Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout199-109
" STATE OF ALASKA)
ALAS.v: 61L AND GAS CONSERVATION COMMISSION RE
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
FEB I 4 2005
Aituk8\Qí1 &~
B Develqffm1mk~(¡¡ Exploratory
0 Stratigraphic 1:1 Service
12. Permit to Drill Number
199-109 304-468
13. API Number
50- 029-21 045-03-00
14. Well Name and Number:
PBU K-07C
15. Field I Pool(s):
Prudhoe Bay Field I Prudhoe Bay
Pool
No. of Completions
1 a. Well Status: 0 Oil 0 Gas 0 Plugged B Abandoned 0 Suspended 0 WAG
20AAC 25.105 20AAC 25.110
0 GINJ 0 WINJ 0 WDSPL
2. Operator Name:
BP Exploration (Alaska) Inc.
3. Address:
P.O. Box 196612, Anchorage, Alaska 99519-6612
4a. Location of Well (Governmental Section):
Surface:
2041' SNL, 473' EWL, SEC. 04, T11N, R14E, UM
Top of Productive Horizon:
576' NSL, 1266' EWL, SEC. 33, T12N, R14E, UM
Total Depth:
298' NSL, 157' EWL, SEC. 33, T12N, R14E, UM
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 670744 y- 5975163 Zone- ASP4
TPI: x- 671470 y- 5977797 Zone- ASP4
Total Depth: x- 670368 y- 5977494 Zone- ASP4
18. Directional Survey 0 Yes B No
21. Logs Run:
22.
Zero Other
5. Date Comp., Susp., or Aband.
12/30/2004 ~
6. Date Spudded
11/25/1999
7. Date T.D. Reached
12/0311999
8. KB Elevation (ft):
54.66'
9. Plug Back Depth (MD+ TVD)
10734 + 8885
10. Total Depth (MD+ TVD)
10820 + 8888
11. Depth where SSSV set
N/AMD.
19. Water depth, if offshore
NI A MSL
CASING.
SIZE
20" x 30"
13-3/8"
9-5/8"
7"
4-1/2"
GRADE
Conductor
L-80
L-80
L-80
L-80
CASING, LINER AND CEMENTING RECORD
SetrING.DEPTH MD . SETTING .DEPTH TVD HOLE
I OP ~TTOM .. lOP . ~TTOM SIZE
Surface 110' Surface 110' 36"
Surface 2709' Surface 2709' 17-1/2"
Surface 6992' Surface 9279' 12-1/4"
6803' 9189' 6139' 8362' 8-1/2"
9036' 10820' 8210' 8888' 6-1/8"
WT. PER FT.
Insulated
72#
47#
26#
12.6#
23. Perforations oRen to Production (MD + TVD of Top and
Bottom Interval, Size and Number; if none, state "none"):
None
MD
TVD
MD
SCANNED FEB 1 8 2005
26.
Date First Production:
Not on Production
Date of Test Hours Tested
27.
24.
SIZE
4-1/211, 12.6#, L-80
TVD
Ft
Ft
16. Property Designation:
ADL 028300
17. Land Use Permit:
20. Thickness of Permafrost
1900' (Approx.)
CEMENTING RECORD
8 cu yds Concrete
3264 cu ft PF 'E', 465 cu ft PF II
2119 cu ft Class 'G', 133 cu ft PF 'C'
527 cu ft Class IG'
280 cu ft Class IG'
AMOUNT
PULLED
TUBING RECORD
DEPTH SET (MD)
9040'
PACKER SET (MD)
9011'
ACID, FRACTURE, CEMENT SaUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
9366' Set WS-R-BB Weatherford Packer
9325' Set Whipstock
ORIGINAL
Form 10-407 Revised 12/2003
CONTINUED ON REVERSE SIDE
GAs-McF
W ATER-BBl
PRODUCTION TEST
Method of Operation (Flowing, Gas Lift, etc.):
N/A
PRODUCTION FOR Oil -BBl
TeST PERIOD +
Flow Tubing Casing Pressure CALCULATED + Oll-BBl
Press. 24-HoUR RATE
GAs-McF
W ATER-BBl
CHOKE SIZE
GAS-Oil RATIO
Oil GRAVITY-API (CORR)
CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separa~,U~..:t, ij necessary).
Submit core chips; if none, state "none". r7:m~'¡:;;r.:i,f¡~~
None RBDMS BFl FEB 1 7 200S ,.1 P'> ?~1:.^,;..
1'£Ar.~V~;
¡. :~~}
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G 1"
t-
28.
r.
GEOLOGIC MARKER~ ')
29.
')
FORMATION TESTS
NAME
MD
TVD
Include and briefly summarize test results. List intervals tested,
and attach detailed supporting data as necessary. If no tests
were conducted, state "None".
Sadlerochit
9277'
8449'
None
Zone 1 B
9654'
8766'
30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports
31. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed Terrie Hubble ~.AAi.t 1 ~~ Trtle Technical Assistant Date Od../, I.{ 105
PBU K-07C 199-109 304-468 Prepared By Name/Number: Terrie Hubble, 564-4628
Well Number Permit No. I Approval No. Drilling Engineer: Sean McLaughlin, 564-4387
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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water
Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with
production from each pool completely segregated. Each segregated pool is a completion.
ITEM 4b: TPI (Top of Producing Interval).
ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other
spaces on this form and in any attachments.
ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
ITEM 20: True vertical thickness.
ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the
cementing tool.
ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in
item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional
interval to be separately produced, showing the data pertinent to such interval).
ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or
Other (explain).
ITEM 27: If no cores taken, indicate "None-.
ITEM 29: List all test information. If none, state "None".
Form 10-407 Revised 12/2003
Submit Original Only
Well:
Field:
API:
Permit:
)
)
K-07D
Prudhoe Bay Unit
50-029-21045-04-00
204-242
Accept:
Spud:
Release:
Rig:
PRE-RIG WORK
12/13/04
DRIFT WI 3.70" DMY WHIPSTOCK.
01/05/05
01/06/05
01/20/05
Nordic #1
12/14/04
DRIFT WI WFD DUMMY WHIPSTOCK (3.70 O.D,OAL 13') TO 9377' SLM (27' CORRECTION KB-BF). TARGET
DEPTH 9350' MD, TIGHT SPOT AT 9015' SLM. WORKED THROUGH SEVERAL TIMES UNTIL WE DIDN'T SEE
IT ANY MORE. SET 4.5" XX PLUG (WI 8 1/8" EQ PORTS, LOCK OPEN 25" OAL) AT 1981' SLM.
12/30/04
PULLED 41/2" XX-PLUG FROM 1985' (SLM).
/
SET BOTTOM OF 4-1/2" WS-R-BB WEATHERFORD PACKER AT 9336'. LUG ORIENTED AT 20 DEGREES
LEFT OF HIGH SIDE LOOKING DOWNHOLE. POS SP AT SET: 698 MV. JOB COMPLETE - LEAVE WELL SI.
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BPEXPLORATION
Operatioßs$l¡Jmmary.Report
Page 1 48
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
K-07
K-07
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 1
Start: 1/5/2005
Rig Release: 1/21/2005
Rig Number: N1
Spud Date:
End:
Date From - To Hours Task Code NPT Phase Descriþtion...of..Openations
1/5/2005 00:00 - 07:30 7.50 MOB P PRE Move Nordic 1 from OS 13-24A. Scope down derrick to move
rig under twin towers. Phase 1 weather with 20-30 mph winds.
Good move, 14.2 miles in 9.5 hrs. Killed well with Little Red,
290 bbls of 2% KCl water and 40 BBl Diesel. Well was dead
and all valves closed.
Raise derrick.
07:30 - 07:45 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and
mitigation for backing rig over well.
07:45 - 08:00 0.25 MOB P PRE Back rig over well and set down. No problems.
08:00 - 09:30 1.50 BOPSUP P PRE ACCEPT RIG AT 0800 HRS, 01/05/2005. N/U BOPE.
General rig up and positioning trailers, tanks and M/U hardline.
09:30 - 14:30 5.00 BOPSUF P PRE Pressure and function test BOPE. Send test report to AOGCC.
14:30 - 16:00 1.50 WHIP P WEXIT Pump dart and fill coil. Dart on seat at 56.9 bbls.
16:00 - 16:15 0.25 WHIP P WEXIT SAFETY MEETING. Review procedure, hazards and
mitigation for M/U Whipstock BHA. Phase 2 weather
conditions.
16:15 - 17:20 1.08 WHIP P WEXIT M/U BHA #1, Weatherford Whipstock tray and running tools.
3 RA tags in tray. OAl =
17:20 - 19:10 1.83 WHIP P WEXIT RIH with WFD whipstock tray. pump at minimum rate.
Up Wt at 9200' = 40K, Own Wt = 20K.
19:10 - 19:20 0.17 WHIP P WEXIT Tag WFD packer at 9340' CTD. Packer was set at 9336'. Set
Own 6K. Pick up to 43K. Whipstock is latched. Set down 8K.
Pick up to 46K, Set down 10K, Pick up and pulled free at 54K.
Did not use jars. Whipstock running tool was set to release at
11.5K over. It released at 14K over. looks good.
Top of WFD packer set at 9,336'.
Top of WFD whipstock set at 9,325'. Whipstock tray set at
30R TF.
19:20 - 21 :00 1.67 WHIP P WEXIT POH while circ well to 1.5# Biozan with 2% KCl water.
21:00 - 21:15 0.25 WHIP P WEXIT layout WFD running tools.
21:15 - 21:30 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and
mitigation for M/U WFD window milling BHA. Phase 2 weather
conditions.
21 :30 - 22:45 1.25 STWHIP P WEXIT M/U BHA #2, WFD 3.80. window milling BHA with WFD
diamond mill and reamer. M/U WFD CTC and pull 1 press test.
OAl=
22:45 - 00:00 1.25 STWHIP P WEXIT RIH with 3.80. window milling BHA. Circ at 0.2 bpm.
1/6/2005 00:00 - 00:30 0.50 STWHIP P WEXIT RIH with 3.80. WFD window milling BHA.
00:30 - 01 :30 1.00 STWHIP P WEXIT Tag XN Nipple at 9041 ft. Mill out lightly with one small stall.
Ream up and down 2 times. Clean.
01 :30 - 01 :45 0.25 STWHIP P WEXIT Pressure test well to 2100 psi to prove whipstock 1 packer is
sealed.
Start pressure = 2110 psi, End pressure at 15 min. = 2098 psi.
Good Test.
01 :45 - 02:00 0.25 STWHIP P WEXIT RIH and tag top of whipstock at 9332'. corrected depth to
9325'.
02:00 - 04:30 2.50 STWHIP P WEXIT Milling 3.80. window with WFD milling BHA. Flag Coil at 9325'.
2.7 bpm, 2000-2200 psi, 2-4K WOB, Milled to 9327'. Pick up
to check free spin pressure and down wt. No stalls, slow
steady milling.
04:30 - 06:00 1.50 STWHIP P WEXIT Milling window, 2.7 bpm, 1970-2200 psi, 3-4K WOB, Milled
to 9327.4'.
06:00 - 10:30 4.50 STWHIP P WEXIT Milling window, 2.7 bpm, 2260 psi, 3-4K WOB, Milled
Printed: 1/24/2005 10:25:56 AM
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Page 2-
BP EXPLORATION
OJ¡1erat¡iOAS...SUR'lmary. ."epørt
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
K-07
K-07
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 1
Start: 1/5/2005
Rig Release: 1/21/2005
Rig Number: N1
Spud Date:
End:
Date From''; To HoUrs Task
1/6/2005 06:00 - 10:30 4.50 STWHIP P WEXIT
10:30 - 11 :45 1.25 STWHIP N WAIT WEXIT
11:45 -13:45 2.00 STWHIP P WEXIT
13:45 - 16:00 2.25 DRILL P PROD1
16:00 - 16:35 0.58 DRILL P PROD1
16:35 - 16:40 0.08 DRILL N RREP PROD1
16:40 - 18:00 1.33 DRILL P PROD1
18:00 - 19:00 1.00 DRILL P PROD1
19:00 - 19:40 0.67. DRILL P PROD1
19:40 - 21 :30 1.83 DRILL P PROD1
21 :30 - 21 :50 0.33 DRILL P PROD1
21 :50 - 00:00 2.17 DRILL P PROD1
117/2005 00:00 - 02:00 2.00 DRILL P PROD1
02:00 - 04:00 2.00 DRILL P PROD1
04:00 - 05:00 1.00 DRILL P PROD1
05:00 - 07:00 2.00 DRILL P PROD1
07:00 - 07:30 0.50 DRILL P PROD1
07:30 - 09:00 1.50 DRILL P PROD1
09:00 - 16:00 7.00 DRILL P PROD1
16:00 - 19:00 3.00 DRILL P PROD1
19:00 - 19:30 0.50 DRILL P
19:30 - 21 :45 2.25 DRILL P
21:45 - 22:10 0.42 DRILL PROD1
22:10 - 22:30 0.33 DRILL PROD1
22:30 - 00:00 1.50 DRILL PROD1
1/8/2005 00:00 - 02:00 P PROD1
02:00 - 02:15 P PROD1
P PROD1
2.50 DRILL P PROD1
1.50 DRILL P
PROD1
Description...of.Operations
window to 9330.4 and drill open hole to 9341.
Wait on mud arrival. MI power outage slowed loading.
Swap to mud while POH.
LD window mill and string reamer. 3.79"0.D. Mills in good
condition. MU Suilding assembly with 2.29 bent housing.
Rehead coil.
RIH to 3120'
Power Outage. Total Slack out. Generator went down due to
overspeed.
Rig electrician looking into cause.
RIH seen window, tag bottom at 9345'.
Logged GR Tie-in. -12 ft CTD correction. RIH. Tag bottom at
9333'.
Orient TF to 90R.
Drilling build / turn section. 2.7 bpm, 3100-3800 psi, 90R.
Drilled to 9353', Toolface went to left side.
Orient TF to right side.
Drilling Zone 3 build / turn section. 2.7 bpm, 3100-3
90R. 3-5K WOS, Drilled to 9,378'.
Drilled Z3 build / turn section, 2.6/2.6 bpm, 00-3900 psi,
75R, 3-5K WOS, Slow drilling in Zone 3. rilled to 9,392 ft.
Drilled Z3 build / turn section, 2.6/2.6 pm, 3000-3900 psi,
80R, 3-5K WOS, Slow drilling in e 3. Drilled to 9,405'.
Drilled Z3 build / turn section, /2.6 bpm, 3000-3900 psi,
80R, 3-5K WOS, Slow drill' in Zone 3, several stalls at
9407'. Not able to drill ad. Drilled to 9,407.
POH for bit. Flag C t 9200' EOP. POH.
Swap bits 8-8 rin d out. PU rebuilt HCC bi center.
RIH
Drill Z3 2 2.7 bpm @ 3100 psi, FS = 3000 psi, Up wt 33K,
On W 8K, TF 90 R, WOS 3-4K, ROP 5-20. Drill to 9468'.
Dr' 22.54- 2.67 bpm @ 3100 psi, FS = 3200 psi, Up wt 31K,
n Wt 15K , TF 44 R, WOS 3-4K, ROP 20 - 40. Drilled to
9550'.
Wiper trip to window, clean hole. RIH.
Drilled 22 build / turn section, 2.7/2.7 bpm, 3100 - 3900 psi,
30R, 65 deg incl, 90 fph, Drilled to 9700'.
Wiper trip to window, clean hole. RIH.
Orient TF to 30L.
Drilled Z2 - 21 build / turn section, 2.7/2.7 bpm, 3100 - 3900
psi, 20L, 85 deg incl, 50-90 fph, Drilled to end of build
section at 9780'.
POH for lateral RES / MWD SHA.
SAFETY MEETING. Review procedure, hazards and
mitigation for C/O BHA.
C/O BHA. Adjust motor to 1.1 deg, M/U Bit #4, new 3.75" HYC
DS49, M/U RES with MWD. Upload RES tool. OAL = 89.27'.
RIH with Lateral RES MWD BHA #5. SHT tools and orienter.
RIH.
Orient TF to high side to go thru window. Tag botttom and
correct to tag.
Mad pass to window at 120& 900 hr I hr. Tie - in . Correction
-16'.
Printed: 1/2412005 10:25:56 AM
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~
FRANK H. MURKOWSKI, GOVERNOR
AItASIiA OIL AND GAS
CONSERVATION COMMISSION
333 W. "JTH AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
e,~'t&f
Sean McLaughlin
CT Drilling Engineer
BP Exploration (Alaska) Inc.
P.O. Box 196612
Anchorage, Alaska 99519-6612
Re: Prudhoe Bay K-07C
Sundry Number: 304-468
Dear Mr. McLaughlin:
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.
Daniel T. Seamount, Jr.
Commission
DATED thisL day of December, 2004
Encl.
SCANNEC~ DEG 0 2 2004
\¡JG~ , 2./í{ ~OO1
') STATE OF ALASKA )
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVAL
20 AAC 25.280
2004
1. Type of Request:
II Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate
0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver
0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well
10. Field / Pool(s):
Prudhoe Bay Field / Prudhoe Bay Pool
PRESENT.WELL'CONDITIQNSUMM~Y ,
Total Depth TVD (ft): I Effective Depth MD (ft):.IEffective Depth TVD (ft): Plugs (measured): Junk (measured):
8888 10734 8885 None None
Length Size MD TVD Burst Colläpse
2. Operator Name:
BP Exploration (Alaska) Inc.
3. Address:
P.O. Box 196612, Anchorage, Alaska 99519-6612
7. KB Elevation (ft): 54.66'
8. Property Designation:
ADL 028300
11.
Total Depth MD (ft):
10820
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
0 Other
0 Time Extension
4. Current Well Class:
IBI Development 6"Exploratory
0 Stratigraphic 0 Service
5. Permit TO;;iII Number
199-109 . /
6. API Number: /
50- 029-21 045-03-00
9. Well Name and Number: /
PBU K-07C
110' 20" x 30" 110' 110'
2709' 13-3/8" 2709' 2709' 5380 2670
6992' 9-5/8" 6992' 6279' 6870 4760
2386' 7" 6803' - 9189' 6139' - 8362' 7240 5410
1784' 4-1/2" 9036' - 10820' 8210' - 8888' 8430 7500
12. Attachments:
IBI Description Summary of Proposal 0 BOP Sketch
0 Detailed Operations Program
14. Estimated Date for
Commencing Operations:
16. Verbal Approval:
Commission Representative:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Printed Name Sean McLaughlin Title CT Drilling Engineer
\ I'/I(.L .
Signature ...;'^ l"¡" /\...--
Liner
Perforation Depth MD (ft): Perforation Depth TVD (ft):
9720' - 10730' 8805' - 8885'
Packers and SSSV Type: 7" x 4-1/2" HES 'TNT' packer;
4-1/2" HES 'X' Nipple
Decembe~o04
DateY'"
Tubing Size:
4-1/2", 12.6#
Tubing Grade:
L-80
Packers and SSSV MD (ft): 9011'
2014'
Tubing MD (ft):
9040'
13. Well Class after proposed work:
0 Exploratory IBI Development 0 Service
15. Well Statu~agr proPo~dG:~rk: 0 Plugged /' IBI Abandoned
0 WAG 0 GINJ 0 WINJ 0 WDSPL
Contact Sean McLaughlin, 564-4387
Phone 564-4387
ComrnissÎônUse Only
Prepared By Name/Number:
Terrie Hubble, 564-4628
Date tll1p/~1
I Sundry Number: 3ot.{ - Ýb€"
0 Plug Integrity
0 Mechanical Integrity Test
Conditions of approval: Notify Commission so that a representative may witness
0 Location Clearance
0 BOP Test
Other: Ay I) i 0 V d r:o ý V\^- 10 . 4 Q t rlb tU N' J Ct. s; ~ -t tUiL tM-€iI ¡¿ - 01\:),
R8DMS BFL DEC 0 1 20D4
Subsequent Form Required: l 0-- 4- 0 :1
Approved By: ¿-J ci/ //¿J
Form 10-403 R~~ /'/
COMMISSIONER
APPROVED BY
THE COMMISSION
Date / 2/1/4-
ORIG\NAL
Submit In Duplicate
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JJ
To:
Winton Aubert
Petroleum Engineer
Alaska Oil & Gas Conservation Commission
From: S.M. McLaughlin
CTD Engineer
Date: November 29,2004
Re:
P&A operations for well K-07C as part of the CTD sidetrack
Well K-07C is scheduled for a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig on or
around 1/5/05. The sidetrack, K-07D, will exit out of the existing 4 'lí" liner off a whipstock in Zone 3 and target -
Zone 1A sands. The existing perforations will be isolated by a packer below the whipstock and liner cement. /"
Note that a hollow, perforatable whipstock will be used for the purpose of restoring communication with the /'
existing perfs at some point in the future. The following describes work planned for the P&A and is submitted as
an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference.
Pre CTD Summary
1) S - dummy GLMs
2) S - Caliper tubing to 9350'
3) S - Dummy whipstock drift to 9350'
4) 0 - MIT-IA, MIT-OA, PPPOT-T, IC
5) E - Set packer and whipstock tray at 9320' /
The pre CTD work is slated to begin on 12/20/04.
Sean McLaughlin
CTD Drilling Engineer
564-4387
CC: Well File
Sondra StewmanlTerrie Hubble
TREE =- 6" McEVOY
~~~~~~ ,=* . .~~~<?~I
ACTUA TOR = OTIS
. .
KB. ELEV = 54.66'
BF. ELEV = 27,91'
-~-",-....,..,,-...,.,.:,..,..~.=....,..
KOP = 3300'
Max Angle ~~90 @10123'
Datum MÖ = 10069'
<>.. , .'. - .
Datum TVD = 8800' SS
')
113-3/8" CSG, L-80, ID = 12.347" 1-1 2709'
Minimum ID = 3.725" @ 9028'
4-1/2" HES XN NIPPLE
14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1
I TOP OF BAKER TIEBACK SLEEVE 1-1 6803'
\9-5/8" x 7" BAKER ZXP PKR, ID = 6.313" 1-1 6809'
19-5/8" x 7" BAKER HMC HGR, ID = 6.250" 1-1 6816'
I TOP OF WHIPSTOCK 1-1 6992'
\9-5/8" CSG, 47#, L-80, ID = 8.681" 1
I TOP OF 9-5/8" CIBP 1-1 7024'
OLD5-1/2" TBG STUB 1-1 7336'
K-07C
S.)-YNOTES: WELL ANGLE > 70° @ 9784' & >
80° @ 9830'. PRE- K-07C SDTRK WELL80RE (K-
078) NOT SHOWN ON THIS DIAGRAM.
I I
2014' 1-14-1/2" HES X NIP, ID = 3.813" 1
~-
=----1 2604' 1-19-5/8" DV COLLAR 1
~
...l
ST MD TVD DEV
4 3295 3238 11
3 6012 5501 42
2 7836 6982 17
1 8888 8009 8
GAS LIFT MANDRELS
TYPE VLV LATCH PORT
MMG-M DOME RK 16
MMG-M S/O RK 20
KBG-2LS DV BTM 0
KBG-2LS DV BTM 0
DATE
12/11/99
12/11/99
12/06/99
12/06/99
l
i
J
i
9-5/8" CSG MILLOUT WINDOW
6992' - 7008' (OFF WHIPSTOCK)
8997' 1-14-1/2" HES X NIP, ID = 3.813" 1
9011' 1-17" x 4-1/2" HES TNT PKR, ID = 3.875" 1
9028' 1-14-1/2" HESXN NIP, ID = 3.725" 1
9040' 1-14-1/2" WLEG I
IT' X 5" BKR ZXP PKR / HMC HGR, ID = 4.375" 1-1 9036'
14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 9039'
17" LNR, 26#, L-80, ID = 6.276" 1-1
ÆRFORA TION SUMMARY
REF LOG: TCP ÆRF
ANGLEATTOPÆRF: 80 @ 9830'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERV AL Opn/Sqz DA TE
2-7/8" 6 9720 - 9740 0 10/23/03
2-7/8" 6 9750 - 9770 0 10/23/03
2-3/4" 4 9830 - 10030 0 12/05/99
2-3/4" 4 10080 - 10230 0 12/05/99
2-3/4" 4 10300 - 10530 0 12/05/99
2-3/4" 4 10580 - 10730 0 12/05/99
DATE
12/05/83
12/06/99
02/28/02
08/04/03
1 0/23/03
REV BY
COMMENTS
ORIGINAL COM PLETION
RIG SIDETRACK (K-07C)
CH/TP CORRECTIONS
CMOffLP KB ELEVATION & MAX ANGLE
CJSITlP ADD ÆRFS
I PBTD 1-1 10734' 1
14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 10820'
DA TE REV BY
PRUDHOE BAY UNIT
W8.L: K-07C
ÆRMIT No: 1991090
API No: 50-029-21045-03
SEe 4, T11N, R14E, 2041' SNL & 473' EWL
COMMENTS
BP Exploration (Alaska)
SA),NOTES:WELLANGLE> 700@9784' & >
80° @ 9830'. PRE- K-07C SDTRK WELLBORE (K-
Proposed CTD Sidetrack 07B) NOT SHOWN ON THIS DIAGRAM.
(I'
TREE :
~ElLHEAD : ~.
ACTUATOR:
, , . - .
KB. ELEV =
\".. .' ,.,
BF. ELEV =
.. " . ,.. ".
KOP=
.. ,. - - - ~ .
,Ma~ A~gle =
Datum MD =
. ^ .'-' ", -..
DatumlVD =
")
6" McEVOY
~f:\I<?'1'J
OTIS
54.66'
27.91'
3300'
, ....,.. ~ -
< ~.O ~ 101~3'"
10069'
"8aöo; 58
-
113-3/8" CSG, L-80, ID= 12.347" 1-1 2709' ~-
Minimum ID = 3.725" @ 9028'
4-1/2" HES XN NIPPLE
(milled to 3.8")
14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1
I TOP OF BAKER TIEBACK SLEEVE 1-1 6803' 1
9-5/8"X7"BAKERZXPPKR,ID=6.313" 1-1 6809' 1
19-5/8" X 7" BAKER HMC HGR, ID = 6.250" 1-1 6816' 1
TOP OF WHIPSTOCK 1-1 6992' ~
1 TOP OF 9-5/8" CIBP 1-1 7024' I
lOLD 5-1/2" TBG STUB 1-1 7336'
I 9-5/8" CSG, 47#, L-80, ID = 8.681" ~
K-07D
I I
--.!
l
i
.J
i
~
. .
g
g
r ,
9036' I ~ ~
9039' r---
91$' ~ ~
. -, f
!'.'.\ I
:~~
17" X 5" BKR ZXP PKR / HMC HGR, ID = 4.375" 1-1
14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1
17" LNR, 26#, L-80, ID = 6.276" 1-1
ÆRFORA TION SUMMARY
REF LOG: TCP ÆRF
ANGLEATTOPÆRF: 80 @ 9830'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERV AL Opn/Sqz DATE
2-7/8" 6 9720 - 9740 isolated proposed
2-7/8" 6 9750 - 9770 isolated proposed
2-3/4" 4 9830 - 10030 isolated proposed
2-3/4" 4 10080 - 10230 isolated proposed
2-3/4" 4 10300 - 10530 isolated proposed
2-3/4" 4 10580 - 10730 isolated proposed
I PBTD - 10734'
14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" - 10820'
DATE
12/05/83
12/06/99
02/28/02
08/04/03
10/23/03
REV BY
DA TE REV BY
COMMENTS
ORIGINAL COM PLETION
RIG SIDETRACK (K-07C)
CI-VTP CORRECTIONS
CMOITLP KB ELEVATION & MAX ANGLE
CJSITLP ADD ÆRFS
...~
COMMENTS
2014' 1-14-1/2" HES X NIP, ID = 3.813" 1
= --1 2604' 1-19-5/8" DV COLLAR 1
~
ST MD lVD DEV
4 3295 3238 11
3 6012 5501 42
2 7836 6982 17
1 8888 8009 8
GAS LIFT MANDRELS
ìYÆ VLV LATCH PORT
MMG-M DOME RK 16
MMG-M SIO RK 20
KBG-2LS DV BTM 0
KBG-2LS DV BTM 0
DATE
12/11/99
12/11/99
12/06/99
12/06/99
9-5/8" CSG MILLOUT WINDOW
6992' - 7008' (OFF WHIPSTOCK)
8997'
1-14-1/2" HES X NIP, ID = 3.813" 1
1-17" X 4-1/2" HES TNT PKR, ID = 3.875" 1
1-14-1/2" HES XN NIP, ID = 3.725" 1
(Milled to 3.8"
9011'
9028'
9040' 1-14-1/2" WLEG 1
9285' I., Liner Top Packer
9290'
9290'
9300'
10000'
1
I-ITop of 3-3/16" Liner 1
1-1 Top of Cerrent 1
1-13-1/2" HES X NIP, ID = 2.813" 1
1-13-3/16 x 2-7/8 X-OVêl 1
(' .. "'
I
0 0 0 0 0 0 0 0 01
1 3-3/16" X 2-7/8" Banzai Con,:>letionl-l 11900' 1
9320' 1-1 Mechanical Hollow Whipstock 1 ./
PRUDHOE BA Y UNrr
WELL: K-07C
ÆRMrr No: 1991090
API No: 50-029-21045-03
SEe 4, T11 N, R14E, 2041' SNL & 473' EWL
BP Exploration (Alaska)
STATE OF ALASKA C;EiVE[)
ALASKA OIL AND GAS CONSERVATION COMMISSION SE8 2 4 2004
REPORT OF SUNDRY WELL OPERATiON::)
,r, ~ .' .' ,'t ..., '"
1. Operations Performed:
Abandon D
Alter Casing 0
Change Approved Program 0
2. Operator
"-_1 '.' ;"t~1 "- :
Suspend D
Repair Well 0
Pull Tubing 0
Operation Shutdown 0
Plug PerforationsD
Perforate New Pool 0
4. Current Well Class:
Perforate ŒJ Waive~ffil)~m);¡gf
Stimulate 0 Time ExtensionO
Re-enter Suspended Well 0
5. Permit to Drill Number:
199-1090
OtherD
Name:
BP Exploration (Alaska), Inc.
54.66
8. Property Designation:
ADL-0028300
11. Present Well Condition Summary:
Stratigraphic 0
9. Well Name and Number:
K-07C
10. Field/Pool(s):
Prudhoe Bay Field / Prudhoe Oil Pool
Exploratory 0
Service 0
6. API Number
50-029-21045-03-00
Development I]]
3. Address: P.O. Box 196612
Anchorage, Ak 99519-6612
7. KB Elevation (ft):
Total Depth
measured 10820 feet
Plugs (measured)
Junk (measured)
None
true vertical 8888.3 feet
Effective Depth
measured 10734 feet
true vertical 8885.0 feet
None
Casing Length Size MD TVD Burst Collapse
Conductor 80 20" 91.5# H.40 27 107 27.0 - 107.0 1490 470
Liner 2386 7" 26# L-80 6803 - 9189 6138.8 - 8362.0 7240 5410
Liner 1784 4-1/2" 12.6# L-80 9036 - 10820 8210.0 - 8888.3 8430 7500
Production 6967 9-5/8" 47# L-80 25 - 6992 25.0 - 6278.6 6870 4760
Surface 2674 13-3/8" 72# L-80 26 - 2700 26.0 - 2699.9 4930 2670
Perforation deDth:
Measured depth: 9720 - 9740,9750 - 9770,9830 -10030, 10080 -10230, 10300 -10530,10580 -10730
True vertical depth: 8805.44 - 8815.27, 8819.75 - 8827.86, 8845.27 - 8853.28, 8854.95 - 8859.69, 8862.11 - 8872.51, 8876.02 - 8884.8
Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80
@ 25
9040
Packers & SSSV (type & measured depth): 4-1/2" Howco TNT Packer
5" Baker ZXP Liner Top Packer
7" Baker ZXP Packer
@
@
@
9011
9036
6803
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
Prior to well operation:
Subsequent to operation:
Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure
1255 39.9 26 420 1245
2268 43.9 92 400 2249
Reoresentative Dailv Averaae Production or Iniection Data
13
14. Attachments:
15. Well Class after proposed work:
Exploratory D
Development ŒI
Service 0
Copies of Logs and Surveys run-
16. Well Status after proposed work: Operational Shutdown D
Oil I]] GasO WAG 0 GINJD WINJD WDSPLO
Prepared by Garry Catron (907) 564-4657.
Sundry Number or N/A if C.O. Exempt:
N/A
Daily Report of Well Operations. ~
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Garry Catron
Printed Name Garr Catron
Title
Production Technical Assistant
Signature
Phone 564-4657
Date
2/20/04
Form 10-404 Revi~~~cNEO MAF~ 1 () 200(~
ibWL
¡[,!ED')'ë¡),~~,~,,~
r s¡;;,.u ~.,.. t.0I,~1 q¡
K-07C
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
EVENT SUMMARY
10/19/03 DRIFT W/ 27/8" DUMMY GUN TO 98251 SLM, STOP DUE TO DEVIATION (TARGET
DEPTH IS 97701)
10/23/03 A TOTAL 40' PERFORATED USING 2.88" HSD GUNS LOADED WITH POWERJET PJ2906
CHARGES, 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. PERFORATED
INTERVALS 97201-97401 & 97501-97701.
FLUIDS PUMPED
B:LS : TOTAL
No Fluids Pumped
Page 1
TREE =
6" MeEV OY
WELLHEAD = MeEV OY
ACTUA. TOR = OT
KB. B...EV = 54.66'
BF. B...EV = 27.91'
KOP= 3300'
IVax Angle = 90 @ 10123'
Datum MD = 10069'
Datum TVD = 8800' SS
s
K-07C
SAFETY NOTES: W B.L ANGLE > 700 @ 9784' & >
800 @ 9830'. PRE- K-07C SDTRKWELLBORE(K-
078) NOT SHOWN ON THIS DIAGRAM.
4-1/2" HES X NIP, 10 = 3.813"
13-318" CSG, L-80, 10 = 12.347"
9-518" r:N COLLA R
4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958"
ST MD TVD DEV
4 3295 3238 11
3 6012 5501 42
2 7836 6982 17
1 8888 8009 8
GAS LIFT Ml\NDRB...S
TYPE V LV LA TCH PORT
MMG-M DOME RK 16
MMG-M S/O RK 20
KBG-2LS DV BTM 0
KBG-2LS DV BTM 0
DATE
12/11/99
12/11/99
12/06199
12/06/99
Minimum ID = 3.725" @ 9028'
4-1/2" HES XN NIPPLE
9-5/8" CSG, 47#, L-80, ID = 8.681"
9-5/8" CSG MLLOur WINDOW
6992' - 7008' (OFFWHPSTOO<)
ITOP OF BAKffi TEBACK SLEEVE I
19-5/8" X 7" BAKERZXP PKR, D = 6.313" I
9-5/8" X 7' BAKffi Hv1C HGR, D = 6.250"
TOP OF WHIPSTOCK
6992'
1 TOP OF 9-518" aBP I
IOLD5-1/2"TBGSlUB I
7' LNR, 26#, L-80, ID = 6.276"
PffiFORA TION SUMMI\ RY
REF LOG: TCP PffiF
ANGLEATTOPÆRF: 80 @ 9830'
I\bte: Refer to A'oduetion DB tor historieal :>art data
SIZE SPF INTERV AL OpnlSqz DATE
2-7/8" 6 9720 - 9740 0 10/23103
2-7/8" 6 9750 - 9770 0 10/23103
2-3/4" 4 9830 - 10030 0 12105/99
2-3/4" 4 10080 - 10230 0 12105/99
2-3/4" 4 10300 - 10530 0 12105/99
2-3/4" 4 10580 - 10730 0 12105/99
4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958"
DATE REV BY COMMENTS DATE REV BY COMM8'JTS
12/05183 ORIGINAL COMPLETION
12/06199 RIG SIDEfRACK (K-07C)
02/28/02 CHffP CORRECTIONS
08/04/03 CMO/TLP KB ELEV A TON & Ml\X ANGLE
10/23/03 CJSffLP ADD PERFS
PRUDHOE BA Y UNrr
WB...L: K-07C
ÆRMT No: 1991090
API No: 50-029-21045-03
SEe 4, T11 N, R14E, 2041' SNL & 473' EWL
8P Exploration (Alaska)
09/26/03
Schlumberger
Alaska Data & Consulting Services
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Beth
NO. 2976
Company: State of Alaska
Alaska Oil & Gas Cons Corem
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Prudhoe Bay
Color
Well Job # Log Description Date Blueline Prints CD
MPL-01A ~--,~-~'~('O~, 23433 ,CHEDITMGR(PDC) 061'11103
D.S. 15-28A-~.),('~,_-~-Ir-,~.LIJ~ 23431 MCNL 08126/03
K-07C ~-~ ~ i ~ 10560303 EST-SIGMA 09/16/03
C-3~B ~~~ 23423 CH EDIT MGR (PDC) 04/23/03
D.S. t5-30A-~-~~ 23422 CH EDIT MGR (PDC) 02/03/03
3-25~N-24 -)~~ ~ SCMT (REP~CES 3-26~M-27 PRINTS) 01/04/03
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrotectnical Data Center LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508 i,~'~;' ~-i".'"':' ':- "~ ~ '" ~'-":
i, ';","~ ' ,, '":' ¢-, ~
Date Delivered:
Schlumberger GeoQuest
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Beth
Schlumberger
Alaska Data & Consulting Services
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Beth
09/18/03
No. 2963
Company:
State of Alaska
Alaska Oil & Gas Cons Corem
Attn: Lisa Weepie
333 West 7th Ave, Suite
Anchorage, AK 99501
Field: Prudhoe Bay
Color
Well Job # Log Description Date Blueline Prints CD
H-17A I (::~ ~ '-~ ~c') ~ MEM PROD PROFILE 08/13107
E-27A '1 ~ C~ ~ (~.~.~/ BEE PROD PROFILE 08/09/03
D.S. 13-08A IC~'~ ~.~ GLS 09/04/03
E-25 1 ~:~ '~--- I .-c~ r~ LDL 09/05103
D.S. 3-09 ~'~ % ~ ~,. PeP PROD PROFILE 08/06103
D.S. 1-11 ~-~ -~(~?--)='~ INJECTION PROFILE 09/16/03
K-07C~ qq ,. ~-(~)-01' SeEP 09/16103
A-23 ~ ~'~~ ~. RST-C GRAVEL PACK 09/07/03
D.S. 15-48A '.~'~ ~[~.~ PeP LDL 08130103
MPS-06 ~(~, ~---[(~..~ TEMPERATURE LOG 08/30/03
t.35/O-25 -~ ~ (,.Q -- i ~' ~LI PROD PROFILEIDEFTIGHOST 091t 4~03
- .
~J-20B 23076 OH EDIT MWD SLIMPULSE & ARC DATA I0114/02
J-20B 23076 MD VISION RESISTIVITY 10/14/02
~J-20B 23076 TVDVISION RESISTIVITY 10114102
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska)Jnc.
Petrotectnical Data Center LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
Date Delivered:
RECEIVE
2005
Aia~ka u~'~ & G~ ~ons. Commission
Schlumberger GeoQuest
3940 Arctic-Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Beth
,,
Permit to Drill No. 1991090
DATA SUBMITTAL COMPLIANCE REPORT
2/$/200~
Well Name/No. PRUDHOE BAY UNIT Ko07C Operator BP EXPLORATION (ALASKA) INC
APl No. 50-029-21045-03-00
MD 10820 TVD 8888 Completion Date 12/6/1999 Completion Status 1-OIL Current Status 1-OIL ' UIC N
~ £~-?~__ ~__~. 2L~_L~'7-'~_-2___~ --_~__2_2.£- -- ~ 22_ ~L_ ~--~2'~Z~-Z--T2-L- -_._ ~.J.~_ ,T-2~Z__- i- ' ?'~ ~5_'X~ '~7_- -. ~-.'_~_-_~27~' ~ - _-- _~_ ~£-- '~ .' .... ~ £_-~---~--~ ..... ~ T-'_-?' '~ ~-~i_.7~_~ ~ -~ ''~'~ -' ~- ~ -~- 7 ~ --
REQUIRED INFORMATION
Mud Log No Samples No Directional Survey~ ~,/~ ,'
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
Log/
Data Digital Digital
Type Media Format Name
(data taken from Logs Portion of Master Well Data Maint)
Log Log Run Interval OH / Dataset
Scale Media No Start Stop CH Received Number Comments
T ,,' ..e'* c-~ 9/7/2001 10307 6989-10780
~/CBL 5 FINAL 6300 7260 CH 2/4/2000
10820 OH 1/6/2000 SPERRY 6991..
ch 8/20/2001 Lis Verification
10730 CH 9/14/2001 BL, Sepia
O](-e-'''''~''' 8/20/2001 10246 6989-10780
C"-'"' ...... 9/12/2001 10284 8900-10370
E~" .~'"'~J:IVY RPT 45
tR'~Lis Verification FINAL
j~ Thermal Neutorn 2 FINAL 8900
~-~ii -~ 0~'e S)Sa'm-pi~s- iii]:~r m ati~-n-?
Interval Dataset
Name Start Stop Sent Received Number Comments
ADDITIONAL INFORMATION
Well Cored? Y/~
Daily History Received? ~ N
Formation Tops Receuived? ~ / N
Comments:
Compliance Reviewed By: ........ Date:
09/12/01
Schlumberger
Alaska Data & Consulting Services
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
NO. 1435
Company:
State of Alaska
Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Prudhoe Bay
Color
Well Job # Log Description Date Blueline Sepia Prints CD
J-17A /',_~:::~'""~ c,~ 21388 SCMT 08/29/01 2
K-07C /_o)~. _/O.~ 20034 'MCNL 12/10/99 I I 1
S-20A ¢.~ t3/-/-y~ 21348 VICNL 071~ 8/01 ~ 4 ~
X-15LJ (REDO) ~(~/~O~ ~ 2~330 IMCNL 06/11/01 1
D.S. ~5~2A (REDO~-~ 20307 MCNL 071~6/00 4
NK-07A (REDO~(%[~~ 21341 MGR 04/26/01 I
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP ExPloration (Alaska)Inc.
Petrotectnical Data Center LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
Date Delivered:
RECEIVED
S£P 1 4 2001
Alaska Oil & Gas Cons. Commission
Anchorage
Schlumberger GeoQuest
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
-!
WELL LOG TRANSMITTAL
To~
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Lisa Weepie
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
August 17, 2001
MWD Formation Evaluation Logs ·
K-07C, AK-MM-90192
K-07C:
Digital Log Images:
1 CD Rom
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL
LETTER TO THE ATTENTION OF:
SpelTy-Sun Drilling Services
Attn: Jim Galvin
6900 Arctic Blvd.
Anchorage, Alaska 99518
BP Exploration (Alaska) Inc.
Petro-technical Data Center LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
Date:
RECEIVED
SEP 0 7 2001
Anchorage
WELL LOG TRANSMITTAL
To.'
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.' Lisa Weepie
333 West 7th Avenue, Suite 100
Anchorage, Alaska
August 14, 2001
RE: MWD Formation Evaluation Logs K-07C, AK-MM-90192
1 LDWG formatted Disc with verification listing.
API#: 50-029-21045-03
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL
LETTER TO THE ATTENTION OF:
Sperry-Sun Drilling Services
Attn: Jim Galvin
6900 Arctic Blvd.
Anchorage, Alaska 99518
BP Exploration (Alaska) Inc.
Petro-Technical Data Center LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
Date:
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO:
THRU:
Julie Heusser,
Commissioner
Tom Maunder,
P. i. Supe~isor
DATE: April 20, 2001
FROM: Chuck Scheve; SUBJECT:
Petroleum Inspector
Safety Valve Tests
Prudhoe Bay Unit
K Pad
Friday, April 20, 200t: I traveled to BPXs K Pad and witnessed the 30-day retest
of the safety valve systems.
As the attached AOGCC Safety Valve System Test Report indicates I witnessed the
testing of 11 wells and 22 components with 3 failures. The pilots on wells K-06, K-
07 and K-09 tripped below the required set point. The pilot on well K-09 was
retested and operated properly. Wells K-06 and K-07 normally flow into the Iow-
pressure system (at 200 to 300 psi) but were recently switched into the high-
pressure system. The pilots on these two wells were left in the iow pressure setting
(125 psi) and tdpped near this set point but were failed on this test due to the higher
flowing tubing pressure required to produce into the high pressure system. These
two pilots were adjusted to the higher set pressure (550 psi) and retested at this
time.
Merv Liddelow performed the testing today; he demonstrated good test procedures
and was a pleasure to work with.
A walk through inspection of the well houses on this pad was performed during the
SVS testing with no problems noted. All well houses inspected were reasonably
clean and all equipment appeared to be in fair conditions.
.Sum.mary: I witnessed the 30-day retest of the safety valve systems at BPXs K-
Pad in the Prudhoe Bay Field.
PBU K Pad, 11 wells, 22 components, 3 failure 13.6% failure rate
16 wellhouse inspections
Attachment: SVS PBU K Pad 4-20-01 CS
X Unclassified
Confidential (Unclassified if doc. removed )
SVS ?BU ~ ~ad 4-20-01 CS
Alaska Oil and Gas Conservation Commission
Safety Valve System Test Report
Operator: BPX
Operator Rep: Merv Liddelow
AOGCC Rep: Chuck Scheve
Submitted By: Chuck Scheve
Field/Unit/Pad: Prudhoe / PBU / K Pad
Separator psi: LPS 154
Date: 4/20/01
HPS 670
Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN&
Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE
K-01 1831210 670 550 525 P P OIL
K-02B 1941350 670 550 525 P P OIL
K-03A 1990030 154 125 100 P P OIL
K-04A 1970210
K-05A 1931560
,K-06A 1981360 670 550 100 3 P 4/20/01 OIL
IK-07C 1991090 670 550 100 3 P 4/20/01 OIL
:K-08 1851790 670 550 525 P P OIL
K-09B 1970860 670 550 100 3 P 4/20/01 OIL
K-10 1871140
K-Il 1871170
K-12 1871040 154 125 110 P P OIL
K-13 1871010
K-14 1870950
K-16A 1981800 154 125 120 P P OIL
K-17A 1980610
K-19A 1981680 154 125 125 P P OIL
K-20A 1981500 154 125 150 P P OIL
Wells: 11 Components: 22 Failures: 3 Failure Rate: 13.64°/~] 90 Day
Remarks:
The pilot on well K-09 tripped below the set point it was retested and worked properly
Wells K-06 & K-07 were recently switched from the low pressure to high pressure oi
train but the pilots were left at the low pressure setting. These pilots were adjusted an
retested.
RJF 1/16/01 Page 1 of 1 SVS PBU K Pad 4-20-01 CS
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 [] Suspended [] Abandoned ~-I Service
2. Name of Operator 7. Permit Number
BP Exploration (Alaska) Inc. 199-109
3. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21045-03
!4. Location of well at surface ~ .~ 2~: -~ [ r , ' ' ' · ' : 9. Unit or Lease Name
2041' SNL, 473' EWL, SEC. 04, T11N, R14E, UM i _: ;. ~ Prudhoe Bay Unit
At top of productive interval ~//~ '].'. 10. Well Number
~ %. .~.
At total depth ~ ._.~
~~_~_~' 11. Field and Pool
298' NSL, 150' EWL, SEC. 33, T12N, R14E, UM
Prudhoe Bay Field / Prudhoe Bay
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool
KBE = 54.66'I ADL 028300
12. Date Spudded11/25/99 I13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if Offsh°re I 16' N°' °f C°mpleti°nsl 2/3/99 12/6/99 N/A MSL, One
17. Total Depth (M'D+TVD)118. Plug Back Depth (MD+TVD)t19. Directional Survey I0. Depth where SSSV set 121. Thickness of Permafr(~'t
10820 8888 FTI 10734 8885 FTJ [~ Yes [] No (Nipple) 2014' MD 1900' (Approx.)
22. Type Electric or Other Logs Run
23. CASING, LINER AND CEMENTING RECORD U I~ I ~ 1 ~1/~ L
CASING SE-I-rING DEPTH HOLE
S~ZE WT. PER FT. GRADE TOP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED
20" X 30" Insulated Conductor Surface 110' 36" 8 cu yds concrete
13-3/8" 72# L-80 Surface 2709' 17-1/2" 3264 cu ft PF 'E', 465 cu ft PF II
9-5/8" 47# L-80 Surface 6992' 12-1/4" 2119 cu ft Class 'G', 133 cuft PF 'C'
7" 26# L-80 6803' 9189' 8-1/2" !527 cuft Class 'G'
4-1/2" 12.6# L-80 9036' 10820' 6-1/8" :280 cuft Class 'G'
24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD
Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
2-3/~4?Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9040' 9011'
MD TVD MD TVD
9830' - 10030' 8845' - 8853'
10080'- 10230' 8855'- 8860' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
10300'- 10530' 8862' - 8873' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
10580'- 10730' 8876' - 8885' Freeze Protect with 155 Bbls of Diesel
D CEIVED
27. PRODUCTION TEST J'~'~
Date First Production I Method of Operation (Flowing, gas lift, etc.)
December 13, 1999 I Flowing Alaska 0il & Gas Cons. Commission
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL !CHOKE SIZE
TEST PERIOD
/
Flow Tubing Casing Pressure CALCULATE OIL-BBL GAS-MCF WATER-BBL O~L GRAWTY-API (CORR)
Press. D 24-HOUR
,,,
28. RATE CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
Form 10-407 Rev. 07-01-80 Submit In Duplicate
29. Geologic Markers 30. Formation Tests
Measured True Vertical Include interval tested, pressure data, all fluids recovered and
Marker Name
Depth Depth gravity, GOR, and time of each phase.
Sag River 9163' 8336'
Shublik 9214' 8387'
Sadlerochit 9276' 8448'
Zone 3 9370' 8540'
Zone 2 9433' 8597'
26N 9466' 8625'
126P 9472' 8630'
!24N 9512' 8662'
24P 9520' 8668'
!23N 9570' 8706'
23P 9586' 8718'
22P 9617' 8740'
Zone 1 B 9695' 8792'
31. List of Attachments
Summary of Daily Drilling Reports, Surveys
32. I hereby certify that the fo, regoing is true and correct to the best of my knowledge
Signed TerrieHubble' I~//~'~ Title Technical Assistant III Date OI '0(._¢~ '~.~
K-07C 199-109 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
Facility PB K Pad
Date/Time
20 Nov 99 10:30-13:00
10:30-13:00
13:00
Duration
2-1/2 hr
2-1/2 hr
13:00-18:30
13:00-18:30
18:30
5-1/2 hr
5-1/2 hr
18:30-06:00
18:30-06:00
11-1/2 hr
11-1/2 hr
21 Nov 99 06:00-17:00
06:00-17:00
17:00
17:00-19:00
17:00-19:00
19:00
19:00-20:00
19:00-19:30
19:30
llhr
llhr
2hr
2hr
19:30-20:00
20:00
1/2 hr
20:00-22:30
20:00-22:30
22:30
2-1/2 hr
2-1/2 hr
Progress Report
22:30-02:30
22:30-23:30
23:30
23:30-02:30
22 Nov 99 02:30
02:30-06:00
02:30-05:00
05:00
4hr
lhr
3hr
3-1/2 hr
2-1/2 hr
Well K-07C Page
Rig Nabors 7ES Date
1
08 December 99
Rig Accepted @ 1700 hrs on 21 st November 1999
Fluid system
Fill pits with Seawater
Completed operations
take on fluids and R/U onto wellhead. Install
secondary annulus valve.
Wellhead work
Held safety meeting
Completed operations
Hold Pre-sud Meeting to discuss well and HSE
expectations.
Retrieved Hanger plug
Equipment work completed
Pull BPV.
Fluid system
Circulated at 2328.0 ft
Hole displaced with Seawater - 100.00 % displaced
Circulate out 156 bbls Freeze Protect. Flowcheck.
Wellhead work
Installed Hanger plug
Equipment work completed
Install TWC. Test from below to 1500 psi. Test tree
from above to 5000 psi- not a flat line- probably
leaking past TWC, no visual outside leaks.
Retrieved Xmas tree
Equipment work completed
Blowdown lines. R/D X-mas tree and stand back.
Inspect tubing hanger threads- bad- will need to spear.
BOP/riser operations - BOP stack
Rigged up BOP stack
Equipment work completed
Activity
Move rig
Rigged down Drillfloor / Derrick
Equipment work completed
Blowdown all lines. PJSM. Lay down Derrick. P/U
Berns and disconnect lines.
Suspend operations
Rig waited: Engineering facilities
Resumed operations
Because of fieldwide outages unable to get the
Electrician Technicians to escort rig under
highlines. Wait until CPS can provide cover.
Move rig
Rig moved 70.00 %
Move camp, substructure and pits from Drillsite 5
to K-pad. Arrive on Location @ 0400 hrs and begin
laying down herculite, around well location.
Move rig (cont...)
Rig moved 100.00 %
At well location - Cellar
Spot Rig. Close windwalls. Lay liner and spot Pit
Module. Raise Derrick. R/U Top Drive, hang bridal
lines. Hammer connections. Hang Stabbing Board.
Facility
Date/Time
23 Nov 99
PB K Pad
Progress Report
Well K-07C Page 2
Rig Nabors 7ES Date 08 December 99
05:00-06:00
06:00-08:30
06:00-08:30
08:30
08:30-11:00
08:30-11:00
11:00
11:00-15:00
11:00-13:00
13:00
13:00-14:30
14:30
14:30-15:00
15:00
15:00-15:30
15:00-15:30
15:30
15:30-22:00
15:30-22:00
22:00
22:00-06:00
22:00-06:00
22:00-06:00
06:00-08:30
06:00-06:30
00:30
06:30-08:30
08:00
Duration
lhr
2-1/2 hr
2-1/2 hr
2-1/2 hr
2-1/2 hr
4hr
2 hr
1-1/2 hr
1/2 hr
1/2 hr
1/2 hr
6-1/2 hr
6-1/2 hr
8hr
8hr
8hr
2-1/2 hr
1/2 hr
2hr
Activity
Tested BOP stack
R/U to test BOPE to 3500 psi.
Chuck Cheevey of AOGCC Waived witness
BOP/riser operations - BOP stack (cont...)
Tested BOP stack
Pressure test completed successfully - 3500.000 psi
Test BOPE to 3500 psi. R/D test equipment.
BHA run no. 1
Fished at 25.0 ft
Fish came free
While dry rodding out TWC retaining pin came free
leaving running tool in TWC. Gather fishing tools
and fish same. 100% recovery- Running Tool, TWC and
pin.
Pull Gas lift completion, 5-1/2in O.D.
Retrieved Tubing hanger
Equipment work completed
Make up spear assembly- BHA #2 and latch tubing
hanger. Pull free. Up weight 150 klbs. Lay down
fishing tools and tubing hanger.
Circulated at 7336.0 ft
Obtained bottoms up (100% annulus volume)
Circulate bottoms up. Flowcheck - good.
Laid down 80.0 ft of Tubing
Completed operations
Pull two joints of 5.1/2" tubing.
4in. Packer assembly workstring run
Set packer at 30.0 ft with 0.0 psi
Packer set at 30.0 ft
R/U and set storm packer below wellhead testing
same to 1000 psi.
Wellhead work
Installed Casing spool
Equipment work completed
N/D BOP. Change out 9.5/8" packoff and install new
tubing spool. Test pack-off to 3200 psi. NFLI BOP
and test flange to 3500 psi. Pull Test plug.
Pull Gas lift completion, 5-1/2in O.D.
Laid down Tubing of 5760.0 ft
171 its and cut-off.
Laid down Tubing of 5760.0 ft
Pull Storm packer and L/O same. POOH laying down
tubing. 144 joints out of 160 laid down at report
time. 25 Control line clamps recovered.
Pull Gas lift completion, 5-1/2in O.D. (cont...)
Laid down 7310.0 ft of Tubing (cont...)
Pull Storm packer and L/O same. POOH laying down
tubing. 144 joints out of 160 laid down at report
time. 25 Control line clamps recovered.
Completed operations
Rigged down Tubing handling equipment
Equipment work completed
Facility
Date/Time
PB K Pad
Duration
13hr
08:30
08:30-21:30
08:30-10:30
10:30
10:30-16:00
16:00
16:00-17:00
17:00
17:00-18:00
18:00
18:00-20:30
20:30
20:30-21:30
21:30
2hr
5-1/2 hr
lhr
lhr
2-1/2 hr
lhr
Progress Report
21:30-03:00
21:30-00:15
Well K-07C
Rig Nabors 7ES
Page
Date
24 Nov 99 00:15
00:15-03:00
03:00
5-1/2 hr
2-3/4 hr
Activity
Equipment work completed
Install wear ring.
BHA run no. 3
03:00-03:30
03:00-03:30
03:30
03:30-06:00
03:30-04:30
04:30
04:30-06:00
06:00-22:00
06:00-09:30
2-3/4hr
1/2 hr
1/2 hr
2-1/2 hr
lhr
1-1/2hr
Made up BHA no. 3
PU mills for drift run in 9 5/8" casing.
BHA no. 3 made up
Singled in drill pipe to 7310.0 ft
At Top of packer: 7310.0 ft
Tag top[ of tubing stub.
Circulated at 7290.0 ft
Obtained bottoms up (100% annulus volume)
Serviced Block line
Line slipped and cut
Pulled out of hole to 940.0 ft
At BHA
Pulled BHA
BHA Stood back
09:30
09:30-10:30
10:30
10:30-12:00
12:00
12:00-16:30
16:30
16:30-18:00
16hr
3-1/2 hr
lhr
1-1/2hr
4-1/2hr
1-1/2hr
3
08 December 99
Electric wireline work
Conducted electric cable operations
Run CBT/CCL/GR. Found sand section to set whipstock
but CBT shows very poor/no cement at proposed
setting depth of 7024' ELM.
Completed logging run with Cement bond log from 7260.0 ft to 6300
Conducted electric cable operations
Completed run with Bridge plug from 7024.0 ft to 7027.0 ft
Set CIBP with top at 7024' ELM (3' below casing
coupling)
Perform integrity test
Tested Casing - Via string
Pressure test completed successfully - 3000.000 psi
BHA run no. 4
Made up BHA no. 4
PU whipstock BHA, MWD and orient same.
BHA no. 4 made up
R.I.H. to 1700.0 ft
Fill pipe and check MWD at 2079
BHA run no. 4 (cont...)
R.I.H. to 6900.0 ft (cont...)
Fill pipe and check MWD at 2079
At Kick off depth · 6900.0 ft
Took MWD survey at 6900.0 ft
Orient whipstock 75 deg left and set on CIBP at
7022.
Top of whipstock 6992'.
Acceptable survey obtained at 6992.0 ft
Whipstock set.
Circulated at 6992.0 ft
Displace well to drilling mud.
Hole displaced with Water based mud - 100.00 % displaced
Milled Casing at 6992.0 ft
Mill window from 6992'-7008' without problems.
Completed operations
Circulated at 7021.0 ft
Ream and clean up window. Circ sweep around to
) ft
Facility
Date/Time
PB K Pad
Duration
18:00
18:00-20:00 2 hr
20:00
20:00-21:30 1-1/2 hr
21:30
21:30-22:00 1/2 hr
22:00
22:00-06:00 8 hr
22:00-23:00 1 hr
23:00
23:00-01:00 2 hr
25 Nov 99 01:00
01:00-04:30 3-1/2 hr
Progress Report
26 Nov 99
Well K-07C Page 4
Rig Nabors 7ES Date 08 December 99
27 Nov 99
Activity
04:30
04:30-05:00 1/2 hr
05:00
05:00-06:00 1 hr
06:00-06:00 24 hr
06:00-19:30 13-1/2 hr
19:30
19:30-19:45 1/4 hr
19:45
19:45-20:00 1/4 hr
20:00
20:00-06:00 10 hr
06:00-06:00 24 hr
06:00-06:00 24 hr
06:00-06:00 24 hr
06:00-16:00 10 hr
16:00
16:00-18:00 2 hr
18:00
18:00-20:00 2 hr
20:00
20:00-20:30 1/2 hr
20:30
20:30-22:00 1-1/2 hr
Hole swept with slug - 100.00 % hole volume
Pulled out of hole to 930.0 ft
At BHA
Pulled BHA
LD DC's and mills. Dressing mill was full gauge.
BHA Stood back
Serviced BOP stack
Run stinger and flush ram cavities. Clean suction
pit to remove metal cuttings.
Equipment work completed
BHA run no. 5
Made up BHA no. 5
MWD tool not working properly on down load. PU tool
and break float sub and GR sub.
Completed operations
Made up BHA no. 5
Load MWD tool.
BHA no. 5 made up
R.I.H. to 6900.0 ft
Test MWD at 2982' - OK. PU 66 singles on way in.
At Window · 6902.0 ft
Stop above window to cut line.
Serviced Block line
Slip 40'.
Line slipped
Took MWD survey at 6990.0 ft
Orient motor and exit window w/o problems.
BHA run no. 5 (cont...)
Drilled to 7183.0 ft
Tag btm and time drill 7021-7026. Slide and drop
angle. Getting good formation returns in samples.
Sidetrack looks good.
Began precautionary measures
Pulled out of hole to 7015.0 ft
Pull 2 stands up to window - hole cond good. RIH.
At top of check trip interval
R.I.H. to 7183.0 ft
On bottom
Drilled to 7440.0 ft
BHA run no. 5 (cont...)
Drilled to 8640.0 ft (cont...)
BHA run no. 5 (cont...)
Drilled to 9190.0 ft (cont...)
Reached planned end of run - Section / well T.D.
Circulated at 9190.0 ft
Pump Lo-Hi vis sweep around. Pump pill.
Hole swept with slug - 125.00 % hole volume
Pulled out of hole to 6990.0 ft
Pull up in to window - no problems.
At Window · 6990.0 ft
Serviced Top drive
Equipment work completed
R.I.H. to 9190.0 ft
UII~'IIL IIItJLUI:, I I.J. ll I. llll. J. VI/IIIU. UF¥ dill. 1\111 tO 1~,
Facility
Date/Time
28 Nov 99
PB K Pad
Progress Report
22:00
22:00-01:00
Well K-07C Page 5
Rig Nabors 7ES Date 08 December 99
Duration
Activity
01:00
01:00-02:30
02:30
02:30-03:00
03:00
06:00-08:30
06:00-08:30
08:30
08:30-20:30
08:30-09:30
09:30
09:30-09:45
09:45
09:45-13:30
13:30
13:30-14:00
14:00
14:00-17:00
17:00
17:00-18:30
18:30
18:30-20:30
20:30
20:30-02:00
20:30-22:00
22:00
22:00-22:15
22:15
22:15-22:45
22:45
22:45-23:00
23:00
23:00-23:15
23:15
23:15-23:30
3hr
1-1/2 hr
1/2 hr
2-1/2 hr
2-1/2 hr
12hr
lhr
1/4 hr
3-3/4 hr
1/2 hr
3hr
1-1/2 hr
2hr
5-1/2 hr
1-1/2 hr
1/4 hr
1/2 hr
1/4 hr
1/4 hr
1/4 hr
On bottom
Circulated at 9190.0 ft
Pump hi-vis sweep around & circ hole clean.
Spot 45 bbl liner pill in OH. Flowcheck - OK.
Hi-Vis mud spotted downhole
Spot shale inhibitor pill.
Backreamed to 6990.0 ft
Drop Sperry EMS to satisfy JORPS. POH to window.
At Window · 6990.0 ft
Circulated at 6990.0 ft
Flow check. Drop 2 3/8" rabbit and pump pill.
Heavy slug spotted downhole
BHA run no. 5 (cont...)
Pulled BHA
BHA Laid out
Clear floor.
Run Liner, 7in O.D.
Rigged up Casing handling equipment
Equipment work completed
Held safety meeting
Completed operations
Ran Liner to 2300.0 ft (7in OD)
Stopped · To circulate
Installed Liner hanger
MU hanger and 1 stand DP. Circ liner vol.
Equipment work completed
Ran Drillpipe in stands to 6990.0 ft
At Window · 6990.0 ft
Circulated at 6990.0 ft
PU plug dropping head on single. Well appears to be
breathing.
Obtained bottoms up (100% annulus volume)
Ran Drillpipe in stands to 9190.0 ft
On bottom
Estimated fluid lost while running liner - 35 bbls.
Cement · Liner cement
Circulated at 9189.0 ft
Circ at 7 BPM with minimal losses. RU cementers
while circ.
Obtained clean returns - 150.00 % hole volume
Held safety meeting
Completed operations
Tested High pressure lines
Air up & prime up.
Test lines to 4500 psi.
Pressure test completed successfully - 4500.000 psi
Pumped Lo/Hi vis combination spacers - volume 30.000 bbl
Pump B45 visc spacer at 10.8 ppg.
Required volume of spacer pumped
Mixed and pumped slurry - 74.000 bbl
Lead slurry Class G with extender. Wt - 11.0 ppg.
Lead cement pumped
Mixed and pumped slurry - 20.000 bbl
Facility PB K Pad
Date/Time
23:30
23:30-00:00
29 Nov 99 00:00
00:00-02:00
02:00
02:00-05:30
02:00-05:30
05:30
05:30-06:00
05:30-06:00
06:00-08:30
06:00-08:00
08:00
08:00-08:30
08:30
08:30-06:00
08:30-09:00
09:00
09:00-10:30
10:30
10:30-11:00
11:00
11:00-13:00
13:00
13:00-14:00
14:00
14:00-16:30
16:30
16:30-17:30
17:30
17:30-18:00
18:00
18:00-22:30
22:30
22:30-23:00
Progress Report
Well K-07C Page 6
Rig Nabors 7ES Date 08 December 99
Duration
Activity
1/2 hr
2hr
3-1/2 hr
3-1/2 hr
1/2 hr
1/2 hr
2-1/2 hr
2hr
21-1/2 hr
1/2 hr
1-1/2 hr
1/2 hr
2hr
lhr
2-1/2 hr
lhr
1/2 hr
4-1/2 hr
1/2 hr
Tail cement pumped
Release DP dart and kick out with 5 bbl water.
Displaced slurry - 150.700 bbl
Displace with rig pumps at 7 bpm.
No losses while displacing cement.
Plug bumped
Pressure up to 3200psi to set hanger and 4200 psi
to set liner top packer.
Circulated at 6800.0 ft Release from hanger.
PU and set LTP mechanically.
Circ cement from hole - est 10 bbl cement back.
Obtained clean returns - 125.00 % hole volume
Pull Drillpipe, 4in O.D.
Pulled Drillpipe in stands to 0.0 ft
At Surface: 0.0 ft
POH with liner running tool. LD tool and cement
head.
Test well control equipment
Serviced Bore protector
Pull wear ring and run test plug.
Test well control equipment (cont...)
Tested BOP stack
No BOPE failures but gas detector system not
working properly.
Pressure test completed successfully - 3500.000 psi
Installed Bore protector
Eqpt. work completed, running tool retrieved
BHA run no. 6
Serviced Top drive
Equipment work completed
Made up BHA no. 6
BHA no. 6 made up
Functioned downhole tools at 185.0 fl
Flow test MWD.
Equipment work completed
Singled in drill pipe to 2500.0 ft
PU 69 its 4" DP
69 joints picked up
Serviced Block line
Line slipped and cut
R.I.H. to 8682.0 ft
Stopped: To pressure test
Circulated at 8682.0 ft
Obtained req. fluid properties - 50.00 %, hole vol.
Circ 1 DP vol for casing test.
Tested Liner - Via string
Pressure test completed successfully - 3000.000 psi
Serviced Top drive
Weld gooseneck bracket on TD. Change out XO and
saver sub. Adjust pipe grabber.
Equipment work completed
R.I.H. to 9065.0 ft
Facility PB K Pad
Date/Time Duration
23:00
23:00-04:00 5 hr
30 Nov 99 04:00
04:00-05:00 1 hr
05:00
05:00-06:00 1 hr
05:00-06:00 1 hr
06:00-06:00 24 hr
06:00-06:30 1/2 hr
06:30
06:30-09:30 3 hr
09:30
09:30-06:00 20-1/2 hr
09:30-06:00 20-1/2 hr
01 Dec 99 06:00-06:00 24 hr
06:00-13:00 7 hr
13:00
13:00-14:30 1-1/2 hr
15-1/2 hr
14:30
14:30-06:00
14:30-06:00 15-1/2 hr
Progress Report
Well K-07C Page 7
Rig Nabors 7ES Date 08 December 99
0Z Dec 99 06:00-18:30 12-1/2 hr
06:00-18:30 12-1/2 hr
Activity
At Top of cement · 9065.0 ft
Drilled installed equipment - Float shoe
Drill shoe track. Had difficulty drilling landing
collar and plugs.
Reduce MW to 9.5 ppg while drilling shoe track.
Completed operations
Circulated at 9191.0 ft
Circ and get MW down to 9.5 ppg for FIT. Calibrate
gas detectors after repairs.
Obtained req. fluid properties - 100.00 %, hole vol.
Drilled to 9207.0 ft
Drill new hole for FIT.
Drilled to 9207.0 ft
Drilled from 9207' to 9212'. Observe well for 15
min, FIT.
BHA run no. 6 (cont...)
Drilled to 9212.0 ft (cont...)
Drilled from 9207' to 9212'. Observe well for 15
min, FIT.
Stopped · To circulate
Circulated at 9212.0 ft
Pmp 80 bbls H20, 40 bbls spacer and displaced to
8.4 ppg Quikdrill-N. Monitor hole and clean possum
belly.
Hole displaced with Water based mud - 100.00 % displaced
Drilled to 9600.0 ft
Drilled building angle from 9600' to 9737'.
AST=5.0 hrs
Drilled to 9600.0 ft
Drilled ahead from 9212' to 9600'. ART= 4.0 hrs
AST=14.0 hfs Drilling ahead turning at report
time.
BHA run no. 6 (cont...)
Drilled to 9600.0 ft (cont...)
Drilled ahead from 9212' to 9600'. ART= 4.0 hrs
AST=14.0 hrs Drilling ahead turning at report
time.
Stopped ' To correlate depth
Circulated at 9737.0 ft
Circulate while evaluate logs and perform
directional calculations. Decision made to drill ahead,
lowered bottom of target.
Obtained bottoms up (100% annulus volume)
Circulated sweep.
Drilled to 10200.0 ft
Drilled from 10,200' to 10,639'. ART= 7 hrs
AST=3.0 hrs
Drilled to 10200.0 ft
Drilled from 9737' to 10200'. AST= 9.0 hrs ART=
5.0 hrs Drilling ahead sliding at report as per
Geologists.
BHA run no. 6 (cont...)
Drilled to 10639.0 ft (cont...)
Drilled from 9737' to 10200'. AST= 9.0 hrs ART=
.~.~J ~nb .t.~,t~n~ afl.au 3~un~ at report as pcr
Facility
Date/Time
03 Dec 99
PB K Pad
Progress Report
Well K-07C Page
Rig Nabors 7ES Date
8
08 Dece~nber 99
18:30
18:30-20:00
18:30-20:00
20:00
20:00-06:00
20:00-01:00
01:00
01:00-03:00
03:00
03:00-04:30
04:30
04:30-05:00
05:00
05:00-05:30
05:30
05:30-06:00
06:00-14:00
06:00-08:30
08:30
08:30-13:00
13:00
13:00-14:00
14:00
14:00-00:00
14:00-14:45
14:45
14:45-15:00
15:00
15:00-17:30
17:30
17:30-18:00
18:00
18:00-22:00
22:00
22:00-23:00
Duration
1-1/2 hr
1-1/2 hr
10hr
5hr
2hr
1-1/2 hr
8hr
2-1/2 hr
4-1/2 hr
lhr
10hr
3/4 hr
1/4 hr
2-1/2 hr
4hr
lhr
Activity Geologists.
Top drive failed - Circulate
Repair
Repaired Top drive
Lubricator pump warning light indicated pump
pressure failure. Trouble shoot, changed screen and
filter, changed oil.
Equipment work completed
BHA run no. 6
Drilled to 10820.0 ft
Drilled from 10,639' to 10,820'. ART=4.5 hfs
Reached planned end of run - Section / well T.D.
Circulated at 10820.0 ft
Circ hi visc sweep and circ hole clean.
Obtained clean returns - 150.00 % hole volume
Pulled out of hole to 9157.0 ft
POH to 9272'. Took check shot, OK. Finish POH to
shoe.
Began precautionary measures
Serviced Block line
Line slipped
R.I.H. to 10820.0 ft
RIH. No hole problems.
On bottom
Circulated at 10820.0 ft
Circ hi-visc sweep and spotted liner running pill
in open hole.
BHA run no. 6 (cont...)
Circulated at 10820.0 ft (cont...)
Circ hi-visc sweep and spotted liner running pill
in open hole.
Obtained clean returns - 200.00 % hole volume
Pulled out of hole to 185.0 ft
POH to shoe. Dropped 2.125" rabbit. Finish POH.
At BHA
Pulled BHA
BHA Laid out
Run Liner, 4-1/2in O.D.
Rigged up Tubing handling equipment
Equipment work completed
Held safety meeting
PJSM on liner running.
Completed operations
Ran Liner to 1795.0 ft (4-1/2in OD)
Ran 43 its 4-1/2", 12.6#, L-80, BTC-m liner.
Stopped: To circulate
Circulated at 1795.0 ft
Circ liner volume while changing handling
equipment.
Broke circulation
Ran Drillpipe on landing string to 9180.0 ft
Stopped: To circulate
Circulated at 9180.0 ft
Circ drill pipe plus liner volume while M/U cement
head.
Facility
Date/Time
04 Dec 99
Progress Report
PB K Pad
Well K-07C Page 9
Rig Nabors 7ES Date 08 December 99
23:00
23:00-00:00
00:00
00:00-04:30
00:00-00:30
00:30
00:30-02:00
02:00
02:00-03:00
03:00
03:00-04:00
04:00
04:00-04:30
04:30
04:30-06:00
04:30-06:00
04:30-06:00
06:00-06:30
06:00-06:30
06:30
06:30-10:30
06:30-10:30
10:30
10:30-11:30
10:30-11:30
11:30
11:30-06:00
11:30-13:00
13:00
13:00-13:30
13:30
13:30-15:30
Duration
lhr
4-1/2 hr
1/2 hr
1-1/2 hr
lhr
1 hr
1/2 hr
1-1/2 hr
1-1/2 hr
1-1/2 hr
1/2 hr
1/2 hr
4 hr
4hr
lhr
lhr
18-1/2 hr
1-1/2 hr
1/2 hr
2hr
Activity
Broke circulation
Ran Drillpipe on landing string to 10820.0 ft
Finish RIH and tagged bottom on depth.
On bottom
Cement: Liner cement
Held safety meeting
Completed operations
Batch mixed slurry - 50.000 bbl
Circulate while batch mix cement.
Batch slurry mixed
Displaced slurry - 50.000 bbl
Pmp 5 bbls 9.0 ppg spacer and tested lines to 4500
psi. Pmp 25 bbls spacer. Pmp 50 bbls 15.8 ppg
cmt. Clear lines and drop plug. Displace with 28
bbls pill and 88 bbls mud. Could not reciprocate when
cement around shoe. CIP 0250 hrs 12/4/99.
Plug bumped
Pressure to 3000 psi to set hanger, 4200 psi to set
packer.
Circulated at 9036.0 ft
Rotate and unsting from hanger/packer. Circ, got
back 10 bbls cmt returns.
Obtained clean returns - 125.00 % hole volume
Cleared Circulating head
L/D cement head.
Equipment work completed
Fluid system
Circulated at 9036.0 ft
Pump sweep and change out mud to seawater.
Circulated at 9036.0 ft
Pump fresh water sweep and changeover well to
seawater.
Fluid system (cont...)
Circulated at 9036.0 ft (cont...)
Pump fresh water sweep and changeover well to
seawater.
Hole displaced with Seawater - 150.00 % displaced
4in. Drillpipe workstring run
Pulled Drillpipe in stands to 0.0 fl
POH and L/D running tool.
At Surface: 0.0 ft
Perform integrity test
Tested Liner
R/U and tested casing to 3500 psi, 30 min. OK.
Pressure test completed successfully - 3500.000 psi
2-3/4in. Perforation assembly workstring run
Rigged up Tubing handling equipment
R/U handling equipment while load perf guns in pipe
shed.
Equipment work completed
Held safety meeting
Completed operations
Rigged up sub-surface equipment - Perforating tools
P/U 2-3/4" perf guns.
Facility
Date/Time
PB K Pad
Progress Report
Well K-07C Page
Rig Nabors 7ES Date
10
08 December 99
15:30
15:30-17:00
17:00
17:00-21:30
21:30
21:30-23:30
23:30
23:30-00:30
05 Dec 99 00:30
00:30-01:30
01:30
01:30-05:00
05:00
05:00-06:00
06:00
06:00-16:30
06:00-09:00
09:00
09:00-10:00
10:00
10:00-11:30
11:30
11:30-16:30
16:30
16:30-06:00
16:30-17:30
17:30
17:30-18:00
18:00
18:00-05:30
06 Dec 99 05:30
05:30-06:00
06:00
06:00-11:30
Duration
1-1/2 hr
4-1/2 hr
2hr
1 hr
lhr
3-1/2 hr
lhr
10-1/2 hr
3hr
lhr
1-1/2 hr
5hr
13-1/2 hr
lhr
1/2hr
11-1/2 hr
1/2 hr
5-1/2 hr
Activity
Equipment work completed
Ran Tubing to 1795.0 ft (2-7/8in OD)
Ran perf guns on 2-7/8" fox tubing. P/U fas fill,
pkr, jars.
Stopped: To change handling equipment
Ran Drillpipe in stands to 10731.0 ft
On bottom
Perforated from 9830.0 ft to 10730.0 ft
Tagged PBTD and set guns on depth. Finish R/U and
test lines to 3500 psi. Close annular and pressure
to 3300 psi to fire guns. Good indication guns
fired.
Interval perforated
Reverse circulated at 8960.0 ft
Open bypass and rev circ two casing volumes. No
loss or gain. Monitor hole, pump pill.
Obtained clean returns - 200.00 % hole volume
Rigged down High pressure lines
Blow down choke and kill lines. R/D surface hoses.
L/D surface equipment.
Equipment work completed
Laid down 4650.0 ft of Drillpipe
Began precautionary measures
Serviced Block line
Line slipped and cut
2-3/4in. Perforation assembly workstring run (cont...)
Laid down 4287.0 ft of 4in OD drill pipe
Stopped: To change handling equipment
Retrieved Retrievable packer
L/D HES packer and tools.
Stopped: To change handling equipment
Laid down 846.0 ft of Tubing
L/D 2-7/8" fox tubing spacer.
Stopped: To change handling equipment
Rigged down sub-surface equipment - Perforating tools
L/D 2-3/4" perf guns. All shots fired OK, 200 psi
underbalance (1888' dry pipe). Perforation
interval 9,830'- 10,030', 10,080'-10,230',
10,300'o10,530', 10,580'-10,730' 4 spf.
Work completed, equipment laid out
Run Gas lift completion, 4-1/2in O.D.
Rigged up Completion string handling equipment
Equipment work completed
Held safety meeting
Completed operations
Ran Tubing to 9040.0 ft (4-1/2in OD)
Ran 216 Jts 4-1/2",12.6#, L-80, IBT tubing, (4)
GLM's, HES "TNT" packer. Spaced out and landed
tubing.
Hanger landed
Serviced Tubing hanger
RILDS. R/U to circulate.
Equipment work completed
Run Gas lift completion, 4-1/2in O.D. (cont...)
Facility
Date/Time
Progress Report
PB K Pad
Well K-07C Page 11
Rig Nabors 7ES Date 08 December 99
06:00-08:00
08:00
08:00-09:30
09:30
09:30-10:30
10:30
10:30-11:30
11:30
11:30-14:00
11:30-14:00
14:00
14:00-14:30
14:00-14:30
14:30
14:30-16:30
14:30-16:30
16:30
16:30-06:00
16:30-19:30
19:30
19:30-20:00
20:00
20:00-21:00
21:00
Duration
2hr
1-1/2 hr
lhr
lhr
2-1/2 hr
2-1/2 hr
1/2 hr
1/2 hr
2 hr
2 hr
13-1/2 hr
3hr
1/2 hr
lhr
Activity
Reverse circulated at 3295.0 ft
Reverse circulate correxit corrosion inhibitor into
annulus.
Hole displaced with Inhibited brine - 100.00 % displaced
Set packer at 9010.0 ft with 4800.0 psi
Dropped ball to set packer. Attempt to pressure
up, sensor not working. Changeout sensor. Pressure
to 4800 psi with HBR to set packer. Bled pressure
off to 3000 psi.
Packer set at 9010.0 ft
Tested Tubing
Held 3000 psi for 30 min tubing test. Had ice plug
in HBR line when bleed off. Thaw line.
Pressure test completed successfully - 3000.000 psi
Tested Permanent packer - Via annulus and string
Pressure test packer and casing to 3000 psi for 30
min. Held OK. Bled off tubing pressure and
sheared RP shear.
Pressure test completed successfully - 3000.000 psi
Fluid system
Freeze protect well - 155.000 bbl of Diesel
Changed lines and pumped 155 bbls diesed into
tubing annulus using HBR. U-tube diesel.
Completed operations
Wellhead work
Installed Hanger plug
Installed TWC and tested to 500 psi.
Eqpt. work completed, running tool retrieved
Nipple down BOP stack
Removed BOP stack
Equipment work completed
Wellhead work
Installed Xmas tree
N/U adaptor and tree and test to 5000psi.
Equipment work completed
Removed Hanger plug
R/U lubricator and pulled TWC.
Equipment work completed
Installed Hanger plug
Installed BPV and tested to 500 psi. Secured well.
Released rig at 2100 hrs, 12/6/99.
Equipment work completed
Rig released for move to NV-18.
North Slope Alaska
Alaska State Plane 4
PBU WOA K Pad
K-07C
Surveyed: 3 December, 1999
SURVEY REPORT
3 January, 2000
Your Ref: AP1-500292104503
Surface Coordinates: 5975163.00 N, 670744.00 E (70° 20' 17.0279" N, 148° 36' 52.1810" W)
Kelly Bushing: 54.66ft above Mean Sea Level
sFae~r~d-sLjra
DRILLING SERVICES
Survey Ref: svy9571
AIL, U~I~I~IJR'¥O~ CO~,tPAN¥
Sperry-Sun Drilling Services
Survey Report for K-07C
Your Ref: API-500292104503
Surveyed: 3 December, 1999
North Slope Alaska
Measured
Depth
(ft)
Incl.
Azim.
Sub-Sea
Depth
(ft)
Vertical
Depth
(ft)
6991.45 42.620 28.803 6223.55 6278.21
6992.00 42,620 28.800 6223.95 6278.61
7008.24 42.930 27.960 6235.88 6290.54
7042.69 42.880 26.200 6261.11 6315.77
7077.20 41.000 24.270 6286.78 6341.44
7107.29 38.650 22.470 6309.89 6364.55
7136.08 36.270 20.630 6332.74 6387.40
7168.74 33.960 18.390 6359.46 6414.12
7200.23 32.570 16.060 6385.79 6440.45
7231.43 31.110 12.680 6412.29 6466.95
7262.37 29.420 11.350 6439.02 6493.68
7292.60 27.130 12.920 6465.64 6520.30
7324.25 25.320 16.700 6494.03 6548.69
7356.72 22.760 20.250 6523.68 6578.34
7385.52 20.550 18.340 6550.45 6605.11
7415.80 17.950 15.080 6579.03 6633.69
7508.10 16.620 7.110 6667.18 6721.84
7600.45 16.620 7.910 6755.67 6810.33
7694.62 16.450 7.970 6845.94 6900.60
7789.30 15.490 11.780 6936.97 6991.63
7881.62 14.870 13.680 7026.07 7080.73
7975.54 14.660 13.600 7116.89 7171.55
8064.13 14.350 13.130 7202.66 7257.32
8160.69 13.890 13.830 7296.30 7350.96
8251.65 13.690 14,470 7384.64 7439.30
Local Coordinates
Northings Eastings
(ft) (ft)
1987.92 N 809.59 E
1988.24 N 809.76 E
1997.95 N 815.01 E
2018.83 N 825.68 E
2039.68 N 835.52 E
2057.37 N 843.17 E
2073.65 N 849.61E
2091.35 N 855.89 E
2107.84 N 861.01E
2123.78 N 865.10 E
2139.03 N 868.35 E
2153.03 N 871.36 E
2166.54 N 874.92 E
2179.09 N 879.09 E
2189.12 N 882.61E
2198.67 N 885.49 E
2225.51 N 890.83 E
2251.69 N 894.28 E
2278.24 N 897.98 E
2303.89 N 902.42 E
2327.47 N 907.74 E
2350.73 N 913.38 E
2372.32 N 918.51 E
2395.22 N 924.00 E
2416.25 N 929.30 E
Global Coordinates
Northings Eastings
(ft) (ft)
5977168.83 N 671508.11 E
5977169.16 N 671508.28 E
5977178,98 N 671513.30 E
5977200.10 N 671523,50 E
5977221.18 N 671532.86 E
5977239.03 N 671540,11 E
5977255.46 N 671546.17 E
5977273.30 N 671552.05 E
5977289.90 N 671556.79 E
5977305.93 N 671560.52 E
5977321.25 N 671563.42 E
5977335.31 N 671566.11 E
5977348.91 N 671569.36 E
5977361.54 N 671573.24 E
5977371.65 N 671576.53 E
5977381.26 N 671579.20 E
5977408.21N 671583.92 E
5977434.47 N 671586.78 E
5977461.09 N 671589.87 E
5977486.84 N 671593.73 E
5977510.53 N 671598.51 E
5977533.92 N 671603.62 E
5977555.62 N 671608.26 E
5977578.64 N 671613.22 E
5977599.78 N 671618.04 E
Dogleg
Rate
(°/100ft)
0.426
3.998
3.481
6.606
8.698
9.134
8.098
5.996
7.385
5.876
7.964
7.779
9.052
8.053
9.288
2.939
0.248
0.181
1.501
0.861
0.225
0.374
0.508
0.277
Alaska State Plane 4
PBU_WOA K Pad
Vertical
Section
(ft)
Comment
1858.60
1858.90
1867.79
1887.02
1906.33
1922.81
1938.05
1954.73
1970.37
1985.60
2000.26
2013.72
2026.62
2038.48
2047.93
2057.00
2082.85
2108.32
2134.11
2158.92
2181.55
2203.82
2224.50
2246.44
2266.55
Tie-on Survey
Window Point
Continued...
3 January, 2000 - 11:40 - 2 - DrillQuest 1,05.04e
Sperry-Sun Drilling Services
Survey Report for K-07C
Your Ref'. AP1-500292104503
Surveyed: 3 December, 1999
North Slope Alaska
Measured
Depth
(ft)
Incl.
Azim.
Sub-Sea
Depth
(ft)
Vertical Local Coordinates 'Global Coordinates
Depth Northings Eastings Northings Eastings
(ft) (ft) (ft) (ft) (ft)
8345.83 12.510 14.400 7476.36 7531.02
8441.31 11.090 14.340 7569.82 7624.48
8533.73 12.460 11.700 7660.30 7714.96
8626.95 11.060 10.880 7751.56 7806.22
8720.24 10.190 10.840 7843.25 7897.91
8813.53 9.270 11.780 7935.19 7989.85
8907.45 8.310 12.540 8028.01 8082.67
9000.77 7.510 13.570 8120.44 8175.10
9095.63 6.660 11.410 8214.58 8269.24
9145.12 6.400 10.760 8263.75 8318.41
9194.52 6.270 10.970 8312.84 8367.50
9226.45 6.200 11.120 8344.59 8399.25
9258.28 6,090 349,820 8376.24 8430.90
9285.35 8.240 321.890 8403.10 8457.76
9315.66 12.410 310.190 8432.92 8487,58
9347.83 17.000 305.580 8464.03 8518.69
9379.80 21.590 298.740 8494.20 8548.86
9413.05 26.170 296.940 8524.59 8579.25
9443.33 30.220 291.480 8551.28 8605.94
9470.12 33.820 285.300 8573.99 8628.65
9503.50 37.800 282.850 8601.06 8655.72
9532.83 40.970 279.150 8623.73 8678.39
9563.06 42.560 271.330 8646.29 8700.95
9594.20 43.350 263.820 8669.10 8723.76
9626.54 43.790 259.940 8692.53 8747.19
2436.92 N 934.62 E
2455.83 N 939.47 E
2474.21 N 943.69 E
2492.84 N 947.42 E
2509.73 N 950.66 E
2525.19 N 953.75 E
2539.22 N 956.77 E
2551.73 N 959.66 E
2563.15 N 962.20 E
2568.67 N 963.29 E
2574.03 N 964.31E
2577.43 N 964.98 E
2580.78 N 965.01E
2583.72 N 963.56 E
2587.53 N 959.73 E
2592.50 N 953.26 E
2598.06 N 944.30 E
2604.32 N 932.39 E
2610.14 N 919.34 E
2614.58 N 905.87 E
2619.31N 886.92 E
2622.84 N 868.66 E
2624.65 N 848.64 E
2623.75 N 827.47 E
2620.60 N 805.41 E
5977620.57 N 671622.89 E
5977639.59 N 671627.31 E
5977658.06 N 671631.11 E
5977676.76 N 671634.41E
5977693.73 N 671637.27 E
5977709.25 N 671640.00 E
5977723.35 N 671642.70 E
5977735.92 N 671645.31E
5977747.40 N 671647.59 E
5977752.94 N 671648.55 E
5977758.32 N 671649.45 E
5977761.74 N 671650,04 E
5977765.08 N 671650.00 E
5977767.99 N 671648.48 E
5977771.72 N 671644.56 E
5977776.54 N 671637.98 E
5977781.88 N 671628.89 E
5977787.88 N 671616.85 E
5977793.40 N 671603.67 E
5977797.53 N 671590.10 E
5977801.82 N 671571.05 E
5977804.94 N 671552.71 E
5977806.30 N 671532.66 E
5977804.91 N 671511.51 E
5977801.26 N 671489.53 E
Dogleg
Rate
(°/100ft)
1.253
1.487
1.592
1.512
0.933
1.001
1.030
0.871
0.939
0.546
0.267
0.225
7.131
14.895
15.332
14.713
15.980
13.946
15.846
18.156
12.671
13.446
18.006
16.622
8.379
Alaska State Plane 4
PBU_WOA K Pad
Vertical
Section
(ft)
Comment
2286.30
2304.37
2322.00
2339.94
2356.23
2371.13
2384.61
2396.61
2407.57
2412.90
2418.06
2421.34
2424.65
2427.77
2432.07
2437.87
2444.60
2452.43
2459.98
2466.22
2473.49
2479.49
2484.02
2486.02
2485.91
Continued...
3 January, 2000 - 11:40 - 3 - DrillQuest 1.05,04e
Sperry-Sun Drilling Services
Survey Report for K-07C
Your Ref: API-500292104503
Surveyed: 3 December, 1999
North Slope Alaska
Measured
Depth
(ft)
Incl.
Azim.
Sub-Sea
Depth
(ft)
Vertical Local Coordinates Global Coordinates
Depth Northings Eastings Northings Eastings
(ft) (ft) (ft) (fi) (ft)
9656.66 48.700 260.090 8713.36 8768.02
9687.26 53.610 258.180 8732.55 8787.21
9719.43 58.590 257.650 8750.48 8805.14
9750.92 64.500 255.570 8765.48 8820.14
9784.01 70.130 254.480 8778.24 8832.90
9814.71 75.680 252.890 8787.26 8841.92
9843.69 81.970 251.180 8792.87 8847.53
9875.61 88.000 251.860 8795.66 8850.32
9906.61 89.290 254.300 8796.40 8851.06
9938.21 89.350 255.250 8796.77 8851.43
9967.15 89.070 255.010 8797.17 8851.83
9999.86 88.900 253.420 8797.75 8852.41
10031.42 87.750 255.180 8798.67 8853.33
10065.27 88.190 253.770 8799.87 8854.53
10096.54 88.900 253.770 8800.67 8855.33
10123.07 89.870 253.770 8800.95 8855.61
10159.18 87.580 255.890 8801.75 8856.41
10190.41 87.220 255.710 8803.17 8857.83
10216.86 87.320 255.610 8804.43 8859.09
10251.13 87.580 255.180 8805.96 8860.62
10281.92 88.370 255.360 8807.04 8861.70.
10309.75 89.380 255.700 8807.59 8862.25
10344.12 87.840 254.830 8808.42 8863.08
10374.38 87.660 256.710 8809.61 8864.27
10404.59 88.430 256.030 8810.64 8865.30
2616.83 N 783.99 E
2612.32 N 760.60 E
2606.73 N 734.50 E
2600.31N 707.58 E
2592.42 N 678.10 E
2584.17 N 649.96 E
2575.40 N 622.93 E
2565.33 N 592.78 E
2556.31 N 563.14 E
2548.01 N 532.65 E
2540.59 N 504.68 E
2531.69 N 473.21E
2523.15 N 442.84 E
2514.10 N 410.25 E
2505.36 N 380.23 E
2497.95 N 354.76 E
2488.50 N 319.93 E
2480.85 N 289.68 E
2474.30 N 264.08 E
2465.67 N 230.95 E
2457.85 N 201.19 E
2450.90 N 174.25 E
2442.16 N 141.02 E
2434.72 N 111.72 E
2427.61 N 82.38 E
5977797.00 N 671468.21E
5977791.96 N 671444.92 E
5977785.78 N 671418.95 E
5977778.75 N 671392.19 E
5977770.18 N 671362,90 E
5977761,30 N 671334.95 E
5977751.92 N 671308.12 E
5977741.16 N 671278.22 E
5977731.47 N 671248.78 E
5977722.48 N 671218.49 E
5977714.42 N 671190.70 E
5977704.81 N 671159.44 E
5977695.58 N 671129.27 E
5977685.79 N 671096.90 E
5977676.37 N 671067.09 E
5977668.38 N 671041,79 E
5977658.14 N 671007.18 E
5977649.80 N 670977.12 E
5977642.68 N 670951.67 E
5977633.29 N 670918.75 E
5977624.79 N 670889.18 E
5977617.23 N 670862.40 E
5977607.73 N 670829.38 E
5977599.64 N 670800.25 E
5977591.86 N 670771.08 E
Dogleg
Rate
(°/100ft)
16.305
16.765
15.540
19.644
17.283
18.743
22.462
19.010
8.901
3.012
1.274
4.888
6.660
4.361
2.271
3.656
8.641
1.289
0.534
1.465
2.631
3.829
5.146
6.236
3.400
Alaska State Plane 4
PBU_WOA K Pad
Vertical
Section
(ft)
Comment
2485.10
2483.84
2481.87
2479.18
2475.40
2471.08
2466.08
2460.23
2455.34
2451.29
2447.76
2443.25
2438.94
2434.43
2429.87
2426.01
2421.42
2417.97
2414.99
2410.96
2407.28
2404.07
2399.96
2396.60
2393.57
Continued...
3 January, 2000- 11:40 -4- DrillQuest 1.05.04e
Sperry-Sun Drilling Services
Survey Report for K-07C
Your Ref: A PI-500292104503
Surveyed: 3 December, 1999
North Slope Alaska
Measured Sub-Sea Vertical Local Coordinates
Depth Incl. Azim. Depth Depth Northings Eastings
(ft) (ft) (ft) (ft) (ft)
Global Coordinates
Northings Eastings
(ft) (ft)
10466.06 86.610 257.300 8813.30 8867.96 2413.45 N 22.62 E 5977576.34 N
10498.61 85.630 257.440 8815.50 8870.16 2406.35 N 9,07W 5977568.51 N
10529.31 85.810 256.590 8817.80 8872.46 2399.47 N 38.90W 5977560.96 N
10560.23 85.990 257.470 8820.01 8874.67 2392.54 N 68.95W 5977553.35 N
10591.16 86.260 257.120 8822.10 8876.76 2385.76 N 99.06W 5977545.88 N
10622.89 86.340 257.300 8824.14 8878.80 2378.75 N 129.93W 5977538.17 N
10653.96 86.700 258.180 8826.03 8880.69 2372.16 N 160.24W 5977530.90 N
10685.12 86.700 258.530 8827.82 8882.48 2365.88 N 190.71W 5977523.93 N
10717.22 87.220 257.650 8829.53 8884.19 2359.27 N 222.07W 5977516.60 N
10746.40 87.310 258.710 8830.92 8885.58 2353.30 N 250.60W 5977509.98 N
10772.81 88.020 258.710 8832.00 8886.66 2348.13 N 276.48W 5977504.23 N
10820.00 88.020 258.710 8833.63 8888.29 2338.90 N 322.73W 5977493.94 N
All data is in feet unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference.
670711.66 E
670680.14 E
670650.48 E
670620.59 E
670590.65 E
670559.94 E
670529.79 E
670499.47 E
670468.27 E
670439.88 E
670414.13 E
670368.10 E
Dogleg
Rate
(°/100ft)
3.609
3.041
2.823
2.898
1.427
0.620
3.055
1.121
3.181
3.642
2.688
0.000
Alaska State Plane 4
PBU_WOA K Pad
Vertical
Section
(ft)
Comment
2387.70
2385.00
2382.26
2379.51
2376.9O
2374.18
2371.80
2369.74
2367.48
2365.46
2363.88
2361.06
Projected Survey
The Dogleg Severity is in Degrees per 100ft.
Vertical Section is from Well Reference and calculated along an Azimuth of 352.144° (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 10820.00ft.,
The Bottom Hole Displacement is 2361.06ft., in the Direction of 352.144° (True).
Continued...
3 January, 2000 - 11:40 - 5- DrillQuest 1.05.04e
Sperry-Sun Drilling Services
Survey Report for K-07C
Your Ref: API-500292104503
Surveyed: 3 December, 1999
North Slope Alaska
Alaska State Plane 4
PBU_WOA K Pad
Comments
Measured
Depth
(ft)
6991.45
6992.00
10820.00
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
6278.21 1987.92 N 809.59 E
6278.61 1988.24 N 809.76 E
8888.29 2338.90 N 322.73 W
Comment
Tie-on Survey
Window Point
Projected Survey
3 January, 2000- 11:40 -6- DrillQuest 1.05.04e
GeoQuest
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrle
NO. 121130
Company:
Field:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Prudhoe Bay (Cased Hole)
1/26/o0
Well Job # Log Description Date Blueline Sepia Color CD
Prints
D-33 LEAK DETECTION LOG/PSP 000108 1 1
K-07 (~- CBL 991123 i 1
X-29 UL ~ C._.. PSP INJECTION pROFILE 000118 1 1
.......
Z-03 PRODUCTION PROFILE 000109 1 1
,,,
,
,,
....
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska)Inc.
Petrotectnical Data Center MB3-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
Date Delivered:
RECEIVED
FEB 04 2000
Alaska Oil & G['~ t.:o,qs. I5om.~issioll
z:m:Imra.cl~
Schlumberger GeoQuest
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATrN: Sherrie '--
Received ~~ '._ ":
MEMORANDUM
TO'
State of Alaska
Alaska Oil and Gas Conservation Commission
Robert Christenso~'(~ DATE' November 29, 1999
Chairman
THRU-
Blair Wondzell, ~~
P. I. Supervisor ((/a,¢fg¢-
FROM' JpO_h. n .Crisp?/¢~ SUBJECT:
e[roleum Ir~pector
FILE NO:
BOP Test Nabors 7es. DOC
BOP Test
Nabors 7es
BPX PBU K-O7C
PTD 199-109
November 29,1999: I witnessed weekly BOPE test on Nabors Rig 7es drilling
BP× well K-07C in the PBU.
The Rig was ready to test shortly after my arrival on location. BOP stack
components tested very well. The stroke counter on the super choke panel was
not working. I requested one lighter than air & one heavier than air gas detector
sensor be tested with sample test gas. The gas detector system failed to
function. Drilling Foreman assured me they would not drill out of the casing until
system was tested & operational.
SUMMARY: I witnessed weekly BOP test on Nabors 7es. Two failures
witnessed. Test time 5 hours.
Attachments: BOP Nabors 7es 11-29-99jc
cc;
NON-CONFIDENTIAL
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report
OPERATION: Drlg: X Workover:
Drlg Contractor: Nabors Rig No. 7es PTD #
Operator: BPX Rep.:
Well Name: K-07C Rig Rep.:
Casing Size: 7"Liner Set @ 9189' Location: Sec.
Test: Initial Weekly X Other
199-109
DATE: '11/29/99
Rig Ph.# 559-4103
Dick Maskefl
R/chard Larkin
04 T. 11N R. 14E Meridian UM
MISC. INSPECTIONS:
Location Gen.: OK
Housekeeping: OK (Gen)
PTD On Location Yes
Standing Order Posted Yes
Well Sign Yes
Dd. Rig OK
Hazard Sec. Yes
BOP STACK:
Annular Preventer
Pipe Rams
Lower Pipe Rams
Blind Rams
Choke Ln. Valves
HCR Valves
Kill Line Valves
Check Valve
Quan.
Test Press. P/F
250/3,500 P
25O/3,5OO P
250/3,500 P
25O/3,5OO P
25O/3,5OO P
250/3,500 P
250/3,500 P
N/A
MUD SYSTEM: Visual Alarm
Trip Tank P p
Pit Level Indicators P p
Flow Indicator P p
Meth Gas Detector OK F
H2S Gas Detector OK N/T
FLOOR SAFETY VALVES:
Upper Kelly/IBOP
Lower Kelly / IBOP
Ball Type
Inside BOP
Test
Quan. Pressure P/F
1 250/3,500 P
250/3,5OO P
250/3,500 P
25O/3,5O0 P
CHOKE MANIFOLD:
No. Valves
No. Flanges
Manual Chokes
Hydraulic Chokes
Test
Pressure P/F
14 250/3,500 P
33 250/3,500 P
1 P
Functioned
Functioned
ACCUMULATOR SYSTEM:
System Pressure
Pressure After Closure
200 psi Attained After Closure
System Pressure Attained
Blind Switch Covers: Master:
Nitgn. Btl's:
4 Bfls. ~ 2150
2,900
1,750
minutes 32 sec.
minutes 0 sec.
OK Remote: OK
Psig.
Number of Failures: 2 ,Test Time: 5.0 Hours. Number of valves tested 20 Repair or Replacement of Failed
Equipment will be made within Prior to DO days. Notify 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. I. Supervisor at 279-1433
REMARKS:
Good BOPE test. Rig housekeeping is excellent. Pump stroke counter on super choke panel failed test.
Gas detector system failed to function when exposed to sample test gas. The gas detector system will be repaired & tested
before dr/fling out of cased hole. Bope stack has second mud cross located beneath lower pipe rams. One side of cross ~
has blind flange, the other side has 2 valves that were tested with BOPs. Choke manifold tested while POOH AFTER cement finer.
Distribution:
or/g-Well File
c - Oper./Ri9
C- Database
c - Trip Rpt File
c - Inspe¢t.~,lL (Rev. 12/94)
STATE WITNESS REQUIRED?
YES X NO
24 HOUR NOTICE GIVEN
YES X NO
RRB hhh
Waived By:
Witnessed By: John Crisp
~ 7ES 11-29-99jc
TONY KNO WLES, GO VERNOR
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001PORCUPINE DRIVE
ANCHORAGE. ALASKA 99501-3192
PHONE: (9071 279-1433
FAX: (907/276-7542
November 10. 1999
Anthony S. Bunch
Drilling Superintendent
BP Exploration (Alaska) Inc.
P O Box 196612
Anchorage AK 99519-6612
Rc.'
Prudhoe Bas-' Unit K-07C
BP Exploration (Alaska) Inc.
Permit No: 199-109
Sur Loc: 2041'SNL. 473'EWL. Sec. 04. TI 1N. RI4E. UM
Btmhole Loc. 289'FSL. 186'EWL. Sec. 33. T12N. R14E. UM
Dear Mr. Bunch:
Enclosed is the approved application for permit to rcdrill the above referenced well.
The permit to redrill does not exempt you from obtaining additional permits required by law from
other governmental agencies, and does not authorize conducting drilling operations until all other
required permitting determinations are made.
Bloxvout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035.
Sufficient notice (approximately 24 hours) must be given to allow a representative of the
Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given
' ~'troleum field inspector on the North Slope pager at 659-3607.
David W. J'o,,~nston
Commissione¥,~_~
BY ORDER OF THE COMMISSION
dlf/Enclosures
CC;
Department of Fish & Game. Habitat Section w/o encl.
Department of Environmental Conser~'ation w/o encl.
· -~. STATE OF ALASKA
ALASK _)IL AND GAS CONSERVATION COl
PERMIT TO DRILL
2O AAC 25.OO5
.ISSION
la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil
[] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
BP Exploration (Alaska) Inc. Plan KBE = 56' Prudhoe Bay Field / Prudhoe
3. Address 6. Property Designation Bay Pool
P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028300
4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025)
2041' SNL, 473' EWL, SEC. 04, T11N, R14E, UM Prudhoe Bay Unit
At top of productive interval 8. Well Nt~'~ber Number 2S100302630-277
1313' NSL, 2268' EWL, SEC. 33, T12N, R14E, UM K-07C
At total depth 9. Approximate spud date Amount $200,000.00
289' FSL, 186' EWL, SEC. 33, T12N, R14E, UM 11/10/99
12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
ADL 028299, 186' MD ....I No Close Approach 2560 10862'MD / 8790' TVDss
16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)}
Kick Off Depth 7015' MD Maximum Hole Angle 90° Maximum surface 2395 psig, Attotal depth (TVD) 8800'/3275 psig
18. Casing Program Specifications Setting Depth
Size Top Bottom Quantity of Cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
8-1/2" 7" 26# L-80 BTC-M 2360' 6855' 6116' 9215' 8325' 210 sx Class 'G'
6-1/8" 4-1/;;';''12".'~# L-80 IBT-M 1797' 9065' 8177' 10862' 8790' 242 sx Class 'G'
,
I
19. To be completed fo~"Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured 10530 feet Plugs (measured) ;:,:'-,../
true vertical 8953 feet
Effective depth: measured 10470 feet Junk (measured) '*~ ~':ff' 0ii ~, r.~,.,o r.0r~s
true vertical 8947 feet ,:~.,-,:
Casing Length Size Cemented MD TVD
Structural
Conductor 110' 20" x 30" 8 cu yds Concrete 110' 110'
Surface 2709' 13-3/8" 3264 cu ft PF 'E', 465 cu ft PF '11' 2709' 2709'
Intermediate
Production 9680' 9-5/8" 2119 cu ft Class 'G', 133 cu ft PF 'C' 9680' 8453'
Liner 830' 7" 301 cu ft Class 'G' 9408' - 10238' 8211' - 8882'
CTD Liner 2110' 2-7/8" 67 cu ft Class 'G' 8420' - 10530' 7361' - 8953'
Perforation depth: measured Open: 10330' - 10350', 10380' - 10425'
Sqzd: 10300'-10330', 10350'-10354', 10425'-10432' ORIGINAL
true vertical Open: 8848'- 8854', 8863'- 8875'
Sqzd: 8838'- 8848', 8854'- 8855', 8875' - 8876'
20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Prog'ram
[] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements
.......
Contact Engineer Name/Number: B~an McLeflan, 564-5516 Prepared By Name/Number: Michael Wilfiams, 564-4657
21. I hereby certify that the f,~rego. Qjjzg. is true a3:zd-c.o_rrect to the best of my knowledge
Signed ~'~~~~ -~:. : ~B / /~
Anthony S. Bunch -- Title Drilling Superintendent Date
"'%\-----~' Commission Use Only
Permit Number APl Number I Approval Date I See cover letter
//~4'~-*~/"¢/'~_/~ 50-029-21045-03I /'~/'-~ /~'-- ~; ~'I for other requirements
Conditions of Approval: Samples Required [] Yes ..1~o Mud Log Required ~.es
Hydrogen Sulfide Measures ~'1¢es [] No Directional Survey Required ~'res I--I No
Required Working Pressure for BOPE []2K; [] 3K; []4K; [~5K; [] 10K; [] 15K
Other: ~--~OO ~'~ ~,'b~' ~-~.~k-.
di-iglrlal Signed By by order of
Approved By t").2. Vid W.._lohrl.~i.,r,' *r,: Commissioner the commission Date
Form 10-401 Rev. 12-01-85
Submit In Triplicate
[Well Name: [K-07C
Well Plan Summary
[Type of Well (producer or injector): I Producer I
Surface Location:
Target Start:
Total Depth
2041'FNL, 473'FWL, Sec. 4, T11N, R14E
X=670744 Y=5975163 Z--26.21'ASL
568'FSL, 1086'EWL Sec. 33, T12N, R14E
X=671291 Y=5977786 Z=8765'TVDss
298'FSL, 186'EWL, Sec. 33, T12N, R14E
X =670398 Y=5977495 Z= 8790' TVDss
I AFE Number: [4P1330
I Rig: [ Nabors 7ES ]
Estimated Start Date: I 11/10/99
IOperating days to
complete:
27
IUD 110,862' [
I TVDss: 18790'
I KBE: 156'
I Well Design (conv., slim hole, etc.):
Horizontal Sidetrack w/drlg liner
Objective: Rig will sidetrack out of existing 9-5/8 in West Sak formation,
directionally drill 8-1/2" hole to top Sag River, run and cement 7" drlg
liner, drill out in 6-1/8" hole and thru (1) Z1 target, TD at 10,862' MD.
Run, cmt and test 4 1/2" L80 solid liner, perf. -800' of interval, and
complete with 4 ½", L80 tbg, (5) GLM's and WOA tail assy.
Formation Markers
Formation Tops MD TVD(ss) Comment
WS 1/W.SAK inside csg. 6203
KOP 7015 6240
CM3/K12 7229 6407
THRZ 8474 7594
LCU 8681 7798
TJD 8808 7924
TJA 9112 8224
Sag River 9205 8315
7" drilling liner 9215 8325 Set 7" just in top of Sag River
Shublik 9250 8360
Top Sad 9288 8397
Zone 3 9389 8497
Zone 2 9456 8560
CGOC 9635 8700
Zone 1 9662 8715
Target 1 9857 8765 Geological Target #1
TD 10862 8790 Run and cmt 4-1/2 prod liner at TD
Casing/Tubing Program:
Hole Csg/ Wt/Ft Grade Conn Length Top Btm
Size Tbg MDfrVDss MDfrVDss
O.D.
8-1/2" 7" 26# L-80 BTCM 2360' 6855'/6116' 9215'/8325'
6 -1/8" 4 1/2" 12.6# L-80 IBT 1797' 9065'/8177' 10862'/8790'
liner Mod
Tubing 4-½" 12.6# L-80 IBT 9037' 28'/-27.6' 9065'/8177'
Mod
Logging Program:
l Open Hole Logs:
I Cased Hole Logs
7ES Drilling section: MWD/GR from KOP 7015' to 8-1/2" hole TD
at 9215' MD.
MWD/GR in 6-1/8" hole from 7" liner to TD at 10,862'MD.
MADD pass as per Geologist request.
Sample catchers and rig site geologist on site before TD of 8-1/2"
hole.
Open Hole: DPC Log only if LWD logs of poor quality.
None
Mud Program:
Special design
considerations
Drill from KOP to TD of 8-1/2" with Baroid LSND mud.
Drill 6-1/8" hole with QuikdrilN Polymer system.
Density LSRV PV YP Ca++ pH
(ppg) (cps)
10.2 LSND 10 15
10.3 LSND 12 15
8.3 < 12000 5- 8 20-25 < 100 9.0-9.5
to to to
8.5+ < 12000 5- 8 20-25 < 100 9.0-9.5
Directional:
KOP:
Maximum Hole
Angle:
Surface Shut-in
Close Approach
Well:
Point to point
separation
1) 7015' MD, drill out of 9-5/8 "casing via 40' section mill
window, drop and turn to 13° angle and 12° azimuth, hold
to 8-1/2" TD at Sag River ('MD)
In'6-1/8" interval build and turn angle at 20°/100' to 90°
angle and 256 ° azimuth through targets. TD of interval is
at 10862'MD, 8790'TVDss
90°
No wells will need to be shut-in and de-pressurized
before rig moves on and off of the well. Management of
change form to be filled out to allow close approach
There are no identified close approach wells other than the
original wellbore, which departs quickly after kickoff from
the planned sidetrack path.
Cement Data:
Casing/Liner Lead: Tail: Sxs/Wt/Yield Comments
Sxs/WffYield
P&A Cmt 24/15.8/1.16 Class G cement to
cover from 45' below
bottom perf
to approx. 680' above
top perf in 2-7/8" liner
Kickoff Plug 118/17/0.99 Class G from 100'
below to 200' above
window
7", 26#, L-80 Liner 124/11.0/3.33 86/15.8/1.16 Class G cement
Tail w/30% excess,
lead w/50% excess,
TOC 200' above liner
top w/DP in hole
4-1/2", 12.6~, L-80 242/15.8/1.16 Class "G", 50% excess
liner Shoe at 10786' OH + 200' above liner
MD Liner top top w/DP in hole
@9034'MD
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 and BOPE system schematics on file with AOGCC.
Bottom hole pressure is 3275 psi at 8,800' TVDss = 7.16 ppg EMW
Maximum shut-in casing pressure is 2395 psi (assumes 0.1 psi/ft gas gradient to
surface).
Planned BOPE test pressure is .~0'psi on the K-07C sidetrack
NO ANNULAR INJECTION IN THIS WELL.
K-07C Class II drilling wastes will be disposed at DS-4 grind and inject facility. If Class I wastes
are generated, they will be taken to Pad 3 disposal site.
Contacts
Name Office Home Pager
Bryan McLellan
Jim Smith
Tony Bunch
Tracy Love
Gene Roberts
Mike May
Drilling Eng. 564-5516 274-9055
Drilling Eng. 564-5026 345-8660
Drilling Supt. 564-5219 348-6683
Geologist 564-5033 349-4592
Pad Engr 564-5475 562-3998
Geophysicist 564-4050 348-0324
275-4015
275-3703
229-5712
Drilling Discussion
"
........ :! ','.; ,.; ~,.:,
':' ":./
,~.-. ~ .
The proposed horizontal sidetrack will t~get an 800' horizontal section in Zone 1.
DRILLING HAZARDS AND CONTINGENCIES
Always have two levels of tested isolation before NU/ND.
SURFACE CLOSE APPROACH WELL SHUT-INS
There are no adjacent wells which will require shut in for rig move in or move out. Two wells, K-09A
and K-10 will require dispensation for close approach during the rig move. Careful coordination with
any ongoing pad or facility operations or activities will be initiated prior to commencing the rig move
per ASH procedures.
DRILLING CLOSE APPROACH WELL SHUT-INS
No shut-ins identified on directional well plan Wp gO due to close approach requirements. The only
close approach is to the original wellbore, K-07, which rapidly departs from the sidetrack K-07C.
PORE PRESSURE
The pore pressure in Colville/Kingak interval of the 8-1/2" hole section is expected to be near 9.9 ppg,
a 10.2 ppg system will be used to drill the interval to combat shale instability.
The pore pressure in Zone 1 (in 6-1/8" interval) is expected to be near 7.2 ppg EMW. 8.3 - 8.5 ppg
mud will be used drilling Zone 1. The overlying Sag River and Shublik formations should be at similar
pressure, the 8.3-8.5 ppg mud will provide sufficient overbalance to the reservoir pressure.
HOLE PROBLEMS
No major hole problems are expected, Shale drilling practices will be employed while drilling 8-1/2"
hole section through the Kingak. The well path does not intersect any known faults. Lost circulation is
not anticipated.
H~S: K Pad is not an H2S Pad
The highest reported level of H2S on K pad is 18ppm on K-13 based on data through 4/1998.
There have been incidents of H2S on other pads which involved circulation of annular fluids from the
wellbore. H2S precautions will be in effect at all times. These include (but are not limited to):
· Regular H2S drills (minimum of two per week)
· Proper training of all permanent onsite personnel, unescorted visitors and temporary
onsite personnel;
· H2S monitors with both audible and visual alarms;
· Access to 5-minute emergency escape air packs;
· Personal H2S monitors;
· Functional wind indicator;
· Posted evacuation routes (minimum of two);
· Muster points in designated safe areas;H_H_z_~S_S;
· Functional communications between rig camp and rig floor.
Casing Shoe Kick Tolerance
The smallest kick tolerance for the 8-1/2" hole interval below 9-5/8" casing at the KOP is calculated as
34.7 bbls influx assuming a swabbed gas influx from the Sag River at a depth of 9184'MD with 10.2
ppg mud in the hole and 9.5 ppg pore pressure in the Sag River. Expected pore pressure in the Sag is
7.46 ppg.
The smallest kick tolerance for the 6-1/8" interval drilled below 7" casing is calculated as infinite
influx assuming a swabbed gas influx from Z1 at 10,862' MD. Based on 8.4 ppg MW (8.0 ppg
regervoir pore preggure), and min. frac at 7" shoe of 10.2 ppg.
NORM (Naturally Occurring Radio Active Material) Precautions -
Although very rare, some tubing strings pulled from Prudhoe Bay wells have exceeded what the industry
has defined as "safe" levels of background NORM. The current standard is 0.05 mRem/hr.
Have NORM inspectors on site while POH with the completion. If the background NORM level
exceeds 0.05 mRem/hr, contact Stores Drilling Materials. Mark and store the contaminated material
away from any activity on the pad. Stores Drilling Materials will collect the material and dispose of
properly.
Well Overview and Program:
K-07B was completed by coil tubing drilling in April of 1997 in zone 1. The well immediately went to high GOR
and has been cycled on a 3 on/12 off schedule since October of 1997. The decision has been made to
abandon K-07B and sidetrack in an attempt to increase oil production and decrease GOR.
The K-07B horizontal sidetrack (K-07C) is intended to access additional reserves utilizing a horizontal well
path in the Ivishak Zone 1. Nabors 7ES is expected to move to K-07B on/about November 10, 1999 after
completing the DS 5-16B sidetrack.
The objective of the pre-rig work is to ascertain the condition of the well head and tree presently on the well; P
& A open perforations with 15.8 ppg cement from 10,470' to 9,650' MD, cut the 5-1/2" tubing and test the 9
5/8" casing.
The drilling objective of K-07C is to pull the existing 5-1/2" tubing, place a bridge plug in the 9-5/8" casing
above the tubing cut at 7,300 MD, and section mill through 9-5/8" casing into the West Sak formation, then
directionally drill to the top of the Sag River where a 7" drilling liner will be set. The well will be extended in 6-
1/8" hole size to access the Zone I Ivishak targets. At TD a 4-1/2" production liner will be run and cemented
and the well completed with 4-1/2" production tubing.
Estimated pore pressure at 8800' TVDss is 3275 psi = 7.16 ppg mud weight. The maximum anticipated
surface pressure is 2395 psi based on a full column of gas at 0.1 psi/ft.
Pre-Riq Operations:
NO WORK MAY BEGIN UNTIL AN APPROVED AOGCC SUNDRY PERMIT IS
RECEIVED.
1. Test the 9-5/8" casing packoff and tubing hanger packoff on the McEvoy wellhead to 5000 psi. Cycle
Iockdown screws (one at a time) and identify any that are broken or damaged.
.
RU Coil Tubing. Lay in cement (5 bbls, Class G, 15.8 ppg, yield = 1.17 ft3/sk, TT '- 04:20 hrs) from TD @
10,470' MD to place TOC above TSAD at 9,650' MD (8362' TVDss). Circulate out excess cement.
Perforations are from 10,380' to 10,425' MD. With TOC at 9,650' MD, there will be 730' of cement inside
2-7/8" casing above the top perforations.
3. Tag and pressure test cement per AOGCC regulations.
.
Cut 5-1/2" tubing in the middle of any full joint of tubing that is near 7,300' MD. The depth of this cut is not
critical since KOP will be at 7,015' MD. Run a tubing punch to perforate tubing just below planned tubing
cut depth prior to running chemical cut to ensure that pressure is equalized between tubing and inner
annulus.
.
Pressure test 9-5/8" inner annulus to 3000 psi. Ensure that there is communication between the tubing ID
and the casing/tubing annulus before pressure testing annulus.
6. Circulate the well to seawater from the tubing cut point and freeze protect the well. Set BPV.
7. FAX all reports to Bryan McLellan at fax number 564-5193.
Rig Sidetrack Procedure
o
9.
10.
11.
12.
1. MIRU. ND tree, NU and test BOPE. Circulate well clean through cut at +/- 7,300' MD.
2. Pull the existing 5-1/2" tubing completion from the cut at + 7,300' MD. Tubing will be junked. Replace the
9 5/8" packoff if necessary.
3. Make GR/JB run to at least 7,270'MD. Run 9-5/8" bridge plug on wireline w/GR/CCL and set at +/-7,245
MD. Pressure test 9-5/8" casing to 3000 psi.
4. RIH w/9-5/8' section mill and spot 18 ppg fluid from bridge plug at 7,245' MD to base of planned window
at 7,045' MD. Displace to LSND mud. Mill 40' window from 7,005 to 7,045' MD. (KOP +/- 7,015' MD in
the West Sak formation). Spot 28.5 bbls of cement from 100' below to 200' above the window.
5. RIH with directional assembly and kick off from 7,015' MD. Directionally drill the 8-1/2" hole to the top of
the Sag River at +/-9,215' MD.
6. Run and cement 7", 26#, L-80 BTCM drilling liner with 150' of overlap above the milled section in the 9-
5/8" casing. Test 7" casing to 3000 psi.
?. RIH w/directional assembly and drill float equipment. Perform FIT and displace to QuickdrilN fluid.
Directionally drill 6-1/8" hole along the directional path. Planned TD is +/-10,862'MD, 8790' TVDss at the
base of zone 1.
Run MWD/LWD logs while drilling the target interval of the well.
Run and cement 4 1~,,, 12.6# L-80 IBT-Mod solid production liner with 150' lap inside 7" drilling liner.
Test liner and liner lap to 3000 psi.
DPC perforate the last 800' of 4-1/2" liner.
Run 4-1/2" 12.6#, L80, IBT-Mod Tubing GLM completion, stab WLEG into 4-1/2" T~L. Test tubing to
3,500 psi and annulus to 3,000 psi while holding pressure on tubing ID.
13. Freeze protect well to 2200'
14. ND BOPE, NU and test tree. RDMO.
Prepared by:
Bryan McLellan, ODE
TREE: McEvoy 6' K.-07B KB. ELEV = 63.21'
WELLHEAD: McEvoy
"'"'--'l j~~ SSSV LANDING NIPPLE I 2033
I
fcc- I~1 1 I~
L-80, BTRS j13'3/8"' 72#/ft, 2709 j__ j J k ' (CAMCO W/RK LATCH)
~ N"J MD(BKB) TVOss I
15 u2-. 17#/~. L-8O BTRS TBG I ~ -- I 40 I 3175 . 31~ /
hD 4.892" / CAP 0.0282 BPF I I---~[ 9 I 4750 4475 l
I~:1 -- ' 71 7094 6297/
KOP #1: 2800' 6 I 767O 8738l
KOP#2: 98oo' WS ,~ ~/~:~>~
!MaxAngle=B65at10532' ~'~ J~ i: I~ 2-7/8 ~
Hole in 5 1/2 tubing ~ :/' ~ --~ 'X' profile 3 813' I
-I/~q J L -- - 9-5/8' PACKER (B.O.T.) 19366 I
~ L~,J~I ~ (8.958"1D)
J 8TL CS Hydril ID 2.441' J J~ -- -- - (8 813' ID)4 1/2' 'X" NIPPLE (OTIS) J9414 J9414
JJj ----- 4112" "XN' NIPPLE (OTIS) J9446 J
· o~o~,. ,,,~. ~ ~ ~ JI . ~ (~.~,~',o~ , .
9-5~8. 47#/, I 9~80 I ~ -j 'j ' [---4 U2'TB~TA,L ~.O.~. J9480 I
L-80 ~TRS' ~ ~ J J (3.g58"ID)(ELMD) J9474 J
II
i~,,~: ~.o~,,,,-~o I
PERFORATION SUMMARY ~
REF: LOG: BHCS J~jj~ M~ angle at TD 87 Deg TD 10530'
PBTD 10470'
Tagged top of Cement at 9888
SIZE SPF INTERVAL Open/SQZ J Tagged top of Cement at 9888'
i MARKER JOINT 9941
~ MARKER JOINT J 9941
~.~ ~ ,o~.-,o~.s,.,,~,, '-- I I
! 1.7 4 10380'-10432' Sqz 7/18/97
1.7 4 10380'-10425' Open 7/23/97
21/8' 4 10330'-10350' Open 8-4-97 ~ J
PBTD I ......................... :"?""':' Bottom of Cement at 10147' CTMD
I o~21 ................. -'.'-
Bottom of Cement at 10147' CTMD
7', 26#m, L-8O. BTRS J 10238 J ~
DATE REV. BY COMMENTS PRUDHOE BAY UNIT
8/10/89 W.R.R. Put on Mac
4/4/97 Hildreth ' CTSidetrack WELL: K-07(23-33-12-14)
6/15/97 Nords Update
8/4/97 JTP Re-Perforate BP Exploration (Alaska)
' K 07B P&A
WELLHEAD:, /oy m BF. ELEV = 27.91'
ACTUATOR: OTIS
~ {CAMCO~(4.562' ID)
· FOC -- ~ J I t : GAS LI~ MANDRELS
~82~, I 2709 J~ ~ I I ' (~,~o W/RK ~TCH)
L-~U, U/H~ I I ~~__ .~g Chemi~l N~ MD(BKB~ ~ ~Dss
Is~o ~~.
I,~ ~.,~'/OA~ o.o~,,~ /
~o~.1: ~oo,
KOP~2: 9800' WS : I I ~~35~~R~
M~ Br3~100' at 10187 ] .~ ~ ~~~ Behind
IM~An~le 8658t10532' ' ~ i~ ~~~ ~ 7/8"
Bakem M~el FA Packer , '
' ' I I
, , ....
~Hole in 5 1/2" tubing ~ ~b/U ~ ' ~ / ~ 'x' profile3 813· I I
. , ~ ~J I~ (3.958'1D) ' '
STLCSHydHI'ID2.~I' ~ ~ 4~''X'N~PPLE(OT~S I 4141
~O~O~" ~,N~ I ~408 I -- ~ II II ~ (~.~"~) . .
~-~. 4~ I ~0 ~ , ~' ~ 4~.~,,~ ~.o.~. 1~480 I
~ TSAD
CS Hyddl Tubing
SIZE SPF I~ERVAL Ope~SQZ Tagged top of Cement at 9888'
" I I
1.7 4 10300'-10~4' Sqz7/18/97 MARKER JO~ 9941
1.7 4 10~0'-10~ Sqz 7/18~7
1.7 4 10380'-1~25' Open 7/23/97
2 1/8" 4 10330'-10350' O~n 8~-97
P~TD ~ 10192 ~ ~o~omofCe~e~tat~014~CTUD
-
7". 2~/,. L-SO. aTRS ~ 10238
DATE , R~. BY COMME~S PRUDHOE BAY UNIT
8/10/89 W.R.R P~ on Mac WELL:K-07(23-33-12-14)
4/4/97 Hildreth CTSidetrack APl NO: 50-029-21045
6/15/97 Nords I Update SEC 04 ' TN 11N; RGE 14E;
8/4/97 ~P Re-Pedorate
10/15~9 McLellan P & A for sia~t~ BP Exploration (Alaska)
TREE: McEvoy 6"
WELLHEAD: McEvoy
K-0/C Proposeo
FOC
13-3/8', 72#/ft, ~
L-80, BTRS -"---
Odg Well KOP #1:
2800'
MAX ANGLE: 42
NIPPLE
GAS LIFT MANDRELS
N° MD(BK TVDs
5
4
3 TBA
2
1
~ 7" TOL at 6855'+/-
Kick off in
West Sak at
appmx 7015'MD
,4-1/2' 12.6~L80 IBT-MOd tubing
KB. ELEV = 63.21'
BF. ELEV = 27.91'
Bridge Plug
~lodel FA Packer,
~D:2.668: (Entry Guide)
TUBING SEAL ASSY. y~42'
PACKER (B.O.T.)
FOP OF 7' UNER
9-5/8', 47#/ft,
L-80, BTRS
2 7/8: 6.06#/ft L-80
CS Hyddl Tubing
'X"
'XN"
nipple
Plug back w/
Class G cement
to TSAD at
9,650' MD
7'X4-1/2' prod packer at 9005'+/- MD
stung into 4-1/2" liner top at 9065'MD
7" 26# LB0 BTCM, shoe at 9215' MD in top
,~' Sag River
4-1/2" 12.6# L80 IBT-Mod production
liner TOL at 9,065'MD, shoe at
10,862'MD +/-
CTD Whipstock Top at 9800'
ELMD
Window from 9805 to 9811'
10.5,30'
~{EV. BY
W.R.R.
8/10/8
8/4/97 Hildreth CTSidetrack
6/15/97 Nords Update
8/4/97 JTP Re-Perforate
10/14/99
McLellan
COMMENTS
Put on Mac
Sidetrack proposal
PRUDHOE BAY UNIT
WELL:K-07(23-33-12-14)
APl NO: 50-029-21045
~EC 04; TN 11N; RGE 14E
i
BP Exploration(Alaska)
I DrillQuest'
6400
Current Well Properties
Wel: K-OZC W~
R49[ ~ ~: ~75163.O
Ref. ~lrucl~e Reference: 1990.87
Fle~. ~aphic~ Coominates:
RK~ ~: 56211t ab~
5621ft a~x
Urns: Feet
K-07C WPs
5975163.00 N, 67O744.OO E
1990.87 N, 446.79 E
7O'20' 17.0279' N, 148~ 36' 52.1810' W
562 l. above Mean Sea Level
5621 It ~ S~'uc~xe P,e{ere~ce
Proposal Data for K-O7C WplO
Vedical Origin: Wea
North Relereooe: Trc~ Nocl~
Vmlical .Sec:~xl .~:ime~: 74.00(7
Veric~ Sec~,io~ Odgin: O.OO N,0.OO E
Rate
7015~O 4Z6~42~737 6295R4 20~t98 N 816.94 E 13~
71~ ~ ~.~ ~ 15~ ~ N ~A2 E 13~.76
~.~ 14~ 13~ ~1~3 21~61 N ~2 E 1~43
~I~ 14~ 13~ ~21 2~.~N ~8~7E 1~5
91~.~ 9247 I~1~ ~7121 ~31 N ~1.~ E 1653.16
~.~ 9.247I~1~ ~.43 ~N ~73E 1657AI
~ ~ ~ M75~ ~.42 N ~3.~ E 16~D3
9~7.~ 14~ 3~ ~721 ~ N ~1 E 1~2
~.~ 2~18 ~ ~21~1 2616~7 N ~.91 E 1~3.~ 17~
~4.~ 81~ ~3 ~ 16.43 2616.~ N 718~1 E1411~
~1 ~ ~3~ ~21~1 ~.47N 6~E 13~8
I0~1 ~ ~ ~2121 24~7 N ~I~E . ~92
10~1 ~ ~3~ ~.18 24~N I~.~E ~I.M
I~ ~7 ~1.~ ~ 2~5.11N ~.18 E ~1 8~
I~ ~7 ~l~ ~21 23~.76 N ~17W ~3~ 0~
................................... :"' ' WestSak - 6259.21 TVD
e-on, Start Dir @ 8.000°/100,: 7015.00ft MD, 6295.94ft'l-VO
............................................................................................. ~ ............ CM3 - 6463.21 TVD
Dir: 7376.72, MD, 6610.63ft TVD
6800
7200
I:D7600
'-:5:, "'-~:)!':;:..
"%'::.:.,
..
}.'--.;5-':' :J
8800-
THRZ- 7650.21 TVD
BHNFormation Trend @ 1.000°/10Oft: 8661.22ft MD, 7854.21f
LCU/ Kin$~k- 7854.2] 7'VD
TJD - 7980.21 TVD
TJC - 8059.21 TVD
TJB - 8202.21 TVD
,.Oq.~o. .................... TJA - 8280.21 TVD
L 7" Casing -9199.70 MD, 8381.08'rVD
....................... TSGR - 8371.2/TVD
......................... TSNU - 84/6.2/7"VD
~ ........................ TSAD - 8453.2/TVD
.............................. 9jr. ~ a. t.e. .D. ~ r_ e_ a. s. _e_ ~ .1. 7. : 5_ .09 °.1.1. .~. . . '.. 9. .3.6.7.. ..4.6. ~ .M_ .D_ : 8. .~. .7. . .2.1.fl. ~ .......................... 7Z3- 8553.21 T V D
Dir Rate Increase @ 20.250°/100ft: 9446.44ft MD 8621.21ft TV ..E~.~..
.............................................................................................. ' ~o:~o ...................... T-Z2-8616.21 TVD
..................................................................................... .../ .......... CGOC - 8756.21 TVD
..................................................................................... :;a;~ffo~ ....... : .... :::-':::::' '::: :: :: TZ1 - 8771.21 TVD
10 ~ ~ ..... vsmm_.~ ,,,~oo.oo./ ....
K,-07C Wp b- - ~ --
r ~ ~ ~ Softland @ 15.000°/100ft: 9774.96, MD, 8816.431t TVD
I ~ ~ -- End Dir: 9836.61ft MD, 8821.21, -I-VD
~ ~ Start Dir @ 8.000°/100,: 10286.61ft MD, 8821.21ft TVD
-- End Dir: 10486.37ft MD, 8836.56, TVD
.......... T_o_t_al_ Dep_tb_ _:_ ] 0.8.~.5._ _oq_~ _M. p_~ 8.89. ~-.R~. _'INP. ...................................................................... HOT - 9056.21 TVD
.......... 4. J../¢.'..U.n.o.[: J.0..8.2.5: .09..M.D., .8.~§._2_ ]..~..D. ......................................................................... OOWC- 9096.21 TVD
400 800 1200 1600 2000
Scale: linch = 400ft Section Azimuth: 74.000° (True North)
V t;JI tlL, C:l.I Ot~L~;LIUI I
A II^lJ,[nlrl~'mN COM~^NY
I DrillQuesf
Single Well Target Data for K-07C WPs
Measurement Units: ft
Coordinate
Target Point TVD TVD Northlnga Eaatlnga NorthlngaEaatlnge Target
Name Type aa RKB Shape
K.07C Hit }'x>int Enb'y Point 8320,00 8376.212618.76 N 830.85 E$977800.00 N 671515.00 E Point
K-07C Polygon Entry Potm 8767.50 8823,712431.75 N 312.81 W5977587.00 bi 670375.90 E Polyson
Boundm7 Point A 8767.50 8823.712431.75 N 312.81 W5977587.00 N 670375.90 E
8767.50 8823.712696.31 N 587,95 E5977872.00 N 671270.40 E
C 8767.50 8823,712500.98 N 644,21 E5977678.00 N 671331.I0 E
D 8767.50 8823.712245.77 N 271,53 W5977402.00 N 670421.40 E
K-07C Tm-get 1Emq' Point 8765.00 8821.212609.86 N 606,58 E 5977786.00 N 671291.1)0 E Point
K-07C TI) Enh7 Point 8790.00 8846,212338.76 N 292,17 W5977494.50 N 670398,65 E Point
Current Well Properties
Well: K.07C WPs
Ho~zontal Cool~lnatee:
Re[. Global Coordinates: 5975163.00 N 670744.00 E
Ref. Structure Reference ~ 1990.87 N 446.79 E
Roi. Geographical Ceerdlnatos: 70° 20' 17.0279" N+ 148° 36' 52.1810" W
RKB Elevation: 56.21ft above Mean Sea Level
56.211t above Struclure Reference
I Norlh Reference: True Norlh
[Unl~: Feet
Proposal Data for K-O7C Wp10
Vertical Origin: Well
Horizontal Origin: Well
MeasurernentUnlts:
It
ii.. vertlo,,a Nodhlnge Ea,tlngeVertical Dogleg
Depth Seetlon Rate
2000.98 N 816.74 E1336.64
20~0. 84 N857.42 E1397.76 8.000
2156.61 N 886.32 E1446.43 8.000
2469.98 N 958.67 E1602.35 0.0~0
2576.31 N 981.~4 E1653.16 1,0~0
2585.80 N 982.73 E1657.4 ] 0.0(30
2589.42 N 983.38 E1659.O3 20.250
2597.34 N 978.81 E1656.82 20.250
2616.67 Iq959.91E 1643,98 17.500
2616.(~ lq718.61E 1411.86 20.250
25~0.47 N 659.23 £1350.48 15.000
2495.57 N 221.63 E9~O.920.OOO
247234 N 124.70 E80134 8.0~0
2445.11 N 29,18 E 702.018,000
2338.76 N 292.17 W363.80O.000
2600 -
2400 -
,_
o
z
2200 -
2000 -
Scale: linch = 200ft
-400 -200 0 200
Eastings
4o0
I
6OO
Softland @ 15.000°/1C
End DIr: 9836.61ft
K-07C TD
K-07C Polygon
Total 8846.21 ft TVD
: 10825.00ft MD, 8846.21ft TVD
End DIr: 10486.37ft
Start DI~ '100ft: 10286.61ft
[ I
-400 -200
Scale: 1 inch = 20Oft
I I
o 200
I
400
Eastings
I
6oo
TVD
800 1000 1200
I
8816.43ft TVD
DIr Rate Increase @ 2C 100ft: 9446.44ft MD, 8621.21ft TVD
DIr Rate Decrease : 9367.46ft MD, 8547.2 lft TVD
2600
Start DIr MD, 8430.43ft TVD
O,~o° End DIr 918
800
@
Dir: 7376.72ft MD, 6610.63ft TVD
2400
Tie-on, Start Dtr @ 8.000°/100ft: 7015.00ft MD,
- 2200
- 2000
~95.~ff ~D
1000 1200
Referenceis True Nodh
t MD, 7854.21ft TVD
Spe,'ry-Sun Drilling Services
Proposal Data - K-07C WPs - K-07C Wp 10
.. /
29 October, 1999 - 10:37 - I - DrillQuest
Sperry-Sun Drilling Services
Proposal Report for K-07C WPs - K-07C Wp 10
Revised: 29 October, 1999
Prudhoe Bay Unit
Measured Sub-Sea
Depth Incl. Azim. Depth
(ft) (ft)
7015.00 42.664 28.737 6239.73
7100,00 35.983 26.731 6305.45
7165.00 30.904 24,706 6359.68
7200.00 28.150 23.671 6390.13
7219.01 26.659 23,028 6407.00
7300.00 20.348 19.314 6481.24
7376.72 14.500 13.000 6554.42
7400.00 14.500 13.000 6576.95
7500.00 14.500 13.000 6673.77
7600.00 14.500 13.000 6770.58
7700.00 14.500 13.000 6867.40
7800.00 14.500 13.000 6964.21
7900.00 14.500 13.000 7061.03
8000.00 14.500 13.000 7157.84
8100.00 14.500 13.000 7254.66
8200.00 14.500 13.000 7351.47
8300.00 14.500 13.000 7448.29
8400.00 14.500 13.000 7545.10
8450.51 14.500 13.000 7594.00
8500.00 14.500 13.000 7641.92
8600.00 14.500 13.000 7738.73
8661.22 14.500 13.000 7798100
8700.00 14.114 12.861
8791.00 13.208 12.505
8800.00 13.118 12.467
7835.58
7924.00
7932.77
Vertical Local Coordinates Global
Depth Northings Eastings Northings
(ft) (ft) (ft) (ft)
6295.94 2000.98 N 816.74 E 59771
6361.66 2048.60 N 841.85 E N
6415.89 2080.84 N 857.42 E!!ii?~'' N
6446.34 2096.57 N i78.71N
6463.21 2104.60 N N
6537.45 2134.64 N 5977317.12 N
6610.63 2156.61N 5977339.23 N
6633.16 2162.29 N E 5977344.94 N
6729.98 2186.68':'~:~: :i!!!~:: 893.26 E 5977369.46 N
6826.79 221; .... ~ii!!iii!i:, 898.90 E5977393.97 N
6923.61 Nii:~!;:: 904.53 E 5977418.49 N
7020.42 225~:!~7!N .... 910.16 E 5977443.01N
7117.24 :!?i~:::,2284.27N 915.79 E 5977467.53 N
7214.05 ?; 2308.66 N 921.42 E 5977492.05 N
7310.87.~, 'i:i~ii:i;;::: 2~:33.06 N 927.06 E 5977516.57 N
· . ,
::
7407;68..:: 2357.46 N 932.69 E 5977541.08 N
·
7504;50 2381.85 N 938.32 E 5977565.60 N
· .
7601;31 2406.25 N 943.95 E 5977590.12 N
7650.2'1 2418.57 N 946.80 E 5977602.50 N
7698.13 2430.65 N 949.59 E 5977614.64 N
7794.94 2455.04 N 955.22 E 5977639.16 N
7854.21 2469.98 N 958.67 E 5977654.17 N
7891.79 2479.32 N 960.81E 5977663.55 N
7980.21 2500.28 N 965.53 E 5977684.62 N
7988.98 2502.29 N 965.97 E 5977686.63 N
rdim
Eastings
(ft)
671514.96 E
671538.98 E
671553.82 E
671560.53 E
671563.82 E
671574.91E
671580.98 E
671582.16 E
671587.24 E
671592.32 E
671597.39 E
671602,47 E
671607.54 E
671612.62 E
671617.69 E
671622.77 E
671627.84 E
671632.92 E
671635.48 E
671637.99 E
671643.07 E
671646.18 E
671648.11E
671652.35 E
671652.75 E
Alaska State Plane Zone 4
PBU_WOA K Pad
Dogleg
Rate
(°/100ft)
8.000
8.OO0
8.000
8.000
8.000
8.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
1.000
1.000
1.000
Vertical
Section
(ft)
1336.64
1373.90
1397.76
1408.90
1414.45
1434.05
1446.43
1449.25
1461.39
1473.53
1485.67
1497.81
1509.95
1522.08
1534.22
1546.36
1558.50
1570.64
1576.77
1582.78
1594.92
1602.35
1606.98
1617.30
1618.28
Comment
Tie-on Start Dir @
8.000°;/100ft: 7015.00ft MD,
6295.94ft TVD
CM3
End Dir: 7376.72ft MD,
6610.63ft TVD
THRZ
BHA/Formation Trend @
1.000°/100ft: 8661.22ft MD,
7854.21ft TVD
LCU / Kingak
TJD
Continued...
29 October, 1999- 10:36 - 1 - DrillQuest 1.05.04c
Sperry-Sun Drilling Services
Proposal Report for K-07C WPs - K-07C Wp 10
Revised: 29 October, 1999
Prudhoe Bay Unit
Measured Sub-Sea
Depth Incl. Azim. Depth
(ft) (ft)
8872.01 12.401 12.145 8003.00
8900.00 12.123 12.009 8030.35
9000.00 11.129 11.471 8128.30
9018.04 10.950 11.364 8146.00
9097.38 10.162 10.847 8224.00
9100.00 10.136 10.829 8226.58
9189.70 9.247 10.136 8315.00
9199.70 9.247 10.136 8324.87
9200.00 9.247 10.136 8325.16
9235.30 9.247 10.136 8360.00
9249.70 9.247 10.136 8374.22
9272.66 4.598 10.136 8397,00
9295.36 0.000 0.000 8419.68
9300.00 0.939 330.003 8424.32
9367.46 14.599 330.000 8491.00
9373.67 15.387 327.102 8497.00
9400.00 19.047 317.584 8522.15
9440.88 25.332 308.437 8560.00
9446.44 26.218 307.520 8565.00
9500.00 32.910 290.066
8611.65
Vertical Local Coordinates
Depth Northings Eastings
(ft) (ft) (ft)
8059.21 2517.82 N 969.37 E
8086.56 2523.64 N 970.61 E
8184.51 2543.37 N 974.71 E
8202.21 2546.75 N 975.40 E:.?!
8280.21 2561.01 N 978.2,
8282.79 2561.47 N 978
8371.21 2576.31 N
8381.08 2577.90 N E
8381.37 E
8416.21 2583.! 982.33 E
8430.43 2! 982.73 E
8453.21 2588:53 N 983.22 E
8475.89 2589.42 N 983.38 E
8480.53 2589.46 N 983.36 E
8547.21 2597.34 N 978.81E
8553.21 2598.71 N 977.97 E
8578.36 2604.81N 973.18 E
8616.21 2615.19 N 961.81E
8621.21 2616.67 N 959.91E
8667.86 2628.91N 936.79 E
Global
Northings
(ft)
~.08 N
5977760.98 N
5977762.57 N
5977762.62 N
5977768.22 N
5977770.51N
5977773.24 N
5977774.14 N
5977774.18 N
5977781.95 N
5977783.30 N
5977789.30 N
5977799.41N
5977800.85 N
5977812.56 N
Eastings
(fi)
671655.78 E
671656.89 E
671660.55 E
671661.15 E
671663.63 E
671663.71E
671666.12 E
671666.37 E
671666.37 E
671667.24 E
671667.60 E
671668.02 E
671668.16 E
671668.14 E
671663.42 E
671662.55 E
671657.61E
671646.01E
671644.08 E
671620.68 E
Alaska State Plane Zone 4
PBU_WOA K Pad
Dogleg
Rate
(~100~)
1.000
1.o00
1.o0o
1.000
1.000
1.000
1.o00
0.000
0.000
0.000
0.000
20.250
20.250
20.250
20.250
17.500
17.500
17.500
17.500
20.250
Vertical
Section
(ft)
1625.82
1628.62
1638.00
1639.59
1646.22
1646.43
1653.16
1653.87
1653.89
1656.39
1657.41
1658.63
1659.03
1659.02
1656.82
1656.39
1653.46
1645.40
1643.98
1625.12
Comment
TJC
TJB
TJA
End Dir: 9189.70ft MD,
8371.21ft TVD
TSGR
7" Casing
TSHU
Start Dir @ 20.250°/100ft:
9249.70ft MD, 8430.43ft TVD
TSAD
Dir Rate Decrease @
17.500°/100ft: 9367.46ft MD,
8547.21ft TVD
TZ3
TZ2
Dir Rate Increase @
20.250°/100ft: 9446.44ft MD,
8621.21ft TVD
Continued...
29 October, 1999 - 10:36 - 2 - DrillQuest 1.05.04c
Sperry-Sun Drilling Services
Proposal Report for K-07C WPs - K-07C Wp 10
Revised: 29 October, 1999
Prudhoe Bay Unit
Measured
Depth
(ft)
Incl.
Azim.
9600.00 49.148 271.269
9620.45 52.751 268.639
9646.67 57.446 265.614
9700.00 67.180 260.319
9774.96 81.099 254.003
9800.00 84.713 255.033
9836.61 90.000 256.520
9900.00 90.000 256.520
10000.00 90.000 256.520
10100.00 90.000 256.520
10200.00 90.000 256.520
10286.61 90.000 256.520
10300.00 88.929 256.520
10386.61 82.000 256.520
10400.00 82.852 255.865
10486.37 88.367 251.688
10500.00 88.367 251.688
10600.00 88.367 251.688
10700.00 88.367 251.688
10800.00 88.367 251.688
10825.00 88.367 251.688
Sub-Sea Vertical Local Coordinates Global rdin
Depth Depth Northings Eastings Northings Eastings
(ft) (ft) (ft) (ft) (ft) (ft)
8687.12 8743.33 2639.18 N 872.79 E 671556.47 E
8700.00 8756.21 2639.15 N 856.92 E 671540.60 E
8715.00 8771.21 2638.06 N 835.45 E N 671519.17 E
8739.76 8795.97 2632.19 N 788.67 Ei!ii!;,' 12.47 N 671472.53 E
8760.22 8816.43 2616.08 N 718.6' N 671402.86 E
8763.31 8819.52 2609.45 N 5977787.59 N 671379.07 E
8765.00 8821.21 2600.47 N 5977777.81 N 671343.85 E
8765.00 8821.21 2585.69 N E 5977761.63 N 671282.56 E
8765.00 8821.21 2562.38 N E 5977736.11 N 671185.87 E
8765.00 8821.21 2539.( 403.10 E 5977710.59 N 671089.18 E
8765.00 8821.21
8765.00 8821.21
8765.13 8821,34 i!?~2492.45'N
8771.97 8828.18 2472.34 U
8773.73 8829.94.~.ii~i:':2~69.17N
8780.35 8836;56:::'ii 2445.11N
8780.74 8836.95 2440.83N
8783.59 :~:~,8'839.80 2409.43 N
8786.44. !;:, 8842.65 2378.02 N
8789.291 "8845.50 2346.61N
8790.00 8846.21 2338.76N
305.86 E 5977685.07 N 670992.49 E
221.63 E 5977662.97 N 670908.75 E
208.61 E 5977659.56 N 670895.80 E
124.70 E 5977637.54 N 670812.37 E
111.81 E 5977634.08 N 670799.56 E
29.18 E 5977608.14 N 670717.49 E
16.24 E 5977603.57 N 670704.66 E
78.65W 5977570.01N 670610,50 E
173.55W 5977536.45 N 670516.35 E
268.45W 5977502.89 N 670422.19 E
292.17W 5977494.50 N 670398.65 E
Alaska State Plane Zone 4
PBU_WOA K Pad
Dogleg
Rate
(°/100ft)
20.250
20.250
20.250
20.250
20.250
15.000
15.000
0.000
0.000
0.000
0.000
0.000
8.000
8.000
8.000
8.000
0.000
0.000
0.000
0.000
0.000
Vertical
Section
(ft)
1566.44
1551.17
1530.23
1483.65
1411.86
1387.02
1350.48
1287.15
1187.25
1087.35
987.45
900.92
887,54
801.34
788.08
702.01
688.40
588.52
488.64
388.77
363.80
Comment
CGOC
TZ1
Softland @ 15.000°/100ft'
9774.96ft MD, 8816.43ft TVD
End Dir: 9836,61ft MD,
8821.21ft TVD
Start Dir @ 8.000°/100ft '
10286.61ft MD, 8821.21ft TVD
End Dir: 10486.37ft MD,
8836.56ft TVD
Total Depth: 10825.00ft MD
8846.2 lft TVD '
4 1/2" Liner
Target - K-07C TD, Geological
Continued...
29 October, 1999 - 10:36 - 3 - Dr#/Quest 1o05.04c
Sperry-Sun Drilling Services
Proposal Report for K-07C WPs - K-07C Wp 10
Revised: 29 October, 1999
Prudhoe Bay Unit
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.
Alaska State Plane Zone 4
PBU_WOA K Pad
The Dogleg Severity is in Degrees per 100ft.
Vertical Section is from Well and calculated along an Azimuth of 74.000° (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 1
The Bottom Hole Displacement is 2356.94ft., in the Direction of 352.879° (True)~
Comments
Measured Station Coordinates
Depth TVD Northings Eastings
(ft) (ft) (ft) (ft)
7015.00 6295.94 2000.98 N 816.74 E
7376.72 6610.63 2156.61 N 886.32 E
8661.22 7854.21 2469.98 N 958.67 E
9189.70 8371.21 2576.31 N 981.04 E
9249.70 8430.43 2585.80 N 982.73 E
9367.46 8547.21 2597.34 N 978.81 E
9446.44 8621.21 2616.68 N 959.91 E
9774.96 8816.43 2616.08 N 718.61 E
9836.61 8821.21 2600.47 N 659.23 E
10286.61 8821.21 2495.57 N 221.63 E
10486.37 8836.56 2445.11 N 29.18 E
10825.00 8846.21 2338.76 N 292.17 W
COmment
Tie-on, Start Dir @ 8.000°/100ft: 7015.00ft MD, 6295.94ft TVD
End Dir: 7376.72ft MD, 6610.63ft TVD
BHA/Formation Trend @ 1.000°/100ft: 8661.22ft MD, 7854.21ft TVD
End Dir: 9189.70ft MD, 8371.21ft TVD
Start Dir @ 20.250°/100ft: 9249.70ft MD, 8430.43ft TVD
Dir Rate Decrease @ 17.500°/100ft: 9367.46ft MD, 8547.21ft TVD
Dir Rate Increase @ 20.250°/100ft: 9446.44ft MD, 8621.21ft TVD
Softland @ 15.000°/100ft: 9774.96ft MD, 8816.43ft TVD
End Dir: 9836.61ft MD, 8821.21ft TVD
Start Dir @ 8.000°/100ft: 10286.61ft MD, 8821.21ft TVD
End Dir' 10486.37ft MD, 8836.56ft TVD
Total Depth · 10825.00ft MD, 8846.21ft TVD
Cont/nued...
29 October, 1999 o 10:36 - 4 - DrillQuest 1.05.04c
Sperry-Sun Drilling Services
Proposal Report for K-07C WPs - K-07C Wp 10
Revised: 29 October, 1999
Prudhoe Bay Unit
Alaska State Plane Zone 4
PBU_WOA K Pad
Formation Tops
Measured Ve~ical Sub-Sea
Depth Depth Depth Nothings
(ft) (ft) (ft) ~t)
7219.01 6463.21 6407.00 2104.60 N
8450.51 7650.21 7594.00 2418.57 N
8661.22 7854.21 7798.00 2469.98 N
8791.00 7980.21 7924.00 2500.28 N
8872.01 8059.21 8003.00 2517.82 N
9018.04 8202.21 8146.00 2546.75 N
9097.38 8280.21 8224.00 2561,01N
9189.70 8371.21 8315.00 2576.31 N
9235.30 8416.21 8360.00 2583.53 N
9272.66 8453.21 8397.00 2588.53 N
9373.67 8553.21 8497.00 2598,71N
9440.88 8616.21 8560.00 2615.19 N
9620.45 8756.21 8700.00 2639.15 N
9646.67 8771.21 8715.00 2638.06 N
Eastings Formation Name
(ft)
867.96 E CM3
946.80 E THRZ
958.67 E LCU / Kin(
965.53 E TJD
969,37 E TJC
975,40 E
978.20
981.04
977.97 E TZ3
961.81 E TZ2
856.92 E CGOC
835.45 E TZ1
Continued...
29 October, 1999 - 10:36
- 5 - DrillQuest 1.05.04c
Sperry-Sun Drilling Services
Proposal Report for K-07C WPs - K-07C Wp 10
Revised: 29 October, 1999
Prudhoe Bay Unit
Alaska State Plane Zone 4
PBU_WOA K Pad
Casing details
From To
Measured Vertical Measured
Depth Depth Depth
(ft) (ft) (ft)
9770.00 8815.62 9199.70
6600.00 5988.35 10825.00
Targets associated with this wellpath
Target
Name
K-07C Hit point
K-07C Polygon
Vertical
Depth Casing Detail
(ft)
8381.08 7" Casing
8846,21 4 1/2" Liner
Mean Sea Level/Global Coordinates:
Geographical Coordinates:
Mean Sea Level/Global Coordinates:
Geographical Coordinates:
Target Boundary Point #1
#2
#3
#4
Mean Sea Level/Global Coordinates #1
#2
#3
#4
Target Entry Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
8376.21 2618.76 N 830.85 E
8320.00 5977800.00 N 671515,00 E
70° 20' 42.7844" N 148° 36' 27,9042" W
8823.71 2431.75 N 312.81 W
8767.50 5977587.00 N 670375.90 E
70° 20' 40.9454" N 148° 37' 01.3208" W
8823.71 2431.75 N 312.81 W
8823.71 2696.31 N 587.95 E
8823.71 2500.98 N 644.21 E
8823.71 2245.77 N 271.53 W
8767.50 5977587.00 N 670375,90 E
8767.50 5977872.00 N 671270.40 E
8767.50 5977678.00 N 671331,10 E
8767.50 5977402.00 N 670421.40 E
Target Target
Shape Type
Point Geological
Polygon Geological
Continued...
29 October, 1999 - 10:37 - 6 - DrillQuest 1.05.04c
Sperry-Sun Drilling Services
Proposal Report for K-07C WPs - K-07C Wp 10
Revised: 29 October, 1999
Prudhoe Bay Unit
Target
Name
Targets associated with this wellpath (Continued)
K-07C Target 1
K-07C TD
Geographical Coordinates #1
#2
Mean Sea Level/Global
Geoc es:
Mean Sea es:
Target
TVD
(ft)
Alaska State Plane Zone 4
PBU_WOA K Pad
tr oordinates
rthings Eastings
(ft)
Target Target
Shape Type
8821.21
8765.00
8846.21
8790.00
70° 20' 40.9454"N 148° 37' 01.3208"W
70° 20' 43.5474"N 148° 36' 35.0013"W
70° 20'41.6261"N 148° 36'33.3577"W
70°20'39.1162"N 148°37'00.1146"W
2609.86 N 606.58 E
5977786.00 N 671291.00 E
70° 20' 42.6971"N 148° 36' 34.4570"W
2338.76 N 292.17W
5977494.50 N 670398.65 E
70°20'40.0308"N 148° 37'00.7177"W
Point Geological
Point Geological
29 October, 1999 - 10:37 - 7- DrillQuest 1.05.04c
I DATE I CHECK NO.
H 1 581 88 I I
VENDOR AL, ~,SIAAST 14 OO
DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET
102799 CIA 102799A 1 OO_ OO 1 OO. OO
HANDLINO INST: S/H TERRIE HUBBLE X4&28
THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE~ 1 OO. OO 100. O0
::BP EXPLORATION (ALASKA),,INC,
' :"P'o.,ij~0X196612::i'::."::.::.::.:: :::.::::..'::: !::: :!:::.:: ~':;:
::::;:::'::"AN~'HO~AG'E;:'ALASK~:: 99519-6612 .:.: ': '.::::: .::'"..
PAY
To Th e
ORDER
I~iRST ~ATIO~Ai,,BANK :~3F ASH£AND
: ' .:^":X~mUATE~.~ i:~:':.* ':"
::: NATION~,L: CITY.E~.' K :.::: ::.::
· 'C~EV~AND. OHIO
'.: ~: :' :~:::':';B~389.:::'~:,' "':' :.: ::': '
412
No. ':H ::::::::::::::::::::: 88.
CONS~iOX:~Eo,:~(~M~CliL:AcCO'UNT: ::
.::::::.:..'" :':i::: .::::::::. :: ::: :::::::::::: :' DATE .i:::::::::: ":::::::' :'?:: :' :"" .' .'"::'::;:mOUNT
..
ALASIAA STATE DEPT OF REVENUE
nOocC: : '
3OO1 .::'PORCUP I NE: .DR '!'
ANCHORAGE
AIA 99501-3120
·" NOTVALID AFTER 120 DAYS '>' ": '" '::' 'i :::
~-i~"~'i-I~l-J~¥ J~',~-Ti O' ~
i." P'~'F~-J'~'":~-~-~-i:'J~-6J~}'8] '-.'"'-~"'7-J-'-'7-~-'i" J L";'. L"":; '. ';' .'- i'~
........ 2. Lease number appropriate ................... I'~' N ..........................................................................................................................
3. Unique well name and number .................. I'~,~N
4. Well located in a defined pool .................. t N
5. Well located proper distance from drilling unit boundary .... '~ N
6. Well located proper distance from other wells .......... '~ N
7. Sufficient acreage available in drilling unit ........... t N
8. If deviated, is wellbore plat included~ ..............
9. Operator only affected party ................... t N
10. Operator has appropriate bond in force ............. 'r N -
11. Permit can be issued without conservation order ........ '~ N
AP~R DATE 12. Permit can be issued without administrative approval ......
~ ,//. O..~ -~'¢ 13. Can permit be approved before 15- yda wait ........... ,.). N
ENGINEERING 14
15.
16.
17.
18.
19.
20.
21.
22.
23.
24.
25.
j?DATE 26.
u('.~ 27.
28.
"'-,, 20.
GEOLOGY
30.
31.
32.
· Conductor string provided ...................
Surface casing protects all known USDWs ...........
CMT vol adequate to circulate on conductor & surf csg. ....
CMT vol adequate to tie-in long string to surf csg ........
CMT will cover all known productive horizons ..........
Casing designs adequate for C, T, B & permafrost .......
Adequate tankage or reserve pit .................
If a re-drill, has a 10-403 for abandonment been approved·
Adequate wellbore separation proposed .............
If diverter required, does it meet regulations ..........
Drilling fluid program schematic & equip list adequate .....
BOPEs, do they meet regulation ................
BOPE press rating appropriate; test to -'$b--Cbr,,~ psig.
Choke manifold complies w/APl RP-53 (May 84) ........
Work will occur without operation shutdown ...........
Is presence of H2S gas probable .................
P~ermit can be issued wig hydrogen s~jfi-d~ ~ne-~s-~i.~s-.---7--~--.
Data presented on potential overpressure zones .......
Seismic analysis of shallow gas zones .............
DATE 33.
///~.~' ~ 34.
ANNULAR DISPOSAL 35.
APPR DATE
Seabed condition survey (if off-shore) ............. ,.~.~ N,4/,/¢
Contact name/phone for weekly progress reports [exploratory onlyl~Y,; N
With proper cementing records, this plan - ' "' -- \'-. ........ :kcr~
(A) will contain was_t~r'-eceivi~... Y N .-.~ ' ~ '
(B) will not cont~ate freshwater; or cause drilling waste.."~ Y N
to s ud.d_,,~, __ . ~ ...........................................
(C) wil~t impair mechanical integrity of the well used for disposal; Y-"-N..
(Di2~l not da'mage producing forr~ation or impair recovery fr(~m a Y N '"'~ ~
/ pool; and i'/
CE) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N -
ENGINEERING: UIC/Annular COMMISSION:
Comments/Instructions:
c:\msoffice\wordian\diana\checklist (rev. 09~27~99)
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.
k-07c.tapx
Sperry-Sun Drilling Services
LIS Scan Utility
SRevision: 3 $
LisLib SRevision: 4 $
Fri Aug 10 10:17:17 2001
Reel Header
Service name ............. LISTPE
Date ..................... 01/08/10
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 ..................... 01/08/10
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
~rudhoe Bay Unit
~.iWD/MAD LOGS
WELL NAME:
A?I NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
COB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
#
WELL CASING RECORD
~[D RUN 1
AK-MM-90192
M. HANIK
D. M~SKELL
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
REMARKS:
I.
2.
K-07C
500292104503
BP Exploration (Alaska), Inc.
Sperry Sun
10-AUG-01
~D RUN 2
AK-MM-90192
M. HANIK
J. RALL
4
liN
14E
2041
473
.00
54.66
26.16
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
8.500 9.625 7021.0
6.125 7.000 9190.0
ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
WELL K-07C KICKS OFF FROM K-07B WITH TOP OF
WHIPSTOCK
Page 1
k-07c.tapx
SET AT 6992' MD, 6278' TVD.
3. MWD RUN 1 IS DIRECTIONAL ONLY TO SET THE WHIPSTOCK.
4. ~D RUNS 2-3 ARE DIRECTIONAL WiTH DUAL GAMM~ RAY
(DGR) UTILIZING
GEIGER-MUELLER TUBE DETECTORS.
5. DEPTH SHIFTING IS WAIVED PER THE E-MAIL OF 3/16/2001
FROM D.
DOUGLAS OF BP EXPLORATION (ALASKA) INC.
6. MWD RUNS 2-3 REPRESENT THE MWD DATA FOR WELL K-07C
WITH
API# 50-029-21045-03. THIS WELL REACHED A TOTAL
DEPTH (TD)
OF 10820' MD, 8888' TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING
SGRC = SMOOTHED GAM/~ RAY COMBINED
$
File Header
Service name ............. STSLIB.00t
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/08/10
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.000
Comment Record
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD
Depth shifted and clipped curves; all bit runs merged.
DEPTH INCREMENT: .5000
FILE SUMMARY
PBU TOOL CODE START DEPTH STOP DEPTH
GR 6989.5 10780.5
ROP 7021.5 10820.0
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
EQUIVALENT UNSHIFTED DEPTH
BASELINE DEPTH
$
MERGED DATA SOURCE
PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE
I~ND 1 6989.5 9190.0
MWD 2 9158.5 10820.0
$
REMARKS: 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
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order
DEPT
ROP ~D
Units Size Nsam Rep Code Offset Channel
FT 4 1 68 0 1
FT/H 4 1 68 4 2
Page 2
GR MWD API 4 ! 68
k-07c.tapx
8 3
Name Service Unit Min Max
DEPT FT 6989.5 10820
ROP MWD FT/H 0 119.74
GR MWD API 17.19 686.04
Mean
8904.75
55.0237
97.6011
First Reading For Entire File .......... 6989.5
Last Reading For Entire File ........... 10820
File Trailer
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/08/10
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.002
Nsam
7662
7598
7583
First
Reading
6989.5
7021.5
6989.5
Last
Reading
10820
10820
10780.5
Physical EOF
File Header
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/08/10
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLiB.001
Comment Record
FILE HEADER
FILE NUMBER: 2
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 1
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
GR 6989.5 9158.0
ROP 7021.5 9190.0
$
#
LOG HEADER DATA
DATE LOGGED: 27-NOV-99
SOFTWARE
SURFACE SOFTWARE VERSION: Insite
DOWNHOLE SOFTWARE VERSION: 630.91
DATA TYPE (MEMORY OR REAL-TIME): Memory
TD DRILLER (FT) : 9190.0
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG
MINIMUM ANGLE: 6.4
MAXIMUM ANGLE: 42.9
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMP~ RAY P1362HGV6
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 8.500
DRILLER'S CASING DEPTH (FT) :
Page 3
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
Depth Units .......................
Datum Specification Block sub-type...0
k-07c, tapx
LSND
10.20
44.0
9.0
1000
4.8
.000
.000
.000
.000
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD020 FT/H 4 1 68 4 2
GR MWD020 API 4 1 68 8 3
.0
139.7
.0
.0
Name Service Unit Min Max Mean Nsam
DEPT FT 6989.5 9190 8089.75 4402
ROP MWD020 FT/H 0 119.74 65.6529 4338
GR MWD020 API 25.38 347.11 122.644 4338
First Reading For Entire File .......... 6989.5
Last Reading For Entire File ........... 9190
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/08/10
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.003
First
Reading
6989.5
7021.5
6989.5
Last
Reading
9190
9190
9158
Physical EOF
File Header
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/08/10
Maximum Physical Record..65535
File Type ................ LO
Page 4
k-07c.tapx
Previous File Name ....... STSLIB.002
Conunent Record
FILE HEADER
FILE NUMBER: 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 2
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
GR 9158.5 10780.5
ROP 9190.5 10820.0
$
LOG HEADER DATA
DATE LOGGED: 03-DEC-99
SOFTWARE
SURFACE SOFTWARE VERSION: Insite
DOWNHOLE SOFTWARE VERSION: 0.41
DATA TYPE (MEMORY OR REAL-TIME): Memory
TD DRILLER (FT) : 10820.0
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG
MINIMUM ANGLE: 1!.0
MAXIMUM ANGLE: 89.9
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY P1362HGV6
$
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 [,~X CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
6.125
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
QUIKDRIL-N
8,40
45.0
8.6
800
9.2
.000
.000
.000
.000
.0
123.5
.0
,0
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
Depth Units .......................
Datum Specification Block sub-type...0
Page 5
Name Service Order
DEPT
ROP MWD030
GR MWD030
k-07c.tapx
Units Size Nsam Rep Code Offset Channel
FT 4 1 68 0 1
FT/H 4 1 68 4 2
API 4 1 68 8 3
Name Service Unit Min
DEPT FT 9158.5
ROP MWD030 FT/H 0
GR MWD030 API 17.19
Max Mean Nsam
10820 9989.25 3324
86.96 40.8797 3260
686.04 64.1229 3245
First Reading For Entire File .......... 9158.5
Last Reading For Entire File ........... 10820
File Trailer
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... !.0.0
Date of Generation ....... 01/08/10
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.004
First Last
Reading Reading
9158.5 10820
9190.5 10820
9158.5 10780.5
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 01/08/10
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Next Tape Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Reel Trailer
Service name ............. LISTPE
Date ..................... 01/08/10
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Scientific Technical Services
Scientific Technical Services
Physical EOF
Ph~jsical EOF
End Of LIS File
Page 6
