Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout198-070• •
SEAN PARNELL, GOVERNOR
John McMullen
Engineering Team Leader
P.OEBox 196612Alaska), Inc. ~~~~ ~ ~ y„~, ~ ~~° '1 C} ~ ~ ~ ~ l~] b
Anchora e AK 99519-6612 ~~ `
~~
Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-36
Sundry Number: 310-179
Dear Mr. McMullen:
Enclosed is the approved Application for Sundry Approval relating to the above
referenced well. Please note the conditions of approval set out in the enclosed
form.
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause shown,
a person affected by it may file with the Commission an application for
rehearing. A request for rehearing is considered timely if it is received by 4:30
PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend. A person may not appeal a
Commission decision to Superior Court unless rehearing has been requested.
Sincerely,
Daniel T. Seamount, Jr.
r ~ Chair
DATED this! b day of June, 2010.
Encl.
~ `~/ GV~~C~gv
r,~ STATE OF ALASKA
"~(~~~ ALASK~L AND GAS CONSERVATION COMMIS~I ,~uN ~ ~ ?01Q~~~S-/O
(e APPLICATION FOR SUNDRY APPROVAL
Alaska Ai! ~ has Ceps. Commission
20 AAC 25.280 ~,,,,ha„„®
1. Type of Request:
^ Abandon - ®Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program
^ Suspend ^ Plug Perforations ^ Perforate - ®Pull Tubing ^ Time Extension
^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other
2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number
}
BP Exploration (Alaska) Inc. ®Development ^ Exploratory 198-070 -
3. Address: _
^ Service ^ Stratigraphic 6. API Number:
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22877-00-00 `-
7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number:
property line where ownership or landownership changes:
PBU 02-36 -
Spacing Exception Required? ^ Yes ®No
9. Property Designation: 10. Field /Pool(s):
ADL 028308 & 028307 Prudhoe Bay Field / Prudhoe Bay Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
13862' - 8747' - 13768' - 8748' None 11677'
Casin Len Size MD TVD .Burst Colla e
Structural
Conductor 1 1 1
Surface 7 9-5/8" 7 7' 7 0
Intermediate 1 41 7" 1043 ' 8208' 7 4 5410
Production
Liner 3658' 4-112" 1 ' - 1 80 ' - 747' 8430 7
Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft):
11374' - 13710' 8759' - 8748' 4-1/2", 12.6# 13Cr80 / L-80 10193'
Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer; Packers and SSSV 10017';
7" x 4-1/2" Baker'SB-3' packer MD (ft) and TVD (ft): 10148'
12. Attachments: 13. Well Class after proposed work:
® Description Summary of Proposal ^ BOP Sketch
^ Exploratory ®Development ^ Service
^ Detailed Operations Program
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: July 1, 2010 ^ Oil ^ WINJ ^ WDSPL ^ Plugged
16. Verbal Approval: Date: ^ Gas ^ GINJ ^ GSTOR ^ Abandoned
^ WAG ^ SPLUG - ®Suspended
Commission Representative:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Eli V~r uez, 564-5918
Printed Name J IS , I en Title Engineering~Team Leader
/ Prepared BY Name/Number.
Signature C--~-~ Phone 564-4711 Date ~ /y ~G' Terrie Hubble, 564-4628
Commission Use Onl
Conditions of approval: Notify Commission so that a representative may witness ~~ ~. 1
Sundry Number: 1
^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance
~- 3 Soo ,03 ~ GD ~ s ~
Other: Q _ T L \
Subsequent Form Required: 1 ~'-~Q
APPROVED BY ~ ~~~ l
d
1
Approved By: COMMISSIONER THE COMMISSION Date
Form 10-403 Revised 01~D~~[ fUN 17 ~ ~ I ~t ~- ~'~i /O Submit In Duplicate
-~`
•
To: Alaska Oil & Gas Conservation Commission
From: Eli Vazquez ~~
CTD Engineer
Date: June 4t", 2010
Re: 02-36 Sundry Approval
Sundry approval is requested to abandon perforations on well 02-36 in preparation for a CTD sidetrack.
The 02-36 well was originally drilled and completed as a Zone 1 producer in June, 1998. The perforation guns
became stuck after perforating and following different attempts to fish them, the team was unable to retrieve
them. The guns were left in the same position as when fired. On June 06, 2000, the fish was tagged and
appeared to have sat down at 11,237' SLM. The well was drifted with an impression block, jarred down many
times but no picture was recovered.
The 02-36 well produced as a full time well for 1 year and began cycling in mid 1999. The well cycled poorly and
Z1 heel additional perforations were shot (11522'- 11562', 11374' -11394') in December 2000. The additional
perforations increased the oil rate and diluted the GOR. The well began cycling again in early 2002.
In April 2002, the well failed a TIFL with an initial fluid level at 7400'. Dummy gas lift valves were installed but
the well failed the subsequent TIFL. A caliper log in June 2002 indicated several tubing holes and severe
corrosion damage. The well was secured with a TTP set at 10,170' MD in June 2002 and it was left shut in until
2006.
In September 2006 a CMIT TxIA to 3500 psi was done in the well. The passing test confirmed the 7" casing.
integrity. In March 2007, a caliper log was run in the well. The caliper confirmed the poor condition of the tubing.
Based on the results of the previous diagnostics, a RWO package was submitted and on 06/16/2007 a RWO to_
repair a TxIA communication was completed.
After the RWO, the well continued flowing as a fulltime producer with high GOR. The well was set on cycles but
it showed no signs of healing during the SI periods. Due to the inability to do some well work (fish), the well was
tested at different FTP settings to bring some extra fluid.
The results of the test showed that the well could only flow safely at 2000 psi due to solids production. At lower
pressures, the well produces solids (sand) and it will not be considered safe to flow to the facilities. In August
2009, the well reached a high GOR making it non-competitive. With no more well work opportunities, a coil
tubing sidetrack will enable this 4th" monobore to be more effectively utilized and bring value to the field.
The sidetrack, 02-36A, is scheduled to be drilled by Nordic 2 starting on July 20t", 2010. This horizontal lateral
,~uilLtarget Ivishak Zone 1 A. The perforations in the parent well will be abandoned with a 4~h" monobore packer
whipstock placed inside the 4Yz" L-80 production liner at 10,900' MD. The "A" sidetrack lateral will exit the parent
well at 10,900' MD in the Ivishak Zone 2 and drill a 2,300' lateral to a TD of 13,200' MD. The sidetrack will be
completed with a solid, cemented and perforated 3'/z" x 2-7/8" L-80 production liner. The following describes
work planned. A schematic diagram of the proposed sidetrack is attached for reference. ~
CTD Sidetrack Summary
C;v.aCo'~. ~~i5t.~~/Q
Pre-CT Rig Work: The pre CTD work is planned to begin July 1St. 2010. r /'~^~~~
1. D MIT-IA to 3000 psi, MIT- OA to 2000 psi. ~*.'-.v,•g,
2. W Check tubing hanger LDS. ~r<,~'+~~;ri~,
3. W PPPOT-T to 5000 psi ~ ~ ~ ~ ~,
4. V PT tree (MV,SV,WV)
5. E Drift for 4'/z" monobore packer whipstock.
6. E Set 4'/z" monobore packer whipstock low-side at 10,900' MD. '
7. F Test 4'/z" monobore packer whipstock to 1000 psi.
8. D Bleed wellhead pressures down to zero. .
9. D Bleed production flow lines and GL lines down to zero and blind flange.
10. O Remove wellhouse, level pad.
~%,,d/~
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~%° • /~;ny y~~ r~gzl~
~tt~:%~c% lv~ti~~'ar~ Grv
hn~ ~~~( ~//~
yhtl ~ecr~~ei' f~M i'~i~f ~`%~~~
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~~~~
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Rig Sidetrack Operations:
1. MIRU Nordic Rig 2
(Scheduled to begin on July 20th, 2010 using Nordic Rig 2)
2. NU 7-1/16" CT Drilling BOPE and test
3.
4.
5.
6.
7.
8.
9.
10.
11.
12.
13.
14.
Mill 3.80" single string window in 4'/i" 12.6# L-80 BTC production liner from mechanical whipstock.
Drill build and turn section with 4.25" bicenter bit, and land well in target Ivishak Zone 1 A sand.
Drill 4.25" lateral section to 13,200' MD.
Run and cement a 3t/z" x 2-7/8" L-80 production liner string. Place liner top at 10,720' MD.
Cement 3'/z" x 2-7/8" L-80 production liner. Expect ~29 bbl of 15.8 ppg cement.
Perform cleanout/log run with mill, motor and MCNL
Test Liner lap to 2000 psi.
Perforate well
Run Liner Top Packer, if needed.
Freeze protect well to 2000' TVD.
Set BPV. ND 7-1/16" BOPE stack. Freeze protect tree and PT tree cap to 3500 psi.
RDMO Nordic 2.
Post-Rig Work:
1. Re-install wellhouse and FL's.
2. Pull BPV.
3. RU test separator.
Eli Vazquez
Coil Tubing Drilling Engineer
~'t D
ps 2.3~A
CC: Well File
Sondra Stewman/Terrie Hubble
TREE = CIW
WELLHEAD = FMC
,.,-.,--~
ACNATOR = ,n_
BAKER C
KB. ELEV = 60'
BF. ELEV
KOP = 1787'
Max Angle = 95° @ 12208'
Datum MD = 11097'
Datum ND = 8800' SS
O ~ ~ " 6 SAFETY NOT WELL ANGLE > 70° @ 11289' TM*"' 4-1/2"
CHROMET ""
1985' ~4-112" HES X NIP, ID = 3.813"
GAS LIFT MANDRELS
9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" ~~ 3763'
Minimum ID = 3.813" @ 1985'
4-1 /2" HES X NIPPLE
4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, I 10101'
.0152 bpf, ID = 3.958"
4-1l2" TBG STUB (06/02/07) 10108'
ITOPOF4-1/2"LNR 10192'
4-1/2" TBG, 12.6#, L-80 BTC, 10193'
.0152 bpf, ID = 3.958"
~ 7" CSG, 26#, L-80 BTGM, ID = 6.276" ~
PERFORATION SUMMARY
R~ LOG: GRlCCL
ANGLEATTOPPERF:83° @ 11374'
Note: Refer to Production DB for historical pert data
SIZE SPF INTERVAL Opn/Sqz DATE
3-3l8" 4 11374 - 11394 C 11 /24/00
3-3/8" 4 11522 - 11562 C 11 /25/00
2-3/4" 4 11665 - 11930 C 06!01 /98
2-3/4" 4 12200 - 12660 C 06/01 /98
2-3/4" 4 12700 - 12790 C 06/01 /98
2-3/4" 4 13000 - 13040 C 06/01 /98
2-3/4" 4 13210 - 13520 C 06/01 /98
2-3/4" 4 13580 - 13710 C 06/01 /98
PBTD 13768'
4-1/2" LNR, 12.6#, L-80 BTC, .0152 bpf, ID = 3.958" 13850'
TD 138x2'
ST MD ND DEV NPE VLV LATCH PORT DATE
2
1 3771
7369 3484
6010 46
46 KBG-2
KGB-2 DMY
DMY BK
BK 0
0 01/11/10
01/11/10
9996' ~4-112" HES X NIP, ID = 3.813"
10017' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875"
10041' 4-1/2" HES X NIP, ID = 3.813"
~~ 7" X 4-1 /2" UNIQUE OV ERSHOT i
7" X 4-1/2" BKR S-3 PKR, ID = 3.875"
4-1/2" HES X NIP, ID = 3.813"
10192' -j 7" X 5" BKR ZXP LTP I
wlfIEBACK SLV, ID = 4.40"?
10193' 4-1/2" WLEG, ID = 3.958"
10206' 7" X 5" HMC LNR HGR, ID = 4.40?
10213' S" X 4-1/2" XO, ID = 3.937"
10198' ELMD TT LOGGED 06/16/98
DATE REV BY COMMENTS DATE REV BY COMMENTS
08/04/98 N22E ORIGINAL COMPLETION
08/14/07 N4ES RWO
06/23/07 JLJ/PJC GLV CORRECTIONS
12/18/08 AW/JMD DRLG DRAFT CORRECTIONS
01/31/10 JLJ/PJC GLV GO (01/11/10)
~ FISH (06/01/98) PERF GUNS ~
PRUDHOE BAY UNIT
WELL: ~2-36
PERMIT No: 198-070
API No: 50-029-22877-00
SEC 36, T11 N, R14E, 620.58 FNL & 1688.72 FWL
BP Exploration (Alaska)
TREE = CMJ
WELLkiEAD= FMC
ACTUATOR = BAKER C
KB. ELEV = 60'
BF. ELEV =
KOP = 1787'
Max Angle = 95° @ 12208'
Datum MD = 11097'
Datum TV D = 8800' SS
9-518" CSC, 40#, L-80 BTC, ID = 8.835"
~ 02-36
Proposed CTD Sidl
Minimum ID = 2.3" @ 10720'
TOL 3-112"
4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 10101'
.0152 bpf, ID = 3.958"
4-1/2" TBG STUB (06/02/07) 10108'
TOP OF 4-1/2" LNR ~ 10192'
4-1/2" TBG, 12.6#, L-80 BTC, 10193
.0152 bpf, ID = 3.958"
7" CSC, 26#, L-80 BTGM, ID = 6.276" ~~ 1
4-1/2" HES X NIP, ID = 3.813"
~A S I IFT MANDRELS
ST MD TVD DEV TYPE VLV LATCH PORT DATE
2
1 3771
7369 3484
6010 46
46 KBG-2
KGB-2 DMY
DMY BK
BK 0
0 01/11/10
01/11/10
9996' ~ 4-1 /2" HES X NIP, ID = 3.813"
10017' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875"
10041' 4-1/2" HES X NIP, ID = 3.813"
10106' 7" X 4-1 /2" UNIQUE OV ERSHOT
10148' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875"
10171' 4-1/2" HES X NIP, ID = 3.813"
10192' 7" X 5" BKR ZXP LTP
w /TIEBACK SLV, ID = 4.40"?
10193 4-1/2" WLEG, ID = 3.958"
10206' 7" X 5" HMC LNR HGR, ID = 4.40?
10213' 5" X 4-1/2" XO, ID = 3.937"
10198' ELMD TT LOGGED 06/16/98
TSGR 10447'
10700' ~~4-1/2" BKR KB LTP ID = 2.375"
1/2" monobore pkr w hipstock
PERFORATION SUMMARY
REF LOG: GR/CCL
ANGLE AT TOP PERF: 83° @ 11374'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
3-3/8" 4 11374 - 11394 C 11 /24/00
3-3/8" 4 11522 - 11562 C 11/25/00
2-3/4" 4 11665 - 11930 C 06/01/98
2-3/4" 4 12200 - 12660 C 06/01/98
2-3/4" 4 12700 - 12790 C 06/01/98
2-3/4" 4 13000 - 13040 C 06/01/98
2-3/4" 4 13210 - 13520 C 06/01/98
2-3/4" 4 13580 - 13710 C 06/01/98
PBTD
4-1/2" LNR, 12.6#, L-80 BTC, .0152 bpf, ID = 3.958"
DATE REV BY COMMENTS DATE REV BY COMMENTS
06/04/98 N22E ORIGINAL COMPLETION
06/14/07 N4ES RWO
06/23/07 JLJ/PJC GLV CORRECTIONS
12/18/08 AW/JMD DRLG DRAFT CORRECTIONS
01/31/10 JLJ/PJC GLV GO (01/11/10)
03/10/10 MSE PROPOSED CTD SIDETRACK
11677' ~--~ FISH (06/01/98) PERF GUNS
PRUDHOE BAY UNfr
WELL: 02-36A
PERMfr No:
API No: 50-029-22877-01
SEC 36, T11 N, R14E, 620.58 FNL & 1688.72 FWL
BP Exploration (Alaska)
44° 10720' TOL, TOC ID = 2.30"
10870 3-3116 x z-7/8 x-over gCGL 10876'
43° ~,
~ 3-1/2" X 2-718" liner ~
~-
. STATE OF ALASKA .r~.:5-d7
ALASKA Oil AND GAS CONSERVATION COM~ION
REPORT OF SUNDRY WELL OPERATIONS
RECE'VED
JUL 1 3 Z007
Alaska Oil & Gas Coos. CQmmission
1. Operations Performed: ...."....' "\:j'
o Abandon o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well
o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver o Other
o Change Approved Program o Operation Shutdown o Perforate o Time Extension
2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number:
BP Exploration (Alaska) Inc. ~ Development o Exploratory 198-070 -
3. Address: o Service o Stratigraphic 6. API Number:
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22877 -00-00 -
7. KB Elevation (ft): 59.52' / 9. Well Name and Number:
PBU 02-36 /
8. Property Designation: 10. Field / Pool(s):
ADL 028307 < Prudhoe Bay Field / Prudhoe Bay Pool -
11. Present well condition summary
Total depth: measured 13862 I feet
true vertical 8747 feet Plugs (measured) None
Effective depth: measured 13768 feet Junk (measured) 11677
true vertical 8748 feet
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 110' 20" 110' 110' 1490 470
Surface 3733' 9-5/8" 3763' 3478' 5750 3090
Intermediate 1041 0' 7" 1 0439' 8208' 7240 5410
Production
Liner 3658' 4-1/2" 10192' - 13850' 8039' - 8747' 8430 7500
SCANNED JUL 1 B 2007
Perforation Depth MD (ft): 11374'-13710'
Perforation Depth TVD (ft): 8759' - 8748'
4-1/2", 12.6# 13Cr80 1L-80 10193'
Tubing Size (size, grade, and measured depth):
Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer; 10017';
7" x 4-1/2" Baker 'SB-3' packer 10148'
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment description including volumes used and final pressure: R8DMS 8Fl JUL 1 Î 20D7
13. Representative Dailv Averaae Production or Iniection Data
Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure
Prior to well operation:
Subsequent to operation: 2,350 37,043 27 1,020 659
14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work:
~ Daily Report of Well Operations o Exploratory ~ Development o Service
16. Well Status after proposed work:
~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ DWINJ o WDSPL
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number òr N/A if C.O. Exempt:
Contact Aras Worthington, 564-4102 N/A
Printed Name Terrie Hubble Title Technical Assistant
Signature /1Ôf\AiD tJo I~ o 7j/zi Prepared By Name/Number:
Phone 564-4628 Date 07 Terrie Hubble, 564-4628
. .
Form 10-404 Revised 04/2006
ORIGINAL
þ,-.",,, # ;1Í't67 S"bm'O"g"""O"~
Digital Wellfile
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Page 1 of 1
Well: 02-36
Well Events for SurfaceWell - 02-36
Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FSl -> 02 -> 02-36
Date Range: 05/Mar/2007 to 11/Jun/2007
Data Source(s): AWGRS
Events
Source Well
AWGRS 02-36
AWGRS 02-36
Date
06/11/2007
06/04/2007
AWGRS 02-36 06/04/2007
AWGRS 02-36 06/04/2007
AWGRS 02-36 06/02/2007
AW_GJs5. 02-36 06/01/2007
AWGRS 02-36 OS/27/2007
AWGRS 02-36
OS/26/2007
AWGJ~.S 02-36 OS/25/2007
AWGRS 02-36 OS/20/2007
AWGRS 02-36 05/19/2007
AWGRS 02-36 03/15/2007
AWGRS 02-36 03/14/2007
AWGRS 02-36 03/06/2007
AW~RS 02-36 03/05/2007
Description
PULL 4" CIW BPV THRU TREE POST RIG MOVING ON WELL API VALVE SHOP
T/I/0=20/80/20 Temp=SI Bleed WHPs to 0 psi (pre-rig). TBG, lA, & Oil. FLs near surface. Bled
TBG & lAP to bleed trailer from 20/80 psi to % psi in 30 min. Bled OAP from 20 psi to 0 psi
in 20 min. Shut in and monitor pressures for 30 min. No change in pressures post monitor.
Final WHPs=O/O/O
SET 4" CIW BPV THRU TREE PRE RIG WORK API VALVE SHOP
SET 4" crw BPV THRU TREE PRE RIG WORK API VALVE SHOP
INITIAL WHP 100/0/0 SHOT TWO STRAND STRING SHOT FROM 10098'-10110', CUT TUBING
10108' MID JT OF FIRST FULL JT ABOVE PACKER WITH CHEMICAL CUTTER 3.625",3
CENTRALIZERS RUN. WELL SHUT IN. FINAL WHP 50/50/0. ***JOB COMPLETE***
SHOT SMALL TUBING PUNCH ON THE INTERVAL 10090'-10092', WHP BEFORE: 0/0/0, WHP
AFTER: 0/0/0. REMAINDER OF JOB POSTPONED DUE TO CALL OUT TO DO CORRELATION ON
A RIG AT W-213. ***CONTINUED ON 02-JUNE-2007***
T/I/O=O/O/O. PPPOT-T (PASS), PPPOT-IC (PASS). Pre rig. PPPOT-T: Stung into test port to
check pressure (0 psi). Pumped through void until clean fluid was achieved. Pressured void to
5000 psi for 30 min test, lost 100 psi in 15 min, lost 40 psi in second 15 min (PASS).
Functioned LDS, all moved freely, no sign of bent or broken pins. PPPOT-IC: Stung into test
port to check pressure (800 psi), bled to 0 psi. Pressured void to 3500 psi for 30 min test, lost
150 psi in 15 min, lost 50 psi in second 15 min (PASS). Functioned LDS, all moved freely, no
sign of bent or broken pins.
T/I/O = 100/120/0 CMIT TxIA to 3500 psi (PASSED) HIT Oil. to 2000 psi (PASSED) (Pre RWO)
Pumped 13 BBLS of Crude into tubing to reach test pressure. CMIT TxIA lost 80/80 psi in the
first 15 min and 40/40 psi in the second 15 min for a total loss of 120/120 psi in the 30 min
test. MIT Oil. pumped 1.2 BBLS of Crude to reach test pressure. MIT Oil. lost 30 psi in the first
15 min and 0 psi in the second 15 min for a total loss of 30 psi in the 30 min test. Bled down
all WHPs Final WHPs = 0/0/0
***WELL WAS SHUT IN ON ARRIVAL*** (Pre RWO) DUMP BAIL (2) 100 LBS BAGS OF
SLUGGITS FROM 10,150' SLM TO 10,141' SLM. ***LEFT WELL S/I*** DSO NOTIFIED
T/I/O = 10/40/0. Temp = S1. WHPs (pre-RIG). TBG pressure increased 10 psi and the lAP
increased 40 psi overnight.
T/I/O = 350/210/80. S1. Bleed WHPs to 0 psi (pre-Rig). No AL Bled WHPs to bleed trailer to 0
psi (9 hrs). Monitor 30 min. Final WHPs = 0+/0/0.
***JOB CONTINUED FROM 14 MAR*** RAN MULTI-FINGER CALIPER AND ELECTRO-
MAGNETIC IMAGING TOOL FROM SURFACE TO 10,100'. CONFIRMED TUBING WAS IN POOR
CONDITION AS PDS LOG RUN ON 6-6-02. DATA TO HAVE FINAL PORCESSING DONE AT
SHOP. DSO NOTIFIED WELL SHUT-IN AND SECURE. ***JOB COMPLETE***
***WELL SHUT IN ON ARRIVAL *** LOGGING PMIT AND EMIT FROM PLUG AT 10170' TO
SURFACE. ***JOB CONTINUED ON MAR 15 WSR***
*** CONTINUED FROM 3/5/07 WSR *** DRIFTED W/ 2.5" CENT TO 4-1/2" TT PLUG AT
10160' SLM *** WELL LEFT S/I ON DEPARTURE ***
*** WELL S/I ON ARRIVAL *** RIH W/2.50" DRIFT TO TT PLUG / PRE-EMIT ***CONT ON 03-
06-2007***
http://digitalwellfile.bpweb.bp .comIW ellEvents/Home/Defaul t. asp x
7/12/2007
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Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
02-36
02-36
WORKOVER
l-\ ~ <> ~ fVA" '"1. ( \ '\
Start: 6/1/2007
Rig Release:
Rig Number:
Spud Date: 4/20/1998
End: 6/9/2007
6/11/2007 06:00 - 07:30 1.50 RIGD P PRE PJSM - Lower derrick. Lower derrick. Rig down sub base, pits
and pipe shed. AOGCC - Gave 24-hr. notice of impending
BOPE test.
07:30 - 10:30 3.00 MOB P PRE Move rig down drillsite to 02-36. Spot sub, pipeshed and pits.
10:30 - 12:00 1.50 MOB P PRE Rig up pits, pipeshed & sub. Raise derrick to half mast.
12:00 - 13:00 1.00 MOB P PRE Scope derrick to full mast. Take on seawater into pits.
Accepted rig @ 1300-hrs.
13:00 - 15:00 2.00 RIGU P DECOMP Hook up circulating lines in cellar and to Tiger Tank. PJSM-
All crew: Pull BPV w/lubricator.
15:00 - 15:30 0.50 WHSUR P DECOMP PUMU lubricator. Valve shop tech pull BPV. UD lubricator.
15:30 - 16:00 0.50 KILL P DECOMP PIT circulating lines to 3500-psi. wlseawater. SITP - 75-psi,
SICP - 100-psi, OAP - O-psi.
16:00 - 19:00 3.00 KILL P DECOMP Reverse circulate well with 50-Bbls. of 120F seawater @
5.0-BPM @ 300-psi to displace dead crude from tubing taking
returns to Tiger Tank. Swap to circulating down tubing and
pumped total of 475 bbls. Pumped @ 5.0-BPM, 355-psi.
Pressure increased to 570 psi. Taking returns to Tiger Tank.
SID after 325 bbls & check Tiger tank. Hook up Vac Truck to
tank. Resume cirulating. Pump 3 BPM @ 260 psi & increased
to 5 BPM @ 720 psi. started getting water returns @ 365 bbls.
Con't to pump until clean returns. SID TP = 0 psi, CP = 0 psi.
19:00 - 19:30 0.50 KILL P DECOMP Open up & Monitor well, .. well dead.
19:30 - 21 :30 2.00 WHSUR P DECOMP P/U T-bar & install TWC. Pressure test from to to 3500 psi &
test from bottom to 1000 psi. Held each test for 10 min.
Charted same.
21 :30 - 23:00 1.50 WHSUR P DECOMP N/D adapter flange & tree. Check hanger threads, 8 1/2 turns:
41/2" NSCT. Measure KB, 19.70'.
23:00 - 00:00 1.00 BOPSU DECOMP NIU BOPE.
6/12/2007 00:00 - 01 :00 1.00 BOPSU DECOMP Finish NIU BOPE.
01 :00 - 05:30 4.50 BOPSU DECOMP Pressure test BOPE as per BP I AOGCC requirements. LP =
250 psi. HP = 3500 psi. Tested rams w/3 1/2" & 41/2" test jts.
BOP test witnessing waived by Jeff Jones wI AOGCC.
05:30 - 06:00 0.50 BOPSU P DECOMP Drain stack. N/D test equip.
06:00 - 07:00 1.00 WHSUR P DECOMP P/U 7" lubricator extension, close annular preventer and P/U
lubricator. Pull TWC. Well dead. UD lubricator, open annular
preventer UD 7" lubricator extension.
07:00 - 08:00 1.00 PULL P DECOMP PUMU 3-1/2" DP landing jt. & 3-1/2" x 4-1/2" NSCT XO. Screw
assy. in tubing hanger. BOLDS. Unland tubing hanger and
hoist to floor. PUW = 125K. BO/LD landing joint and tubing
hanger.
08:00 - 09:00 1.00 PULL DECOMP Circulate bottoms up @ 5.0-bpm @ 600-psi. Small amount of
gas in returns at bottoms up.
09:00 - 18:00 9.00 PULL P DECOMP Rig up floor with 4-1/2" tubing handling tools and control line
spooler. POH w/4-1/2" 12.6#/ft. L-80 tubing 1 x1 through
pipeshed. Maintaining well control with double steel
displacement while POH. 48 jt. POH @ 1200-hrs. Recovered
52 SS bands. Con't to POOH & UD 1921 Jts.
18:00 - 18:30 0.50 PULL P DECOMP Crew change. Check PVT alarms. Inspect derrick.
18:30 - 19:30 1.00 PULL P DECOMP Con't to POOH & UD 4 1/2" completion. Total recovery as
follows: 244 Jts 41/2" 12.6#, L-80, IBTM tubing, 1 - cut off jt
19.33' (4.55" OD), 1 - SSV Assy, 3 - GLM Assys.
19:30 - 21:00 1.50 PULL P DECOMP Clear & clean rig floor. RID tubing tools. RlU DP handling
equip.
Printed: 7/10/2007 10:41:06AM
.
.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
02-36
02-36
WORKOVER
1-\ t: ~
Start: 6/1/2007
Rig Release:
Rig Number:
Spud Date: 4/20/1998
End: 6/9/2007
6/12/2007 21 :00 - 22:30 1 .50 CLEAN P DECOMP PIU, Tally & M/U BHA #1 as follows: Cut Lip Shoe, 2 .
Washpipe Ext, W/O Boot Basket, XO, 2 Boot Baskets, Csg
Scraper, Bit Sub, Bumper Sub, Jars, Pump Out Sub, 6 . 4 3/4"
DCs. TL = 237.71'.
22:30 - 23:00 0.50 CLEAN DECOMP RIH wI BHA #1 on 24 its of 31/2" DP.
23:00 - 23:30 0.50 CLEAN P DECOMP M/U Storm Packer on string. PIU 1 it of 31/2" DP. RIH & set
Packer @ 30'.
23:30 - 00:00 0.50 CLEAN P DECOMP Pressure test Storm packer to 1000 psi for 10 min. Good test.
Charted same. RID test equip.
6/13/2007 00:00 - 00:30 0.50 WHSUR P DECOMP M/U running tool, RIH & engage 7" Pack off. BOLDS. Pull Pack
off wI 20K overpull. POOH & UD Pack off.
00:30 - 01 :30 1.00 WHSUR P DECOMP M/U new 7" Pack off on running tool. RIH & set Pack off in
spool. RILDS. UD running tool. Pressure up on Pack off & test
to 5000 psi for 15 min. Tested Good. Install Wear Bushing in
spool.
01 :30 - 02:00 0.50 CLEAN P DECOMP PIU single, RIH & screw into Storm Packer. P/U & unset
Packer. POOH & UD Packer.
02:00 - 06:00 4.00 CLEAN P DECOMP P/U 3 1/2" DP 1x1 & RIH wI BHA #1. RIH wI 220 jts.
06:00 - 06:30 0.50 CLEAN P DECOMP PJSM. Check crown 0 matic, PVT system, derrick inspection,
OK.
06:30 - 09:00 2.50 CLEAN P DECOMP PJSM. Continue in hole picking up 31/2" DP 1x1 from pipe
shed, 311 its + a 24' pup. Pick up kelly.
09:00 - 09:30 0.50 CLEAN P DECOMP PJSM. Establish parameters, 157K up wt, 97K down wt. Bring
on pump, 5 bpm 11400 psi. See top of stub @ 10,104' DPM,
wash over to 10,116', no bobbles, no trobbles. Repeat wlo
rotating, OK.
09:30 - 11 :00 1.50 CLEAN P DECOMP PJSM. Reverse circulate hole clean, 5 bpm 11400 psi, nothing
significant back over shaker, hole clean, OK. ~
11 :00 - 16:00 5.00 CLEAN P DECOMP PJSM. Replace mud manifold to comply to AOGCC regs
concerning threaded connections on kill line. Pressure tested
mud manifold to 5000 psi, OK.
16:00 - 18:00 2.00 CLEAN P DECOMP PJSM. POOH w/3 1/2" DP & overshot assembly.
18:00 - 18:30 0.50 CLEAN P DECOMP Crew Change. Check PVT alarms. Inspect derrick.
18:30 - 19:30 1.00 CLEAN P DECOMP Finsh POOH & stand back 31/2" DP.
19:30 - 20:30 1.00 CLEAN P DECOMP Stand back DCs. Break out & UD BHA # 1.
20:30 - 21 :30 1.00 CLEAN DECOMP Clean & empty boot baskets. Recovered small amount of scale
& 1 - SS band. Clear & clean rig floor.
21 :30 - 22:00 0.50 CLEAN P DECOMP P/U, tally & M/U BHA #2 to fish "XX" Plug as follows: GS
Spear, XO, 4' Jts 2 7/8" PAC DP, XO, Bumper Sub, Jars,
Pump Out Sub, 6' 4 3/4" DCs. TL = 333.92'. RIH wI same.
22:00 - 00:00 2.00 CLEAN P DECOMP RIH wI BHA #2 on 3 1/2" DP.
6/14/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP Con't to RIH wI BHA #2 on 103 stands of 31/2" DP.
01 :00 - 02:00 1.00 CLEAN P DECOMP Break circulation & P/U 1 single, 24' pup & 9 1/2' of 2nd it .
Circulate 3.4 BPM @ 1620 psi. Tag up on XX Plug @ 10168'.
02:00 - 04:00 2.00 CLEAN N WAIT DECOMP Wait on Vac truck wI seawater. Trucks stacked up 12 deep @
Pad 3. Waiting on fluid prior to pulling plug (H2S well).
04:00 - 04:30 0.50 CLEAN P DECOMP Engage "XX" Plug & P/U. Plug came free 10K overpull. Fluid
level slowly dropped. P/U Wt = 147K, SIO Wt = 102K.
04:30 - 05:00 0.50 CLEAN P DECOMP Drop ball & open Pump out Sub wI 2200 psi. Circulate & check
losses. Losing 15 bbls in 10 min @ pump rate of 4 BPM.
05:00 - 05:30 0.50 CLEAN P DECOMP SID pump. RIH to insure plug is still latched on. RIH past nipple
profile., Con't in hole to 27' outside of tubing tailpipe @ 10220'.
Printed: 7/10/2007 10:41:06 AM
.
.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
02-36
02-36
WORKOVER
u.ES
Start: 6/1/2007
Rig Release:
Rig Number:
Spud Date: 4/20/1998
End: 6/9/2007
POOH & LDDP, LD collars & 2 7/8" PAC pipe, recovered plug,
packing missing.
16:00 - 18:00 2.00 RUNCMP PJSM. Clear I clean rig floor, pull wear bushing, prep to run
completion string. RlU Torque Turn equip.
18:00 - 19:00 1.00 RUNCMP P/U & M/U completion tailpipe assys. Baker Lok all
connections below packer & torque Turn same.
19:00 - 00:00 5.00 RUNCMP PIU 4 1/2" 12.6#, 13Cr-80 Vam Top completion & RIH as per
program. Torque Turn all connections to 4440 ft-Ibs. Used Jet
Lube Seal Guard on all connections. RIH wI 61 jts.
6/15/2007 00:00 - 10:00 RUNCMP Con't to RIH w/4 1/2" 12.6#, 13Cr-80 Yarn Top completion.
Torque Turn all connections to 4440 ft-Ibs. Used Jet Lube Seal
Guard on all connections. RIH wI 237 jts. 120K up wt, 83K
down wt.
10:00 - 12:30 RUNCMP PJSM. Pick up jt # 238, see pins shear on Unique overshot wI
8 -10K down w/1' in on jt # 238. Space out, UD # 238,237 &
236, install (3) pups, (9.90', 5.82'. & 3.83'). Make up Jt # 236 &
tubing hanger wI pup. M/U landing jt. Land hanger, RILDs.
12:30 - 15:00 RUNCMP PJSM. Line up & reverse circulate 150 bbls of 120 degree
inhibited seawater followed by 150 bbls of 120 degree seawater
@ 3 bpm I 675 psi.
15:00 - 17:30 RUNCMP PJSM. Drop rod I ball assembly. Fill tubing & pressure test
tubing I set packer wI 3500 psi, 30 minute test, charted, OK.
Bleed pressure to 2000 psi, line up & pressure up 7" x 4 1/2"
annulus @ 3500 psi, 30 minutes, charted, OK. Bleed off TP &
shear out DCK-SV. Pump thru Shear valve both ways.
17:30 - 18:30 1.00 WHSUR P RUNCMP Install TWC. Test from above & below to 1000 psi for 10 min.
Test Good. Charted test.
18:30 - 19:00 0.50 BOPSU RUNCMP RID & blow down lines. Drain stack.
19:00 - 20:30 1.50 BOPSU P RUNCMP N/D BOPE.
20:30 - 22:30 2.00 WHSUR P RUNCMP N/U adapter flange. Test Tbg void to 5000 psi, OK. NIU tree.
Fill tree & test to 5000 psi. Ok.
22:30 - 23:00 0.50 WHSUR P RUNCMP P/U lubricator & pull TWC. UD same.
23:00 - 00:00 1.00 WHSUR P RUNCMP RlU Hot Oilers. Test lines to 3500 psi. Freeze protect well wI
90 bbls of diesael. Pumped 2112 BPM @ 1000 psi.
6/16/2007 00:00 - 00:30 0.50 WHSUR P RUNCMP Finish freeze protecting well. Pumped 2112 BPM @ 1000 psi.
Total volume pumped = 90 bbls.
00:30 - 01 :00 0.50 WHSUR P RUNCMP RlU lines & allow well to U-tube.
01 :00 - 02:00 1.00 WHSUR P RUNCMP P/U T-bar & install BPV. Pressure test BPV to 1000 psi.
Charted same.
02:00 - 03:00 1.00 WHSUR P RUNCMP Blow down lines. Secure tree & cellar. RELEASE RIG @
0300 hrs.
Printed: 7/10/2007 10:41:06 AM
TREE '"
\NELLHEAD '"
ACTUA TOR '"
FMC
crw
SA KER C
19-5/8" eSG, 40#, L-BO,ID '" 8.B35" I
17" CSG, 25#, L-80, II) '" 6..276" I
PERFORA 110N SUMMARY
REF LOG: GRfCCL
A NGLE AT TOP PERF: 83@ 11374'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL OpnlSqz DA IE
3-3/8" 411374 - 11394 C 11/24/00
3-3/8" 4 11522 - 11562 C 11/25/00
2-3/4" 4 11665 - 11930 C 06/01/98
2-314" 4 12200 12660 c 06101/98
2-3/4" 412:700 - 12700 C 06/01/98
2-3/4" 4 13000-13040 C 06/01198
2-3/4" 4 13210-13520 C 06/01/98
2-3/4" 4 13580 13710 e 06/01/98
10439'
"
. SAFETY NOTES' HORIZONTAL \NELL
10193' i 4-1IZ" TUBING TAL W/LEG I
10198' H E1.MDTrlOGGE006/16/98 I
11677' -l.. FISH(06!G1/9B) PERF GUNS
IPBID I
14-112" LNR, 12.5#, L-BO, 0152 bpf, II) '" 3.953" f
13768'
13850'
13862'
DA TE REV BY
PRUDHOE BAY UNIT
\NELL:'bZ-36
PERMIT No: 19B-070
API No: 50-029-22877-00
SEC 36 T11NR14E973.Z3 FEt 3473.53 FNL
COMIIJIENTS
BPExploTatìon (Ataska)
ell Job# loa DescriDtion Date Bl Color CD
L3-22 11638627 PRODUCTION PROFilE 04/14/07 1
L3-30 11637115 PRODUCTION PROFILE 03/19107 1
L4-10 11660529 MEM PROD PROFilE 04/04/07 1
L3-12 11686732 PRODUCTION PROFilE 04/08/07 1
02-29C N/A EMIT & CALIPER IMAGE 04/17/07 1
DS 02·36 11637141 MUl TI·FINGER CALlPE 03/14/07 1
F-16A N/A SCMT 02/12/07 1
X-21A 11660531 MEM CBl 04/07/07 1
F-08A 11676934 SCMT 03/20/07 1
A-30A 11628762 MEM CBl 03/13/07 1
03-36A 11637326 USIT (CORROSION) 04/12/07 1
03-36A 11637326 US IT (CEMENT) 04/12/07 1
DS 17-05 11594492 USIT 04/24/07 1
DS 03-01 11630462 USIT 03/11/07 1
Scblumberger
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
W
05/15/07
NO. 4024
/C¿~ -0'16
Company: State of Alaska
Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Prudhoe Bay
.
.
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO:
BP Exploration (Alaska) Inc. 2007
Petrotechnical Data Center LR2-1 SCANNED MAY 1 7
900 E. Benson Blvd.
Anchorage, Alaska 99508
Date Delivered:
Alaska Data & Consulting Services
2525 Gambell Street, Suite 4 0
Anchorage, AK 99503-2 38
ATTN: Beth
---
~vw J\.. {) 1001
Received by:
\~
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations pedormed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X
Pull tubing _ Alter caslng _ Repair well _ Other_
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet)
BP Exploration (Alaska), Inc. Development__X RKB 60 feet
3. Address F_xplorato~___ 7. Unit or Property name
P. O. Box 196612 Slratigraphic__
Anchorage, AK 99519-6612 se~ce__ Prudhoe Bay Unit
4. Location of well at surface 8. Well number
618' FNL, 3590' FEL, Sec. 36, T11N, R14E, UM (asp's 688432, 5950600) 02-36
At top of productive interval 9. Permit number / approval number
119' FNL, 4046' FEL, Sec. 25, T1 1 N, R14E, UM (asp's 687831, 5956369) 198-070
At effective depth 10. APl number
50-029-22877
At total depth 11. Field / Pool
3474' FNL, 973' FEL, Sec. 23, T11 N, R14E, UM (asp's 685573, 5958237) Prudhoe Bay Oil Pool
12. Present well condition summary
Total depth: measured 13862 feet Plugs (measured)
true vertical 8747 feet
Effective depth: measured 11665 feet Junk (measured) top of perf guns (fish) @ 11665' MD
true vertical 8775 feet
Casing Length Size Cemented Measured Depth True vertical Depth
Conductor 110' 20" 260 sx AS 1 10' 1 10'
Surface 3703' 9-5/8" 3215 sx PFE & 295 Sx Class G 3763' 3478'
Production 10379' 7' 19o sx Class G 10439' 8208'
Uner 12758' 4-1/2" 430 sx class G 13850' 8747'
Perforation depth: measured 11374' - 11394'; 11522' - 11562'; 11665' - 11930'; 12200' - 12660'; 12700' - 12790'.
13000'- 13040'; 13210'- 13520'; 13580'- 13710'.
true vertical 8759' - 8761'; 8773' - 8775'; 8922' - 8925'; 8931' - 8936'.
8747' - 8747'; 8748' - 8754'; 8752' - 8748'. RECEIVED
Tubing (size, grade, and measured depth) 4-1/2', 12.6#, L-80 Tbg @ 10193' MD.
Packers& SSSV (type & measured depth)7X4-1'2 BAKERSB-3 PACKER @ 101"7'MD. DEC 0 7 2000
4-1/2 CAMCO BAL-O SSSV NIP ID 3.812 @ 2083' MD. A I,,,.!.. ~.~1 o ~::
13. Stimulation or cement squeeze summary ,-u~ono ~,l ~ u~o
Intervals treated (measured) (see attached) Anchorage
Treatment description including volumes used and final pressure
14. Representative Daily Avera.qe Production or Injection Data
OiFBbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 761 21639 0 1882
Subsequent to operation 1209 12526 0 1801
15. Attachments 16. Status of well classification as:
Copies of Logs and Surveys run __
Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed ~~~~~-----~ Title: DS 2 Surveillance Engineer Date
Brian Carlson Prepared by Paul Rauf 564-5799
Form 10-404 Rev 06/15/88 ·
SUBMIT IN DUPLICATE
02-36
DESCRIPTION OF WORK COMPLETED
PERFORATING OPERATIONS
Date Event Sum mary
6/06/2000: Drifted to 11237' MD.
10/10/2000: Drifted to 11235' MD.
11/24/2000 - MIRU CTU. PT'd equip. RIH w/CT conveyed 3-3/8" perforating guns & shot 60' of add
11/25/2000: perforations listed below:
11374'- 11394' MD (Zone 1 B)
11522' - 11562' MD (Zone 1 B)
All shots @ 4 SPF, random orientation, overbalanced press. & 60° phasing. POOH w/CT
conveyed perforating guns - ASF. RD CTU.
Placed well BOL & obtained a valid well test.
RECEIVED
DEC 07 2000
Alaska Oil & Gas Cons. CornmissJor
Anchorage
Page 1
Annular Injection 2N-343
Subject: Annular Injection 2N-343
Date: Mon, 23 Oct 2000 14:23:52 -0900
From: "Brian D Noel" <BNOEL~ppco.com>
To: "blair_wondzell" <"blair_wondzell%admin. state.ak.us>" ~ppco.com>
CC: "Nabors 19E Company Man" <NABORSCM~ppco.com>,
"Randy L. Thomas" <RLTHOMAS~ppco.com>,
"Tom J Brassfield" <TBRASS~ppco.com>
Blair -
Almost 32,000 bbls have been injected into the 2N-347 annulus at Tarn. Nabors
19E is currently drilling the production interval on 2N-326 and then will be
moving to 2N-303 next.
After reaching 32,000 bbls injection on 2N-347, we plan to move our annular
injection to well 2N-343. As agreed, we are notifying AOGCC of the intent to
begin injection into the 2N-343 annulus. Our records indicate the following
information for 2N-343:
Annular injection approval by AOGCC letter dated 5/14/98
Well permit no. 98-92
API# 50-103-20260
Cumulative volume injected to date is 17,995 bbls
Thanks - Brian
1 of 1 10/25/00 11:15 AM
WELL LOG TRANSMITTAL
To:
StaJ:e_ofAlaska
Alaska Oil and Gas Conservation Comm.
Atm.: Loft Taylor
3001 Porcupine Dr.
Anchorage,. Alaska 995.01
MWD Formation Evaluation Logs · D.S. 2-36,
...~.o.vember.30, 1999
AK-MW-80210
The technic~lxtata.listed below.istzeing2xflm:tilt~.herewith~ .P_lease_~dressxny.problems..or.concems
to the attention of.'
Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518
D.S. 2-36:
2" x 5" MD Resistivity & Gamma Ray Logs:
50-029-21952-61
2"x 5" TVDJ~..,sisfixdly & GammaRay. Logs:
50'029-21952-61
1 Blueline
1 Folded Sepia
. .1]31ueline
1 Folded Sepia
5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535
A Halliburton Company
WELL LOG TRANSMITTAL
To~
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Lori Taylor
3001 Porcupine Dr. ~-. ,f~
Anchorage, Alaska 99501 i~i .-7.- ',_., .'-~t ~q'~ d:~0
MWD Formation Evaluation Logs - D.S. 2-36, AK-MW-80210
November 23, 1999
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~
Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518
1 LDWG formatted Disc with verification listing.
API#: 50-029-22877-00.
i999
5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535
A Halliburton Company
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
[] Oil [] Gas I~ Suspended [--~ Abandoned [--] Service
2. Name of Operator 7. Permit Number
ARCO Alaska Inc. 98-70
3. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22877
!4. Location of well at surface ~-'-~'~;~:':--'~'.-',~ 9. Unit or Lease Name
4659' NSL, 3591' WEL, SEC. 36, T11 N, R14E, ,,hA,_,,v, ~j ,~u,,,,~'~.~ ~ ~:~ ~!~,.~;~ : ~ Prudhoe Bay Unit
At top of productive interval .!~~_,,~_.~ !i'~ ~ 10. WellNumber
5160'At totalNSL'depth4046' WEL, SEC. 25, T11N, R14E, UMi] ~,/~jFiEi? ~i' '~j 02-36
1805' NSL, 977' WEL, SEC. 23, T11N, R14E, UM !~-'":-''''5/-~'--'--~:,-~ ..... .... --'i 11. Field and Pool
Prudhoe Bay Field / Prudhoe Bay
5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. Pool
KBE -- 59.52'I ADL 028307
12. Date Spudded4/27/98 113' Date T'D' Reached ! 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re I 16' NO' °f C°mpleti°ns5/28/98 6/4/98 N/A MSL, One
17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost
13862 8754 FTI 13768 8748 FTI [~]Yes ~No (Nipple) 2083' MD 1900' (Approx.)
22. Type Electric or Other Logs Run
MWD, RES/ALT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES, 4-Phase RES
23. CASING~ LINER AND CEMENTING RECORD
CASING SE-I-rING DEPTH HOLE
SIZE WT. PER FT. GRADE TOP BOTFOM SIZE CEMENTING RECORD AMOUNT PULLED
20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.)
9-5/8" 40# L-80 30' 3763' 12-1/4" 3215 sx PF 'E', 295 sx Class 'G'
7" 26# L-80 29' 10439' 8-1/2" 190 sx Class 'G'
4-1/2" 12.6# L-80 10192' 13850' 6" 430 sx Class 'G'
24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD
Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD)
2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10193' 10148'
MD TVD MD TVD
11665' - 13710' 8774' - 8749'
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
Freeze Protect with 75 Bbls of Diesel
(.} I i Iki/3 i
I v ~ I ',Ii TI,...
Date First Production I Method of Operation (Flowing, gas lift, etc.)
June 8, 1998I Gas Lift
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAS-OIL RATIO
TEST PERIOD
I
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR)
Press. _~4-HOUR RATE
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
i~.~,
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.
Sag River 10446' 8213'
Shublik 10501' 8251'
Sadlerochit 10573' 8301'
Kavik 11582' 8775'
31. List of Attachments
Summary of Daily Drilling Reports, Surveys
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed DanStone (L-~'~-~'--~r-'-'?' ~ Title Engineering Supervisor Date "?(~'1~*
02-36 98-70 Prepared By Name/Number: Terrie Hubble, 564-4628
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 27: 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
Performance Enquiry Report
Operator ARCO
Date 23:30, 27 Jul 98
FIT Report for 02-36
Page
The analysis is from - 00:00, 04 May 98 - to - 15:30, 18 May 98
Programs in Result Table: 02-36 Drill & Complete
Well Type
02-36 Event
02-36 Event
Time From Time To Duration Description E.M.W.(equivalent mud weight)
00:00, 04 May 98 00:00, 04 May 98 0 hr 0 min Obtained leak off 13.2
15:30, 18 May 98 15:30, 18 May 98 0 hr 0 min Obtained required level of integrity 10.0
Depth MDR
4042.0
10710.0
Hole Size MDR
8-1/2
6
Progress Report
Facility PB DS 02
Well 02-36
Rig Nabors 22E
Page 1
Date 21 July 98
Date/Time
22 Apr 98 20:00-23:00
23:00-06:00
23 Apr 98 06:00-06:15
06:15-12:00
12:00-14:00
14:00-17:00
17:00-18:00
18:00-18:15
18:15-04:30
24 Apr 98 04:30-06:00
06:00-06:15
06:15-16:00
16:00-20:30
20:30-01:30
25 Apr 98 01:30-03:00
03:00-06:00
06:00-06:30
06:30-13:00
13:00-14:00
14:00-18:00
18:00-18:15
18:15-20:00
20:00-01:00
26 Apr 98 01:00-06:00
06:00-06:15
06:15-17:30
17:30-18:30
18:30-01:00
27 Apr 98 01:00-06:00
06:00-06:15
06:15-12:30
12:30-13:00
13:00-17:00
17:00-20:00
20:00-20:30
20:30-21:30
21:30-00:00
28 Apr 98 00:00-01:00
01:00-01:30
01:30-04:00
04:00-06:00
06:00-06:15
06:15-06:30
06:30-09:30
09:30-10:00
10:00-18:00
18:00-18:15
18:15-06:00
29 Apr 98 06:00-12:00
12:00-13:00
13:00-17:30
17:30-18:00
18:00-18:30
18:30-19:00
Duration
3hr
7 hr
1/4 hr
5-3/4 hr
2hr
3hr
lhr
1/4 hr
10-1/4 hr
1-1/2 hr
1/4hr
9-3/4 hr
4-1/2 hr
5hr
1-1/2 hr
3hr
1/2 hr
6-1/2 hr
lhr
4hr
1/4 hr
1-3/4 hr
5hr
5hr
1/4 hr
11-1/4 hr
lhr
6-1/2 hr
5hr
1/4hr
6-1/4 hr
1/2 hr
4hr
3hr
1/2 hr
1 hr
2-1/2 hr
lhr
1/2 hr
2-1/2 hr
2hr
1/4 hr
1/4 hr
3hr
1/2 hr
8hr
1/4 hr
11-3/4 hr
6hr
1 hr
4-1/2 hr
1/2hr
1/2 hr
1/2 hr
Activity
Rigged down Service lines
Rig moved 30.00 %
Held safety meeting
Rig moved 40.00 %
Rigged up Service lines
Rigged down Top drive
Serviced Block line
Held safety meeting
Rigged down Top drive
Rigged down Drillfloor / Derrick
Held safety meeting
Rigged down Drillfloor / Derrick
Rigged down Drillfloor / Derrick
Removed Drillfloor / Derrick
Rig moved 75.00 %
Rigged up Drillfloor / Derrick
Held safety meeting
Rigged up Drillfloor / Derrick
Rigged up Handling equipment
Rigged up Divertor
Held safety meeting
Rig moved 90.00 %
Rig moved 100.00 %
Rigged up Lines / Cables
Held safety meeting
Rigged up Top drive
Held safety meeting
Rigged up Drillfloor / Derrick
Racked back drill pipe
Held safety meeting
Racked back drill pipe
Tested Divertor
Installed Flowline
Made up BHA no. 1
Tested Flowline
Washed to 110.0 ft
Drilled to 250.0 ft
Cleared Flowline
Pulled out of hole to 58.0 ft
Cleared Flowline
Washed to 246.0 ft
Held safety meeting
Pulled out of hole to 60.0 ft
Cleared Flowline
Washed to 250.0 ft
Drilled to 702.0 ft
Held safety meeting
Drilled to 1800.0 ft
Drilled to 2507.0 ft
Circulated at 2507.0 ft
Pulled out of hole to 191.0 ft
Pulled BHA
Made up BHA no. 2
R.I.H. to 250.0 ft
Progress Report
Facility PB DS 02
Well 02-36
Rig Nabors 22E
Page 2
Date 21 July 98
Date/Time
19:00-20:00
20:00-04:00
30 Apr 98 04:00-06:00
06:00-15:30
15:30-18:00
18:00-23:00
23:00-00:00
01 May 98 00:00-04:30
04:30-06:00
06:00-07:00
07:00-07:30
07:30-08:30
08:30-09:00
09:00-11:00
11:00-11:30
11:30-16:30
16:30-17:00
17:00-19:00
19:00-21:00
21:00-22:30
22:30-23:30
23:30-00:30
02 May 98 00:30-01:00
01:00-02:00
02:00-03:00
03:00-04:00
04:00-04:30
04:30-06:00
06:00-06:15
06:15-07:30
07:30-09:00
09:00-09:30
09:30-10:00
10:00-10:30
10:30-11:00
11:00-13:00
13:00-15:30
15:30-16:30
16:30-17:00
17:00-20:00
20:00-23:00
23:00-00:00
03 May 98 00:00-06:00
06:00-07:00
07:00-12:00
12:00-14:30
14:30-16:30
16:30-17:00
17:00-18:00
18:00-20:00
20:00-20:30
20:30-21:00
21:00-23:00
23:00-00:00
Duration
lhr
8hr
2hr
9-1/2 hr
2-1/2 hr
5hr
lhr
4-1/2 hr
1-1/2 hr
lhr
1/2 hr
1 hr
1/2hr
2hr
1/2 hr
5hr
1/2 hr
2hr
2hr
1-1/2 hr
lhr
lhr
1/2 hr
lhr
lhr
lhr
1/2 hr
1-1/2 hr
1/4 hr
1-1/4 hr
1-1/2 hr
1/2 hr
1/2 hr
1/2 hr
1/2 hr
2hr
2-1/2 hr
lhr
1/2 hr
3hr
3hr
lhr
6hr
lhr
5hr
2-1/2 hr
2hr
1/2 hr
lhr
2 hr
1/2 hr
1/2 hr
2hr
lhr
Activity
Serviced Top drive motor
R.I.H. to 2507.0 ft
Drilled to 2792.0 ft
Drilled to 3770.0 ft
Circulated at 3770.0 ft
Pulled out of hole to 191.0 ft
Serviced Top drive motor
R.I.H. to 3770.0 ft
Circulated at 3770.0 ft
Circulated at 3770.0 ft
Pulled out of hole to 3485.0 ft
Backreamed to 3295.0 ft
R.I.H. to 3770.0 ft
Circulated at 3770.0 ft
Held safety meeting
Backreamed to 1880.0 ft
R.I.H. to 3770.0 ft
Circulated at 3770.0 ft
Pulled out of hole to 200.0 ft
Pulled BHA
Rigged down Drillstring handling equipment
Rigged up Casing handling equipment
Ran Casing to 130.0 ft (9-5/8in OD)
Circulated at 130.0 ft
Rigged up Circulating head
Ran Casing to 756.0 ft (9-5/8in OD)
Rigged up Circulating head
Ran Casing to 1890.0 ft (9-5/8in OD)
Held safety meeting
Ran Casing to 3763.0 ft (9-5/8in OD)
Circulated at 3763.0 ft
Held safety meeting
Mixed and pumped slurry - 83.000 bbl
Mixed and pumped slurry - 60.000 bbl
Displaced slurry - 282.000 bbl
Circulated at 2017.0 ft
Mixed and pumped slurry - 1159.000 bbl
Displaced slurry - 153.000 bbl
Rigged down Cement head
Rigged down Casing handling equipment
Rigged down Divertor
Installed Casing head
Installed BOP stack
Installed BOP stack
Tested BOP stack
Made up BHA no. 3
R.I.H. to 2017.0 ft
Circulated at 2017.0 ft
Drilled installed equipment - DV collar
R.I.H. to 3674.0 ft
Circulated at 3674.0 ft
Tested Casing - Via string
Drilled installed equipment - Float collar
Performed formation integrity test
Progress Report
Facility PB DS 02
Well 02-36 Page 3
Rig Nabors 22E Date 21 July 98
Date/Time
04 May 98
05 May 98
06 May 98
07 May 98
08 May 98
00:00-04:30
04:30-05:00
05:00-06:00
06:00-07:30
07:30-08:00
08:00-11:00
11:00-11:30
11:30-14:30
14:30-15:00
15:00-17:30
17:30-18:00
18:00-18:30
18:30-19:30
19:30-22:30
22:30-00:30
00:30-02:00
02:00-04:00
04:00-06:00
06:00-06:30
06:30-08:30
08:30-09:30
09:30-10:30
10:30-11:30
11:30-12:30
12:30-16:30
16:30-18:00
18:00-18:15
18:15-22:30
22:30-23:30
23:30-00:00
00:00-03:30
03:30-04:00
04:00-05:00
05:00-06:00
06:00-13:00
13:00-18:00
18:00-06:00
06:00-08:00
08:00-09:00
09:00-10:00
10:00-11:00
11:00-12:00
12:00-13:00
13:00-13:30
13:30-18:00
18:00-06:00
06:00-06:30
06:30-07:00
07:00-07:30
07:30-08:30
08:30-16:30
16:30-18:00
18:00-18:15
18:15-18:30
Duration
4-1/2 hr
1/2 hr
1 hr
1-1/2 hr
1/2 hr
3 hr
1/2 hr
3 hr
1/2 hr
2-1/2 hr
1/2 hr
1/2 hr
lhr
3hr
2hr
1-1/2 hr
2hr
2hr
1/2 hr
2hr
lhr
lhr
lhr
lhr
4hr
1-1/2 hr
1/4 hr
4-1/4 hr
lhr
1/2 hr
3-1/2 hr
1/2 hr
lhr
lhr
7hr
5hr
12hr
2hr
lhr
lhr
lhr
lhr
lhr
1/2 hr
4-1/2 hr
12hr
1/2 hr
1/2hr
1/2 hr
lhr
8hr
1-1/2 hr
1/4 hr
1/4 hr
Activity
Drilled to 4042.0 ft
Circulated at 4042.0 ft
Pulled out of hole to 1500.0 ft
Pulled BHA
Serviced Top drive
Ran Drillpipe to 4038.0 ft (5in OD)
Worked toolstring at 4042.0 ft
Pulled out of hole to 0.0 ft
Rigged down sub-surface equipment - Other sub-surface equipment
R.I.H. to 3650.0 ft
Tested MWD - Via string
R.I.H. to 3959.0 ft
Reamed to 4046.0 ft
Pulled out of hole to 0.0 ft
Ran Drillpipe in stands to 4046.0 ft
Worked toolstring at 4056.0 ft
Pulled out of hole to 0.0 ft
Ran Drillpipe in stands to 3770.0 ft
Held safety meeting
Circulated at 4050.0 ft
Batch mixed slurry - 10.500 bbl
Circulated at 3760.0 ft
Pulled out of hole to 0.0 ft
Rigged up Drillfloor / Derrick
Tested BOP stack
Made up BHA no. 5
Held safety meeting
R.I.H. to 3851.0 ft
Washed to 3940.0 ft
Pulled out of hole to 3763.0 ft
Circulated at 3763.0 ft
R.I.H. to 3940.0 ft
Drilled to 3971.0 ft
Drilled to 3972.0 ft
Drilled to 4000.0 ft
Drilled to 4411.0 ft
Drilled to 5364.0 ft
Drilled to 5553.0 ft
Circulated at 5553.0 ft
Pulled out of hole to 3763.0 ft
Serviced Top drive motor
Serviced Block line
R.I.H. to 5250.0 ft
Reamed to 5553.0 ft
Drilled to 5935.0 ft
Drilled to 6602.0 ft
Held safety meeting
Circulated at 6602.0 ft
Pulled out of hole to 5350.0 ft
R.I.H. to 6602.0 fi
Drilled to 7105.0 ft
Circulated at 7105.0 ft
Held safety meeting
Drilled to 7115.0 ft
Progress Report
Facility PB DS 02
Well 02-36
Rig Nabors 22E
Page 4
Date 21 July 98
Date/Time
18:30-19:00
19:00-22:00
22:00-23:30
23:30-00:00
09 May 98 00:00-01:00
01:00-03:30
03:30-06:00
06:00-06:30
06:30-18:00
18:00-18:30
18:30-22:30
22:30-00:00
10 May 98 00:00-01:30
01:30-02:00
02:00-02:30
02:30-03:00
03:00-06:00
06:00-06:30
06:30-18:00
18:00-18:15
18:15-02:00
11 May 98 02:00-02:30
02:30-03:00
03:00-06:00
06:00-06:30
06:30-07:00
07:00-09:00
09:00-10:00
10:00-13:00
13:00-17:00
17:00-18:00
18:00-18:30
18:30-19:00
19:00-06:00
12 May 98 06:00-06:30
06:30-18:00
18:00-18:30
18:30-06:00
13 May 98 06:00-06:15
06:15-18:00
18:00-18:15
18:15-06:00
14 May 98 06:00-07:00
07:00-08:00
08:00-11:30
11:30-12:00
12:00-12:45
12:45-13:30
13:30-16:00
16:00-17:00
17:00-18:00
18:00-18:15
18:15-20:30
20:30-21:00
Duration
1/2 hr
3hr
1-1/2 hr
1/2 hr
lhr
2-1/2 hr
2-1/2 hr
1/2 hr
11-1/2 hr
1/2 hr
4hr
1-1/2 hr
1-1/2 hr
1/2 hr
1/2 hr
1/2 hr
3hr
1/2 hr
11-1/2 hr
1/4 hr
7-3/4 hr
1/2hr
1/2 hr
3hr
1/2hr
1/2 hr
2hr
lhr
3hr
4hr
lhr
1/2 hr
1/2 hr
llhr
1/2 hr
11-1/2 hr
1/2 hr
11-1/2 hr
1/4 hr
11-3/4 hr
1/4 hr
11-3/4 hr
lhr
1 hr
3-1/2 hr
1/2 hr
3/4 hr
3/4 hr
2-1/2 hr
lhr
lhr
1/4 hr
2-1/4 hr
1/2 hr
Activity
Circulated at 7115.0 ft
Pulled out of hole to 300.0 ft
Pulled BHA
Made up BHA no. 6
Serviced Top drive motor
R.I.H. to 7115.0 ft
Drilled to 7365.0 ft
Held safety meeting
Drilled to 8509.0 ft
Held safety meeting
Drilled to 8984.0 ft
Circulated at 8984.0 ft
Pulled out of hole to 7175.0 ft
R.I.H. to 7800.0 ft
Serviced Top drive motor
R.I.H. to 8984.0 ft
Drilled to 9270.0 ft
Held safety meeting
Drilled to 9937.0 ft
Held safety meeting
Drilled to 10432.0 ft
Circulated at 10432.0 ft
Drilled to 10452.0 ft
Circulated at 10452.0 ft
Held safety meeting
Circulated at 10542.0 ft
Pulled out of hole to 6800.0 ft
R.I.H. to 10452.0 ft
Circulated at 10452.0 ft
Pulled out of hole to 809.0 ft
Pulled BHA
Held safety meeting
Pulled BHA
Serviced Brake
Held safety meeting
Repaired Brake
Held safety meeting
Repaired Brake
Held safety meeting
Repaired Draw works
Held safety meeting
Repaired Draw works
Circulated at 810.0 ft
Pulled out of hole to 200.0 ft
Pulled BHA
Held safety meeting
Retrieved Wear bushing
Installed BOP test plug assembly
Tested All rams
Retrieved BOP test plug assembly
Made up BHA no. 7
Held safety meeting
R.I.H. to 3763.0 ft
Serviced Draw works
Progress Report
Facility PB DS 02
Well 02-36
Rig Nabors 22E
Page 5
Date 21 July 98
Date/Time
21:00-21:30
21:30-22:30
22:30-23:30
23:30-00:30
15 May 98 00:30-01:30
01:30-02:30
02:30-03:00
03:00-05:00
05:00-06:00
06:00-06:30
06:30-07:00
07:00-07:30
07:30-10:30
10:30-12:30
12:30-13:15
13:15-14:00
14:00-17:00
17:00-21:00
21:00-23:00
23:00-23:45
23:45-00:00
16 May 98 00:00-04:30
04:30-05:00
05:00-06:00
06:00-10:30
10:30-11:00
11:00-13:30
13:30-15:00
15:00-16:30
16:30-18:00
18:00-18:15
18:15-05:00
17 May 98 05:00-06:00
06:00-06:15
06:15-08:00
08:00-09:00
09:00-09:30
09:30-12:30
12:30-13:00
13:00-16:00
16:00-17:00
17:00-19:00
19:00-21:00
21:00-21:15
21:15-00:00
18 May 98 00:00-06:00
06:00-08:00
08:00-09:00
09:00-09:30
09:30-10:30
10:30-11:00
11:00-14:00
14:00-15:00
15:00-15:30
Duration
1/2 hr
1 hr
lhr
lhr
lhr
lhr
1/2 hr
2hr
lhr
1/2 hr
1/2 hr
1/2 hr
3hr
2hr
3/4 hr
3/4 hr
3hr
4hr
2hr
3/4 hr
1/4 hr
4-1/2 hr
1/2 hr
lhr
4-1/2 hr
1/2 hr
2-1/2 hr
1-1/2 hr
1-1/2 hr
1-1/2 hr
1/4 hr
10-3/4 hr
lhr
1/4 hr
1-3/4 hr
lhr
1/2 hr
3hr
1/2 hr
3hr
lhr
2 hr
2hr
1/4 hr
2-3/4 hr
6 hr
2 hr
lhr
1/2 hr
lhr
1/2hr
3hr
lhr
1/2 hr
Activity
Circulated at 3763.0 ft
R.I.H. to 5862.0 ft
Circulated at 5862.0 ft
R.I.H. to 8059.0 ft
Circulated at 8059.0 ft
R.I.H. to 10452.0 ft
Circulated at 10452.0 ft
Pulled out of hole to 10070.0 ft
Circulated at 10070.0 ft
Circulated at 10070.0 ft (cont...)
Pulled out of hole to 9895.0 ft
R.I.H. to 10070.0 ft
Washed to 10452.0 ft
Circulated at 10452.0 ft
Pulled out of hole to 9100.0 ft
R.I.H. to 10452.0 ft
Circulated at 10452.0 ft
Pulled out of hole to 642.0 ft
Pulled BHA
Rigged up Casing handling equipment
Held safety meeting
Ran Casing to 3700.0 fl (7in OD)
Circulated at 3700.0 ft
Ran Casing to 7in (4500.0 ft OD)
Ran Casing to 10439.0 ft (7in OD) (cont...)
Rigged up Cement head
Circulated at 10439.0 ft
Mixed and pumped slurry - 39.000 bbl
Serviced Drillfloor / Derrick
Installed Seal assembly
Held safety meeting
Laid out 5in drill pipe from derrick
Serviced Pipe ram
Held safety meeting
Serviced Top drive
Serviced Drillfloor/Derrick
Installed BOP test plug assembly
Tested BOP stack
Installed Wear bushing
Singled in drill pipe to 3720.0 ft
Racked back Drillpipe
Held drill (Stripping)
Racked back Drillpipe
Held safety meeting
Made up BHA no. 8
Singled in drill pipe to 7600.0 ft
Singled in drill pipe to 10220.0 ft
Tested Casing
Held drill (Kick (well kill))
Serviced Block line
Washed to 10354.0 ft
Drilled installed equipment - Float shoe
Circulated at 10472.0 fl
Performed formation integrity test
Progress Report
Facility PB DS 02
Well 02-36 Page 6
Rig Nabors 22E Date 21 July 98
Date/Time
19 May 98
20 May 98
21 May 98
22 May 98
23 May 98
24 May 98
15:30-17:30
17:30-19:00
19:00-21:30
21:30-04:00
04:00-05:00
05:00-06:00
06:00-06:15
06:15-11:00
11:00-13:00
13:00-14:30
14:30-21:00
21:00-21:30
21:30-06:00
06:00-06:15
06:15-18:00
18:00-18:15
18:15-21:30
21:30-22:30
22:30-06:00
06:00-06:15
06:15-08:00
08:00-09:00
09:00-10:00
10:00-14:30
14:30-15:00
15:00-02:00
02:00-03:00
03:00-06:00
06:00-06:15
06:15-09:00
09:00-10:00
10:00-11:30
11:30-20:30
20:30-22:30
22:30-02:30
02:30-04:00
04:00-06:00
06:00-06:15
06:15-08:00
08:00-09:30
09:30-11:30
11:30-12:30
12:30-13:30
13:30-16:00
16:00-17:30
17:30-21:00
21:00-02:00
02:00-02:30
02:30-03:00
03:00-04:00
04:00-06:00
06:00-06:15
06:15-08:00
Duration
2hr
1-1/2 hr
2-1/2 hr
6-1/2 hr
lhr
lhr
1/4hr
4-3/4 hr
2hr
1-1/2 hr
6-1/2 hr
1/2 hr
8-1/2 hr
1/4 hr
11-3/4 hr
1/4 hr
3-1/4 hr
lhr
7-1/2 hr
1/4 hr
1-3/4 hr
lhr
lhr
4-1/2 hr
1/2 hr
llhr
lhr
3hr
1/4-hr
2-3/4 hr
lhr
1-1/2 hr
9 hr
2hr
4hr
1-1/2 hr
2hr
1/4 hr
1-3/4 hr
1-1/2 hr
2hr
lhr
lhr
2-1/2 hr
1-1/2 hr
3-1/2 hr
5 hr
1/2 hr
1/2 hr
lhr
2hr
1/4 hr
1-3/4 hr
Activity
Circulated at 10472.0 ft
Circulated at 10472.0 ft
Serviced Top drive
Drilled to 10710.0 ft
Circulated at 10710.0 ft
Pulled out of hole to 10330.0 ft
Held safety meeting
Pulled out of hole to 196.0 ft
Pulled BHA
Made up BHA no. 9
R.I.H. to 10605.0 ft
Washed to 10710.0 ft
Drilled to 11000.0 ft
Held safety meeting
Drilled to 11202.0 ft
Held safety meeting
Drilled to 11224.0 ft
Circulated at 11224.0 ft
Pulled out of hole to 2000.0 ft
Held safety meeting
Pulled out of hole to 193.0 ft
Pulled BHA
Made up BHA no. 10
R.I.H. to 11104.0 ft
Reamed to 11224.0 ft
Drilled to 11642.0 ft
Circulated at 11642.0 ft
Pulled out of hole to 7500.0 ft
Held safety meeting
Pulled out of hole to 196.0 ft
Pulled BHA
Made up BHA no. 11
R.I.H. to 10220.0 ft
Functioned Formation logs
Logged hole with LWD: Formation evaluation (FE) from 10220.0 ft to
11632.0 ft
Rigged down Logging/braided cable equipment
Pulled out of hole to 6500.0 ft
Held safety meeting
Pulled out of hole to 131.0 ft
Pulled BHA
Made up BHA no. 12
R.I.H. to 2400.0 ft
Set Retrievable packer at 40.0 ft with 0.0 psi
Serviced Top drive
Serviced Block line
Tested BOP stack
Repaired Annular preventor
Tested Annular preventor
Installed Wear bushing
Serviced Retrievable packer
R.I.H. to 5900.0 ft
Held safety meeting
R.I.H. to 11510.0 ft
Progress Report
Facility PB DS 02
Well 02-36 Page 7
Rig Nabors 22E Date 21 July 98
Date/Time
25 May 98
26 May 98
27 May 98
28 May 98
29 May 98
30 May 98
08:00-09:00
09:00-18:00
18:00-18:15
18:15-06:00
06:00-19:30
19:30-22:30
22:30-03:30
03:30-06:00
06:00-06:15
06:15-08:30
08:30-09:30
09:30-10:00
10:00-13:30
13:30-14:00
14:00-15:00
15:00-16:00
16:00-16:30
16:30-06:00
06:00-06:30
06:30-18:00
18:00-18:30
18:30-06:00
06:00-06:30
06:30-08:30
08:30-09:00
09:00-09:30
09:30-10:30
10:30-11:00
11:00-12:00
12:00-15:00
15:00-15:30
15:30-18:00
18:00-18:30
18:30-03:00
03:00-04:30
04:30-05:30
05:30-06:00
06:00-06:30
06:30-09:00
09:00-10:00
10:00-10:30
10:30-16:00
16:00-20:30
20:30-22:00
22:00-23:00
23:00-00:30
00:30-03:00
03:00-03:30
03:30-04:30
04:30-06:00
06:00-06:30
06:30-08:30
08:30-11:00
Duration
lhr
9hr
1/4 hr
11-3/4 hr
13-1/2 hr
3hr
5hr
2-1/2 hr
114 hr
2-1/4 hr
lhr
1/2 hr
3-1/2 hr
1/2 hr
lhr
lhr
1/2 hr
13-1/2 hr
1/2 hr
11-1/2 hr
1/2 hr
11-1/2 hr
1/2 hr
2hr
1/2 hr
1/2 hr
lhr
1/2 hr
1 hr
3 hr
1/2 hr
2-1/2 hr
1/2hr
8-1/2 hr
1-1/2 hr
1 hr
1/2 hr
1/2 hr
2-1/2 hr
lhr
1/2 hr
5-1/2 hr
4-1/2 hr
1-1/2 hr
lhr
1-1/2 hr
2-1/2 hr
1/2 hr
lhr
1-1/2 hr
1/2 hr
2hr
2-1/2 hr
Activity
Reamed to 11642.0 ft
Drilled to 11989.0 ft
Held safety meeting
Drilled to 12180.0 ft
Drilled to 12666.0 ft
Circulated at 12666.0 ft
Logged hole with LWD: Formation evaluation (FIE) from 12626.0 ft to
11600.0 ft
Pulled out of hole to 4690.0 ft
Held safety meeting
Pulled out of hole to 72.0 ft
Pulled BHA
Made up BHA no. 13
R.I.H. to 10439.0 ft
Serviced Top drive
R.I.H. to 12000.0 ft
Reamed to 12270.0 ft
R.I.H. to 12666.0 ft
Drilled to 13045.0 ft
Held safety meeting
Drilled to 13428.0 ft
Held safety meeting
Drilled to 13862.0 ft
Held safety meeting
Circulated at 13855.0 ft
Circulated at 13855.0 ft
Held safety meeting
Pulled out of hole to 10439.0 ft
Serviced Top drive motor
R.I.H. to 13855.0 ft
Circulated at 13855.0 ft
Held safety meeting
Pulled out of hole to 13230.0 ft
Held safety meeting
Pulled out of hole to 200.0 ft
Pulled BHA
Installed Casing handling equipment
Ran Liner to 0.0 ft (4-1/2in OD)
Held safety meeting
Ran Liner to 3634.0 ft (4-1/2in OD)
Rigged up Tubing handling equipment
Held safety meeting
Ran Tubing to 3520.0 ft (2-7/8in OD)
Ran Liner in stands to 10423.0 ft
Circulated at 10423.0 ft
Rigged up Cement head
Ran Liner in stands to 13855.0 ft
Circulated at 13850.0 ft
Held safety meeting
Batch mixed slurry - 88.000 bbl
Displaced slurry - 127.000 bbl
Held safety meeting
Circulated at 13730.0 ft
Laid down 2100.0 ft of 4in OD drill pipe
Progress Report
Facility PB DS 02
Well 02-36 Page 8
Rig Nabors 22E Date 21 July 98
Date/Time
31 May 98
O1 Jun 98
02 Jun 98
11:00-12:00
12:00-13:00
13:00-15:00
15:00-15:30
15:30-16:30
16:30-18:00
18:00-18:30
18:30-19:30
19:30-21:00
21:00-21:30
21:30-00:00
00:00-01:00
01:00-02:00
02:00-06:00
06:00-06:30
06:30-07:30
07:30-08:30
08:30-09:30
09:30-12:00
12:00-13:00
13:00-18:00
18:00-18:30
18:30-19:00
19:00-20:00
20:00-21:30
21:30-22:00
22:00-00:30
00:30-01:30
01:30-02:00
02:00-06:00
06:00-06:30
06:30-07:00
07:00-12:00
12:00-13:30
13:30-17:00
17:00-18:00
18:00-18:30
18:30-19:00
19:00-01:00
01:00-02:00
02:00-02:30
02:30-04:00
04:00-05:30
05:30-06:00
06:00-06:30
06:30-08:30
08:30-09:00
09:00-10:00
10:00-17:00
17:00-17:30
17:30-18:00
18:00-18:30
18:30-20:30
20:30-21:30
Duration
lhr
lhr
2hr
1/2 hr
lhr
1-1/2 hr
1/2 hr
lhr
1-1/2 hr
1/2 hr
2-1/2 hr
1 hr
lhr
4hr
1/2 hr
lhr
1 hr
lhr
2-1/2 hr
lhr
5hr
1/2 hr
1/2 hr
lhr
1-1/2 hr
1/2hr
2-1/2 hr
lhr
1/2 hr
4hr
1/2 hr
1/2 hr
5hr
1-1/2 hr
3-1/2 hr
1 hr
1/2 hr
1/2hr
6hr
lhr
1/2 hr
1-1/2 hr
1-1/2 hr
1/2 hr
1/2 hr
2hr
1/2hr
lhr
7hr
1/2 hr
1/2 hr
1/2 hr
2hr
lhr
Activity
Tested Liner - Via annulus and string
Laid down 600.0 ft of 4in OD drill pipe
Pulled Drillpipe in stands to 7500.0 ft
Rigged down sub-surface equipment - Setting tools
Pulled Tubing in stands to 3500.0 ft
Laid down 1000.0 ft of Tubing
Held safety meeting
Laid down 900.0 ft of Tubing
Serviced Block line
Held safety meeting
Rigged up sub-surface equipment - Gun assembly
Ran Tubing in stands to 3665.0 ft
Rigged up sub-surface equipment - TCP
Ran Drillpipe in stands to 13730.0 ft
Held safety meeting
Set packer at 9973.0 ft with 0.0 psi
Perforated
Reverse circulated at 9981.0 ft
Bullhead well
Worked toolstring at 9984.0 ft
Pulled out of hole to 0.0 ft
Held safety meeting
Rigged up sub-surface equipment - Other sub-surface equipment
Rigged up sub-surface equipment - Drill collar
Ran Drillpipe in stands to 3000.0 ft
Serviced Top drive motor
Rigged down Top drive pipe handler
Ran Drillpipe in stands to 10003.0 ft
Functioned Other sub-surface equipment
Worked toolstring at 10003.0 ft
Held safety meeting
Worked toolstring at 9984.0 ft
Pulled out of hole to 1674.0 ft
Pulled out of hole to 0.0 ft
Tested BOP stack
Retrieved BOP test plug assembly
Held safety meeting
Installed Wear bushing
Ran Drillpipe to 5000.0 ft (3-1/8in OD)
Serviced Top drive
Serviced Iron roughneck
Ran Drillpipe to 11671.0 ft (2-7/8in OD)
Circulated at 11671.0 ft
Worked toolstring at 11678.0 ft
Held safety meeting
Worked toolstring at 11678.0 ft
Worked toolstring at 11678.0 ft
Circulated at 11678.0 ft
Laid down 9630.0 ft of 4in OD drill pipe
Rigged up Drillstring handling equipment
Laid down 240.0 ft of 2-7/8in OD drill pipe
Held safety meeting
Laid down 1140.0 ft of 2-7/8in OD drill pipe
Removed Drillstring handling equipment
Progress Report
Facility PB DS 02
Well 02-36
Rig Nabors 22E
Page 9
Date 21 July 98
Date]Time
21:30-23:00
23:00-00:00
03 Jun 98 00:00-00:30
00:30-06:00
06:00-06:30
06:30-07:30
07:30-08:30
08:30-13:30
13:30-16:00
16:00-17:00
17:00-18:00
18:00-18:30
18:30-21:30
21:30-23:30
23:30-00:30
04 Jun 98 00:30-03:00
03:00-04:00
04:00-05:30
05:30-06:00
Duration
1-1/2 hr
1 hr
1/2 hr
5-1/2 hr
1/2 hr
lhr
lhr
5hr
2-1/2 hr
1 hr
lhr
1/2 hr
3hr
2hr
lhr
2-1/2 hr
lhr
1-1/2 hr
1/2 hr
Activity
Rigged up Variable ram
Rigged up Completion string handling equipment
Held safety meeting
Ran Tubing to 6300.0 ft (4-1/2in OD)
Held safety meeting
Ran Tubing to 6600.0 ft (4-1/2in OD)
Installed SCSSSV
Ran Tubing to 10196.0 ft (4-1/2in OD)
Circulated at 10196.0 ft
Tested Tubing
Installed Hanger plug
Held safety meeting
Rigged down BOP stack
Installed Xmas tree
Tested Xmas tree
Removed Hanger plug
Tested Permanent packer
Circulated at 3600.0 ft
Installed Hanger plug
0 F! I I--I--I N 13
13-Jul-98
AOGCC
Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Re: Distribution of Survey Data for Well 2-36
Dear Lori Taylor:
Enclosed are two survey hard copies.
Tie-on Survey:
Window / Kickoff Survey:
Projected Survey:
3,882.44' MD
3,971.00' MD
1,385...5,~,,:- MD
(if applicable)
Please call me at 563-3256 if you have any questions or concerns.
Regards,
William T. Allen
Survey Manager
Attachment(s)
~or~
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
13-Jul-98
AOGCC
Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Re: Distribution of Survey Data for Well 02-36PB1
Dear Lori Taylor:
Enclosed are two survey hard copies.
Tie-on Survey:
Window / Kickoff Survey:
Projected Survey:
0.00' MD
'MD
4,042.00' MD
(if applicable)
Please call me at 563-3256 if you have any questions or concerns.
Regards,
William T. Allen
Survey Manager
Attachment(s)
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
Prudhoe Bay Unit
Alaska State Plane Zone 4
PBU EOA DS 02
02.36
SURVEY REPORT
8 July, 1998
Your Ref: A P1-500292287700
Last Survey Date 28-May-98
Job# AKMW80210
KBE - 59.52'
sp=r',r~-sun
DRILLING SERVICES
Survey Ref: svy3551
Prudhoe Bay Unit
Measured
Depth
(ft)
Incl.
3882.44
3971.00
4062.94
4158.18
4254.32
4349.36
4444.06
4539.09
4633.73
4728.39
4825.93
4921.26
5016.38
5111.22
5207.40
5301.89
5396.64
5491.69
5587.14
5682.42
5777,80
5873.16
5965.40
6061.99
6157.88
6252.71
6348.84
6443.67
6538.67
6635.50
45.920
43.870
41.6o0
43.430
44.850
46.660
46.760
46.180
45.420
45.320
45.14o
44.470
43.530
43.120
42.500
41.770
42.760
44.990
45.200
45.080
44.570
45.400
45.960
45.910
46.000
46.290
45.900
46.670
46.640
46.980
Azim.
347.060
348.280
348.450
350.690
353.060
355.500
356.430
356.070
355.600
355.530
355.450
355.510
355.640
356.140
355.190
354.470
356.160
358.720
359.550
0.030
0.600
359.740
358.260
357.520
357.960
355.480
355.670
354.210
354.620
354.430
Sub-Sea
Depth
(ft)
3501.66
3564.39
3631.92
3702.12
3771.12
3837.43
3902.37
3967.82
4033.80
4100.30
4168.99
4236.63
4305.05
4374.05
4444.61
4514.68
4584.80
4653.32
4720,70
4787.91
4855.56
4923.00
4987.45
5054.63
5121.29
5187.00
5253.66
5319.20
5384.40
5450.68
Vertical
Depth
(ft)
3561.18
3623.91
3691.44
3761.64
3830.64
3896.95
3961.89
4027.34
4093.32
4159.82
4228.51
4296.15
4364.57
4433.57
4504.13
4574.20
4644.32
4712.84
478O.22
4847,43
4915.08
4982.52
5O46.97
5114.15
5180.81
5246.52
5313.18
5378.72
5443.92
5510.20
Sperry-Sun Drilling Services
Survey Report for 02-36
Your Ref: API-500292287700
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/100ft) (ft)
1089.09 N 2.02 E 5951688.89 N 688406.82 E 381.11
1150.15 N 11.33W 5951749.59 N 688391.94 E 2.511 415.09
1211.25 N 23.92W 5951810.36 N 688377.83 E 2.472 448.36
1274.54 N 35.55W 5951873.34 N 688364.62 E 2.493 481.50
1340.81 N 44.99W 5951939.36 N 688353.52 E 2.265 513.65
1408.55 N 51.75W 5952006.90 N 688345.06 E 2.647 543.80
1477.31N 56.60W 5952075.52 N 688338.49 E 0.723 572.52
1546.06 N 61.11W 5952144.13 N 688332.27 E 0.669 600.92
1613.72 N 66.03W 5952211.66 N 688325.65 E 0.878 629.33
1680.89 N 71.24W 5952278.67 N 688318.76 E 0.118 657.82
1749.92 N 76.69W 5952347.54 N 688311.59 E 0.194 687.20
1816.89 N 81.98W 5952414.36 N 688304,62 E 0.704 715.71
1882.77 N 87.08W 5952480.09 N 688297.87 E 0.993 743.65
1947.67 N 91.74W 5952544.86 N 688291.58 E 0.564 770.84
2012.85 N 96.68W 5952609.89 N 688285.02 E 0.931 798.38
2075.98 N 102.39W 5952672.86 N 688277.73 E 0.926 825.93
2139.49 N 107.59W 5952736.21 N 688270.95 E 1.591 853.12
2205.28 N 110.50W 5952801.92 N 688266.39 E 2.998 878.99
2272.88 N 111.52W 5952869.47 N 688263.68 E 0.654 903.72
2340.42 N 111.77W 5952936.98 N 688261.74 E 0.379 927.70
2407.65 N 111.40W 5953004.20 N 688260.42 E 0.681 951.00
2475.06 N 111.20W 5953071.59 N 688258.93 E 1.079 974.52
2541.04 N 112.36W 5953137.52 N 688256.12 E 1.299 998.81
2610.40 N 114.91W 5953206.79 N 688251.83 E 0.553 1025.59
2679.27 N 117.63W 5953275.58 N 688247.39 E 0.343 1052.36
2747.53 N 121.55W 5953343.72 N 688241.77 E 1.910 1080.03
2816.58 N 126.89W 5953412.61 N 688234.70 E 0.430 1109.32
2884.85 N 132.94W 5953480.71 N 688226.94 E 1.378 1138.99
2953.61N 139.66W 5953549.28 N 688218.50 E 0.315 1169.46
3023.89 N 146.40W 5953619.36 N 688210.00 E 0.379 1200.48
Comment
Tie-in Survey
Window Point
Alaska State Plane Zone 4
PBU EOA DS 02
Continued...
8 July, 1998 - 16:22 - 2 - DrillQuest
Prudhoe Bay Unit
Measured
Depth
Incl.
6731.00
6826.05
6921.31
7017.65
7112.81
7208.39
7303.99
7398.62
7494.52
7589.69
7685.67
7782.16
7876.11
7971.72
8067.14
8162.36
8256.89
8351.57
8446.54
8543.27
8638.39
8734.32
8827.76
8923.81
9o17.12
9112.21
9208.36
9302.71
9398.59
9493.02
47.540
47.570
47.980
47.830
46.150
46.150
46.330
46.040
45.950
44.820
44.710
44.620
44.680
44.340
43.850
44.030
44.840
45.480
44.920
44.200
44.680
43.730
44.510
43.400
42.630
42.020
42.450
41.830
42.990
43.220
354.410
354.860
355.130
355.300
354.440
353.710
352.89O
351.930
351.370
352.650
351.860
350.590
350.750
350.240
349.830
349.690
351.900
353.030
352.420
351.150
354.060
353.560
355.470
355.280
354.880
354.040
355.280
354.770
356.130
356.450
Sub-Sea
Depth
(ft)
5515.49
5579.64
5643.65
5708.24
5773.15
5839.36
59O5.48
5971.00
6O37.62
6104.47
6172.61
6241.24
6308.08
6376.26
6444.79
6513.35
6580.86
6647.62
6714.54
6783.46
6851.38
6920.15
6987.23
7056.37
7124.60
7194.90
7266.O9
7336.05
7406.85
7475.79
Vertical
Depth
(ft)
5575.01
5639.16
5703.17
5767.76
5832.67
5898.88
5965.00
6030.52
6097.14
6163.99
6232.13
6300.76
6367.60
6435.78
6504.31
6572.87
6640.38
6707.14
6774.06
6842.98
6910.90
6979.67
7006.75
7115.89
7184.12
7254.42
7325.61
7395.57
7466.37
7535.31
Sperry-Sun Drilling Services
Survey Report for 02-36
Your Ref: API-500292287700
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/100ft) (ft)
3093.69 N 153.22W 5953688.98 N 688201.44 E 0.587 1231.42
3163.53 N 159.78W 5953758.62 N 688193.13 E 0.351 1262.12'
3233.80 N 165.93W 5953828.72 N 688185.22 E 0.479 1292.59
3305.04N 171.90W 5953899.79 N 688177.48 E 0.203 1323.22
3374.34 N 178.11W 5953968.91 N 688169.53 E 1.885 1353.41
3442.90 N 185.22W 5954037.27 N 688160.70 E 0.551 1384.19
3511.47 N 193.28W 5954105.62 N 688150.93 E 0.647 1415.84
3579.16 N 202.30W 5954173.06 N 688140.22 E 0.794 1448.09
3847.40 N 212.32W 5954241.03 N 688128.50 E 0.430 1481.46
3714.49 N 221.74W 5954307.86 N 688117.40 E 1.525 1513.88
3781.46 N 230.85W 5954374.58 N 688106.62 E 0.591 1545.96
3848.49 N 241.19W 5954441.33 N 688094.60 E 0.930 1579.22
3913.64 N 251.90W 5954506.20 N 688082.26 E 0.136 1612.15
3979.75 N 262.96W 5954572.01 N 688069.54 E 0.516 1645.76
4045.14 N 274.45W 5954637.09 N 688056.42 E 0.594 1679.51
4110.16 N 286.20W 5954701.80 N 688043.05 E 0.215 1713.37
4175.48 N 296.78W 5954766,84 N 688030.84 E 1.847 1746.25
4242.04 N 305.58W 5954833.15 N 688020.38 E 1.083 1777.89
4308.88 N 314.11W 5954899.76 N 688010.18 E 0.745 1809.38
4376.06 N 323.80W 5954966.67 N 687998.81 E 1.184 1842.08
4442.09 N 332.36W 5955032.46 N 687988.59 E 2.201 1873.32
4508.58 N 339.57W 5955098.76 N 687979.72 E 1.055 1903.45
4573.33 N 345.78W 5955163.33 N 687971.89 E 1.650 1932.03
4639.78 N 351.16W 5955229.62 N 687964.86 E 1.184 1960.43
4703.20 N 356.61W 5955292.88 N 687957.81E 0.875 1987.85
4766.92 N 362.79W 5955356.44N 687950.04 E 0.875 2016.00
4831.27 N 368.80W 5955420.61 N 687942.42 E 0.975 2044.30
4894.34N 374.29W 5955483.52 N 687935.36 E 0.751 2071.61
4958.79 N 379.41W 5955547.83 N 687928.62 E 1.542 2099.08
5023.18 N 383.59W 5955612.10 N 687922,84E 0.336 2125.63
Comment
Alaska State Plane Zone 4
PBU EOA DS O2
Continued...
8 July, 1998 - 16:22 - 3 - DrillQuest
Prudhoe Bay Unit
Measured
Depth
(ft)
Incl.
9588.74
9684.22
9779.64
9875.77
9970.01
10064.99
10160.07
1 O255.49
10351.64
10394.68
10454.98
1O552.4O
1 O646.63
10739.80
10836.11
10931.23
10965.04
1 O997.19
11030.81
11065.17
11096.01
11127.53
11159.67
11193.88
11225.63
11256.52
11289.09
11321.41
11350.86
11384.96
41.760
42.440
43.460
44.600
43.390
45.390
46.940
46.390
47.180
46.530
47.160
46.140
44.93O
44,960
43.910
43.340
45.530
49.58O
53.290
56.350
57.840
59.270
61.230
62.550
65.02O
69.400
74.28O
78.930
81.870
83,360
Azim.
355.680
355.550
355.660
356.140
354.830
355.490
355.660
355.680
352.210
351.970
351.590
350.590
350.690
349.210
350.080
350.420
348.280
348.590
345.910
345.510
343.610
342.660
340.600
338.200
337.81o
337.060
335.47O
333.100
330.330
324.78o
Sub-Sea
Depth
(ft)
7546.37
7617.22
7687.06
7756.17
7823.97
7891.84
7957.69
8023.17
8089.02
8118.45
8159.69
8226.57
8292.57
8358.52
8427.29
8496.14
8520.28
8541.98
8562.93
8582.73
8599.48
8615.92
8631.87
8647.99
8662.02
8673.98
8684.13
8691.62
8696.53
8700.91
Vertical
Depth
(ft)
7605.89
7676.74
7746.58
7815.69
7883.49
7951.36
8017.21
8082.69
8148.54
8177.97
8219.21
8286.09
8352.09
8418.04
8486.81
8555.66
8579.80
8601.50
8622.45
8642.25
8659.00
8675.44
8691.39
8707.51
8721.54
8733.50
8743.65
8751.14
8756.05
876O.43
Sperry-Sun Drilling Services
Survey Report for 02-36
Your Ref: API-500292287700
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/100ft) (ft)
5087.68 N 388.02W 5955676.47 N 687916.79 E 1.619 2152.46
5151.51N 392.91W 5955740.15 N 687910.30 E 0.718 2179.49
5216.33 N 397.89W 5955804.83 N 687903.70 E 1.072 2206.95
5282.97 N 402.67W 5955871.33 N 687897.26 E 1.236 2234.85
5348.23 N 407.81W 5955936.43 N 687890.48 E 1.606 2262.62
5414.43 N 413.41W 5956002.47 N 687883.23 E 2.161 2291.14
5482.81 N 418.70W 5956070.70 N 687876.23 E 1.635 2320.14
5552.01 N 423.94W 5956139.75 N 687869.26 E 0.577 2349.38
5621.67 N 431.35W 5956209.20 N 687860.11 E 2.755 2380,81
5652.78 N 435.67W 5956240.19 N 687855.01 E 1.564 2395.79
5696.31 N 441.96W 5956283.55 N 687847.63 E 1.141 2416.99
5766.30 N 452.92W 5956353.24 N 687834.92 E 1.286 2451.87
5832.65 N 463.86W 5956419.30 N 687822.32 E 1.286 2485.45
5897.45 N 475.35W 5956483.80 N 687809.22 E 1.123 2518.99
5963.78 N 487.47W 5956549.80 N 687795.44 E 1.260 2553.66
6028.46 N 498.58W 5956614.18 N 687782.71 E 0.648 2586.81
6051.71 N 502.97W 5956637.32 N 687777.75 E 7.847 2599.09
6074.95 N 507.72W 5956660.43 N 687772.41 E 12.617 2611.72
6100.58 N 513.54W 5956685.90 N 687765.96 E 12.672 2626.17
6127.79 N 520.47W 5956712.93 N 687758.35 E 8.956 2642.23
6152.75 N 527.36W 5956737.70 N 687750.83 E 7.078 2657.46
6178.48 N 535.17W 5956763.23 N 687742.38 E 5.215 2673.82
6204.96 N 543.96W 5956789.48 N 687732.92 E 8.255 2691.36
6233.20 N 554.58W 5956817.45 N 687721.60 E 7.292 2711.24
6259.60 N 565.25W 5956843.58 N 687710.28 E 7.857 2730.51
6285.90 N 576.18W 5956869.59 N 687698.69 E 14.355 2749.99
6314.21 N 588.64W 5956897.59 N 687685.53 E 15.684 2771.61
6342.53 N 602.28W 5956925.55 N 687671.18 E 16.058 2794.34
6368.09 N 616.04W 5956950.76 N 687656.79 E 13.625 2816.21
6396.62 N 634.18W 5956978.82 N 687637.94 E 16.721 2843.22
Comment
Alaska State Plane Zone 4
PBU EOA DS 02
Continued...
8 July, '1998 - 16:22 - 4 - DriilQuest
Prudhoe Bay Unit
Measured
Depth
(ft)
Incl.
11416.00
11447.17
11479.44
11511.47
11542.80
11575.83
11587.10
11634.91
11731.85
11826.96
11921.94
12Ol 7.72
12051.43
12083.14
12113.21
12148.44
12179.99
12208.40
12244.79
12277.17
12305.50
12338.56
12373.88
12402.33
12436.46
12468.21
12498.89
12548.59
12595.34
12690.40
83.950
83.880
85.070
86.520
87.970
89.480
89.780
90.12o
92.680
90.650
89.720
89.630
90.520
91.050
91.720
92.620
93.570
94.520
93.140
91.910
91.290
90.400
89.110
87.910
87.500
87.720
87.700
88.830
89.570
92.710
Azim.
323.630
323.850
321.980
320.170
318.650
318.540
319.030
319.430
320.620
321.340
321.510
319.750
319.950
319.350
316.560
313.310
309.650
306.930 '
305.960
305.460
304.650
302.970
300.520
296.700
293.820
292.550
291.420
291.230
291.690
289.490
Sub-Sea
Depth
(ft)
8704.34
8707.65
8710.76
8713.10
8714.61
8715.35
8715.42
8715.46
8713.09
8710.33
8710.02
8710.56
8710.52
8710.09
8709.36
8708.02
8706.32
8704.32
8701.89
8700.46
8699.67
8699.18
8699.33
8700.07
8701.44
8702.76
8703.99
8705.49
8706.15
8704.25
Vertical
Depth
(ft)
8763.86
8767.17
8770.28
8772.62
8774.13
8774.87
8774.94
8774.98
8772.61
8769.85
8769.54
8770.08
8770.04
8769.61
8768.88
8767.54
8765.84
8763.84
8761.41
8759.98
8759.19
8758.70
8758.85
8759.59
8760.96
8762.28
8763.51
8765.01
8765.67
8763.77
Sperry-Sun Dril#ng Services
Survey Report for 02-36
Your Ref: API-500292287700
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/100ft) (ft)
6421.64N 652.22W 5957003.39 N 687619.28 E 4.144 2868.91
6446.63 N 670.55W 5957027.91 N 687600.33 E 0.737 2894.86
6472.25 N 689.92W 5957053.04 N 687580.32 E 6.846 2922.00
6497.10 N 709.99W 5957077.38 N 687559.64 E 7.229 2949.52
6520.86 N 730.35W 5957100.63 N 687538.69 E 6.701 2976.94
6545.63 N 752.19W 5957124.84 N 687516.24 E 4.584 3006.10
6554.11N 759.61W 5957133.13 N 687508.60 E 5.098 3016.03
6590.32 N 790.83W 5957168.54 N 687476.48 E 1.098 3057.99
6664.57 N 853.09W 5957241.22 N 687412.39 E 2.912 3142.38
6738.43 N 912.94W 5957313.55 N 687350.71 E 2.265 3224.38
6812.69 N 972.16W 5957386.30 N 687289.64 E 0.995 3305.94
6886.73 N 1032.92W 5957458.80 N 687227.06 E 1.840 3388.85
6912.49 N 1054.65W 5957484.01 N 687204.68 E 2.706 3418.25
6936.66 N 1075.18W 5957507.65 N 687183.56 E 2.524 3445.97
6958.98 N 1095.31W 5957529.47 N 687162.87 E 9.539 3472.66
6983.84 N 1120.23W 5957553.70 N 687137.34 E 9.566 3504.73
7004.70 N 1143.83W 5957573.96 N 687113.23 E 11.969 3534.16
7022.26 N 1166.07W 5957590.96 N 687090.56 E 10.119 3561.16
7043.83 N 1195.27W 5957611.79 N 687060.82 E 4.632 3596.08
7062.71 N 1221.54W 5957630.01 N 687034.09 E 4.100 3627.31
7078.98 N 1244.72W 5957645.69 N 687010.51 E 3.600 3654.73
7097.37 N 1272.19W 5957663.38 N 686982.59 E 5.750 3686.91
7115.95 N 1302.22W 5957681.21 N 686952.10 E 7.839 3721.56
7129.57 N 1327.18W 5957694.20 N 686926.81 E 14.069 3749.72
7144.12 N 1358.02W 5957707.97 N 686895.61E 8.517 3783.70
7156.61 N 1387.18W 5957719.72 N 686866.15 E 4.056 3815.39
7168.08 N 1415.61W 5957730.49 N 686837.44E 3.681 3846.04
7186.15 N 1461.88W 5957747.39 N 686790.73 E 2.306 3895.71
7203.25 N 1505.39W 5957763.39 N 686746.81E 1.864 3942.45
7236.67 N 1594.34W 5957794.57 N 686657.05 E 4.033 4037.47
Comment
Alaska State Plane Zone 4
PBU EOA DS 02
Continued...
8 July, 1998 - 16:22 - 5 - DrillQuest
Sperry-Sun Drilling Services
Survey Report for 02-36
Your Ref: AP1-500292287700
Prudhoe Bay Unit
Measured Sub-Sea Vertical
Depth Incl. Azim. Depth Depth
(ft) (ft) (ft)
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/100ft) (ft)
12786.97 93.670 290.280 8698.88
12882.85 94.380 291.130 8692.15
12978.23 90.650 292.090 8687.97
13045.52 89.230 291.580 8688.04
13074.13 89.380 291.490 8688.38
13169.75 90.090 292.870 8688.83
13266.06 89.690 294.780 8689.01
13362.26 88.060 294.820 8690.90
13456.36 88.090 295.450 8694.06
13554.46 92.160 295.760 8693.85
13650.74 91.910 296.580 8690.43
13747.33 90.460 295.790 8688.43
13795.81 90.650 295.360 8687.96
13855.00 90.650 295.360 8687.29
,8758.40
8751.67
8747.49
8747.56
8747.9O
8748.35
8748.53
8750.42
8753.58
8753.37
8749.95
8747.95
8747.48
8746.81
7269.46 N 1685.01W 5957825.09 N 686565.59 E 1.287 4133.88
7303.28 N 1774.47W 5957856.65 N 686475.30 E 1.153 4229.53
7338.36 N 1863.05W 5957889.51 N 686385.88 E 4.038 4324.78
7363.39 N 1925.51W 5957912.97 N 686322.81E 2.242 4392.05
7373.89 N 1952.12W 5957922.80 N 686295.95 E 0.611 4420.66
7409.99 N 2040.66W 5957956.67 N 686206.53 E 1.623 4516.24
7448.89 N 2128.76W 5957993.35 N 686117.49 E 2.026 4612.39
7489.23 N 2216.07W 5958031.50 N 686029.20 E 1.695 4708.31
7529.18 N 2301.21W 5958069.30 N 685943.08 E 0.670 4802.06
7571.57 N 2389.65W 5958109.46 N 685853.60 E 4.161 4899.76
7614.00 N 2476.01W 5958149.72 N 685766.21 E 0.890 4995.52
7656.61 N 2562.66W 5958190.15 N 685678.51 E 1.709 5091.63
7677.54 N 2606.39W 5958209.97 N 685634.28 E 0.970 5139.92
7702.89 N 2659.88W 5958233.98 N 685580.18 E 0.000 5198.90
All data is in feet unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
The Dogleg Severity is in Degrees per 100ft.
Vertical Section is from Well and calculated along an Azimuth of 290.590° (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 13855.00ft.,
The Bottom Hole Displacement is 8149.20ft., in the Direction of 340.950° (True).
Comment
Projected Survey
Alaska State Plane Zone 4
PBU EOA DS 02
Continued...
8 July, 1998- 16:22 - 6- DrillQuest
Prudhoe Bay Unit
Sperry-Sun Drilling Services
Survey Report for 02-36
Your Ref: API-500292287700
Alaska State Plane Zone 4
PBU EOA DS 02
Comments
Measured
Depth
(ft)
3882.44
3971.00
13855.00
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
3561.18 1089.09 N 2.02 E
3623.91 1150.15 N 11.33 W
8746.81 7702.89 N 2659.88 W
Comment
Tie-in Survey
Window Point
Projected Survey
8 July, 1998 - '16:22 - 7 - DrillQuest
Prudhoe Bay Unit
Alaska State Plane Zone 4
PBU EOA DS 02
02-36PB1
SURVEY REPORT
REcE~V'ED
ORI$1N/ ,L
8 July, 1998
Your Reft API.500292287770
Last Survey Date 04-May-98
Job# AKMWS0210
KBE- 59.52'
DRILLING SERVICES
Survey Ref: svy3549
Prudhoe Bay Unit
Measured
Depth
(ft)
Incl.
0.00
110.00
196.75
249.60
330.60
466.62
557.55
649.51
737.23
833.87
927.18
1023.34
1119.66
1214.23
1308.44
1405.14
1499.70
1596.15
1692.22
1786.66
1881.87
1977.13
2071.53
2171.56
2265.19
2355.64
2451.11
2547.72
2640.96
2736.64
0.000
0,000
0.170
0.100
0.340
1.010
2.640
4.990
5.100
5.470
5.550
7.160
7.120
7.450
7.540
7.400
7.270
8.570
9.600
10,000
10.640
12.470
14.970
16.420
16.730
16.750
16.720
18.690
21.920
25.030
Azim.
0.000
0.000
13.770
18.700
73.210
72.900
72.580
72.270
71.960
71.650
71.340
62.550
50.520
32.500
24.180
18.700
9.520
9.620
9.560
11.540
8.740
8.860
6.840
7.530
7.330
7.480
8.020
8.280
8.790
3.610
Sub-Sea
Depth
(ft)
-59.52
50.48
137.23
190.08
271.08
407.09
497.97
589.72
677.10
773.33
866,21
961.78
1 O57.35
1151.17
1244.58
1340.46
1434,25
1529.78
1624.64
1717.70
1811.37
19O4.7O
1996.40
2092.70
2182.44
2269.05
236O .48
2452.51
2539.94
2627.70
Vertical
Depth
(ft)
0.00
110.00
196.75
249.60
330.60
466.61
557.49
649.24
736.62
832.85
925.73
1021.30
1116.87
1210.69
1304.10
1399.98
1493.77
1589.30
1684.16
1777.22
1870.89
1964.22
2055.92
2152.22
2241.96
2328.57
2420.00
2512.03
2599.46
2687.22
Sperry-Sun Drilling Services
Survey Report for 02-36PB1
. Your Ref: API-500292287770
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/100ft) (ft)
0.00 N
0.00 N
0.12N
0.24 N
0.38 N
0.85 N
1.71 N
3.57 N
5.93 N
8.71 N
11.56 N
15.81 N
22.37 N
31.27 N
42.06 N
53.75 N
65.42 N
78.52 N
93.48 N
109.28 N
126.06 N
144.92 N
167.10 N
193.95 N
220.43 N
246.27 N
273.50 N
3O2.59 N
334.58 N
372.44 N
0.00 E 5950600.09 N 688432.06 E 0.00
0.00'E 5950600.09 N 688432.06 E 0,000 0,00
0.03 E 5950600,22 N 688432.09 E 0.196 0,02
0.06 E 5950600.34 N 688432.12 E 0.134 0,03
0.32 E 5950600.48 N 688432.37 E 0.362 -0,16
1.85 E 5950600.99 N 688433.89 E 0.493 -1.43
4.61 E 5950601.92 N 688436.63 E 1.793 -3.72
10.44 E 5950603.92 N 688442.41E 2.556 -8.52
17.79 E 5950606.47 N 688449.69 E 0.129 -14.56
26,24 E 5950609.46 N 688458.08 E 0.384 -21.50
34.74 E 5950612.51 N 688466.50 E 0.091 -28.45
44.46 E 5950617.01 N 688476.11 E 1.952 -36.06
54.40 E 5950623.82 N 688485.88 E 1.550 -43.05
62.22 E 5950632.91 N 688493.47 E 2.431 -47.24
68.03 E 5950643.84 N 688499.02 E 1.155 -48.89
72.62 E 5950655.64 N 688503.32 E 0.751 -49.08
75.57 E 5950667.38 N 688505,97 E 1.246 -47.73
77.78 E 5950680.53 N 688507.85 E 1.348 -45.19
80.30 E 5950695.55 N 688510.00 E 1.072 -42.30
83.25 E 5950711.42 N 688512.55 E 0.554 -39.50
86.24 E 5950728.27 N 688515.12 E 0.854 -36.40
89.16 E 5950747.20 N 688517.57 E 1.921 -32.50
92.18 E 5950769.45 N 688520.03 E 2.696 -27.53
95.58 E 5950796.37 N 688522.75 E 1.461 -21.26
99.03 E 5950822.93 N 688525.54E 0.337 -15.18
102.39 E 5950848.84 N 688528.25 E 0.053 -9.24
106.09 E 5950876.16 N 688531.27 E 0.166 -3.13
110.26 E 5950905.34 N 688534.71E 2.041 3.19
115.07 E 5950937.44N 688538.72 E 3.469 9.94
119.08 E 5950975.40 N 688541.78 E 3.898 19.51
Comment
Alaska State Plane Zone 4
PBU EOA DS 02
Continued...
8 July, 1998 - 16:21 - 2 - DrillQuest
Sperry-Sun Drilling Services
Survey Report for 02-36PBI
Your Ref: AP1-500292287770
Prudhoe Bay Unit
Measured Sub-Sea Vertical
Depth Incl. Azim. Depth Depth
(ft) (ft) (ft)
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/t00ft) (ft)
2832.64 28.200 359.450 2713,53 2773.05
2928.34 31.570 356.800 2796.49 2856.01
3023.27 34.120 353.330 2876.25 2935.77
3116.84 36.460 352.430 2952.62 3012.14
3213.31 38.770 351,070 3029.03 3088.55
3307.51 41.790 349.530 3100.89 3160.41
3402.91 45.490 347.980 3169.92 3229,44
3497,73 46.940 347.700 3235.53 3295.05
3593.89 46.550 347.530 3301.42 3360.94
3687.86 45.780 347.740 3366.51 3426.03
3718.09 45.570 348.500 3387.63 3447.15
3787.97 46.360 347.660 3436.20 3495.72
3882.44 45.920 347.060 3501.66 3561.18
3970.53 43.870 348.280 3564.06 3623.58
4042.00 43.850 348.281 3615.59 3675.11
415.41N 120.14 E 5951018.37 N 688541.76 E 3.829 33.62
463.04N 118.53 E 5951065.96 N 688538.96 E' 3.781 51.89
514.31 N 114.04 E 5951117.10 N 688533.19 E 3.338 74,11
567.95 N 107.33 E 5951170.55 N 688525.14 E 2.562 99.26
626.21N 98.87 E 5951228.58 N 688515.22 E 2.544 127.67
686.22 N 88.58 E 5951288.32 N 688503.43 E 3.375 158.41
750.78 N 75.72 E 5951352.53 N 688488.96 E 4.037 193.15.
817.69 N 61.30 E 5951419.06 N 688472.87 E 1.544 230.18
886.10 N 46.28 E 5951487.07 N 688456.14 E 0.426 268.30
952.31 N 31.76 E 5951552.90 N 688439.97 E 0.835 305.18
973.47 N 27.31 E 5951573.94 N 688434.99 E 1.928 316.79
1022.62 N 16.93 E 5951622.82 N 688423.38 E 1.423 343.79
1089.09 N 2.02 E 5951688.89 N 688406.82 E 0.653 381.11
1149.82 N 11.26W 5951749.27 N 688392.01 E 2.524 414.91
1198.31 N 21.32W 5951797.49 N 688380.75 E 0.028 441.38
All data is in feet unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
The Dogleg Severity is in Degrees per 100ft.
.~/ertical Section is from Well and calculated along an Azimuth of 290.590° (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 4042.00ft.,
The Bottom Hole Displacement is 1198.50ft., in the Direction of 358.981° (True).
Comment
Projected Survey
Alaska State Plane Zone 4
PBU EOA DS 02
Continued...
8 July, 1998 - ~6:21 - 3 - DrfllQuest
Prudhoe Bay Unit
Sperry-Sun Drilling Services
Survey Report for 02-36PB1
Your Ref: API-500292287770
Alaska State Plane Zone 4
PBU EOA DS 02
Comments
Measured
Depth
(ft)
0.00
4042.00
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
0.00 0.00 N 0.00 E
3675.11 1198.31 N 21.32 W
Comment
Tie-on Survey at Surface
Projected Survey
8 July, 1998 - 16:21 - 4 - DrillQuest
-Weii-'C0mpliance Report
File on Left side of folder
198-070-0
MD 13862
TVD 08754
PRUDHOE BAY UNIT 02-36 50- 029-22877-00
/
Completion Date: ~//4/98 Completed Status: 1-OIL
ARCO
Current:
Name / Interval
D 9067 ~-11 SPERRY GR/EWR4
Sent Received T/C/D
OH 11/23/99 11/23/99
R SRVY RPT SPERRY 3882.44-13855. OH 7/13/98 7/22/98
R SRVY RPT SPERRY 0-4042. PB1 OH 7/13/98 7/22/98
Daily Well Ops
Are Dry Ditch Samples Required? yes ~(~ And Rece~'iVed? yes n~''~
Was the well cored? ye .~~.,. ' Analysis Descriptio~ Sa~'
Comments:
Tuesday, May 30, 2000 Page 1 of I
MEMORANDUM State of Alaska
TO:
/
/
David John~,
Chairman
THRU:
Alaska Oil and Gas Conservation Commission
DATE: May 23, 1998
Blair Wondzell,
P. I. Supervisor
FROM' Lou Grimaldi,(¢'~¢-"~ SUBJECT:
Petroleum Inspector
FILE NO: AEOJEWFE.DOC
BOPE Test
Nabors 22E
PBU #DS 2-36
PTD #98-70
Saturday, May 23, 1998: I witnessed the weekly BOPE test on Nabors rig #22E
which was drilling Arco well #DS 2-36 in the EOA of the Prudhoe Bay field.
The rig was not ready to test when I arrived and while waiting for them to get
ready I managed to catch a BOP test over on Doyon 9. I returned to this rig after
completing that test.
All BOPE equipment was tested and passed with the exception of the annular
preventer, which leaked, was replaced, and retested "OK".
The rig and its surrounding area was somewhat clean and provided adequate
access. Larry Wordeman (Neighbors Toolpusher) was on hand and ran a good
BOP test procedure.
SUMMARY: I witnessed the weekly test of the BOPE on Neighbors rig #22E
drilling Arco well #DS 2-36 in the WOA of the Prudhoe Bay field. There was one
failure observed. Test time 2 1/2 hours.
Attachments: AEOJEWFE.XLS
CC: (Shared Services Drilling)
NON-CONFIDENTIAL
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report
OPERATION: Drlg:
Drlg Contractor:
Operator:
Well Name:
Casing Size:
Test: Initial
X
Workover: DATE:
Nabors Rig No. 22E PTD # 98-70 Rig Ph.#
ARCO Rep.: Pete Wilson
DS 2-36 Rig Rep.: Larry Wordeman
Set @ Location: Sec. 36 T. 11N R. 14E Meridian Umiat
Weekly
X Other
5/23/98
659-4454
TEST DATA
MISC. INSPECTIONS:
Location Gen.: P
Housekeeping: P (Gen)
PTD On Location P
Standing Order Posted P
BOP STACK:
Annular Preventer
Pipe Rams
Lower Pipe Rams
Blind Rams
Choke Ln. Valves
HCR Valves
Kill Line Valves
Check Valve
Well Sign P
Drl. Rig P
Hazard Sec. P
Quan. Test Press. P/F
F
250/3000
500/5,000 P
500/5,000 P
500/5,000 P
500/5,000 P
500/5,000 P
500/5, 000 P
N/A
MUD SYSTEM: Visual Alarm
Trip Tank P P
Pit Level Indicators P P
Flow Indicator P P
Meth Gas Detector P P
H2S Gas Detector P P
FLOOR SAFETY VALVES:
Upper Kelly / IBOP
Lower Kelly / IBOP
Ball Type
Inside BOP
Test
Quan. Pressure P/F
500/5,000 P
500/5,000 P
500/5, 000
500/5,000 IPP
CHOKE MANIFOLD:
No. Valves 18
No. Flanges
Manual Chokes
Hydraulic Chokes
Test
Pressure P/F
500/5,000 P
38 500/5, 000 P
I P
Functioned
Functioned
ACCUMULATOR SYSTEM:
System Pressure
Pressure After Closure
200 psi Attained After Closure 0
System Pressure Attained 2
Blind Switch Covers: Master:
Nitgn. Btl's: Eight Bottles
1800
3,000 P
1,750 P
minutes 45 sec.
minutes 55 sec.
P Remote: P
Psig.
Number of Failures: 1 ,Test Time: 2.5 Hours. Number of valves tested 24 Repair or Replacement of Failed
Equipment will be made within N/A days. otify the Inspector and follow with Written or Faxed verification to
the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687
If your call is not returned by the inspector within 12 hours please contact the P. 1. Supervisor at 279-1433
REMARKS: Annular preventer failed, replace and retest.
Distribution:
orig-Well File
c - Oper./Rig
c - Database
c- Trip Rpt File
c ~ Inspector
STATE WITNESS REQUIRED?
YES X NO
24 HOUR NOTICE GIVEN
YES X NO
Waived By:
Witnessed By:
Louis R. Grimaldi
FI-021 L ( Rev. 12/94) Adojewfe.xls
TONY KNOWLE$, GOVERNOR
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
May 14, 1998
Mr. Mike Zanghi
Drill Site Development Supervisor
.~UR, CO Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
Re: Tarn w 2N-,~29,,.i'q-_~e.~ annular disposal requests
Dear Mr. Zanghi:
Pursuant to reviewing the additional geologic information, leak-off.test data and
cementing information presented today, the Commission is satisfied that sufficient data has
been submitted to determine that the waste will be contained in a suitable receiving zone
and the disposal will not contaminate freshwater, cause drilling waste to surface, impair
the mechanical integrity of the well used for disposal, damage a producing or potentially
producing formation or impair the recovery of oil or gas from a pool.
Therefbre, your request for annular injection into wells 2N-323, 2N-329 and 2N-343 is
approved.
David W. John~~ .
Chairman
TONY KNOWLE$, GOVERNOR
ALASI~& OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
April 16, 1998
James E. Smith
Senior Drilling Engineer
ARCO Alaska, Inc.
P O Box 196612
Anchorage, AK 99519-6612
Re~
Prudhoe Bav Unit 02-36
ARCO Alaska. Inc.
Permit No. 98-70
Sur. Loc.: 4659'NSL, 3591'WEL, Sec. 36, T11N, RI4E, UM
Btmhole Loc: 1712'NSL. 795'WEL? Sec. 23, TI IN, R14E, UM
Dear Mr. Smith:
Enclosed is thc approved application for permit to drill the above referenced well.
The permit to drill does not exempt you from obtaining additional permits required bv law from
other governmental agencies, and docs not authorize conducting drilling operations until all other
required permitting determinations are made.
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035.
Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the
surface casing shoe must be given so that a representative of thc Commission mav xvitness the
test. Notice may be given by contacting the Commission petroleum field inspector on the North
id W:~J,,,ohnston '~ ~
airman
BY ORDER OF THE COMMISSION
dlffenclosures
cc:
Department of Fish & Game. Habitat Section w/o encl.
Dcpamnent of I';nvironmental Conservation w/o encl.
STATE OF ALASKA
ALASKA C-:,: AND GAS CONSERVATION-.~OM~-.-~.$SION
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
ARCO Alaska Inc. Plan KBE = 50.02' Prudhoe Bay Field / Prudhoe
3. Address 6. Property Designation Bay Pool
P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028307
4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025)
4659' NSL, 3591' WEL, SEC. 36, T11 N, R14E, UM Prudhoe Bay Unit
At top of productive interval 8. Well Number Number U-630610
585' NSL, 4277' WEL, SEC. 24, T11N, R14E, UM 02-36
At total depth 9. Approximate spud date Amount $200,000.00
1712' NSL, 795' WEL, SEC. 23, T11N, R14E, UM 04/30/98
12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
ADL 028308, 1712'I No Close Approach 2560 13635' MD / 8700' TVD
16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)}
Kick Off Depth 300' Maximum Hole Angle 90° Maximum surface 2320 psig, At total depth (TVD) 8800' / 3200 psig
18. Casing Program Setting Depth
Size Specifications Top Bottom Quantity of Cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
30" 20" 91.5# H-40 Weld 110' Surface Surface 110' 110' 260 sx Arctic Set (Approx.)
12-1/4" 9-5/8" 40# L~80 BTC 3883' Surface Surface 3883' 3475' 1850 sx PF 'E', 210 sx Class 'G'
8-1/2" 7" 26# L-80 BTC-Mod 10424' Surface Surface 10424' 8142' 170 sx Class 'G'
6" 4-1/2" 12.6# L-80 IBT-Mod 3403' 10232' 8100' 13635' 8700' 400 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 feetORIGINAL
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented M D TVD
Structural
Conductor
Surface
Intermediate
Production
Liner
APR 05 1998
Perforation depth: measured
~lCfi0~g-8
true vertical
;201 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: Gavin Kidd, 564-5516 Prepared By Name/Number: Terrie Hubble, 564-4628
21. I hereby certif~h~t the foregoing ~rect to the best of my knowledge
Signed James E.~ ~' Title Senior Drilling Engineer Date .
U Commission Use Only
Permit Number I APl Number I App,,rovaI.Date.~ I See cover letter
9~~'- ~'~:2 50- ~ ~ ~ -. ~.. ~ ~ ~' 7 ~.z/b~. / ~ _j ~ ¢ for other requirements
Conditions of Approval: Samples Required []Yes [] No Mud Log Required []Yes ~No
Hydrogen Sulfide Measures []Yes [] No Directional Survey Required ~Yes [] No
Required Working Pressure for DOPE []2M; []3M; ~5M; [] 10M; [] 15M
Other:
by
order
of
Approved By Commissioner the commission Date~--¢'~///,~.¢¢~,-4</'~.
Form 10-401 Rev. 12-01-85 uavld W. dutl~l::,'~on
Submit In Triplicate
["Well Nh~me: 12-36
Well Plan Summary
IType of Well (producer or
injector):
IProducer
Surface Location: 4659'FSL, 3591'FEL, Sec. 36, TllN, R14E
X = 688431.72 Y = 5950600.26
Target Start: 585' FSL, 4277' FEL, Sec. 24, Ti iN, R14E
X = 687580.00 Y = 5957068.00 Z = 8,720' TVDss
Mid Point 1108' FSL, 4722' FEL, Sec. 24, TllN, R14E
X = 687122.00 Y - 5957579.00 Z = 8,710' TVDss
Target End: 1712' FSL, 795' FEL, Sec. 23, TllN, R14E
X = 685754.00 Y = 5958149.00 Z = 8,700 TVDss
[AFE Number: ] 4J0383
Estimated Start 04/30/98
Date:
I Rig: I Nabors 22E
Operating days to
complete:
26
I MD I 13,635'
ITVD: 18,700' I
I mBg: I 0.02' I
IWell Design (conventional, slim
hole, etc.)'
New Well' Horizontal USH
I Objective: [Zone lB Horizontal Bore
Formation Markers
Formation Tops MD TVD(ss)
SV3 3,873' 3,465' Marker for 9.5/8" casing seat. Set
casing 10 ft into SV3
Ugnu 6,578' 5,395'
SAG 10,414' 8,132' Marker for 7" casing seat. Set casing
10 ft into SAG
Shublick 10,470' 8,172'
TSAD 10,559' 8,236'
Zone 3 10,768' 8,385'
Zone 2 10,859' 8,450'
Zone 1 11,176' 8,655'
TD 13,635' 8,700
Casing/Tubing Program:
Hole Csg/ Wt/Ft Grade Conn Length Top Btm
Size Tbg MD/TVD MD/TVD
O.D.
12 '¼" 9.5/8" 40# L-80 BTC 3,883' 0'/0' 3,883'/
3,475'
8 Y2" 7" 26# L-80 Mod 10,424' 0'/0' 10,424'/
BTC 8,142'
6" 4 Y2" 12.6# L-80 IBT- 3,403' 10,232'/ 13,635'/
Mod 8,100' 8,700'
4 Y2" 12.6# L-80 IBT- 10,232' 0'/0' 10,232'/
Mod 8,100'
Logging Program:
Open Hole Logs: DPC Platform Express/Sonic through 6" Build PRIOR to
drilling horizontal.
Drilling section: MWD/GR 7" shoe through build in 6" hole.
MWD/GR/4 phase Resistivity in the horizontal section .
MAD pass once interval drilled to assess permeability/porosity
Mud Program:
Special design
considerations
Fresh Water spud mud for the surface hole which will
be diverter drilled. Standard fresh water LSND for
the intermediate section. Quikdrill ( 6% KCL)for the
production interval.
Mud weight in intermediate hole will be dictated by
the Put River pore pressure which can be as high as
10.3 ppg.
04/01/98 2-36 Well Permit 2
Mud Properties: [12.1/4" Surface Hole
Density PV Yield AP1 MBT pH
(PPG) Point Filtrate
8.8-9.6 15-20 50-60 8-12 25-30 8.5-9.5
Mud Properties 8 ~A" Intermediate Hole
Density PV Yield API (200 deg) pH
(PPG) Point Filtrate HTHP
9.0-10.5 10-20 10-25 8-10 8-12 8.5 - 9.5
Mud Prol>erties: 6" Hole Horizontal Leg
Density LSYP LSRV API Filtrate pH
.(PPG)
8.6- 8.8 10-18 35 -45,000 N/A 8.5- 9.0
Directional:
KOP: Grass roots well. Plan is to kick off in 12.1/4" hole @ 300 ft MD
and achieve sail angle of 44.48 degrees by 3,305 ft ,maximum
doglegs of 2.5 degrees / 100 ft. Sail angle will be maintained until
10,993 ft in 6" hole at which point the well will build @ 12
degs/100ft to horizontal.
Maximum Hole 90° in horizontal section
Angle:
Close Approach There are close approach issues with 2-36.The wells
Well: are on 30 ft centers so will need to be shut in when the
Point to point rig moves in. Other than this there are no close
separation approach issues at surface. Well 2-18A has 329 ft
separation @ 11,043 MD while 18-05 has 306 ft
separation @ 13,122 ft. Both these wells will undergo
the close approach analysis BP procedures dictate.
04/01/98 2-36 Well Permit 3
Cement Data:
Casing/Liner Lead: Tail: Comments
Sxs/Wt/Yield Sxs/Wt/Yield
9 5/8", 40 #,L-80 1850/12.0/2.17 210/15.8/1.15 Lead- Permafrost Type E
Tail Premium Cement.
Excess 500% to 1800' & 50%
from 1800' to TD. Cement to
surface
7" ,26#, L-80 N/A 170/15.8/1.15 Tail Cement- Premium
Excess 50%. TOC 1,000 ft
above SAG river or PUT
river- whichever is highest.
4 V2" , 12.6#, L-80N/A 400/15.8/1.15 Tail Cement- Premium
liner Excess 50%.
Well Control:
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.
Diverter, BOPE and drilling fluid system schematics on file with AOGCC.
NO ANNULAR INJECTION IN THIS WELL.
2-36 Class II drilling wastes will be disposed at CC-2A grind and inject facility. If Class I wastes
are generated, they will be taken to Pad 3 disposal site.
Bottom hole pressure is 3,200 psi at 8,800' TVDss (estimated).
Maximum shut-in casing pressure is 2,320 psi (assumes 0.1 psi/ft gas gradient to
surface).
Drilling Discussion
Well Objective
Well 2-36 is an 80 acre infill location to drain the Lower Romeo sands. The proposed well will target a
2,200 ft horizontal section in the deepest producible sands of the lower Romeo, beginning approximately
900 ft North of existing well 2-18A and extending to the Northwest. Initially , production will be
04/01/98 2-36 Well Permit 4
confined to the horizontar sectio-n. If Upper Romeo or Tan~-gb oil ~renses are identified, additional
perforations in the build section will be evaluated when producing GOR from the horizontal section
becomes uncompetitive. Predicted average wellbore oil production rate is 1280 BOPD. Total additional
recovery is expected to be 1.64 MMBO. The upper limit of the target is defined by standoff from gas and
reservoir quality.
Drilling Objective
Well 2-36 will be drilled as an Ultra Slim Hole horizontal producer targeting zone lB. The conductor
has been pre-installed and the 9.5/8" surface casing will be set 10 ft into the SVB3 sand at
approximately 3,883 ft MD. The well bore will then hold a tangent angle of 45 degrees to 7" casing
point which will be set in the Sag River Formation.
The build and horizontal sections will be drilled with a 6" hole for a 4.1/2" liner. The well will land
horizontal in Zone 1 at approximately 8,655 ft SSTVD, the exact depth will be determined by tagging
Kavik shale and rising back into lowest producible sand. Pipe conveyed Platform Express with sonic
logs will be run open hole through the build section and into the heel of the well after the well has been
landed horizontal and prior to drilling the horizontal section. The wet connect should be set just above
the Base of HRZ. A four-phase Resistivity tool will be run as part of the MWD package from target
interval to TD on this well in the horizontal sections due to questionable rock quality. A MAD pass of
the entire production interval will be required unless hole conditions do not allow it.
Perforating will be done with pipe conveyed guns prior to running the production tubing. Initially only
the horizontal section will be perforated. Future perforation of zone 2A and 2B oil lenses will be a
possibility. The tubing will be 12.6# L-80, BTC- Mod tubing and tailpipe. The packer and the required
"X" nipple will be set at less than 60 degrees deviation to facilitate future wireline entries into the well.
The packer will be set above the Tango lens to allow sufficient space for any future coil tubing work.
Three GLM's are planned.
DRILLING HAZARDS AND CONTINGENCIES
Always have two levels of tested isolation before NU/ND.
SURFACE CLOSE APPROACH WELL SHUT-INS
There are wells which need to be shut in during the rig move. Well spacing of the adjacent wells is
30ft. Careful coordination with any ongoing pad or facility operations or activities will be initiated prior
to commencing the rig move.
04/01/98 2-36 Well Permit 5
DRILLING CLOSE APPROACH WELL SHUT-INS
The closest actual point to point separation is 329' at 11,043', Well 2-18A and 306 ft at 13,122 ft for
well 18-05.
H_~_S, DS 2 has not had H_2S reported:
As of September 1996 Hydrogen Sulphide levels above 10 ppm have not been recorded, at
drillsite 2.
PORE PRESSURE: The well is considered to be normally pressured however on drillsite 2
there are two considerations. Water injection pressures can be expected in the UGNU and the
Put River formation can be virgin pressure, i.e. 10.3 ppg EMW. Reservoir pressure is expected
to be +/- 7.8 ppg EMW.
HOLE PROBLEMS
Shallow ice / water problems may cut mud viscosity.
Heavy Gravel concentrations in Sagavanirktok formation can lead to tight hole. Typically on the East
side of the pad. Due to Ugnu water injection mudweight must be maintained above 9.8 ppg while
drilling the intermediate interval.
Lost circulation can be an issue in the Ivishak sandstone formation Lost circulation, if it occurs, will be
handled using a comprehensive lost circulation decision tree. No other hole problems are expected in
the production zones.
Casing Shoe Kick Tolerance
The kick tolerance for the 9.5/8" surface shoe would be 25 bbls assuming a 10.3 ppg kick from the Put
River formation. This is based on a 10.0 ppg mudweight and a minimum fracture gradient at the 9 5/8"
shoe of 12.4 ppg.
The kick tolerance for 7" shoe is calculated as infinite influx assuming a swabbed gas influx at the top
of the Sadlerochit along the planned directional path. Based on 8.0 ppg EMW pore pressure and a
minimum fracture gradient of 12.0 ppg at the 7" liner shoe.
04/01/98 2-36 Well Permit 6
Well Plan Procedure
1. MIRU. NU and function test diverter. Circulate conductor clean
2. Drill 12 ¼" surface hole to 3,883' MD ( 10' into SV3)
3. Run and cement 9.5/8" casing to surface.
4. NU and test BOPE. Drill out and perform LOT.
5. Drill 8 1/=,, intermediate hole 10 ft into TSAG (10,424'MD).
6. Run and cement 7", L-80 casing.
7. Drill out and displace to 8.0 to 9.0 ppg QUIKDRILn fluid.
8. Drill 6" build and turn interval to horizontal target in Zone 1 ( maximum DLS is 12 degrees)
9. Run DPC platform express and sonic though build interval.
10. Drill 6" horizontal hole to TD of 13,635ft MD
11. Run and cement 4 V2" L-80 solid liner.
12. Perforate liner on DPC.
13. Run 4.1/2" L-80 tubing completion, test same.
14. Freeze Protect, ND BOPE, NU and test tree. RDMO.
Fault Evaluation
One small fault is observed within the target polygon, just North of the anticipated well path.
Significant 30 ft throws are observed present 500 ft North of well path and 750 ft South East of well
path. Smaller faults located 300 feet South of well path. None of these faults are considered to have an
impact on the drilling of this well..
ENDS.
04/01/98 2-36 Well Permit 7
,)S
Proposed Completion Design
',i,,, i "!,, ', 20" @ +110' . Pre- rig lnstalled I
~,ilii!i!i I ~ ii!iiiil~rI SSSV Landing Nipple @ +/- 2,200 ftI
13 GLM's Depth TBD I
9 5/8", 4O#
3,883' MD,
BTC
4 1/2",12.6 #/ft, L-80
IBT-Mod
Production Tubing
7" Production Pkr. @ -10,132' MD
4 112" TOL @ -10,232' MD
7", 26#, L-80,BTC-Mod@ 10,424' MD I
4-1/2", 12.6 #, IBT-Mod
L-80 Solid, Cemented,
Perforated Liner
@ +13,635' MD
DATE
2-4-98
3-31-98
REVISED BY
TAB
GNK
COMMENTS
DS 2-36 Proposed Completion
PRUDHOE BAY UNIT
WFII. R,qP-RR
BP Exploration (Alaska)
W
0_
~nadri[[ Scttlu~erger
Alaska District
5~11 East BOth Avenue
~nchorage, AK 99518
(907} 349-45[! Fax 344-2k60
DIRECTIO~A/~ WELL PLu~N for SRA3tED gERVICES DRILLIk~
well ......... : DS02-36 (PLO)
Field ........ : Prudhce Bay
Co~Kputahion..: Minimum Curvature
Units ........ : FEET
Surface Lat..: 70.26981945 N
Surface Lon9.: 148.47601870 W
L~gal Description
~urface ...... : 4658 FSL 3591 FEL S36 TL[N R14E I3IW
Target BAL...: 585 FSL 4277 FEL $2~ TLiN Ri~EUM
T~t Mid ~o~nt: 1~08 FSL 4722 FEb S24 TI~ RI~E UM
B}IL .......... : [7[2 FSL 795 FEL S23 TllN RI~EUM
LOCATIONS - ~J_~KA Z<)ne: 4
X-Coord Y-Coord
60&431.72 5950600.26
68758~_00 5957068.00
6871~2.D0 5957579~D0
685754,D0 5958149.00
PRD~D~ WEL/~ PROFILE
STATION bfEAStTRED INCLN DIRECTION
IDENTIFICATION DEPTH ~/4~LE AZI~3TH
VERT~C. AL-DEPT~
TVD SUB - SEA
0,00 0.00 0.00
300,00 0.00 83,93
400~00 1.00 83,93
500.00 2-00 83.93
600.00 3.00 83.93
700.00 4.00
800.00 4,05
~O0.DO 4,34
1000.00 4.83
~100,00 5.~5
[200,00 6.18
83.93
69.6B
56.57
36 8~
30 02
O.O0 -60.40
300.00 239.60
399.99 339.59
499.96 439.56
599.86 539.66
699.68 639.28
799.43 739.03
a99.~6 S30.76
998.85 938.45
~98,45 1038,05
1197.93 1137,53
(Anadri]l (c) 98 0236910 3.2b,5 3:08 PM P)
SECT I ON
DEPART
0. O0
0. O0
0.00
0.00
O.O0
O.O0
O.B7
3.48
7.83
13.92
21.75
Prepared ..... : 31 Mar 1998
Vert sect az, 353.93
K~ ~leYation.: 60.40 ft
~a~ne~ic Dcln: +28.303 (E)
Scale Factor.: 0.99994033
Convergence..: +[.43455134
: ',.-' ',~' ', - ~.-. .A ~'..~,.~ ~
~...,, ....... ,~.-:~. ,-.? .~ , ,. ,
~..k. ~. % , ~ ' ':-~/
. ,-....- ..~
, , .......
.... ':. ~,..x~ '{~ e
[::~
~ :-.:'~"i: ~4 :¢";" j
-: . . .; -.... ........ . . _ :-~<~=~c,.=j
_--_--_--_--: = _-: _-.==.~= = = = ......---= = =
COORDI14ATE~-FROM A/~ASKA Zone 4
WELLHEAD X Y
== = ..= .......
0.D0 N 0.00 E
0, DO N 0~0~ E
0,09 N 0.87 E
0.37 ~ 3.47 E
0,83 }; 7.B1 E
~O~L DL/
FACE 100
688431.72 5950600,26 B4R 0-00
688431.72 5950600.26 B4R 0-00
688~32,59 5950600.37 848 1-OO
699~35.1~ 5950600.~2 B4R 1-00
g88439~50 59506D1.29 $48 1-00
1.48
3.01
6.39
1L.42
13.88 E 688445-56 5950602.08 708 1,00
20,66 E 688452-30 S950603.85 578 1.DD
27.14 ~ 600458.69 5950607,32 ~68 1,OO
33.30 E 688~64.72 5950612.5[ 378 1.O0
39.15 E 688470,41 5950619,40 47L 1.OO
26,62 N 44.69 E 688475.73 5950627.99 40L 1.00
DS02-$6 {P/0) 31 Mar 1.998 Page 2
03
Z
<[
S TAT I
I DEN~I F I CAT/ON
mad 1/lOO CURVE
CURVE 2.5/10O
[~]DASURED 1NCLN
1300.00 6.97
1400.00 7.81
1500.00 B.GB
1600.00 9.58
1700.00 10.50
1800.00 11.43
S~O0,0D 12.37
2000.00 12.37
2180.00 14.76
2200.00 Z7_18
2300.00 19.62
2400.00 22.07
2500.00 24.53
2600.00 27,00
2700,00 29,47
2800.00 31.95
2900.00 34.43
3000.00 36.91
3100.00 39.39
3200.00 41.88
3300.00 44.37
EI~D 2.5/100 CURV~ 3304.53 44.48
T-5 3~73.28 44.48
g-5/8" CASING PT 3887.29 44.48
K-15 5499.05 44.48
UCRxr~ 6578.23 44.48
~ SAK 7643,~0 4~.48
K-10 B5B~,43 44.~8
PROPOSED WELL PROPIL4~
D1RECI'S ON VERT I CAL-DEPTHS
24.68 i297.27 1236.87
20.45 1396.44 1336.04
[7.06 L495.~1 1435.01
14.29 1594.14 1533.74
11.99 1692.61 1632.21
10.06 179~.78 1730,38
8.42 1888.64 1828.24
8-42 1986.3t 1925.91
5.26 2883,52 2023.12
2.96 2179.66 2119.26
~.21 2274.54 2214.14
359.84 2367.99 2307.59
358,74 - 2459.83 2399.43
357.~2 2549-88 2489.48
357.05 2637.9E 2577,58
356.38
355.80
355.30
354 B4
354 43
2723,95 2663.55
2~07,63 2747.23
2888.87 2B28.47
2967.50 2907.10
3043.38 2952,98
35~ 06
354.05
354.05
354.05
354.05
3116.36 3055,96
3119,60 3059.20
3525,40 3465.00
3535.4~ 3475.00
4685.~0 46~5.00
35~.05
354.05
354.05
5455.40 5395.00
6215.40 6155.00
6890,40 6830.00
(Aoadrill {0)98 0236P10 3.2b.5 3:0B PM P)
SECTION
DEPART
31.31
42.60
55.62
70.36
86_83
12%,89
145.63
[68.49
L95.57
226.B1
262.15
301.52
392.07
443.0s
497.77
556.85
617.85
682.92
751.27
754.~4
1152.94
1162.76
2292.0~
3048 , [6
3794.47
4457,31
COORDI NAT~$ - FRO~
N E LL44F~D
....... ==== ====
AhASKA Zone 4 TOOL DL/
X Y FACE 100
36.79'N
48.67
62.25
77.53
94.5~
113.17
!33.52
154.71
205.42
236.96
272.53
322.07
355,5~
402.7'7
50B.35
566.48
628.02
692.~5
760.86
764.01
1160.36
1170.12
2293,32
49.92 E 688480.70 595063F.29 35L
54.82 E 688485,30 5950650.28 31L
59.41 E 68B489.55 5950663.97 27L
63.68 E 688493,43 5950679.36 25L 1.0O
67.63 E 688496.96 5950696.42 22L 1.0O
71.25
74.55
77.69
80.~3
82.35
688500.11 5950715.17
688502.90 5950735.60
6885~5.51 5950756.86 S~L
688507.66 595~780.20 16L
68850~.90 5950807.67 L4L
83.47 E 68B509.23 5950839.22 12L 2
83.78 E 688598.64 5950B74.78 llL 2
83.27 E 688507.15 5950914.30 10L 2
81,95 ~ 688504.74 5950957.69 9I 2
79.82 E 68850[.42 5951004.87 8L 2
76.88
68-61
63.29
57.20
68B~97,21 5951055.76 8L 2
6BB492,L! 59511L0.25 7L 2
688486.12 595116~. 24 7L 2
68B~79.27 5951229.63 6L 2
688471 . 55 5951294 , 28 6L 2
50.34
50.02
8.69
7.67
109.44
..
'-~ ? ~ .~'. :. .._.
'?':"" ' ,~"'"~
.5o .~{..
.;.~-., ..._j..~=~-~
· S~ ...~.j.~ -:- ;......_~. :.
50
. . ' ,.~.. ..;
50
'.~ "~,. ,..
.50/
-,
.50 'i ~" '
,50 ,,,~ ,_.,, . .
,50 .=.
,.
.50 ........................
1.00
1.00
%:.
0.00 :
2.50
2~50 .
6824~3.00 5951362.09 6L 2-50
688462.59 5951365-24 HS 2.50
68B~11,36 5951760.40 HS O.OO
688410,10 5951770.14 H$ O,OO
688264,9[ 5952889.92 ~S O,OO
3045.37
37B7.65
4446.92
187.85
265.24
333.9~
688Z67.70 5953639.79 HS 0.00
688071.76 5~54379.86 HS 0.00
6879~6.54 5955037.16 ~$ 0.00
D~02-36 (P10) .%1 rziar 1995 Page 3
~TATION
I DENZrlF I CAT IOl~
K-5
LCU
JARAS ~I C A
SAG
7" CASIlqG PT
PROPOSED ~]~LL PROFILE
MEASURED
......
9409.33 44.48
10285,29 44.48
10348,36 44,48
10414.23 44.48
10428.24 44.48
DI RECTI OIT VERTICAL - DE PTHS
AZIMUT~ TVD SUB-SEA
......... ====~=~ == ......
354.05 7475,4O 7415.D0
354 .05 8100.40 8040.00
354.05 8145.40 8085.00
354.05 8192.40 8132 .00
354.05 8202.40 8142.00
SECTION
DEPART
5031.77
5645.51
5689.70
5735.85
5745.67
====
COORDIMATES-i~RC{4 ALAS¥~ Zone 4 TOOL DL/
~'IE~D X Y FACE l O0
5018.28 N 393.55 W 687912.68 5955606.82 H$ 0.00
5628.71 N 457.20 ~g 687833.78 5956215,43 KS O.00
5672.66 N 461.78 W 687828.10 5956259,25 HS 0.00
5718-57 N 466.57 W 687822.1f 5956305.01 MR O.OO
5728.33 N 467.59 W 687820.90 5956314,'75 }tS 0-00
n~
Z
9HUBLI
TSAD
ZONE
ZO]~E
ROMEO
ZON~ 1
BSAD
END 12/~00 CURVE
TARGET BSL
CURVE 8/100
TARG]DT ~ID POINT
10~70.29 44.48
10559.99 44.48
10768.82 44.48
18859.92 44.48
10992.50 44,45
llOD0.00 45.14
11055.02 50.1~
]1100.00 54.42
11176,85 62.0[
11200.00 64.35
11300.00 74.63
11400.00 85.09
11454.60 90.B3
11454.60 90.83
~1454,6~ 90.83
12140.93 90.83
12140.93 90-83
12200.00 90.76
1230~.00 90.63
~2400.00 90.48
12500.00 90-32
END 8/100 CURVID 52503.21 ~0.32
¢-1/2" LINER PT 13635.59 90.32
(Anadrill (c}98 0236P10 3.2b.5 3:08 PM P)
354,05 8232~40 8172.00 5775.13
354.05 8296,40 8236.00 S837.98
354.05 8445.40 8355.00 598~.29
354.05 a5~0.40 8450.00 6048.12
354.05 8605.00 8544.60 6141.02
353.tB 861D.32 8549.92 6146.30
347,33 8647.40 8587.00 6186.82
343,17 8674.92 8614.52 622[.96
337.00 8715,40 8655.00 62S5.~6
335.32 $725.85 8665.45 6304.93
328.7l 8760-87 B700.4~ 6391.56
322,73 877S.46 8718.06 647g.12
319,57 8780.40 8720.00 6523.97
319,57 8780.40 8720.00 6523.97
319.57 8780.40 8720.00 6523.97
319.57 8770.¢0 8710,00 7090.43
319,57 8770.40 8710.00 7090.43
314.84 8769.58 8709.18 7L37.75
306,84 8768.36 8707.96 7210.71
298.84 8767.40 8707.00 7273.47
290.8.4 8766.69 8706.29 7324,79
290,59 8766.68 8706.28 7326~24
290.59 8760.40 8700.00 783~.20
5757.64 N 470.64 W 687817,11 5956343.96 85 0.00
5820.14 N 477.16 N 687B09.03 5956406.29 MS' 0.00
5965.67 N 492.33 W 687790.22 5956551.38 ES O.OO
6029.16 N 498,95 W 687782.02 5956614.67 HS 0.00
612~.55 N 508.59 ~ 687770.07 5956706,79 43L D.O0
6126.80 N 509.17 W 687769,35 5956712.03 43L 12.00
6166.81 ~ 516.13 W 687761.40 595~751.85 .39L 12.D0
620L.18 ~ ~25.22 W 687751.45 5956785.98 3~L 12,00
6262.46 N 547,56 W 687727.58 5956546.67 33L 12,OO
6281,36 N 555,92 W 6877[8.76 5956865.36 32L 12.~0
6363-81 N 599.94 ~ 68767~.69 5956946.6~ 30L 12.00
6444.95 N 655.35 W 687615.27 5957026.40 29L 12.00
6487.42 N 6~9.57 W 687580,00 5957068.~0 }LS 12.DO
6457[42 ~ 689.57 W 687580.00 5957068.00 ~S 12.00
6487,42 N 689.57 N 687580.00 5957068.00 BS 12,00
7009.76 N 1134.65 W 687122.00 5957579.00 91L 0.00
7009.76 N %t34.65 W 687122,0D 5957579.00 91L 0.00
7053-09 N 1174.77 W 687080,81 5957621.31 91L 8.00
7118-43 N 1250.36 W 687003.62 5957684.73 9iL 8.00
7172.6L ~ 1334,30 W 686918.35 5957736.79 91L 8.00
7224.59 N 1424,98
7215.72 N 1427.98
7613.87 N 2488.04
686826.66 5957776.48 ElL
686823.~3 5957777.54 HS
685754,00 5958149.00 D.00
DSO2-36 (P10) 3~ Mar 1998 Page 4
Ld
~_-==_-_-:=_- ............
STATION
IDENT IFr CAT I ON
TARGET ESL / ~D
~]EASURED fNCLN
DEPTH A..WGLE
13635 .59 90.3~
PROPOSED ~ELL PROFfLE.
DIRECTION VERTICAL-DEPT~S
AZIMUTH ~UD SUB -SEA
290.59 8760.40 87DD.00
SECTfON COORDfNATES-FROM
DEPART W~LLKEAD
.........
7834.20 7613.$7 ~ 2~E8.04 W
A/~SKA Zone 4 TOOL, DL/
X Y FACE 10O
685754.00 5958149.00
FF
Z
(Anadrill (0)98 e256P1D 3.2b.5 3:98 P~! P)
J
d
z
SHARED SERV_TCES DRZLLZN6
iiii ! ,lllll III --1 '11 ' ' ' ' Il II 111111 ' 11 .....
0S02-36 (PLO)
VERTICAL SECTION VIEW
i '*" ..... "'"">; i ' ~
-'~'-:"-." ..... '...'~'., ,-.~ /~.....::,..i1:.¢.~¢ ~ ,Sect iun al' 353 93
!'-....:'~,: ~'r~'..$ Di ¢~,..t.-,, TVD Scale. ] :i ch = ]500 teet
8-- i , ~ - ...... ; ~'-~-'~i*~ Iu'nep
Scale.:
~nch
]500
~eet
,~ ?.~?''c~.~ /~-: ~'.~ ;".'.~ :?~"~¥/Y2~ ~l~% ~
-- ' .-- " .... ' '- .... ~"', ~.,~% Igra~n ..... : 3~ Nar i998
[
..... ~ '~ -- ~rker Identi*icabion ~D 8KB SECTN INEL
~" ..... ~ .............. = ........ = ..... ~ ..... A] K~ 0 0 O 0.(
~ ~l KOP / 8UZLD l/~O0 300 aO0 0
E) CURVE ~/~00 700 700 0 4.(
'- D] END i/lO0 CURVE 1900 ~S89
[) CURVE ~.5/tOD 2000 ~986
[ Fl END 2.5/~00 CURVE 3~5 3~26 754 44.,
6) 9-5/B" CASZ~ P~ 3887 3535 ~tE3 44.,
, , ~~'. '~ ......
Z) CURVE ~Z/tO0 ~0993 8605 6t4'~ 44.48
I ~ [f'~ ~ J) END 12/~00 CURVE 11455 87B0 6524 9D,63
~ ~ ' ' K) TAROT BSL t1455 87B0 6~4 ~,B3
L) CURVE 8/100 t2~41 877D 7090 ~,63
M) TARGET MZD POINT 12~41 8779 7090 90,83
.... ~ ........ , N~ ENB 8/~00 CUR~E 125e3 8767 7326 90,32
~ % ...... O~ 4-1/2" L]NER PT , 13636 8750 7B34
'K:,~-~ ~ [ ............ P} T~GET E~ / lO 13636 8750 7834 90.32
..... ! I ~ ~ ~ I
-~ - ~,~ .......... i ......~-- .................
; ~ ......
..... ,
.
- ~~ ......
/
..... I_ ~ __ .
~ .... ~ ............... =:~ ..... 4 .............. ~_~
:::::::::::::::::::::::::::::::::::::::::::::::::::::: ,,, ~ ,';,-i ; ..... r .......
,.:::: :::::..:::::::::::::::::::::::::::::::::: :::::: l
0 750 ]500 22~ 3000 3750 4500 5250 6000 67~ 7500 8250 9000 9750 10500 t 1~0 12000 12750
Section 9epanture
$ RED Si:RVICE S DRILLTNG
Marker
,1 o o, DS02-36 (P O
~oo ~ ~ PLAN VIE~
D) ENO ~/lO0 CURVE 1900 ~34 N 75 E~ .....
E) CURVE ~.~/~00 ~000
F) END 2.6/~D0 CURVE ]30~ 764 N 50 E '
6) 9-~/8" CASING PT ?B~7 ~]70 N B E DECLINATION,' +28,303 (E}
I-I) 7" CASING Pf ]0428 5728 N 468 W SCALE ' ~ inch = ~500 feet
l) CURVE ~2/i00 ]0993
J) END ~2/~00 CURVE 1~455 6487 N 690 N DRAWN ' 3~ Mar ~998
K) TARGET BSL 11455 8487 N 690
~) CURVE 8/100 ~2141 7010 N ll35 W
M) TARGET 14ZO POINT ~2i4] 7010 N ]i35 N ...
N) END 8/100 CURVE i2503 7216, ~4~8 ~ /nadrJ]] S¢hJu~berger
O) 4-~/2" LZNER PT ~3636 ?~4 N 2488 H ....
9750--- ~. . ........
--
¢ ....... .~..~ ~..- _..~._. p ..... ..%......, ........
9000- -- . . , ,', ~,,, , ,,~ .... ,. ,.
. ~' ........
8250-- .-.. ~ , ¢ ~"~-~"
.,. ~.~.
¢ .,¢" ..L F- ~% ~ ,~. .~ , .
: .... . ..... . ........ . . _ ......'~-'~.~ ~"~,~-~ .....
...... .~ ... ..... ... .....
6750 .....
~~~ eS. [Po~nL] ........
6000-~ ' -
IH "'
5250-- - .............
4500
3750 ........
3000---
,,,.,
2250 ...........
~500= ,. ~ ..
.
i
750- ..
,~,
750 -, -
5250 4500 3750 3000 2250 ~500 750 0 750 1500 2250 3000 3750 4500 5250
<- NEST' EAST ->
~0 BDVd 3dG ]]I~N9 09~-~£-106 60'9I 866~/[$/£0
I I° ~==1
VENDOR ALASI4,AST 14 0(:
DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET
0218c~8 CK0218c~8~ 100. O0 100. O0
HANDLING INST' s/h terrie hubbl.~ x 4~28
THE A'~I'ACHED CHECK I$ IN PAYMENT FO" r~EM$ DESC.IBED ABOVE. ll~l]ll~illl ~ 1 OO. OO :1_ OO. OO
· WELL PERMIT CHECKLIST COMPANY /,,"',,,'"~<~:~ WELL NAME /¢2t~/___./ ~--__~ ~ PROGRAM: exp [] dev-~edrll [] serv [] wellbore seg I': ann. disposal para req Ii
FIELD & POOL ~ 4'/O~,.¢",~ INIT CLASS .__,~_,~.,,ZP" /..,,'~/// GEOL AREA ~ ~ UNIT# /,/~',_¢'<:2 ON/OFF SHORE ,~1 ,,,,,,a
ADMINISTRATION
ENGINEERING
GEOLOGY
1. Permit fee attached ...................
2. Lease number appropriate ..................
3. Unique well name and number. .................
4. Well located in a defined pool ..................
5. Well located proper distance from drilling unit boundary ....
6. Well located proper distance from other wells ..........
7. Sufficient acreage available in drilling unit ...........
8. If deviated, is wellbore plat included ............
9. Operator only affected party ..................
10. Operator has appropriate bond in force ............
11. Permit can be issued without conservation order .......
12. Permit can be issued without administrative approval
13. Can permit be approved before 15-day wait ...........
N
N
N
N
N
N
N
N
N
N
N
N
N
14. Conductor string provided ................... f,,.~ NN
15. Surface casing protects all known USDWs ...........
16. CMT vol adequate to circulate on conductor & sud csg ..... N
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...
22 Adequate wellbore separation proposed ............. N
23. If diverter required, does it meet regulations ..........
24. Drilling fluid program schematic & equip list adequate .... ~ N
25. DOPEs, do they meet regulation ...... ..: .~?.,,) ..... ~ N
26. DOPE press rating appropriate; test to -;~ psig. N
27. Choke manifold complies w/APl RP-53 (May 84) ........ .,~ N
28. Work will occur without operation shutdown ........... ~ N
29. Is presence of H:S gas probable ................. ~ N
30. Permit can be issued w/o hydrogen sulfide measures ..... Y ~"/~/~Y '
31. Data presented on potential overpressure zones .......
32. Seismic analysis of shallow gas zones .............
33. Seabed condition survey (if off-shore) ............ .// Y N
34. Contact name/phone for weekly progress reports ..... ~,. Y N
[exploratory only] '~'
REMARKS
G E_.O,~/_GY:
ENGINEERING: COMMISSION'
B EvC W DW¢
JDFt ~' ~ RNC
co
Comments/Instructions:
tl('iW/IF A ~,t ()l;~Mf;~, I~, I,h,t f,., iFU',
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
Mon Nov 22 10:08:23 1999
Reel Header
Service name ............. LISTPE
Date ..................... 99/11/22
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 ..................... 99/11/22
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
PRUDHOE BAY
MWD/MAD LOGS
#
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 7
AK-MW-80210
S. LAITILA
P. WILSON
RECEIVED
,-, , 25 1999
D. S. 2-36
500292287700
ARCO ALASKA, INC.
SPERRY-SUN DRILLING SERVICES
19-NOV- 99
MWD RUN 8
AK-MW-80210
S. LAITILA
P. WILSON
MWD RUN 9
AK-MW-80210
S. LAITILA
P. WILSON
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 10
AK-MW-80210
S. LAITILA
P. WILSON
MWD RUN 10
AK-MW-80210
S. LAITILA
P. WILSON
MWD RUN 11
AK-MW-80210
S. LAITILA
P. WILSON
JOB NUMBER:
LOGGING ENGINEER:
MWD RUN 11
AK-MW-80210
S. LAITILA
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
P. WILSON
36
llN
14E
4659
3591
59.50
59.50
30.90
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
1ST STRING
2ND STRING 12.250 9.625 3763.0
3RD STRING 8.500 7.000 10439.0
PRODUCTION STRING 6.000 13855.0
REMARKS:
1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
2. MWD RUNS 1 THROUGH 6 ARE DIRECTIONAL ONLY AND ARE
NOT PRESENTED.
3. MWD RUNS 7 THROUGH 9 ARE DIRECTIONAL WITH NATURAL
GAMMA PROBE (NGP)
UTILIZING A SCINTILLATION DETECTOR.
4. MWD RUNS 10 AND 11 ARE DIRECTIONAL WITH DUAL GAMMA
RAY (DGR) UTILIZING
GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE
RESISTIVITY PHASE-4
(EWR4). THE CHANGE FROM NGP TO DGR DETECTORS OCCURS AT
11586'MD, 8772'TVD.
5. MEASUREMENT AFTER DRILLING (MAD) DATA WAS ACQUIRED
ON PASSES WHILE PULLING
OUT OF THE HOLE FOLLOWING MWD RUNS 10 AND 11, AND IS
PRESENTED AS A TAIL TO
THIS LOG.
6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS
PER THE E-MAIL MESSAGE
FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 10/26/99. A PDC
LOG MAY BE PENDING
7. MWD RUNS 7-11 REPRESENT WELL 2-36 WITH API#:
50-029-22877-00.
THIS WELL REACHED A TOTAL DEPTH (TD) OF 13855'MD,
8746'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRD = SMOOTHED GAMMA RAY.
SGRC = SMOOTHED GAMMA RAY COMBINED.
SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA
SHALLOW SPACING).
SESP = SMOOTHED PHASE 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.
SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING.
CURVE WITH THE EXTENSION "M" DENOTES MEASUREMENT AFTER
DRILLING (MAD) PASS.
$
File Header
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
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.
.5000
DEPTH INCREMENT:
FILE SUMMARY
PBU TOOL CODE
GR
ROP
FET
RPD
RPM
RPS
RPX
$
START DEPTH
10204.5
10453 0
11564 0
11564 0
11564 0
11564 0
11564 0
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
$
#
MERGED DATA SOURCE
PBU TOOL CODE
MWD
MWD
MWD
MWD
MWD
$
#
REMARKS:
BIT RUN NO MERGE TOP MERGE BASE
7 10453.0 10708.0
8 10708.0 11221.0
9 11221.0 11640.0
10 11640.0 12666.0
11 12666.0 13855.0
STOP DEPTH
10654.0
13855.0
13813.5
13813.5
13813.5
13813.5
13813.5
EQUIVALENT UNSHIFTED DEPTH
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
DEPT
ROP
GR
RPS
RPD
RPX
RPM
FET
Name Service Order Units Size Nsam Rep
FT 4 1 68
MWD FT/H 4 1 68
MWD API 4 1 68
MWD OHMM 4 1 68
MWD OHMM 4 1 68
MWD OHMM 4 1 68
MWD OHMM 4 1 68
MWD HOUR 4 1 68
Code Offset Channel
0 1
4 2
8 3
12 4
16 5
20 6
24 7
28 8
Name
DEPT
ROP
GR
RPS
RPD
RPX
RPM
FET
Min
10204.5
5 9326
15 8465
8 5655
15 0734
4 7143
10 5066
0 4036
Max Mean Nsam
13855 12029.8 7302
4703.91 96.9549 6805
667.43 67.0539 7205
2000 68.7814 4500
2000 175.739 4500
172.947 54.2269 4500
2000 115.603 4500
57.6511 3.60335 4500
First
Reading
10204.5
10453
10204.5
11564
11564
11564
11564
11564
Last
Reading
13855
13855
13806.5
13813.5
13813.5
13813.5
13813.5
13813.5
First Reading For Entire File .......... 10204.5
Last Reading For Entire File ........... [3855
File Trailer
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
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 ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER: 2
EDITED MERGED MAD
Depth shifted and clipped curves; all MAD runs merged using earliest
passes.
DEPTH INCREMENT:
FILE SUMMARY
PBU TOOL CODE
RAT
GR
RPD
RPM
RPS
RPX
FET
$
#
MERGED DATA SOURCE
PBU TOOL CODE
MWD
MWD
$
REMARKS:
.5000
START DEPTH
11534 0
11541 5
11541 5
11541 5
11541 5
11542 5
STOP DEPTH
13805.5
13812.5
13812.5
13812.5
13812.5
13812.5
MAD RUN NO. MAD PASS NO. MERGE TOP
10 11640.0
11 12666.0
MERGED MAD 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
MERGE BASE
12666.0
13855.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
RAT MAD FT/H 4 1 68 4 2
GR MAD API 4 1 68 8 3
RPX MAD OHM- 4 1 68 12 4
RPS MAD OHM- 4 1 68 16 5
RPM MAD OHM- 4 1 68 20 6
RPD MAD OHM- 4 1 68 24 7
FET MAD HOUR 4 1 68 28 8
First
Name Min Max Mean Nsam Reading
Last
Reading
DEPT 11534 13852 12693 4637
RAT 57.2854 447.557 238.407 4539
GR 15.0235 204.39 77.2994 4544
RPX 4.9801 106.717 30.9625 4543
RPS 9.2126 138.706 42.7665 4543
RPM 10.5804 2000 62.7672 4543
RPD 15.3959 2000 97.2813 4543
FET 4.3241 100.256 30.8844 4541
11534 13852
11583 13852
11534 13805.5
11541.5 13812.5
11541.5 13812.5
11541.5 13812.5
11541.5 13812.5
11542.5 13812.5
First Reading For Entire File .......... 11534
Last Reading For Entire File ........... 13852
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
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 ....... 99/11/22
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: 7
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
GR 10204.5 10654.0
ROP 10453.0 10708.5
$
LOG HEADER DATA
DATE LOGGED: 19-MAY-98
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
ISC 5.07, ISC 5.07
3.01E, 2.22A, 7.53
MEMORY
10708.0
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (R?M):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
NGP NATURAL GAMMA PROBE
$
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
10453.0
10708.0
44.9
47.2
TOOL NUMBER
PCG 7
6.000
6.0
LSND
8.70
64.0
8.5
22000
8.0
.000
.000
.000
.000
41.1
.6
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 7 API 4 1 68 4 2
ROP MWD 7 FT/H 4 1 68 8 3
Name Min Max Mean Nsam
DEPT 10204.5 10708.5 10456.5 1009
GR 22.1241 667.43 77.554 900
ROP 7.0447 287.824 79.1978 512
First Last
Reading Reading
10204.5 10708.5
10204.5 10654
10453 10708.5
First Reading For Entire File .......... 10204.5
Last Reading'For Entire File ........... 10708.5
File Trailer
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.004
Physical EOF
File Header
Service name ............. STSLIB.004
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.003
Comment Record
FILE HEADER
FILE NUMBER: 4
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 8
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
GR 10654.5 11165.0
ROP 10709.0 11219.5
$
#
LOG HEADER DATA
DATE LOGGED: 20-MAY-98
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT):
ISC 5.07, ISC 5.07
3.01E, 2.22A, 7.53
MEMORY
11221.0
10708.0
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
NGP NATURAL GAMMA PROBE
$
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
11221.0
43.3
61.8
TOOL NUMBER
PCG 11
6.000
6.0
QUIK DRILN FLUI
8.70
65.0
8.6
22000
8.0
.000
.000
.000
.000
44.6
.6
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 8 API 4 1 68 4 2
ROP MWD 8 FT/H 4 1 68 8 3
Name Min Max Mean Nsam
DEPT 10654.5 11219.5 10937 1131
GR 15.8465 102.759 26.1449 1022
ROP 9.5084 2253.52 79.8916 1022
First Last
Reading Reading
10654.5 11219.5
10654.5 11165
10709 11219.5
First Reading For Entire File .......... 10654.5
Last Reading For Entire File ........... 11219.5
File Trailer
Service name ............. STSLIB.004
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.005
Physical EOF
File Header
Service name ............. STSLIB.005
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.004
Comment Record
FILE HEADER
FILE NUMBER: 5
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 9
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
GR 11165.5 11586.0
ROP 11220.0 11640.5
$
LOG HEADER DATA
DATE LOGGED: 22-MAY-98
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
ISC 5.07, ISC 5.07
3.01E, 2.22A, 7.53
MEMORY
11640.0
11221.0
11640.0
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
NGP NATURAL GAMMA PROBE
$
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
62.5
89.5
TOOL NUMBER
PCG 7
6.000
6.0
QUIK DRILN
8.70
63.0
8.6
20000
8.2
.000
.000
.000
.000
46.7
.6
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 9 API 4 1 68 4 2
ROP MWD 9 FT/H 4 1 68 8 3
Name Min Max Mean Nsam
DEPT 11165.5 11640.5 11403 951
GR 18.4659 113.334 43.757 842
ROP 12.3521 1626.05 89.9894 842
First
Reading
11165.5
11165.5
11220
Last
Reading
11640.5
11586
11640.5
First Reading For Entire File .......... 11165.5
Last Reading For Entire File ........... 11640.5
File Trailer
Service name ............. STSLIB.005
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.006
Physical EOF
File Header
Service name ............. STSLIB.006
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.005
Comment Record
FILE HEADER
FILE NUMBER: 6
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 10
DEPTH INCREMENT: .5000
#
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
FET
RPD
RPM
RPS
RPX
GR
ROP
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
11564 0
11564 0
11564 0
11564 0
11564 0
11586 5
11641.0
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
STOP DEPTH
12624.5
12624 5
12624 5
12624 5
12624 5
12 617 5
12666 0
25-MAY-98
ISC 5.07, ISC 5.07
3.01E, 2.22A, 7.53
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (R?M):
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
12666.0
11640.0
12666.0
87.5
94.5
TOOL NUMBER
P1006SP4
P1006SP4
6.000
6.0
QUIK DRILN
8.70
63.0
8.7
19000
7.2
.280
.143
3.000
.540
56.1
.6
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 10
RPX MWD 10
RPS MWD 10
RPM MWD 10
RPD MWD 10
ROP MWD 10
FET MWD 10
API 4 1 68
OHMM 4 1 68
OHMM 4 1 68
OHMM 4 1 68
OHMM 4 1 68
FT/H 4 1 68
HOUR 4 1 68
4
8
12
16
20
24
28
Name
DEPT
GR
RPX
RPS
RPM
RPD
ROP
FET
Min
11564
30 3991
4 7143
8 5655
10 5066
15 0734
5 9326
0 5234
Max Mean Nsam
12666 12115 2205
163.787 75.0956 2063
172.568 59.5453 2122
2000 81.0909 2122
2000 144.85 2122
2000 227.407 2122
1818.23 78.9865 2051
57.6511 5.38475 2122
First
Reading
11564
11586.5
11564
11564
11564
11564
11641
11564
Last
Reading
12666
12617.5
12624.5
12624.5
12624.5
12624.5
12666
12624.5
First Reading For Entire File .......... 11564
Last Reading For Entire File ........... 12666
File Trailer
Service name ............. STSLIB.006
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.007
Physical EOF
File Header
Service name ............. STSLIB.007
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.006
Comment Record
FILE HEADER
FILE NUMBER: 7
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 11
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
GR 12618.5 13806.5
FET 12625.0 13813.5
RPD 12625.0 13813.5
RPM 12625.0 13813.5
RPS 12625.0 13813.5
RPX 12625.0 13813.5
ROP 12667.5 13855.0
$
#
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
$
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:
2 8 -MAY- 9 8
ISC 5.07, ISC 5.07
3.01E, 2.22A, 7.53
MEMORY
13855.0
12666.0
13855.0
88.1
94.4
TOOL NUMBER
P1006SP4
P1006SP4
6.000
6.0
QUIK DRILN
8.70
61.0
8.7
18000
6.2
.300
.145
2.800
.400
60.9
.6
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
DEPT FT 4 1 68
GR MWD 11 API 4 1 68
RPX MWD 11 OHMM 4 1 68
RPS MWD 11 OHMM 4 1 68
RPM MWD 11 OHMM 4 1 68
RPD MWD 11 OHMM 4 1 68
ROP MWD 11 FT/H 4 1 68
FET MWD 11 HOUR 4 1 68
Code Offset Channel
0 1
4 2
8 3
12 4
16 5
20 6
24 7
28 8
Name Min Max
DEPT 12618.5 13855
GR 24.8149 173.543
RPX 10.0265 172.947
RPS 12.9792 285.392
RPM 14.1672 2000
RPD 17.9725 2000
ROP 7.1133 4703.91
FET 0.4036 23.9604
Mean
13236.8
81 943
49 481
57 797
89 505
129 633
126 155
2.01372
Nsam
2474
2377
2378
2378
2378
2378
2376
2378
First
Reading
12618.5
12618.5
12625
12625
12625
12625
12667.5
12625
Last
Reading
13855
13806.5
13813.5
13813.5
13813.5
13813.5
13855
13813.5
First Reading For Entire File .......... 12618.5
Last Reading For Entire File ........... 13855
File Trailer
Service name ............. STSLIB.007
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.008
Physical EOF
File Header
Service name .............. STSLIB.008
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.007
Comment Record
FILE HEADER
FILE NUMBER: 8
RAW MAD
Curves and log header data for each pass of each run in separate files.
DEPTH INCREMENT:
MAD RUN NUMBER:
MAD PASS NUMBER:
FILE SUMMARY
.5000
10
VENDOR TOOL CODE START DEPTH
GR
RPD
RPM
RPS
RPX
FET
RAT
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
11529.0
11536 5
11536 5
11536 5
11536 5
11537 5
11578 0
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:
STOP DEPTH
12625.5
12632.5
12632.5
12632.5
12632.5
12632.5
12673.5
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):
25-MAY-98
ISC 5.07, ISC 5.07
3.01E, 2.22A, 7.53
MEMORY
12666.0
11640.0
12666.0
87.5
94~5
TOOL NUMBER
P1006SP4
P1006SP4
6.000
6.0
QUIK DRILN
8.70
63.0
8.7
19000
7.2
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
.280
.143
3.000
.540
.6
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MAD 10 API 4 1 68 4 2
RPX MAD 10 OHMM 4 1 68 8 3
RPS MAD 10 OHMM 4 1 68 12 4
RPM MAD 10 OHMM 4 1 68 16 5
RPD MAD 10 OHMM 4 1 68 20 6
RAT MAD 10 FT/H 4 1 68 24 7
FET MAD 10 HOUR 4 1 68 28 8
56.1
Name
DEPT
GR
RPX
RPS
RPM
RPD
RAT
FET
Min
11529
26 9032
4 9801
9 2126
10 5804
15 3959
57 2854
4 3241
First
Max Mean Nsam Reading
12673.5 12101.2 2290 11529
181.689 73.3318 2194 11529
63.1453 27.7989 2193 11536.5
114.8 42.4208 2193 11536.5
594.962 71.7069 2193 11536.5
2000 123.125 '2193 11536.5
447.557 246.067 2192 11578
100.256 29.7975 2191 11537.5
Last
Reading
12673.5
12625.5
12632.5
12632.5
12632.5
12632.5
12673.5
12632.5
First Reading For Entire File .......... 11529
Last Reading For Entire File ........... 12673.5
File Trailer
Service name ............. STSLIB.008
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.009
Physical EOF
File Header
Service name ............. STSLIB.009
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.008
Comment Record
FILE HEADER
FILE NUMBER: 9
RAW MAD
Curves and log header data for each pass of each run in separate files.
DEPTH INCREMENT: .5000
MAD RUN NUMBER: 11
MAD PASS NUMBER:
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
STOP DEPTH
FET 12625.5 13815.0
RPD 12625.5 13815.0
RPM 12625 . 5 13815.0
RPS 12625.5 13815.0
RPX 12625.5 13815.0
GR 12626.0 13808 . 0
RAT 12674 . 0 13854 . 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)
28-MAY-98
ISC 5.07, ISC 5.07
3.01E, 2.22A, 7.53
MEMORY
13855.0
12666.0
13855.0
88.1
94.4
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 IS):
MUD PH:
MUD CHLORIDES (PPM) :
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT ~tAX 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 r. ecord ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
TOOL NUMBER
P1006SP4
P1006SP4
6.000
6.0
QUIK DRILN
8.70
61.0
8.7
18000
6.2
.300
.145
2.800
.400
60.9
.6
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MAD 11 API 4 1 68 4 2
RPX MAD 11 OHMM 4 1 68 8 3
RPS MAD 11 OHMM 4 1 68 12 4
RPM MAD 11 OHMM 4 1 68 16 5
RPD MAD 11 OHMM 4 1 68 20 6
RAT MAD 11 FT/H 4 1 68 24 7
FET MAD 11 HOUR 4 1 68 28 8
Name
DEPT
GR
RPX
RPS
RPM
RPD
RAT
FET
Min
12625.5
15 0235
7 2195
10 3136
12 0391
15 5533
64 3159
11 1072
Max Mean Nsam
13854.5 13240 2459
204.39 81.1508 2365
106.717 33.88 2380
138.706 43.0913 2380
2000 54.3183 2380
2000 73.0674 2380
372.066 231.578 2362
74.4713 31.8971 2380
First Last
Reading Reading
12625.5 13854.5
12626 13808
12625.5 13815
12625.5 13815
12625.5 13815
12625.5 13815
12674 13854.5
12625.5 13815
First Reading For Entire File .......... 12625.5
Last Reading For Entire File ........... 13854.5
File Trailer
Service name ............. STSLIB.009
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 99/11/22
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.010
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 99/11/22
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number..~...01
Next Tape Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Services
Reel Trailer
Service name ............. LISTPE
Date ..................... 99/11/22
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Services
Scientific Technical
Scientific Technical
Physical EOF
Physical EOF
End Of LIS File
