RHOB
GR
PUfA
GR
~HLIB
GR
POTA
G~
GR
PUTA
GR
RHUB
GR
PUTA
G~
G~
POTA
GA
RHOB
GR
POTA
GR
MHU~
PUTA
G~
RHUB
GR
PUTA
GR
RHOB
PUTA
VALUE
d~9.500
2.359
212.500
0.025
153.375
2.428
lb0.U75
0.020
123.81]
2.471
122.81]
0.025
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.J00
-999.300
-999.300
-999.300
-999.30U
-999.300
DEPTH
6800.000
8700.000
6600.000
6500·000
64O0. 000
6 tO0. O00
6200.000
8100.000
6000,000
~N~ MUNIC
CALl
NRAT
DT
SG~
CALl
NRAT
DT
ILD
CALl
NRAT
DT
lbo
CALl
NPAT
DT
CALl
NRAT
DT
ILD
CALl
DT
ILD
CAI, I
NRAT
DT
6GR
1Lf)
CALl
NRA1
DT
I LD
CALl
NRAI
bT
VALU
.
9.
-999.
-999.
-999.
.
9.
-999.
-999.
-999.
.
9.
-999.
-999.
-999.
·
9.
-999.
-999.
-999.
·
9.
-999.
-999.
-999.
9.
-999
-999
-999
9.
-999.
-999.
-999.
·
9.
-999.
-999.
-999.
.
9.
-999·
-999.
-999,
129
Ob3
30O
300
3OO
97~%
13]
3OO
3OO
30O
398
219
30O
300
3O0
748
148
3O0
3O0
300
248
313
3OO
300
3OO
834
398
3OO
3OO
3OO
O35
367
3OO
300
3OO
818
523
3O0
300
3OO
998
461
300
300
300
MNEMUNIC
DRHO
NCNL
THOR
1bM
DRHO
NCNb
THOB
DRHO
NCNb
THOR
1bM
NCNb
THOR
DRHU
NCNb
IbM
DRHO
NCNb
~HOR
1bM
DRHO
NCNb
THOR
ILM
DRHO
NCNb
TH(JR
DRHO
NCNL
THOR
VALUE
2.160
-999.300
-999.300
-999.]00
1.969
-999.300
-999.]00
-999.300
2.410
-999.300
-999.300
-999.300
2.766
-999.300
-999.300
-999.]00
2.248
-999.300
-999.300
-999.30O
2.818
-999.300
-999.$00
-999.~00
3.088
999,300
2999.]00
-999.300
2.805
-999.300
-999.300
-999.300
2.979
-999.300
-999.900
-999.300
MNEM[]NIC
GR
NPHI
fCNL
URAN
GR
NPH1
~CNL
URAN
GR
NPHI
~CNL
URAN
GR
NPHI
~CNL
URAN
G~
NPHI
~CNL
ORAN
G~
NPHI
fCNL
ORAN
GR
NPhi
$CNL
ORAN
GR
NPHI
fCNb
URAN
NPHI
URAN
VALUk
110.625
-999.300
-999.300
-999.300
93.063
-999.300
-999.300
-999.300
94.000
-999.300
-999.300
-999.300
112.688
-999.300
-999.300
-999.300
99.188
-999.300
-999.300
-999.300
104.875
-999.300
-999.300
-999.300
85.250
-999.300
-999.300
-999·300
100.188
-999.300
-999.300
-999.300
97.063
-999.300
-999.300
-999.300
MNkMON 1C
GR
RHOB
GR
POTA
GH
HHOB
GR
POTA
GR
RHOB
GR
PUTA
G~
RHOB
GR
POTA
GR
RHUB
GR
POTA
GR
RHOB
GR
POTA
G~
RHOB
GR
POTA
GR
GR
POTA
GR
RHO~
GR
POTA
VALUE
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.]00
-999.300
-999.300
-999·300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.]00
-999.300
-999·300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
DEPTH
5900.000
5800.000
5700. 000
5600,000
5500.000
5400.000
5300.000
5200.000
5100.000
CALl
NRAT
DT
SGR
ILD
CALl
NRAT
DT
CALl
NRAT
DT
SGR
1LD
CALl
N~AT
DT
llab
CALl
NRAT
DT
SGR
CALl
NMAT
DT
IbD
CALl
NRAT
DT
i b D
CAI, 1
NRAT
~GR
IIJD
CALl
NRAI'
DT
VALU
·
9.
-999·
-999.
-999.
10.
-999
-999,
-999
.
9.
-999,
-999·
-999.
10.
9.
-999,
-999,
-999,
10.
-999.
-999.
-999.
-999
-999
-999
.
-999,
-999.
-999.
10.
-999,
-999.
-999.
11.
-999
-q99
-999
859
563
300
3OO
3OO
795
531
3OO
300
300
889
400
300
300
300
016
383
300
300
300
254
656
300
3O0
300
826
023
300
300
300
559
375
300
300
300
OO4
563
3OO
3OO
3OO
336
242
300
3O0
300
MNLMONIC
IbM
DRHO
NCNb
NCNb
TH(JR
IbM
DRHO
NCNb
THOR
ibm
DRHO
NCNb
THOR
IbM
DRHO
NCNb
THOR
1LM
DRHO
NCNb
THOR
iLM
DRHO
NCNb
IHOH
IbM
DRHO
NCNb
THOM
DIk. HO
NCNb
THOM
VALUE
2.828
-999.]00
-999,300
-999.300
3,934
-999.300
-999.300
-999.300
4.121
-999.300
-999.300
-999.300
9.273
-999.300
-999.300
-999.300
3.223
-999.300
-999.300
-q99.300
3.7b0
-999,300
-999.300
-999,300
4·605
-999.300
-999.]00
-999.]00
3.100
-999.300
-999.300
-999.300
4.332
-999.300
-999.300
-999.]00
MNLMONIC
GR
ORAN
GM
NPHI
~CNL
URAN
GR
NPH1
~CNL
UMAN
GR
NPHI
fCNL
ORAN
GH
NPHI
~CNL
URAN
GR
NPHI
~CNO
ORAN
GH
NPHI
fCNL
URAN
GR
NPHI
~CNL
URAN
GM
NPHI
~CNb
URAN
VAbUk
78·188
-999.300
-999.300
-999.300
80,188
-999.300
-999.300
-999.300
94.750
-999,300
-999.300
-999,300
91.125
-999.300
-999.300
-999.300
90.438
-999.300
-999.300
-999.300
114.503
-999.300
-999.300
-999.300
94.125
-999.300
-999.300
-999.300
107.813
-999.300
-999.300
-999.300
84.188
-999.300
-999.300
-999.300
MN LMUN lC
GH
~HUI~
GH
POTA
GR
RHOB
GR
POTA
GR
RHOB
GR
POTA
GR
HHOB
GR
POTA
GR
RHOB
G~
~OTA
GR
RHUB
GR
POTA
RHOB
GH
POTA
GR
RHLI~
GR
PU~'A
GR
RHOB
PUTA
VALUk
-999.]00
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.]00
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.30O
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-9~9.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
-999.300
5000.000
4900.000
4800.000
1700.000
4600.000
qSO0.O00
4400.000
4300,000
4200.000
MNEMiJNIC
1LD
CAI,!
NHAT
ilo
CALl
NRAi'
DT
SGH
ILD
CALl
NRAT
DT
ILO
CAI, I
NRAI'
DT
ILD
CALl
NRAI
DT
ILD
CALl
NRAT
DT
IIJD
CALl
NRAT
OT
ILD
CALl
NHAT
DT
SG~
ILD
CALl
NRAT
VA
1
11
1
11
8
1
12
7
Lb~
~.678
O.648
3.326
0.188
1.250
0.648
0.992
3.471
4.563
1.250
8.750
0.008
3.260
5.000
6.938
8
10
122
77
13
9
3
87
61
5
10
120
78
7
10
3
119
89
8
10
3
116
90
7
11
3
122
70
.430
.047
.473
.000
.063
.451
.984
.lOg
.188
.313
.867
.141
.591)
.188
.438
.129
.813
.594
.000
.719
.922
.504
.188
.688
.578
.02]
.645
.56]
.563
MNEMONIC
1bM
DRHO
NCNb
THOR
DRHO
NCNL
IHUR
iL~4
DRHO
NCN6
THOR
DRHO
NCNL
IHUR
DRHO
NCNb
THOR
IbM
DRH(J
NCNL
THOR
iLM
DRHO
NCNL
THOR
DRHO
NCNb
THOR
ILM
DRHO
NCNL
THOR
YALUL
3.680
0.008
2058.O00
9.867
4.613
0.013
2080.000
6.484
9.609
0.001
2112.000
8.867
7.q41
0.006
2084.000
7.668
16.828
0.000
2170.000
5.547
5.383
0.052
1833.000
8.031
b.766
0.008
1823.000
9.875
8.695
0.007
1981.000
9.977
7.570
0.012
2056.000
7.422
MNbMUNIC
GR
NPH1
PCNL
UPAN
GR
PCNL
ORAN
G~
NPH1
PCNb
ORAN
G~
NPHI
~CNL
ORAN
GH
NPH1
~CNL
ORAN
GR
NPHI
PCNL
URAN
GH
NPHi
~CNL
ORAN
NPH1
PCNL
ORAN
GP
NPHI
PCNL
ORAN
VALUE
107.125
37.207
556.000
4.055
72.500
]9.600
542.000
3.084
74.750
36.914
589.500
2.227
07.688
40.674
555.500
3.127
60.813
34.277
649.000
1.603
73.250
42.676
481.250
1.775
88.500
41.895
403.750
1.925
90.938
40.234
479.250
1.942
74.625
42.725
530.500
1.483
MNLMONIC
GR
RHOB
POTA
GR
RHOO
GR
POTA
GR
RHOB
GR
POTA
GR
RHOB
GR
PUTA
GR
RHO~
GR
POTA
GR
RHOB
GR
POTA
GR
RHOB
GR
PUTA
GR
RHOB
G~
POrA
GR
RHO8
GR
POTA
VALUL
112.250
2.332
101.125
0.027
80.625
2.236
72.500
0.021
17.813
2.156
14.750
0.018
74.813
2.230
07.688
0.Olb
b0.219
2.157
b0.813
0.017
78.313
2.305
73.250
0.021
90.125
2.305
88.500
0.024
90.688
2.357
90.938
0.02]
70.563
2.200
74.025
0.019
Db, I"'I H
'~100. 000
4090.000
3900.000
]800.000
:1700.000
~600.000
:1500.000
3400.000
3300.000
MNLMUNIC
1
CALl
NRA~
DT
!
CALl
NRAT
D'I
II.,D
CALl
NRAT
DT
l LI)
CALl
NRA]:'
CALl
NkAT
CALk
NRAI'
DT
CABi
NRAT
CALl
NRAT
6GR
CALl
NEAT
DT
VALUE
13.297
9.125
3.600
133.000
48.063
9.711
9.484
3.604
122.000
70.875
8.344
9.5OO
3.615
121.750
82.313
7.445
9.484
3.656
123.750
75.313
10.901
9.484
3.455
130.375
50.938
9.578
10.680
3.416
130.375
73.188
9.711
10.070
3.643
122.563
14.875
7.945
10.820
3.604
128.500
6].875
7.996
10.563
~.012
131.750
79.313
MNgMON lC
DRH(J
NCNB
THOR
IbM
DRHO
NCNB
THOR
DRHO
NCNB
THOR
DRMO
NCNB
THOR
DRHO
NCNL
DRHO
NCNB
THOR
ILM
DRHO
NCNb
tHOR
DRHO
NCNB
THOR
1LM
DRHO
NCNB
I. HOR
VALUE
13.758
0.002
2216.000
5.156
9.688
0.015
1988.000
6.277
7.980
0.012
1902.000
8.008
6.730
0.005
2354.O00
9.188
10.938
-0.001
2298.000
6.383
9.336
0.005
1816.000
4.875
9.453
O.OO6
1955.000
5.840
8.102
-0.000
1926.000
6.672
7.480
0.010
1783,000
6.414
MN~MON1C
GH
NPHi
~CNb
URAN
GR
NPHI
FCNL,
URAN
NPHI
I~CNG
ORAN
GH
NPH1
.~ CN L.
URAN
NPHJL
~CNL,
UI~AN
GR
NPHI
bCNB
ORAN
~CN~
ORAN
NPH1
~-CNL
ORAN
NPHI
~CNL
ORAN
VALUE
43.844
44.385
560.000
I .201
66,125
43.896
505.250
2.471
78.813
44.092
467.250
2.914
75.125
44.824
556.000
0.542
54~. 156
41.211
601.000
1.117
34.719
38.770
469.000
4.445
71.500
43,750
503.000
3.713
74.O63
42.041
495.250
1.884
75.875
49.658
372.000
3.865
MNEMONIC
GR
RHOB
GR
POTA
GR
RHO~
GR
PUTA
G~
RHU8
POTA
GR
RHOB
GR
POTA
GR
RHOB
GR
POTA
GR
RHO~
GR
POTA
GR
RHOB
GR
POmA
GR
RHUB
GR
POTA
GR
GR
~O~A
VABUE
47.313
2.117
43.844
0.013
69.o25
2.268
66.125
0.017
u2.313
2.250
78.813
0.017
80.750
2.201
75.125
0.020
53.750
2.119
5~.156
O.Ot3
34.650
2.232
34.719
0.014
75.313
2.221
71.500
0.015
03.875
2.156
74.063
0.017
80.313
2.279
75.875
0.017
]200.OO0
3100.000
3000.000
29~5.000
lbo
CALl
NRAT
OT
SGR
CALl
NHA1
UT
lbo
CALl
NRAI
OT
iLD
CALl
N~AT
VALU
.
10.
].
143.
55.
.
10.
134.
68.
.
11.
q.
133.
76.
-999.
-999.
-999.
-999.
-999.
883
O39
498
125
781
6O5
438
902
375
81~
551
38]
191
000
125
250
250
25O
25O
250
MNF. MONIC
DRHO
NCNb
THOR
IbM
DRHO
NCNb
THUR
DRHU
NCNL
THOR
IbM
DRHO
NCNb
IHOR
VALUk
8.992
0.004
2104.O00
5.805
5.059
0.013
lb19.000
7.203
5. 348
0.012
1654.O00
7.246
-999.250
-999.250
-999.250
-999.250
MNkMONIC
NPHI
fCNb
URAN
GR
NPH1
FCNL
URAN
GR
NPHI
~CNL
URAN
NPHI
FCNL
bRAN
VALUk
47.375
41.162
491.750
1.505
77.e25
47.852
371.250
2.080
b7.750
52.393
3bl.250
2.61]
-999.250
-99925.000
-999.250
-999.250
MNEMONIC
GR
RHOs
GR
POTA
GR
RHO8
GR
POTA
GR
RHO~
GR
POTA
GR
RHUD
GR
POTA
57.531
2.084
41.315
0.013
72.31J
2.170
77.b25
0.015
72.b25
2.148
bl.750
0.018
-999.250
-999.250
-999.250
-999.250
i
SUmmARY U[" OA'IA RL¢(J~U5
NU~Bt~ DP NECUHDS: 79b
LENG%ti fJ.~ LA6[ [~ECO[~D: 78 BY%L5
FILE T~AILEP
(~ENGfH: 62 BYTE5
fILE NAME: EDI~ .OOI
MAXIMUM PHYSICAL PLCURD LENGTH:
NLX[ fIL~ NAME:
TAPE, I~AILE~
LENGIh: 1 ~2 ~Y'I'ES
TAPE hAME: bllOb
SERVICE NAME: EDIT
TAPE CUNTINUA21UN NU~u~:
NEXT 3AP~ NAMt;
._
1~.~
01
1024 BYTES
DATE:
80/10/25
