Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout203-200Post Office Box 244027
Anchorage, AK 99524-4027
3800 Centerpoint Drive
Suite 1400
Anchorage, AK 99503
Phone: (907) 564-4891
02/09/2024
Mr. Mel Rixse
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor
through 02/09/2024.
Dear Mr. Rixse,
Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off
with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024.
Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement
fallback during the primary surface casing by conductor cement job. The remaining void space
between the top of the cement and the top of the conductor is filled with a heavier than water
corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached
spreadsheets include the well names, API and PTD numbers, treatment dates and volumes.
As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that
the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations.
If you have any additional questions, please contact me at 564-4891 or
oliver.sternicki@hilcorp.com.
Sincerely,
Oliver Sternicki
Well Integrity Supervisor
Hilcorp North Slope, LLC
Digitally signed by Oliver Sternicki
DN: cn=Oliver Sternicki, c=US,
o=Hilcorp North Slope LLC,
ou=PBU,
email=oliver.sternicki@hilcorp.com
Date: 2024.02.09 11:15:58 -09'00'
Oliver
Sternicki
Hilcorp North Slope LLC.
Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor
Top-off
Report of Sundry Operations (10-404)
02/09/2024
Well Name PTD #API #
Initial top
of cement
(ft)
Vol. of
cement
pumped
(gal)
Final top
of cement
(ft)
Cement top
off date
Corrosion
inhibitor
(gal)
Corrosion
inhibitor/ sealant
date
L-293 223020 500292374900 30 8/29/2023
S-09A 214097 500292077101 2 9/19/2023
S-102A 223058 500292297201 2 9/19/2023
S-105A 219032 500292297701 10 9/19/2023
S-109 202245 500292313500 7 9/19/2023
S-110B 213198 500292303002 35 9/19/2023
S-113B 202143 500292309402 10 9/19/2023
S-115 202230 500292313000 4 9/19/2023
S-116A 213139 500292318301 4 9/19/2023
S-117 203012 500292313700 3 9/19/2023
S-118 203200 500292318800 9 9/19/2023
S-122 205081 500292326500 5 9/19/2023
S-125 207083 500292336100 2 9/19/2023
S-126 207097 500292336300 3 9/19/2023
S-134 209083 500292341300 35 9/19/2023
S-200A 217125 500292284601 7 9/19/2023
S-202 219120 500292364700 13 9/19/2023
S-210 219057 500292363000 10 9/19/2023
S-213A 204213 500292299301 4 9/19/2023
S-215 202154 500292310700 3 9/19/2023
S-216 200197 500292298900 4 9/19/2023
S-41A 210101 500292264501 3 9/19/2023
W-16A 203100 500292204501 2 9/23/2023
W-17A 205122 500292185601 3 9/23/2023
S-118 203200 500292318800 9 9/19/2023
Well
Name PTD # API #
Initial top
of
cement
(ft)
Vol. of
cement
pumped
(gal)
Final top
of
cement
(ft)
Cement
top off date
Corrosion
inhibitor
(gal)
Corrosion
inhibitor/
sealant date
W-19B 210065 500292200602 8 9/23/2023
W-21A 201111 500292192901 8 9/23/2023
W-32A 202209 500292197001 4 9/23/2023
W-201 201051 500292300700 44 9/23/2023
W-202 210133 500292343400 6 9/23/2023
W-204 206158 500292333300 3 9/23/2023
W-205 203116 500292316500 3 9/23/2023
W-207 203049 500292314500 3 9/23/2023
W-211 202075 500292308000 8 9/23/2023
W-213 207051 500292335400 3 9/23/2023
W-214 207142 500292337300 10 9/23/2023
W-215 203131 500292317200 2 9/23/2023
W-223 211006 500292344000 7 9/23/2023
Z-69 212076 500292347100 2.0 27 1.5 10/24/2023
S-128 210159 500292343600 11 12/27/2023
S-135 213202 500292350800 16 12/27/2023
V-113 202216 500292312500 24 12/31/2023
V-114A 203185 500292317801 5 12/31/2023
V-122 206147 500292332800 5 12/31/2023
V-205 206180 500292333800 2 12/31/2023
V-207 208066 500292339000 8 12/31/2023
V-214 205134 500292327500 5 12/31/2023
V-215 207041 500292335100 2 12/31/2023
V-218 207040 500292335000 5 12/31/2023
V-224 208154 500292340000 16 12/31/2023
V-225 209118 500292341900 6 12/31/2023
V-01 204090 500292321000 3 1/1/2024
V-02 204077 500292320900 5 1/1/2024
V-04 206134 500292332200 5 1/1/2024
V-102 202033 500292307000 8 1/1/2024
V-104 202142 500292310300 5 1/1/2024
V-220 208020 500292338300 4 1/1/2024
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Operator Name:2.
Exploratory Development
Service
5
Permit to Drill Number:203-200
6.API Number:50-029-23188-00-00
PRUDHOE BAY, AURORA OIL
Hilcorp North Slope, LLC 5.
Field/Pools:9.
Well Name and Number:
ADL 0028257
Property Designation (Lease Number):10.
8.
PBU S-118
7.If perforating:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception?
Stratigraphic
Current Well Class:4.
Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well
5
Operations shutdown
Op Shutdown
GAS
GSTOR WAG
SPLUG
Abandoned
Oil 5 WINJ
Exploratory Development 5Stratigraphic Service
WDSPL
12. Attachments:
PRESENT WELL CONDITION SUMMARY
7255
Effective Depth MD:
L-80
11.
12/1/2020
Commission Representative:
15.
Suspended
Contact Name: Brian Glasheen
Contact Email: brian.glasheen@hilcorp.com
Authorized Name: Stan Golis
Authorized Title:Operations Manager
Authorized Signature:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Yes No Spacing Exception Required?Subsequent Form Required:
Approved by:COMMISSIONER
APPROVED BYTHE
COMMISSION Date:
OtherAlter Casing
Pull Tubing
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
COMMISSION USE ONLY
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Detailed Operations Program
Packers and SSSV Type:
No SSSV Installed
Packers and SSSV MD (ft) and TVD (ft):
Perforation Depth MD (ft):Tubing Size:
Size
Total Depth MD (ft):Total Depth TVD(ft):
6960
Effective Depth TVD:Plugs (MD):Junk (MD):
Other Stimulate
Re-enter Susp Well
Suspend
Plug for Redrill
Perforate
Perforate New Pool
No Packer
No SSSV Installed
Date:
Liner
Well Status after proposed work:
16. Verbal Approval:
5
Change Approved Program
28 - 3262 28 - 2986
14. Estimated Date for Commencing Operations:
BOP Sketch
30 - 110
Structural
Proposal Summary 13. Well Class after proposed work:
No Packer
6976 - 7070 6681 - 6775 3-1/2"26 - 6754
Production
7122 6827 None None
30 - 110 520
7-5/8"
Contact Phone:(907)564-5277
Date:
80 153020"Conductor
4790
GINJ
5
Post Initial Injection MIT Req'd? Yes No
5
5
Comm.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Surface 3234 6890
Intermediate
7206 5-1/2" x 3-1/2" 26 - 7232 26 - 6937 7000, 10160 4990, 10530
Address:3800 Centerpoint Dr, Suite 1400,
Anchorage, AK 99503
3.
No 5Yes
Casing Length MD TVD Burst
Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):
Collapse
MPSP (psi):
Wellbore Schematic
Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng
Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval.
1830
By Samantha Carlisle at 1:58 pm, Oct 05, 2020
320-420
Digitally signed by Stan Golis
DN: cn=Stan Golis,
ou=Users
Date: 2020.10.05 13:46:33 -
08'00'
Stan Golis
X
BOPE test to 3000 psi, annular to 2500 psi.
MGR08OCT20
10-404
DLB10/05/2020 DSR-10/12/2020
Yes Required?
Comm
10/12/2020
dts 10/12/2020 JLC 10/12/2020
RBDMS HEW 1/26/2021
Tubing Swap
Well: S-118
PTD: 203-200
API: 50-029-23188-00-00
Well Name:S-118 API Number:50-029-23188-00-00
Current Status:SI collapsed TBG Rig:ASR
Estimated Start Date:November 2020 Estimated Duration:5day
Reg.Approval Req’d?Yes Date Reg. Approval Rec’vd:TBD
Regulatory Contact:Abbie Barker Permit to Drill Number:
203-200
First Call Engineer:Brian Glasheen (907)545-1144 (M)
Second Call Engineer:Brodie Dave Wages (713)380-9836 (M)
AFE Number:TBD
Current Bottom Hole Pressure:2309 psi @ 6700’ TVD SBHP Survey 04/16/2020
Maximum Expected BHP:2500 psi @ 6700’ TVD
Max. Anticipated Surface Pressure:1830 psi Gas Column Gradient (0.1 psi/ft)
Equivalent Brine Weight:6.7 ppg
Min ID:2.813” @ 2345’ MD 3-1/2” HES NIP
History:
S-118 is a vertical frac’d Kuparuk producer drilled and completed in 2004. A tubing collapse at 6742' MD was
discovered in 09/07. S-118 remained operable until a failed TIFL in 04/14 when it was then classified as “Not
Operable”. S-118 passed a MIT-T with a plug set at 6718' MD on 3/15/15, confirming the leak to be at or below the
collapse. The exact cause of the collapse has not been determined but is thought to be due to the PBR assembly
being stuck and the thermal effects from pumping multiple HOT’s. The HOT’s likely induced expansion of the
tubing string, causing helical movement and eventually causing the tubing to collapse.
S-118 is in the East of Crest of the Aurora field and is isolated by faults on the north, east and west. Because of this,
the well behaves as if it's on primary depletion and is cycled with relatively low on-time. S-09 (to the south) was
intended to provide pressure support but was found to not communicate with S-118 and has been sidetracked.
The on-cycle is short with high flush production but falls off within a month because of depleted reservoir
pressure.
Scope of Work: The primary objective of the RWO is to restore integrity to the tubing.
Pre Rig Prep Work:
Wellhead Tech
1. MIT-OA. PPPOT-T to 5000 psi. PPPOT-IC to 3500 psi. Function all LDS
FullBore (Freeze protect can be eliminated if schedule day of rig move)
2. Pump 120-bbls of 1% KCL at max rate but not to exceed 2000 psi down the IA.
3. Pump 30-bbls of Diesel down the IA if freeze protect is needed prior to Rig arrival.
4. Pump 100-bbls of 1% KCL at max rate but not to exceed 2000 psi down the Tubing
5. Top with 30-bbls of diesel down tubing if freeze protect is needed prior to Rig arrival.
6. Pump freeze protect as needed down flowline.
Proposed RWO Procedure:
1. MIRU ASR Rig.
2. ND tree. NU & Test BOPE to 250psi Low / 3000psi High, annular to 250psi Low / 2,500psi High (hold each
ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests.
a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015.
b. Notify AOGCC 24 hrs in advance of BOP test.
c. Confirm test pressures per the Sundry Conditions of approval.
d. Test VBR rams on 2-7/8” and 3-1/2” test joints.
e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test.
3. Pull and rerun 3-1/2” tubing with packer
4. Perform MIT-T to 3000psi and MIT-IA to 3000psi.
5. Set a TWC and RDMO.
30 minute charted tests to be recorded.
Pull test plug.
Set BPV or TWC.
Tubing Swap
Well: S-118
PTD: 203-200
API: 50-029-23188-00-00
Post Rig Work:
1. Spot Slickline unit and RU.
2. Pressure test lubricator to 300psi low and 2,800psi high.
3. Pull Ball and rod
4. Pull RHC profile
5. Set GLV per GL Engr.
6. RDMO POP well with GL.
Attachments:
1. Well Schematic Current
2. Well Schematic Proposed
3. BOP Drawing
4. RWO Sundry Revision Change Form
Proposed Completion Diagram
3-½”, 9.3#/ft, L-80 IBT-mod tubing ~6703'3-1/2” HES X Nip
~6653' 5-1/2" X 3-1/2” Stacker Packer
~6603 3-1/2'' HES X Nip
ASR Rig 1 BOPE
BOPE
~4.48'
~4.54'
2.00'
5000#
2-7/8" x 5" VBR
5000#Blind
DSA, 11 5M X 7 1/16 5M (If Needed)
2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves
HCRManualManualManual
Stripping Head
Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: October 2, 2020Subject: Changes to Approved Sundry Procedure for Well S-118Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date
e e
Image Project Well History File Cover Page
XHVZE
This page identifies those items that were not scanned during the initial production scanning phase.
They are available in the original file, may be scanned during a special rescan activity or are viewable
by direct inspection of the file.
d ð:3 - ~O 0 Well History File Identifier
Organizing (done)
o Two-sided 11I11111111111 II III
o Rescan Needed III II 1111111 "" III
R'lCAN
\?' Color Items:
o Greyscale Items:
DIGITAL DATA
~iskettes, No. (
o Other, NolType:
OVERSIZED (Scannable)
o Maps:
o Other Items Scannable by
a Large Scanner
o Poor Quality Originals:
o Other:
OVERSIZED (Non-Scannable)
o Logs of various kinds:
NOTES:
DmeS ~/00
Date 5/11/0~
--I- X 30 =
o Other::
BY: ~
/5/
vnE
III 1111111111111111
ü11?-
Project Proofing
BY: ~
/5/
BY:
+ á 7 = TOTAL PAGES S7-
~t does not include Cover sheet)
/51
Scanning Preparation
Production Scanning
Stage 1 Page Count from Scanned File: 5 <3 (Count does include cover sheet)
Page Count Matches Number in Scanning Prraration: ¿ YES
BY: ~ Date:S/11¡oh
Stage 1 If NO in stage 1, page(s) discrepancies were found: YES
1111111111111111111
NO
/5/ mp
NO
BY:
Maria
Date:
/51
1111111111111111111
Scanning is complete at this point unless rescanning is required.
ReScanned
III II 111111/11 11II1
BY:
Maria
Date:
/5/
Comments about this file:
Quality Checked
11111111/11I1111111
10/6/2005 Well History File Cover Page. doc
~ •
June 25, 2009 ~-~ ~e ~ r~-~ ~~,~
i~~- ~ ~ ~~ ~ L ~l
JUL ~ ~. ZOQ9
Mr. Tom Maunder
Alaska Oil and Gas Conservation Commission ~,4~~~~ ~~! ~~~,` ~:~n~~ C~~r~E~~sa~
333 West 7th Avenue ~n~~~~~~~c~
Anchorage, Alaska 99501
~1a~-~,~o
Subject: Corrosion Inhibitor Treatments of S-Pad d"~
Dear Mr. Maunder, ~ ` ' ~ o
Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated
with corrosion inhibitor in the surface casing by conductor annulus. The corrosion
inhibitor is engineered to prevent water from entering the annular space and causing
external corrosion that could result in a surface casing leak to atmosphere. The
attached spreadsheet represents the well name, top of cement depth prior to filling and
volumes of corrosion inhibitor used in each conductor.
As per previous agreement with the AOGCC, this letter and spreadsheet serve as
notification that the treatments took place and meet the requirements of form 10-404,
Report of Sundry Operations.
If you require any additional information, please contact me or my alternate, Anna Dube,
at 659-5102.
Sincerely,
~s~~r~;~~ , ~ ~. ~ U U.~~`
Qu^~ci`,~`S; `i: °1~4r ~a EJ i.,. xe
Torin Roschinger
BPXA, Well Integrity Coordinator
•
BP Exploration (Alaska ) Inc.
Surface Casing by Conductor Annulus Cement, Corrosio~ inhibitor, Seatant Top-off
Report of Sundry Operetions (10-404)
S-pad
~
/
I~A~R
6/25/2009
Well Name
PTD S
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cemeni top off
tlate
Cortosion
inhibitor Corrosion
inhibitod
sealant date
ft bbls ft na al
S-O18 1952020 025 NA 025 NA 2.6 5/30/2009
S-02A 1941090 025 NA 025 NA 1.7 5/25/2009
S-03 1811900 1325 NA 13.25 NA 92.65 5/2W2009
5-04 1830790 0 NA 0 NA 0.9 5/25/2009
S-0SA 1951890 0 NA 0 NA 0.9 5/26/2009
5-06 1821650 0 NA 0 NA 0.9 5/26/2009
S-07A 1920980 0 NA 0 NA 0.9 5/26I2009
S-OBB 2010520 0 NA 0 NA 0.85 5/27/2009
S-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009
S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009
S-71B 1990530 025 NA 025 NA 1.7 5/27/2009
S-~2A 1851930 025 NA 025 NA 1.7 fi/1/2009
S-ts 1821350 8 NA 8 NA 55.3 6/1l2009
S-75 1840170 0.25 NA 0.25 NA 3 6/2I2009
S-17C 2020070 025 NA 025 NA 2.6 6/1I2009
S-18A 2021630 0.5 NA 0.5 NA 3 6/2I2009
5-19 1867160 0.~5 NA 0.75 NA 22 5/19/2009
S-20A 2010450 025 NA 025 NA 1.3 5/19/2009
5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009
S-22B 7970510 0.75 NA 0.75 NA 3 5/19/2009
S-23 1901270 025 NA 025 NA 1.7 5/25/2009
5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009
S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009
S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009
S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009
S-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009
S-29AL7 1960720 0 NA 0 NA 0.85 5727/2009
S30 1900660 0.5 NA 0.5 NA 5.t 5/31/2009
S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009
S32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009
5-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009
5-34 1921360 0.5 NA 0.5 NA 3.4 5/37/2009
5-35 1921480 0 NA 0 NA .85in 5/31/2009
S-36 1921160 0.75 NA 0.75 NA 425 5/27/2009
5-37 7920990 125 NA 125 NA 11.9 5/27l2009
S38 1921270 0.25 NA 025 NA 102 5/27/2009
S-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009
5-42 1960540 0 NA 0 NA 0.9 5/30/2009
S-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009
S-44 1970070 025 NA 025 NA 1.7 5/28/2009
S•t00 2000780 2 NA 2 NA 21.3 5/29/2009
S-101 2001150 125 NA 125 NA 11.9 5/29/2009
5-702U 2031560 125 NA 125 NA 17.7 5/31/2009
5-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009
S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009
S-105 2001520 4 NA 4 NA 32.7 5/20/2009
S-tOS 2010120 1625 NA 1625 NA 174.3 6/2/2009
5-107 2011130 225 NA 225 NA 28.9 5/18/2009
5-108 2011000 3.5 NA 3.5 NA 40 SI30/2009
5-109 2022450 2 NA 2 NA 21.3 5/30/2009
S-110 2011290 11.75 NA 11.75 NA 98.6 5/30/2009
S-~ 7 7 2050510 2 NA 2 NA 19.6 5/30/2009
5-112 2021350 0 NA 0 NA 0.5 5/30/2009
S-i73 2021430 1J5 NA 1J5 NA 22.1 5/18/2009
S-7~aA 2021980 1.25 NA 125 NA 102 5l30/2009
S-115 2022300 2.5 NA 2.5 NA 27.2 5/29/2009
5-116 2031810 1.5 NA 1.5 NA 13.6 5/28/2009
S-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009
S-178 2032000 5 NA 5 NA 76.5 5/28M2009
S-119 2041620 1 NA 1 NA 52 5/30/2009
5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009
S-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2009
S-~22 2050810 3 NA 3 NA 27.3 5/29/2009
5-723 2041370 1.5 NA 1.5 NA 20.4 5/26/2009
5-124 2061360 1.75 NA 1.75 NA 11.9 5/26/2009
S-125 2070830 225 NA 225 NA 20.4 5/28J2009
S-726 20770970 125 ~ NA 125 NA 75.3 6/1/2009
S-2oo 1972390 1.25 NA 1.25 NA ta.5 5/28/2009
5-207 2001840 0 NA 0 NA 0.85 6/19/2009
S•213A 2042130 2 NA 2 NA 13.8 5/29/2009
5-215 2021540 2 NA 2 NA 18.7 6/1/2009
S-216 2001970 4.75 NA 4.75 NA 57 5/29/2009
S-217 2070950 0.25 NA 025 NA 7.7 6/1/2009
Sd00 2070740 2 NA 2 NA 9.4 5/28/2009
S~a07 2060780 16 NA 16 NA 99.5 6/2/2009
S-SOa 0 NA 0 NA 0.85 5/28/2009
u
• •
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03/01 !2008
DO NOT P LAC E
ANY NEW MATERIAL
UNDER THIS PAGE
F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc
dD:3 -·dê-C
08/07/06
Sdl......
NO. 3903
Schlumberger-DCS
2525 Gambell St, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
:# ( L( t::l::'/'ð
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Aurora
Well
Job #
Log Description
Date
BL
Color
CD
S-118 10687665 OH EDIT OF WIRELINE LOGS 01109/04 3 1
S-120 10621756 OH EDIT OF WIRELlNE LOGS 12/28/03 4 1
S-123 10877787 OH EDIT OF WIRELlNE LOGS 09/20/04 4 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrotechnical Data Center LR2-1
900 E Benson Blvd.
Anchorage AK 99508-4254
Schlumberger-DCS
2525 Gambell St, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
Date Delivered:
Received by:
. - - ," ¡ :!"-.j'"
~:l.:~~t~ ;\~t:.L)
{'A -<
I:: /.
RECEtVED
AUG 0 8 2006
I\IaSka Oil & Gas Cons. eommisSiOn
And10fage
I ~ /IIt'1 ~~
DATA SUBMITTAL COMPLIANCE REPORT
4/24/2006
Permit to Drill 2032000
Well Name/No. PRUDHOE BAY UN AURO S-118
Operator BP EXPLORATION (ALASKA) INC
AP~'O~;O~-~3~-:={
MD 7255 /"
TVD 6960 ("'" Completion Date 4/12/2004 ""
Completion Status 1-01L
Current Status 1-01L
UIC N
REQUIRED INFORMATION
Mud Log No
Samples No
Directional Survey ~
DATA INFORMATION
Types Electric or Other Logs Run: MWD I GR, Gyro, MWD / GR / PWD, PEX, / Sonic, GR / eeL, SCMT
Well Log Information:
(data taken from Logs Portion of Master Well Data Maint
Log/ Electr
Data Digital Dataset Log Log Run Interval OH/
Type Med/Frmt Number Name Scale Media No Start Stop CH Received
I~D Directional Survey 0 7255 1/22/2004
Directional Survey 0 7255 1/22/2004
I 'c-êi ¡',eT ,t evel.......... "-( ---e-
t~~ Cement Evaluation 5 Col 6600 7071 2/11/2005
r- C>fZ ~.
I > ~C-(!, Ci fZM-.
.
Comments
-]
SCMf -CB/PBMS-AlSCMT I
CEMENT BOND LOG & I'
JEWELRY LOG
Well Cores/Samples Information:
Name
Interval
Start Stop
Sent
Received
Sample
Set
Number Comments
ADDITIONAL INFORMATION
Well Cored? Y (f;)
Chips Received? Y / N
Daily History Received?
~:
.
Formation Tops
Analysis
Received?
~
Comments:
Compliance Reviewed By:
i1a
Date: / ~ - ~ ~\ Ç:,
no
an
was
current state.
current
IS
PRUDHOE BAY, AURORA OIL
PBU_S
2
10
10'
)
)
o
10
2004
2005
·
..
1
S-118 (PTD #2032000) Classified as Problem Well
All,
Well S-118 (PTD #2032000) has been found to have sustained casing pressure on the IA and has been
classified as a problem well. The TIO's on 08/08/05 were 2070/2050/130. The well failed a TIFL on
8/8/05.
The plan forward for this well is as follows:
1. DHD: TIFL - FAILED, FTS
2. WIE/APE: Eval for secure /
3. SL:SetTTP
A wellbore schematic has been included for reference. Please call if you have any questions.
«S-118.pdf»
Thanks,
Donald Reeves - Filling in for Anna Dube
Well Integrity Engineer
907-659-5102
907-659-5100 #1923 pgr
Content-Description: S-118.pdf
Content- Type: application/octet-stream
Content-Encoding: base64
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1 of 1
8/10/20054:12 PM
TREE = 3-1/8" 5M CIW
WB.LHEAD = 11" 5M FMC 5-118 I I
A CTUA TOR - SAFETY NOTES:
KB. ELEV - 64.30'
BF. ELEV =
KOP- 460'
Max Angle- 39 @ 2270' I . 2345' 3-1/2" HES X NIP, ID= 2.813" 1
DatumMD- 7059' I
DatumTVD = 6700' SS
17-518" CSG, 29.7#, L-80, ID = 6.875" 3262' W ~
GAS LIFT MA.NDRB.S
ST MD TVD DEV TYÆ VLV LATCH PORT DATE
U 4 3321 3041 20 KBG2-9 OIIIY INT 0 01/12/04
3 4205 3911 1 KBG2-9 OIIIY INT 0 04/16/04
2 6518 6287 2 KBG2-9 OIIIY INT 0 01/12/04
Minimum ID = 2.813" @ 2345' 1 6703 6408 3 KBG2-9 so INT 24 05/02/04
3-1/2" HES X NIPPLE
H 5667 H5-1/2" RA MARKER I
I I 6729' H3-1/2" BAKERCIIt1J SLIDING SLV, ID -2.813" 1
3-1/2" TBG, 9.3#, L-80, ,0087 bpf, ID = 2.992" 6753' r-~ ~y 6753' I-1BAKER 3-1/2" X 5-112" PBR w /SEAL ASSY, ID - 2.990" 1
15-1/2" CSG, 15.5#, L-80, ID = 4.950" 6774' 6774' 1-15-1/2" X 3-1/2" XO, ID - 2.992
ÆRFORA TON SUt.lMARY
REF LOG: PEX GRlBHC
ANGLE AT TOP PERF: 2 @6976' . 1 6952' H3-1/2" HES X NIP, ID - 2.813" 1
Note: Refer to Production DB for historical perf data ~
SIZE SPF IN1ERV A L Opn/Sqz 1)l\.1E
2-1/2' 7 6976 - 6981 0 04/17/04
2-1/2' 3 6980 - 7010 0 07/21/04 ~
2-1/2" 6 7056 - 7070 0 04/12/04
I 7037' H3-1/2"HESX NIP,ID-2.813" I
]
~ 7122'
13-112" CSG, #9.3#, L-80, .0087 bpf, ID =2.992" I 7232'
DATE REV BY COMIVENTS DATE REV BY COt.IMENTS AURORA UNIT
01120/04 JDMfTLI- ORIGINAL COMPLETION 05/02/04 I)l\.V/KAK GL V C/O WB.L: S-118
04/10/04 JLJ/KA K GL V C/O 07/21/04 LDKlKAK ADÆRFS ÆRMT No: 2032000
04/12/04 LDKlKAK IÆRFS API No: 50-029-23188-00
04/16/04 KS/KA K GLV C/O SEe 35, T12N, R12E, 4286' NSL, 4501 WB.
04/17/04 LDKlKAK ADPERFS
04/27/04 JLG/KAK CORRECTIONS BP Exploration (Alaska)
-
it
o
.
.
:Zð3- /9<3'
;;<Otf-I~'I
-;:z..o ..$ -
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Schlumberger
NO. 3335
Schlumberger-DCS
2525 Gamben 51, Suite 400
Anchorage, AK 99503-2838
A TTN: Beth
Company: Alaska Oil & Gas Cons Camm
Attn: Helen Wannan
333 We.t 7th Ave, Suite 100
Anchorage, AK 99501
Field: Aurora
Wen
Job#
Log Description
Color
BL
CD
Date
- S-120 10674426 USIT 4/16/04 1
~-123 10900127 USIT 12/22/04 1
- S-116 10674425 USIT 04/15/04 1
_ S-118 10703986 SCMT 04112/04 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO:
BP Exploration (Alaska) Inc.
PetrotechnÎcal Data Center LR2~1
900 E Benson Blvd.
Anchorage AK 99508-4254
éR 'õ -?/ ~ <_"2..ðL:.:>
02/11/05
:2þ !o 6-
I I
Schlumberger Des
3940 Arctic Blvd Suite 300
Anchorage AK 99503-5789
::2:2/k; ¿J.~a~
Date Delivered:
·
"'"
e STATE OF ALASKA e
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: OtherO
Abandon 0 Repair Well 0 PluQ PerforationsD Stimulate 0
Alter CasingD Pull TubingD Perforate New Pool 0 WaiverD Time ExtensionD
Change Approved ProgramD Operation ShutdownD Perforate IKI Re-enter Suspended Well 0
2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number:
Name: Development Œ] ExploratoryD 203-2000
3. Address: P.O. Box 196612 6. API Number
Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-23188-00-00
7. KB Elevation (ft): 9. Well Name and Number:
63.78 S-118
8. Property Designation: 10. Field/Pool(s):
ADL-028257 Prudhoe Bay Field / Aurora Oil Pool
11. Present Well Condition Summary:
Total Depth measured 7255 feet
true vertical 6959.9 feet Plugs (measured) None
Effective Depth measured 7123 feet Junk (measured) None
true vertical 6827.9 feet
Casing Length Size MD TVD Burst Collapse
Conductor 82 20" 91.5# H-40 28 - 110 28.0 - 110.0 1490 470
Production 6748 5-112" 15.5# L-80 26 - 6774 26.0 0 6479.2 7000 4990
Production 458 3-1/2" 9.3# Lo80 6774 0 7232 6479.2 - 6936.9 10160 10530
Surface 3235 7-5/8" 29.7# L-80 27 - 3262 27.0 - 2985.6 6890 4790
Perforation depth:
Measured depth: 697606980,6980 - 6981,6981 -7010,7056 - 7070
True vertical depth: 6680.97 - 6684.97,6684.97 - 6685.97,6685.97 - 6714.95,6760.9306774.92 RECEIVED
Tubing ( size, grade, and measured depth): 3-112" 9.3# L-80 @ 26 - 6753 SEP 1 6 2004
Packers & sssv (type & measured depth): None Alaska Oil & Gas Cans. Commission
12. Stimulation or cement squeeze summary: Anchorage
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13 Representative Dailv Averaae Production or Iniection Data
Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 1115 8 0 880 236
Subsequent to operation: 222 2.6 0 1200 1328
14. Attachments: 15. Well Class after proposed work:
ExploratoryD Development ŒI Service 0
Copies of Logs and Surveys run _ 16. Well Status after proposed work:
Daily Report of Well Operations. ~ Oil!!] GasD WAG 0 GINJD WINJ 0 WDSPLD
Prepared by Garry Catron (907) 564-4657.
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt:
Contact Garry Catron N/A
Printed Name Garry Catron Title Production Technical Assistant
Signature 1j~~ Phone 564-4657 Date 9/14/04
Form 10-404 Revised 4/2004
ORlG\NAL
RBOM58ft..
'SEP 16lÞ
e
e
S-118
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
EVENT SUMMARY
07/17/04 DRIFT W/ 2.50" DUMMY GUN TO 7039' SLM, TARGET DEPTH 7010' ELM. ***NOTIFY PAD
OPER OF WELL STATUS, CAN POP***
07/21/04 Perforate 6980'-7010' 3 SPF
07/21/04 RAN 2.5" HSD 3 SPF POWER FLOW CHARGES. TOTAL OF 30' OF GUN, 89 CHARGES
TOTAL. ALL SHOTS FIRED, API PENETRATION DEPTH OF 4.8" AND ENTRANCE HOLE
OF 0.66" AS PER PROGRAM. TIED INTO SLB SCMT LOG DATED 12-APR-04, Used X-
nipple at 6935' to Tie-in. Gun fired with secure system.
FLUIDS PUMPED
BBLS
: TOTAL
No Fluids Pumped
o
Page 1
, ' ~
TREE = 3-1/8"5MCIW
WB..LI-EAD = 11" 5M FMC 5-118 1 I
A CTUA TOR - SAFETY NOTES:
KB. ELEV = 64.30'
BF. ELEV -
KOP= 460'
Max Angle - 39 @ 2270' . I 2345' 3-1/2" HES X NIP, ID = 2.813" I
Datum MD = 7059' I
DatumTVD = 6700' SS
17-5/8" CSG, 29.7#, L-80, ID = 6.875" 3262' W ~
GAS LIFT MANDRB..S
ST MD TVD DEV TYÆ VLV LATOi PORT DATE
L 4 3321 3041 20 KBG2-9 CJi\.1Y INT 0 01/12/04
3 4205 3911 1 KBG2-9 CJi\.1Y INT 0 04/16/04
2 6518 6287 2 KBG2-9 CJi\.1Y INT 0 01/12/04
Minimum ID = 2.813" @ 2345' 1 6703 6408 3 KBG2-9 SO INT 24 05/02/04
3-1/2" HES X NIPPLE
-I 500T 5-1/2" RA MARKER
I I 6729' 3-1/2" BAKERCMJ SLI[)NG SLV, ID = 2.813" I
3-1/2" TBG, 9.3#, L-BO, .0087 bpf, ID = 2.992" 6753' ~~ ~~ 6753' BAKER 3-1/2" X 5-1/2" FBRw /SEAL ASSY, ID - 2.990" I
15-1/2" CSG, 15.5#, L-BO, ID-4.95O" 6774' 6774' 5-1/2" X 3-1/2" XO, ID= 2.992
ÆRFORA TON SUI'v1\i1ARY
REF LOG: PEX GRlBI-C
ANGLE AT TOP PERF: 2 @ 6976' . I 6952' H3-1/2" HES X NIP, ID = 2.813" I
Note: Refer to Production DB for historical perf data ]
SIZE SPF INTERVAL Opn/Sqz D<\TE
2-1/2" 7 6976 - 6981 0 04117 /04
2-1/2" 3 69BO - 7010 0 07/21/04 ]
2-1/2" 6 7056 - 7070 0 04112/04
I 703T H3-1/2" HES X NIP, ID = 2.813" I
~ 7122'
3-1/2" CSG, #9.3#, L-BO, .0087 bpf, ID = 2.992" 7232' ~~~
DATE REV BY COMf'ÆNfS DATE REV BY (X)I'v1\i1ENfS A LRORA UNIT
01/20104 JDM/TLI- ORIGINAL COMPLETION 05/02/04 D<\ V/KAK GL V C/O WB..L: S-118
04/10/04 J...J/KAK GL V C/O 07/21/04 LDK/KAK ADÆRFS ÆRMT No: 2032000
04/12/04 LDK/KAK IÆRFS API No: 50-029-23189-00
04/16/04 KS/KAK GL V C/O sa; 35, T12N, R12E, 4286' NSL, 4501 WB..
04/17/04 LDK/KAK ADPERFS
04/27/04 JLG/KAK CORRECTIONS BP Exploration (Alaska)
'F' ...
_ STATE OF ALASKA .
ALASKA~L AND GAS CONSERVATION COM~SION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
"
1a. Well Status: 1m Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class:
20AAC 25.105 20AAC 25.110 1m Development o Exploratory
OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic Test o Service
2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number
BP Exploration (Alaska) Inc. 4/12/2004 203-200
3. Address: 6. Date Spudded 13. API Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 1/3/2004 50- 029-23188-00-00
4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number:
Surface: 1/8/2004 PBU $-118
4286' NSL, 4501' WEL, SEC. 35, T12N, R12E, UM 8. KB Elevation (ft): 15. Field I Pool(s):
Top of Productive Horizon:
3436' NSL, 5191' WEL, SEC. 35, T12N, R12E, UM 63.78' Prudhoe Bay Field / Aurora Pool
Total Depth: 9. Plug Back Depth (MD+ TVD)
3441' NSL, 5197' WEL, SEC. 35, T12N, R12E, UM 7123 + 6828 Ft
4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation:
Surface: x- 618930 y- 5980490 Zone- ASP4 7255 + 6960 Ft ADL 028257
TPI: x- 618255 y- 5979629 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit:
Total Depth: x- -- (Nipple) 2345' MD
618248 y- 5979634 Zone- ASP4
18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost
1m Yes ONo NIA MSL 1900' (Approx.)
21. Logs Run:
MWD I GR, Gyro, MWD I GR 1 PWD, PEX I Sonic, GR I CCL, SCMT
22. CASING, LINER AND CEMENTING RECORD ~
CASING W""PER FT. . ;:SETTINGLJf;f:rfH MD SETTING f;ptHTVD ~<:~.....
SIZE GRADE lOP BOTTOM TOP ¡BOTTOM RECORD
20" 91.5# H-40 Surface 110' Surface 110' 30" 260 sx Arctic Set (Approx.)
7-5/8" 29.7# L-80 28' 3262' 28' 2986' 9-7/8" 400 sx Articset Lite 3, 197 sx 'G'
5-1/2" x 3-1/2" 15.5# 19.3# L-80 26' 7232' 26' 6937' 6-3/4" 93 sx LiteCrete, 126 sx Class 'G'
23. Perforations op'en to Production (MD + TVD of To,e and 24. l' JSHI/G.
Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD)
2-1/2" Gun Diameter, 6spf 3-1/2", 9.3#. L-80 6772' None
MD TVD MD TVD
6976' - 6981' 6681' - 6686' 25. ACID, FRACTURE,CEMENT Squ~EZ§, ETC."
7056' - 7070' 6761' - 6775' >
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
Freeze Protected with 39 Bbls Dead Crude &
45 Bbls Diesel
6976' - 7070' Frac'd with 16/20 Carbolite
Placed 301,0000 Ibs behind pipe
26. PRODUCTION TEST
Date First Production: Method of Operation (Flowing, Gas Lift, etc.):
April 15, 2004 Gas Lift
Date of Test Hours Tested PRODUCTION FOR OIL -BSL GAs-McF W A TER-BSL CHOKE SIZE I GAS-OIL RATIO
5/8/2004 4 TEST PERIOD ... 273 1,855 4 1760 6,802
Flow Tubing Casing Pressure CALCULATED ... OIL-BSL GAs-McF W A TER-BSL OIL GRAVITY-API (CORR)
Press. 71 1,732 24-HoUR RATE 1,636 11 ,132 24
27. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water~~'è::~r\lË1::1 necessary).
Submit core chips; if none, state "none". .
'. . \3 tf'J
,i " " '. . " "'BfL ~. Jj\j'4
None!#~~RBDMS MAY 11 2004
, .~ -~t7'
~-=J ORIGINAL Alaska Oìl & Gas Cons. Commission
"
Form 10-407 Revised 12/2003
CONTINUED ON REVERSE SIDE
, '" ,
GI~
.'
28. GEOLOGIC MARKERS
NAME MD TVD
Ugnu 3864' 3571'
Ugnu M 5025' 4731'
Schrader Bluff N 5246' 4952'
Schrader Bluff 0 5365' 5071'
Base Schrader I Top Colville 5650' 5356'
HRZ 6823' 6528'
Kalubik 6963' 6668'
Kuparuk C 6971' 6676'
Kuparuk B 7017' 6722'
Kuparuk A 7047' 6752'
Miluveach 7115' 6820'
29.
FORMATION TESTS
Include and briefly summarize test results. List intervals tested,
and attach detailed supporting data as necessary. If no tests
were conducted, state "None".
None
RECEIVED
MAY 11 2004
Alaska Oil & Gas Cons. Commission
Anchorage
30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys
31. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed Terrie Hubble Title Technical Assistant
Date OS.. /l-OL(
PBU S-118
Well Number
Prepared By Name/Number:
Drilling Engineer:
Terrie Hubble, 564-4628
Jim Smith, 564-5773
203-200
Permit No. I A roval 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 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".
nD ~ ~\LAL
ITEM 29: List all test information. If none, state "None".
Form 10-407 Revised 12/2003
Printed: 1/13/2004 3:18:41 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-118
S-118
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 7ES
Start:
Rig Release:
Rig Number:
1/2/2004
1/11/2004
Spud Date: 1/3/2004
End: 1/11/2004
1/212004 04:00 - 11 :00 7.00 MOB P PRE Break down Pits & Move out of way for snow removal. Move
Sub off S-120 to other side of Pad for snow removal and Prep.
Clean out around S-118 Cellar. RIG ACCEPTED @ 11 :00.
11 :00 -18:00 7.00 MOB N WAIT PRE Shoot Grade wI Tool Service. Level Location, Remove Snow
from Pad. Set matting boards over Cellar area. Spread
Herculite over area. Set all Wellhead Equipment & Tree into
Cellar area.
18:00 - 20:00 2.00 MOB N WAIT PRE Back Sub over Well & set Matting Boards under Sub. Spot Sub
over Conductor.
20:00 - 21 :00 1.00 MOB N WAIT PRE Back Pits into position and set same.
21 :00 - 00:00 3.00 MOB P PRE Nipple Up Riser & Riser extension to Flow Line and install
turnbuckles. Hook up fluid, Electric & Air Lines. Connect back
up to High Line Power. Take on water & Fuel.
1/3/2004 00:00 - 02:30 2.50 DRILL P SURF CIO Quill to 41/2" IF. Hook Up Kelly & Blower Hose. UD old
Jars & P/U new Jars. Conductor clean to 93'.
02:30 - 03:00 0.50 DRILL P SURF Bring BHA Stabilizers & Subs to Rig Floor.
03:00 - 03:45 0.75 DRILL P SURF PJSM wI SWS E-Line, GyroData & Crew. RIU E-Line.
03:45 - 05: 15 1.50 DRILL P SURF Held PJSM. M I U BHA #1: 97/8" HTC MXC-1 Bit, Ser#
5032164, dressed w/1 x16, 3x18 jets - 8" Motor wI 1.50 deg
Bent Housing - Float Sub - 2 x 10' Non Mag Pony Collars -
9,875 Near Bit Stabilizer - MWD - Orienting Sub - Non Mag XO.
Total BHA Length - 83.39'. Oriented MWD and Motor.
05:15 - 05:30 0.25 DRILL P SURF Fill Conductor & Lines wI Mud. Test Standpipe to 3500 psi.
05:30 - 08:00 2.50 DRILL P SURF Spud and drill 9 7/8"" Hole from 110 to 262'. WOB 2,000#-
10,000#, RPM 70, Motor RPM 121, No Torque, Pump Rate 550
gpm, SPP 450 psi. Circulated Bottoms Up, Pump Rate 550
gpm, SPP 450 psi. Took Survey. POOH to UBHO Sub for
Additional BHA Components.
08:00 - 09:00 1.00 DRILL P SURF Held PJSM. M I U Additional Drill Collars, Stabilizer and Jars.
BHA #1 now consists of: 97/8" HTC MX-C1 Bit, Ser# 5032164,
dressed w/1 x16, 3x18 jets - 8" Motor wI 1.50 deg Bent
Housing - Float Sub - 2 x 10' Non Mag Pony Collars - 9 7/8"
Non Mag Stabilizer - MWD - Orienting Sub - 9 7/8" Non Mag
Stabilizer - Non Mag Drill Collar - Non Mag XO - Non Mag Drill
Collar - 9 7/8" Non Mag Stabilizer - Non Mag Drill Collar - Saver
Sub - Hyd Jars. Total BHA Length - 222.65'. RIH wI BHA #1 to
262'.
09:00 - 09:30 0.50 DRILL P SURF Drill from 262' to 282'. Same Parameters
09:30 - 10:30 1.00 DRILL P SURF Take Gyro Survey: 0.17 Deg Inc @ Azimuth of 44.68 Deg.
10:30 -16:30 6.00 DRILL P SURF Directional Drill from 282' to 820'. Sliding & Rotating. Gyro
Surveying. 520 GPM @ 1170 psi. WOB 10 to 25K.
16:30 - 17:00 0.50 DRILL N SFAL SURF Chain came off sprocket on Drag Chain - Fix Same.
17:00 - 18:00 1.00 DRILL P SURF Directional drill from 820' to 910' burying all the 5" HWDP.
same Parameters.
18:00 - 18:30 0.50 DRILL P SURF Circulate Hole Clean @ 550 GPM, 1420 psi. & 80 RPM while
reciprocating Pipe.
18:30 - 19:30 1.00 DRILL P SURF POH & Stand Back 1 stand HWDP. Change out Top Drive Quill
from 4 1/2" IF to 4" HT -40.
19:30 - 00:00 4.50 DRILL P SURF Directionally Drilled 97/8" Hole by Rotating and Sliding from
910' to 1,432'. WOB Sliding 30,000# - 40,000#, WOB Rotating
25,000# - 30,000#, RPM 80, Motor RPM 116, Torque On
Bottom 3,500 ft Ilbs, Torque Off Bottom 1,500 ft Ilbs, Pump
Rate 525 gpm, SPP On Bottom 1,580 psi, SPP Off Bottom
Printed: 1/13/2004 3:18:50 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-118
S-118
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 7ES
Start:
Rig Release:
Rig Number:
1/2/2004
1/11/2004
Spud Date: 1/3/2004
End: 1/11/2004
1/3/2004 19:30 - 00:00 4.50 DRILL P SURF 1,300 psi. String Weight Up 80,000#, String Weight Down
70,000#, String Weight Rotating 75,000#. Daily AST = 4.30
hrs, ART = 4.54 hrs.
1/4/2004 00:00 - 06:00 6.00 DRILL P SURF Directionally Drilled 9 7/8" Hole by Rotating and Sliding from
1,432' to 2,251'. WOB Sliding 30,000# - 40,000#, WOB
Rotating 10,000# - 40,000#, RPM 80, Motor RPM 121, Torque
On Bottom 3,500 ft Ilbs, Torque Off Bottom 2,000 ft Ilbs,
Pump Rate 550 gpm, SPP On Bottom 1,890 psi, SPP Off
Bottom 1,770 psi. String Weight Up 90,000#, String Weight
Down 75,000#, String Weight Rotating 85,000#. AST = 1.94
hrs, ART = 2.01 hrs.
06:00 - 07:00 1.00 DRILL P SURF Circulate Hole Clean for Trip. 550 GPM, 1700 psi &
Reciprocating @ 100 RPM.
07:00 - 10:00 3.00 DRILL P SURF Pump out of Hole to 1677' @ 550 GPM, 1700 - 1600 psi. (Did
not attempt to pull dry, elected to pump through base of
Permafrost). Pull out of hole the rest of the way dry. No
Problems.
10:00 - 11 :00 1.00 DRILL P SURF CIO Bit & Orient Motor.
11 :00 - 12:30 1.50 DRILL P SURF Service Top Drive, Draw-works, Re-align Top Drive Mud Hose.
12:30 - 14:30 2.00 DRILL P SURF RIH to 2150' - No Problems. Precautionary Wash to 2251' - No
Fill.
14:30 - 20:00 5.50 DRILL P SURF Directionally Drilled 9 7/8" Hole by Rotating and Sliding from
2,251' to 3,275'. WOB Sliding 30,000# - 35,000#, WOB
Rotating 25,000# - 35,000#, RPM 80, Motor RPM 144, Torque
On Bottom 5,100 ft Ilbs, Torque Off Bottom 3,800 ft Ilbs,
Pump Rate 650 gpm, SPP On Bottom 2,830 psi, SPP Off
Bottom 2,640 psi. String Weight Up 100,000#, String Weight
Down 70,000#, String Weight Rotating 85,000#. AST = 0.73
hrs, ART = 2.83 hrs.
20:00 - 21 :00 1.00 DRILL P SURF Circulate 2X bottoms Up - Hole Clean. 650 GPM @ 2600 psi.
Reciprocating 70' @ 100 RPM.
21 :00 - 22:30 1.50 DRILL P SURF POH to 1867'. Trying to Swab at Base of Permafrost. Wiped
through once - OK. Max overpull on trip + 10K
Run Back in Hole to 3275' with no Problems & No Fill. Hole in
good shape.
22:30 - 23:30 1.00 DRILL P SURF Circulate Nut Plug Sweep. Sweep brought back mostly clay.
Cleaned up immediately after sweep.
Comparing strokes, Surface to Surface, calculated & actual:
indicates a 10% wash-out Factor.
23:30 - 00:00 0.50 DRILL P SURF Monitor Well - Static. Pump Pill. Blow Down Top Drive.
1/5/2004 00:00 - 03:30 3.50 DRILL P SURF POH to BHA - No Problems.
03:30 - 05:30 2.00 DRILL P SURF UD BHA. Clear Floor.
05:30 - 07:00 1.50 CASE P SURF RlU to run 7 5/8" Surface Casing.
07:00 - 13:00 6.00 CASE P SURF PJSM wI Crew & Casers. Run 79 Jts. 75/8",29.7#, L-80,
BTC-M Casing.
13:00 - 14:00 1.00 CEMT P SURF Circulate landing Jt. down, Hanger on Ring. Circ. & Condo Mud.
Stage pumps up to 8 BPM & 770 psi. CBU. Shoe @ 3261',
Float Collar @ 3176'.
14:00 - 15:30 1.50 CEMT P SURF RID Franks Tool & RlU Cement Head. Continue Circulating at
same Rate & Pres. Reciprocating Csg 10'. Hold PJSM wI
Crew & Cementers. Mud YP = 18.
15:30 - 17:00 1.50 CEMT N HMAN SURF Dowell unable to pump through Line - Pressuring up. Had
already blown down to them. Found 2 ft. section of rig mud
Printed: 1/13/2004 3:18:50 PM
legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-118
S-118
DRilL +COMPLETE
NABORS ALASKA DRilLING I
NABORS 7ES
Start:
Rig Release:
Rig Number:
1/2/2004
1/11/2004
Spud Date: 1/3/2004
End: 1/11/2004
1/512004 15:30 - 17:00 1.50 CEMT N HMAN SURF manifold cemented up. Were able to disconnect plugged line &
bypass with high pressure valves & hoses.
17:00 - 19:00 2.00 CEMT P SURF Turned back over to Dowell and Cemented as follows:
Pump 5 Bbls. Water & test Lines to 3600 psi.
Pump 25 Bbls CW-100.
Mix & Pump 40 Bbls, 10.2 ppg. MudPush Spacer.
Drop Bottom Plug
Mix & Pump 318 Bbls, 418 Sx, 10.7 ppg Lite Slurry wI yield of
4.45 ft3/sk (Red Dye in first Tub)
Mix & Pump 41 Bbls, 197 Sx, 15.8 ppg. Class 'G' Tail Slurry wI
yield of 1.17 ft3/sk.
Drop bottom Plug and chase with 10 Bbls Water from Dowell to
clear thier Lines.
Switch to Rig Pumps & displace wI 136 Bbls 9.5 ppg Mud @ 9
BPM. Final 4 Bbls @ 3 BPM.
Bumped plug wI 3460 psi. Shut in but was bleeding back
through pump. discontinued Test & Bled off.
100 % Returns throughout Job. Reciprocated Casing
throughout Job. 135K Up Wt., 90K Dn, Wt.
25 Bbls of good 10.7 ppg Cement to Surface - additional 13
Bbls in Riser & Lines.
CIP @ 19:00 Hrs.
19:00 - 20:30 1.50 CEMT P SURF Flush Flow Lines & Cement Lines RIR Cement Head & Lines.
20:30 - 21 :30 1,00 CEMT P SURF Wash out Riser, Suck out Cellar. Break Out & Lay Down
Landing Jt.
21 :30 - 22:30 1,00 CASE P SURF Remove spiders, C/O long Bails, RIU To UD 5" HWDP
22:30 - 00:00 1.50 CASE P SURF UD 5" HWDP out of Derrick.
1/6/2004 00:00 - 01 :30 1.50 WHSUR P PROD1 Held PJSM. N I D 20" Riser and Starter Head.
01 :30 - 02:30 1.00 WHSUR P PROD1 N I U FMC, Gen-IV, 12" Metal to Metal Seal x 11" 5M Speed
Head. Tested Metal to Metal Seal to 1,000 psi, OK.
02:30 - 06:30 4.00 BOPSU P PROD1 Held PJSM. N I U 13-5/8" x 5,000 psi BOP Stack. Hydril
Annular Preventer, Top Pipe Ram wi 3-1/2" x 6" Variable
Rams, Blind Rams, Mud Cross, Lower Pipe Rams wI 3-1/2" x
6" Variable Rams, Tubing Spool, Kill and Choke Lines.
Refabricated Bell Nipple to Length Utilizing New Crossover
Spool.
06:30 - 07:30 1.00 BOPSU P PROD1 R I U Test Equipment to Test BOPE. M I U Test Joint and Test
Plug. RIH and Set Plug in Wellhead. Opened Annulus Valve.
Filled BOP Stack.
07:30 - 12:30 5.00 BOPSU P PROD1 Held PJSM. Tested BOPE. Tested Upper and Lower Rams,
Blind Rams, Stand Pipe Manifold, Choke Manifold, Valves,
HeR, Kill Line, Choke Line, Floor Valves and IBOP to 5,000 psi
High I 250 psi Low. Tested Annular Preventer to 3,500 psi High
1250 psi Low. All Tests Held f/5 Min. All Pressure Tests Held
wi No Leaks or Pressure Loss. Witnessing of BOPE test
Waived by AOGCC Rep Chuck Scheve.
12:30 - 14:00 1.50 BOPSU P PROD1 Blew Down All Lines, Closed Annular Valve, Pulled Test Plug,
LID Test Joint. RID BOPE Test Equipment. Ran and Set
Wear Bushing.
14:00 - 16:00 2.00 DRILL P PROD1 Held PJSM. M I U BHA #3. 6-3/4" Hycalog DS69 PDC Bit, Ser#
205694, dressed wI 5x12 jets - 4-3/4" A475M4560XP 4 I 5 6.0
stg Motor w/1.15 deg Bent Housing - NM 6-3/4" Stabilizer -
Printed: 1/13/2004 3:18:50 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-118
S-118
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 7ES
Start:
Rig Release:
Rig Number:
1/2/2004
1/11/2004
Spud Date: 1/3/2004
End: 1/11/2004
1/612004 14:00 - 16:00 2.00 DRILL P PROD1 Lead Collar - Impulse - VPWD - NM 6-3/4" Stabilizer - 3 x
4-3/4" NM Flex Collars - 3 Jts 3-1/2" HWDP - Drilling Jars - 20
Jts 3-1/2" HWDP - XO - Straight Blade Reamer. Total BHA
Length - 921.54'. Set Motor Bend and Oriented to MWD.
16:00 - 16:30 0.50 DRILL P PROD1 M I U Top Drive and Pulse Tested MWD Tools, OK.
16:30 - 17:00 0.50 DRILL P PROD1 Serviced Rig.
17:00 - 20:00 3.00 DRILL P PROD1 RIH wI 6-3/4" Directional BHA on 4" DP to 3,175'. PI U Single
Joints of DP from Pipe Shed. Tagged Up at 3,175'. M I U
Blower Hose to Top Drive and Adjusted Kelly Hose.
20:00 - 20:30 0.50 EVAL P PROD1 Held PJSM. R I U Circulating Head, Lines and Test Equipment.
Established Circulation.
20:30 - 21 :30 1.00 EVAL P PROD1 Closed Upper Pipe Rams. Tested 7-5/8" Surface Casing to
3,500 psi fl 30 minutes, OK. Calculated Strokes to Pressure Up
to 3,500 psi, 22 - 1.43 bbls, Actual Strokes 31 - 2.07 bbls. Bled
off Pressure, Opened Pipe Rams. Blew Down Lines, RID
Lines and Circulating Head.
21 :30 - 23:00 1.50 DRILL P PROD1 Drilled Cement and Float Equipment from 3,175' to 3,261'.
WOB 2,000# - 5,000#, RPM 40, Motor RPM 225, Torque On
Bottom 3,200 ft Ilbs, Pump Rate 240 gpm, SPP 1,600 psi.
Cleaned Out to 3,275'. Displaced Hole to New 9.7 ppg LSND
Mud While Drilling Out Shoe Track.
23:00 - 23:30 0.50 DRILL P PROD1 Drilled New 6-3/4" Hole from 3,275' to 3,295'. WOB 2,000#-
5,000#, RPM 40, Motor RPM 267, Torque On Bottom 3,200 ft I
Ibs, Pump Rate 290 gpm, SPP 1,750 psi. Circulated Bottoms
Up to Clean the Hole and Condition Mud. Pump Rate 290 gpm,
1,750 psi. Circulated Until Returns Over Shaker were Clean
and MW In Equaled MW Out, 9.7 ppg, Pulled Into Shoe.
23:30 - 00:00 0.50 DRILL P PROD1 Blew Down Top Drive. M I U Circulating Head, Lines and
Testing Equipment.
1/7/2004 00:00 - 00:30 0.50 DRILL P PROD1 Held PJSM. Closed Pipe Rams and Performed LOT.
Strokes Pmp'd Pressure
1 112 psi
2 243 psi
3 336 psi
4 448 psi
5 538 psi
6 617 psi
7 672 psi
8 734 psi
9 754 psi
10 754 psi
MW 9.7 ppg, Csg Shoe TVD 2,995', Pressure 734 psi = 14.41
ppg EMW. Held Pressure f/1 0 minutes, Pressure Leaked off
from 550 psi to 190 psi in 10 minutes. Bled down Pressure,
Opened Pipe Rams.
RID Testing Equipment.
00:30 - 01 :00 0.50 DRILL P PROD1 M I U Top Drive, Established Drilling Parameters: String
Weight Up 95,000#, String Weight Down 68,000#, String
Weight Rotating 75,000#. SPR Pump #1 28 spm - 160 psi, 43
spm - 270 psi; SPR Pump #2 28 spm - 170 psi, 43 spm - 290
psi. Clean Hole Baseline ECD 10.8 ppg. 60 RPM - Torque
3,350 ft Ilbs, 100 RPM - Torque 3,500 ft Ilbs.
Printed: 1/13/2004 3:18:50 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-118
S-118
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 7ES
Start:
Rig Release:
Rig Number:
1/2/2004
1/11/2004
Spud Date: 1/3/2004
End: 1/11/2004
1/712004 01 :00 - 12:00 11.00 DRILL P PROD1 Drilled 6-3/4" Directional Hole by Rotating and Sliding from
3,295' to 4,860'. WOB Sliding 4,000# - 7,000#, WOB Rotating
5,000# - 12,000#, RPM 60, Motor RPM 267, Torque Off Bottom
5,500 ft Ilbs - On Bottom 6,000 ft Ilbs, Pump Rate 290 gpm,
SPP Off Bottom 1,900 psi, On Bottom 2,100 psi. String Weight
Up 120,000#, String Weight Down 80,000#, String Weight
Rotating 98,000#. Calculated ECD 10.65 ppg VPWD ECD
10.95 ppg. Pumped 30 bbl Hi-Vis Weighted Sweeps Every
400'. ART 4.23 hrs, AST 1.29 hrs.
Slide Sheet
Depth Tool Face
3,405' - 3,440' 180.0 -G
3,501' - 3,536' 150.0 R - G
3,596' - 3,672' 170.0 R - G
3,692' - 3,717' 180.0 -G
3,787' - 3,817' 150.0 R - G
4,075' - 4,105' 160.0L-G
4,170' - 4,200' 180.0 -G
4,774' - 4,839' 20.0 R - G
12:00 - 21 :00 9.00 DRILL P PROD1 Drilled 6-3/4" Directional Hole by Rotating from 4,860' to 6,179'.
WOB Rotating 10,000#, RPM 60, Motor RPM 267, Torque Off
Bottom 4,000 ft Ilbs - On Bottom 7,500 ft Ilbs, Pump Rate
290 gpm, SPP Off Bottom 2,100 psi, On Bottom 2,400 psi.
String Weight Up 130,000#, String Weight Down 90,000#,
String Weight Rotating 115,000#. Calculated ECD 10.85 ppg
VPWD ECD 11.0 ppg. Pumped 30 bbl Hi-Vis Weighted
Sweeps Every 400'. Began Weighting Up to 10.0 ppg.
21 :00 - 22:00 1.00 DRILL P PROD1 ECD Increased to 11.97 ppg. Pumped and Circulated Around
30 bbl Hi-Vis Nut Plug Sweep. Pump Rate 290 gpm, SPP
2,250 psi. Rotated and Reciprocated Drill String While
Circulating, RPM 100, Torque 5,000 ft Ilbs. After Bottoms Up
ECD Decreased to 11.45 ppg.
22:00 - 00:00 2.00 DRILL P PROD1 Drilled 6-3/4" Directional Hole by Rotating and Sliding from
6,179' to 6,371'. WOB Sliding 8,000#, WOB Rotating 10,000#-
12,000#, RPM 100, Motor RPM 267, Torque Off Bottom 5,000
ft Ilbs - On Bottom 8,000 ft Ilbs, Pump Rate 290 gpm, SPP
Off Bottom 2,400 psi, On Bottom 2,700 psi. String Weight Up
135,000#, String Weight Down 95,000#, String Weight Rotating
115,000#. Calculated ECD 11.14 ppg VPWD ECD 11.65 ppg.
ART 7.85 hrs, AST .46 hrs
Slide Sheet
Depth Tool Face
6,179' - 6,209' 275.0 - M
1/8/2004 00:00 - 12:00 12.00 DRILL P PROD1 Drilled 6-3/4" Directional Hole by Rotating and Sliding from
6,371' to 7,255'. WOB Sliding 20,000#, WOB Rotating 10,000#
- 12,000#, RPM 100, Motor RPM 267, Torque Off Bottom 8,500
ft Ilbs - On Bottom 9,000 ft Ilbs, Pump Rate 290 gpm, SPP
Off Bottom 2,500 psi, On Bottom 2,800 psi. String Weight Up
175,000#, String Weight Down 100,000#, String Weight
Rotating 133,000#, Calculated ECD 11.2 ppg, VPWD ECD =
11.75 ppg. ART = 6.95 hrs, AST = .95 hrs.
Slide Sheet
Depth Tool Face
Printed: 1/1312004 3:18:50 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-118
S-118
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 7ES
Start:
Rig Release:
Rig Number:
1/2/2004
1/11/2004
Spud Date: 1/3/2004
End: 1/11/2004
1/812004 00:00 - 12:00 12.00 DRILL P PROD1 6,850' - 6,890' 170.0 L -G
12:00 - 13:00 1.00 DRILL P PROD1 Pumped and Circulated Around 30 bbl Hi-Vis Sweep wI Mix II.
Pump Rate 300 gpm, SPP 2,900 psi. Rotated Drill String 100
RPM and Reciprocated Drill String While Circulating. Monitored
Well, Well Static. Blew Down Top Drive.
13:00 - 16:00 3.00 DRILL P PROD1 POOH wI 4" DP fl Wiper Trip from 7,255' - 3,261'. Encountered
Slight Overpull and Slight Swabbing at 6,850'. Worked Through
Section from 6,900' to 6,830' Several Times, Overpull
Diminished. Calculated Fill 22.8 bbls, Actual Fill 26.0 bbls.
16:00 - 16:30 0.50 DRILL P PROD1 Serviced Rig.
16:30 -18:30 2.00 DRILL P PROD1 RIH f/3,261' to 7,160', Filled the Pipe at 5,200'. M I U Top
Drive, Precautionary Wash and Ream from 7,160' to 7,255', No
Fill. Calculated Displacement 22.8 bbls, Actual Displacement
20.0 bbls.
18:30 - 20:30 2.00 DRILL P PROD1 Pumped and Circulated Around 30 bbl Hi-Vis Sweep wI Mix II.
Pump Rate 300 gpm, 2,750 psi. Rotated Drill String 100 RPM,
Torque 8,000 ft Ilbs, Reciprocated Drill String 95'. Circulated
Until Returns Over Shaker Were Clean. Monitored Well, Well
Static. Pumped Dry Job, Blew Down Top Drive.
20:30 - 00:00 3.50 DRILL P PROD1 POOH wI 4" Drill Pipe f/7,255' to 2,500'. No Overpull, No
Swabbing.
1/9/2004 00:00 - 01 :30 1.50 DRILL P PROD1 POOH wI 4" Drill Pipe 925'. Calculated Fill 36.2 bbls, Actual Fill
45.5 bbls.
01 :30 - 02:30 1.00 DRILL P PROD1 POOH wI Directional BHA. Racked 3-1/2" HWDP in Derrick.
Flushed, Broke Down and LID Directional BHA Components.
02:30 - 03:30 1.00 DRILL P PROD1 Cleared and Cleaned Rig Floor.
03:30 - 05:00 1.50 EVAL P PROD1 Held PJSM wI Drilling Crew, Schlumberger Wireline Crew,
Toolpusher and Drilling Supervisor. R I U Schlumberger
Wireline Equipment and Tools.
05:00 - 10:30 5.50 EVAL P PROD1 Tested Logging Tools, OK. Cleared Rig Floor. Schlumberger
Loaded Radioactive Sources into Logging Tools. RIH wI
PEX-BHCS Tool on E-Line. Logged Down While RIH. Tagged
Up at 7,242'. Logged Up from 7,242' to 7-5/8" Casing Shoe at
3,261'. No Hole Problems While Logging.
10:30-11:30 1.00 EVAL P PROD1 Held PJSM. POOH wI Logging Tools to 200'. Cleared Rig
Floor, Pulled Tools to Surface. Schlumberger Removed and
Secured Radioactive Sources. Broke Out and LID PEX-BHCS
Tools. RID Schlumberger Wireline Equipment.
Cleared Equipment Off of Rig Floor.
11:30-12:00 0.50 WHSUR P COMP M I U Retrieving Tool. Latched and Retrieved Wear Bushing.
12:00 - 12:30 0.50 CASE P COMP Held PJSM. PI U 5-112" Landing Joint and 5-1/2" Casing
Hanger. Made Dummy Run wI 5-1/2" Hanger, Marked Landing
Joint. LID Landing Joint and Hanger.
12:30 - 13:00 0.50 CASE P COMP R I U 3-1/2" Handling Tools and Equipment.
13:00 - 13:30 0.50 CASE P COMP Held PJSM wI Drilling Crew, Nabors Casing, Toolpusher and
Drilling Supervisor.
13:30 - 16:00 2.50 CASE P COMP M I U 3-1/2" Tail Pipe:3-1/2" Float Shoe - 2 Jts 3-1/2" 9.3# L-80
IBT Tubing - 3-1/2" Float Collar - 1 Jt 3-1/2" 9.3# L-80 IBT
Tubing - PESI Sleeve Assembly - 2 Jts 3-1/2" 9.3# L-80 IBT
Tubing - Lower X Nipple Assembly - 2 Jts 3-1/2" 9.3# L-80 IBT
Tubing - Upper X Nipple Assembly - 5 Jts 3-1/2" 9.3# L-80 IBT
Tubing. Average M I U Torque 4,750 ft Ilbs. BAKERLOK'D All
Connections Below PESI Assembly, After M I U PESI Sleeve
Printed: 1/13/2004 3:18:50 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-118
S-118
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 7ES
Start:
Rig Release:
Rig Number:
Spud Date: 1/3/2004
End: 1/11/2004
1/2/2004
1/11/2004
1/912004 13:30 -16:00 2.50 CASE P COMP
16:00 -17:00 1.00 CASE P COMP
17:00 - 17:30 0.50 CASE P COMP
17:30 - 21 :00 3.50 CASE P COMP
21 :00 - 21 :30 0.50 CASE P COMP
21 :30 - 00:00
2.50 CASE P
COMP
1/10/2004
00:00 - 04:00
4.00 CASE P
COMP
04:00 - 07:00
3.00 CASE P
COMP
Assembly, Filled Tubing and Checked Float Equipment, OK.
RID 3-1/2" Handling Equipment and Tools, R I U 5-112"
Handling Equipment and Tools.
M I U 5-1/2" Casing Seal Receptacle Assembly.
M I U and RIH wI 5-1/2", 15.5#, L-80, 1ST Casing to 7-5/8"
Casing Shoe at 3,261'. Filled Casing Every Joint. Average M I
U Torque 6,500 ft Ilbs.
M I U Circulating Head and Line. Circulated 2 x Sottoms Up at
3,261', Staged Pumps Up to 5 bpm, 500 psi. No Losses. String
Weight Up 70,000#, String Weight Down 54,000#. Monitored
Well, Static. Blew Down and RID Lines and Head.
M I U and RIH wI 5-1/2", 15.5#, L-80, 1ST Casing. Filled Casing
Every Joint. Average M I U Torque 6,500 ft Ilbs.
M I U and RIH wI 165 Joints 5-112", 15.5#, L-80, 1ST Casing.
Filled Casing Every Joint. Sroke Circulation at 5,285' and
6,854', No Losses. String Weight 135,000#, String Weight
Down 75,000#. Average M I U Torque 6,500 ft Ilbs.
M I U Cement Head to Jt #165, Washed Last Joint Down.
Circulated to Clean and Cool Hole. Slowly Staged Up Pump
Rate to 4 bpm, SPP 855 psi. No Losses. Attempted to
Reciprocate String, Overpull 40,000#, Landed Casing Hanger
in Wellhead. 3-1/2" x 5-1/2" Casing Set As Follows:
Item Length
Depth
Float Shoe 1.18'
7,231.70'
2 Jts 3-1/2" 9.3# L-80 IBT Tbg 63.20'
7,167.32'
Float Collar 1.02'
7,166.30'
1 Jt 3-1/2" 9.3# L-80 1ST Tbg 31.81'
7,134.49'
PES I Landing Collar Assembly 23.38'
7,111.11'
2 Jts 3-1/2" 9.3# L-80 IBT Tbg 63.68'
7,047.43'
X Nipple Assembly 20.65'
7,026.78'
2 Jts 3-1/2" 9.3# L-80 IBT Tbg 63.63'
6,963.15'
X Nipple Assembly 20.68'
6,942.47'
5 Jts 3-1/2" 9.3# L-80 IBT Tbg 159.08'
6,783.39'
PSR Assembly 40.53'
6,742.86'
26 Jts 5-112" 15.5# L-80 1ST Csg 1,055.93'
5,686.93'
5-112" 15.5# L-80 1ST Marker Jt wI RA Tag 20.04'
5,666.89'
138 Jts 5-1/2" 15.5# L-80 IBT Csg 5,638.51'
28.38'
5-1/2" Casing Hanger 2.48'
Printed: 1/13/2004 3:18:50 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-118
S-118
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 7ES
Start:
Rig Release:
Rig Number:
1/2/2004
1/11/2004
Spud Date: 1/3/2004
End: 1/11/2004
1/10/2004 04:00 - 07:00 3.00 CASE P COMP 25.90'
07:00 - 08:30 1.50 CEMT P COMP Held PJSM wI Dowell Crew, Rig Crew, Truck Drivers,
Toolpusher and Drilling Supervisor. Switched Over to Dowell.
Pumped 5 bbls of Water at 3 bpm, 100 psi. Shut in Cement
Manifold and Tested Lines to 4,000 psi. OK. Pumped 15 bbls
of CW, Pump Rate 5.00 bpm, 1,220 psi. Pumped 20 bbls 10.2
ppg Mud Push Pump Rate 5 bpm, 1,190 psi. Pumped 55 bbls
(95 sks) 11.0 ppg Lead Cement wI 0.70 %bwoc Dispersant,
0.20 %bwoc Antifoam, 0.10% bwoc Extender and 1.50 gall sk
GASBLOK, Followed by 29 bbls (135 sks) 15.8 ppg Premium
Tail Cement wI 3.00 %bwoc Expanding Agent, 0.30 gall sk
Dispersant, 0,12 %bwoc Retarder, .010 gall sk Antifoam, 2.00
gall sk GASBLOK. Pumped Cement at the Following Rates:
Pumped Rate Pressure
5.0 bbls 5.00 bpm 1,300 psi
10.0 bbls 4.90 bpm 1,350 psi
20.0 bbls 4.90 bpm 1,320 psi
30.0 bbls 4.90 bpm 1 ,290 psi
40.0 bbls 5.00 bpm 1,337 psi
50.0 bbls 4.80 bpm 1,282 psi
54,0 bbls 3.50 bpm 775 psi
Tail Cement
59.0 bbls 5.00 bpm 1,566 psi
64.0 bbls 5.00 bpm 1 ,460 psi
69.0 bbls 5.00 bpm 1 ,483 psi
74.0 bbls 5.00 bpm 1 ,428 psi
79.0 bbls 5.00 bpm 1,369 psi
84.0 bbls 2.80 bpm 439 psi
Opened Floor Valve and Washed Up Lines Behind Plug
Dropped Wiper Plugs and Displaced wI 165.0 bbls Clean SW
at the Following Rates:
Pumped Rate Pressure
15.0 bbls 5.00 bpm 1,355 psi
25.0 bbls 5.00 bpm 1,475 psi
50.0 bbls 5.00 bpm 1,250 psi
75.0 bbls 5.00 bpm 1,135 psi
100.0 bbls 5.00 bpm 1,433 psi
125.0 bbls 5.00 bpm 1,547 psi
150.0 bbls 5.00 bpm 1,845 psi
Slowed Pump Rate
155.0 bbls 2.00 bpm 1,240 psi
160.0 bbls 2.00 bpm 1,280 psi
Observed Pressure Spike as Wiper Plug Entered 3-1/2" Tubing
at 161 bbls Pumped
165.0 bbls 2.00 bpm 1,635 psi
Wiper Plug Bumped wI 165.0 bbls Total Displacement
Pumped. Pressured up to 2,135 psi. Cement in place @ 0815
hrs. Held Pressure fl 5 Minutes, Bled Down Pressure and
Checked Floats, Floats Held.
08:30 - 09:30 1.00 CEMT P COMP RID Cementing and Casing Handling Equipment.
09:30 - 10:30 1.00 CEMT P COMP Flushed Kill, Choke and Hole Fill Lines wI Water, Blew Down
Same.
10:30-11:00 0.50 CEMT P COMP Broke Out and LID 5-1/2" Landing Joint.
Printed: 1/13/2004 3:18:50 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-118
S-118
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 7ES
Start:
Rig Release:
Rig Number:
1/2/2004
1/11/2004
Spud Date: 1/3/2004
End: 1/11/2004
1/10/2004 11 :00 - 12:00 1.00 WHSUR P COMP Held PJSM. M I U Pack Off Running Tool. Ran and Set 5-1/2"
Pack Off. RILDS. Tested Pack Off to 5,000 psi f/15 Minutes,
OK.
12:00 - 14:00 2.00 CEMT P COMP Held PJSM. RID Long Bails, R I U Short Bails. R I U DP
Elevators and Link Tilt. Installed Mouse Hole.
SIMOPS: R I U Secondary Kill Line to 7-5/8" x 5-112" Annulus
Valve. Tested Line Against Closed Valve to 3,500 psi, OK.
Bled Down Pressure, Opened Valve and Performed LOT:
Strokes Pmp'd Pressure
2 500 psi
3 600 psi
4 680 psi
5 700 psi
6 700 psi
7 700 psi
MW 10.1 ppg, Csg Shoe TVD 2,995', Pressure 680 psi = 14.46
ppg EMW.
Performed Injectivity Test:
1.5 bpm 700 psi
14:00 - 23:00 9,00 CEMT P COMP Broke Out and LID DP from Derrick Using Mouse Hole.
23:00 - 00:00 1.00 CEMT P COMP RID DP Handling Equipment, R I U 3-1/2" Tubing Handling
Equipment. R I U Equipment to Test 5-1/2" x 3-1/2" Casing.
1/11/2004 00:00 - 00:30 0.50 EVAL P COMP Held PJSM. Closed Blind Rams. Tested 5-1/2" x 3-1/2" Casing
to 4,000 psi f/30 minutes, OK. Calculated Strokes to Pressure
Up to 4,000 psi, 31 - 2.20 bbls, Actual Strokes 37 - 2.55 bbls.
Bled off Pressure, Opened Blind Rams.
00:30 - 01 :00 0.50 EVAL P COMP RID Testing Equipment.
01 :00 - 01 :30 0.50 RUNCO COMP M I U 3-1/2" Tail Pipe:3-1/2" Seal Assembly wI Seal Locator
No-Go - Sliding Sleeve Assembly - GLM #1 wI DCK Shear
Valve. M I U Torque 3,000 ft Ilbs. Vam ACE Connections.
01:30 -12:00 10.50 RUNCO COMP M I U and RIH wI 206 Joints of 3-1/2" 9.3# L-80 IBT Tubing.
Average M I U Torque 2,250 ft Ilbs. String Weight Up 95,000#,
String Weight Down 65,000#.
12:00 - 14:00 2.00 RUNCO COMP M I U Jt #207, M I U Circulating Head and Lines to Jt #208.
Washed Down, Pump Rate 2 bpm, 200 psi. Observed
Pressure Increase to 500 psi as Seals Engaged PBR. Shut
Down Pump and Bled Down Pressure. RIH, No-Goed Out in
PBR wI Seal Locator, Stacked 10,000# on PBR to Ensure
Seals Located Out. POOH Broke Out and LID Jt #208, #207
and #206.
14:00 - 15:30 1.50 RUNCO COMP M I U 2 Space Out Pups, 9.00' and 9.81', Jt #206, Tubing
Hanger and Landing Joint. RIH, Landed Tubing Hanger in
Wellhead, RILDS. Completion Equipment Set At The Following
Depths:
Item Length
Depth
Seal Assembly 18.67'
6,772.30'
Locator Seal Assembly 0.74'
6,752.89'
CMD Sliding Sleeve Assembly 33.71'
6,719.18'
Printed: 1/13/2004 3:18:50 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-118
S-118
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 7ES
Start:
Rig Release:
Rig Number:
1/2/2004
1/11/2004
Spud Date: 1/3/2004
End: 1/11/2004
15:30 - 18:30
3.00 RUNCO
COMP
18:30 - 19:00
0.50 WHSUR P
COMP
19:00 - 19:30
0.50 WHSUR P
COMP
19:30 - 20:00
0.50 WHSUR P
COMP
20:00 - 21 :30 1.50 SOPSU P COMP
21 :30 - 22:30 1.00 WHSUR P COMP
22:30 - 23:30 1.00 WHSUR P COMP
#1 GLM Assembly wI DCK Shear Valve
6,693.12'
5 Jts 3-1/2" 9.3# L-80 1ST Tbg 159.26'
6,533.86'
#2 GLM Assembly 25.56'
6,508.30'
72 Jts 3-1/2" 9.3# L-80 IBT Tbg 2,287.90'
4,220.40'
#3 GLM Assembly 25.56'
4,194.84'
27 Jts 3-1/2" 9.3# L-80 1ST Tbg 858.52'
3,336.32'
#4 GLM Assembly 25.60'
3,310.72'
30 Jts 3-1/2" 9.3# L-80 1ST Tbg 954.55'
2,356.17'
X Nipple Assembly 20.62'
2,335.55'
71 Jts 3-1/2" 9.3# L-80 IBT Tbg 2,255.75'
79.80'
3-1/2" 9.3# L-80 IBT Pup Jt 9.00'
70.80'
3-1/2" 9.3# L-80 IBT Pup Jt 9.81'
60.99'
1 Jt3-1/2"9.3#L-80ISTTbg 32.18'
28.81'
Tubing Hanger 2.84'
25.90'
Held PJSM. R I U Circulating Head and Lines. Tested Lines to
4,000 psi, OK. Pressured Tested Tubing To 4,000 psi fl 30
Minutes, OK. Sled Tubing Pressure Down to 2,500 psi and
Shut In. Tested 5-112" x 3-1/2" Annulus to 4,000 psi f/30
Minutes, OK. Sled Down Tubing Pressure and Observed DCK
Valve Shear. Bled Down All Pressures. Blew Down and RID
Lines. Sroke Out and LID Landing Joint.
Set TWC and Tested from Below to 1,000 psi, OK. RID and
Cleared Floor of All 3-1/2" Tubing Equipment.
Held PJSM. R I U Secondary Kill Line to 7-5/8" x 5-112"
Annulus. Tested Lines to 3,500 psi. Bullheaded 15 bbls of 11.4
ppg Mud Down Annulus to Salance Dead Crude Freeze
Protect. Injection Rate 1.0 bpm, 800 psi. Blew Down and RID
Lines.
Held PJSM. R I U Little Red Hot Oil Unit to 7-5/8" x 5-112"
Annulus. Tested Lines to 3,000 psi. Bullheaded 38.5 bbls Dead
Crude Oil Down Annulus to Freeze Protect. Injection Rate 1.0
bpm, 500 psi. Slew Down Lines.
Held PJSM. N I D BOPE.
Held PJSM. N I U Adapter Flange and Production Tree. Tested
Hanger, Neck Seal and Void to 5,000 psi, OK. Tested Tree to
5,000 psi, OK. R I U DSM Lubricator, Pulled TWC, RID DSM.
Held PJSM, Pumped 45 bbls of Diesel Freeze Protect Down
Annulus. Opened Tree Valves and U-Tubed Diesel Freeze
Protect. Blew Down Lines, RID Little Red Hot Oil.
Printed: 1/13/2004 3: 18:50 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-118
S-118
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 7ES
Start: 1/2/2004
Rig Release: 1/11/2004
Rig Number:
Spud Date: 1/3/2004
End: 1/11/2004
1/11/2004
23:30 - 00:00
0.50 WHSUR P
COMP Set BPV. Installed Blind Flange on Tree. Secured Well.
Released Rig at 2359 hrs, 01 111 I 2004.
Printed: 1/13/2004 3:18:50 PM
e
.
S-118
Prudhoe Bay Unit
50-029-23188-00-00
203-200
Accept:
Spud:
Release:
Ri:
01/02/04
01/03/04
01/11/04
Nabors 7ES
PRE-RIG WORK
04/09/04
DRIFT WI 2.5" DUMMY GUN TO TO @ 7078'SLM - NO SAMPLE. SET 3.5" XX CATCHER @ 7015' SLM. PULL
DCKV @ STATION 1 @ 6680' SLM - 6703 MD.
04/10/04
SET LGLV (16/64" PORT, 1987# TRO) @ 4181' SLM. LOAD IA & TBG WIDIESEL. SET OGLV (24/64" PORT) @
6681' SLM. PULL CATCHER - EMPTY. TURN WELL OVER TO DSO - WELL LEFT SHUT IN.
04/12/04
PERFORMED SCMT CEMENT BOND LOG AND JEWELRY LOG FROM TD TO 6600'. TIE-IN TO PEX-DSI LOG
DATED 9-JAN2004. ALL JEWELRY DETECTED 17' SHALLOWER THAN ON TUBING TALLY. A TOTAL 85
HOLES PERFORATED USING 2.5" HSD GUN, POWERJET PJ2506 SHARGES, 6 SPF, 60 DEG PHASING,
RANDOM ORIENTATION. PERFORATED INTERVAL 7056'-7070'.
04/16/04
RUN 31/2" X- CATCHER SUB UNABLE TO GET PAST 3512' SLM DUE TO PARAFIN. RUN 3 1/2" BL BRUSH
AND 2.79" GAUGE RING TO 7000' SLM. HB&R PUMPED 44 BBLS DIESEL TO BRUSH AND FLUSH TUBING
TO 7000' SLM. SET CATCHER IN X NIP @ 6952' MD. PULL 24/64" PORT OGLV FROM STA# 1. PULL 16/64"
PORT, 1987 TRO LGLV FROM STA# 3. SET DGLV IN STA# 3. SET SPMG VLV IN STA# 1. PULL CATCHER.
04/17/04
A TOTAL OF HOLES PERFORATED 5' (31 HOLES) FROM 6976' TO 6981' USING 2.5" HSD GUN LOADED 6
SPF WITH POWERFLOW 2506, HMX CHARGES. API PENETRATION 4.8", ENTRANCE HOLE 0.66", AREA
OPEN TO FLOW 2.05 IN2/FT.
04/20/04
FRAC'D C & A SAND PERFS 6976'-7070' W/318K# 16/20 CARBOLlTE USING YF-125 SYSTEM. PLACED
301K# BEHIND PIPE, SCREENOUTWITH 160 BBLS 10 PPGA IN PERFS, LEFT 17000# IN CSG. EST. TOS=
3800' MD. MAX TREAT= 8600 PSI, AVG TREAT=6750 PSI. LOAD TO RECOVER- 1920 BBLS. ALL ELEMENTS
AND CUPS ON ISOLATION TOOL RECOVERED. WELL LEFT SHUT IN. PAD OPERATOR NOTIFIED.
04/25/04
RIH TRICKLING KCL TO DISPLACE MEOH FROM COIL. TAG ICE AT 678'. WASH THROUGH ICE TO 1363.
WASH SAND FROM 2200 TO 3665 USING FLO-PRO SWEEPS AND 1% KCL.
04/26/04
WASH SAND FROM 3368 TO TD. INITIAL PASS ACROSS PERFS MINIMAL LOSSES. SECOND PASS LOSSES
INCREASE TO 80%. POH TO TOP OF PERFS AND COMPLETE CIRCULATING FROM HERE. CHASE OUT OF
HOLE AT 30%. FP WELL, INSPECT TOOLSISURFACE EQUIP FOR RADIATION - NEGATIVE READINGS.
RDMO. NOTIFY POIPCC OF WELL STATUS. WELL SHUT IN READY FOR SLICK LINE LOGGING.
DRIFT WI 2.25" CENT & S. BAILER. TAGGED @ 7073' SLM. BAILER FULL OF FRAC SAND. RIH WI PRO-
TECH GAUGE. START LOGGING UP @ 30' PER MIN. FROM 7030'.
04/27/04
GOOD DATA ON PRO-TECH GAUGE. SET 31/2" SLIP-STOP CATCHER @ 6803' SLM. MADE SEVERAL
ATTEMPTS TO PULL STA # 1. BRUSH GLM'S. HIT SAND BRIDGE AT 6968'. PULL STA # 3 WI DANIELS
PULLING TOOL.
S-118, Summary of Post Rig.
Page 2
e
04/28/04
SET 1" DOME GLV W/INT. LATCH (16/64" TRO, 1987#) IN STA #3 @ 4186' SLM. RIH W/2.5" DD BAILER TO
ATTEMPT TO WORK THROUGH SUSPECTED BRIDGE. SET DOWN @ 6696' SLM, WORK THROUGH TO
6701' SLM. POOH. BAILER HAD GEL AND APPROX. 1 CUP OF FRAC SAND.
05/01/04
COMPLETE BOP TEST AND PUMP BALL THRU COIL. RIH WITH 2" JS NOZZLE. WELL APPEARS TO BE
PLUGGED ON CIRCULATING HOLDING 400 PSI ON WELL. CLEAN OUT TO CATCHER SUB AT 6828'. LOOKS
LIKE MIGHT BE PULLING CATCHER UP HOLE. PUSH CATCHER DOWN TO 6800, NO INDICATION PULLING
CATCHER UP HOLE. PUMP NUMEROUS HEC SWEEPS DURING FCO, FINAL 20 BBLS OF SWEEP HAD NO
SAND RETURNS. WASH ALL GLM WHILE POH FP WELL TO 2000'. SUSPECT CHECK LEAKING IN GLV, T/lA
COMMUNICATING. CLEAN OUT COMPLETE. NOTIFY POIPCC OF WELL STATUS - WELL SHUT IN READY
FOR SLlCKLlNE. RDMO.
05/02/04
PULL SPMG FROM STATION # 1. SET SOGLV IN STATION # 1. RAN LIB TO STA # 4 @ 3389' SLM, PIC OF
TOP OF VALVE. RAN LIB TO STA # 3 @ 4186' SLM, PIC OFTOP OF VALVE. BAIL SAND AND LCM OFF TOP
OF CATCHER.
05/03/04
BAIL ON S.S. CATCHER SUB. RAN 2.25" PUMP BAILERS, WI BALL & FLAPPER BOTTOMS. BAILED TO
6737' SLM. LEFT WELL SHUT IN, S.S. CATCHER STILL IN HOLE.
05/04/04
RIH WITH 3" GS. LATCH FISH AT 6835. HIT WITH 32 JAR LICKS. POH, RECOVERED FISH. FP WELL TO
2500' RDMO. NOTIFY POIPCC OF WELL SHUT IN STATUS. JOB COMPLETE.
e
e
5-118 Survey Report
Schlumberuer
Report Date: 8-Jan-04
Client: BP Exploration Alaska
Field: Prudhoe Bay Un. - WOA
Structure I Slot: S-PADIS-118
Well: S-118
Borehole: S-118
UWVAPI#: 500292318800
Survey Name I Date: S-1181 Janua¡y 8, 2004
Tort I AHDIDDIIERD ratio: 115,956' / 1306.47 II / 5,1981 0,188
Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet
Location LatILong: N 70 21 19,259. W 149 2 2,992
Location Grid NÆ YIX: N 5980489,870 IIUS, E 618929,810 IIUS
Grid Convergence Angle: +0,90962970'
Grid Scale Factor: 0,99991607
Survey I DLS Computation Method: Minimum Curvature / Lubinski
Vertical Section Azimuth: 219.090'
Vertical Section Ori9in: N 0,000 II, E 0.000 II
TVD Reference Datum: KB
TVD Reference Elevation: 63.78 II relative to MSL
Sea Bed I Ground Level Elevation: 35,80 II relative to MSL
Magnetic Declination: 25,273'
Total Field Strength: 57567,461 nT
Magnetic Dip: 80.856'
Declination Date: Janua¡y 02, 2004
Magnetic Declination Model: BGGM 2003
North Reference: True North
Total Carr Mag North -> True North: +25.273'
Local Coordinates Referenced To: Well Head
550,00 3.51 94.62 549.77 485.99 -6.15 11.33 -1.13 11.14 0.97 0.97 -1.68 5980488.91 618940.97 N 70 21 19.248 W 14922,666
637,00 4.89 100.14 636.53 572.75 -9.45 17.70 -2.00 17.45 1.65 1.59 6.34 5980488.15 618947.28 N 70 21 19.239 W 14922.482
705.98 6.43 108.23 705.18 641 .40 -12.25 24.49 -3.73 24.01 2.51 2.23 11.73 5980486.53 618953.87 N702119.222 W 14922.290
748.22 7.79 112.25 747.09 683.31 -13.92 29.72 -5,55 28.91 3.43 3.22 9.52 5980484.78 618958.80 N 7021 19.205 W 14922.147
841,88 8.06 124.63 839.86 776.08 -16.27 42.58 -11.69 40.18 1.84 0.29 13.22 5980478.82 618970.17 N702119.144 W 14921.817
935.56 8.93 146.31 932.54 868.76 -14.63 56.26 -21.47 49.62 3.52 0.93 23.14 5980469.19 618979.76 N 70 21 19.048 W 14921.541
1032,70 10.80 161.85 1028.26 964.48 -7.47 72.80 -36.40 56.64 3.33 1.93 16,00 5980454.38 618987.02 N 70 21 18,901 W 14921.336
1128,68 10.17 176.40 1122.65 1058.87 3.63 90.18 -53.40 59.98 2.83 -0.66 15.16 5980437.43 618990.62 N 70 21 18.734 W 14921.238
1224,57 10.87 202.64 1216.98 1153.20 18.53 107.39 -70.20 57.03 5.00 0.73 27.36 5980420.59 618987.94 N 70 21 18.569 W 14921.325
1319,26 13.50 218.71 1309.56 1245.78 38.16 127.25 -87.08 46.67 4.51 2.78 16.97 5980403.55 618977.85 N 70 21 18.403 W 14921.627
1413,72 15.88 221.39 1400.92 1337.14 62.10 151.20 -105.38 31,23 2.62 2.52 2.84 5980385,01 618982.71 N 7021 18.223 W 14922.079
1509.10 17.39 221.67 1492.31 1428.53 89.38 178.50 -125.82 13,12 1.59 1.58 0.29 5980364.29 618944.93 N 7021 18.022 W 14922.608
1604.41 18.94 221.04 1582.87 1519.09 119.07 208.22 -148.12 -6,50 1.64 1.63 -0.66 5980341.67 618925.66 N 70 21 17.802 W 14923.182
1699.39 24.60 220.99 1671.04 1607.26 154.26 243.43 -174,69 -29,61 5,96 5.96 -0.05 5980314.74 618902.98 N 70 21 17.541 W 14923.857
1795.28 29.37 219.75 1756.46 1692.68 197.74 286.92 -207.86 -57,75 5,01 4.97 -1.29 5980281.14 618875.37 N 7021 17.215 W 14924.680
1890.92 31.26 220.33 1839,02 1775.24 246.01 335.20 -244.81 -88.81 2.00 1.98 0.61 5980243.70 618844,90 N 7021 16.851 W 14925.588
1987.26 31.98 220.79 1921,06 1857.28 296.50 385.71 -283.18 -121.66 0.79 0.75 0.48 5980204.82 618812.67 N 7021 16.474 W 14926.548
2083.13 35.25 221.73 2000,89 1937.11 349,53 438.77 -323 06 -156.67 3.45 3.41 0.98 5980164.39 618778.31 N 7021 16.082 W 14927.571
2179.33 38.27 225.49 2077.96 2014,18 406,89 496.32 -364,68 -196.40 3.91 3.14 3.91 5980122.15 618739,24 N 702115.673 W 14928.732
2270.49 39.16 226.42 2149,09 2085.31 463.49 553,34 -404,31 -237.39 1.17 0.98 1.02 5980081 .88 618698.89 N 7021 15.283 W 14929.930
2365.46 38.69 225,93 2222,97 2159.19 522.71 613.01 -445,63 -280.44 0.59 -0.49 -0.52 5980039.88 618656.51 N 7021 14.876 W 149211.189
2460,90 37.25 225,28 2298.21 2234.43 581,04 671.73 -486.70 -322.40 1.57 -1.51 -0.68 5979998.15 618615.21 N 7021 14.472 W 149212.415
2558.83 36.63 224,94 2376.48 2312.70 639.57 730.58 -528.24 -364.09 0.67 -0.63 -0.35 5979955.96 618574.18 N 7021 14.064 W 149213.634
2654.99 36.11 224.99 2453,91 2390.13 696.29 787.60 -568.58 -404.39 0.54 -0.54 0.05 5979914.99 618534.53 N 70 21 13.667 W 149214.812
2752.30 33.40 224,64 2533,85 2470.07 751.48 84307 -607.93 -443.49 2.79 -2,78 -0.36 5979875.03 618496.07 N 7021 13.280 W 149215.954
2849.68 32.87 223.44 2615.39 2551.61 804.51 896,30 -646.19 -480.49 0.87 -0,54 -1.23 5979836.19 618459.68 N 7021 12.904 W 149217.036
2944.85 29.42 225,08 2696,84 2633.06 853.53 945,51 -681.46 -514.81 3.73 -3,63 1.72 5979800.39 618425.92 N 70 21 12.557 W 149218.039
3041.14 25.84 226.56 2782.13 2718.35 897.87 990.16 -712.59 -546.81 3.79 -3.72 1.54 5979768.75 618394.43 N 70 21 12.251 W 149218.974
3135.60 22.84 224.89 2868.19 2804.41 936.53 1029,08 -739.74 -574.70 3.26. -3.18 -1.77 5979741.16 618366.98 N 70 21 11.984 W 149219.789
3203.64 21.93 225,02 2931.10 2867.32 962.30 1054,99 -758.08 -593.01 1.34 -1,34 0.19 5979722.54 618348.96 N 702111.803 W 149220.324
3251.36 20.48 223,98 2975.59 2911.81 979.48 1072,25 -770.39 -605.11 3.14 -3.04 -2.18 5979710.04 618337.06 N 70 21 11.682 W 149220.678
3346.72 19.78 220,60 3065.13 3001.35 1012.24 1105.06 -794.64 -627,19 1.42 -0,73 -3.54 5979685.44 618315.37 N 70 21 11.444 W 149221.324
3442.11 16.17 220,51 3155.84 3092.06 1041.66 1134.49 -817.00 -646,33 3.78 -3.78 -0.09 5979662.78 618296.59 N 70 21 11.224 W 149221.883
3538.42 12.73 22402 3249.10 3185.32 1065.65 1158.52 -834,84 -662.42 3.68 -3,57 3.64 5979644.69 618280.78 N 70 21 11.048 W 149222.353
3633.72 9.49 224,57 3342.60 3278.82 1083.93 1176.88 -847.99 -675.23 3.40 -3.40 0.58 5979631.34 618268.18 N 70 21 10.919 W 149222.728
3731.39 7.57 219.22 3439.18 3375.40 1098.38 1191.35 -858,71 -684,95 2.13 -1.97 -5,48 5979620.47 618258.63 N702110.814 W 149223.012
3825.73 5.14 238,14 3532.95 3469.17 1108.59 1201.70 -865.76 -692.47 3.37 -2,58 20.06 5979613.31 618251.23 N 70 21 10.744 W 149223,231
3922.02 5.15 236,74 3628.85 3565.07 1116.79 1210.34 -870.40 -699.75 0.13 0.01 -1.45 5979608,54 618244.02 N 70 21 10.699 W 149223.444
4016.13 4.84 239,35 3722.60 3658.82 1124.54 1218.53 -874,74 -706,70 0.41 -0.33 2.77 5979604,09 618237.15 N 70 21 10.656 W 149223.647
4111.89 3.20 221,39 3818.13 3754.35 1131.00 1225.19 -878,81 -711.94 2.14 -1.71 -18.76 5979599,95 618231.97 N702110.616 W 149223,800
4207.18 0.62 19401 3913.36 3849.58 1134.13 1228.33 -881,30 -713.82 2,80 -2.71 -28,73 5979597.42 618230.13 N 70 21 10.591 W 149 2 23.855
4303.51 0.85 161.42 4009.68 3945.90 1134.98 1229.54 -882.49 -713.72 0.49 0.24 -33,83 5979596.24 618230.25 N 70 21 10.580 W 149223,852
4398.65 0.61 187.77 4104.81 4041.03 1135.79 1230.73 -883,66 -713.57 0.43 -0.25 27.70 5979595,07 618230.42 N 70 21 10.568 W 149 2 23.848
4494.19 1.06 180.25 4200.34 4136.56 1136.91 1232.12 -88505 -713.64 0.48 0.47 -7,87 5979593,68 618230.37 N 70 21 10.554 W 149 2 23.850
4590.4 1 0.97 200,77 4296.55 4232.77 1138.38 1233.80 -886,70 -713.93 0,39 -0.09 21,33 5979592.03 618230.10 N 7021 10.538 W 149 2 23.859
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Generated 1/21/20049:54 AM Page 1 of 2
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.
5165.31 0.76 28.06 4871.37 4807.59 1135.30 1242.52 -883.51 -712.97 0.20 0.15 11.16 5979595,23 618231,01 N 70 21 10,570 W 149223.831
5259.78 0.51 27.87 4965.84 4902.06 1134.27 1243.56 -882.58 -712.48 0.26 -0.26 -0.20 5979596,17 618231.49 N 70 21 10,579 W 149223.816
5355.84 0.65 6.53 5061.89 4998.11 1133.39 1244,52 -881.66 -712.22 0,27 0.15 -22.22 5979597.09 618231.74 N 70 21 10.588 W 149223.809
5452.08 0.74 24.08 5158.13 5094,35 1132.33 1245.68 -880.55 -711.91 0.24 0.09 18.24 5979598,20 618232.03 N 70 21 10.599 W 149223.799
5546.85 0.78 31.88 5252.89 5189,11 1131.10 1246.94 -879.45 -711.31 0,12 0.04 8.23 5979599.32 618232,61 N 70 21 10.610 W 149223.782
5643.41 0.73 34.59 5349.44 5285,66 1129.84 1248.21 -878.38 -710.62 0.06 -0.05 2.81 5979600.39 618233,29 N 70 21 10.620 W 149223.762
5739.08 1.41 85.49 5445.09 5381,31 1128.42 1249.89 -8n. 79 -709.10 1.16 0.71 53.20 5979601.01 618234.80 N 70 21 10.626 W 149223.717
5835.02 2.01 92.30 5540.99 5477,21 1126.59 1252.75 -877.76 -706.24 0.66 0.63 7.10 5979601.08 618237.65 N 70 21 10.626 W 149223.634
5931.12 2.72 88.09 5637.01 5573.23 1124.09 1256.71 -877.75 -702.28 0.76 0.74 -4.38 5979601.15 618241.61 N 70 21 10.626 W 149223.518
6026.26 2.89 85.45 5732.03 5668.25 1120.95 1261.37 -877.49 -697,63 0.22 0.18 -2.77 5979601.49 618246.26 N 70 21 10.629 W 149223.382
6122.36 2.78 84.68 5828.02 5764.24 1117,65 1266.12 -877.08 -692.90 0.12 -0.11 -0.80 5979601.98 618250.98 N 70 21 10.633 W 149223.244
6218.26 1.21 35.58 5923.86 5860.08 1115.01 1269.29 -876.04 -689.99 2.28 -1.64 -51.20 5979603.06 618253.87 N 7021 10.643 W 149223.159
6313.11 1.73 42.28 6018.68 5954.90 1112,58 1271.72 -874.17 -688.44 0.58 0.55 7.06 5979604.96 618255.39 N 7021 10.662 W 149223.114
6409.27 1.79 33.63 6114.79 6051.01 1109.64 1274.67 -871.84 -686.64 0.28 0.06 -9.00 5979607.31 618257.16 N 7021 10.684 W 149223.061
6505.75 1.60 32.76 6211.23 6147.45 1106,80 1277.52 -869.46 -685.07 0.20 -0.20 -0.90 5979609.72 618258.68 N 7021 10.708 W 149223.015
6599.49 2.26 5.28 6304,92 6241.14 1103.96 1280.62 -866.51 -684.19 1.19 0.70 -29.32 5979612,68 618259.52 N 7021 10.737 W 149222.989
6696.17 3,15 356.04 6401 .49 6337.71 1100.44 1285.17 -861.97 -684.20 1.02 0.92 -9.56 5979617,23 618259.43 N 7021 10.782 W149222.990
6791.32 3.75 350.97 6496.47 6432.69 1096.45 1290.89 -856.28 -684.87 0.71 0.63 -5.33 5979622,90 618258.68 N 7021 10.837 W 149223.009
6887.46 2,16 315.15 6592.49 6528.71 1094.16 1295.70 -851.89 -686.64 2.46 -1.65 -37.26 5979627.26 618256.84 N 7021 10.881 W 149223.061
6984.06 1.86 313.54 6689,03 6625.25 1093.85 1299.09 -849.52 -689.06 0,32 -0.31 -1.67 5979629.59 618254,38 N 7021 10.904 W 149223.132
7078.68 1,90 303.76 6783,60 6719.82 1093.87 1302.18 -847.59 -691.48 0.34 0.04 -10.34 5979631 .48 618251,93 N 7021 10.923 W 149223.202
7173.71 1,26 302.03 6878,59 6814.81 1094.15 1304.80 -846.17 -693.68 0.68 -0.67 -1.82 5979632.87 618249.71 N 7021 10.937 W 149223.267
7198.83 1,16 289.23 6903.70 6839.92 1094.27 1305.33 -845.93 -694.15 1.14 -0.40 -50.96 5979633.10 618249.23 N 7021 10.939 W 149223.280
7255.00 1,16 289.23 6959.86 6896.08 1094.65 1306.47 -845.56 -695.22 0.00 0.00 0.00 5979633.45 618248.16 N 7021 10.943 W 149223.312
Leaal DescriDtiDn:
Northina IVI [ftUS] Eastina IXI [ftUSl
8urface: 4286 F8L 4501 FEL 835 T12N R12E UM 5980489.87 618929.81
BHL: 3440 F8L 5198 FEL 835 T12N R12E UM 5979633.45 618248.16
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TREE = 3-1/8" 5M CIW
WB...U-EAD = 11" 5M FMC 5-118 I I
A CTUA TOR - SAFETY NOTES:
KB. ELEV - 64.30'
BF. ELEV -
KOP= 460'
Max Angle = 39 @ 2270' I 2345' 1- 3-1/2"HESXNIP, 10=2.813" I
DatumMD= 7059'
Datum TVD = 6700' SS
17-5I8"CSG, 29.7#, L-80, 10 =6.875" 3262' 1----J ~
GAS LIFT rv1ANDRB...S
ST MD TVD DEV TYÆ VLV LATa-J PORT DATE
L 4 3321 3041 20 KBG2-9 D\i1Y INT 0 01/12/04
3 4205 3911 1 KBG2-9 D\i1Y INT 0 04/16/04
2 6518 6287 2 KBG2-9 D\i1Y INT 0 01/12/04
Minimum ID = 2.813" @ 2345' 1 6703 6408 3 KBG2-9 SO INT 24 05/02/04
3-1/2" HES X NIPPLE
-I 566T 5-1/2" RA MARKER
I I 6729' H 3-1/2" BAKER CtvD SLIDING SLV, 10 - 2.813" I
3-1/2"TBG, 9,3#, L-80, .0087 bpf, 10 -2.992" 6753' t-J I 6753' BAKER3-1/2" x 5-1/2" FBRw /SEAL ASSY, 10- 2.990" I
15-1/2" CSG, 15.5#, L-BO, 10=4.950" I 6774' -I 6774' 5-1/2" X 3-1/2" XO, 10= 2.992
ÆRFORA TON SUMMARY
REF LOG: PEX GRlBI-C I I 6952' H3-1/2" HES X NIP, 10 = 2.813" I
ANGLE AT TOP PERF: 2 @ 6976'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL OpnlSqz DATE
2-1/2' 7 6976 - 6981 0 04117/04
2-1/2" 6 7056 - 7070 0 04112/04
I I 703T H 3-1/2" HES X NIP. 10 = 2813" I
[!§]-1 7122'
Å x x
13-1/2" CSG, #9.3#, L-BO, .0087 bpf, 10 = 2.992" 7232' ~~~
DATE REV BY COMM::NTS DATE REV BY OOMMENTS A URORA UNIT
01/20/04 JDIIII fTL I- ORIGINAL COMPLETION 05/02/04 DAV/KAK GL V C/O WB...L: S-118
04/10/04 JLJ/KAK GL V C/O ÆRMT No: 2032000
04/12/04 LDK/KAK IÆRFS API No: 50-029-23188-00
04/16/04 KS/KA K GL V C/O SEe 35. T12N, R12E, 4286' NSL, 4501 WB...
04/17/04 LDK/KAK A DPERFS
04/27/04 JLG/KA K CORRECTIONS BP Exploration (Alaska)
.
.
g;O:3-aco
Schlumberger Drilling & Measurements
MWD/LWD Log Product Delivery
Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie
Well No S-118 Date Dispatched: 2-Jan-04
Installation/Rig Nabors 7ES Dispatched By: F. Alabi
Data No Of Prints No of Floppies
Surveys 2 1
~ - .~ Please sign and return to: James H. Johnson
"",i"d Byo . el "--'-.N _- ~ _ ~Y'\RECEIV BP "p"""" IAI,,") ,,,
ED Petrotechnical Data Center (LR2-l)
900 E. Benson Blvd.
! " t, 2? 2004 Anchorage, Alaska 99508
....; \ i Fax: 907-564-4005
e-mail address: johnsojh@bp.com
LWD Log Delivery V 1.1 , 10-02-03 Ala8ka "
Anchorage
Schlumberger Private
~~'bN\~
SCRLUMBERGER
Survey report
Client......... ... .......: BP Exploration (Alaska) Inc.
Field............ .... ....: Prudhoe Bay Unit - Aurora
Well. . . . . . . . . . . . . . . . . . . . .: S-118
API number...............: 50-029-23188-00
Engineer.................: B. Barnes
Rig Name:................: Nabors 7ES
STATE: . . . . . . . . . . . . . . . . . . .: Alaska
----- Survey calculation methods-------------
Method for positions.....: Minimum curvature
Method for DLS..,.. ,.....: Mason & Taylor
----- Depth reference -----------------------
Permanent datum..........: GROUND LEVEL
Depth reference. .... .....: Driller's Pipe Tally
GL above permanent..... ..: 35.80 ft
KB above permanent.......: N/A
DF above permanent.......: 63.78 ft
----- Vertical section origin----------------
Latitude (+N/S-).... .....: 0.00 ft
Departure (+E/W-). .......: 0.00 ft
----- Platform reference point---------------
Latitude (+N/S-).. ... ....: -999.25 ft
Departure (+E/W-).... ....: -999.25 ft
Azimuth from rotary table to target: 219.09 degrees
RECEIVED
[(c)2004 IDEAL ID8 1C_01]
J:\!'! 2? 2Q04
Alaska Oil & Gas COns. ComrI\IiOO
And\cIf8ge
. ~~~r)\~
8-Jan-2004 13:51:03
Spud date... .............:
Last survey date.........:
Total accepted surveys...:
MD of first survey....,..:
MD of last survey........:
..
g2C)3 ~' ~~ð
Page
1 of 4
03-Jan-03
08-Jan-04
79
0.00 ft
7255.00 ft
.
----- Geomagnetic data ----------------------
Magnetic model. ..........: BGGM version 2003
Magnetic date.. ..........: 03-Jan-2004
Magnetic field strength..: 1151.37 RCNT
Magnetic dec (+E/W-).....: 25.27 degrees
Magnetic dip.... .........: 80.86 degrees
----- MWD survey Reference
Reference G.. ... .........:
Reference R.. ... .... .....:
Reference Dip.... ........:
Tolerance of G...........:
Tolerance of R...........:
Tolerance of Dip.........:
Criteria ---------
1002.68 mGal
1151. 37 RCNT
80.86 degrees
(+/-) 2.50 mGal
(+/-) 6.00 RCNT
(+/-) 0.45 degrees
.
----- Corrections ---------------------------
Magnetic dec (+E/W-).....: 25.27 degrees
Grid convergence (+E/W-).: 0.00 degrees
Total az corr (+E/W-) ....: 25.27 degrees
(Total az corr = magnetic dec - grid conv)
Survey Correction Type ...:
I=Sag Corrected Inclination
M=Schlumberger Magnetic Correction
S=Shell Magnetic Correction
F=Failed Axis Correction
R=Magnetic Resonance Tool Correction
D=Dmag Magnetic Correction
SCHLUMBERGER Survey Report 8-Jan-2004 13:51:03 Page 2 of 4
-------- ------ ------- ------ -------- -------- ---------------- -------------.....- ----- ----- ------
-------- ------ ------- ------ -------- -------- ---------------- --------------- ------
Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool
# depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr
(ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg)
-------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------
-------- ------ ------- ------ -------- -------- ---------------- --------------- ------
1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None
2 189.00 0.17 44.68 189.00 189.00 -0.28 0.20 0.20 0.28 44.68 0.09 GYR None
3 280.00 0.65 107.64 91.00 280.00 -0.60 0.14 0.78 0.80 79.95 0.65 GYR None
4 367.00 1. 90 98.68 87.00 366.97 -1.51 -0.23 2.68 2.69 94.87 1. 45 GYR None
5 460.00 2.64 96 .13 93.00 459.90 -3.46 -0.69 6.33 6.37 96.21 0.80 GYR None
6 550.00 3.51 94.62 90.00 549.77 -6.15 -1.13 11.14 11.20 95.81 0.97 GYR None
7 637.00 4.89 100.14 87.00 636.53 -9.45 -2.00 17.45 17.56 96.54 1. 65 GYR None .
8 705.98 6.43 108.23 68.98 705.18 -12.25 -3.73 24,01 24.30 98.82 2.51 G-Mag None
9 748.22 7.79 112.25 42.24 747.09 -13.92 -5.55 28.91 29.43 100.87 3.43 G-Mag None
10 841. 88 8.06 124.63 93.66 839.86 -16.27 -11.69 40.18 41. 85 106.21 1. 84 G-Mag None
11 935.56 8.93 146.31 93.68 932.54 -14.63 -21.47 49.62 54.07 113.40 3.52 G-Mag None
12 1032.70 10.80 161. 85 97.14 1028.26 -7.47 -36.40 56.64 67.33 122.72 3.33 G-Mag None
13 1128.68 10.17 176.40 95.98 1122.65 3.63 -53.40 59.98 80.30 131.68 2.83 G-Mag None
14 1224.57 10.87 202.64 95.89 1216.98 18.53 -70.20 57.03 90.45 140.91 5.00 G-Mag None
15 1319.26 13.50 218.71 94.69 1309,56 38.16 -87.08 46.67 98.80 151. 81 4.51 G-Mag None
16 1413.72 15.88 221. 39 94.46 1400.92 62.10 -105.38 31.23 109.91 163.49 2.62 G-Mag None
17 1509.10 17.39 221. 67 95.38 1492.31 89.38 -125.82 13 .12 126.50 174.04 1. 59 G-Mag None
18 1604.41 18.94 221.04 95.31 1582.87 119.07 -148.12 -6.50 148.27 182.51 1. 64 G-Mag None
19 1699.39 24.60 220.99 94.98 1671. 04 154.26 -174.69 -29.61 177 . 18 189.62 5.96 G-Mag None
20 1795.28 29.37 219.75 95.89 1756.46 197.74 -207.86 -57.75 215.73 195.53 5.01 G-Mag None
21 1890.92 31. 26 220.33 95.64 1839.02 246.01 -244.81 -88.81 260.42 199.94 2.00 G-Mag None .
22 1987.26 31. 98 220.79 96.34 1921.06 296.50 -283.18 -121.66 308.21 203.25 0.79 G-Mag None
23 2083.13 35.25 221.73 95.87 2000.89 349.53 -323.06 -156.67 359.04 205.87 3.45 G-Mag None
24 2179.33 38.27 225.49 96.20 2077.96 406.89 -364.68 -196.40 414.20 208.31 3.91 G-Mag None
25 2270.49 39.16 226.42 91. 16 2149.09 463.49 -404.31 -237.39 468.85 210.42 1.17 G-Mag None
26 2365.46 38.69 225.93 94.97 2222.97 522.71 -445.63 -280.44 526.53 212.18 0.59 G-Mag None
27 2460.90 37.25 225.28 95.44 2298.21 581.04 -486.70 -322.40 583.80 213.52 1. 57 G-Mag None
28 2558.83 36.63 224.94 97.93 2376.48 639.57 -528.24 -364.09 641.56 214.58 0.67 G-Mag None
29 2654.99 36.11 224.99 96.16 2453.91 696.29 -568.58 -404.39 697.72 215.42 0.54 G-Mag None
30 2752.30 33.40 224.64 97.31 2533.85 751.48 -607.93 -443.49 752.50 216.11 2.79 G-Mag None
[(c)2004 IDEAL ID8 1C 01]
- -
SCHLUMBERGER Survey Report 8-Jan-2004 13:51:03 Page 3 of 4
-------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------
-------- ------ ------- ------ -------- -------- ---------------- --------------- ------
Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool
# depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr
(ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg)
--- -------- ====== ------- ====== ======== ======== ================ =============== .c=== ===-= ====.=
-------- -------
31 2849.68 32.87 223.44 97.38 2615.39 804.51 -646.19 -480.49 805.25 216.63 0.87 G-Mag None
32 2944.85 29.42 225.08 95.17 2696.84 853.53 -681.46 -514.81 854.06 217.07 3.73 G-Mag None
33 3041.14 25.84 226.56 96.29 2782.13 897.87 -712.59 -546.81 898.21 217.50 3.79 G-Mag None
34 3135.60 22.84 224.89 94.46 2868.19 936.53 -739.74 -574.70 936.75 217.84 3.26 G-Mag None
35 3203.64 21.93 225.02 68.04 2931.10 962.30 -758.08 -593.01 962.47 218.03 1. 34 G-Mag None
36 3251.36 20.48 223.98 47.72 2975.59 979.48 -770.39 -605.11 979.62 218.15 3.14 Interpolated
37 3346.72 19.78 220.60 95.36 3065.13 1012.24 -794.64 -627.19 1012.34 218.28 1. 42 G-Mag None .
38 3442.11 16.17 220.51 95.39 3155.84 1041. 66 -817.00 -646.33 1041.75 218.35 3.78 G-Mag None
39 3538.42 12.73 224.02 96.31 3249.10 1065.65 -834.84 -662.42 1065.72 218.43 3.68 G-Mag None
40 3633.72 9.49 224.57 95.30 3342.60 1083.93 -847.99 -675.23 1083.99 218.53 3.40 G-Mag None
41 3731.39 7.57 219.22 97.67 3439.18 1098.38 -858.71 -684.95 1098.43 218.58 2.13 G-Mag None
42 3825.73 5.14 238.14 94.34 3532.95 1108.59 -865.76 -692.47 1108.63 218.65 3.37 G-Mag None
43 3922.02 5.15 236.74 96 .29 3628.85 1116.79 -870.40 -699.75 1116.80 218.80 0.13 G-Mag None
44 4016.13 4.84 239.35 94.11 3722.60 1124.54 -874.74 -706.70 1124.54 218.93 0.41 G-Mag None
45 4111.89 3.20 221.39 95.76 3818.13 1131. 00 -878.81 -711. 94 1131.00 219.01 2.14 G-Mag None
46 4207.18 0.62 194.01 95.29 3913.36 1134.13 -881.30 -713.83 1134.13 219.01 2.80 G-Mag None
47 4303.51 0.85 161.42 96.33 4009.68 1134.98 -882.49 -713.72 1134.98 218.96 0.49 G-Mag None
48 4398.65 0.61 187.77 95.14 4104.81 1135.79 -883.66 -713.57 1135.79 218.92 0.43 G-Mag None
49 4494.19 1. 06 180.25 95.54 4200.34 1136.91 -885.05 -713.64 1136.92 218.88 0.48 G-Mag None
50 4590.41 0.97 200.77 96.22 4296.55 1138.38 -886.70 -713.93 1138.39 218.84 0.39 G-Mag None
51 4686.27 1.41 201.77 95.86 4392.39 1140.28 -888.55 -714.66 1140.29 218.81 0.46 G-Mag None .
52 4781.07 0.98 21. 60 94.80 4487.18 1140.62 -888.88 -714.79 1140.63 218.80 2.52 G-Mag None
53 4877.79 1.12 23.51 96.72 4583.88 1138.92 -887.24 -714.11 1138.93 218.83 0.15 G-Mag None
54 4973.44 0.80 6.63 95.65 4679.52 1137.45 -885.72 -713.66 1137.46 218.86 0.44 G-Mag None
55 5069.56 0.62 17.37 96.12 4775.63 1136.40 -884.56 -713.43 1136.41 218.89 0.23 G-Mag None
56 5165.31 0.76 28.06 95.75 4871.38 1135.30 -883.51 -712.97 1135.30 218,90 0.20 G-Mag None
57 5259.78 0.51 27.87 94.47 4965.84 1134.27 -882.58 -712.48 1134.28 218.91 0.26 G-Mag None
58 5355.84 0.65 6.53 96.06 5061.89 1133.39 -881.66 -712.22 1133.40 218.93 0.27 G-Mag None
59 5452.08 0.74 24.08 96,24 5158.13 1132.33 -880.55 -711. 91 1132.33 218.95 0.24 G-Mag None
60 5546.85 0.78 31.88 94.77 5252.89 1131.10 -879.45 -711.32 1131. 10 218.97 0.12 G-Mag None
[(c)2004 IDEAL ID8 1C 01]
-
SCHLUMBERGER Survey Report 8-Jan-2004 13:51:03 Page 4 of 4
--- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------
-------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------
Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool
# depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr
(ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg)
--- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------
-------- ------ ------- ------ -------- -------- ---------------- --------------- ------
61 5643.41 0.73 34.59 96 .56 5349.44 1129.84 -878.38 -710.62 1129.84 218.97 0.06 G-Mag None
62 5739.08 1.41 85.49 95.67 5445.10 1128.42 -877.79 -709.10 1128.42 218.93 1.16 G-Mag None
63 5835.02 2.01 92.30 95.94 5540.99 1126-.59 -877.76 -706.24 1126.61 218.82 0.66 G-Mag None
64 5931.12 2.72 88.09 96.10 5637.01 1124.09 -877.75 -702.28 1124.12 218.66 0.76 G-Mag None
65 6026.26 2.89 85.45 95.14 5732.04 1120.95 -877.49 -697.63 1121. 02 218.49 0.22 G-Mag None
66 6122.36 2.78 84.68 96 .10 5828.02 1117.65 -877.08 -692.90 1117.75 218.31 0.12 G-Mag None
67 6218.26 1. 21 35.58 95.90 5923.86 1115.01 -876.04 -689.99 1115.14 218.22 2.28 G-Mag None .
68 6313.11 1. 73 42.28 94.85 6018.68 1112.58 -874.17 -688.44 1112.71 218.22 0.58 G-Mag None
69 6409.27 1. 79 33.63 96 .16 6114.80 1109.64 -871.84 -686.64 1109.77 218.22 0.28 G-Mag None
70 6505.75 1. 60 32.76 96.48 6211.23 1106.80 -869.46 -685.07 1106,92 218.24 0.20 G-Mag None
71 6599.49 2.26 5.28 93.74 6304.92 1103.96 -866.51 -684.19 1104.07 218.29 1.19 G-Mag None
72 6696.17 3.15 356.04 96.68 6401.49 1100.44 -861.97 -684.20 1100.51 218.44 1. 02 G-Mag None
73 6791.32 3.75 350.97 95.15 6496.47 1096.45 -856.28 -684.87 1096.48 218.65 0.71 G-Mag None
74 6887.46 2.16 315.15 96.14 6592 .49 1094.16 -851.89 -686.64 1094.17 218.87 2.46 G-Mag None
75 6984.06 1. 86 313.54 96.60 6689.03 1093.85 -849.52 -689.06 1093.85 219.05 0.32 G-Mag None
76 7078.68 1. 90 303.76 94.62 6783.60 1093.87 -847.59 -691.48 1093.87 219.21 0.34 G-Mag None
77 7173.71 1. 26 302.03 95.03 6878.59 1094.15 -846.17 -693.68 1094.16 219.34 0.68 G-Mag None
78 7198.83 1.16 289.23 25.12 6903.70 1094.27 -845.93 -694.15 1094.28 219.37 1.14 G-Mag None
79 7255.00 1.16 289.23 56.17 6959.86 1094.65 -845,56 -695.22 1094.67 219.43 0.00 Projected to TD
[(c) 2004 IDEAL ID8 lC 01] .
- -
.
.
.
n
II
.1
FRANK H. MURKOWSKI, GOVERNOR
AIfASIiA. ORAND GAS
CONSERVATION COMMISSION
Lowell Crane
Senior Drilling Engineer
BP Exploration (Alaska), Inc.
PO Box 196612
Anchorage AK 99519
333 W. 7'" AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Re: Prudhoe Bay Unit S-118
BP Exploration (Alaska), Inc.
Pennit No: 203-200
Surface Location: 4286' NSL, 4501' WEL, Sec. 35, T12N, R12E, UM
Bottomhole Location: 3408' NSL, 5216' WEL, Sec. 35, T12N, R12E, UM
Dear Mr. Crane:
Enclosed is the approved application for pennit to drill the above referenced development well.
This pennit to drill does not exempt you from obtaining additional pennits or approvals required
by law from other governmental agencies, and does not authorize conducting drilling operations
until all other required pennits and approvals have been issued. In addition, the Commission
reserves the right to withdraw the pennit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the
Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure
to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska
Administrative Code, or a Commission order, or the tenns and conditions of this pennit may
result in the revocation or suspension of the pennit. Please provide at least twenty-four (24)
hours notice for a representative of the Commission to witness any required test. Contact the
Commission's North Slope petroleum field inspector at 659-3607 (pager).
Sincerely,
BY ORDER OF THE COMMISSION
DATED this-1- day of December, 2003
cc: Department ofFish & Game, Habitat Section w/o encI.
Department of Environmental Conservation w/o encI.
Exploration, Production and Refineries Section
WGI-\- 12-/2-{2..00'3
_ STATE OF ALASKA a
ALASKA O-'ND GAS CONSERVATION COM_SION
PERMIT TO DRILL
20 MC 25.005 /
1a. Type of work II Drill o Redrill rb. Current Well Class o Exploratory 181 Development Oil o Multiple Zone
ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone
2. Operator Name: 5. Bond: B Blanket o Single Well 11. Well Name and Number:
BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU 5-118 ./
3. Address: 6. Proposed Depth: 12. Field I Pool(s):
P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 7278 TVD 6980 Prudhoe Bay Field I Aurora Pool
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface: ADL 028257
4286' NSL, 4501' WEL, SEC. 35, T12N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date:
Top of Productive Horizon:
3408' NSL, 5216' WEL, SEC. 35, T12N, R12E, UM December 31, 2003
Total Depth: 9. Acres in Property: 14. Distance to Nearest P.roperty:
3408' NSL, 5216' WEL, SEC. 35, T12N, R12E, UM 2560 9800'
4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan RKB 15. Distance to Nearest Well Within Pool
Surface: X-618930 y-5980490 Zone-ASP4 (Height above GL): = 64.7' feet S-112 is 1775' away
16. Deviated Wells: 17. Anticipated pressure (see 20 AAC 25.035)
Kickoff Depth 300 ft Maximum Hole Angle 40 0 Max. Downhole Pressure: 3400 psig. Max. Surface Pressure: 2732 psig
18...·.,C~~ingerogr~m ", .' T~ IP~emng LJ~R't!'II:!^f I;"'¡;¡"
Size \ ,.. ,.
Hole CasinQ WeiQht Grade CouDlina LenQth MD TVD MD TVD (includinQ staQe data)
30" 20" 91.5# H-40 Weld 80' Surface Surface 133' 133' 260 sx Arctic Set (ADDrox.)
9-7/8" 7-5/8" 29.7# L-80 BTC 3205' Surface Surface 3233' 2955' 386 sx Articset Lite 3, 199 sx 'G'
6-3/4" 5-1/2" 17# L-80 BTC-M 6754' Surface Surface 6782' 6485' 147 sx LiteCrete, 128 sx Class 'G'
6-314" 3-1/2" 9.2# L-80 IBT-M 496' 6782' 6485' 7278' 6980' LonQstrinQ Cemented with 5-1/2")
19. PRESf;NT WELL. cöNDrnöNSuMMARY(To. bø, cQmpletèqfO!'R~rill ANt) Re-entijÖ~$ti(jI)$)
Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured):
"""'>,,'..'\,", .....,."...,-"'..:. ¡.c:\ ',";/' ".'" ..
'?" "5
~ t I
Conductor
~ r
IntAr ~r-h
P .... r n ""LIllI,;. . .......
UnAr ¡ 'f ..... ,U
,...."....' f"¡ .' _
Af-.J,. ..., I ¿fill '"(
^ ~
Perforation Depth MD (ft): perfOration Depth TVD (ft): ~(¡~;:;~. Gemme ,
,e -af,'
20. Attachments B Filing Fee o BOP Sketch B Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis
B Property Plat o Diverter Sketch o Seabed Report B Drilling Fluid Program 18120 AAC 25.050 Requirements
21. Verbal Approval: Commission Representative: Date:
22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jim Smith, 564-5773
Printed Name I¡.?well Crane Title Senior Drilling Engineer
y pre~ared By Name/Number:
Permit To Drill API Number: )/ Permit APproval, J t A. See cover letter for
Number: 203-'.2..0<:3 50- 02...9- z... 3/:;;> Date: f¡lol:NJ'J other requirements
Conditions of Approval: Samples Required DYes ..!8rNo Mud Log Required r DYes ß No
Hydrogen Sulfide Measures DYes ß'I No Directional Survey Required .tg¡ Yes DNo
Other: 'T.e s t ¡SoPE To S"ooo r~t,
(ì.¿~ 1..0 Me zs,o~s [k) [1..) I ck" €-vt t,... V'e~,,';'y...( M.~t 1(,. wcU \led,
Original Signed By BY ORDER OF Date / ~ IÌ\ ð~
ADDroved Bv: ~~ro!>h 6",li.. COMMISSIONER THE COMMISSION
Form 10-401 Revised 3/2003 Su jmit I n Dl [ licate
p
e
..,tAt,. bp
..~~ ~~.
~..- -.......
--,~ ~,--
.'J'~\"
-
To:
Winton Aubert, AOGCC
Date: Nov. 26,2003
From: Jim Smith
Subject: Dispensation for 20 AAC 25.035 (c) on Aurora 8-118
BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter
/'
system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling
and Completion: Blowout Prevention Equipment and Diverter Requirements".
Experience and data gathered, summarized herein, supports rationale of the request.
To date, none of the 40-plus Ivishak wells at S-pad, nor the recent twenty AuroraIPolaris
wells have experienced pressure control or shallow gas problems above the surface
casing depth, apart from minor and inconsequential hydrate shows. The first twenty
surface holes for the AuroraIPolaris development were drilled no deeper than the shale
underlying the SV-1 sands; S-118 is planned to TD in the shallower SV-3 shale, as did
the most recent wells. The shale underlying the SV1 is the deepest planned surface
casing setting depth for future pad development wells. This casing point is ±600' TVD
above the U gnu horizon.
The shallowest and most recent RFT points recorded in the area are from S-201,
recording a pore pressure of 1,423psi at 3,175' TVDss (8.6 ppg EMW) and not exceeding
8.7 ppg EMW above 3700' TVDss. S-118 is planned to reach 9.6 ppg mud weight
before TD at 2,890' TVDss. Supporting surface hole gas detection information is on file
with the AOGCC from recently drilled S-105.
Your consideration of the waiver is appreciated.
Sincerely,
let-
h Jim Smith
GPB Drilling Engineer
564-5773
e e
¡Well Name: 18-118
Drill and Complete Plan Summary
I Type of Well
I Producer
Surface Location: X = 618,929.81' Y = 5,980,489.87'
As-Staked 4286' FSL, 4501' FEL, Sec. 35, T12N, R12E Umiat
Target Location: X = 618,230' Y = 5,979,600'
Kuparuk "C" sands 3407' FSL, 5217' FEL, Sec. 35, T12N, R12E Urn
Bottom Hole Location: X = 618,230' Y = 5,979,600'
3407' FSL, 5217' FEL, Sec. 35, T12N, R12E Urn
/'
I AFE Number: I AUD5M0068 I
I Rig: 1 Nabors 7ES
/"
I Estimated Start Date: 112/31/03 I /' I Operating days to complete: 112
[MQJ 7278'
I TVD: 16979'
I BF/MS: I
I RKB: 164.7'
I Well Design (conventional, slim hole, etc.): I Microbore (Iongstring) //
I Objective: I Kuparuk Formation - Target zone C sand
Mud Program:
9-7/8" Suñace Hole (0-3233'): Fresh Water Surface Hole Mud
Densitv Viscosity Yield Point API FL PH
(ppq) (seconds) (lb/100ft:¿) (mls/30min)
Initial 8.5 - 8.6 300 50 - 70 15 - 20 8.5- 9.5
below -2000' MD 9.3 - 9.5 200 40 - 45 <10 8.5 - 9.5
Sfc hole TD 9.7 max 200 40-45 <10 8.5- 9.5
6 %" Intermediate 1 Production Hole (3233' - 7278'): Fresh Water LSND
Interval Density Viscosity YP PV pH API HTHP
(ppg) (seconds) Filtrate Filtrate
Surface shoe 9.7 -10.0 40-60 20-29 8-15 8.5-9.5 6cc <10 by
to HRl /\ HRl
HRl to TD ¡(O.OI 40-60 20-29 8-15 8.5-9.5 6 cc <10
\..V
S-118 Permit to Drill
Page 1
e
e
Directional:
Vert I Anadrill plan 4
KOP: 1300'
Maximum Hole Angle: 40.10 at 2242' MD
Close Approach Wells: All wells pass major risk criteria. A surface gyro will be required
to a maximum of 1000'. IFR required.
Nearest Lease Line:
The nearest lease line is 9800' to the north of S-118 at the Kuparuk level.
Nearest Wells in the Pool:
The closest wells at the top of the Kuparuk are the S-112 producer at 1775' northeast and the
S-115 producer which is 2150 northwest, both at the Kuparuk level. /~
The S-04 (Ivishak) well is 340' to the east at the Kuparuk level.
Lo
Intermediate/Production Hole
Drilling:
o en Hole:
Drilling:
Open Hole:
Cased Hole:
MWD / GR
G ro to1000'max
MWD / GR /PWD
PEX plus sonic, contingent FMI
GR/CCL
Formation Markers:
Formation Tops MDbkb TVDss Estimated pore pressure, PPG
SV6 1700 1605
Base Permafrost 2014 1951
SV5 2408 2190
SV4 2651 2380
SV3 3125 2859
7-5/8" Casing 3233 2890
SV2 3281 2935
SV1 3620 3260 8.8 ppq
UG4 3852 3490 8.8 ppq
UG4A 3893 3530 8.8ppq* (see discussion in proQram)
UG3 4223 3860 9.0 PPQ
UG1 4768 4405 9.0 ppq
Ugnu Ma 5063 4700 8.7
WS2 Schrader Na 5153 4790 8.8
WS1 Schrader OA 5383 5020 8.8
Base Obf 5743 5380
Colville CM1 6623 6260
HRZ 6893 6530 10.0 PPQ mud weiQht (in prep for tarQet sand)
Kalubik 6978 6615
Kuparuk (C) tarQet 6983 6620 Target Sand 9.5 -9.8 ppq EMW
LCU (KUP B) 7035 6672
Kuparuk A 7063 6700
Miluveach 7128 6765
TD 7278 6915
TD Criteria 150' below Miluveach top
't·7
/0.0
S-118 Permit to Drill
Page 2
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e
C
IT b-
p
aSlnn, u Ing rogram:
Hole Csgl WtlFt Gr~e co~ Length Top Btm
Size Tbg O.D. MDITVD MDITVD bkb
30" 20" 91.5# H-40 WLD 80' GL 133/133
9-7/8" 7 5/8" 29.7# L-80 STC 3205' GL 3233'/2955'
6-3/4" 5-1/2" 17.0# L-80 STC-m 6754' GL 6782'/6485'
6-3/4" 3-1/2" 9.2# L-80 1ST-mod 496' 6782'/6485 7278'/6980'
Tubing 3-1/2" 9.2# L-80 1ST -mod 6754' GL 6782'/6485'
Casin Criteria:
Csgl WtlFt Grade Con"
Tb O.D.
20" 91.5# H-40 WLD
7 5/8" 29.7# L-80 STC
5-1/2" 17.0# L-80 STC-m
3-1/2" 9.2# L-80 1ST-mod
Cement Calculations:
The following surface cement calculations are based upon a single stage job using a port collar as
contingency if cement is not circulated to surface.
Casin Size 7-5/8" Surface
Basis: Lead: Based on 2014' of annulus in the permafrost @ 250% excess and 469' of open
hole from top of tail slurry to base permafrost @ 30% excess.
Lead TOC: To surface
Tail: Based on 750' MD open hole coverage + 30% excess + 85' shoe track volume.
Tail roc: At -2483' MD 2312' TVDbkb .
Total Cement Volume: Lead 305.4 bbl 11715 ft I
at 10.7 and .21·
Tail 41.1 bbll ft
an fisk.
8 ks of Dowell ARTICSET Lite 3
fisk.
sks of Dowell Premium 'G' at 15.8
Casing Size 5-1/2"x3-1/2" Production
Lon strin
Basis: Lead: Based on TOC 500' above top of Ugnu 4A formation & 30% excess above top of
Tail
Lead TOC: 3393' MD, 3040' TVDbkb
Tail: Based on TOC 500' MD above top of Kuparuk target + 30% excess + 80' shoe
volume
Tail roc: 6483' MD, 6120' TVDbkb
Total Cement Volume: Lead 59.9 bbls I ks of Dowell LiteCrete at 12.0
and .2 fisk.
Tail 27.4 bb154 f s of Dowell Premium 'G' at
15.8 and.2
8-118 Permit to Drill
Page 3
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.
Well Control:
Surface hole will be drilled without diverter (pending AOGCC approval). The production hole
well control equipment consists of 5000 psi working pressure pipe rams(2), blind/shear rams,
and annular preventer which will be installed on surface casing and is capable of handling
maximum potential surface pressures. Based upon calculations below BOP equipment will
be tested to -36Ð6"'psi
5"0190 WC;A-
Diverter, BOPE and drilling fluid system schematics on file with the AOGCC.
Production Interval-
· Maximum anticipated BHP:
· Maximum surface pressure:
3400 psi @ 6620' TVDss, 6685'TVD - Kuparuk C -Sands
2732 psi @ surface /
(based on BHP and a full column of gas from TD @ 0.10 psi/ft)
· Planned BOP test pressure:
· Planned completion fluid:
5000 psi
8.6 ppg filtered seawater / 6.8 ppg Diesel
Disposal:
· No annular injection in this well.
· Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind
and inject at DS-04.
· fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-
04 for injection. Haul all Class I wastes to Pad 3 for disposal.
$-118 Permit to Drill
Page 4
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DRILL AND COMPLETE PROCEDURE SUMMARY
Pre-Rig Work:
The 20" conductor is in place.
1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor.
2. If necessary, level the pad and prepare location for rig move.
3. Ensure any required plugs and I or well shut-ins have been accomplished in nearby wells for rig move
and close approach concerns.
Rig Operations:
1. MIRU Nabors 7ES.
2. Nipple up riser pipe (pending AOGCC diverter dispensation). PU 4" DP as required and stand back in
derrick.
3. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3233'
MD I 2955' TVD. The actual surface hole TO will be +1-100' MD below the SV3 sands.
4. Run and cement the 7-5/8", 29.7# surface casing back to surface. A port collar or stage tool may be
run in the casing to allow for secondary cementing if cement is not circulated to surface during primary
cementing operations. Drill cuttings returns will be used as a guide to determine hole washout and
assist in determining if the port collar is needed. 5av µ4A-
5. NU casing I tubing head. NU BOPE and test to4Q66-psi.
6. MU 6-3/4" drilling assembly with MWD/GR/PWD and RIH to float collar. Test the 9-5/8" casing to
3000 psi for 30 minutes.
7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8"
shoe and perform Leak Off Test.
8. Drill ahead to -150' of rat hole below base of the Kuparuk A-5. Condition hole for logging and POOH.
9. RU Schlumberger E-line unit. Make a single run with PEX plus sonic, if target pay is not conclusive, a
second (contingent) run with FMI may be needed. POOH and RD Schlumberger.
10. RIH with 6-3/4" clean out assembly and condition hole for running the 5 %" x 3 %" casing. POOH
laying down the 4" DP.
11. Run and cement the tapered production casing as required to cover all significant hydrocarbon
intervals. Displace the casing with seawater during cementing operations and freeze protect the 5 %"
x 7-5/8" annulus as required.
12. Test the casing to 4500 psi for 30 min.
13. Run the 3-1/2", 9.3#, L-80 gas lift completion assembly. Sting seal assembly into tieback receptacle
and test to 4500 psi for 30 minutes, test both the tubing and annulus sequentially.
14. Nipple down the BOPE. Nipple up and test the tree to 5000 psi.
15. Freeze protect the well to -2200' TVD and secure the well.
16. Rig down and move off.
Estimated Spud Date:
Jan 1, 2004
Jim Smith
GPB Drilling
564-5773
S-118 Permit to Drill
Page 5
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5-118 Hazards and Contingencies
Job 1: MIRU
þ> Standard Operating Procedures for H2S precautions should be followed at all times. ~
The highest level of H2S recently measured on S-pad was on S-40 @ 70 ppm, (January /
2000). The closest wells to S-118 (S-104,S-103,S-100 and S-101) all measured 8 ppm at
their last tests.
þ> The closest surface locations are S-116 (drilled just before S-118) and S-200, each at 15' from
well S-118. Surface shut-in's will be required for rig moves.
Job 2: Drillina Surface Hole
þ> No faults are expected to be penetrated by S-118 in the surface interval.
þ> There are the normal close approach issues for 15' well spacing in the surface hole. All wells
pass major risk criteria. The closest well (apart from those on close centers immediately after
spud) is S-41 at roughly 34' center-center at approximately 1245' MD.
þ> The SV sands may contain gas hydrates, though little has been encountered thus far in the recent
S-pad development. Hydrates will be treated at surface with appropriate mud products and
problems minimized by reduction in mud circulation rate as required.
Job 3: Install surface Casina
þ> It is critical that cement is circulated to surface for well integrity. 250% excess cement through the
permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 7-5/8"
port collar may be positioned at ±1000'MD to allow a secondary circulation as required.
Job 7: Drillina Intermediate I Production Hole
þ> S-118 will cross faults at -3150'TVDss (near 3500'MD in the SV2) and -6250'TVDss (near
6600'MD in the CM1)
þ> The faults mapped in the area produce some uncertainty around which side of a substantial fault
near the top of Kuparuk the wellbore will land. Logging will determine whether the target Kuparuk
sands have been penetrated on the desired side of the fault. It may be necessary to run an FMI
log after the PEX + sonic to select a new sidetrack target if the pay is insufficient.
þ> The target for this well is a circle of 80' radius at the top of Kuparuk. It will be necessary to closely
monitor surveys to ensure hitting the target. This target is bounded on all sides by faults about
200' away.
þ> The surface casing point is chosen just below the SV3 sands, leaving the SV1 open for the 6-3/4"
hole interval drilling. Differential sticking across the SV-1 sands has not been identified as a
major issue in the Aurora development, though the potential exists with the mud weight required
on this well.
þ> KICK TOLERANCE: In the worst case scenario of 9.761 ppg pore pressure at the Kuparuk target
depth, a fracture gradient of 12.2 ppg at the surface casing shoe, and 10.0 ppg mud in the hole, /'
kick tolerance is 15.3 bbls. An accurate LOT will be required as well as heightened
awareness for kick detection. Contact Drilling Superintendent if LOT is less than 12.2 ppg.
S-118 Permit to Drill
Page 6
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Job 8: Loa Production Hole
~ Ensure the hole is in very good condition prior to POOH for logs to avoid a stuck tool string or
bridges in the wellbore that may preclude wireline logging.
Job 9: Case & Cement Production Hole
~ The Ugnu 4A is expected to be oil bearing. For this reason the 5-1/2" casing will be cemented to
500' above the Ugnu 4A sand (the uppermost significant hydrocarbon). The top of the
hydrocarbon interval should be verified with PEX resistivity log during logging to assist in followup
work if cement does not rise to 500' above the Ugnu.
~ There is risk of cement bypass or jamming of the wiper dart during cementing of the 5-1/2" x 3-
1/2" production casing. Carefully measure the dart and confirm with vendor that the correct dart is
used for this application (capable of sealing in both 5-1/2" and 3-1/2" casing and with OD
adequate to clear into the 3-1/2" casing).
~ After freeze protecting the 5 %" x 7-5/8" casing annulus with 15 bbl of mud at 11.4 ppg followed by
38.5 bbl of dead crude at 7.5 ppg, the hydrostatic pressure will balance the 8.5 ppg pore pressure
just below the 7-5/8" casing shoe. Follow this procedure to ensure the annulus does not indicate
trapped pressure on the gauge. It will be necessary to pump a small amount of fluid down the
annulus after cementing the 5-1/2" by 3-1/2" casing to ensure the annulus remains open, this
should be done about 12 hours after cementing the string.
Job 12: Run Completion
Hazards and Contingencies
~ No hazards specific to this well have been identified for this phase of the well construction.
Job 13: ND/NUlRelease Ria
Hazards and Contingencies
~ No hazards specific to this well have been identified for this phase of the well construction.
8-118 Permit to Drill
Page 7
5-118 Proposed Completion ,/
TREE: 3-1/8" - 5M CIW Carbon Cellar Box Elevation = 36.2'
WELLHEAD: 11" - 5M FMC G5 RKB = 64.7' AMSL
3-1/2'''X' Landing Nipple with 2.813"seal bore. I 2200' I
7-5/8",29.7 #lft, L-80, BTC
I 3233'
3-1/2" x 1" Gas Lift Mandrels with handling pups installed.
GAS LIFT MANDRELS
TVD Size
3-1/2" 9.3# L-80,IBT-M
#
4
3
2
1
3000
4500
6400
2 jts. above
seal assy.
1"
1"
1"
1"
DV
DV
DV
DCK
Valve Type
5-1/2", 17.0 #Ift, L-80, BTC- _
Mod (reduced clearance cplg)
3-1/2" GLM, KGB2-9 with DCK-3 shear valve
chrome pups below this GLM to the seal bore
3-1/2" CMD Sliding sleeve
chrome pups
3-1/2" Seal Assembly, 17'
3-1/2" PBR
5-1/2" x 3-1/2" XO placed +/-200' above the top Kuparuk /
6740'
6780'
6783'
. 3-1/2" 'X' Landing Nipple with 2.813" seal bore (50' above Kup C) I 6933'
Approx. -6540 TVDss
3-1/2" 'X' Landing Nipple with 2.813" seal bore (50' above Kup A) I 7013'
Approx -6665 TVDss
Plug Back Depth
17193'
3-1/2",9.3 #Ift, L-80, IBT-M
17278'
Date
1 0/22/03
Rev By Comments
JES Proposed Well Completion
Microbore with 5-1/2" x 3-1/2" tapered long-string
Aurora
WELL: Producer
API NO: 50-029-11111
BP Alaska Drilling & Wells
S-118 (P4) Proposal
Schlumberuer
Latitude Longitude
N 70.35535011 W 149.03416276
N 70.35535011 W 149.03416276
N 70.35535011 W 149.03415213
N 70.35535011 W 149.03415155
N 70.35535011 W 149.03412025
566.67 4.00 90.00 566.45 501.75 -5.87 0.00 9.30 1.50 1.50 0.00 95.99M 5980490.15 618939.30 N 70.35535011 W 149.03408721
600.00 4.70 95.99 599.69 534.99 -7.35 -0.14 11.83 2.50 2.10 17.97 106.34M 5980490.05 618941.83 N 70.35534972 W 149.03406674
700.00 6.98 106.34 699.16 634.46 -11.94 -2.28 21.73 2.50 2.28 10.35 19.73G 5980488.07 618951.76 N 70.35534388 W 149.03398632
764.00 8.50 110.00 762.58 697.88 -14.99 -4.99 29.90 2.50 2.38 5.71 123.76G 5980485.48 618959.98 N 70.35533647 W 149.03391994
800.00 7.95 116.51 798.21 733.51 -16.40 -7.01 34.63 3.00 -1.53 18.07 117.32G 5980483.54 618964.74 N 70.35533095 W 149.03388155
900.00 7.09 138.64 897.37 832.67 -16.89 -14.73 44.90 3.00 -0.86 22.13 95.37G 5980475.98 618975.13 N 70.35530986 W 149.03379816
1000.00 7.43 162.39 996.59 931.89 -12.31 -25.53 50.94 3.00 0.34 23.75 71.80G 5980465.28 618981.33 N 70.35528036 W 149..14
1100.00 8.84 181.27 1095.60 1030.90 -2.69 -39.38 52.73 3.00 1.41 18.88 53.11G 5980451.4 7 618983.34 N 70.35524252 W 149. 64
1200.00 10.90 194.05 1194.13 1129.43 11.95 -56.24 50.26 3.00 2.07 12.78 40.51G 5980434.57 618981.14 N 70.35519646 W 149.0 467
1300,00 13.33 202.54 1291.90 1227.20 31.57 -76.07 43.54 3.00 2.42 8.48 32.22G 5980414.64 618974.74 N 70.35514230 W 149.03380920
1400.00 15.94 208.36 1388.65 1323.95 56.12 ~98.80 32.60 3.00 2.62 5.83 26.57G 5980391.74 618964.16 N 70.35508019 W 149.03389807
1500.00 18.67 212.56 1484.12 1419.42 85.52 -124.39 17.45 3.00 2.73 4.19 22.57G 5980365.92 618949.42 N 70.35501029 W 149.03402104
1600.00 21.47 215.70 1578.04 1513.34 119.71 -152.75 -1.85 3.00 2.80 3.15 19.61G 5980337.25 618930.58 N 70.35493281 W 149.03417777
1655.83 23.06 217.14 1629.70 1565.00 140.84 -169.77 -14.41 3.00 2.84 2.57 18.29G 5980320.04 618918.28 N 70.35488632 W 149.03427980
1700.00 24.32 218.15 1670.15 1605.45 158.58 -183.81 -25.26 3.00 2.86 2.29 17.36G 5980305.82 618907.67 N 70.35484794 W 149.03436783
1800.00 27.20 220.11 1760.20 1695.50 202.02 -217.49 -52.70 3.00 2.88 1.96 15.60G 5980271.72 618880.76 N 70.35475593 W 149.03459069
1900.00 30.10 221.71 1847.96 1783.26 249.93 -253.70 -84.12 3.00 2.90 1.61 14.19G 5980235.02 618849.93 N 70.35465703 W 149.03484575
2000,00 33,01 223.06 1933.16 1868.46 302.17 -292.32 -119.41 3.00 2.92 1.35 13.04G 5980195.84 618815.26 N 70.35455150 W 149.03513231
Report Date:
Client:
Field:
Structure I Slot:
Well:
Borehole:
UWI/API#:
Survey Name I Date:
Tort I AHD I 0011 ERD ratio:
Grid Coordinate System:
Location LatlLong:
Location Grid NIE Y/X:
Grid Convergence Angle:
Grid Scale Factor:
October 21, 2003
BP Exploration Alaska
Prudhoe Bay Unit - WOA
S·PAD/S-1189-18-3 III bill I III_hi 5
~~~~;-118 Feasl I .~
50029
8-118 (P4) 1 October 21,2003
93.367' 11220.38 ft 15,0751 0. m
NAD27 Alaska State Planes, Zone 04, US Feet
N 70.35535011, W 149.03416276
N 5980490.000 ftUS, E 618930.000 ftUS
.¡{).90963117'
0,99991607
Comments
RT
KOP Bid 1.5/100
G1
Cry 2.5/100
Cry 3/100
SV6
Well Design Ver 3.1RT-8P3.03-HF1.2 Bld( d031rt-546)
Survey I DLS Computation Method:
Vertical Section Azimuth:
dy Vertical Section Origin:
TVD Reference Datum:
TVD Reference Elevation:
Sea Bed I Ground Level Elevation:
Magnetic Declination:
Total Field Strength:
Magnetic Dip:
Declination Date:
Magnetic Declination Model:
North Reference:
Total Corr Mag North·> True North:
Local Coordinates Referenced To:
Minimum Curvature 1 Lubinski
219.100'
N 0000 ft, E 0,000 ft
KB
64.7 ft relative to MSL
0.000 ft relative to MSL
25.151'
57575.950 nT
80.860'
April 15, 2004
BGGM 2003
True North
+25.151'
Well Head
e
8-118 9-18-3\Plan 8-118\8-118\8-118 (P4)
Generated 10/21/20033:18 PM Page 1 of 3
Comments Latitude Longitude
N 70.35453644 W 149.03517426
N 70.35443964 W 149.03544958
2200.00 38.88 225.22 2095.01 2030.31 419.03 -376.42 -201.23 3.00 2.94 1.00 11.29G 5980110.46 618734.78 N 70.35432175 W 149.03579669
End Cry 2241.65 40.10 225.60 2127.15 2062.45 445.36 -395.02 -220,10 3.00 2.94 0.91 O.OOG 5980091.57 618716.22 N 70.35427095 W 149.03594983
EOUC 2264.59 40.10 225.60 2144.70 2080.00 460.04 -405.36 -230.65 0.00 0.00 0.00 O.OOG 5980081.07 618705.83 N 70.35424270 W 149.03603556
SV5 2408.41 40.10 225.60 2254.70 2190.00 552.09 -470.18 -296.84 0.00 0.00 0.00 O.OOG 5980015.21 618640.69 N 70.35406560 W 149.03657294
Drp 2.5/100 2478.53 40.10 225.60 2308.34 2243.64 596,98 -501.79 -329.11 0.00 0.00 0.00 180.00G 5979983.09 618608.92 N 70.35397924 W 149.03683497
2500.00 39.57 225.60 2324.82 2260.12 610.64 -511.41 -338.94 2.50 -2.50 0.00 180.00G 5979973.32 618599.25 N 70.35395295 W 149.03691474
2600.00 37.07 225.60 2403.27 2338.57 672.24 -554.79 -383.23 2.50 -2.50 0.00 180.00G 5979929.24 618555.66 N 70.35383444 W 149.03727435
SV4 2651.48 35.78 225.60 2444.70 2380.00 702.61 -576.18 -405.07 2.50 -2.50 0.00 180.00G 5979907.51 618534.16 N 70.35377600 W 149.03745166
2700.00 34.57 225.60 2484.36 2419.66 730.38 -595.74 -425.04 2.50 -2.50 0.00 180.00G 5979887.64 618514.51 N 70.35372257 W 149..76
2800.00 32.07 225.60 2567.91 2503.21 784.95 -634.17 -464.28 2.50 -2.50 0.00 180.00G 5979848.60 618475.89 N 70.35361758 W 149. 34
2900.00 29.57 225.60 2653.79 2589.09 835.85 -670.01 -500.87 2.50 -2.50 0.00 180.00G 5979812.18 618439.87 N 70.35351965 W 149.03822946
3000.00 27.07 225.60 2741.81 2677.11 882.98 -703.20 -534.76 2.50 -2.50 0.00 180.00G 5979778.46 618406.51 N 70.35342897 W 149.03850458
3100.00 24.57 225.60 2831.82 2767.12 926.25 -733.67 -565.87 2.50 -2.50 0.00 180.00G 5979747.50 618375.89 N 70.35334572 W 149.03875716
SV3 3125.09 23.94 225.60 2854.70 2790.00 936.49 -740.89 -573.24 2.50 -2.50 0.00 180.00G 5979740.17 618368.65 N 70.35332602 W 149.03881694
3200.00 22.07 225.60 2923.65 2858.95 965.57 -761.37 -594.15 2.50 -2.50 0.00 180.00G 5979719.36 618348.06 N 70.35327005 W 149.03898673
7-5/8" Csg PI 3233.41 21.23 225.60 2954.70 2890.00 977.82 -769.99 -602.96 2.50 -2.50 0.00 180.00G 5979710.60 618339.39 N 70.35324649 W 149.03905822
SV2 3281.49 20.03 225.60 2999.70 2935.00 994.65 -781.85 -615.06 2.50 -2.50 0.00 180.00G 5979698.55 618327.48 N 70.35321410 W 149.03915648
3300.00 19.57 225.60 3017.11 2952.41 1000.88 -786.23 -619.54 2.50 -2.50 0.00 180,OOG 5979694.10 618323.07 N 70.35320212 W 149.03919284
3400.00 17.07 225.60 3112.04 3047.34 1032.11 -808.22 -641.99 2.50 -2.50 0.00 180.00G 5979671.76 618300.98 N 70.35314204 W 149.03937511
3500.00 14.57 225.60 3208.24 3143.54 1059.19 -827.29 -661.46 2.50 -2,50 0.00 180.00G 5979652.38 618281.81 N 70.35308993 W 149.03953320
3600.00 12.07 225.60 3305.55 3240.85 1082.07 -843.41 -677.92 2.50 -2.50 0.00 180.00G 5979636.01 618265.61 N 70.35304590 W 149.03966679
SV1 3619.57 11.58 225.60 3324.70 3260.00 1086.06 -846.22 -680.78 2.50 -2.50 0.00 180.00G 5979633.16 618262.79 N 70.35303824 W 149.03969004
3700.00 9.57 225.60 3403.76 3339.06 1100.72 -856.54 -691.33 2.50 -2.50 0.00 180.00G 5979622,66 618252.42 N 70.35301002 W 149.03977564
Faull Crossing 3786.89 7.40 225.60 3489.70 3425.00 1113.45 -865.51 -700.48 2.50 -2.50 0.00 180.00G 5979613.55 618243.41 N 70.35298552 W 149.03984996
3800.00 7.07 225.60 3502.70 3438.00 1115,09 -866.66 -701.66 2.50 -2.50 0.00 180.00G 5979612.38 618242.25 N 70.35298237 W 149.03985953
UG4 3852.33 5.76 225.60 3554.70 3490.00 1120.90 -870.75 -705.84 2.50 -2.50 0.00 180.00G 5979608.23 618238.14 N 70.35297119 W 149.03989343
UG4A 3892.50 4.76 225.60 3594.70 3530.00 1124.56 -873.33 -708.47 2.50 -2.50 0.00 -134.40M 5979605.61 618235.55 N 70.35296416 W 149..78
3900.00 4.57 225.60 3602.18 3537.48 1125.16 -873.76 -708.90 2.50 -2.50 0.00 -134.40M 5979605.18 618235.12 N 70.35296299 W 149. 32
4000.00 2.07 225.60 3702.00 3637.30 1130.91 -877.81 -713.04 2.50 -2.50 0.00 -134.40M 5979601.06 618231.05 N 70.35295193 W 149. 188
End Drp 4082.71 0.00 225.60 3784.70 3720.00 1132.40 -878.85 -714.10 2.50, -2.50 ·0.00 -134.40M: 5979600.00 618230.00 N 70.35294907 W 149.03996054
,
UG3 4222.71 0.00 225.60 3924.70 3860.00 1,132.40 -878.85 -714.10 0.00 0.00 0.00 -134.40M 5979600.00. 618230.00, N 70.35294907 W 149.03996054
UG1 4767.71 0.00 225.60 4469.70 4405.00 1132.40 -878.85 -714.10 0.00 0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W149.03996054
Ma 5062.71 0.00 225.60 4764.70 4700.00 1132.40 -878.85 -714.10 0.00 0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
Na 5152.71 0.00 225.60 4854.70 4790.00 1132.40 -878.85 -714.10 0.00 0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
OA 5382.71 0.00 225.60 5084.70 5020.00 1132.40 -878.85 -714.10 0.00 0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
OBd 5552.71 0.00 225.60 5254.70 5190.00 1132.40 -878.85 -714.10 0.00 0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
OBf 5642.71 0.00 225.60 5344.70 5280.00 1132.40 -878.85 -714.10 0.00 0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
OBf Base 5742.71 0.00 225.60 5444.70 5380.00 1132.40 -878.85 -714.10 0.00 0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
CM1 6622.71 0.00 225.60 6324.70 6260.00 1132.40 -878.85 -714.10 0.00 0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
WellDesign Ver 3.1 RT-8P3.03-HF1.2 Bld( d031 rt-546 )
8-118 9-18-3\Plan 8-118\8-118\8-118 (P4)
Generated 10/21/2003 3: 18 PM Page 2 of 3
Longitude
Comments
Kalubik 6977. 71 0.00 225.60 6679.70 6615.00 1132.40 -878.85 -714.10 0.00
8-118 Tgt 6982.71 0.00 225.60 6684.70 6620,00 1132.40 -878.85 -714.10 0.00
TKUP / C 6982.72 0.00 225.60 6684.71 6620.01 1132.40 -878.85 -714.10 0.00
LCU 1 Kup B 7034.71 0.00 225.60 6736.70 6672.00 1132.40 -878.85 -714.10 0.00
KupA 7062.71 0.00 225.60 6764.70 6700.00 1132.40 -878.85 -714.10 0.00
7127.71 0.00 225.60 6829.70 6765.00 1132.40 -878.85 -714.10 0.00
TMLV 7127.72 0.00 225.60 6829.71 6765.01 1132.40 -878.85 -714.10 0.00
TO 15-1/2" Csg 7277.71 ~ 0.00 225.60 6979.70 6915.00 1132.40 -878.85 -714.10 0.00
LeQal DescriDtion:
NorthinQ IV) IftUSl EastinQ IX) IftUSl
8urface: 4286 F8L 4501 FEL 835 T12N R12E UM 5980490.00 618930.00
8-118 Tgt: 3407 F8L 5217 FEL 835 T12N R12E UM 5979600.00 618230.00
BHL: 3407 F8L 5217 FEL 835 T12N R12E UM 5979600.00 618230.00
Well Design Ver 3.1 RT-8P3.03-HF1.2 Bld( d031 rt-546 )
8-118 9-18-3\Plan 8-118\8-118\8-118 (P4)
Latitude
N 70.35294907 W 149.03996054
0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
0.00 0.00 -134.40M 5979600.00 618230.00 N 70.35294907 W 149.03996054
0.00 0.00 O.OOM 5979600.00 618230.00 N 70.35294907 W 149.03996054
e
e
Generated 10/21/20033:18 PM Page 3 of 3
e
e
Schlumberger
WELL
S-118 (P4)
FIELD
Prudhoe Bay Unit - WOA
SlRUCTIJRE S-PAD
Magnetic Parameters
Model: BGGM2003
Dip: 80,860'
MagDec: +25.151'
TVD Ref: KB (64.70 II. above MSL)
SNyDate: 0ct0ber21,2003
g 3000
0
0
0
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0 4000
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Date: April 15. 2004
FS: 57575.9nT
Surface location
Lat: N702119.260
Lon: W14922.986
MisceIaneous
Slot: $-1189-18-3
Plan; S-118 (P4)
NAD27 Alaska state Planes, Zone 04, US Feet
Northing 5980490.00 ftUS Grid Cony; +Ð.90963117'
Easling: 618930.00ftUS Scale Fact: 0.9999160676
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1000
2000
3000
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I---KOP Bid 1.51100
,.-..- '_n_.._.. 13'
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TO /5-112" Csg
1000
2000
5000
6000
7000
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Vertical Section (ft) Azim = 219.1°, Scale = 1 (in):1000(ft) Origin = 0 N/-S, 0 E/-W
o
1000
2000
3000
4000
5000
6000
7000
e
e
Schlumberger
WELL
S-118 (P4)
FIELD
Prudhoe Bay Unit - WOA
STRUCTURE S-PAD
Magnetic ~arameteB
Model BGGM 2003
Dip: 80.860"
MagDec: +25.151'
Date" Apri115,2004
FS: 57575.901
Surface Location
Lat N702119.260
Lon W14922.986
NA027 Alaska State Planes, Zone 04, US Faet
Northing: 5980490.00ftUS GridCorw: +(I.90963117"
Easting: 618930.00 flUS Scale Fact 0.9999160676
""""""'"
Slot: 5-1189-18-3
Plan: S-118 (P4)
TVD Ref: KB (64.10 ft above MSl)
SrvyDate: 0ct0ber21,2003
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<<< W Scale = 1(in):200(ft) E >>>
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200
e
BPX AK
Antico lision Report
e
NO GLOBAL SCAN: Using user defined selection,& scan criteria
Interpolation Method: MD Interval: 50.00 ft
Deptþ Range: 28,50 to 7277.71 ft
Maximum Radius: 10000.00 ft
Reference:
Error Model:
Scan Method:
Error Surface:
Principal Plan & PLANNED PROGRAM
18CWSA Ellipse
Trav Cylinder North
Ellipse + Casing
Survey Program for Definitive Well path
Date: 11/6/2002 Validated: No
Planned From To Survey
ft ft
28.50 7277.71 Planned: Plan #4 V2
Version: 2
Toolcode
Tool Name
MWD+IFR+M8
MWD + IFR + Multi Station
Casing Points
3233.41 2954.70
7277.70 6979.69
7.625
5.500
9.875
6.750
7"
51/2"
PB S Pad Plan S-111 Plan 8-111 V3 Plan: PI 500.59 500.00 241.43 9.06 232.38 Pass: Major Risk
PB S Pad Plan 8-116 Plan S-116 V3 Plan: PI 499.81 500.00 15.97 8.47 7.50 Pass: Major Risk
PB 8 Pad Plan S-119 Plan 8-119 V2 Plan: PI 449.87 450.00 211.11 7.55 203.56 Pass: Major Risk
PB 8 Pad Plan 8-120 Plan S-120 V2 Plan: PI 450.26 450.00 74.92 7.64 67.29 Pass: Major Risk
PB S Pad 8-01A S-01A V1 4553.63 4450.00 276.69 119,86 156.84 Pass: Major Risk
PB S Pad 8-01 B S-01 B V1 4549.75 4450.00 276.69 119.85 156,84 Pass: Major Risk
PB S Pad 8-01 8-01 V1 4488.20 4350.00 349.18 99.18 249.99 Pass: Major Risk
PB 8 Pad 8-02APB1 8-02APB 1 V1 2185.85 2100.00 404.71 36.62 368.09 Pass: Major Risk
PB 8 Pad 8-02A S-02A V1 2185.85 2100.00 404.71 36.62 368.09 Pass: Major Risk
PB S Pad 8-02 S-02 V1 2184.93 2100.00 404.66 36.60 368.06 Pass: Major Risk
PB S Pad 8-03 S-03 V1 2161.72 2150.00 400.29 33.85 366.45 Pass: Major Risk
PB S Pad 8-04 8-04 V1 7266.31 7150.00 249.88 147.65 102.23 Pass: Major Risk
PB 8 Pad 8-05APB1 8-05APB 1 V1 1880.23 1850.00 639.86 29.43 610.43 Pass: Major Risk
PB 8 Pad 8-05A S-05A V1 1880.23 1850.00 639.86 29.43 610.43 Pass: Major Risk
PB 8 Pad 8-05 S-05 V1 1875.19 1850.00 639.72 29.33 610.39 Pass: Major Risk
PB S Pad 8-06 S-06 V1 1775.89 1750.00 722.48 29.04 693.43 Pass: Major Risk
PB S Pad 8-07A 8-07A V1 1500.00 1450.00 809.58 21.24 788.34 Pass: Major Risk
PB S Pad 8-07 8-07 V1 1500.00 1450.00 809.58 21.24 788.34 Pass: Major Risk
PB S Pad 8-08 S-08 V1 1565.26 1550.00 902.31 24.15 878.16 Pass: Major Risk
PB S Pad S-08 S-08A V1 1565.26 1550.00 902.31 24.16 878.16 Pass: Major Risk
PB S Pad S-08 S-08B V3 1565.26 1550.00 902.31 24.16 878.16 Pass: Major Risk
PB S Pad 8-09 8-09 V1 1547.48 1550.00 1001.41 24.46 976.94 Pass: Major Risk
PB S Pad 8-100 8-100 V10 350.06 350.00 151.75 5.75 146.00 Pass: Major Risk
PB 8 Pad 8-101 8-101 V2 597.11 600.00 121.78 11.29 110.49 Pass: Major Risk
PB 8 Pad 8-101 S-101PB1 V9 597.36 600.00 122.46 11.39 111.07 Pass: Major Risk
PB 8 Pad S-102 Plan#4 S-102A V1 Plan: 250.49 250.00 166.92 4.54 162.37 Pass: Major Risk
PB 8 Pad 8-102 8-102V11 250.49 250.00 166.92 4.54 162.37 Pass: Major Risk
PB S Pad 8-102 8-102PB1 V14 250.49 250.00 166.92 4.54 162.37 Pass: Major Risk
PB S Pad 8-103 S-103 V6 597.80 600.00 286.54 9.08 277.45 Pass: Major Risk
PB 8 Pad 8-104 S-104 VO 350.28 350.00 360.77 6.39 354.38 Pass: Major Risk
PB 8 Pad S-105 8-105 V5 596.87 600.00 350.25 9.43 340.82 Pass: Major Risk
PB S Pad S-106 S-106 V2 294.49 300.00 316.90 6.13 310.78 Pass: Major Risk
PB S Pad S-106 8-106PB1 V12 294.49 300.00 316.90 6.21 310.69 Pass: Major Risk
PB S Pad S-107 8-107 V35 444.56 450.00 271.91 8.64 263.27 Pass: Major Risk
PB S Pad S-108 S-108 V6 444.49 450.00 221.96 7.36 214.59 Pass: Major Risk
PB S Pad 8-109 S-109 V8 696.12 700.00 176.53 11.88 164.65 Pass: Major Risk
PB 8 Pad S-109 S-109PB1 V2 696.12 700.00 176.53 11.88 164.65 Pass: Major Risk
PB S Pad S-10APB1 8-10APB1 V1 1500.00 1499.96 1084.35 23.66 1060.68 Pass: Major Risk
PB S Pad S-10A 8-10A V1 1500.00 1500.00 1084.41 23.61 1060.80 Pass: Major Risk
PB S Pad S-10 S-10 V1 1500,00 1499.96 1084.35 23.66 1060.68 Pass: Major Risk
PB S Pad 8-110 S-110V18 545.51 550.00 191.05 10.35 180.70 Pass: Major Risk
PB 8 Pad 8-112 S-112V19 495.21 500.00 42.46 9.27 33.19 Pass: Major Risk
PB 8 Pad S-113 8-113V13 590.82 600.00 260.76 11.04 249.72 Pass: Major Risk
PB S Pad S-113 8-113A V2 590.82 600.00 260.76 10.89 249.87 Pass: Major Risk
e
BPX AK
Anticollision Report
e
Summary
PB 8 Pad 8-113 8-113B V5 590.82 600.00 260.76 10.89 249.87 Pass: Major Risk
PB S Pad 8-114 S-114V13 493.64 500.00 333.95 9.63 324.32 Pass: Major Risk
PB S Pad 8-114 S-114A V6 493.64 500.00 333.95 9.48 324.48 Pass: Major Risk
PB S Pad 8-115 S-115 ST V1 Plan: Plan 647.71 650.00 111.12 10.46 100.67 Pass: Major Risk
PB S Pad 8-115 S-115 V7 647.71 650.00 111.12 10.36 100.76 Pass: Major Risk
PB S Pad S-117 8-117V4 598.91 600.00 89.41 10.16 79.25 Pass: Major Risk
PB 8 Pad S-11A 8-11A V7 1300.00 1250.00 1216.16 21.56 1194.60 Pass: Major Risk
PB 8 Pad S-11 B 8-11B V5 1467.56 1450.00 1183.76 21.20 1162.56 Pass: Major Risk
PB 8 Pad S-11 S-11 V1 1480.78 1500.00 1183,62 21.45 1162.17 Pass: Major Risk
PB 8 Pad S-12A S-12A V1 1400.00 1400.00 1277.73 22.98 1254.75 Pass: Major Risk
PB 8 Pad 8-12 S-12 V1 1430.48 1450.00 1300.32 24.45 1275.87 Pass: Major Risk
PB S Pad 8-13 S-13 V1 1348.30 1350.00 1389.32 22.39 1366.93 Pass: Major Risk
PB S Pad 8-14 S-14 V1 1374.35 1400.00 1483.20 41.37 1441.83 Pass: Major Risk
PB S Pad 8-15 8-15 V2 2760,39 2550.00 547.63 46.73 500.90 Pass: Major Risk
PB S Pad S-16 8-16 V1 2888.65 2650.00 618.49 46.67 571.81 Pass: Major Risk
PB 8 Pad S-17 8-17 V1 4632.61 4450.00 555.17 95.53 459.64 Pass: Major Risk
PB 8 Pad S-17 8-17A V1 4632.61 4450.00 555.17 95.53 459.64 Pass: Major Risk
PB 8 Pad S-17 S-17AL 1 V1 4632.61 4450.00 555.17 95.53 459.64 Pass: Major Risk
PB 8 Pad 8-17 S-17APB1 V1 4632.61 4450.00 555.17 95.53 459.64 Pass: Major Risk
PB S Pad S-17 S-17B V1 4632.61 4450.00 555.17 95.53 459.64 Pass: Major Risk
PB S Pad 8-17 S-17C V1 4632.61 4450.00 555.17 95.36 459.81 Pass: Major Risk
PB 8 Pad 8-17 S-17CPB1 V2 4632.61 4450.00 555.17 95.36 459.81 Pass: Major Risk
PB S Pad 8-17 8-17CPB2 V1 4632.61 4450.00 555.17 95.36 459.81 Pass: Major Risk
PB 8 Pad 8-18 8-18 V1 2316.02 1700.00 1314.82 47,56 1267.26 Pass: Major Risk
PB 8 Pad S-18 8-18A V15 2318.53 1700.00 1314.92 47.65 1267.28 Pass: Major Risk
PB 8 Pad S-19 S-19 V1 2197.46 2100.01 359.84 37.40 322.44 Pass: Major Risk
PB 8 Pad S-200PB1 S-200PB1 V4 449.18 450,00 14.63 7.01 7.62 Pass: Major Risk
PB S Pad S-200 S-200 V2 449.18 450.00 14.63 7.12 7.51 Pass: Major Risk
PB S Pad 8-201 S-201 V2 250.28 250.00 300.35 4.17 296.19 Pass: Major Risk
PB S Pad 8-201 S-201PB1 V11 250.28 250.00 300.35 4.25 296.10 Pass: Major Risk
PB S Pad 8-20 8-20 V4 2134.59 2050.00 470.74 36.29 434.46 Pass: Major Risk
PB 8 Pad S-20 8-20A V2 2134.59 2050.00 470.74 36.28 434.46 Pass: Major Risk
PB 8 Pad S-213 S-213 V6 597.76 600.00 59.17 8.55 50.62 Pass: Major Risk
PB 8 Pad S-215 S-215 V7 2587.25 2350.00 764.35 41.64 722.71 Pass: Major Risk
PB 8 Pad S-216 S-216 V1 399.55 400.00 31.02 7.83 23.19 Pass: Major Risk
PB 8 Pad S-21 S-21 V1 2059.06 2000.00 497.31 30.93 466,38 Pass: Major Risk
PB 8 Pad 8-22A 8-22A V1 2261.52 2150.00 336.54 35.27 301.27 Pass: Major Risk
PB S Pad 8-22B 8-22B V2 2261.52 2150.00 336.54 35.51 301.03 Pass: Major Risk
PB S Pad 8-22 8-22 V1 2261.51 2150,00 336.54 35.27 301.28 Pass: Major Risk
PB S Pad 8-23 S-23 V1 2124.57 2050.00 446.22 32.35 413.87 Pass: Major Risk
PB S Pad S-24 Plan#4 8-24B VO Plan: 1963.61 1900.00 530.26 31.48 498.78 Pass: Major Risk
PB 8 Pad S-24 S-24 V5 1961.64 1900.00 530.23 31.25 498.98 Pass: Major Risk
PB 8 Pad S-24 S-24A V1 1963.61 1900.00 530.26 31.31 498.96 Pass: Major Risk
PB S Pad S-25APB1 8-25APB1 V1 1781.58 1800.00 531.08 56.28 474.80 Pass: Major Risk
PB S Pad S-25A 8-25A V1 1939,61 1900.00 575.52 29.78 545.74 Pass: Major Risk
PB S Pad 8-25 8-25 V1 1939.61 1900.00 575.52 29.78 545.74 Pass: Major Risk
PB 8 Pad S-26 S-26 V1 1893.20 1850.00 606.86 27.25 579.62 Pass: Major Risk
PB 8 Pad S-27 Plan S-27B V4 Plan: PI 1831.82 1800.00 658.52 26.46 632.06 Pass: Major Risk
PB S Pad S-27 S-27 V1 1831.44 1800.00 658.51 26.72 631.79 Pass: Major Risk
PB 8 Pad S-27 S-27A V2 1831.44 1800.00 658.51 25.74 632.77 Pass: Major Risk
PB 8 Pad S-28 8-28 V4 5223.12 5200.00 629.68 76.98 552.70 Pass: Major Risk
PB 8 Pad 8-28 8-28A V1 5223.12 5200.00 629.68 76.98 552.70 Pass: Major Risk
PB S Pad 8-28 8-28B V2 5224.10 5200.00 629.67 76.97 552.70 Pass: Major Risk
PB S Pad 8-28 8-28BPB1 V7 5224.10 5200.00 629.67 76.97 552.70 Pass: Major Risk
PB S Pad S-29AL 1 S-29AL 1 V1 1558.64 1550.00 927.29 21.97 905.31 Pass: Major Risk
PB 8 Pad S-29A Plan S-29AL2 VO Plan: 1561.80 1550.00 927.40 21,94 905.46 Pass: Major Risk
PB 8 Pad S-29A S-29A V1 1558.64 1550.00 927.29 21.97 905.31 Pass: Major Risk
PB 8 Pad S-29 Plan 8-29B V1 Plan: S- 1561.80 1550.00 927.40 22.11 905,29 Pass: Major Risk
PB 8 Pad 8-29 8-29 V1 1558.64 1550.00 927.29 21.97 905.31 Pass: Major Risk
PB S Pad 8-30 S-30 V1 1715.18 1700.00 780.13 26.43 753.70 Pass: Major Risk
PB S Pad 8-31A S-31A V3 1659.42 1650.00 833.60 24.59 809.00 Pass: Major Risk
PB S Pad 8-31 S-31 V1 1659.42 1650.00 833.60 24.59 809.00 Pass: Major Risk
PB S Pad S-32 S-32 V1 1458.48 1450.00 1061.38 22.37 1039.01 Pass: Major Risk
e
BPX AK
Anticollision Report
e
PB S Pad S-33 S-33 V1 1530.20 1500.00 880.94 21.99 858.95 Pass: Major Risk
PB S Pad S-34 S-34 V1 1331.21 1300.00 1141.62 17.40 1124.22 Pass: Major Risk
PB S Pad S-35 S-35 V1 1445.99 1450.00 1152.10 18.44 1133.66 Pass: Major Risk
PB S Pad S-36 S-36 V1 7268.37 7350.00 1219.92 104.74 1115.18 Pass: Major Risk
PB S Pad S-37 S-37 V1 1300.00 1300.00 1262.90 19.07 1243.83 Pass: Major Risk
PB S Pad S-38 S-38 V1 1500.00 1500.00 1019.21 19.48 999.73 Pass: Major Risk
PB S Pad S-40A S-40A V1 2654.43 2300.00 821.76 40.56 781.20 Pass: Major Risk
PB S Pad S-40 S-40 V1 2654.43 2300.00 821.76 40.56 781.20 Pass: Major Risk
PB S Pad S-41L1 S-41L1V1 1245.86 1250.00 34.09 19.34 14.75 Pass: Major Risk
PB S Pad S-41PB1 S-41PB1 V1 1245.86 1250.00 34.09 19.34 14.75 Pass: Major Risk
PB S Pad S-41 S-41 V1 1245.86 1250.00 34.09 19.34 14.75 Pass: Major Risk
PB S Pad S-42PB 1 S-42PB1 V1 1557.23 1550.00 61.90 19.89 42.02 Pass: Major Risk
PB S Pad S-42 S-42 V2 1557.23 1550.00 61.90 19.89 42.02 Pass: Major Risk
PB S Pad S-43L 1 S-43L 1 V2 1354.55 1350.00 35.33 17.52 17.81 Pass: Major Risk
PB S Pad S-43 S-43 V3 1354.55 1350.00 35.33 17.60 17.72 Pass: Major Risk
PB S Pad S-44L 1 PB1 S-44L 1 PB 1 V3 698.06 700.00 45.52 10.45 35.07 Pass: Major Risk
PB S Pad S-44L 1 S-44L 1 V5 698.06 700.00 45.52 10.54 34.99 Pass: Major Risk
PB S Pad S-44 S-44 V10 698.06 700.00 45.52 10.54 34.99 Pass: Major Risk
147
100
50
5-216 (5-216)
27
~50
'100
147
Field: Prudhoe Bay
Site: PB S Pad
Well: Plan S-118
Wellpath: Plan S-118
e
e
Travelling Cylinder Azimuth (TFO+AZI) (deg] vs Centre to Centre Separation [50ft/in]
Target: S-118 Tgt 1
Site: PB S Pad a
Drilling Target Conf.: 95%_
Description:
Map Northing: 5979600.00 ft
Map Easting : 618230.00 ft
Latitude: 70021'lO.617N
Shape: Circle
_I: Plan S-118
.ed on: Planned Program
Vertical Depth: 6620.00 ft below Mean Sea Level
Local +NI-S: -878.85 ft
Local +E/-W: -714.10 ft
Longitude: 149°02'23.858W
Radius: 80 ft
00
-lOO
-800
-900
-1000
~ ~ CJ CJ CJ CJ
CJ CJ CJ CJ
~ ~ ~ m I LO Ln
~ ~ ( ~ I I I I
~ ~ ~
~ ~
~
e
S-PAD
N 1100
N 1010
CXIU)
~~
íí
CIXJ)
........
::~~~~~
I I I I I I
tn(f)U)(/)(I)(f)
-. . .
~ ~ ~ ;¡:
I I I I
en (I) V) (f)
.................
~2~~~ª~~~~~~~~ª§~
~~~~~~~~~~~~~~~~~
N 840
U)
<0
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f-
Z
c(
-'
IL
~-
I
LEGEND
-+ AS-BUILT CONDUCTOR
. EXISTING CONDUCTOR
NOTES:
1. DATE OF SURVEY: NOVEMBER 2 & 4, 2003.
2. REFERENCE FIELD BOOK: W003-09 PAGES 71-74.
3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD 27.
4. GEODETIC COORDINATES ARE NAD-27.
5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.9999165.
6. HORIZONTAL CONTROL IS BASED ON MONUMENTS S-3
& S-4. (HELD S-4)
7. BASIS OF VERTICAL CONTROL IS OPERATOR MONUMENTATION.
ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM.
e
27
26
25
S PAD
34
1
-I'j-
35 I
PROJECT
AREA
36
2
VICINITY MAP
N.T.S.
f--
ã:
C>
z
F
(f)
X
w
~N~
MANIFOLD
MODULE
SURVEYOR'S CERTIFICATE
I HEREBY CERTIFY THAT I AM
PROPERLY REGISTERED AND LICENSED
TO PRACTICE LAND SURVEYING IN
THE STATE OF ALASKA AND THAT
THIS PLAT REPRESENTS A SURVEY
MADE BY ME OR UNDER MY DIRECT
SUPERVISION AND THAT ALL
DIMENSIONS AND OTHER DETAILS ARE
CORRECT AS OF NOVEMBER 4, 2003.
LOCATED WITHIN PROTRACTED SEC. 35, T. 12 N.. R. 12 E., UMIAT MERIDIAN, ALASKA
WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION
NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS
S-116 Y= 5,980,474.81 N. 1,009.97 70'21'19.111" 70.3553086' 355' 4,271' FSL
X= 618,929.95 E. 380.16 149'02'02.994" 149.0341650' . 4,502' FEL
S-118 Y=5,980,489.87 N. 1,009.84 70'21'19.259" 70.3553497" 35.8' 4,286' FSL
X= 618,929.81 E. 365.09 149'02'02.992" 149.0341644' 4,501' FEL
~, DRAWN: Obp
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DATE: 11 05/03
DRAWING: SHEET:
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SCALE: AS-BUILT CONDUCTORS
o 11 07 03 ISSUED FOR INFORMATION JJ K\\tf ENGINŒRS»IDI..ANDSUR'ÆYORS WELLS 5-116 & 5-118 1 OF 1
1I01\IIEST F'lREIIUD LANE 1"= 150'
NO. OAlE REVlSON BY CHK ANOfORAœ. ~A H503
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DATE
10/6/2003
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10/6/2003 INV# PR100103G
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PERMIT TO DRILL
IE AlTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE.
BP EXPLORATION, (ALASKA) INC.
PRUDHOE BAY UNIT
PO BOX 196612
ANCHORAGE, AK 99519-6612
NATIONAL CITY BANK
Ashland, Ohio
56-389
412
No. p 055167
CONSOLIDATED COMMERCIAL ACCOUNT
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B. P r.' "I'"
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DATE
October 6, 2003
AMOUNT
*******$100.00*******
fO THE
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ALASKA OIL & GAS CONSERVATION COMMISSION
333 W 7TH AVENUE
SUITE 100
ANCHORAGE, AK 99501-3539
1110 5 5 ~ b ? III I: 0... . 2 0 ~ 8 9 5 I: O. 2 ? B Ii ¡; III
: Field & Pool PRUDHOE BAY, AURORA OIL - 640120 Well Name: PRUDHOE BAY UN AURO S-118 Program DEV Well bore seg 0
PTD#: 2032000 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 11-01L GeoArea Unit On/Off Shore On Annular Disposal 0
Administration 1 P_ermit.fee ¡¡ttaçheJL _ _ _ _ _ _ _ ,_ ,,_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _
2 le¡¡se_number _appropri¡:¡te_ _ _ _ _ _ _ , , Yes _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ,
3 _U_nique weltnarne_and r:Jl!mb_er _ , _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ' _ _ _ _YeS _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
4 Well Joc¡:¡ted In_a_ d_efil1edpool, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ , _ , _ , _ _ _ , , _ _ _ _ , ,
5 WelUocated prpper _distance from driJling ul1itb9Ul1d_ary_ , , , , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes, , , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
6 WellJoc¡:¡ted prpper _distançe, from otheJ wells_ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ , , , , _ _ _ _ _ _ _ _ _ _ , _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _
7 _S_uffiçieI1Laçre¡¡Q.e,ay¡¡il¡:¡ble indJillillg uniL _ _ _ , _ _ , , , _ _ _ _ _ Yes _ _ _ , _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ,
8 Jfdevi¡;¡ted, is_ weJlbore platil1cJuded _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ Yes _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ , _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ ,
9 _Operator ol1l}' ¡¡ffecled party _ _ _ _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _
10 _Operator bas_appropriate-'~ond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _
11 Permit can Þe issued without conservaJiOI1 order, _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ , No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , _ , _ _ _ _ _ _ _ _ _ , _ , ,
Appr Date 12 Permit can Þe issued without ¡¡d_millistratille_approvaJ _ _ _ _ _ _ _ _ _ _ _ , , _ , , , _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ , , , _ , , _ _ _ _ _ _ _ _ _
RPC 12/1/2003 13 Can permit be approved before 15-day wait Yes
14 WeIUocatedwithil1¡;¡rea¡;¡nd_strat¡:¡_authorizedby_JlljectioIlOrder#(putIO#in_c,omrnellts)(ForNA _ _ _ _ _ _ _ _ _ _ _ _" ,_ _ _ _ _ _ _ _, _ _"" _ _ _ _ _ _ _ _ _ _,,_
15 _AJI weIJs_witJ1inJl4Jl'Jile_are.a_of reyiew identified (For $ervjceJ,\(ellol1l}'L _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
16 PJe.-produced il1jector; dur<ltion_of pre-productiOl1les$ th.m 3 mOl1ths_ (For_se(\/ice well onJy) _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _
17 ACMPJ'il1ding9fConsiJ>tel1cyhas bee_nJssuedJorJhis projeçt _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ , , , , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Engineering
Appr Date
IIWA- 1"4 ¥ 0 '$
Geology
Appr Date
RPC
Geologic
Commissioner:
PV;:;
e
18Condu_ctor string,PJovided _ _ _ _ _ _ _ _ _ ___Yes, _ _ _ _ _ _ _ , , , _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ , , _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , ,
19 _S_urface,ca$ing,pJotect$aILknownUSQWs _ _ _ _ _ _ , Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , ,
20 ,CMTvoladec:¡uateJo çirculate_oJl_cOl1d_uçtor,& SUJtCJ>g _ _ _ _ _ _ _ _ _ , , _ _ _ _ YeS _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
21 _CMT v_ol adec:¡uateJo tie-in Jong string to_surf ~g_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , No _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ , _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , ,
22 _CMT will coyer_aU J<l1owJl,pro_ductiYe horizons _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ Yes _ , _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , , _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _
23 _C_asing desigl1s ¡;¡d_equa_te for C,T, B&permaftost _ _ _ _ , , , , _ _ _ _ _ _ _ _ Yes, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ , _ , _ _ _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _
24 ,Adequ<ltet¡¡nk¡;¡ge_oJ re_serye pit, _, ,,_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , _ , _ , , _ _ _ _ _ _ Yes , , \ ¡¡bors7ES, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ,
25 Jta.re-drilt hasa 10-403 for <lbandonmeJlt been apPJoved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ , NA _ _ _ _ _ _ _ _ _ _ _ _ , _ , _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ ,
26 _Mequ<ltewellbore. $ep¡¡r¡:¡tjo_n_proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
27 Jtdiverter Jeq,uired, does iLmeet reguJatiol1s_ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , NA _ _ _ _ _ _ _ DiYerter waive_d_on_SoF'ad. , _ _ _ _ _ _ _ _ _ _ _ _ _ , _ , , _ _ _ _ _ _ _ _ _ , _ _ , ,
28 _DJillillg fluid_program schem¡;¡tic& equip Jistadequ¡:¡te_ _, ,_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , ,Yes _ _ _ _ _ _ _ M¡;¡J( MWJD,O_ppg._ _ _ _, ,,_ _ _ _ _ _ _ _ _ _ _ _ , , , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , ,
29 BOPEs, do they meetreguJatiol1 , _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ Yes _ _ _ , , , _ _ _ _ _ _ _ _ _ _ _ _"", _ _ _ _ , _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ ,
30 _BOPE_pre.ss raiillg ¡¡ppropriate;testto_(puJ PSig in _commel1ts) _ _ _ _ _ _ , _ , , , , Yes _ _ _ _ _ Test tp _50QO_ psi. _MSF' 2732 psi. _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _
31 _C,hoke,manifold çompJies w/APt RF'-53 (May 84>- _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ Yes _ _ _ _ _ _ _ , _ _ , _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ ,_ ,_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _
32 Work wiU OCCur withoutoperatjon _shutdown, , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ , _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ , , _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ , _ _ _ , ,
33 J$ pre$ence of H2S g¡¡S_ prob_able _ _ , , _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ Yes _ _ _ _ _ , , 70 ppm.. _ ,_ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ ,
34 Meçha_nicaLCOl1dilioI1P{we.IISwithil1AORYerified(for_s_erviceweU0 nlyj_ _ _ _ _ _ _, "NA _ _ _ _ _ _ _ _ _ _, _ _ _ _, _ _ _ _ _ _ _" _ _ _ _ _ _ _ _ _ _, _" _ _,,_
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35 Permit c,al1 be issued wlo hydrogen sulfide me¡¡S_Ures _ _ , , ,
36 DatapJesellted on pote_ntial oveJpressurezOl1eJ> _ _ _ _ _ , ,
37 _Seismic_analysjs of shaJlow gaszPlles_ _ _ _ _ _ _ _ _ _ _ _
38Se¡;¡bed _col1ditioll survey (if off-shore) _ _ _ _ , , , _ ,
39 ,Contact l1amelpJ1oneJorweekly progress reports [e¡cploratory _only]. _ , ,
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Engineering
Commissioner:
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Public
commissio~e
