Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: Milne Point Well C-36 (PTD# 198-001) NOT OPERABLE
Date:Tuesday, February 7, 2023 9:32:17 AM
From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>
Sent: Tuesday, January 31, 2023 9:33 AM
To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC)
<phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; DOA AOGCC
Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>
Cc: Alaska NS - Milne - Wellsite Supervisors <AlaskaNS-Milne-WellsiteSupervisors@hilcorp.com>;
Alaska NS - Wells Foreman <PBWellsForeman@hilcorp.com>; Scott Pessetto
<Scott.Pessetto@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>
Subject: Milne Point Well C-36 (PTD# 198-001) NOT OPERABLE
All,
Milne Point well C-36 (PTD # 198-001) will not be brought on line for the regularly scheduled MIT
this month. A tag will be hung on the well head, it will be classified as NOT OPERABLE, and it will be
tested prior to returning to injection.
Please respond with any comments or concerns.
Jerimiah Galloway
MPU/Islands Well Integrity Engineer
Email: jerimiah.galloway@hilcorp.com
O: (907)564-5005
C: (828)553-2537
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please
immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete
this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
DATE: 3/27/2019
188001
Debra Oudean Hilcorp Alaska, LLC 3 0 5 1 1
AK_GeoTech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
Fax: 907 777-8510
E-mail: doudean@hilcorp.com
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
IPROF
CD: HALLIBURTON 1 SEP 2018
RECEIVED
MAR 2 8 2019
AOGCC
MPC-36i_IPR0F 01SEP18
11t°x`2071 2:6S PM
PDF Document
11 MPC-36i_IPROF_01SEP78_040dn
1I/V201E 2,32 PM
LAS File
J MPC -36 IPP.OF 01SEP '18 040up
11:`512018 2:32 PtA
LAS File
MPC-36i_IPR0F_01SEP18_080dn
11/$!20182:32PM
LAS File
AMPC-36'r_IPROF_01SEP'18_080up
11J5:'20782;32PM
LAS File
;J MPC-35i_IPR0F 01SEP18_120dn
11/e'2018 2:32 PM
LAS File
.A MPC-36o_IPROF_01SEP 18120up
11;`Sf2618 2:32 PM
LAS File
N MPC-36i_IPR0F_01SEP18img
11,`e "201 S5 2:66 PM
TIFF File
MPC-36i_IPROF_01 SEP18_Stop13267
11/c.201 9 2:08 PM
LAS File
MPC-315i_IPROF01SEP18Stop13317
11/5x20192:08PI'd
LAS File
MPC-36i_IPROF_01SEP 18_Stop13367
11 5.20182:68 PM
LAS File
MPC-3]5i_IPROF_01SEP78_Stop13497
1115?2618 2:08 PM
LAS File
MPC-36i_IPR0F_01SEP18_Stop13537
11!&+20182;05 PPA
LAS File
3 MPC-36i_IPROF 01SEP78_Stop13700
1115120152:68 PM
LAS File
Please include current contact information if different from above.
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510
Received ey:� Dane: 1
U
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO.gg ^ DATE: Thursday, January 24, 2019
Pll. Supervisor 1- ee ��i51ICI SUBJECT: Mechanical Integrity Tests
HILCORP ALASKA LLC
C-36
FROM: Bob Noble MILNE PT UNIT C-36
Petroleum Inspector
Sre: Inspector
Reviewed By:
P.I. Supry
NON -CONFIDENTIAL Comm
Well Name MILNE PT UNIT C-36
API Well Number 50-029-22853-00-00
Inspector Name: Bob Noble
Permit Number: 198-001-0 Inspection Date: 1/19/2019 '
Insp Num: mitRCN190120161155
Rel Insp Num:
Packer Depth Pretest Initial
15 Min 30 Min 45 Min 60 Min
Well
C-36
Type Inj
w,
TVD
7037 '
Tubing
2727
2729 "
nn
2726
PTD
1980010
-
Type Test
SPT
Test psi
1759
IA
los
1920
1862 -
1842 -
BBL Pumped:
2 "
BBL Returned:
2.2
OA
137
! 371
368 -
360 '
Interval
41RTST
p/F P
Notes:
Thursday, January 24, 2019 Page I of I
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: DATE: Thursday,February 05,2015
Jim Regg ISP Zf 6(1,
P.I.Supervisor 11 SUBJECT: Mechanical Integrity Tests
HILCORP ALASKA LLC
C-36
FROM: Johnnie Hill MILNE PT UNIT KR C-36
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry--1. —
NON-CONFIDENTIAL Comm
Well Name MILNE PT UNIT KR C-36 API Well Number 50-029-22853-00-00 Inspector Name: Johnnie Hill
Permit Number: 198-001-0 Inspection Date: 1/30/2015
Insp Num: mitJWH150201130557
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well C-36 Type Ini W TVD 6986 - Tubing 3098 - 3098 " 3100 3100
PTD 1980010 Type Test SPT Test psi 1746 - IA 456 - 2015 - 1 2006 - 1 2015 - 1
Interval 4YRTST 1 p/F P ,, OA 208 . 408 - 404 . 404
Notes: 1.84bbls of diesel -
—
SCA
NNED ;.? , ,i E,
Thursday,February 05,2015 Page 1 of 1
• •
bp
BP Exploration (Alaska) Inc.
Attn: Well Integrity Coordinator, PRB-20 k FE.�
Post O ffi ce u Y
Box 196612
Anchorage, Alaska 99519 -6612
\G\c6 CX3
December 30, 2011 ! Q Ci
Mr. Tom Maunder ''
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue ��
Anchorage, Alaska 99501
Subject: Corrosion Inhibitor Treatments of MPC -Pad
Dear Mr. Maunder,
Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -Pad
that were treated with corrosion inhibitor in the surface casing by conductor annulus.
The corrosion inhibitor is engineered to prevent water from entering the annular space
and causing external corrosion that could result in a surface casing leak to atmosphere.
The attached spreadsheet represents the well name, API and PTD numbers, top of
cement depth prior to filling and volumes of corrosion inhibitor used in each conductor.
As per previous agreement with the AOGCC, this letter and spreadsheet serve as
notification that the treatments took place and meet the requirements of form 10 -404,
Report of Sundry Operations.
If you require any additional information, please contact me or my alternate, Gerald
Murphy, at 659 -5102.
Sincerely,
Mehreen Vazir
BPXA, Well Integrity Coordinator
-- .
• •
BP Exploration (Alaska) Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off
Report of Sundry Operations (10 -404)
MPC -Pad
10/9/2011
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTD # API # cement pumped cement date inhibitor sealant date
ft bbls ft gal ,
MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA
MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA
MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA
MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA
MPC -05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA
MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA
MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA
MPC-08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011
MPC-09 1850360 50029212990000 Tanko conductor NA NA NA NA NA
MPC-10 1850150 50029212780000 Tanko conductor NA NA NA NA NA
MPC -11 1850590 50029213210000 Tanko conductor NA NA NA NA NA
MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA
MPC -13 1850670 50029213280000 Tanko conductor NA NA NA NA NA
MPC-14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011
MPC-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA
MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA
MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA
MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA
MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA
MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA
MPC-21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011
MPC -22A 1951980 50029224890100 38 NA Need top job
MPC -23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011
MPC -24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011
MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011
MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011
MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011
--Oh. MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011
MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011
MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011
MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011
MPC-42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011
MPC-43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011
. •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Wednesday, February 02, 2011
TO: Jim Regg
P.I. Supervisor (.- 2-e.-- , 2 f I( SUBJECT: Mechanical Integrity Tests
l BP EXPLORATION (ALASKA) INC
C -36
FROM: John Crisp MILNE PT UNIT KR C -36
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Supry T s
-
NON CONFIDENTIAL Comm
Well Name: MILNE PT UNIT KR C - 36 API Well Number: 50 029 - 22853 - 00 - 00 Inspector Name: John Crisp
Insp Num: mitJCr110201141018 Permit Number: 198 - 001 - Inspection Date: 1/30/2011
Rel Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well j C-36 ' Type Inj. G F- TVD 6986 - IA 100 2000 1940 1920 - 1
P.T.D 1980010 - ,TypeTest SPT Test psi 1746 - OA o 10 10 10 _^
Interval 4YRTST - P/F P - Tubing 4300 4250 4275 4250
Notes: 2.8 bbls pumped -
Wednesday, February 02, 2011 Page 1 of 1
.
.
WELL LOG
TRANSMITTAL
ProActive Diagnostic Services, Inc.
To: AOGCC
Records Department
333 W. 7th Ave
Suite 100
Anchorage, Alaska 99501
RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by
returning a signed copy of this transmittal letter to the attention of :
ProActive Diagnostic Services, Inc.
Attn: Robert A. Richey
130 West Intemational Airport Road
Suite C
Anchorage, AK 99518
Fax: (907) 245-8952
1)
2)
3)
4)
5)
6)
7)
'::DE Disk
MPC - 36i
Injection Profile
15-Sep-06
S~NED APR 03 2007
û"IC-- \ C1 Y; -tD \
$ H5:)----r
.. '.' I>..._.~"....._-J...,~.....:.^!ot........,.~""";'.............~
Signed:
n, ()
r\ ~ ^^--
,1) .it> <")'-1'7
jy 'JJJ dJU I
Print Name:
0..\1\ ~\ :sVlV~.p m{),\.i iJ'llL.ç)/\
Date~ :¡;~ ~:~:;':;~" :(:Jy(~~~~is~~cr:
PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Ro SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAX: (907)245-8952
E-MAIL: PDSANCHORAGE@MEiVlORYLOG.COM
WEBSITE : WlJlJW.MEMORYLOG.COM
D:\Master ~ cOPY- 00 ~ PDSANC-2Oxx\Z ~ W ord\DistributionlTransmittat SbeetslTransrnit_ OriginaL doc
MEMORANDUM
.
State of Alaska
.
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg
P.I. Supervisor
íZ:è1t'{ II! 't 0 7
DATE: Wednesday, January 17,2007
SUBJECT: Mechanical Integrity Tests
BP EXPLORATION (ALASKA) TNC
C-36
MILNE PT liNIT KR C-36
rCjra-oof
FROM:
John Crisp
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Supr~"6i2-
Comm
NON-CONFIDENTIAL
Well Name: MILNE PT UNIT KR C-36
Insp Num: mitJCr070II6092821
ReI Insp Num
API Well Number 50-029-22853-00-00
Permit Number: 198-00[-0
Inspector Name: John Crisp
Inspection Date: 1115/2007
Packer
Depth
Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
--
--- .. ~
--,-_._---~- ,
----~-r_---- .
Well
P.T.
---
Interval 4~T_ST_
C-36 Type Inj. W: TVD 6986 IA
---------- ..----- -- ----
1980010 TypeT est~:r__!e~t.EsL__~746~OA ~___425_
100
2000
1970
1970
--~-
680
700
700
-~.._.
_n____n___
---~._-
P/F
P
/
Tubing
2800
2800
2800
2800
-------..-.
Notes 2.5 bbl's pumped for test. No problems witnessed.
SCANNED JAN 2 5 2007
Wednesday. January 17.2007
Pagc I of I
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Mike Bill'"r~
Commissioner
THRU: Tom Maunder ~
Petroleum Engineer, ~ .O'~2
FROM: Lou Grimaldi
Petroleum Inspector
NON. CONFIDENTIAL
DATE: January 17, 2003
SUBJECT: Mechanical Integrity Tests
BPX
C & F pads
C-36i, F-92i, & F-95i
Milne Point Unit
Kuparuk River Field
Well
P.T.D.
Notes:
P.T.D.
Notes:
Well
P.T.D.
Notes:
Packer Depth Pretest Initial 15 Min. 30 Min.
C-36i Typelnj. IMiscibleI T.V.D.I 6986 I T. .ingl4700I 4700 I4700147o0 I,nterva, I 4
198-0010 ITypetestl P ITestpsil 1747 I CasingI 10 I 2050 I 2010 I 20001 P/F I P
198-19301Type testI P ITestpsil 1847 ICasingl 10 I 2040 I 20201 2O1O1 P/F I P
198-1790 ITypetestl P ITestpsil 1828 I CasingI 1450I 2100I 2100I 2100I P/F I -P
Type INJ. Fluid Codes
F = FRESH WATER INJ.
G = GAS INJ.
S = SALT WATER INJ.
N = NOT INJECTING
Type Test
M= Annulus Monitoring
P= Standard Pressure Test
R= Internal Radioactive Tracer Survey
A= Temperature Anomaly Survey
D= Differential Temperature Test
Test's Details
Interval
I= Initial Test
4= Four Year Cycle
V= Required by Variance
W= Test during Workover
O= Other (describe in notes)
I witnessed three Mechanical Integrity tests/n the Milne Point unit. All wells passed their test.
M.I.T.'s performed: _3
Attachments:
Number of Failures: None
Total Time during tests: 4 hours
cc: Jones/Hulme
8CANNED FEB 0 4 2003
MIT report form
5/12/00 L.G.
030117-MIT MPU LG.xls
1/27/2003
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations periormed: Operation shutdown_ Stimulate _ Plugging _
WAG SWAP Pull tubing _ Alter casing _ Repair well _
2. Name of Operator
BP Exploration (Alaska), Inc.
3. Address
P. O. Box 196612
Anchorage, AK 99519-6612
4. Location of well at surface
4326' FNL, 2378' FEL, Sec. 10, T13N, R10E, UM
At top of productive interval
2358' FNL, 1994' FEL, Sec. 08, T13N, R10E, UM
At effective depth
2324' FNL, 2230' FEL, Sec. 08, T13N, R10E, UM
At total depth
2317' FNL, 2283' FEL, Sec. 08, T13N, R10E, UM
5. Type of Well:
Development __
Explorato~__
Stratigraphic__
Service__X
(asp's 558083, 6029234)
(asp's 547889, 6031130)
(asp's 547653, 6031162)
(asp's 547600, 6031169)
12. Present well condition summary
Total depth: measured
true vertical
13896 feet Plugs (measured)
7583 feet
Effective depth: measured
true vertical
13787 feet Junk (measured)
7495 feet
Casing Length
Conductor 112'
Surface 8470'
Production 13842'
Perforate _
Other_X WAG SWAP
6. Datum elevation (DF or KB feet)
RKB 48 feet
7. Unit or Property name
Miline Point Unit
MPC-36
9. Permit number / approval number
198-0010
10. APl number
50-029-22853-00
11. Field / Pool
Miline Point Unit / Kuparuk River Sands
Size Cemented Measured Depth True Vertical Depth
20" 250 sx Arcticset 1 (approx) 145' 145'
9-5/8" 2156 sx PF 'E', 747 sx 8501' 4750'
Class 'G'
7" 225 sx Class 'G' 13871' 7561'
Perforation depth:
Tubing (size, grade, and measured depth)
Packers & SSSV (type & measured depth)
measured Open Perfs 13320'-13333', 13360'-13374', 13385'-13392', 13468'-13520', 13542'-13550'
true vertical Open Perfs 7088'-7099', 7122'-7133', 7143'-7149', 7213'-7258', 7276'- 7283'
RECEIVE1D
7" x 3-1/2" 8-3 Baker PKRs @ 13198' & 13259'; & 7" x 3-1/2" SABL-3,.~.kI~r ~'R ._.~(~:~48'.
3.5" H.E.S. 'X' Nipple @ 2141'.
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure
14.
Prior to well operation 12/11/2002
Subsequent to operation 01/21/2002
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations __
OiI-Bbl
Representative Daily Averaqe Production or Iniection Data
Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
2367 3303
1203 SCANNED FER 0 20j]3474o
I 16. Status of well classification as:
Oil__ Gas__ Suspended __ Service WAG Injector
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
,~,~L//~ .~,~~ Title: Technical Assistant
DeWayne R Schnorr
Form 10-404 Rev 06/15/88 ·
9eot s BFL
Date January 29, 2003
Prepared by DeWayne R Schnorr 564-5174
SUBMIT IN DUPLICATE
09/04/2002
12/20/2002
01/17/2003
01/22/2003
09/04/03
12/20/02
MPC-36
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
WAG SWAP --- GAS TO WATER INJECTION.
WAG SWAP --- WATER TO GAS INJECTION.
MIT --- PRESSURE TEST IA.
TESTEVENT--- INJECTION PRESSURE, PSI: 4,744 TYPE: PW VOLUME: 1210
BWPD.
EVENT SUMMARY
PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR WATER INJECTION AND
TORQUED FLANGES TO SPEC. MIRU FESCO. PT'd TO 4800 PSI. PUMPED 5
BBLS METHANOL DOWN THE TUBING @ 0.8 BPM AT 4300 PSI. SWITCHED TO
SOURCE WATER AND PUMPED 90 BBLS @ 1.0 BPM AT 4400 TO 4500 PSI & 2
BBLS METHANOL @ 1.25 BPM AT 4500 PSI. RDMO. TURNED OVER TO THE
OPERATOR TO BE PUT ON INJECTION. JOB COMPLETED WITH NO
PROBLEMS. PUT ON INJECTION @ 2000 BPD.
PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND
TORQUED FLANGES TO SPEC. MIRU FESCO. PT'd TO 4500 PSI. PUMPED 19
BBLS METHANOL DOWN THE TUBING @ 1.3 BPM AT 3850 TO 4000 PSI, AND 2
BBLS METHANOL DOWN THE FLOW LINE FOR FREEZE PROTECTION. RDMO.
WELL WAS SWAPPED TO GAS AND PUT ON INJECTION AT 2500 MSCFD.
01-17-03
TGSM. MIRU HB&R. PRESSURE TESTED SURFACE EQUIPMENT TO 3500 PSI.
PRESSURED UP ON IA TO 2050 PSI. TUBING STAYED AT 4700 PSI. HELD
PRESSURE FOR 30 MINUTES. IA CAME DOWN TO 2000 PSI AND TUBING
STAYED AT 4700 PSI. GOOD TEST. BLED IA BACK TO 0 PSI. RDMO. MIT TEST
WAS GOOD.
01/22/03
TESTEVENT --- INJECTION PRESSURE, PSI: 4,744 TYPE: PW VOLUME: 1210
BWPD
FLUIDS PUMPED
BBLS DISCRIPTION
28 METHANOL
90 SOURCE WATER
118 TOTAL
SCANNED FEB 0 & 2003
Page I
Tr~: 3 1/8"-5M WKM
Wellhead: 11"x 71/16" 5M FMC
Gen. 5A
Tb_o. Ho_r: 7 1/16" x 3.5" FMC Tbg.
Hng., 4.25 Acme LH threads x 3.5"
EUE btm, 3" CIW "H" BPV profile
20"91.1 ppf, H-40 I 113' I
KOP @ 300'
Max. hole angle = 60 to 69 deg.
f/3,000' to 12,000'
Hole angle through perfs = 31 deg.
95/8",40ppf, L-80 Btrc. I 8,501'I
MPU C-36i
.,
Orig. KB. elev. = 49.2"(N 22E)
Orig. GL. elev.= 16.6'
RT to tbg. hng. = (N 22E)
9 5/8" Howco
'ES' Cementer
3.5" HES X-Nipple
( 2.813" pkg.bore )
2,141'
3.5" 9.3 ppf, L-80, EUE tubing
(cap. = 0.0087 bpf, drift ID = 2.867")
7" 26 ppf, L-80, Btrc. production cas:ng
( drift ID = 6.151", cap. = 0.0383 bpf )
Stimulation Summary
none performed
Perforation Summary
Ref Ioq: USIT 02/05/98
ISize
4.5"
4.5"
4.5"
45"
415"
3PF
5
5
5
5
5
Interval
13,320'-13,333'
13,360'-13,374'
13,385'-13,392'
13,468'-13,520'
3,542'-13,550'
(TVD)
7,088'-7,099'
7,122'-7,134'
7,143'-7,149'
7,214'-7,259'
7,277'-7,289'
SWS 51B HJII RDX deep penetrating
Jet charges @ 60 / 120 deg. phasing
(EHD = 0.46", TTP = 34.5")
Two 7" x 20' marker joints
f/12,800' to 12,840' wlm
3.5" HES X-Nipple
( 2.813" pkg.bore )
7" Baker 'S-3' Packer
3.5" HES X-Nipple
( 2.813" pkg.bore )
Ported pup Joint
5.875" Unique machine
scoop 2' off cut stub
3.5' Cut stub (8' long)
7" Baker 'S-3' Packer
13,187'
13,198'
13,213'
13,214'
13,229'
13,231'
13,259'
3.5" Camco MMG-2 GLM I ~
1
3~322'
I
I
wi1.5" RK latch
3.5" Camco MMG-2 GLM
13,382'
w/1.5" RK latch
7" Baker'SABL-3' PackerI 13,448'
(shear anchor seal)
3.5" HES XN-Nipple I 13,467'
(w/2.75" no-go)
3.5" WLEGI 13,479'
Minimum tubing restriction = 2.75"
"XN" profile @ 13,479'
7" float collar (PBTD) I 13,787'I
7" casing shoe 13,871'
DATE REV. BY COMMENTS
02/14/98 MDO Drilled and Completed by Nabors 22E
07/12/98 M. Linder
Repair of parted tubing Nabors 4-ES
MILNE POINT UNIT
WELL C-36i
APl NO: 50-029-22853
BP EXPLORATION (AK)
SCANNED FEB 0 4 2003
-' STATE OF ALASKA "'
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_
WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other_X WAG SWAP
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet)
BP Exploration (Alaska), Inc. Development__ RKB 48 feet
3. Address Explorato~__ 7. Unit or Property name
P. O. Box 196612 Stratigraphic__
Anchorage, AK 99519-6612 Service__X Miline Point Unit
4. Location of well at surface
4326' FNL, 2378' FEL, Sec. 10, T13N, R10E, UM (asp's558083, 6029234) MPC-36
At top of productive interval 9. Permit number / approval number
2358' FNL, 1994' FEL, Sec. 08, T13N, R10E, UM (asp's 547889, 6031130) 198-0010
At effective depth 10. APl number
2324' FNL, 2230' FEL, Sec. 08, T13N, R10E, UM (asp's 547653, 6031162) 50-029-22853-00
At total depth 11. Field / Pool
2317' FNL, 2283' FEL, Sec. 08, T13N, R10E, UM (asp's 547600, 6031169) Miline Point Unit / Kuparuk Ri~er Sands
12. Present well condition summary
Total depth: measured 13896 feet Plugs (measured)
true vertical 7583 feet
Effective depth: measured 13787 feet Junk (measured)
true vertical 7495 feet
Casing Length Size Cemented Measured Depth ' 'TrueVe~.fical Depth
Conductor 112' 20" 250 sx Arcticset 1 (approx) 145' 145'
Surface 8470' 9-5/8" 2156 sx PF 'E', 747 sx 8501' 4750'
Class 'G'
Production 13842' 7" 225 sx Class 'G' 13871' 7561'
Perforation depth: measured Open Perfs 13320'-13333', 13360'-13374', 13385'-13392', 13468'-13520', 13542'-13550'
true vertical Open Perfs 7088'-7099', 7122'-7133', 7143'-7149', 7213'-7258', 7276'- 7283'
Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 TBG to 13479' MD.
Packers & SSSV (type & measured depth) 7" x 3-1/2" S-3 Baker PKRs @ 13198' & 13259'; & 7" x 3-1/2" SABL-3 Baker PKR @ 13448'.
3.5" H.E.S. 'X' Nipple @ 2141'.
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure
14. Representative Daily Average Production or Iniection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 12/31/2001 2602 4097
Subsequent to operation 01/15/2002 1724 2710
15. Attachments 16. Status of well classification as:
Copies of Logs and Surveys run __
Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service WAG Iniector
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
- -- .- '-- /~- '" .~,~ or~~~..~~ Title: Technical Assistant Date January 16, 2002
DeWayne R. Sc orr ~ Prepared by DeWayne R. Schnorr 564-5174
Form 10-404 Rev 06/15/88 ·
SUBMIT IN DUPLICATE
MPC-36
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
01/10/2002 SWAP WELL FROM GAS TO WATER INJECTION.
EVENT SUMMARY
01/10/02
WELL SUPPORT RIGGED UP AND SWAPPED BLINDS AND TORQUE TO SPEC.
HB&R RIGGED UP AND PUMPED 10 BBLS METHANOL, PUMPED AT 1.5 BPM
FROM 4150 TO 3925 PSI. PUMPED 80 BBLS SOURCE WATER, PUMPED AT 2.5
BPM FROM 3925 TO 3200 PSI. SWITCHED TO METHANOL, PUMPED 2 BBLS.
PUT ON WATER INJECTION.
FLUIDS PUMPED
BBLS DISCRIPTION
12 METHANOL
80 SOURCE WATER
92 TOTAL
Page 1
.
.
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Dan Seamount 0.77 DATE: July 12, 2000
Commissioner' tf I/eyb(.-:.)
THRU: Blair Wondzell, Q3~
P. I. Supervisor .9f1(d:J
FROM: Jeff Jone~, I:!¡-- SUBJECT: Safety Valve Tests
Petroleum I sp c r Milne Point Unit
8 & C Pads
Julv 9. 2000: I traveled to BP's Milne Point Field to witness Safety Valve System
tests on MPU B & C Pads.
Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles.
Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV
failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold
DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28
SV failed to test because the tree cap o-ring leaked. The AOGCC test reports
are attached for reference.
Well house inspections were done on 21 well houses. All well houses inspected
were clean and in satisfactory condition.
SUMMARY: I witnessed SVS tests on BP's MPU 8 & C pads.
MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate.
MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3 jvp... r-<...f:z-<;>-(-
21 well houses were inspected, no failures. -r
Attachments: SVS MPU B-PAD 7-9-00 JJ
SVS MPU C-PAD 7-9-00 JJ
cc;
NON-CONFIDENTIAL
SVS MPU B & C PADS 7-12-00 JJ.doc
.
.
Alaska Oil and Gas Conservation Commission
Safety Valve System Test Report
Operator: BPX
Operator Rep: Larry Niles
AOGCC Rep: Jeff Jones
Submitted By: Date:
FieldlUnitlPad: Kuparuk River/MPU/C-Pad
Separator psi: LPS 140 HPS
7/9/00
!%a"
~
,/
.l\'ell Data I . I ~ .' pOI' ,'.. '; t.I,,!!:.,"I.'.. .:I'S f'::;' . ss\r: '~~'~"~ '~'} ~~:,' ii~. ?~: ~~: 1}., ',~fel1-,Tyþe>.
1-'., .. . , I ,0/ S . ';' . ; ~ t '! "~I :. :.- , '. 1\
. . '.' ~ ~ r - I .. . - 'I .
Well Permit Separ Set LIP Test Test Test
Number Number PSI PSI Trip Code Code Code Oil, WAG, GIN.J,
GAS or CYCLE
;, '<#~O l,t~~ .1'.;1/ 1811430 140 100 95 P P OIL
C-03 1820500 140 100 95 P P OIL
C-04 1821260 140 100 100 P 4 OIL
C-05A 1842430 140 100 100 P 4 OIL
C-07 1850020 140 100 100 P P OIL
C-08 1850140
C-09 1850360 140 100 120 P 4 OIL
C-13 1850670
C-14 1850880 140 100 100 P P OIL
C-15 1851030
C-17 1852630
C-20 1890150
C-21 1940800
C-22A 1951980 140 100 95 P P OIL
C-23 1960160
C-25A 1960210 4000 2000 2000 P 4 WAG
C-26 1952060
C-28 1960290 4000 2000 2000 P 43 WAG
C-36 1980010
C-39 1972480
C-02 1821940 4000 1900 P P WAG
C-06 1842410 4000 1900 P 4 WAG
12 Conzponents:
23 Failures:
6 Failure Rate: 26.0%090 Day
Wells:
Rcmarks:
Wells # C-02 & C-06 are listed as water injection wells, and are not in this database
Well # C-28 SV could not be pressure tested because the tree cap a-ring leaked.
The SV on well # C-07 recorded a slow closing time;(2:27).
Larry Niles, the BP representative, said he would have these iteITIS corrected.
8/7/00
Page 1 of]
VI v7irqm.xls
198-001-0 MILNE POINT UNIT C-36 50- 029-22853-00 BP EXPLORATION
MD 13896 TVD 07583 t~C~ompletion Date: ~'/10/98 Completed Status: WAGIN Current:
T Name
PERF
Interval Sent Received T/C/D
D 8720
D 9304 ~ PDS INJP
L DG/CNP/SLD-MD ~lq"~L' 41'/63-13896
L~SED:IgID- ~A~L~ 47.20 -8~ )
L DGR/CNP/SLD-TVD (_.,,,,FINAL f~-07583
L --DGR/CNP/SLDft'VD ,' ....... FINAL~"'4~5'7~6767~
L ~r'~,~R&-MD ............ FINAL-- 57-2~8248-- ')
L DGR/EWR4-MD LF~AL 4163-13896
L---IX3R4~-4-=~'D .............FrNAE--4~57-~67 d?~
/
L INJP L~I~AL 13220-13668
R MWDSRVY ~~Y 0-13896.
Was the well cored? yes ~
Comments:
SPERRY MPT/GR/EWR4/CNP/SLD
CH 2/25/98 2/26/98
OH 9/9/98 9/9/98
CH 9/13/99 9/13/99
OH 9/16/98 9/16/98
OH 3/11/98 g/44¢98
OH 9/16/98 9/16/98
OH 3/11/98 3/444.98
OH 3/11/98 .3/~1A4-98
OH 9/16/98 9/1 ~/98
OH 3/11/98 ~14:/987
OH 9/16/98 9/16/98
CH 5 9/13/99 9/13/99 D
CH 5 3/23/98 3/25/98
OH 1/22/99 1/25/99
Dry Ditch Samples Required? yes ~____~And Received?~-yes-.ao~-
Are
Analysis Description Received9 mple
Thursday, February 03, 2000 Page 1 of 1
~_~Active Diagnostic Services, Inc.
TO:
State of Alaska AOGCC
Lori Taylor
3001 Porcupine St.
Anchorage, Alaska 99501
RE: Distribution - Final Print(s)
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning
a signed copy of this transmittal letter to the attention of:
ll~~ll~~obert Richey
PDS, Inc.
Mail Pouch 340112
Prudhoe Bay, AK 99734
BP Exploration (Alaska), Inc.
Petro-Technical Data Center, MB 3-3
900 E. Benson Blvd.
Anchorage, Alaska 99508
LOG DIGITAL MYLAR / BLUE
WELL DATE TYPE DATA SEPIA FILM LINE
PRINT(S)
Open Hole I i . ~;~,, 1
Signed ' -~~
Print Name:
Date:
ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734
Phone: (907)659-2307 Fax: (907)659-2314 E-mail: pdsprudhoe@NA800.net Website: www.memorylog.com
C:kMy DocumentskExcel_Word_DocumentskDistribution_FormskBp_rnilpt_form.doc
STATE OF ALASKA ....
ALASKA OIL AND GAS CONSERVATION COMMISSION ~,...~i~:~ ~ ~,"; ': ~,~q,_~,~
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service V~.6~li0:~
[] Oil [] Gas [] Suspended [] Abandoned [] Service Water & Gas Injector
2. Name of Operator 7. Permit Number
BP Exploration (Alaska)Inc. 98-001
3. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22853
~' 9. Unit or Lease Name
4. Location of well at surface :' '.,'i ,i:7:L: i-¥~-I ( :~ ~~ Milne Point Unit
952' NSL, 2378' WEL, SEC. 10, T13N, R10E, UM .......... t
i ~~-~"-/~'¢~' !~1 10. Well Number
At top of productive interval .... '~
2921' NSL, 1995' WEL, SEC. 8, T13N, R10E, UM ~- ' MPC-36
Attotal depth ~~ii i 11. Field and Pool
2969' NSL, 2286' WEL, SEC. 8, T13N R10E, UM .....
~ -- ..... . ...... Milne Point Unit / Kuparuk River
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands
KBE = 48.20'I ADL 025509
12. Date Spudded1/22/98 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if OffshOre 116' NO' Of cOmpletiOns1/31/98 2/10/98 N/A MSLI One
17. Total Depth(MD+TVD) 18. Plug BackDepth(MD+TVD)I19. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost
13896 7583 FT 13787 7495 FTI [~Yes F-INo 'x' nipple at 2182' MD 1800' (Approx.)
22. Type Electric or Other Logs Run ~.~
MWD, GR/REs/Dens/Neu, USIT 0 ~ i ¢"~ ' i\l/_~ '
23. CASING, LINER AND CEMENTING RECORD ~ t~ i L
CASING SETTING DEPTH HOLE
SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED
20" 91.1 # H-40 33' 112' 24" 250 SX Arcticset I (Approx.)
9-5/8" 40# L-80 31' 8501' 12-1/4" ;2156 sx PF 'E', 747 sx Class 'G'
7" 26# L-80 29' 13871' 8-1/2" ;225 sx Class 'G'
24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD
Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
4-1/2" Gun Diameter, 5 spf 3-1/2", 9.3#, L-80 13479' 7" Baker Packer @ 13259'
M D TVD M D TVD Baker SABL-3 Packer @ 13448'
13542' - 13550' 7276' - 7283'
13468' - 13520' 7213' - 7258' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
13385' - 13392' 7143' - 7149' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
13360' - 13374' 7122' - 7133'
13320' - 13333' 7088' - 7099' Freeze protect with 75 bbls Diesel
:27. PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
December 9, 1998I Other (explain) Water and Gas Injection
Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE I GAS-OIL RATIO
TEST PERIOD
I
Flow Tubing Casing Pressure CALCULATED OIL-EEL GAS-MCF WATER-EEL O~L GRAWTY-API (CORR)
Press. 24-HOUR RATE
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
Form 10-407 Rev. 07-01-80 Submit In Duplicate
29. Geologic Markers 30. Formation Tests
Measured True Vertical Include interval tested, pressure data, all fluids
Marker Name Depth Depth recovered and gravity, GOR, and time of each phase.
Top Kuparuk 'C' 13319' 7087'
Top Kuparuk 'A3' 13467' 7212'
Top Miluveach 13550' 7283'
i31. List of Attachments
Summary of Daily Drilling Reports, Surveys
Charles R. Mallary ~fv~.........~-__ Title Drilling Superintendent Date
I
¥
MPC-36 ~'98-001 Prepared By Name/Number: Carol Withey, 564-4114
Well Number Permit No. / Approval No.
INSTRUCTIONS
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and
leases in Alaska.
ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water
supply for injection, observation, injection for in-situ combustion.
ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces
on this form and in any attachments.
ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item
16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional
interval to be separately produced, showing the data pertinent to such interval.
ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of
the cementing tool.
ITEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In,
Other-explain.
ITEM 28: If no cores taken, indicate 'none'.
Form 10-407 Rev. 07-01-80
Facility
M Pt C Pad
Progress Report
Well MPC-36
Rig N abors~~0-~¢
Page
Date
1
21 January 99
Date/Time
21 Jan 98
22 Jan 98
23 Jan 98
24 Jan 98
25 Jan 98
26 Jan 98
27 Jan 98
28 Jan 98
01:00-01:30
01:30-06:00
06:00-14:00
14:00-23:30
23:30-00:00
00:00-01:00
01:00-06:00
06:00-06:00
06:00-14:30
14:30-16:00
16:00-18:30
18:30-20:00
20:00-22:00
22:00-01:00
01:00-03:30
03:30-04:00
04:00-05:00
05:00-06:00
06:00-13:00
13:00-14:30
14:30-16:00
16:00-16:30
16:30-05:30
05:30-06:00
06:00-08:00
08:00-11:00
11:00-12:00
12:00-14:30
14:30-18:00
18:00-18:30
18:30-22:30
22:30-23:00
23:00-23:30
23:30-02:30
02:30-04:30
04:30-06:00
06:00-06:30
06:30-09:30
09:30-14:30
14:30-17:30
17:30-20:00
20:00-22:00
22:00-22:30
22:30-06:00
06:00-09:00
09:00-11:30
11:30-12:00
12:00-14:30
14:30-18:30
18:30-21:00
21:00-23:30
23:30-01:00
01:00-05:30
05:30-06:00
Duration
1/2 hr
4-1/2 hr
8hr
9-1/2 hr
1/2 hr
1 hr
5hr
24 hr
8-1/2 hr
1-1/2 hr
2-1/2 hr
1-1/2 hr
2 hr
3 hr
2-1/2 hr
1/2 hr
1 hr
1 hr
7 hr
1-1/2 hr
1-1/2 hr
1/2 hr
13hr
1/2 hr
2 hr
3 hr
1 hr
2-1/2 hr
3-1/2 hr
1/2 hr
4 hr
1/2 hr
1/2 hr
3 hr
2 hr
1-1/2 hr
1/2 hr
3 hr
5 hr
3 hr
2-1/2 hr
2 hr
1/2 hr
7-1/2 hr
3 hr
2-1/2 hr
1/2 hr
2-1/2 hr
4 hr
2-1/2 hr
2-1/2 hr
1-1/2 hr
4-1/2 hr
1/2 hr
Activity
Held safety meeting
Rig moved 60.00 %
Rig moved 100.00 %
Rigged up Divertor
Held safety meeting
Circulated at 0.0 ft
Made up BHA no. 1
Drilled to 3235.0 ft
Drilled to 4166.0 ft
Circulated at 4166.0 ft
Pulled out of hole to 909.0 ft
Pulled BHA
Serviced Top drive
Made up BHA no. 2
R.I.H. to 4166.0 ft
Drilled to 4236.0 ft
Serviced Mud pumps
Drilled to 4532.0 fl
Drilled to 5773.0 ft
Circulated at 5773.0 ft
Pulled out of hole to 4166.0 ft
R.I.H. to 5773.0 ft
Drilled to 7585.0 ft
Circulated at 7585.0 ft
Circulated at 7585.0 ft
Pulled out of hole to 927.0 ft
Serviced Top drive
R.I.H. to 7585.0 ft
Drilled to 7967.0 fl
Serviced Mud pumps
Drilled to 8443.0 fl
Serviced Mud shakers
Drilled to 8537.0 fl
Circulated at 8537.0 ft
Pulled out of hole to 4166.0 ft
R.I.H. to 8537.0 ft
R.I.H. to 8537.0 ft
Circulated at 8537.0 ft
Pulled out of hole to 927.0 ft
Pulled BHA
Rigged up Casing handling equipment
Serviced Casing stabbing board
Held safety meeting
Ran Casing to 5982.0 ft (9-5/8in OD)
Ran Casing to 8501.0 ft (9-5/8in OD)
Circulated at 8501.0 ft
Held safety meeting
Mixed and pumped slurry - 522.500 bbl
Circulated at 2155.0 ft
Mixed and pumped slurry - 463.000 bbl
Rigged down Casing handling equipment
Rigged down Divertor
Rigged up BOP stack
Tested BOP stack
Progress Report
Facility M Pt C Pad
Well MPC-36
Rig Nabors~ ~'
Page 2
Date 21 January 99
Date/Time
06:00-10:30
10:30-12:00
12:00-14:00
14:00-18:00
18:00-19:30
19:30-20:30
20:30-06:00
29 Jan 98 06:00-06:30
06:30-07:00
07:00-09:30
09:30-10:30
10:30-01:30
30 Jan 98 01:30-02:30
02:30-05:00
05:00-06:00
06:00-07:00
07:00-19:30
19:30-21:00
21:00-22:30
22:30-23:30
23:30-06:00
31 Jan 98 06:00-06:30
06:30-09:30
09:30-19:00
19:00-21:00
21:00-00:30
01 Feb 98 00:30-01:30
01:30-03:30
03:30-06:00
06:00-07:30
07:30-08:00
08:00-15:00
15:00-19:00
19:00-20:00
20:00-20:30
20:30-05:00
02 Feb 98 05:00-06:00
06:00-13:00
13:00-15:00
15:00-16:30
16:30-17:00
: 17:00-22:30
22:30-00:00
03 Feb 98 00:00-02:00
02:00-04:00
04:00-06:00
06:00-09:00
09:00-11:30
11:30-04:00
04 Feb 98 04:00-05:00
05:00-06:00
06:00-10:00
10:00-12:00
12:00-12:30
Duration
4-1/2 hr
1-1/2 hr
2 hr
4 hr
1-1/2 hr
1 hr
9-1/2 hr
1/2 hr
1/2 hr
2-1/2 hr
1 hr
15hr
1 hr
2-1/2 hr
1 hr
1 hr
12-1/2 hr
1-1/2 hr
1-1/2 hr
1 hr
6-1/2 hr
1/2 hr
3 hr
9-1/2 hr
2hr
3-1/2 hr
1 hr
2 hr
2-1/2 hr
1-1/2 hr
1/2 hr
7 hr
4 hr
1 hr
1/2 hr
8-1/2 hr
1 hr
7 hr
2 hr
1-1/2 hr
1/2 hr
5-1/2 hr
1-1/2 hr
2 hr
2 hr
2hr
3 hr
2-1/2 hr
16-1/2 hr
1 hr
1 hr
4 hr
2 hr
1/2 hr
Activity
Tested BOP stack
Made up BHA no. 2
Serviced Draw works
Made up BHA no. 2
R.I.H. to 2155.0 ft
Drilled installed equipment - DV collar
R.I.H. to 8414.0 ft
R.I.H. to 8414.0 ft
Tested Casing
Drilled installed equipment - Float shoe
Performed formation integrity test
Drilled to 10415.0 ft
Circulated at 10415.0 ft
Pulled out of hole to 8501.0 ft
Serviced Top drive
R.I.H. to 10415.0 ft
Drilled to 12217.0 ft
Circulated at 12217.0 ft
Pulled out of hole to 10315.0 ft
R.I.H. to 12217.0 ft
Drilled to 12874.0 ft
Drilled to 12968.0 ft
Circulated at 12968.0 ft
Drilled to 13896.0 ft
Circulated at 13896.0 ft
Pulled out of hole to 8500.0 ft
Serviced Top drive
R.I.H. to 13896.0 ft
Circulated at 13896.0 ft
Circulated at 13896.0 ft
Took EMS survey at 13896.0 ft
Pulled out of hole to 771.0 ft
Pulled BHA
Rigged up Casing handling equipment
Held safety meeting
Ran Casing to 8480.0 ft (7in OD)
Circulated at 8480.0 ft
Ran Casing to 13871.0 ft (7in OD)
Circulated at 13871.0 ft
Mixed and pumped slurry - 46.100 bbl
Tested Casing
Monitor wellbore pressures
Bleed down well
Installed Seal assembly
Rigged down BOP stack
Rigged up BOP stack
Rigged up BOP stack
Rigged up Top ram
Laid down 13132.0 ft of 5in OD drill pipe
Rigged up Bell nipple
Tested BOP stack
Tested BOP stack
Serviced Block line
Tested Internal BOPs
Facility
M Pt C Pad
Progress Report
Well MPC-36 ' Page 3
Rig NaborsE4~S~ c2~-5 Date 21 January 99
Date/Time
05 Feb 98
06 Feb 98
07 Feb 98
08 Feb 98
09 Feb 98
10 Feb 98
12:30-03:30
03:30-06:00
06:00-09:00
09:00-16:00
16:00-18:00
18:00-19:30
19:30-02:30
02:30-05:00
05:00-05:30
05:30-06:00
06:00-06:30
06:30-10:00
10:00-12:00
12:00-15:00
15:00-18:00
18:00-21:30
21:30-01:30
01:30-06:00
06:00-09:00
09:00-10:00
10:00-12:00
12:00-21:00
21:00-05:00
05:00-06:00
06:00-23:30
23:30-01:30
01:30-06:00
06:00-06:30
06:30-10:30
10:30-15:30
15:30-18:00
18:00-18:30
18:30-20:30
20:30-23:30
23:30-01:30
01:30-02:30
02:30-06:00
06:00-06:30
06:30-08:00
08:00-13:00
13:00-17:00
Duration
15hr
2-1/2 hr
3 hr
7 hr
2 hr
1-1/2 hr
7 hr
2-1/2 hr
1/2 hr
1/2 hr
1/2 hr
3-1/2 hr
2 hr
3 hr
3hr
3-1/2 hr
4hr
4-1/2 hr
3 hr
1 hr
2 hr
9 hr
8 hr
1 hr
17-1/2 hr
2 hr
4-1/2 hr
1/2 hr
4 hr
5 hr
2-1/2 hr
1/2 hr
2 hr
3 hr
2 hr
1 hr
3-1/2 hr
1/2 hr
1-1/2 hr
5 hr
4 hr
Activity
Ran Tubing to 13787.0 ft (3-1/2in OD)
Circulated at 13787.0 ft
Circulated at 13787.0 ft
Pulled out of hole to 0.0 ft
Installed Additional services
Conducted electric cable operations
Conducted electric cable operations
Conducted electric cable operations
Held safety meeting
Conducted electric cable operations
Held safety meeting
Conducted electric cable operations
Conducted electric cable operations
Perforated
Perforated
Perforated
Perforated
Perforated
Perforated
Conducted electric cable operations
Serviced Top drive
Ran Tubing in stands to 13787.0 ft
Pulled out of hole to 0.0 ft
Rigged up Additional services
Ran Tubing to 13400.0 ft (3-1/2in OD)
Pulled Tubing in stands to 0.0 ft
Installed Top drive
Held safety meeting
Ran Drillpipe to 2018.0 ft (3-1/2in OD)
Worked toolstring at 2018.0 ft
Ran Tubing to 2018.0 ft (3-1/2in OD)
Held safety meeting
Rigged up sub-surface equipment - Slickline / braided cable
R.I.H. to 13236.0 ft
Ran Tubing to 1941.0 ft (3-1/2in OD)
Rigged down sub-surface equipment - Downhole tools
Rigged down BOP stack
Held safety meeting
Rigged down BOP stack
Installed Xmas tree
Laid down 2100.0 ft of Drillpipe
Performance Enquiry Report
Operator BP Exploration Date 02:36, 22 Jan 99
Page 1
The analysis is from - 10:30, 29 Jan 98 - to - 10:30, 29 Jan 98
Programs in Result Table: MPC-36 Drill and Complete
Well Type Time From Time To Duration Description E.M.W. (equivalent mud weight)
MPC-36 Event 10:30, 29 Jan 98 10:30, 29 Jan 98 0 hr 0 min Obtained leak off 14.1
Hole Size MDR
8-1/2
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
SHARED SERVICES DRILLING
MPU / MPC-36
500292285300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 2/12/98
.PAGE 1
DATE OF SURVEY: 013198
MWD SURVEY
JOB NUMBER: AKMM80102
KELLY BUSHING ELEV. = 48.20 FT.
OPERATOR: BP EXPLORATION
TRUE SUB-SEA COURS COURSE DLS TOTAL
MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT.
DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT.
.00 .00 -48.20 0 0 N .00 E .00
203.36 203.36 155.16 0 33 N 68.45 W .27
294.93 294.91 246.71 1 20 N 61.81 W .87
384.47 384.39 336.19 2 40 N 67.39 W 1.51
475.94 475.72 427.52 3 39 N 72.31 W 1.11
.00N .00E .00
.36N .91W .96
1.03N 2.26W 2.41
2.33N 5.12W 5.46
4.03N 9.87W 10.46
567.41 566.98 518.78 4 4 N 75.37 W .51
657.15 656.40 608.20 5 30 N 78.38 W 1.62
752.12 750.76 702.56 7 18 N 79.74 W 1.90
841.74 839.42 791.22 9 22 N 81.09 W 2.32
931.92 928.11 879.91 11 23 N 80.75 W 2.23
5.74N 15.80W 16.60
7.42N 23.11W 24.10
9.41N 33.52W 34.70
11.56N 46.35W 47.70
14.13N 62.40W 63.94
1023.49 1017.44 969.24 13 57 N 79.33 W 2.83
1114.61 1105.26 1057.06 16 55 N 79.36 W 3.25
1203.19 1189.63 1141.43 18 31 N 79.04 W 1.82
1298.25 1278.77 1230.57 22 4 N 77.87 W 3.75
1388.74 1361.88 1313.68 24 28 N 78.33 W 2.67
17.63N 82.18W 84.03
22.11N 106.02W 108.29
27.17N 132.50W 135.25
33.79N 164.80W 168.22
41.16N 199.78W 203.97
1486.96 1450.37 1402.17 26 52 N 78.68 W 2.45
1578.83 1532.24 1484.04 27 6 N 79.29 W .38
1671.12 1614.67 1566.47 26 20 N 79.56 W .83
1764.78 1698.22 1650.02 27 22 N 80.05 W 1.14
1855.89 1778.34 1730.14 29 27 N 79.54 W 2.29
49.63N 241.49W 246.52
57.60N 282.41W 288.21
65.22N 323.20W 329.70
72.70N 364.85W 372.02
80.39N 407.51W 415.36
1949.67 1858.87 1810.67 32 12 N 78.76 W 2.96
2043.04 1936.43 1888.23 35 26 N 78.46 W 3.47
2137.17 2011.91 1963.71 37 54 N 77.32 W 2.72
2229.67 2084.04 2035.84 39 34 N 77.34 W 1.81
2321.34 2153.98 2105.78 40 57 N 77.10 W 1.51
89.45N 454.70W 463.41
99.71N 505.63W 515.37
111.52N 560.59W 571.56
124.22N 617.06W 629.42
137.32N 674.84W 688.64
2414.17 2222.56 2174.36 43 46 N 77.63 W 3.06
2506.30 2287.33 2239.13 46 51 N 76.46 W 3.46
2600.24 2349.59 2301.39 50 7 N 77.59 W 3.59
2692.17 2407.48 2359.28 51 48 N 77.14 W 1.88
2782.41 2461.59 2413.39 54 30 N 80.29 W 4.08
151.00N 735.88W 751.17
165.70N 799.71W 816.63
181.48N 868.25W 886.92
197.10N 937.92W 958.28
211.19N 1008.73W 1030.48
2875.05 2513.25 2465.05 57 42 N 80.64 W 3.48
2966.31 2560.69 2512.49 59 38 N 79.32 W 2.45
3057.77 2605.59 2557.39 61 32 N 79.38 W 2.08
3150.55 2648.39 2600.19 63 31 N 79.33 W 2.13
3241.25 2687.34 2639.14 65 35 N 80.65 W 2.64
223.92N 1084.55W 1107.34
237.49N 1161.30W 1185.27
252.21N 1239.59W 1264.93
267.42N 1320.48W 1347.24
281.64N 1401.12W 1429.11
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA.
· PAGE 2
SHARED SERVICES DRILLING
MPU / MPC-36
500292285300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 2/12/98
DATE OF SURVEY: 013198
MWD SURVEY
JOB NUMBER: AKMM80!02
KELLY BUSHING ELEV. = 48.20 FT.
OPER~_TOR: BP EXPLORATION
TRUE SUB-SEA COURS COURSE DLS TOTAL
MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT.
DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT.
3332.52 2724.17 2675.97 66 48 N 80.23 W 1.38
3428.30 2762.09 2713.89 66 33 N 79.92 W .39
3523.90 2800.50 2752.30 66 3 N 79.95 W .53
3618.83 2839.21 2791.01 65 49 N 79.76 W .30
3714.94 2878.74 2830.54 65 36 N 80.05 W .35
295.51N 1483.47W 1512.59
310.67N 1570.11W 1600.53
325.97N 1656.30W 1688.06
341.24N 1741.62W 1774.73
356.59N 1827.87W 1862.33
3810.40 2916.77 2868.57 67 25 N 80.16 W 1.91
3905.87 2954.51 2906.31 66 0 N 79.79 W 1.54
4001.24 2993.51 2945.31 65 43 N 80.49 W .73
4096.70 3031.81 2983.61 66 58 N 78.74 W 2.13
4163.08 3058.34 3010.14 65 55 N 76.82 W 3.09
371.64N 1914.11W 1949.86
386.90N 2000.46W 2037.53
401.80N 2086.20W 2124.55
417.57N 2172.20W 2211.97
430.44N 2231.66W 2272.79
4252.16 3095.99 3047.79 64 3 N 76.74 W 2.09
4348.76 3137.83 3089.63 64 36 N 75.70 W 1.13
4444.17 3177.88 3129.68 65 45 N 75.74 W 1.20
4539.70 3216.09 3167.89 67 5 N 76.17 W 1.46
4634.92 3252.20 3204.00 68 20 N 76.13 W 1.31
448.90N 2310.23W 2353.44
469.64N 2394.79W 2440.40
491.00N 2478.71W 2526.85
512.25N 2563.64W 2614.27
533.34N 2649.18W 2702.26
4730.96 3287.65 3239.45 68 20 N 75.82 W .30
4826.39 3323.15 3274.95 67 58 N 75.96 W .41
4921.81 3358.53 3310.33 68 30 N 75.29 W .86
5017.48 3394.21 3346.01 67 41 N 75.25 W .86
5112.83 3431.09 3382.89 66 48 N 75.51 W .97
554.97N 2735.78W 2791.39
576.56N 2821.68W 2879.83
598.56N 2907.53W 2968.29
621.13N 2993.37W 3056.86
643.33N 3078.45W 3144.60
5208.14 3469.16 3420.96 66 7 N 75.29 W .74
5302.44 3507.24 3459.04 66 14 N 76.47 W 1.15
5399.54 3545.74 3497.54 67 2 N 77.52 W 1.29
5494.99 3583.26 3535.06 66 39 N 76.87 W .74
5588.68 3620.40 3572.20 66 38 N 78.84 W 1.93
665.35N 3163.01W 3231.80
686.39N 3246.66W 3317.93
706.45N 3333.51W 3407.01
725.90N 3419.09W 3494.73
743.99N 3503.17W 3580.71
5684.27 3657.39 3609.19 67 49 N 80.20 W 1.81
5779.89 3693.25 3645.05 68 6 N 81.17 W .99
5875.59 3728.85 3680.65 68 13 N 80.75 W .42
5971.09 3764.18 3715.98 68 20 N 79.50 W 1.22
6066.97 3799.31 3751.11 68 39 N 80.09 W .66
760.02N 3589.84W 3668.84
774.37N 3677.30W 3757.44
788.32N 3765.03W 3846.23
803.54N 3852.43W 3934.93
819.34N 3940.23W 4024.13
6162.23 3833.43 3785.23 69 21 N 80.20 W .74
6257.87 3867.44 3819.24 68 59 N 79.41 W .86
6353.29 3901.33 3853.13 69 24 N 77.88 W 1.56
6449.06 3935.76 3887.56 68 27 N 79.43 W 1.80
6543.58 3970.52 3922.32 68 22 N 77.72 W 1.68
834.57N 4027.86W 4113.05
850.39N 4115.84W 4202.43
867.95N 4203.28W 4291.62
885.53N 4290.89W 4380.97
902.94N 4377.03W 4468.86
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
SHARED SERVICES DRILLING
MPU / MPC-36
500292285300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 2/12/98
DATE OF SURVEY: 013198
MWD SURVEY
JOB NUMBER: AKMM80102
PAGE 3
KELLY BUSHING ELEV. = 48.20 FT.
OPERATOR: BP EXPLORATION
TRUE SUB-SEA COURS COURSE DLS TOTAL
MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT.
DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT.
6639.09 4005.77 3957.57 68 18 N 79.23 W 1.47
6734.71 4041.73 3993.53 67 31 N 79.09 W .83
6830.23 4078.48 4030.28 67 13 N 79.33 W .38
6925.98 4115.37 4067.17 67 26 N 77.43 W 1.84
7021.55 4151.80 4103.60 67 45 N 79.09 W 1.64
920.67N 4464.00W 4557.61
937.33N 4551.02W 4646.21
953.84N 4637.63W 4734.38
971.64N 4724.16W 4822.71
989.61N 4810.66W 4911.05
7116.77 4187.92 4139.72 67 40 N 79.99 W .88 1005.61N 4897.30W 4999.15
7212.14 4224.19 4175.99 67 37 N 79.64 W .34 1021.20N 4984.11W 5087.35
7307.31 4260.23 4212.03 67 52 N 79.38 W .37 1037.24N 5070.72W 5175.43
7403.35 4297.26 4249.06 66 45 N 79.75 W 1.23 1053.29N 5157.86W 5264.03
7496.39 4335.16 4286.96 65 10 N 79.18 W 1.79 1068.82N 5241.39W 5348.99
7592.59 4375.58 4327.38 65 8 N 79.76 W .55 1084.77N 5327.21W 5436.28
7687.63 4415.66 4367.46 64 58 N 80.11 W .38 1099.83N 5412.06W 5522.44
7780.97 4454.94 4406.74 65 15 N 80.56 W .54 1114.05N 5495.53W 5607.09
7876.28 4494.64 4446.44 65 30 N 80.27 W .38 1128.48N 5580.97W 5693.72
7971.74 4534.32 4486.12 65 22 N 80.46 W .23 1143.01N 5666.57W 5780.52
8066.83 4573.72 4525.52 65 40 N 80.49 W .32 1157.33N 5751.92W 5867.03
8163.01 4613.29 4565.09 65 44 N 80.74 W .25 1171.62N 5838.41W 5954.66
8258.27 4652.48 4604.28 65 40 N 80.65 W .11 1185.66N 5924.09W 6041.45
8354.23 4691.49 4643.29 66 20 N 81.07 W .80 1199.59N 6010.65W 6129.08
8449.75 4729.40 4681.20 66 54 N 81.69 W .84 1212.73N 6097.33W 6216.68
8532.69 4761.68 4713.48 67 16 N 79.57 W 2.40 1225.17N 6172.70W 6293.04
8628.78 4799.48 4751.27 66 24 N 81.84 W 2.36 1239.44N 6259.86W 6381.33
8724.47 4838.28 4790.08 65 45 N 83.14 W 1.42 1250.87N 6346.57W 6468.63
8819.59 4878.03 4829.83 64 50 N 83.96 W 1.24 1260.58N 6432.44W 6554.77
8915.43 4917.65 4869.45 66 19 N 82.37 W 2.16 1270.97N 6519.06W 6641.80
9010.77 4956.33 4908.13 65 48 N 82.86 W .71 1282.17N 6605.48W 6728.77
9106.54 4993.81 4945.61 68 5 N 81.92 W 2.56 1293.85N 6692.81W 6816.73
9201.28 5028.58 4980.38 68 50 N 79.49 W 2.51 1308.08N 6779.76W 6904.80
9297.19 5063.83 5015.63 68 2 N 79.73 W .87 1324.17N 6867.50W 6993.99
9392.78 5099.88 5051.68 67 38 N 80.38 W .76 1339.46N 6954.69W 7082.50
9487.71 5136.55 5088.35 66 54 N 81.06 W 1.01 1353.58N 7041.10W 7170.02
9584.30 5i75.07 5126.87 66 5 N 82.01 W 1.24 1366.62N 7128.71W 7258.51
9679.91 5213.46 5165.26 66 33 N 80.04 W 1.95 1380.28N 7215.19W 7346.01
9775.6! 5250.00 5201.80 68 32 N 78.43 W 2.59 1396.8tN 7302.06W 7434.44
9870.22 5285.50 5237.30 67 22 N 79.29 W 1.49 !413.75N 7388.09W 7522.13
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 4
SHARED SERVICES DRILLING
MPU / MPC-36
500292285300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 2/12/98
DATE OF SURVEY: 013198
MWD SURVEY
JOB NUMBER: AKMM80102
KELLY BUSHING ELEV. = 48.20 FT.
OPERATOR: BP EXPLORATION
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS
INCLN
DG MN
COURSE DLS TOTAL
DIRECTION RECTANGULAR COORDINATES
DEGREES DG/100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
9965.99 5323.14 5274.94
10060.24 5361.50 5313.30
10156.78 5399.41 5351.21
10252.09 5435.41 5387.21
10345.34 5470.09 5421.89
66 19
65 38
68 6
67 30
68 49
N 79.56 W 1.13 1429.91N 7474.66W
N 80.40 W 1.09 1444.89N 7559.43W
N 79.43 W 2.72 1460.44N 7646.83W
N 79.69 W .68 1476.44N 7733.62W
N 79.00 W 1.56 1492.44N 7818.68W
7610.18
7696.26
7785.02
7873.27
7959.82
10440.53 5504.75 5456.55 68 28
10535.58 5539.70 5491.50 68 23
10631.22 5575.43 5527.23 67 43
10725.31 5610.48 5562.28 68 31
10821.37 5646.15 5597.95 67 52
N 80.01 W 1.05 1508.59N 7905.85W
N 79.21 W .79 1524.53N 7992.79W
N 79.20 W .69 1541.15N 8079.93W
N 77.88 W 1.56 1558.50N 8165.50W
N 77.38 W .84 1577.60N 8252.62W
8048.47
8136.86
8225.57
8312.87
8402.04
10916.50 5682.36 5634.16
11011.78 5719.25 5671.05
11106,74 5756.59 5708.39
11202.16 5794.95 5746.75
11296.62 5833.74 5785.54
67 22
67 3
66 37
65 58
65 32
N 78.44 W 1.15 1596.03N 8338.63W
N 78.18 W .42 1613.82N 8424.66W
N 78.79 W .74 1631.25N 8510.21W
N 79.45 W .94 1647.75N 8596.01W
N 79.04 W .60 1663.82N 8680.62W
8489.98
8577.82
8665.13
8752.50
8838.62
11392.86 5873.99 5825.79
11488.15 5914.67 5866.47
11582.64 5955.70 5907.50
11676.09 5996.52 5948.32
11771,07 6038.41 5990.21
65 0
64 26
64 5
64 5
63 34
N 79.68 W .82 1679.96N 8766.53W
N 78.23 W 1.50 1696.46N 8851.10W
N 78.73 W .60 17t3.46N 8934.50W
N 79.63 W .87 1729.24N 9017.06W
N 80.64 W 1.10 1743.85N 9101.04W
8926.04
9012.19
9097.31
9181.37
9266.59
11867.48 6081.56 6033.36
11962.75 6125.41 6077.21
12056.94 6171.44 6123.24
12149.78 6220.06 6171.86
12245,35 6273.61 6225.41
63 15
61 55
59 33
57 16
54 34
N 81.46 W .83 1757.26N 9186.21W
N 79.74 W 2.13 1771.06N 9269.63W
N 79.57 W 2.51 1785.82N 9350.45W
N 78.40 W 2.69 1800.91N 9428.07W
N 75.92 W 3.55 1818.47N 9505.23W
9352.75
9437.28
9519.43
9598.50
9677.60
12338.29 6329.30 6281.10 51 47
12431.33 6388.76 6340.56 48 44
12523.86 645!.61 6403.41 45 41
12618.25 6519.28 6471.08 42 40
12712.42 6590.18 6541.98 39 37
N 76.79 W 3.07 1836.03N 9577.53W
N 74.90 W 3.64 1853.50N 9646.90W
N 75.37 W 3.32 1870.93N 9712.53W
N 75.92 W 3.21 1887.25N 9776.25W
N 77.47 W 3.41 1901.53N 9836.54W
9751.91
9823.34
9891.08
9956.74
10018.65
12807.93 6664.58 6616.38
12900,80 6739.09 6690.89
12995.09 6816.29 6768.09
13089.39 6894.38 6846.18
13184.68 6974.09 6925.89
38 1
35 16
34 48
33 22
33 4
N 78.59 W 1.84 1913.96N 9895.11W
N 77.74 W 3.01 1925.31N 9949.36W
N 79.16 W .99 1936.15N I0002.39W
N 79.60 W 1.55 1945.90N 10054.34W
N 79.09 W .42 1955.55N 10105.65W
10078.51
10133.93
10188.06
10240.91
10293.12
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 5
SHARED SERVICES DRILLING
MPU / MPC-36
500292285300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 2/12/98
DATE OF SURVEY: 013198
MWD SURVEY
JOB NUMBER: AKMM80102
KELLY BUSHING ELEV. = 48.20 FT.
OPERATOR: BP EXPLORATION
TRUE SUB-SEA COURS COURSE DLS TOTAL
MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT.
DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT.
13275.36 7050.24 7002.04 32 42 N 79.10 W .42 1964.87N 10154.00W 10342.36
13368.68 7128.95 7080.75 32 16 N 79.77 W .60 1974.06N 10203.27W 10392.48
13463.90 7209.74 7161.54 31 39 N 79.59 W .65 1983.09N 10252.86W 10442.88
13557.89 7289.93 7241.73 31 12 N 80.58 W .73 1991.53N 10301.15W 10491.89
13651.42 7370.25 7322.05 30 25 N 80.65 W .83 1999.34N 10348.42W 10539.79
13744.45 7450.74 7402.54 29 45 N 81.30 W .81 2006.66N 10394.49W 10586.41
13832.76 7527.69 7479.49 29 0 N 81.85 W .89 2013.01N 10437.34W 10629.69
13896.00 7583.00 7534.80 29 0 N 81.85 W .00 2017.36N 10467.70W 10660.32
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
HORIZONTAL DISPLACEMENT = 10660.32 FEET
AT NORTH 79 DEG. 5 MIN. WEST AT MD = 13896
VERTICAL SECTION RELATIVE TO WELL HEAD
VERTICAL SECTION COMPUTED ALONG 280.95 DEG.
TIE-IN SURVEY AT SURFACE 0.00' MD
PROJECTED SURVEY AT 13,896.00' MD
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 6
SHARED SERVICES DRILLING
MPU / MPC-36
500292285300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 2/12/98
DATE OF SURVEY: 013198
JOB NUMBER: AKMM80!02
KELLY BUSHING ELEV. = 48.20 FT.
OPERATOR: BP EXPLORATION
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
· 00 .00 -48.20 .00 N .00 E
1000.00 994.61 946.41 16.62 N 76.74 W
2000.00 1901.04 1852.84 94.84 N 481.63 W
3000.00 2577.72 2529.52 242.88 N 1189.87 W
4000.00 2993.00 2944.80 401.62 N 2085.09 W
.00
5.39 5.39
98.96 93.57
422.28 323.33
1007.00 584.72
5000.00 3387.58 3339.38 617.01 N 2977.73 W
6000.00 3774.85 3726.65 808.44 N 3878.86 W
7000.00 4143.64 4095.44 985.84 N 4791.07 W
8000.00 4546.10 4497.90 1147.27 N 5691.90 W
9000.00 4951.92 4903.72 1280.95 N 6595.73 W
1612.42 605.43
2225.15 612.73
2856.36 631.21
3453.90 597.54
4048.08 594.18
10000.00 5336.80 5288.60 1435.56 N 7505.29 W
11000.00 5714.66 5666.46 1611.60 N 8414.04 W
12000.00 6142.95 6094.75 1776.92 N 9301.97 W
13000.00 6820.32 6772.12 1936.68 N 10005.15 W
13896.00 7583.00 7534.80 2017.36 N 10467.70 W
4663.20 615.12
5285.34 622.13
5857.05 571.72
6179.68 322.62
6313.00 133.32.
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 7
SHARED SERVICES DRILLING
MPU / MPC-36
500292285300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 2/12/98
DATE OF SURVEY: 013198
JOB NUMBER: AKMM80102
KELLY BUSHING ELEV. = 48.20 FT.
OPERATOR: BP EXPLORATION
iNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
.00 .00 -48.20
48.20 48.20 .00
148.20 148.20 100.00
248.21 248.20 200.00
348.24 348.20 300.00
.00 N .00 E
.00 N .00 E
.16 N .42 W
.55 N 1.36 W
1.67 N 3.55 W
.00
.00 .00
.00 .00
.01 .01
.04 .03
448.37 448.20 400.00
548.59 548.20 500.00
648.92 648.20 600.00
749.54 748.20 700.00
850.64 848.20 800.00
3.50 N 8.19 W .17 .13
5.41 N 14.51 W .39 .22
7.26 N 22.34 W .72 .33
9.35 N 33.20 W 1.34 .62
11.78 N 47.78 W 2.44 1.10
952.44 948.20 900.00
1055.27 1048.20 1000.00
1159.50 1148.20 1100.00
1265.42 1248.20 1200.00
1373.71 1348.20 1300.00
14.82 N 66.52 W
19.10 N 90.00 W
24.53 N 118.89 W
31.31 N 153.07 W
39.90 N 193.69 W
4.24 1.80
7.07 2.82
11.30 4.24
17.22 5.91
25.51 8.30
1484.52 1448.20 1400.00
1596.76 1548.20 1500.00
1708.54 1648.20 1600.00
1821.27 1748.20 1700.00
1937.10 1848.20 1800.00
49.42 N 240.40 W
59.12 N 290.44 W
68.22 N 339.54 W
77.30 N 390.77 W
88.16 N 448.17 W
36.32 10.81
48.56 12.24
60.34 11.78
73.07 12.73
88.90 15.82
2057.49 1948.20 1900.00
2183.23 2048.20 2000.00
2313.68 2148.20 2100.00
2450.07 2248.20 2200.00
2598.09 2348.20 2300.00
101.39 N 513.84 W
117.75 N 588.26 W
136.20 N 669.95 W
156.49 N 760.41 W
181.12 N 866.65 W
109.29 20.39
135.03 25.74
165.48 30.45
201.87 36.39
249.89 48.02
2759.54 2448.20 2400.00
2941.60 2548.20 2500.00
3150.13 2648.20 2600.00
3393.39 2748.20 2700.00
3640.77 2848.20 2800.00
207.94 N 990.48 W
233.54 N 1140.35 W
267.35 N 1320.12 W
305.07 N 1538.57 W
344.80 N 1761.32 W
311.34 61.45
393.40 82.06
501.93 108.53
645.19 143.25
792.57 147.38
3890.36 2948.20 2900.00
4138.20 3048.20 3000.00
4372.94 3148.20 3100.00
4624.09 3248.20 3200.00
4893.62 3348.20 3300.00
384.39 N 1986.52 W
425.29 N 2209.53 W
475.04 N 2415.96 W
530.92 N 2639.41 W
591.90 N 2882.15 W
942.16 149.59
1090.00 147.84
1224.74 134.74
1375.89 151.15
1545.42 169.53
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA.
PAGE
SHARED SERVICES DRILLING
MPU / MPC-36
500292285300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 2/12/98
DATE OF SURVEY: 013198
JOB NUMBER: A~M80i02
KELLY BUSHING ELEV. = 48.20 FT.
OPERATOR: BP EXPLORATION
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
5156.26 3448.20 3400.00
5405.85 3548.20 3500.00
5659.93 3648.20 3600.00
5927.79 3748.20 3700.00
6204.08 3848.20 3800.00
653.31 N 3117.10 W
707.70 N 3339.18 W
756.18 N 3567.62 W
796.25 N 3812.86 W
841.26 N 4066.45 W
1708.06 162.64
1857.65 149.59
2011.73 154.08
2179.59 167.86
2355.89 176.30
6482.95 3948.20 3900.00
6751.63 4048.20 4000.00
7012.04 4148.20 4100.00
7275.37 4248.20 4200.00
7527.44 4348.20 4300.00
891.33 N 4321.88 W
940.29 N 4566.37 W
987.95 N 4802.02 W
1031.79 N 5041.64 W
1074.11 N 5269.07 W
2534.75 178.87
2703.43 168.68
2863.84 160.41
3027.17 163.33
3179.24 152.07
7764.86 4448.20 4400.00
8005.05 4548.20 4500.00
8247.88 4648.20 4600.00
8497.80 4748.20 4700.00
8748.62 4848.20 4800.00
1111.65 N 5481.10 W
1148.03 N 5696.43 W
1184.12 N 5914.75 W
1219.38 N 6141.04 W
1253.50 N 6368.44 W
3316.66 137.42
3456.85 140.19
3599.68 142.83
3749.60 149.92
3900.42 150.82
8990.92 4948.20 4900.00
9255.33 5048.20 5000.00
9517.41 5148.20 5100.00
9770.69 5248.20 5200.00
10028.00 5348.20 5300.00
1279.92 N 6587.52 W
1317.24 N 6829.28 W
1357.82 N 7068.09 W
1395.89 N 7297.57 W
1439.99 N 7530.47 W
4042.72 142.30
4207.13 164.40
4369.21 162.08
4522.49 153.28
4679.80 157.31
10285.55 5448.20 5400.00
10558.67 5548.20 5500.00
10826.81 5648.20 5600.00
11085.58 5748.20 5700.00
11331.55 5848.20 5800.00
1481.97 N 7764.04 W
1528.55 N 8013.88 W
1578.70 N 8257.54 W
1627.48 N 8491.15 W
t669.86 N 8711.84 W
4837.35 157.55
5010.47 173.12
5178.61 168.14
5337.38 158.77
5483.35 145.97
11565.48 5948.20 5900.00
11793.06 6048.20 6000.00
12010.75 6148.20 6100.00
12200.83 6248.20 6200.00
12368.49 6348.20 6300.00
1710.45 N 8919.36 W
1747.05 N 9120.47 W
1778.60 N 9311.19 W
1809.95 N 9469.68 W
1841.55 N 9600.42 W
5617.28 133.93
5744.86 127.58
5862.55 117.68
5952.63 90.08
6020.29 67.66
12518.97 6448.20 6400.00
12657.18 6548.20 6500.00
12787.13 6648.20 6600.00
12911.96 6748.20 6700.00
13033.96 6848.20 6800.00
1870.04 N 9709.13 W
1893.45 N 9801.56 W
1911.42 N 9882.55 W
1926.68 N 9955.65 W
1940.33 N 10024.18 W
6070.77 50.48
6108.98 38.21
6138.93 29.96
6163.76 24.82
6185.75 22.00
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
SHARED SERVICES DRILLING
MPU / MPC-36
500292285300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 2/12/98
DATE OF SURVEY: 013198
JOB NUMBER: AKMM80102
KELLY BUSHING ELEV. = 48.20 FT.
OPERATOR: BP EXPLORATION
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
13153.78 6948.20 6900.00 1952.36 N 10089.09 W 6205.58 19.83
13272.94 7048.20 7000.00 1964.62 N 10152.71 W 6224.74 19.16
13391.44 7148.20 7100.00 1976.22 N 10215.23 W 6243.24 18.50
13509.07 7248.20 7200.00 1987.33 N 10276.16 W 6260.87 17.63
13625.85 7348.20 7300.00 1997.24 N 10335.64 W 6277.65 16.78
13741.52 7448.20 7400.00 2006.44 N 10393.05 W 6293.32 15.68
13856.21 7548.20 7500.00 2014.62 N 10448.60 W 6308.01 14.69
13880.00 7569.00 7520.81 2016.26 N 10460.02 W 6311.00 2.99
THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN
THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS
l:! I::t I I_1-- I ~1 G S ~::: I::! ~./I ~-- E S
WELL LOG TRANSMITTAL
To-'
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Loft Taylor
3001 Porcupine Dr.
Anchorage, Alaska 99501
MWD Formation Evaluation Logs - MPC-36, AK-MM-80102
September 16, 1998
MPC-36:
2" x 5" MD Resistivity and Gamma Ray Logs:
50-029-22853-00
2"x 5" TVD Resistivity and Cramma Ray Logs:
50-029-22853-00
2" x 5" MD Neutron & Density Logs:
50-029-22853-00
2" x 5" TVD Neutron & Density Logs:
50-029-22853-00
1 Blueline
1 Folded Sepia
1 Blueline
1 Folded Sepia
1 Blueline
1 Folded Sepia
1 Blueline
1 Folded Sepia
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPIES
OF THE TRANSMITTAL LETrER TO THE ATTENTION OF:
Sperry-Sun Drilling Services
Attn: Ali Turker
5631 Silverado Way, Suite G.
]998
:~.nchorage
BP Exploration (Alaska) Inc.
Petro-technical Data Center, MB3-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535
A Dresser Industries. Inc. Comnanv
EJ I:t I I_1_ I IM I::S ~S ~ Fi~J I CEEc~
To:
WELL LOG TRANSMITTAL
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Loft Taylor
3001 Porcupine Dr.
Anchorage, Alaska 99501
MWD Formation Evaluation Logs
September 9, 1998
MPC-36, AK-MM-80102
1 LDWG formatted LIS tape with verification listing.
API#: 50-029-22853-00
PLEASE ACKNOWLEDGE RECEIFr BY SIGNING ANI} RETURNING THE ATTACHED COPI~S
OF ~ TRANSMITYAL LETrER TO THE ATYENTION OF:
Sperry-Sun Drilling Services
Attn: Ali Turker
5631 Silverado Way, Suite G.
Ancho_raKe, Al~ka~.. 9&l 8
Date:
BP Exploration (Alaska) Inc.
Petro-technical Data Center, MB3-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
5631 Silverado Way, Suite G · Anchorage, Alaska99518 ° (907)563-3256 ° Fax(907)563-7252
A Dresser Industries, Inc. Company
GeoQuest
500 W. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO. 11950
Company:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
3/23/98
Field:
Milne Point (Cased Hole)
Colored
Well Job # Log Description Date Print
RF Sepia LIS Tape
MPB-25 981 47 USlT 9801 01 I 1
MPC-36 981 47 USIT 980205 I 1
MPC-39 98147 ~USIT 980118 I 1
MPG-09 981 47 USlT 980220 I 1
MPJ-17 98147 USIT 971119 I 1
MPL-33 981 47 USlT 971 008 I 1
MPL-42 981 47 USIT 980224 I I
c}'g. Oo !
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska)Inc.
Petrotectnical Data Center MB3-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
Date Delivered:
Schlumberger GeoQuest
500 W. International Airport Road
Anchorage, Alaska 99618-1199
Received ~~~d
/ // /
GeoQuest
500 W. International Airport Road
Anchorage, AK 99518-1199
ATTN; Sherrie
NO. 11867
Company: Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
..
· ,
Field: Milne pOint (Cased Hole)
2/25/98
Well Job # Log Description Date BL RF Sepia LIS Tape
MPC-18 BRIDGE PLUG SET RECORD 980212 I 1
MPU C-36 PERFORATING RECORD 980205 1 1
G-12 PACKER SE'FrlNG RECORD 980119 1 I
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrotectnical Data Center MB3~3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
Date Delivered:
Schlumberger GeoQuest
500 W. International Airport Road
Anchorage, Alaska 99618-1199
Received ~.~
10 February 1998
To: Blair Wondzeli AOGCC
From:
James E. Robertson
Drlg OP's Engineer, Nabors Rig 22E
RE: MP C-36i: Suspension of Operations
On 8Feb98 at approximately 2330 hrs Nabors Rig 22E was running a 3-1/2", 9.2#, L-80 tubing
completion for the injection well Milne Pt. Well# MP C-36i. The entire completion was run and
the completion string was being picked up to add spaceout pups when the tubing string came
apart at approximately 2018' md.
After several discussions about the best way to fix the well it was decided to move off the well
with Nabors Rig 22E and schedule a workover rig to come in and work the well over.
Permission to suspend operations was received from Blair Wondzell, AOGCC, at
approximately 1820 hrs 9Feb98.
The well has a straddle packer assembly in it. A BAKER S3 packer is set at __.13,258' md,
with the lower packer at ±13,447' md. 3-1/2" tubing runs up to 2018' md. The well has a
diesel cap from approximately 2000' md to surface and 10.2 ppg brine from 2018' md down.
A workover rig will be scheduled to come in a repair the well as soon as possible.
TONY KNOWLE$, GOVEF~NOF~
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
January 9. 1998
Dan Stoltz
Senior Drilling Engineer
BP Exploration. (Alaska) Inc.
POBox 196612
Anchorage, AK 99519-6612
Re~
Milne Point Unit MPC-36i
BP Exploration (Alaska) Inc.
Permit No. 98-001
Sur. Loc. 952'NSL. 2378'WEL. Sec. 10. T13N, R10E. UM
Btmhole Loc. 2961'NSL. 2243'WEL. Sec. 8. TI3N. R10E. UM
Dear Mr. Stoltz:
Enclosed is the approved application for permit to drill the above referenced well.
Thc permit to drill does not exempt you from obtaining additional permits required by law from
other governmental agencies, and does not authorize conducting drilling operations until all other
required permitting determinations arc made.
The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035;
and the mechanical integrity (MI) of thc injection wells must be demonstrated under 20 AAC
25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before
operation, and of the BOPE test performed before drilling beloxv the surface casing shoe, must be
given so that a representative of thc Commission max' witness the tests. Notice max' be given by
contacting the Commission petroleum field inspector on the North Slope pager at 659-3607.
David W. Johni'lo,~ ~} -
Chairman
BY ORDER OF THE COMMISSION
dlf/Enclosure
CC;
Department of Fish & Game. Habitat Section w/o cncl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA
ALA$,¢,A OIL AND GAS CONSERVATION L:,~MMISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil
[] Re-Entry [] Deepen []Service [] Development Gas []Single Zone [] Multiple Zone
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
BP Exploration (Alaska) Inc. Plan KBE = 46.5' Milne Point Unit / Kuparuk River
3. Address 6. Property Designation Sands
P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL025509
4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025)
952' NSL, 2378' WEL, SEC. 10, T13N, R10E, UM Milne Point Unit
At top of productive interval 8. Well Number Number 2S100302630-277
2923' NSL, 2045' WEL, SEC. 8, T13N, R10E, UM MPC-36i
At total depth 9. Approximate spud date Amount $200,000.00
2961' NSL, 2243' WEL, SEC. 8, T13N, R10E, UM 01/09/98
12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
ADL 047434, 2243'I No Close Approach 2533 13837' MD / 7486' TVD
16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)}
Kick Off Depth 300' MD Maximum Hole Angle 67.2° Maximum surface 2830 psig, At total depth (TVD) 7090' / 3539 psig
18. Casing Program Specifications Setting Depth
Size Top Bottom Quantity of Cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.)
12-1/4" 9-5/8" 40# L-80 BTC 8818' 31' 31' 8849' 4874' 1887 sx PF 'E', 597 sx Class 'G'
8-1/2" 7" 26# L-80 BTC-Mod 13807' 30' 30' 13837' 7486' 235 sx Class 'G'
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk(measured)
true vertical feet
Casing Length Size Cemented MD TVD
Structural
Conductor
Surface
Intermediate
Production RECEIVED
Liner
Perforation depth: measured ~ 0il & Gas Cons. Commission
Anchorage
true vertical
20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program
[] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements
Contact Engineer Name/Number: Ja~s Robertson, 564-5159 Prepared By Name/Number: Kathy Campoarnor, 564-5122
21.1 hereby certify that th~'for~going is,t/C/e and cprrect to the best of my knowledge
ChipAIvord ./f'~/f2~//_~.~~.__ ,P" Title Senior Drilling Engineer Date /
Commission Use Only
Permit Number I APl Number Approval Date See cover letter
~ O¢ - (DO II 50- O ~. ~ - ~ ,~ ~O~" ~ / .- ~---~¢ for other requirements
Conditions of Approval: Samples Required []Yes [~No Mud Log Required I--lYes I"~No
Hydrogen Sulfide Measures r~ifYes [] No Directional Survey Required [;~hYes F-INo
Required Working Pressure for BOPE []2M; r-]3M; J~EM; I--I10M; []15M
Other: 0rigina! Signed By by order of
Approved By 0avid W. Johnston Commissioner the commission Date//..... ,~'~...
Form 10-401 Rev. 12-01-85 Submit In Triplicate
Shared Services Drilling Contact:
James E. Robertson
I Well Name: IMP C-36i
Well Plan Summary
IType of Well (producer or injector):
IKUPARUK
INJECTOR
Surface Location: 952 FSL, 2378 FEL, S10 T13N R10E UM
Target Location: 2923 FSL, 2045 FEL, S08 T13N R10E UM
Bottom Hole Location: 2961 FSL, 2243 FEL, S08 T13N R10E UM
564-5159
I AFE Number: I 337118 I
I Rig: I Nabors22E
Estimated Start Date: 19 Jan 98 I I Operating days to complete:
I MD: J 13,837' I ITVD: I7486' I
I 17.0
I KBE: 146.5ft
I Well Design:
I Kuparuk Injector
Formation Markers:
Formation Tops MD TVDSS
KOP 300 300
Base of Permafrost 1920 1800
Top of Ugnu
Top M Sand
Top NA 7746 4400 Top of Schrader Bluff Sands (EMW 8.6 ppg)
OA 8468 4680
Top Seabee 8649 4750 Base of Schrader Bluff Sands (EMW 8.3 ppg)
Top of HRZ 12930 6665
MK-19 13114 6815
Top of Kuparuk 'D' 13196 6885 Kuparuk Cap Rock
Top of Kuparuk 'C' 13300 6975
Top of Kuparuk 'B' 13306 6980
Top of Kuparuk 'A' 13433 7090 Target
Top of Miluveach 13537 7180 Base of Kuparuk
TD 13837 7439 TD at 300' MD past base of Kuparuk
Casing/Tub ng Program:
Hole ,~ize ' Csg~ WtJFt Grade Conn. Length Top Bottom
Tbg O.D. MD/TVD MD/'rVD (bkb)
24" 20" 91.1 # H-40 Weld 80' 32'/32' 112' / 112'
12-1/4" 9-5/8" 40.0# L80 BTC 8818' 31 '/31' 8849' / 4874'
8-1/2" 7" 26# LB0 BTC-MOD 13807' 30'/30' 13837' / 7486'
Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the
reservoir at +7090' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of
3539 psi (9.6 ppg EMW), is 2830 psi, well below the internal yield pressure rating of the 7" casing.
Logging Program:
Op~ H~le L(~gs: MWD directional from spud to 12-1/4" TD and LWD (GR/Resistivity) from top of
Schrader Bluff to 12-1/4" TD.
MWD directional and LWD (GR/Resistivity/Density/Neutron/ROP) from top of
Kuparuk to 8-1/2" TD with a controlled drilling speed of no more than 200 ft/hr
across the Kuparuk sands
Cased Hole Logs: Cement bond log
Mudloggers are NOT required for this well.
Mud Program:
I Special design considerations I None-SPUD MUD I
Surface Mud Properties: I
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
8.6 150 15 8 10 9 8
to to to to to to to
9.4 80 35 15 30 10 15
Production Mud Properties: I LSND freshwater mud
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point ~lel gel Loss
8.6 35 6 3 7 8.5 6-12
to to to to to to to
10.2 50 20 10 20 9.5 4-6
Well Control:
Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10"
Diverter Line. Also well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular
preventer will be installed and is capable of handling maximum potential surface pressures.
A CompletionNVorkover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be
used for the completion and is capable of handling maximum potential surface pressures.
Diverter, BOPE, and drilling fluid system schematics on file with AOGCC.
Directional:
I KOP= 1300' MD I
Maximum Hole Angle: 167.2°
Close Approach Well: I NONE
Waste Management:
Cuttings Handling: All cuttings will be hauled to the CC-2A facility.
Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection.
Annular Injection: No wells on C-Pad have been permitted for annular injection.
.
,
10.
11.
MP C-36i
Proposed Summary of Operations
Drill and Set 20" Conductor. Weld a starting head on conductor.
Prepare location for rig move.
MIRU Nabors 22E drilling rig.
NU and function test 20" diverter. Build Spud Mud.
Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD from surface to TD and
LWD GR/Res across Schrader Bluff Sands.
Run and cement 9-5/8" casing.
ND 20" diverter. NU and test 13-5/8" BOP.
MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH,
Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST. If LOT EMW is
less than 12.5 ppg contact appropriate superintendent.
Drill 8.5" hole to TD as per directional plan.
Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with drilling mud.
Test casing to 4000 psig for 30 min.
POST DRILL AND CASE:
Nabors Rig 22E will run the completion on this well.
1. Complete well with 3-1/2" tubing and a straddle packer hookup. Details to follow
2. Install Surface Lines and Wellhouse and turn well over to production.
(End of Nabors 22E operations)
DRILLING HAZARDS AND RISKS:
See the latest Milne Point B-Pad Data Sheet prepared by Pete Van Dusen for information on C pad.
The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the
rig drills and completes them. This will make the near rig area congested and as a result potentially
hazardous. Ensure personnel use caution moving around adjacent production activities.
1. Hydrates:
NO HYDRATES HAVE BEEN ENCOUNTERED ON ANY WELLS DRILLED AT MILNE POINT 'C'
PAD TO DATE.
If hydrates are encountered the cement program will be modified to include a Permafrost C tail on
the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted
spacers will be used during the cement displacement to maintain the hydrostatic head on the
formation so as to minimize the movement of hydrates into the wellbore.
2. Close Approach:
There are no close approach problems with MP C-36i.
3. Lost Circulation:
There were no reports of lost circulation while DRILLING in the production intervals of previous "C" PAD
wells. Several wells at Milne Pt. 'C' Pad have experienced partial to full lost returns while running,
circulating and cementing 7" casing.
Have the LCM materials on location and recommended pills ready to address the Lost Circulation Problem
when drilling into the Kuparuk Sand.
4. Stuck Pipe Potential:
Stuck pipe has occurred on 2 wells on this pad in the Schrader Bluff Sands. These wells and the
corresponding depths at which they were stuck were: C-09 @ 4,427' ss with a mudweight of 9.4 ppg. It
was felt the reason for sticking on this well was inadequate hole cleaning. Milne Pt. Well# C-02 @ 3,911'
ss with 9.2 ppg mudweight. It was felt the reasons for sticking on this well were hole geometry and new
BHA.
If heavy gravels are encountered while drilling the surface hole section, operations should be
immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through
the gravel section.
5. Formation Pressure:
THE KUPARUK IS EXPECTED TO BE NORMALLY PRESSURED. The expected pore pressure for this
well is 9.6 ppg EMW (3539 psi @ 7090' TVDSS) in the KUPARUK sands and may be slightly depleted.
6. Directional Drillinq Concerns
MP C-36i will be another 12-1/4" by 8-1/2" hole to TD at 13837' md. KOP is 300' md and a variable
build rate from that point will yield a sail angle of 67.2° at 3,198' md. This angle will be maintained to
11,745' md at which time a 2.5°/100' md drop will begin. The profile will be dropped to 30° and this
angle maintained to 8-1/2" TD. MP C-36i will have a horizontal displacement of 10622'.
7, Cement
Surface hole will be cemented in 2-stages. A 'C' cement for the second stage tail cement will be
incorporated into the cementing program only if hydrates are encountered.
The 8-1/2" hole will be cemented in a single stage to bring cement 1000' md above the top of the Kuparuk
'C' Sands.
MP C-36i
9-5/8" SURFACE CASING
CEMENT PROGRAM - HALLIBURTON
CASING SIZE: 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS.
SPACER: 75 bbls spacer weighted to mudweight in the hole.
STAGE1 LEAD: TYPE 'E' PERMAFROST
ADDITIVES: Retarder + CELLO-FLAKES (1/4 lb/sack)
WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63
gal/sk
APPROX #SACKS: 956 SACKS THICKENING TIME: Greater than 4 hrs at 50° F.
ANUULAR VOLUME TOP OF TAIL CEMENT TO ES
CEMENTER AT 2150' MD +30% EXCESS.
STAGE1 TAIL CEMENT TYPE: PREMIUM 'G'
ADDITIVES:
WEIGHT:
APPROX #SACKS:
FLUID LOSS:
0.2% CFR-3 + 0.20% HALAD-344 + CELLO-FLAKES
15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk
597 THICKENING TIME: Greater than 4 hrs at 50° F.
100-150 cc FREE WATER: 0
TAIL CEMENT FROM TD TO 500 FEET MD ABOVE
SCHRADER BLUFF + 30% EXCESS + 80'md 9-5/8", 40#
capacity for float joints. EST TOC 7246' md
STAGE2 LEAD:
ADDITIVES:
WEIGHT:
APPROX #SACKS:
TYPE 'E' PERMAFROST
Retarder
12.0 ppg
YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk
931 SACKS THICKENING TIME: > than 4 hrs at 50° F.
ANUULAR VOLUME FROM STAGE COLLAR AT 2150' MD TO
SURFACE+ 200% EXCESS.
DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC & DRILLING SUPERINTENDENT
TOP JOB CEMENT TYPE: Permafrost E
NOTE: TOP JOB WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS
TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE
AFTER THE PUMPS ARE SHUT DOWN.
ADDITIVES: Retarder
WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk
APPROX NO SACKS: 150
RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLFJPRACTICAL
CENTRALIZER PLACEMENT:
1. Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15
required).
2. Place all centralizers in middle of joints using stop collars.
OTHER CONSIDERATIONS:
Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to
pumping job. Ensure thickening times are adequate relative to pumping job requirement.
Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary.
MP C-36i Well
7" PRODUCTION CASING
CEMENT PROGRAM- HALLIBURTON
SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL:
CIRC. TEMP:
SPACER:
140° F BHST 170° F at 7040' TVDSS.
20 bbls fresh water
70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above
current mud weight.
CEMENT TYPE: Premium G
ADDITIVES:
WEIGHT: 15.8ppg
APPROX # SACKS:
FLUID LOSS:
0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344
YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk
235 SACKS
THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F
< 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle.
CENTRALIZER PLACEMENT:
,
7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 21 joints of 7" casing
(42). This will cover _+300' above the KUPARUK 'C' Sand.
Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8"
casing shoe.
OTHER CONSIDERATIONS:
Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to
pumping job. Ensure thickening times are adequate relative to pumping job requirement.
Displace at 8-10 bpm. Batch mixing is not necessary.
CEMENT VOLUME:
,
Single stage cement job is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand
with 30% excess.
2400 MON C-1 ~'~
!~ · 19
411 14
' · ~ ~ i ~C~N~T~ ~AP
~ 28 I ~ 21 N.T.S
. .
'" "'~ ! 1~"-., --' '~
, I 22 ;
18 · ~ 12
'' : I HEREBY C~ ~AT I A~ PROP~LY
REGISTERED AND U~NSED TO PRAC~
' I ~ND SUR~NG IN THE STA~ OF A~A
I A~D THAT THIS P~T ~P~S~N~ A ~Y
~ ~ ~AD~ BY ~E O~ UND~ ~Y DIRECT
~ SUPERCRON AND ~AT ALL DIM~SIONS AND
OTHER DETAILS ARE CORRECT AS
~ DECEMBER 15, 1997,
~ . + N aO0 NO~S
I. DA~ OF ~R~Y: DECEMBER 15, 1997.
~ 2. R~RENCE R[~
MPU C- ~ ~. ~ ~ ~o. ,s
~o~ ~pu c-~ A.o ~pu c-~
DA~U (~.~L.).
AS-BUILT CONDUCTOR
~S~NG CONDUCT~
L~D ~IN PRO~AC~D ~C.1~ T. 13 N., R. 10 E., UMIAT M~R[DIAN.
~LL A,S.P. P~NT ~ ~ODETIC GE~E~C ~O0~D ~C~ON
'NO. ~DINA~S I CO~OINA~S, P~T~(DMS) POS~ON{D.DD) ~VA~ ~FSETS
Y=6,029,233.53 N= 1,788.18 I 70~9'25'7~" 70.49~0' 17.0' 95~' F~
36 X= .558~083,64 E= 6~.05 149~1'30.6~,5" 149.5251764' 2,378' ~L
Y=6,02g,~O.~ N~1,637.83 70~9'24.~" 70.490092~ 16.6' 808' F~
39 X= 558~129.~ E= 599.96 ; 149'31'29.520" ,149~111' 2,~3' ~LI
Y=6,029,035,57 N=1,578.20 70~9'23.774" 70.4899573' 16.3' 751' FSL ~
40 ,X=_55~147.65 E= 599.97 149~1'2a.797' 149.5246659' =2~316' ~L
~,~ MILNE POINT UNIT c-PaD
~ ~ -~ ~~ WELLS C-36, C-39 ~ C-40
~ F [~ [, ~"~' , ....
WELL A,S,P. PLANT I GEODETIC GEODETIC G'~OUND SECTION
'NO. COORDINATES COORDINATESPOSIT[ON(DM$) POSII'ION(D.DD) ELEVATIONOFFSETS
Y=6,029,233.53 N= 1,788.1870'29'25.746- 70.4904850' 17.0' 952' FSL
.36X=,556r083,64E= 600.05 149'31'30.6,3,5" 149.5251764' 2,378' FEL
Y=6,02g, o90.34 N=1,637.83 70'29'24,334" 70.4900928' 16.6' 808' FSL
39 X= 556~129.44E= 599.96 14g'31'29.520" ,149;,5.248111' 2,333' tEL
Y=6,029,035,57 N=1,578.20 70'29'23.774" 70.4899573' 16.3' 751' FSL
40 ,X,= 556~147.65 E== 599.97 149'31'2a.797' 149.5246659' 2~316' tEL
Anadrill Schlulaberger
'_?_..: .. r.: ..... '.... _ .....................................................................................................................
1111 EaSt 80th Avenlle
hJ Anchorage, AK 99518
DIRECTZONAL WELL PLAN for St{ARED E~RVICES DRILLING
~ell ......... : MPC-36 (PO4)
Field ........ : Milne Point
Oomputatiou..: Minimum Cua-vature
UNits ........ : FEET
~urface Lat,.: 70.49048~01
Surface Long.: L49.5~$176~6
LOCATIONS - ALASKA Zone:
Legal Description
Surface ...... : 951 FSL 2378 ~EL SlO T13N R1DE U M
Target ....... : 2923 FSL
4
X- Coord ¥ - Coord
558083.64 6029233.53
547B~9.00 603~132.00
5~7640~~4 6~3~168.80
PROI~DSE~ ~ELL PROFILE
STATION MEASURED INCLN DIRECTION VERTICAL-DEPTHS SECTION
IDENTIFICATION D~PTH A/9~LE AZIMUTH TVD SUB-EEA DEPART
K]~ 0.00 O.O0 0.00 O.O0 -%~.50 O.OO
KOP / ~UIIiD 1.5/tOO ~00.00 0.00 2B0.95 100.00 253.50 -0.00
·
400.00 1.50 2~0.95 399.99 353.~9 1.31
500.~0 3.00 280,95 499.91 453.41 5.23
BUILD 2/500 600.00 4.50 2BO.g5 599,69 553.19 11,77
Prepared ..... : 24 ~ec 1997
Vert sect a~.: ~B0.95
KB elevation.: 46.50 ft
Maglletic DCl~: +27.B65 {~}
C~nverg~uce..: +0,447563~S
ANADRILL
AKA-DPC I
APPROVED
FOR PERMITTING
ONLY
PLAN .
~L~ X Y
0.00 N ~.00 E 558083.64 6029233.53
0.25 N 1.29 W 555082.35 6029233.77
O,gD N 5.14 W 558078.49 602923~.48
2.~4 N 11,56 W 558072.06 6029235.68
FACE tO0
79L O. O0
79L O. O0
79L 1.50
79~ 1.50
79L 1,50
700.0O 6.50 280.95
BO0.OO 8.50 280.95
900.00 10.50 2B0.95
lO00.OO 12.50 280.95
1100.00 14.50 2B0,95
699.23 652.73 21.36
798.37 751.87 34.41
B96.R9 B50.49 50.91
99~-98 94B.~8 70.85
1092.21 1045.71 94.19
4.06 N 20.97 N 558062.64 6029237,42 H8 2.00
6.53 N 33.70 ~ 558049.81 6029239.80 ~S 2.00
9-67 N 49.99 W 558033.58 6029242.81 HS 2,00
13.~5 N 69.56 W 550013.9~ 6029246.44 ~S 2.00
17-89 N 92.~B W 557991.03 6029250,69 HS 2.00
1200.00 16.50
1300.00 18.50
200.95 I188.57 11~2.07 120.92
280.95 Z2BS-93 1237.~3 150.99
22-96 N 118.72 W 557964,76 6029255.56 ES 2.00
28.67 ~ 1~8.24 W 557935.20 6029261.04 HS 2.00
{Alladrill (c)97 MPC36P04 3.2b,5 11:37 AM P)
MPC-36 [F04) 24 Dec 1997 Page 2
DIRECTIO~ VERTICAL-DEPTMS SECTtO~
AZIMUTH T%'D SUB-SEA DEPART
2BO.g5 1378.19 1331.6g 184.36
280.95 1471.23 1424.73 22].01
280.95 1562.93 1516.45 260.89
280.95 1603.19 1606,69 38~.93
280.95 1741,88 1695.38 350.11
1400.09 20.50
1500.00 22.50
1600.00 24.50
1700.00 26.50
1800.D0 28.50
COOFd31M~8- FROM ALASKA Zone 4 TOOL Db/
WELLHEAD X Y FACE 100
35.0] N 18].D1 W 557902.38 6029267.12 2.00
~1.97 N 216,99 W 557866,55 6029273.80 2.00
49.54 N 256.14 W 557827.15 6029281.06 2.00
57,71 N 298.40 ~ 557?84.82 6029288.91 2.00
66.48 N 2.00
HS
BUIhD 2.5/100
3/loo
1885.61 30.21
1920.33 30.21
1931.90 30.21
2000.00 31.91
2100.~0 34.41
2131.90 35.21
2200.00 37.26
2300.00 40.26
2400.00 43.26
2500.00 46.26
2600.00 49.26
2700.00 52.26
2800.00 55.26
2900.00 58.26
3000.00 6~-26
280.95 1816.50 1770.00
280.95 1846.50 lB00.00
280.95 1856,50 1810.00
280.95 1914.83 1~68.33
200.95 1998.53 1952.03
280.95 2~24.72 1978.22
280.95 2079.65 2033.15
280.95 2157.63 2111.13
200.95 2232.22 2185.72
280.95 2303.22 2256.72
392.~8
409.55
415.37
450.51
50~.21
523.42
563.67
626.26
692.~5
768.25
280.95 2370.44 2323,94 $37.27
280.95 2433.70 2387.20 914.70
280.95 2492.82 2446.32 995.34
280.95 2547.63 2501-13 1078.97
280.95 2597.99 2551.49 1165.35
74.45 N 384.94 W 55769~.16 6029304.96 HS
77.77 N 402.09 W 557680.99 6029305.15 ES
78.87 N 407.81 ~ 557675,26 6029309.21 ~
85.54 N 442.31 ~ 557640.72 6029315.61 }iS
95.93 ~ 496.01 W 557506.94 6029325.58 ~S
107.03 N 553.41 ~ 557529,46 6029336.2~ H~
118.92 N 614.E7 ~ 557467.92 6029347.63 H8
1~1.56 H 680.24 W 557402.46 6029359.76 HS
14~.93 ~ 749.36 W 557333.~4 6029372.59 ~S
158,99 N 822.03 ~ 557260.47 6029386.08 R~
173.69 N 89g.06 W 557184.34 6029400,18 HS
1~9.0~ N 977,24 W 557105.05 6029414.88 }IS 3.00
~04.BB N 1059,34 N 557022.84 6029430.11 HS 3,00
221.28 N 1144.14 W 556937.9l 6029445.85 HS 3,08
2 .OD
0.00~
~.oo
2.50
2.~o
3.00
.oo
~.oo
3 O0
3.00
3100.00 64.26
END 3/100 BUIL~ 3198.15 67.20
I~A 7746.04 67.20
OA 8~68.59 67.20
SASE OB 8649.22 67.29
280.95 2643.7? 2597.27 1254,24
280,95 2684.11 2637.61 1343,71
280.95 4446.50 4400.00 5536-23
250.95 4726.50 4680.00 6202.32
280.95 4796.50 4750.00 636~,84
238.16 N 1231.42 W 556850.51 6029462.05 HS 3.00
255.~5 N 1319,26 W 556762.55 6029478.35 HS 3.00
1051.26 N 5435.51 W 552640.61 6030242.2~ 85 O,OO
1177.74 N 60~9.48 W 551985,74 6030363.55 HS 0.00
1209.36 N 6252.97 W 551822.02 6030393.89 HS 0.00
9-5/8" CASING POI~T 8849.22 67.20
DROP 2.5/100 117~5.75 67.20
llB00.OQ 65.84
280.95 4874.00 4827.50 6553.21
250.95 5996.46 5949.96 9223.42
280.95 6018.07 5971.57 9273.17
1244.37 N 6433.99 W 551640.75 6030427.48 HS 0.00
1751.40 N 9055.60 N 549015.51 6030913.98 LS 0.00
L760,85 N 9104.46 i~ 548966,59 6030923,04 LS 2.50
(Anadrill (c) 97 MPC36P04 3,2b.5 11:37 k~ P)
STATION M~ASU~E~ INCM9 DIRECTION VERTICAL-DEPTHS SECTION C00~I~ATES-~OM A~S~ Zon~ ~ ~L DL/
IDE~IFI~TI ON DE~ ~ AZ~ ~ S~-S~ DEPOT [~E~ X ~ FACE 108
31900.00 63.34 2B9.95 6060.97 6014.47 9363.49 ~778.00 N 9193.14 W 54887~.79 6030939.50 2.50
1200O.00 60,84 280.95 6107.77 6061.27 9~51.86 ~794.78 H 9279.89 W 54~790.91 6030~55.60 2,50
i2100.OO 58.3t 280,95 6158.38 6111.88 9538.10 i~iL.15 N 936i.56 W 5~796.L2 6030971.31 2,~0
1~20~,00 55.8~ 288.95 6212,70 6166,20 9622,05 1827.10 N 9446.98 W 5~8623.59 6030986,61 2.50
12388.00 53.34 280.95 627~.6~ 622t,14 9783.55 18~2,57 N 9527.OO W 2.50
BASE HRZ
LS
LS
LS
LS
54B543,46 6033001.45 LS
12490.00 50.84 280.95 6332.07 6285.57 9782.44 tB57.55 N 9604.46 ~ 548465.89 6031015.83 LS 2.50
12500.00 48.34 280.9~ 6396.88 6350.38 9858.58 1872.01 N 9679~22 ~ 548591.03 6031029.?0 L~ 2.50
L2600.O0 45.84 280,95 6464.96 6418.46 9931,~2 1881.92 N 9751,12 W 5483L9.03 60~1043.8~ LS ~.~0
12700,00 43.54 28fl.95 6536.16 6489,66 10882.02 1899.25 ~ 9~20.01 W 548210.~L 60E10£5.83 L$ 2.50
12SOO.OO 40.84 2g0.95 6630.36 6563.86 10069.05 1911.gS ~ 9885.86 W 548184,11 6031068.05 ~S 2.50
12909.00 38.34 280.95 6687.42 6640.92 10132.78 1924.08 H 9948.45 W 548121.45 60310?9.66 LS 2.50
12930.55 57.5B ~B0,95 6711.50 6665.80 10151.5? 1927.65 H 9~66.$8 W 5~8Z02.98 603108F.08 LS 2.50
13000.00 35.B4 280.95 6767,11 6720.6B 10193.09 1935.53 ~ 10~07.64 W 548062.16 6031090.65 LS 2.50
13005.33 35.71 280.95 6771.50 6725.00 10196.21 1936.12 ~ lOOlO.70 W 548059,10 6031091.21 LS 2.50
131OD.fi0 33.34 280.95 6849.49 6802.99 10249.86 ~916.31 N 10063.37 N 548006.34 6031100,99 LS 2.50
MK-19 13114.35 32.98 280.95 686L.50 6815.00 10257.71
Tk~3D 13196.85 30.92 280.g$ 6931,50 6BB5.OO 10301,37
13~OO-OO 30.B4 280.95 6934.20 68B~.78 10302.99
EHD 2.5/100 DROP 13233-74 30,00 2~0.95 6963-29 69L6.99 10320.07
TI~JC 13309.95 30.00 280.95 7021.50 6975.00 30353.67
TKErS 13306.72 30. O0 280.9~ 7026,50 6980. O0 10556.56
TJ%RGET 33435.74 30, OO 280.95 7136.50 7098 .OD
TKA3 13~33.74 30,00 280.95 7136.50 7090.00 10~20.07
T~I 13491,~8 30.00 280.95 7186,50 ?liO.O0 104t8 . 94
TMLV 13537.66 30.00 219-95 7226.50
?D / 7" CASING POINT 1BB37.~6 30.00 2B0-95 74B6.33
(Anadrill {c}97 MPC36~0i 3.2b.5 11:37 A~ P)
1947.80 ~ 100?l. OB W 547998.63 6031102.42 LS 2.50
1956.09 ~ 10113.95 W 547955.70 6031110.37 L$ ~.~0
1956.40 ~ 10[[5.53 W 547954.[l 6031110.67 ~9 2,50
1959.64 N 10132.31 W 547937.32 6031113,78 H$ 2.50
1966.02 H 10165.$0 W 547904.28 601t119.90 HS 0.80
1966,57 N lOi6B.13
1978.63 N 10230.49
1978.63 N 10~30.49
1980.27 N 10235.99
5t7991.44 6031~20.43 HS 0-00
54783g. OD 6031132.00 H$ 0.00
547839.00 603113~.0~ ~S 0.00
547830.49 6031133.58 HS O.OO
547810.62 6031157.26 ~S O.OD
?iS0.00 10472.03 lgBB.50 N 10281.50
7439.B1 ~0622.03
tANADR[LL
APPROVED
FOR PERMITTING
ONLY
PLAN
20t6.98 N 10t28.77 W 547640,44 6031168.$0
AKA-DPC i
i
0.00
0.00
SH ,HED 'SbRVTC"ES
! iii ii ii iiii iiiii
i ii i
LN
!
.21
.20
.20
.20
.~0
2~0
Section Dep,.ar,t, ure ,
MPC-36 (PO4)
ANADRiLL AKA-DPC I, VbHII,L;AL bY_Ur tUN, V,l.b~i
AD ~,~ ~,~ _ Isection at: 280.95
~R ._._ ID~R Sca1,.: ~nch ~00 fe~t
~~ I i Il I IIII I I __
&) KB O O O 0.'
~ ' ~ ~-~D~r-~ ~} KDP / BUILD 1.5/100 30~ 30~ -0 O.~
._ ,,,. C) BO]ED ~/~OO 600 BO0 1~ 4.~
D) E~ 2/1~0 B~ILD ~BB6 18~6 392
E) ~ILD 2.5/100 193~ 1856 ~5 30 '
~ F) 8UIL5 3/100 2~32 2025 523
- -- 6) END 3/~00 BUtED 3~98 2684 1344 67.;
~ ~ 9-5/8" ~ASI~ POINT 8849 4874 6553 67.',
~ I) D~P 2.5/108 ~746 5~6 9223
....... ~ J) E~ 2.5/~0~ DROP ~32F4 5963 J03~ 30,1
~~ K) ~ARGE] I3434 7J36 ~4~0 30,
L) TD / ~" CASI~ POINT 1~38 7486 ~0622
,,
~ -~4~ ~~--- ............
_~i~¢= ............... . - ~~ ..... _ .....
= ~ .... ~ :=~ ~= ~=~ ....................
=::: ..... : = ]]~ .._: .....
------ -- .--------.----_._.
, ., ..
.... '.': ............... ,. ~ .. ~ . _
6300 7000 7700 84~0 9[OD 9800 ]054)0 11200 J~O
i i . ! _ i _ i ii ii i
c]
bJ
n
" SHARED ' SER I'CES
ii ~ ! i i i · .. iii _ i i i
........ ~Br~F~ rr ' t ~ ~-h'Ci-f i'~ t-i on MD N/S E/~
AJ KB 0 O N O E
BI KOP / BUILfl ~.5/~00 300 0 N 0 E
C] BUILD 2/~00 ~0 2 N ~2 ~
D) END 2/~00 BUILD 1~86 74 N 385 K
El BUIL~ 2.5/i00 1932 79 ~ 408 N
FI BUILD 3/~00 2~32 g9 N 514 ~
G] E~ 3/t00 BUILD 3198 255 N t319 W
H] 9-5/8" CASING POINT 88~9 1244 N 6~3~ W
I) DROP 2.5/t00 t1746 ~751 N ~56 W
J) END 2.5/1~0 ~OP 1~234 ~960 N 10132 ~
X] TARGET 13434 %979 N 10230 M
L] TD / Z" CASING POINT 13838 2017 N 10~29 N
DR ILL I'NG .....
n · . mm ilmm i n mm _
ANADRILL AKA-DPC
APPROVED
FOR-PERMITTiNG
ONLY
PLAN
· mllm mi _11 m i m m i1___ I ·
/nadrJ ]7 Schlumberger
I
................ :Z':t'..k ......... n-""-i~ ..............
MPC-36 (PO4)
PLAN VIEW
.. · m iii i i
CLOSURE · t0522 fe~t at Azimuth 280.95
DECLINATION' +27.865
SCALE ' 1 inch = ~408 feet
)RAIN ' 24 Dec ~.907
t Jgoo 11200 1I>500 9800 9100 8400 7700 ?OOO 6300 5600 4~0 4200 3500 2800 2100 1400 700 0 700
<- I'IEST ' EAST->
I~ri~] (c)~7 wmo~04"a.a>.~ 'l'm:m ',.~ PI .....................
fT.~t I:larl~us ~:10 fP-et ~_
,.
·
I
%
VENDOR
DATE INVOICE / CREDIT MEMO I~ESCRIPTION GROSS DISCOUNT NET
i i 1897 CK111897H 100. O0 lO0. O0
PYMT COMMENTS- accompany 'permit to drill'
application
HANDLING iNST' s/h kathy campoaT, OT', x5122
·
.................. ~ '" P&YME~ FOR roMS DE~RIBED ABOVE. B[tlIill ~ 100. O0 i 00. O0
. WELL PERMIT CHECKLIST COMPANY ~ ~) )(,, WELL NAME /'v'¢/,,¢2 ~ ,.. ~ ~ z~ PROGRAM: exp [] dev [] redrll [] serv,J~'wellbore seg [~: ann. disposal para req
FIELD & POOL ~'~,..~ ~ ~ INIT CLASS _.~,,- [ - k.xJ l l~J GEOL AREA ~ ~ ~ UNIT# J I ~ ,~, ~" ON/OFF SHORE o ~
ADMINISTRATION
A~R DATE
1. Permit fee attached ....................... ~ N
2. Lease number appropriate ................... ~ N
3. Unique well name and number ................. ~ N
4. Well located in a defined pool .................. ~ N
5. Well located proper distance from drilling unit boundary .... (~ N
6. Well located proper distance from other wells .......... ~ N
7. Sufficient acreage available in drilling unit ........... N
8. If deviated, is wellbore plat included ............ N
9. Operator only affected party ................ N
10. Operator has appropriate bond in force ............. ,~ N
11. Permit can be issued without conservation order ....... ~) N
12. Permit can be issued without administrative approval ...... N
13. Can permit be approved before 15-day wait ........... N
ENGINEERING
14. Conductor string provided ................... (~ N
15. Surface casing protects all known USDWs ........... (~ N
16. CMT vol adequate to circulate on conductor & surf csg .....
17. CMT vol adequate to tie-in long string to surf csg ........ Y
18. CMT will cover all known productive horizons ..........
19. Casing designs adequate for C, T, B & permafrost ...... __
20. Adequate tankage or reserve pit .................
21. If a re-drill, has a 10-403 for abandonment been approved... ~Y' N ~,,,)//~"-
22. Adequate wellbore separation proposed ............. (,~ N
23. If diverter required, does it meet regulations .......... N .~~
24. Drilling fluid program schematic & equip list adequate ..... (~,..,. N
25. BOPEs, do they meet regulation ................ ~ N
26. BOPE press rating appropriate; test to ~"-O~.O psig~ ~ N
27. Choke manifold complies w/APl RP-53 (May 84) ........
28. Work will occur without operation shutdown ........... ~ N
29. Is presence of H2S gas probable ................. (_Y.,2 N
30. Permit can be issued w/o hydrogen sulfideS.. Y N
31. Data presented on potential overpr~Er, C,sst~e~ones ...... Y N
32. Seismic analysis of shall~~zones ............. Y N
33. Seabed cond~,JJ~ms'Crvey(if off-shore) ............. Y N
34~ne for weekly,progress repo. rts ....... Y N
~ ' [exhlor~ory onlyJ
GEOLOGY
APPR DATE
REMARKS
GEOLOGY:
ENGINEERING: COMMISSION:
BEWC¢~ tf'ef'~ DWJ~N~.
JDH ~ RNC
co -Co"-
Comments/Instructions'
HOW/lit
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.
Sperry-Sun Drilling Services
LIS Scan Utility
Fri Sep 04 10:49:31 1998
Reel Header
Service name ............. LISTPE
Date ..................... 98/09/04
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Previous Reel Name ....... UNKNOWN
Comments ................. STS LIS Writing Library. Scientific
Technical Services
Tape Header
Service name ............. LISTPE
Date ..................... 98/09/04
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Previous Tape Name ....... UNKNOWN
Comments ................. STS LIS Writing Library. Scientific
Technical Services
Physical EOF
Comment Record
TAPE HEADER
MILNE POINT UNIT
MWD/MAD LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
MWD RUN 2
AK-MM-80102
ZIEMKE
LOCKWOOD
RECE -VED
SEP 09 1990
A!a~a Oit & (~as ~ons, C~mmi~
An~omge
MPC-36
500292285300
BP EXPLORATION (ALASKA) , INC.
SPERRY-SUN DRILLING SERVICES
04-SEP-98 -
MWD RUN 3
AK-MM-80102
PIEPER
P. LOCKWOOD
10
13N
10E
952
2378
.00
48.20
17.00
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
1ST STRING
2ND STRING
3RD STRING 12.250 9.625 8501.0
PRODUCTION STRING 8.500 13896.0
REMARKS:
1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
2. MWD RUN %1 IS DIRECTIONAL ONLY.
3. MWD RUN %2 IS DIRECTIONAL WITH ELECTROMAGNETIC WAVE
RESISTIVITY PHASE-4
(EWR4) AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER
TUBE DETECTORS.
4. MWD RUN %3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR)
UTILIZING GEIGER
MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY
PHASE-4 (EWR4),
COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO
DENSITY (SLD).
5. ALL MWD RUNS REPRESENT MPC-36 WITH API#
50-029-22853-00. THIS WELL REACHED
A TOTAL DEPTH (TD) OF 13896'MD, 7583'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRC = SMOOTHED GAMMA RAY COMBINED.
SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA
SHALLOW SPACING).
SESP = SMOOTHED PAHSE SHIFT-DERIVED RESISTIVITY (SHALLOW
SPACING).
SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM
SPACING).
SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP
SPACING).
SFXE = SMOOTHED FORMATION EXPOSURE TIME FOR RESISTIVITY
SENSOR.
$
File Header
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/09/04
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.000
Comment Record
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD
Depth shifted and clipped curves; all bit runs merged.
DEPTH INCREMENT: .5000
FILE SUMMARY
PBU TOOL CODE START DEPTH
FET 4098.0
RPD 4098.0
RPM 4098.0
RPS 4098.0
RPX 4098.0
GR 4107.0
STOP DEPTH
13805 0
13805 0
13805 0
13805 0
13805 0
13824 5
ROP 4165.0 13896.0
FCNT 84 95.0 13779.0
NCNT 8495.0 13779 . 0
NPHI 84 95.0 13779.0
PEF 8497 . 0 13813 . 5
DRHO 8497 . 0 13813 . 5
RHOB 8497 . 0 13813.5
$
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
$
MERGED DATA SOURCE
PBU TOOL CODE
MWD
MWD
$
#
REMARKS:
EQUIVALENT UNSHIFTED DEPTH
BIT RUN NO MERGE TOP MERGE BASE
2 4163.0 8535.0
3 8535.0 13896.0
MERGED MAIN PASS.
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD FT/H 4 1 68 4 2
GR MWD API 4 1 68 8 3
RPX MWD OHMM 4 1 68 12 4
RPS MWD OHMM 4 1 68 16 5
RPM MWD OHMM 4 1 68 20 6
RPD MWD OHMM 4 1 68 24 7
FET MWD HOUR 4 1 68 28 8
NPHI MWD P.U. 4 1 68. 32 9
FCNT MWD CNTS 4 1 68 36 10
NCNT MWD CNTS 4 1 68 40 11
RHOB MWD G/CC 4 1 68 44 12
DRHO MWD G/CC 4 1 68 48 13
PEF MWD BARN 4 1 68 52 14
First
Name Min Max Mean Nsam Reading
DEPT 4098 13896 8997 19597 4098
ROP 12.8815 1193.25 270.456 19463 4165
GR 11.4603 240.87 81.2637 19436 4107
RPX 0.4993 2000 3.55025 19372 4098
RPS 0.0575 2000 3.92193 19372 4098
Last
Reading
13896
13896
13824.5
13805
13805
RPM 0.4846 2000 4.02514 19372
RPD 0.4489 2000 5.42873 19372
FET 0.1125 83.7409 1.32079 19372
NPHI 17.1625 81.7622 39.2521 10569
FCNT 421.5 1131 677.146 10569
NCNT 2118.68 3653.67 2709.77 10569
RHOB 1.4041 3.5106 2.36572 10634
DRHO -0.455 1.0991 0.0352467 10634
PEF 0.5512 8.5827 1.63423 10634
4098
4098
4098
8495
8495
8495
8497
8497
8497
13805
13805
13805
13779
13779
13779
13813.5
13813.5
13813.5
First Reading For Entire File .......... 4098
Last Reading For Entire File ........... 13896
File Trailer
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/09/04
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.002
Physical EOF
File Header
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/09/04
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER: 2
RAW MWD
Curves and log header data for each bit run in seParate files.
BIT RUN NUMBER: 2
DEPTH INCREMENT: .5000
#
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
FET 4098.0
RPD 4098.0
RPM 4098.0
RPS 4098.0
RPX 4098.0
GR 4107.0
ROP 4165.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
STOP DEPTH
8468 0
8468 0
8468 0
8468 0
8468 0
8476 0
8534 5
26- JAN- 98
5.07
5.46
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DGR DUAL GAMMA RAY
EWR4 ELECTROMAG. RESIS. 4
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
MEMORY
8535.0
4163.0
8535.0'
64.1
69.4
TOOL NUMBER
P0922CRG8
P0922CRG8
12.250
12.3
SPUD/LSND
9.30
650.0
8.8
1000
5.2
1.500
1.330
1.500
3.500
36.1
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 2 API 4 1 68 4 2
RPX MWD 2 OHMM 4 1 68 8 3
RPS MWD 2 OHMM 4 1 68 12 4
RPM MWD 2 OHMM 4 1 68 16 5
RPD MWD 2 OHMM 4 1 68
ROP MWD 2 FT/H 4 1 68
FET MWD 2 HOUR 4 1 68
20
24
28
Name Min Max Mean Nsam
DEPT 4098 8534.5 6316.25 8874
GR 11.4603 122.97 64.4106 8739
RPX 1.079 41.0525 4.32249 8741
RPS 1.0765 2000 5.29192 8741
RPM 1.074 2000 5.4102 8741
RPD 1.1282 2000 5.76349 8741
ROP 12.8815 1193.25 334.831 8740
FET 0.1123 13.85 0.8751 8741
First
Reading
4098
4107
4098
4098
4098
4098
4165
4098
Last
Reading
8534.5
8476
8468
8468
8468
8468
8534.5
8468
First Reading For Entire File .......... 4098
Last Reading For Entire File ........... 8534.5
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/09/04
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.003
Physical EOF
File Header
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/09/04
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER: 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 3
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
STOP DEPTH
RPD 8468.5 13805.0
RPM 8468.5 13805.0
RPS 8468.5 13805.0
RPX 8468.5 13805.0
FET 8469.0 13805.0
GR 8476.5 13824.5
FCNT 8495.0 13779.0
NCNT 8495.0
NPHI 8495.0
PEF 8497.0
DRHO 8497.0
RHOB 8497.0
RO? 8538.5
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DGR DUAL GAMMA RAY
EWR4 ELECTROMAG. RESIS. 4
CNP COMPENSATED NEUTRON
SLD STABILIZED LITHO DEN
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
13779.0
13779.0
13813.5
13813.5.
13813.5
13896.0
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
REMARKS:
$
#
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
31-JAN-98
5.07
5.46
MEMORY
13896.0
8535.0
13896.0
29.0
68.8
TOOL NUMBER
P0915CRLGM6
P0915CRLGM6
P0915CRLGM6
P0915CRLGM6
8.500
8.5
LSND
10.60
47.0
9.2
1100
3.5
1.500
.933
1.400
3.400
57.8
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order
Units Size Nsam
DEPT FT 4 1
GR MWD 3 API 4 1
RPX MWD 3 OHMM 4 1
RPS MWD 3 OHMM 4 1
RPM MWD 3 OHMM 4 1
RPD MWD 3 OHMM 4 1
NPHI MWD 3 P.U. 4 1
ROP MWD 3 FT/H 4 1
FET MWD 3 HOUR 4 1
FCNT MWD 3 CNTS 4 1
NCNT MWD 3 CNTS 4 1
RHOB MWD 3 G/CC 4 1
DRHO MWD 3 G/CC 4 1
PEF MWD 3 BARN 4 1
Rep Code Offset Channel
68 0 1
68 4 2
68 8 3
68 12 4
68 16 5
68 20 6
68 24 7
68 28 8
68 32 9
68 36 10
68 40 11
68 44 12
68 48 13
68 52 14
Name Min Max
DEPT 8468.5 13896
GR 22.9397 240.87
RPX 0.4993 2000
RPS 0.0575 15.5825
RPM 0.4846 22.8309
RPD 0.4489 2000
NPHI 17.1625 81.7622
ROP 16.5646 970.312
FET 0.3219 83.7409
FCNT 421.5 1131
NCNT 2118.68 3653.67
RHOB 1.4041 3.5106
DRHO -0.455 1.0991
PEF 0.5512 8.5827
Mean Nsam
11182.2 10856
95.032 10697
2.91231 10674
2.79799 10674
2.89284 10674
8.73601 10674
39.2521 10569
217.973 10716
2.00929 10673
677.146 10569
2709.77 10569
2.36572 10634
0.0352467 10634
1.63423 10634
First
Reading
8468.5
8476.5
8468.5
8468.5
8468.5
8468.5
8495
8538.5
8469
8495
8495
8497
8497
8497
Last
Reading
13896
13824.5
13805
13805
13805
13805
13779
13896
13805
13779
13779
13813.5
13813.5
13813.5
First Reading For Entire File .......... 8468.5
Last Reading For Entire File ........... 13896
File Trailer
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/09/04
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.004
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 98/09/04
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Next Tape Name ........... UNKNOWN
Comments ................. STS LIS Writing
Technical Services
Library.
Reel Trailer
Service name ............. LISTPE
Date ..................... 98/09/04
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Technical Services
Scientific
Scientific
Physical EOF
Physical EOF
End Of LIS File
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Some people who received this message don't often get email from jerimiah.galloway@hilcorp.com. Learn whythis is important
From:Regg, James B (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: Milne Point Well C-36 (PTD# 198-001) NOT OPERABLE
Date:Tuesday, January 31, 2023 9:46:19 AM
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>
Sent: Tuesday, January 31, 2023 9:33 AM
To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC)
<phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; DOA AOGCC
Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>
Cc: Alaska NS - Milne - Wellsite Supervisors <AlaskaNS-Milne-WellsiteSupervisors@hilcorp.com>;
Alaska NS - Wells Foreman <PBWellsForeman@hilcorp.com>; Scott Pessetto
<Scott.Pessetto@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>
Subject: Milne Point Well C-36 (PTD# 198-001) NOT OPERABLE
All,
Milne Point well C-36 (PTD # 198-001) will not be brought on line for the regularly scheduled MIT
this month. A tag will be hung on the well head, it will be classified as NOT OPERABLE, and it will be
tested prior to returning to injection.
Please respond with any comments or concerns.
Jerimiah Galloway
MPU/Islands Well Integrity Engineer
Email: jerimiah.galloway@hilcorp.com
O: (907)564-5005
C: (828)553-2537
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